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205-073
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. 5 - Q ~ ~ Well History File Identifier Organizing (aone> RE CAN Color Items: ~Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY o..o,aaa iiuuuiiiimuii DIGITAL DATA Diskettes, No. I ^ Other, No/Type: Date: ~ ~ /pLq' ae,~a~~e~~ Illllllllfllllllll OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ ~_~ f Project Proofing III IIIIII IIIII (IIII BY: -Maria Date: ~ a.. 0 /s/ ~~ Scanning Preparation _~ x 30 = 3 (~ + l I =TOTAL PAGES (Count does not include cover sheet) ~~ BY: Maria Date: I 1 I ~ C/ I ~ 7 /sl Production Scanning Stage 1 Page Count from Scanned File: _~ (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: ~ YES NO BY: Maria Date: ~ r ~ d~~ O /sl !!! 7 -M, Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II it II I lI ~ (IIII ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked Ill (I'lll ~`t II'I II 10/6/2005 Well History File Cover Page.doc • STATE OF ALASKA t ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 8/20/2011 205 - 073 311 - 206 3. Address: 6. Date Spudded: 13. API Number. P.O. Box 196612, Anchorage, Alaska 99519 - 6612 6/20/2005 50 029 - 21615 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 6/27/2005 PBU 18 -12B 4113' FSL, 4552' FEL, SEC. 19, T11 N, R15E, UM 8. KB (ft above MSL): 47' 15. Field / Pool(s): Top of Productive Horizon: 1449' FSL, 1512' FWL, SEC. 20, T11 N, R15E, UM GL (ft above MSL): 17.04' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth ( MD+TVD): Oil Pool 2228' FSL, 606' FWL, SEC. 20, T11N, R15E, UM 3264' 3065' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 692168 y 5960712 Zone ASP4 13914' 8732' ADL 028321 TPI: x- 698309 y- 5958207 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 697380 Y 5958962 Zone- ASP4 N/A 18. Directional Survey: 0 Yes Si No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 MC 25.071): 22. Re- Drill/Lateral Top Window MD/TVD: MWD / NGP, GR / ROP 11864' 8741' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surface 110' 30" 1610# Poleset 13 -3/8" 68# / 72# K-55 / L -80 Surface 2830' Surface 2698' 17 -1/2" 2500 sx Coldset III. 400 sx C II 9-5/8" 47# L -80 Surface 9935' Surface 8304' 12 -1/4" 500 sx Cc lass 300 sx CS I 7" 29# L -80 9631' 11830' 8154' 8738' 8 -1/2" 450 sx Class 'G' 4-1/2" 13.5# N -80 11707' 11864' 8728' 8741' 8 -1/2" Uncemented Slotted Liner 2 -3/8" 4.7# L -80 11628' 13914' 8723' 8732' 3" 60 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open .SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 3 -1/2 ", 9.3#, N -80 3628' - 11730' 11732' / 8730' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. RECEIVED' DEPTH INTERVAL Set 3 C gp A (MD) AMOUNT AND KIND OF MATERIAL USED SEP 16 2011 8200' (TOC) Punch Tubing & Plug w/ 79.6 Bbls Class 'G' 3285' Set EZSV Alaska oil & Gas Cons. Commission 3264' Set Whipstock 27. Anchorage PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL-BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes Si No Sidewall Core(s) Acquired? ❑ Yes Si 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. ';-: 4,NNED SEP 2 8 ZU1'i None RBDMS SEP 19 2011 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit Original Only 29. GEOLOGIC MARKERS (List all formations and markeScountered): 30. FilIATION TESTS NAME MD TVD Well Tested? ❑ Yes ■■ No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. (From 18 -12A) None Sadlerochit 9915' 8296' 21 TS / Zone 2A 10970' 8628' Zone 1B 11226' 8686' TDF / Zone 1A 11711' 8728' Formation at Total Depth (Name): TDF / Zone 1A 11711' 8728' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing 's true and correct to the best of my knowledge. V Signed: Terrie Hubble MA , tk,(g Title: Drilling Technologist Date: /� ( / PBU 18 - 12B 205 - 073 311 - 206 Prepared By Name/Number. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Mel Rixse, 564-5620 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 well sundry report when the downhole well design is changed. Item la: Classification of Service Welds: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123 - 00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only TREE= , 3 -1/8" FMC SAFETY NO. FHL/TIW HBBP PACKERS HAVE WELLHEAD = FMC REDUCED T PRESSURE LIMITS IN SOME CASES. AGTUATOR = AXELSON 18 -1 2 B CONTACT WIE (x5102) PRIOR TO PRESSURE TESTING. KB. ELEV = 47' WELL ANGLE> 70° @ 10097' & > 90° @ 12183'. BF. ELEV = 23.8' ORIGINAL 4 -1/2" LNR FROM PARENT WELL NOT KOP= 1200' 4E SHOWN ON DIAGRAM Max Angle = 98 @ 12705' Datum MD = WA 2268' I-I -1/2" CAMCO TRDP -1A TRSV, ID = 2.812" I Datum TV D = 8800' SS 01.1,2 2268' ]-I 3-1/2" HOLD OPEN SLV, ID = 2.31" (07/28/11) I 13 -3/8" CSG, 72 #, L -80, ID = 12.347' H 2830' I-- , GAS LIFT MANDRELS gi l i ST MD TVD DEV TYPE VLV LATCH PORT DATE JET CUT TBG (07/26/11) 1 3628' . 1 3790 3503 34 CA -MMG -2 DMYI RK 0 03/20/10 'ESTIMATED TOP OF CMT (07/24/11) -I 8200' 4 : 4 ���■x 9308' - 9313' TUBING PUNCH (07/08/11) Soo' 4-• ∎•••••41 I 4/174 .2.3 •M.S C ■ 9399' —13-1/2" OTIS X NIP, ID = 2.813" 19-5/8" X 7" TM/ LNR HG I 9631' 1- , 9496' - 9500' I I TUBING PUNCH (07/08/11) 1 ••••� I 9599' H 3 -1/2" HES CIBP (07/07/11) 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 9935' I--- ITBG PUNCH (09/13/10) I -1 11396' - 11401' I-- • 11584' CTU H 3 -1/2" HES CIBP (09/13/10) I Minimum ID = 1.745" @ 11628' SEAL ASSY (LNR TOP PKR) ' 11600' - 3 -1/2" CIBP(08/27/10) 11607' - FISH: 11.5' SL TOOLSTRING (08/26/10) i 74 ID 1 11628' ]-I BKR LNR TOP PKR & SEAL ASSY, = 1.745" I 11644' H 2.70" BKR DEPLOY SLV, ID = 2.250" I 11644' I-I EST TOP OF CEMENT LNR 1 ►I 1 4 1 1 A r4 11718'_ flTNV OVERSHOT ASSY, ID = 4.75" (BEHIND PIPE) • ■ 3 -1/2" TBG -PC, 9.3 #, N -80, .0087 bpf, ID = 2.992" 11718' H 1 04 ∎i 11720' H TIW POLISHED RISER W/ 2.813" X- PROFILE (BEHIND PIPE) ► I �` 11730' I -I BTM OF TNV OVERSHOT ASSY (BEHIND PIPE) I • 4 • 4 11732' I-1 7" X 4 -1 /2" TIW SS PKR, ID = 3.00" (BEHIND PIPE) 1 • 4 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 11830' F__ ► 1 '1 MILLED WINDOW (18 -12B) 4 . 11864' - 11871' (MECHANICAL WHIPSTOCK (06/18/05) H 11862' „ > � RA TAG' 11870' ► ; � 4 ��1� • ►j'∎ . 1 12382' I-I MARKER w /PUP JNT 1 PERFORATION SUMMARY • ' . C. REF LOG: MWD /NGP GR/ROP ON 06/28/05 ` TIE -IN LOG: GEOLOGY PDC LOG I I ANGLE AT TOP PERF: 86° @ 11575' Note: Refer to Production DB for historical perf data 13809' - CLEANOUT BY SIZE SPF INTERVAL Opn /Sqz DATE ` RIG (06/30/05) 2 -1/2" 6 11575 - 11580 C 09/15/10 S. 2 -1/2" 6 11590- 11595 C 08/29/10 1- 9/16" 6 12560 - 13120 C 07/03/05 1- 9/16" 6 13190 - 13290 C 07/03/05 1- 9/16" 6 13400 - 13630 C 07/03/05 �;" 1- 9/16 6 13700 - 13780 C 07/03/05 ( PBTD H 13878 `,,1.• 13 12-3/8" LNR, 4.7 #, L -80, STL, .0036 bpf, ID = 1.92" I—{ 13914' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/23/86 ORIGINAL COMPLETION 07/30/11 CJN/ PJC SET HOLD OPEN SLV WELL: 18 -12B 11/08/97 CTD SIDETRACK PERMIT No: 2050730 07/04/05 NORDIC( CTD SIDETRACK API No: 50-029-21615-02 07/28/11 SRD/ PJC TBG PUNCH/SET CIBP (07/08/11) SEC 19, T11 N, R15E, 1166' FNL & 402' FWL 07/28/11 RLM/ PJC P &A (7/24/11) 07/28/11 JCM/ PJC JET CUT (7 /26/11) 1 BP Exploration (Alas ka) • 18 -12B, Well History (Pre Rig Sidetrack) Date Summary 09/27/10 RIH with 2.70" drift to 11613'. POH. RIH with PDS MCCUGR and tag bottom at 11612' uncorrected. Log tie -in log up to 9200' three times. Last pass had no depth error between SWS and PDS. POH and eik download data. Add 1 ft to PDS depth top put on depth with SWS. M/U Halco 3 -1/2" CIBP and setting tools. RIH and set CIBP at 11600'. PT plug to 1000 psi - Pass. POOH. 09/28/10 POOH and RD HES setting tool. MU and RIH w/ 5' of 4 spf TBG punch. Tag CIBP. Position tbg punch and fire gun, shooting 11590' - 11595'. Press test tubing x IA. No communication. POH all shots fired. Prep to run 5' perf gun. Found pinhole in coil at 4550' during press test at surface. Blowdown coil and rig down CTU for reel swap. Conduct Emergency Drill. Blow down reel w/ N2. Go to shop to swap reels. 09/29/10 Move in and rig up. Circ 1.25" ball. Press test BOPE. RIH w /5' perf gun, shoot 6 spf from 11590' - 11595'. Could not establish circ. Pumped 30 bbl's of 50/50 MEOH down IA. POOH, M/U Memory SCMT after discussion w/ town Engr. RIH w /tool string. 09/30/10 RIH w /SCBL, log 1 pass from 11580' to 9580', short pass from 11580' to 11,080'. POH. Send MSCBL log to Anc Eng. Log shows free pipe from 11576' to top of 7" liner. Perform injectivity test. No communication between tubing and 1A. 0.75 BPM injectivity into formation from perfs at 11590' - 11595'. Rig down. Press test Tree cap. 09/04/10 WELL SHUT -IN ON ARRIVAL. INITIAL T /1 /O: 0/150/150 PSI. RIH WITH RST AND WELLTEC TRACTOR. LOG BASELINE GR PASS FROM 11590' TO 9600'. 09/05/10 LOG RST GRAVEL PACK FROM 11590' TO 9600'. LOGGED BASELINE GR PASS FROM 11600' - 9600' AT 30 FPM FOLLOWED BY AN ACTIVATED GR PASS OVER THE SAME INTERVAL AT 5 FPM. A DEFINITE SHIFT WAS SEEN IN THE GR CURVE AT 9964'. TOP GRAVEL DEPTH INCONCLUSIVE. LOGGED UP BASELINE AND ACTIVATED PASS FROM 9600' TO 8600' TO SEARCH FOR A STRONGER GR SHIFT. NO SHIFT SEEN. LOGGING ACROSS THE GLM 0T 37� 90' ALSO SHOWED NO GR SHIFT. FINAL T /1 /O: VAC/150/150 PSI. JOB COMPLETE. r ` , �,,,,��a 09/13/10 M/U Nalco 3 -1/2" CIBP and setting tools. RIH and set CIBP at 11584'. PT plug to 3000 psi - Pass. POOH. RIH w / 1.56" tubing punch tag CIBP correct depth & shoot holes with top shot @ 11396' bottom @ 11401'. At surface confirmed hole in tubing punch recovered 1/2" ball. RIH w/ cementing BHA to CIBP. Attempt to re- establish circulation. At 0.1 bpm : 3800 psi CT psi up to 3900 psi. Attempt to increase to 0.25 bpm. WHP= 3900 CT psi = 4000. Call ADE to discuss options, begin pumping at 0.1 bpm down CT, taking returns up IA. Getting less than 1:1 returns at Max pressures (CT pump pressure =3850 psi, IA= 100 psi). After 90 mins of circulating up IA, trying to establish good circulation there is no improvement in circulation pressures. Decision made to POOH and RDMO. 09/14/10 Perform Weekly BOP test. RDMO. JOB ENDED. 09/15/10 MIRU CT. RIH with WOT BHA and 5' x 2.5" PF and PJO charges at 6 shots per foot. Tagged CIBP PUH corrected to bottom shot, fired from 11575' - 11580', attempt to obtain injectivity. 09/16/10 Attempt to establish injectivity after shooting 2.5" gun. Injectivity is 0.2 bpm at 3300 psi WHP. IAP did not change. Not able to establish good injection rate. Confirmed gun fired. RDMO. Job Complete. 09/22/10 T /I /O = VAC/280/140. Temp = SI. MIT -IA to 2500 psi PASSED, LLR if fails (Establish injectivity). TBG FL @ 240' (3 bbls). IA FL @ surface (liquid /foam). Bled IAP to 70 psi in 5 min (FTS). Used 6.54 bbls DSL to pressure IA from 70 psi to 2500 psi. OAP increased to 160 psi. IAP lost 70 psi in 1st 15 min and 10 psi in 2nd 15 min for a total loss of 80 psi in 30 min. Bled IAP to 380 psi. Monitored during rig down. IAP increased to 480 psi. Job complete. Final WHPs = VAC/480/140. 10/15/10 T /I /O= 0/500/100 TEMP= SI RG 2401 (SURFACE CASING CORR MITIGATION) PJSM. SET UP HYDRO VAC AND JOB SITE. DTART AND COMPLETE EXCAVATION ON WELL CELLAR. RDMO. TOP PLATE, NO TREAT. Page 1 of 4 • 18 -12B, Well History (Pre Rig Sidetrack) Date Summary 01/19/11 T /I /O =0 +/500/50, Temp =SI. PPPOT-T (PASS), PPPOT -IC (FAIL), RWO screen. PPPOT -T: Stung into test port (100 psi), bled to 0 psi. Functioned LDS, all moved freely (1 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in secondl5 min (PASS). Bled void to 0 psi. PPPOT -IC: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS, all moved freely (1"). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 1000 psi in 15 min. Re- torqued LDS. Pressured void to 3500 psi, lost 1000 psi in 15 min (FAIL). Bled void to 0 psi. 01/29/11 T /I /0= 0/440/150 Temp =SI MIT OA 2000 psi PASSED (CTD /RST Prep Unsuccessful) Pumped 2.9 bbls of 0° meth down OA to reach 2000 psi for MIT OA 1st test 1st 15 min lost 80 psi 2nd 15 min lost 20 psi for a total of 100 psi in 30 min bleed OAP down bleed back aprox. 2+ bbls. Final Whp's= 0/460/160 06/17/11 T /I /0 = SSV/490/280. Temp =SI. IA FL (Pre MIT). No AL. IA FL @ surface. 06/17/11 T /I /0= 0/488/360 ( MITx OA to 2000 Psi / MITx IA to 2500 Psi / Injectivity test on TBG) Arrive on location / Get permitted / Riq to OA / Start Low Press. equipment test. 06/18/11 T /I /0= 0/488/360 ( MITx OA to 2000 Psi PASSED / MITx IA to 2500 Psi PASSED / Injectivity test down TBG) Rig up to OA / Pump 1.7 bbls dead crude to achieve a test press. of 2000 Psi. (MITx OA) OA lost 82 Psi in 1st 15 Min and lost 20 Psi in 2nd 15 Min for a total loss of 102 Psi in 30 Min test. Bled OA to 255 Psi. / IA leaking by / called grease crew. Rig up to IA and pump 5 bbls dead crude down IA to achieve a test press. of 2500 Psi. ( MITx IA) IA lost 68 Psi in 1st 15 Min and 22 Psi in 2nd 15 Min for a total loss of 90 Psi in 30 Min test. Bled IA to 450 Psi. Rig up to compainion valve. Pumped 16.2 bbls crude down TBG to establish Injectivity rate of .35 bpm at 3200 psi. Pad op notified, tags hung. 06/29/11 WELL S/I ON ARRIVAL. RIH W/ QC, X0, 2.84 NO -GO CENT, SD @ 2248' SLM. DRIFT TUBING W/ 2.7 CENT AND 1 1/2" S. BAILER TO DEVIATION @ 11170' SLM, NO OBSTRUCTIONS, EMPTY BAILER. WELL LEFT S/I ON DEPARTURE. TURN WELL OVER TO DSO. 07/05/11 WELL S/I ON ARRIVAL. RIH W/ 2.84 NO -GO, SD @ 2284'. RIH W/ , 2.84 NO -GO CENT., 5' STEM, 2.70 CENT, 5' STEM, FLAPPER CHECKER W/ 2.5" PINS, INCONCLUSIVE. RIH W/, X0, 2.84 NO -GO CENT., 5' STEM, 2.70 CENT, 5' STEM, 2.5 CENT, FLAPPER CHECKER W/ 2.2" PINS, FLAPPER APPEARS TO BE STUCK OPEN. RIH W/ , 5' x 1 1/2" STEM, 2.70 CENT. MAKE SEVERAL PASSES THROUGH TRSV TO 2350' SLM. TRSV APPEARS TO BE FULLY OPEN. CONTROL HOLDING 5000 PSI. JOB COMPLETE / WELL LEFT SHUT IN ON DEPARTURE. 07/06/11 T /I /0= 170/540/350. Temp =SI. T FL (E -line call -in). No AL. T FL @ 310' ( -5 bbls). IA integral iry9 lied.* 3 07/07/11 WELL SHUT -IN ON ARRIVAL. INITIAL T /I /0= 20/520/320 PSI. SET HES 3.5" CIBP AT MID EL = 9600'. CCL TO ME= 9.8', CCL STOP DEPTH= 9590.2'. TOP OF PLUG= 9598.8'. RIG DOWN DUE TO WIND GUST APPROACHING CRANE LIMITS. FINAL T /I /0= 50/500/300 PSI. 07/08/11 INITIAL T /I /0= 20/520/320 PSI. SHOT 4' LOADED 5' CARRIER OF 2" POWERFLOW 2006 HMX HSD, A 6 SPF, 60 DEG PHASE FROM 9496' - 9500'. ATTEMPTED TO GET COMMUNICATION T- IA AFTER R SHOOTING PUNCHER. PRESSURE TUBING TO 2500 PSI, NO INCREASE IN IA PRESSURE. SHOT 5' LOADED 1.56" SMALL CHARGE TUBING PUNCHER, 4 SPF, 0 DEG PHASE FROM 9308'- 9313'. E- / \ I py LINE RIGGED DOWN, LRS LEFT ON LOCATION TO TRY TO ESTABLISH COMMUNICATION Oa BETWEEN T /IA. FINAL T /I /0= 350/220/280 PSI. JOB COMPLETE. 07/16/11 WELL SHUT IN UPON ARRIVAL. INITIAL T /I /0 = 400/200/250 PSI. ARRIVED TO LOCATION. BEGAN RIG UP, CHECK OF GYRO TOOLSTRING, STARTED PRESSURE TESTING. Page 2 of 4 18 -12B, Well History (Pre Rig Sidetrack) Date Summary 07/17/11 COMPLETED PRESSURE TEST AND BEGAN RIH WITH GYRO TOOLSTRING. TOOL ZERO REFERENCED TO ELEVATION SURVEY FROM BELL AND ASSOC. DATED 16 -JUL -2011. BASE FLANGE ELEVATION = 17.04' AND KB = 47' REFERENCED TO MSL. PERFORMED STOP COUNTS EVERY 50' FROM SURFACE TO 1560' WHERE THE DEVIATION GOES HIGHER THAN 15 DEG. THEN LOGGED DOWN TO 3600' AT 110 FPM. FROM 3600' LOGGED UP TO 1560' AND THEN IN CONTINUOUS MODE STARTED DOING STOP COUNTS EVERY 100' UP TO SURFACE. RIGGED DOWN AND LEFT LOCATION. FINAL T /I /O = 590/200/250 PSI. JOB COMPLETE. WELL SHUT IN UPON DEPARTURE. 07/22/11 T /I /0= 220/260/280 Temp= S/I (Circ -out OBM to tanks) Speared into TBG w/ 10 bbls neat meth followed by 100 bbls DSL, 50 bbls slick 1% KCL, 50 bbls 150K LSRV Geovis, 627 bbls slick 1% KCL, 227 bbls DSL, 293 bbls slick 1% KCL taking returns up IA to tanks. 07/23/11 Circ -out OBM to tanks ( RST prep) Pumped an additional 107 bbls slick 1% KCL & 22 bbls DSL down TBG taking returns up IA to tanks. RD from TBG RU to IA. Pumped 201 bbls DSL down IA taking returns up TBG to tanks. RD from TBG RU to TBG. Pumped 22 bbls DSL down TBG taking returns to tanks. FWHP's= vac/120/120 07/23/11 MIRU CTU. MU and RIH w/ 2.1" OD BDJSN w/ no check valves. 07/24/11 T /I /O= Si /0/0 Temp =SI PPPOT-T (PASS) PPPOT -IC (PASS) (Pre Sidetrack) PPPOT -T : RU 2 HP BT onto THA 50 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD test equipment, re- installed Alemite caps. Cycle and torque LDS "ET style" all functioned with no problems PPPOT -IC : RU 2 HP BT onto THA 50 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, RD test equipment, re- installed Alemite caps. Cycle and torque LDS "ET style" all functioned with no problems. 07/24/11 Continue RIH w/ 2.1" OD BDJSN. Tag CIBP at 9600' elmd. Lay -in 4.5 bbls 15.8 ppg class G cement in tubing. Circulate 67.4 bbls 15.8 ppg class G cement into IA. Lay -in additional 7.7 bbls 15.8 ppg class G cement in tubing. Leave a total of 12.2 bbls cement in tubing from 9600' elmd to PstimatPd Ti)C ping of 8200' elmd. Leave a total of 67.4 bbls cement in IA from 9300' elmd to estimated TOC in IA of 8200' elmd. POOH, FP tubing w/ diesel to 2800' and (IA freeze protected to 3260' and with diesel). Bled IA and tubing down to 200 psi. RDMO. Job complete. 07/25/11 WELL 5/10N ARRIVAL. TAG TOP OF CEMENT AT 7802' SLM W/ 2.80 CENT, 2.50" SAMPLE BAILER (sample of cement). PERFORM MIT -T TO 2500psi - PASSED. WELL LEFT 5/10N DEPARTURE, DSO NOTIFIED OF STATUS. 07/26/11 T /I /O= vac/vac/80 Temp =SI CMIT -TxIA 2500 psi PASSED (RV Prep) Pumped 7.7 bbls diesel down TBG to bring T /IA to 2520/2500. 1st 15 min T /IA lost 50/60 psi, 2nd 15 min lost 20/20 psi for a total of 70/80 psi in 30 min. Bled back TxIAP ( -4.5 bbls). 07/26/11 ARRIVE ON LOCATION WELL SHUT IN. INITIAL T/I/O= 0/0/100 JET CUT TUBING AT 3628' WITH 2.75" POWER CUTTER. FINAL T /I /O = 0/0/100 JOB COMPLETE LEAVE LOCATIONS. 07/28/11 WELL S/I ON ARRIVAL. MIRU SLB #4516 TO SET HOLD OPEN SLEEVE INTO TRSV. 07/29/11 TAG 3 -1/2" CA. TRDP -1A @ 2,252' SLM / 2,268' MD W/ 2.85" NO -GO CENT. SET 3 -1/2" H.O. SLEEVE (2.31" ID, 2.857" no -go, 113" = oal) AT 2,252' SLM / 2,268' MD. WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 07/30/11 T /1/0= 150/200/100 Upon arrival, verified barriers, removed tree cap, attached lubricator and pressure tested 450 /low... 3650 /high....Pass. Set 3 1/8" FMC IS -A BPV #544 thru tree using 1 -1' ext..Tagged @ 92 ". Pre Doyon 25, no problems. Page 3 of 4 • • 18 -12B, Well History (Pre Rig Sidetrack) Date Summary 07/31/11 T /I /O = SSV/240/120. Temp = SI. Bleed WHPs to 0 psi. (Rig Prep). Wellhouse, flowline and scaffolding removed. BPV in hole. IA has integral installed. IA FL @ surface. OA FL near surface. Bled IAP from 240 psi to 0+ psi in 45 min. Bled OAP from 120 psi to 0+ psi in 1 hr 10 min (FTS, gas /fluid slugs). Multiple bleeds, see log for details. Monitored for 30 min. IAP increased 3 psi & OAP increased 10 psi. Continued bleed on OA per WIE. Maintained open OA bleed for 1 hr 40 min. Monitored for 30 min. OAP increased 6 psi. Final WHPs = SSV /3/6. 08/01/11 T /I /0= BPV /0 +/40. Temp= SI. WHPs (Rig Prep). No AL, flowline, scaffold or wellhouse. Integral installed on IA. OAP increased 34 psi overnight. 08/06/11 T /I /O =BPV /0/46. Temp =SI. Bleed OAP to 0 psi (Rig prep). No AL, flow line, well scaffold, or well house. OAP increased 6 psi since 8/1/11. OA FL is near surface. Bled OAP, to BT, from 46 psi to 0 psi in 4 hrs (gas). Monitor for 30 min. OAP increased to 0 +. Job complete. Final WHPs = BPV /0/0 +. 08/07/11 T /I /O = SSV /0/15. Temp =SI. Monitor WHPs. No AL, flowline, or scaffold. OAP increased 15 psi overnight. Page 4 of 4 • • North America - ALASKA -,BP Page 1 awe Operation Summary Report Common Well Name: 18 -12 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/9/2011 End Date: X3- 0106Y -C: (8,376,273.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: DOYON 25 Spud Date/Time: 11/9/1986 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292161500 Active Datum: 18 -12C Actual @56.29ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/9/2011 12:00 - 20:00 8.00 MOB P PRE CONTINUE TO PREP FOR RIG MOVE TO DS-18 - SCOPE DOWN DERRICK AND PIN TOP DRIVE - FINISH SECURING WELL A -25B - BLOW DOWN MUD LINES - WELD ROLLER ON WIRE LINE DOOR - SECURE IRON DERRICKMAN - RAISE C- SECTION WIND WALL 20:00 - 22:00 2.00 MOB P PRE SKID MOTOR, PUMP, AND PIT COMPLEX AWAY FROM SUB. 22:00 - 00:00 2.00 MOB P PRE PJSM. SKID RIG FLOOR AND LOWER DERRICK. - WALK CASING COMPLEX AWAY FROM DRILLPIPE COMPLEX 8/10/2011 00:00 - 12:00 12.00 MOB N WAIT PRE WAIT ON SUPPORT FOR RIG MOVE DUE TO RIG MAT SHORTAGE. - USE PEAK SOW TO STAGE CASING, POWER, PUMP, AND PIT MODULES ON A PAD IN PREPARATION FOR RIG MOVE TO DRILL SITE 18. - PERFORM 50' TURN WITH DRILLPIPE SHED AND SUB USING STOMPERS 12:00 - 00:00 12.00 MOB N WAIT PRE CONTINUE TO WAIT ON RIG MATS FOR RIG MOVE DUE TO 7ES RIG MOVE - HOLD PRE -SPUD MEETING WITH BOTH CREWS - PERFORM GENERAL HOUSEKEEPING ON PARTS TRAILERS AND BOP DECK - CHANGE OUT TOP DRIVE RAIL SHOES AND WORK ON PREVENTATIVE MAINTENANCE ITEMS 8/11/2011 00:00 - 12:00 12.00 MOB N WAIT PRE CONTINUE TO WAIT FOR RIG MATS FOR RIG MOVE FROM A PAD TO DRILL SITE 18 - BUILD AND INSTALL CUSHIONS FOR ACCUMULATOR ROOM TO DRILLPIPE SHED DOORWAYS - CLEAN DERRICK, PIN JEEP TO SUB, ORGANIZE TRUCK SHOP AND PARTS VAN. 12:00 - 00:00 12.00 MOB N WAIT PRE CONTINUE TO WAIT FOR RIG MATS - CONTINUE GENERAL HOUSEKEEPING IN DERRICK AND RIG SHOP - CHANGE OUT HYDRAULIC FITTINGS ON BOP STACK AND CONTINUE WORKING ON CUSHIONS FOR INTERCONNECTS 8/12/2011 00:00 - 11:00 11.00 MOB N WAIT PRE CONTINUE TO WAIT FOR RIG MOVE ON A PAD WHILE RIG MATS ARE BEING LAYED ON A PAD AND DS 18 - PERFORM GENERAL HOUSEKEEPING AND PREVENTATIVE MAINTENANCE ITEMS 11:00 - 00:00 13.00 MOB P PRE MOVE RIG SUB AND CASING SHED COMPLEX TO DRILL SITE 18 - SPOT AND SHIM SUB OVER WELL 18 -12 WHILE ROUND TRIPPING SOWS TO A PAD TO GET REMAINING RIG MODULES. Printed 9/6/2011 1:26:57PM Ilirth America - ALASKA - BP Page 2 *bee Operation Summary Report Common Well Name: 18 -12 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/9/2011 End Date: X3- 0106Y -C: (8,376,273.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: DOYON 25 Spud Date/Time: 11/9/1986 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292161500 Active Datum: 18 -12C Actual @56.29ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/13/2011 00:00 - 13:00 13.00 MOB P PRE CONTINUE MOVING RIG MODULES FROM A PAD TO DRILL SITE 18 - MOVING TWO MODULES AT A TIME, PULLING EACH MODULE WITH TWO SOWS. - SPOT DP COMPLEX NEXT TO SUB AND SECURE - SPOT CASING SHED NEXT TO DP SHED 13:00 - 20:30 7.50 RIGU P PRE PERFORM DERRICK INSPECTION, RAISE DERRICK, AND SKID RIG FLOOR. - FINISH SPOTTING PITS, CASING SHED, PUMPS, AND MOTOR COMPLEX 20:30 - 00:00 3.50 RIGU P PRE RIG UP AND CONNECT ALL MODULES. - LOWER C- SECTION - RAISE CATTLE CHUTE AND PIN IN PLACE - WORK ON CONNECTING ELECTRICAL CABLES AND SERVICE LINES 8/14/2011 00:00 - 07:00 7.00 RIGU P PRE CONTINUE RIGGING UP ON 18 -12C - TAKE ON 8.5 PPG SEAWATER TO THE PITS - RIG UP TO PRESSURE TEST OA AND T X IA USING RIG INJECTION PUMP - FINISH CONNECTING ELECTRICAL CABLES AND SERVICE LINES NOTIFIED MATT HERRERA WITH AOGCC OF UPCOMING BOPE TEST AT 06:50 HRS RIG ACCEPT ON 8/14/2011 AT 02:00 HRS 07:00 - 09:00 2.00 RIGU P PRE MIT OA TO 250 PSI FOR 5 MIN AND 2000 PSI FOR 30 MIN - TEST PASSED - 4.3 BBLS TO REACH TEST PRESSURE - LOST 71 PSI IN FIRST 15 MIN - LOST 20 PSI IN SECOND 15 MIN - 4.3 BBLS RETURNED MIT T X IA TO 250 PSI FOR 5 MIN AND 2000 PSI FOR 30 MIN - TEST PASSED - 1.1 BBLS TO REACH TEST PRESSURE - LOST 61 PSI IN FIRST 15 MIN - LOST 24 PSI IN SECOND 15 MIN - 1.1 BBLS RETURNED RIG DOWN TEST EQUIPMENT 09:00 - 11:30 2.50 WHSUR P DECOMP PJSM. PICK UP LUBRICATOR TO RIG FLOOR. - R/U AND TEST TO 250 PSI FOR 5 MIN AND 3500 PSI FOR 5 MIN. GOOD TEST. - PULL BPV R/D LUBRICATOR 11:30 - 14:00 2.50 RIGU P DECOMP PERFORM DERRICK INSPECTION AND SCOPE DERRICK UP. R/U TO DISPLACE FREEZE PROTECT. 14:00 - 16:30 2.50 WHSUR P DECOMP PJSM FOR DISPLACING FREEZE PROTECT. - PI IMP 30 RRI S 8 5 PPG SEAWATER DOWN IA AND DISPLACE FREF7F PROTFCT TO 500 BBL OPEN TOP TANK. - R/U AND PUMP 230 BBLS SEAWATER DOWN TUBING, TAKING RETURNS TO OPEN TOP TANK. - 21 BBLS OF DIESEL RETURNED FROM TBG, 201 BBLS OF DIESEL RETURNED FROM IA. - TOTAL VOLUME PUMPED 260 BBLS, TOTAL VOLUME RETURNED 260 BBLS. - MONITOR WELL FOR 10 MIN - STATIC. 16:30 - 17:30 1.00 WHSUR P DECOMP DRY ROD IN BPV. Printed 9/6/2011 1:26:57PM i•rth America - ALASKA - BP Page 3 ear Operation Summary Report Common Well Name: 18 -12 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/9/2011 End Date: X3- 0106Y -C: (8,376,273.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: DOYON 25 Spud Date/Time: 11/9/1986 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292161500 Ac tive Datum: 18 -12C Actual @56.29ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 19:30 2.00 WHSUR P DECOMP TEST BPV FROM BELOW TO 250 PSI LOW / , 2000 PSI HIGH FOR 5 MIN - GOOD TEST. - R/D TEST EQUIPMENT AND B/D LINES. 19:30 - 22:00 2.50 WHSUR P DECOMP DRAIN TREE AND WD. INSPECT AND CLEAN THREADS ON TBG HANGER - GOOD. - INSTALL BLANKING PLUG WITH 6.5 LEFT HAND TURNS ONTO HANGER. - REMOVE RUNNING TOOL FROM BLANKING PLUG WITH 8.5 RH TURNS OPEN ALL RAM DOORS ON BOP AND VISUALLY INSPECT PER HIGH GOR SOP. INSPECTION WITNESSED BY BP WSL GARRET STAUDINGER AND DOYON TOURPUSHER JOHN NEWMAN. 22:00 - 23:00 1.00 WHSUR P DECOMP HOLD PRE -SPUD MEETING AND TABLE TOP RIG EVAC DRILL WITH CREW. 23:00 - 00:00 1.00 BOPSUR P DECOMP P/U AND INSTALL 11 "X 13 -5/8" DOUBLE STUDDED ADAPTER TO TUBING SPOOL. 8/15/2011 00:00 - 06:00 6.00 BOPSUR P DECOMP CONTINUE N/U BOPE. RN 1.5' AND 14' HIGH PRESSURE RISER SECTIONS IN BOP DECK AND M/U TO 11 "X 13 -5/8" DSA. N/U HIGH PRESSURE RISER SECTIONS. MOVE STACK INTO PLACE, R/U CHOKE HOSE AND MOVE FLOW LINE BOX. 06:00 - 07:00 1.00 BOPSUR P DECOMP R/U TEST EQUIPMENT. - PERFOM KICK WHILE TRIPPING DRILL, 17 -BBL TO FILL GAS BUSTER. 07:00 - 12:00 5.00 BOPSUR P 9.29 DECOMP Tc.ST BOPE TO 250 PSI LOW, 3500 PSI HIGH AS PER AOGCC AND BP POLICY. TEST Q© ANNULAR PREVENTER TO 250 PSI LOW, 3500 1 W� PSI HIGH. EACH TEST 5 CHARTED MINUTES. "( TEST THE UPPER VARIABLES AND LOWER VARIABLES WITH 3 -1/2 IN AND 5 IN TEST JOINTS. TEST THE ANNULAR PREVENTER WITH 3 -1/2 IN TEST JOINT. NO FAILED TESTS. TEST WITNESS WAIVED BY MATT HERRERA WITH AOGCC. TEST WITNESSED BY WSL MITCH SKINNER AND TOOLPUSHER SAM DYE. PERFORMED ACCUMULATOR TEST: SYSTEM PRESSURE 3,050 PSI, PRESSURE AFTER CLOSING ALL RAMS AND ANNULAR PREVENTER 1,850 PSI. RECOVERED 1ST 200 PSI - 38 SECONDS. 6 NITROGEN BOTTLES, AVERAGE PRESSURE = 2,450 -PSI. CLOSING TIMES - ANNULAR = 24 SECONDS - UPPER VBR = 19 SECONDS - BLIND /SHEARS = 16 SECONDS - LOWER VBR = 16 SECONDS - CHOKE HCR = 2 SECONDS - KILL HCR = 2 SECONDS 12:00 - 13:00 1.00 BOPSUR P 9.29 DECOMP B/D & R/D TEST EQUIPMENT. - RE -ALIGN VALVES. - BRING IN LUBRICATOR THROUGH THE PIPE SHED. 13:00 - 14:00 1.00 BOPSUR P 9.29 DECOMP PULL BLANKING PLUG WITH DRILL PIPE AND L /D. - P/U LUBRICATOR EXTENSION & CONTROL LINES UP SLIDE. Printed 9/6/2011 1:26:57PM ;rth Arr►erica - ALASKA - BP Page 4 ewe Operation Summary Report Common Well Name: 18 -12 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/9/2011 End Date: X3- 0106Y -C: (8,376,273.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: DOYON 25 Spud Date/Time: 11/9/1986 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292161500 Active Datum: 18 -12C Actual @56.29ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 16:30 2.50 BOPSUR P ■ 9.29 DECOMP P/U DUTCH RISER & SET IN PLACE, RILDS. - P/U LUBRICATOR AND ATTACH TO DUTCH RISER. 16:30 - 17:00 0.50 BOPSUR N SFAL 9.29 DECOMP ATTEMPT TO PRESSURE TEST LUBRICATOR & DUTCH SYTEM AGAINST TOP OF BLIND /SHEARS, TEST FAILED. - PRESSURE LEAKING PAST BLIND /SHEARS. 17:00 - 19:00 2.00 BOPSUR N SFAL 9.29 DECOMP TROUBLESHOOT, ATTEMPT TO RE -TEST, TEST FAILED 19:00 - 19:30 0.50 BOPSUR N SFAL 9.29 DECOMP RE- INSTALL BLANKING PLUG & RE -TEST PLUG & BLIND /SHEARS FROM BOTTOM, TEST PASSED. - 250 -PSI LOW / 3,500 -PSI HIGH FOR 5 -MIN 19:30 - 23:30 4.00 BOPSUR N SFAL 9.29 DECOMP CONSULT TOWN, DRAIN STACK. - OPEN BLIND /SHEARS DOORS - REMOVE BLIND /SHEARS AND INSTALL NEW BLIND RAMS 23:30 - 00:00 0.50 BOPSUR N SFAL 9.29 DECOMP R/U TEST EQUIPMENT. - TEST BLIND RAMS AGAINST BLANKING PLUG TO 250 -PSI LOW / 3,500 -PSI HIGH FOR 5 -MIN, TEST PASSED 8/16/2011 00:00 - 02:00 2.00 BOPSUR N SFAL DECOMP PULL BLANKING PLUG WITH DRILLPIPE. R/U DUTCH RISER AND LUBRICATOR -TEST LUBRICATOR AGAINST BLIND RAMS TO 250 PSI LOW / 3500 PSI HIGH FOR 5 MIN EACH - GOOD TEST 02:00 - 04:00 2.00 BOPSUR N SFAL _ DECOMP ATTEMPT TO PULL BPV WITH LUBRICATOR WITH TWO ATTEMPTS, NO SUCCESS. 04:00 - 05:00 1.00 BOPSUR P -_ DECOMP CHANGE PULLING TOOL. PULL BPV WITH LUBRICATOR. 05:00 - 06:00 1.00 BOPSUR P DECOMP R/D LUBRICATOR AND DUTCH RISER SYSTEM. 06:00 - 10:00 4.00 PULL P DECOMP, RIC; UP TO PULL TUBING - C/O SAVER SUB TO 4 -1/2" IF - R/D LONG BAILS - R/U MEDIUM BAILS WITH BX ELEVATORS AND ROTATOR - CLEAN & CLEAR RIG FLOOR 10:00 - 11:30 1.50 PULL P -_ DECOMP P/U LANDING JT & R/U CIRC EQUIPMENT. BOLDS AS PER FMC REP. 11:30 - 14:00 2.50 PULL P DECOMP PULL TUBING 5' & MONITOR WELL (STATIC). - PULL HANGER FREE WITH NO OVERPULL, 70K UP WEIGHT - REVERSE CIRC 40 BBL SOAP PILL FOLLOWED BY 300 BBL SEAWATER TO OPEN TOP TANK - 126 GPM, 190 PSI 14:00 - 14:30 0.50 PULL P -_ DECOMP BLOW DOWN & RIG DOWN CIRC EQUIPMENT. MONITOR WELL - STATIC 14:30 - 16:00 1.50 PULL P ._ DECOMP PULL TBG HANGER ABOVE RIG FLOOR AND LD. 16:00 - 23:00 7.00 PULL P DECOMP LD 3.5" TUBING FROM 3628' MP TO SURFACE. - RECOVERED 115 JOINTS, ONE 2.70' CUT JT, CONTROL LINE, AND 38 STEEL BANDS MONITOR WELL ON TRIP TANK, HOLE TAKING CALCULATED FILL. 23:00 - 23:30 0.50 PULL P -_ DECOMP CLEAN AND CLEAR RIG FLOOR, UD CSG RUNNING TOOLS, C/O SLIP INSERTS. 23:30 - 00:00 0.50 CLEAN P DECOMP INSTALL WEAR RING Printed 9/6/2011 1:26:57PM •rth America - ALASKA = BP • Page 5 ef-e Operation Summary Report Common Well Name: 18 -12 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/9/2011 End Date: X3- 0106Y -C: (8,376,273.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: DOYON 25 Spud Date/Time: 11/9/1986 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292161500 Active Datum: 18 -12C Actual @56.29ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/17/2011 00:00 02:00 2.00 CLEAN P ■- DECOMP E JOINT, CONTINUE R/D CASING EQUIP. & & RU BHA HANDLING EQUIP. PJSM, P/U 5" DP 02:00 - 04:00 2.00 CLEAN P DECOMP u : ► • : • : - - 8 -1/2" USED MILL TOOTH BIT, BOOT BASKETS (2), WATERMELON MILL, DRILL COLLARS, 5" HWDP. - RIH TO 865' MD, MONITOR HOLE ON TRIP TANK 04:00 - 10:30 6.50 CLEAN P DECOMP RIH WITH CLEANOUT BHA ON 5" DP SINGLES - TAG TUBING STUB 3643' MD - POOH TO 3280' MD, MONITOR DISPLACEMENT ON TRIP TANK - P/U WT = 117K, S/0 WT = 110K 10:30 - 11:30 1.00 CLEAN P DECOMP ROTATE, RECIPROCATE, & CIRCULATE - F/ 3280' MD, T/ 3220' MD - PUMP 22 BBL SOAP PILL, 600 GPM, 2250 PSI - OBTAIN SLOW PUMP RATES AND MONITOR WELL STATIC) 11:30 - 17:30 6.00 CLEAN P DECOMP POOH ON ELEVATORS TO SURFACE - POOH FROM 3220' MD TO SURFACE - MONITOR HOLE FILL ON TRIP TANK, WELL TAKING CALC FILL. 17:30 - 18:30 1.00 CLEAN P -_ DECOMP RACK BACK HWDP & COLLARS L/D SCRAPER AND BOOT BASKETS (EMPTY 18:30 - 19:00 0.50 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR 19:00 - 00:00 5.00 CLEAN P DECOMP SINGLE IN HOLE W/ 5" DP FROM PIPESHED T/ 2919' MONITOR HOLE ON TRIP TANK, HOLE GIVING PROPER DISPLACEMENT 8/18/2011 00:00 - 02:00 2.00 CLEAN P DECOMP RIH WITH 5" DP SINGLES FROM PIPE SHED MONITOR HOLE ON TRIP TANK, HOLE GIVING PROPER DISPLACEMENT STARTED MONITORING OA AT 00:00 HRS AS PER PACK -OFF CHANGE OUT SOP. 02:00 - 03:00 1.00 CLEAN P DECOMP RESPOND TO INJURED PERSON WITH BP MEDICAL TEAM. - HELD AAR / SAFETY STAND DOWN WITH CREW 03:00 06:00 3.00 CLEAN P ■- DECOMP POOH STANDING BACK 5" DP MONITOR HOLE FILL ON TRI P TANK, WELL TAKING CALC FILL. 06:00 - 09:30 3.50 CLEAN P DECOMP SINGLE IN HOLE WITH 5" DPTO 2,072' MD. MONITOR DISPLACEMENT ON TRIP TANK, CALC DISPLACEMENT CORRECT - MONITOR WELL (STATIC 09:30 12:00 2.50 CLEAN P ■- DECOMP MONI RACKING D HOLE FILL ON TRIP TANK, WELL TAKING CALC ILL 12:00 - 16:00 4.00 CLEAN P DECOMP SINGLE IN HOLE WITH 5" DP TO 2,274' -MD MONITOR DISPLACEMENT ON TRIP TANK, CALC DISPLACEMENT CORRECT - MONITOR WELL FOR 10 MIN - STATIC 16:00 - 18:30 2.50 CLEAN P DECOMP - POOH F/ 2,274' -MD, RACKING BACK 24 STANDS MONITOR HOLE FILL ON TRIP TANK, WELL TAKING CALC FILL Printed 9/6/2011 1:26:57PM Orth America - ALASKA - BP Pages Operation Summary Report Common Well Name: 18 -12 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/9/2011 End Date: X3- 0106Y -C: (8,376,273.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: DOYON 25 Spud Date/Time: 11/9/1986 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292161500 Active Datum: 18 -12C Actual @56.29ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 20:30 2.00 DHB P DECOMP PJSM. R/U SLB E -LINE UNIT TO RUN EZSV - HOLD AAR WITH SLB AND RIG CREW ON E -LINE RIG UP. 20:30 - 21:30 1.00 DHB P DECOMP RIH WITH EZSV ON SLB E -LINE - SET TOP OF EZSV @ 3,285' ELMD 21:30 - 22:00 0.50 DHB P DECOMP POOH WITH SLB E -LINE 22:00 - 23:00 1.00 DHB P DECOMP RIG DOWN E -LINE, CLEAN AND CLEAR RIG FLOOR. 23:00 - 00:00 1.00 DHB P DECOMP M/U 5" SHEAR JOINT WITH TIW & LAY DOWN IN PIPE SHED. R/U TO PRESSURE TEST 9 -5/8" CASING AND EZSV. 8/19/2011 00:00 - 01:00 1.00 DHB P DECOMP PRESSURE TEST 9 -5/8" CSG AND EZSV TO 250 PSI FOR 5 MIN AND 3500 PSI FOR 30 MIN - TEST PASSED - WTL APPROVAL TO CONTINUE OPERATIONS - 3.1 BBLS TO REACH TEST PRESSURE - LOST 14 PSI IN FIRST 15 MIN - LOST 0 PSI IN SECOND 15 MIN - 3.1 BBLS RETURNED 01:00 - 02:00 1.00 WHIP P WEXIT HOLD AAR WITH CREW TO CAPTURE LESSONS LEARNED FROM PREVIOUS SLICK -LINE RIG UP OPERATION. HOLD PJSM FOR MAKING UP WHIPSTOCK/MILLING BHA 02:00 - 06:00 4.00 WHIP P WEXIT . Mill WHIPSTOCK /MII I INC; RHA WITH Mil 1 S MWD, HWDP, AND DRILL COLLARS. - SHALLOW HOLE TEST MWD @ 733' MD WITH 421 GPM / 525 PSI, GOOD DETECTION 06:00 - 09:00 3.00 WHIP P WEXIT RIH WITH WHIPSTOCK BHA ON 5" DP STANDS TO 3213' MD 09:00 - 10:00 1.00 WHIP P WEXIT M/U TOP DRIVE FOR SETTING WHIPSTOCK - CIRC AT 423GPM / 860 PSI, P/U = 131K, S/O = 124K - ORIENT WHIPSTOCK FACE TO 55 DEG LOHS - TAG EZSV AT 3285' MD. - SET BOTTOM TRIP ANCHOR WITH 18K DOWN - P/U 10K OVER TO CONFIRM SET - S/O 48K TO SHEAR OFF WHIPSTOCK TOP OF WS SFT AT 3264' MD 10:00 - 10:30 0.50 WHIP P WEXIT POOH TO 3129' MD RACKING BACK TWO STANDS 10:30 - 11:30 1.00 WHIP P WEXIT PJSM. P/U RTTS PACKER. EtIH W/ 1 STAND TO 100'MD - P/U WT. = 129K, S/O WT. = 122K 11:30 - 12:00 0.50 WHIP P WEXIT SET RTTS PACKER AT 100' MD, UD RTTS RUNNING TOOL. TEST RTTS PACKER - 250 PSI LOW / 2000 PSI HIGH FOR 5 MIN. EACH (GOOD TEST) 12:00 - 18:00 6.00 BOPSUR P WEXIT DRAIN STACK, PULL WEAR RING, BLOW DOWN CHOKE AND KILL LINES. PULL STRIP -O- MATIC, FLOW RISER, CHOKE AND KILL LINES. N/D BOPE AND MOVE TO SITE. PULL HIGH PRESSURE RISER ABOVE FLOOR AND UD. 18:00 - 20:00 2.00 BOPSUR P WEXIT PULL OLD TBG SPOOL, PULL 9 -5/8" PACK -OFF - 10K OVERPULL TO PULL PACK -OFF INSTALL NEW 9 -5/8" PACK -OFF Printed 9/6/2011 1:26:57PM • firth America - ALASKAL BP Page 7 G€-2$ Operation Suary mmReport Common Well Name: 18 -12 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/9/2011 End Date: X3- 0106Y -C: (8,376,273.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: DOYON 25 Spud Date/Time: 11/9/1986 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292161500 Active Datum: 18 -12C Actual @56.29ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 22:30 2.50 BOPSUR P WEXIT N/U NEW TBG SPOOL 22:30 - 00:00 1.50 BOPSUR P WEXIT TEST PACK -OFF - 250 PSI LOW FOR 15 MIN / 3500 PSI HIGH FOR 30 MIN (GOOD TEST) 8/20/2011 00:00 - 06:00 6.00 BOPSUR P WEXIT N/U HIGH PRESSURE RISER AND BOP, INSTALL BLIND SHEAR RAMS. Ii/U AND PERFORM FULL BODY TEST ON BOPE - TEST BREAKS, TEST CHOKE AND KILL LINE CONNECTIONS AND BLIND SHEAR RAMS TO 250 PSI / 3500 PSI FOR 5 MIN EACH - GOOD TEST. TEST WITNESSED BY BP WSL GARRET STAUDINGER AND TREVOR HYATT. 06:00 - 07:00 1.00 WHIP P WEXIT INSTALL BX ELEVATORS AND ROTATOR ASSEMBLY 07:00 - 08:00 1.00 WHIP P WEXIT M/U RTTS RUNNING TOOL, RIH M/U FOSV n (� AND RETRIEVE RTTS AS PER HES REP W/ ANNULAR CLOSED 08:00 - 09:30 1.50 WHIP P WEXIT RIH FROM 3097' MD TO 3255' MD DISPLACE WELL TO 9.6 PPG LSND MILLING FLUID - 550 GPM, 1200 PSI - OBTAIN SPR AT 3255' MD / 3055' TVD S.t 09:30 - 15:00 5.50 STWHIP P WEXIT MILL WINDOW AS PER BOT REP FROM 3264' MD TO 3281' MD t' '' - 100 RPM, 450 GPM, 4 -15K TQ, 1100 PSI - RECOVERED 290 LBS OF METAL 15:00 - 16:00 1.00 STWHIP P WEXIT DRILL 20' OF NEW HOLE TO 3301' MD, 3097' TVD f J i - 453 GPM, 1100 PSI, 100 RPM, 2 -5K TQ,10K I WOB " TOW 3264' MD BOW 3281' MD 16:00 - 17:00 1.00 STWHIP P WEXIT PUMP 25 BBL SUPER SWEEP WHILE REAMING THROUGH WINDOW - MINIMAL _Y INCREASE IN CUTTINGS RETURNED WITH SWEEP - 500 GPM, 1275 PSI 17:00 - 18:00 1.00 STWHIP P WEXIT PULL UP INTO CASING TO 3207' MD AND PERFORM LOT - OBTAIN 12.7 PPG LEAK OFF PRESSURE - WTL APPROVAL TO CONTINUE OPERATIONS WITH A 25 BBL KICK TOLERANCE 18:00 - 18:30 0.50 STWHIP P WEXIT POOH TO 3169' MD, OBTAIN SPRAT 3169' MD / 3097' TVD, PUMP DRY JOB, BLOW DOWN TOP DRIVE - MONITOR WELL, HOLE TAKING CORRECT FILL 18:30 - 19:30 1.00 STWHIP P WEXIT POOH TO 2350' MD IRON DERRICKMAN STOPPED OPERATING CORRECTLY WHEN STARTING TO STAND BACK DRILL PIPE ON DRILLERS SIDE 19:30 - 20:00 0.50 STWHIP P WEXIT SERVICE T /D, BLOCKS, ELEVATORS AND IRON DERRICKMAN 20:00 - 00:00 4.00 STWHIP N RREP 2,348.79 WEXIT TROUBLESHOOT IRON DERRICKMAN 8/21/2011 00:00 - 00:30 0.50 STWHIP N RREP WEXIT CONT. TROUBLESHOOT IRON DERRICKMAN, MONITOR WELL VIA TRIP TANK. Printed 9/6/2011 1:26:57PM � . ��, DS-18 m @ t � 1. � . c t li- 2 \i ' t , \ki , in LPC f 4 10 • / DS-2 t'I C—PAD DS-5 9■ 1� ,, ` '' �` \` i) —N— ■13 . 1 I 8■ ti 'F%J 7 • VICINITY MAP 23 • NTS B• •16 27 • •26 . 5■ •15 ■ 25 4• •14 , O F a i . 3■ ■13 r c"): am, 1 < ,. � � 17 • * : 49 2:1 * '',1 : * , 2■ 12 1� a ! t • 19■ ■ 21 , y r � ( .l.!! � 1■ ■11 y a. s l.., la.a.l,. ,..► I ■2. �, hard . Allis " P q ir ■22 � " ! 9' '� 1'x.08• „,„,,, , „ .., s o■! , I�ssia �►� *� I i , . 1 s SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM 1 T I PROPERLY REGISTERED AND LICENSED 1 i 1 TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS —BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT LEGEND SUPERVISION AND THAT ALL AS —BUILT WELL DIMENSIONS OF 15. .20 1 ARE ■ EXISTING WELL NOTES: 1. DATE OF SURVEY: JUNE 21, & JULY 15, 2011. 2. REFERENCE FIELD BOOK: NS11 -34 PGs. 61 -66 & NS11 -50 PG's 04 -06. GRAPHIC SCALE 3. COORDINATES ARE DATUM IS NAD27. ALASKA STATE PLANE ZONE 4 AND 0 200 400 800 LOCAL PLANT BASED ON OPERATOR MONUMENT DS -18A. 4. GEODETIC COORDINATES ARE NAD 27. (IN FEET ) 1 inch = 400 ft. 5. PAD SCALE FACTOR EQUALS 0.9999415. 6, VERTICAL DATUM IS MLLW BASED ON OPERATOR MONUMENT DS -18A. LOCATED WITHIN PROTRACTED SEC. 19, T. 11 N.. R. 15 E.. UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC TOP OF SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) LANDING RING OFFSETS 18 -12 Y= 5.960.712.15 N= 1.279.94 70'14'49.844” 70.2971790' 17.04' 4113'FSL X= 692.167.80 E= 974.96 148'26'37.412" 148.4437255' 4552'FEL F. Robert °A "" tow _ .. CNECRED Mme, � bp I limit! 0A7E I # 8(tt /tt '' pAWINC Date 02 SHEEP' EOA DRILL SITE 18 i AS —BUILT WELL LOCATION 1 or 1 SEALE N .e /t+ /11 issue, soe 11 C MA17OK KrRIM WELL 18 -12 NM MI OWN VW r - 46fr NO MOT REVISION . OY CNF wmWL +.r• Ma _ Page 1 of 1 • Schwartz, Guy L (DOA) From: Hubble, Terrie L [Terrie.Hubble @bp.com] Sent: Monday, July 11, 2011 3:15 PM To: Schwartz, Guy L (DOA) Subject: PBU 18 -12B, PTD# 205 -073 Hi Guy, I understand from Mel Rixse that you need a request from BP to withdraw the following (approved) sundry: Sundry # 310 -207 So..., please withdraw this sundry as we have recently submitted a revised sundry (311 -206) to accommodate changing from CTD to rotary for this work. Thank you. Terrie JUL 1 4 2011 7/11/2011 • • s larif [:t\LnsliKK1 SEAN PARNELL, GOVERNOR ALASKA 0114 AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mary Endacott Sr. Drilling Engineer BP Exploration (Alaska), Inc. — Q 73 P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18 -12B Sundry Number: 311 -206 Dear Ms. Endacott: Ami JUN. 2 2 201 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. 5 1- Chair DATED this 2 / day of June, 2011. Encl. ' , STATE OF ALASKA !/ ,� -eG , e ALASKA* AND GAS CONSERVATION COMMIS• ' ' �t Oki' 6 -/7-// APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Revised: Well now to be Sidetracked by Rotary Rig 1. Type of Request: ❑ Abandon ® Plug for Redrill ' ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development - ❑ Exploratory 205 -073 - 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519- 6612 50- 029 - 21615 -02-00 - 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 18 -12B - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028321- Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13914' - 8731'. 13878'_ 8730'- 11584' 8 11600' 11607' Casing Length Sim MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2830' 13 -3/8" 2830' 2697' 3450 1950 Intermediate 9935' 9-5/8" 9935' 8303' 6870 4760 Production Uner 2192' 7" 9638' - 11830' , 8153' - 8737' 8160 7020 Uner 157' 4-1/2" 11707' - 11864' 8727' - 8740' 9022 8537 Uner 2286' 2 -3/8" 11628' - 13914' , 8721' - 8731' 11200 11780 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12575' - 13780' 8760' - 8728' 3 -1/2 ", 9.3# N -80 11730' Packers and SSSV Type: 7" x 4-1/2" TIW SS packer Packers and SSSV 11732' / 8728' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory - ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 23, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG - IS Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mel Rixse, 564-5620 Printed Name �( J-�'U ` p Title s Q . l JQ I (�[�k O�R darid Signature � Qy iNlf Phone 5�p4 � 3 Date /1 (L7 Prepared ey Name/Number. Terris Hubble, 564 4628 !� Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number I r "- ,(p ❑ Plug Integrity gt BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 4( 3.SC0 sc: C3 o P ies-/- r:, e5 f _ - J Other. / L 61:4,--s-s... ) > Z.500 ,SL tn h / G 5 r H �� �,rrl K ltc.s_. ...`G..f.- rod, iC:a /54 6 2 S. //Z(c) �" - (l t ik I$ a : liNt CM*. 9911111iSSiOa Subsequent Form Required: O Pn�flo 0 / / APPROVED BY 12111 ) APP roved B Y : COMMISSIONER THE COMMISSION Date Ip ` Form 10-403 Rev' _ ... ■ S N 2 2 201 li '/7 // Submit In Duplicate ��ORIG� AL / OS • • bP .1 To: Guy Schwartz Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Mel Rixse Operations Drilling Engineer Date: June 14, 2011 Re: Sundry Request for 18 -12B: Cement Abandonment to Allow for a Rotary Sidetrack Sundry approval is requested for 18 -12B. Abandonment of the existing B -Ieg is proposed. A rotary rig sidetrack to a new bottom hole location following the cement abandonment is planned. Isolation from the existing perforations and cement isolation above the existing packer will be accomplished by punching holes in the existing production tubing then circulating a full bore cement plug in the existing production tubing and inner annulus. 1-4 ( 4600.1w.0 � 6 " %k r' .., .d<6oe ;�„ �1•� o 11667 Z G161°s The pre rig abandonment will begin as soon as approval from AOGCC is received. Doyon 25 is expected to move to 18 -12C on July 10th, 2011 for the decomplete and sidetrack. The permit to drill request will be G • /7. if submitted as soon as final directional plans are completed. WELL HISTORY /CURRENT STATUS: Well Construction: 18 -12B is a July 2005 CTD ST to a ZN1A target SE of DS18. CTD encountered slow drilling, poor quality sands and unpredicted minor faulting. All available sands were perforated. The gas rates remained fairly stable but the oil rates had declined within a couple of months of being POP such that the well was not competitive and was subsequently shut -in & moved to a cycle / swing status within few months. The well displayed no recharge ability for the next two years while in the HP system. In an effort to improve productivity, 18 -12B was swapped to the LP system in the spring of 2008 and the subsequent tests showed it to be making all gas and no oil. The August 2009 slickline drift & tag with sample bailer (to deviation at 11,053' md), came back empty. The most recent POP attempt was in Nov / Dec 2009 and the well was shown to be only making gas in HP. There are currently no viable wellwork options left to pursue. 18 -12B is in sound mechanical shape. The PDS caliper logged on 3/20/10 found the 3.5" N -80 TBG to be in good to poor condition with respect to corrosive and mechanical damage. A maximum wall penetration of 45% was recorded in joint #73 @ 2330' md. The well passed the MITIA to 3000 psi and the MITOA to 2000 psi on 3/21/10. The original cement volume on the 9 -5/8" casing pumped on 11 -24 -1986 shows a volume of 101.5 bbls (500 sacks of class G). No losses were noted. Assuming a 30% washout, the resulting cement height would be 1400' above the 9 -5/8" casing shoe (for TOC at 8535' MD). REASON FOR SIDETRACK: 18 -12B is currently SI with high GOR with no significant on time since 2007. The sidetrack into new fault will allow the well to become productive again. L Cu/ . Veil Agee Ver> 60 1 Coy �p��7�MgAL� f'�CO� {� 14-ell fo re'- - /l S�at�/o� 4 //» � Ueg s�I y `"! pool. ,G • TREE= 3 -1/8" FMC SAFETY NOTES: FHL/TIW HBBP PACKERS HAVE WELLHEAD = FMC ACTUATOR = AXELSON 18-12B CONTACT TEST PRESSURE TI (x5102) PRIOR TO PRESSURETESTING. KB. ELEV = 47' WELL ANGLE> 70° @ 10097' & > 90°0) 12183'. BF. ELEV = 23.8' ORIGINAL 4-1/2" LNR FROM PARENT WELL NOT KOP= 1200' SHOWN ON DIAGRAM Max Angle = 98 @ 12705' Datum MD = WA ' 2268' H 3- 112" CAMCO TRDP -1 A TRSV, ID = 2.812" I Datum TV D = 8800' SS • 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2830' ■ 1 GAS LIFT MANDRELS STi MD I WD IDEV1 TYPE IVLVILATCHIPORTI DATE Minimum ID = 1.745" @ 11628' 1 3790 3503 34 CA-MMG -2 DMY RK 0 03/20/10 SEAL ASSY (LNR TOP PKR) I9 -50 X 7" TM/ LNR HGR H 9631' I- - � l ij 1 9399' H3-1/7' OTIS X NIP, ID =2.813" I 9 -5/8" CSG, 47 #. L -80, ID= 8.681" H 9935' I--a ITBG PUNCH (09/13/10) H 11396' - 11401' I • NM 11584' CTU H3-1/2" HES CIBP (09/13/10) I ✓ Li g =.1.01 11600' 3 -1/2" CIBP(08/27/10) I 1 11607' FISH: 11.5' SL TOOLSTRING (08/26/10) 1 :. .- 11628' BKR LNR TOP PKR & SEAL ASSY, ID = 1.745" I MN III ' 11644' I 2.70" BKR DEPLOY SLV, ID = 2.250" /4 , , 4 11644 I-I EST TOP OF CEMENT LNR I ► I ° 4 ' 11718' HTIW OVERSHOT ASSY, ID = 4.75" (BEHIND PIPE) I 13 -112" TBG-PC. 9.3 #, N-80, .0087 bpf. ID= 2.992" H 11718' 1— •I 1 11720' HTnN POLISHED RISER W/ 2.813" X- PROFILE (BEHIND PIPE) 1 jt Y 11730' BTM OF TM/ OVERSHOT ASSY (BB1IND PIPE) � / 1 11732' H7" X 4 -112" TM/ SS PKR, ID = 3.00" (BEHIND PIPE) 1 1 4 ► 1 I 4 7" LNR 29#, L -80, .0371 bpf, ID= 6.184" H 11830' f ' ► 4 I 4 M ILLS) WINDOW (18 -12B) 11864' - 11871' 'MECHANICAL WHIPSTOCK (06 /18/05) H 11862' ' RA TAG 11870' • I I I I I I I I I 4 ••••• 1 111 I Iu., t r....• • = 4 12382' H MARKER w /PUP JNT PERFORATION SUMMARY I • I 4 REF LOG: IVWD/NGP GR/ROP ON 06/28/05 ` TIE-IN LOG: GEOLOGY PDC LOG 1 I ANGLE AT TOP PERF: 86° @ 11575' 1 1 4411110 u Note: Refer to Production DB for historical pert data I 1380W n CLEANOLIT BY SIZE SPF INTERVAL Opn/Sqz DATE S‘ 1 RIG (06/30/05) 2 -1/2" 6 11575 - 11580 0 09/15/10 tits. ` 2 -1/2" 6 11590- 11595 C 08/29/10 1- 9/16" 6 12560 - 13120 C 07/03/05 1- 9/16" 6 13190 - 13290 C 07 /03 /05 1- 9/16" 6 13400 - 13630 C 07/03/05 ;tt;., 1- 9/16" 6 13700 - 13780 C 07/03/05 I PBTD H 13878' 1 •1": • I2 -3/8" LNR, 4.7 #. L -80, STL .0036 bpf, ID = 1.92" H 13914' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/23/86 ORIGINAL COMPLETION 09/04/10 PBS /SV SET CIBP/TBG FCH (08/29/10) WELL: 18 -12B 11/08/97 CTD SIDETRACK 09/22/10 HJW /PJC TBGPUNCWCIBP(09 /13/10) PERMIT No: t050730 07/04/05 NORDICI CID SIDETRACK 09/22/10 JKDIPJC PERFORATE (08/29 & 09/15/10 API No: 50- 029 - 21615 -02 07/07/05 RMWPJC GLV C/0 11/19/10 CSR/PJC PERF/ CIPB CORRECTION SEC 19. T11N, R15E 1166' FNL & 402' FWL 01 /01 /06 GJB/TLH DRLG DRAFT CORRECTIONS 03/21/10 SWC/SV GLV GO (03/20/10) BP Exploration (Alaska) . • III TREE= 3-1/8" FMC awrc1 T row I ca: rry d tin nom. P nwrc WELLHEAD = FMC REDUCED TEST PRESSURE LIMITS IN SOME CASES. ACTUATOR = A ULSON P R E R I G 18-12B CONTACT WIE (x5102) PRIOR TO PRESSURE TESTING. KB. ELEV = 47 WELL ANGLE' 70° 2 10097' & a 90° 2 12183'. 8F. ELEV = 23.8' ORIGINAL 4 -1/2" LNR FROM PARENT WELL NOT KOP= 1200' SHOWN ON OIACRAM Max Ante = 98 012705' Datum MD= WA 0 I 2 26 8' I— 3-1/2" CAMCO TRDR 1A TRSV, 0 = 2.812" Datum 8800' SS GAS LIFT MANDRELS TUB NG CUT H — 3600' I MD TV D DEV TYPE VLV LATCH', FORT DATE LI I 3790 3503 34 CA -MMG -2 DMY RK 0 03/20/10 113.3/8' CSG, 721, L -80, ID = 12.347' 1---1 2930' I °i ITOC H - 840o' I I9 -5/8" X 7' TIN LNR HGR IH 9631' 9399' — 13 -1/2' OTIS X NIP, ID = 2.813" I [9 -518" CSG, 471, L -80, ID = 8.681' I— 9935' 1 I • • !TBG PUNCH (09/13110) 11 39 6' - 11401 i I a 11584' CTU —13-1 /2' HES CIBP (0911311 11600' — 3 -12" CEP (08/27/10) I • Minimum ID = 1.745" @ 11628' 11607' _ FISH: 11.5' SL TOOLSTRING (0828!10) I i SEAL ASSY (LNR TOP PKR) . _1 _. 11628' BKR LNR TOP PKR & SEAL ASSY, 0 =1.745" I NO • I 11644' — 12.70" BKR DEPLOY SLV, 0= 2.250" 11644' jH EST TOP OF CEMENT LNR I 11718' H TMV OVERSHOT ASSY, ID = 4.75" (BEHIND PIPE) I 3 TBG PC, 9.31, N .0087 bpf, ID = 2.992' 1171 I � ill 11720' H T POLISHED RISER VW 2.813" X - PROFILE (REMIND PIPE) 1 } II! �� 11730' H BTM OF TAN OVERSHOT ASSY (BENNO PIPE) I } 0: 11732' --17" X 4 - 117 T A N PKR ID = 3.00' (BEHIND PIPE) I 17" LNR, 291, L - B0, .0371 bpf, ID = 6.184" — 1 11830' 9) 7 :::. : • MILLED WINDOW (18.12 � 11864' - 11871' 'MECHANICAL WHIPSTOCK (06/18/05) IH 11862' �p RA TAG I 11870' WAS: PERFORATION SUMMARY 4mry It 12382' H MARKER w /PUP JNT REF LOG: IINDMGP GR/ROP ON 06/28/05 TE - LOG: GEOLOGY PDC LOG • ANGLE AT TOP PERF: 86" 0 11575' I I Note: Refer to Production DB for historical perf data I I So SEE SPF NTERVA L Op i /Sqz DATE I L i 13809' — CLEANOUT BY 2 -1/2" 6 11575 - 11580 0 09/15/10 ` RIG (06/30 /05) 2 -1/2" 6 11590- 11595 C 08/29/10 41111111, 1 -9/16" 6 12560- 13120 C 07 /03 /05 1 -9/16" 8 13190 - 13290 C 07 /03 /05 1 - 9/16" 6 13400 - 13630 C 07 /03 /05 1 - 9/18' 8 13700 - 13780 C 07 /03 /05 — PBTD 13878' I2 - 3/8" LNR 4.71, L - 80, STL, .0036 bpi, ID = 1.92" H 13914' DATE REV BY COMMENTS I DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/23/86 ORIGINAL COMPLETION 09/04/10 PBS/SV SET CIBP/TBG PCH (06/29/10) WELL: 18 -12B 11 /08/97 CTD SIDETRACK 09/22/10 HJIMPJC TBG RJNCHICDP (09 /13/10) PERMIT No: 2050730 07/04/05 NORD1C1 CTD SIDETRACK 09/22/10 JKIYPJC PERFORATE (08/29 8 09/15/10 API No: 50-029-21615-02 07 /07 /05 RM4/PJC GLV CIO 11/19/10 CSR/ PERFI CPB CORRECTION SEC 19, T11N, R15E 1166' FNL 8 407 FWL 01/01 /06 GJB/TLH DRLG DRAFT OORRECVIONS 0321 /10 SWC/SV GLV CIO (03/20/10) BP Exploration (Alaska) • TREE= 3- 1/8°FMC 18 -12C WELLHEAD= FMC ACTUATOR= AxasON BB1_ 4T p Pro osed RST SAFETY NOTES: KB. BF. EL EV= 23.8' I I KOP= 1200' Max Angle = 7? Datum MD= WA © I 2200 I — 4 - 171" SSSV NIP O = ?" Datum TVD= 8800'SS GAS LIFT MANDRELS I ST MD TVD DEV TYPE VLV LATCH PORT DATE 13 -3/8" CSG, 72 *, L -80, ID = 12.347° — I 2830' I 3 2 ITOP OF 7" LINER I 1 �:N]:A ; ,�;ti +,•;yt }; ;;; , ; . 9-5/8" WHIPSTOCK @ 3250' Minimum ID 32 Lower SV5 ?? 65 @ 4750' 9.5/8" CSG, 47*, L -80, ID = 8.681' H 9935' I ' I 13176' H4 -12" X NIP ID= 3.813' 2 I 13211' I x 4-12° PKR t I 13246' I - 1412 " X NIP, ID = 3.813" 4 -12" TBG, 12.6 *, 13Cr -80, .0152 bpf, ID = 3.958" H 13308' 13281' H4 -1/7XN NIP, ID= 3.725" I I TOP OF4- 12 " LNR H - 13341' I 7" LNR 26*, L -80 H — 13500' I • • 30° Put River or Shublik @ —13500' PERFORATION SUMMARY REF LOG: MWD/NGP GR/ROP ON 06/28/05 TIE-IN LOG: GEOLOGY PDC LOG 0 ANGLEAT TOP PERF: 7?° ?7 90 @ —14255' Note: Refer to Production 013 for historical part data SIZE SPF NTERVAL Opn/Sqz DATE 6e.1. >o H — 17700' I.. 103 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfr 12/23/80 ORIGINAL COMPLETION 09/04/10 PBS/SV SET CIBP/TBG PCH (0829 /10) WELL 18 -12 1110897 CTD SIDETRACK 09/22/10 HJW/PJC TBG RJNO -UCIBP (09/13/10) PERMIT No: 07/04/05 NORDIC1 CTD SIDETRACK 09/22/10 JKD/PJC PERFORATE (0829 8 09/15/10 API No: 50-029-21815-02 07/07/05 RM -UPJC GLV C/O 11/19/10 CSR/PJC PERF/ CIPB CORRECTION SEC 19, T11N, R15E, 1188' FNL 8402' FWL 01/01 /08 GJI3 /TLH DRLG DRAFT CORRECTIONS 04/18/11 MS PROPOSED RST 032111 SVVCJSV GLV C/O (03/20/10) BP Exploration (Alaska) • • • Recent History: A 2009 CST was planned, but in Sept 2009 the pre -rig work failed. Communication between the tubing and IA couldn't be established to pump the cement packer needed for the CST window exit. It is suspected that the IA is packed off by drilled solids that settled out of the OBM that was used as the packer fluid. Even with the tubing punch the well passes a MIT 3000 psi and MIT x IA to 2500 psi. A gravel pack log was run in the tubing, and the top of the suspected fill was determined to be at -9,900' (8269' SSTVD). There are two CIBP in the tubing with a slick line fish below them. Planned Pre - Rig Abandonment and Preparation Operations: 1. F MIT -IA to 3500 psi, MIT -T to 2500 psi. 2. W Perform diagnostic testing to determine location of IC packoff leak location, i.e. upper seals or lower seals. 3. W Function test LDS tubing, replace if damaged. 4. S Drift tubing with 3.5" drift to 9700' MD. 5. E Punch holes in 3 -1/2" production tubing from 9600' MD to 9605' MD. Ensure circulation to IA. Set CIBP at 9650' 6. F Perform fullbore cement P &A and plan to leave fOC in tubing and IA at 84001MD. Pump 84 bbls of 15.8 ppg Class G cement down the TBG up IA. /Loo' c .o73z = r'4 $S 7. S Drift to TOC and to -3600' MD for jet cutter. Pressure test cement to 2500 psi. 8. E Jet cut 3 -1/2" tubing -3600' MD ( -2' below the nearest tubing collar). 9. F CMIT -TxIA to 3500 psi. 10. D Bleed all casing and annulus pressures to zero psi. 11. V Set BPV 12. 0 Bleed gas lift and production flowlines down to zero and blind flange 13. 0 Remove S- Riser, Remove wellhouse, level pad - Complete Proposed Procedure: 1. MIRU. 2. MIT - OA 2000 psi for 30 minutes (begin monitoring OA). 3. Pull BPV. Circulate out freeze protection and circulate well to a 9.8 ppg Brine. If brine losses are significant with the 9.8 ppg brine, reduce the brine weight as required. Set a TWC and test from above to 3500 psi for 30 minutes and from below to 1000psi with a rolling test. 4. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull TWC. 5. RU and pull the 3 -1/2" tubing w /single 1/4" control line from the pre -rig jet cut at -3600' MD. A single 1/4" hydraulic control line should be run to the SSSV at 2268' MD. 6. Pick up 9 -5/8" casing scraper. RIH to tubing stub at -3600' MD, ensure casing is clean. POOH. LD scraper assembly. 7. RU E -line, run a 9 -5/8" EZSV w/ GR /CCL for 47# casing. Set the EZSV at -3,400' MD (spaced out so whipstock face does not lie across 9 -5/8" casing collar w/ bottom of whipstock face near 3266' MD). Rig Down E -line. P4�� 8. Pressure test the EZSV to 3500 psi for 10 minutes and chart. 9. Negative pressure test EZSV ?? Change 9 -5/8" casing packoffs. Pressure test packoff to 5000 psi for 30 min. 10. PU 9 -5/8" whipstock, bottom trip anchor and 8.5" window milling assembly (to include full gauge string mills). RIH to the top of the EZSV. Orient and set the whipstock. Swap the well over to 9.3 ppg fresh water LSND milling fluid. 11. Mill a windowin the 9 -5/8" casing from approximately 3250'- 3266' MD' plus 20' of formation. 12. Perform a FIT /LOT. POOH for drilling BHA. 13. MU an 8 -1/2" drilling BHA with DIR /GR /RES and RIH. Kick off and drill 8 -1/2" intermediate interval to 7" casing point at the top of the Sag River CBU, wiper trip to shoe, circulate well clean and POOH. eft) • a. NOTE: The mud will need to be weighted up with spike fluid. Plan for one weight -up with the spike fluid to 10.5 ppg over several circulations prior to drilling the HRZ and Put River. 14. Run and partially cement a 7 ", 26 #, L -80 drilling liner in the 8 -1/2" welibore with a minimum of 150' overlap into the 9 -5/8" casing. Set hanger / liner top packer and displace cement with mud. POOH. 15. M/U a 6 -W DIR /GR /RES /NEU /DEN drilling assembly. P/U additional 4" drill pipe as required to TD the well and RIH to top of the float collar and test the casing to 3,500 psi for 30 minutes. 16. Displace the well to 8.5 ppg Flo -Pro SF fluid 17. Drill out shoe and 20' of new formation and perform an FIT. 18. Drill build section with pilot hole, per directional proposal to Zone 1. 19. MU a 6 -1/8" BHA with PDC bit and DIR /GR /RES /NEU /DEN. RIH and drill ahead, per directional proposal and rig site geologist, to TD. 20. CBU at TD. Back ream to shoe, MAD passing as required by geologist. Open circ sub and circulate the well clean at the shoe and POOH. 21. Run and a cement a 4 -1/2 ", 12.6 #, L -80, TC -II liner from TD to 150' inside the 7" shoe. Set the liner top packer and displace the well to seawater. 22. After cement reaches -1000 psi compressive strength, pressure test well to 3500 psi for 30 minutes and chart. 23. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and perf guns. 24. Run the 4 -1/2 ", 12.6 #, L -80 completion tying into the 4 -1/2" liner top. 25. Drop ball & rod and set the production packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. 26. Shear valve and confirm circulation. 27. Set and test a TWC to 1000psi. 28. ND BOPE. NU and test the tree to 5,000 psi (tree will be changed with 4- 1/16 ") 29. Pull TWC. Freeze protect the well to 2,200' TVD. 30. Set a BPV. 31. RDMO. Post -Rig Work: 1. Pull BPV. 2. Pull ball and rod / RHC plug. Set generic GLV design. 3. RU ASRC test separator. Flow well per productiono engineer. 4. Install welihouse, instrumentation, and flowlines. Mel Rixse Operations Drilling Engineer CC: Well File Sondra Stewman/Terrie Hubble 12/30/10 rger NO. 5672 Alaska Data & Consulting Services © 5 / ' Company: State of Alaska 2525 Gambol' Street, Suite 400 J v 72....___. p y Alaska Oil & Gas Cons Comm Anchorage, AK 99503 - 2838/1 - Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Y t' Anchorage, AK 99501 Wet Job 8 Log Description Date BL Color CD E -05 BL65 -00011 MEM GDL _ 12118/10 1 1 - 35 AY1M-00056 PROD PROFILE j' -/ - 11/27/10 1 6(1) 1 11 -12 BCZ2 -00033 PROD PROFILE , C - " "- 12/06/10 1 1r a TG1rs 1 01 -25 BG4H -00022 INJECTION PROFILE 4/.f• ., 1 04 -24 AY1 M -00058 PROD PROFILE - • P2 -16 BSJN -0 r4�t _ 1 A-41 BCZ2 -00030 I!. d C WTiX'L'S+ 1 04-08 BCRJ - 000566 PLEatil [e7r8JaoT31ti3irkeZeaci.LQ a 12/08/10 1 ► Y,i 1 01 -24A BBSK -00043 rI,III*toms19:L•'d144 Iiirami '� _. 4TITi�i 1 04-10 AV1H -00051 INJECTION PROFILE 0 v • 12/07/10 1 Iii Ti _ ) 1 • 15 -26B BD88.00080 MEM PROD PROFILE _ 4 . - 12/12/10 1 RR A • , 1 2- 288/0 -19 BCRJ -00055 PROD PROFILE )' •• 11/30/10 1 IN, 1 07 -23B AY1M -00056 SCMT ^� — 11/28/10 � 1 02-21A BBSK -00042 SCMT 6).1e, - ,t) " 11/23110 .a V,' t 1 02 -228 BL65 -00006 SCMT 1 n — 12/11/10 ,. re, , 1 1 18 -128 BBUO-00029 SCMT (5 08/30/10 • 1 1 P2 -16 85JN-00077 USIT l 'j' � i / Q 11/28/10 1 1 05.278 BAUD -00048 MCNL 4-0 / 09/18/10 1 ", 1 16.068 BBSK -00037 RST L. 4 , • 11/15/10 1 ±, —aj 1 0-098 BGZ7 -00005 RST in ► 09120/10 1 1 E -34L1 BD88 -00050 MCNL / 9 09/28/10 1 1 W -219 BGZ7 -00012 CH EDIT PDC-GR USIT - - • ' 11/22/10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 }y � r � } 0 �y + 2525 Anchorage, A l Street, Suite 400 900 E. Benson Blvd. . i-4) MA }., 4, ! 0 [ Anchorage, AK 99503 -2838 • P • ~~a~~ Oo ~ p~Gl~f~Q /,E..ma~.~~o~,~w John McMullen engineering Team Leader M~''~~~~~j~y "7'. -« " `?(j~%: ._ ~` ~ , BP Exploration (Alaska), Inc. a P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay OiI Pool, PBU 18-12B Sundry Number: 310-207 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this2 day of July, 2010. Encl. STATE OF ALASKA ~~~~~ V ~~~ ALASK~L AND GAS CONSERVATION COMMIS•N ~U~,. ~ ~ ~ ~p APPLICATION FOR SUNDRY APPROVALL 20 AAC 25.280 1. Type of Request: ~t]CltOi"~~8 ~ ^ Abandon ®Plug for Redrill - ^ Perforate New Pool ^ Repair Welt ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 205-073 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21615-02-00 - 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 18-128- Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028321 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13914' ~ 8731'- 13878'- 8730' - None None Casin Len Size MD TVD Burst Colla Structural Conductor 11 1 14 4 Surface 28 0' 13- / " 2 2697' 34 1 Intermediate 5' -5/ " 6 70 47 Production Liner 2199' 7" 1' - 118 0' 1 ' - 8737' 81 0 7 20 Liner 157' 4-1/2" 117 7' - 11 8727' - 8740' 9022 8 7 Liner 1 1' - 117 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12560' - 13780' 8761' - 8728' 3-1/2", 9.3# N-80 11730' Packers and SSSV Type: 7" x 4-1/2" TIW'SS' packer Packers and SSSV 11732' / 8728' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory - ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 15, 2010 ^ Oil ^ WINJ ^ WDSPL ^ Plugged 16. Verbal Approval: Date: ^ Gas ^ GINJ ^ GSTOR ^ Abandoned ^ WAG ^ SPLUG - ®Suspended Commission Representative: 17. I hereby certify that the fore oing is true and correct to the best of my knowledge. Contact Sean McLau hlin, 564-4387 Printed Name Joh i Mullen Title En ineerin Team Leader Prepared By Name/Number. Signature Phone 564-4711 Date ~ ~ _ /~ Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness Sundry Number: chanical Integrity Test ^ Location Clearance ^ Plug Integrity COP Test ^ Me © ~' 3,5~ ~o s~ ~Z~l es?"~ Other: _ ~ZSG~ ~ sue, ~n n. ~ l es'~ ~'"`'..^ Subsequent Form Required: / a _ [~/ ~ APPROVED BY ~ C~ Z . Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Re ' / (1 7Z2 , Submit In Duplicate w~2 ~ ORIGINAL ~ '° ~~,~~,~.% .~- • • ' To: Alaska Oil & Gas Conservation Commission From: Sean McLaughlin ~p CTD Engineer Date: June 28, 2010 Re: 18-12B Sundry Approval Sundry approval is requested for well 18-126. 18-12B is a July 2005 CTD ST to a ZN1A target SE of DS18. CTD encountered slow drilling, poor quality sands and unpredicted minor faulting. All available sands were perforated. The well declined within a couple of months of being POP such that the well was not competitive and was subsequently shut-in & moved to a cycle /swing status within few months. The well displayed no recharge ability for the next two years while in the HP system. In an effort to improve productivity, 18-12B was swapped to the LP system in the spring of 2008 and the subsequent tests showed it to be making all gas and no oil. The August 2009 slickline drift & tag with sample bailer (to deviation at 11,053' md), came back empty. The most recent POP attempt was in Nov / Dec 2009 and the well was shown to be only making gas in HP. There are currently no viable wellwork options left to pursue. REASON FOR SIDETRACK High GOR and no well work option to pursue. The proposed plan for 18-12C is to drill a through tubing sidetrack with the Nordic 1 Coiled Tubing Drilling rig on or around September 15, 2010. The existing perforations will be isolated by a CIBP and the primary cmt job. The sidetrack will exit the 3-1/2" tubing and 7" liner above the production packer. The annular cement pumped as part of the pre-rig will server as the new production packer. The sidetrack will target zone 1 A reserves. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. MA-sP . Z-Yoo p s., Pre-Rig Work: (scheduled to begin August 15, 2010) 1. O MIT-IA, -OA 2. C Dummy WS drift 3. C Set CIBP at 11,600' ' 4. C Punch tubing C«~ 11,590' 5. C Set cement retainer C~ 11,580' 6. C Cement up 3-1/2" x 7" annulas 7. C Cleanout to top of the cement retainer with a 2.8" mill 8. S Pull GLV, pump freeze protect in IA, Set DGLV 9. O Test: PPPOT-T. Torque LDS 10 .0 PT MV, SV, WV 11 .0 Blind and bleed lines, remove well house, level pad • Rig Work: (scheduled to begin on September 15, 2010) 1. MIRU and test BOPE to 250 psi low and 3500 psi high 2. Set 3-1/2" monobore whipstock at_ 11,560' 3. Mill 2.8" window at 11,560' and 10' of rathole 4. MIT-IA to 3000 psi 5. Drill Lateral: 3" OH, 2660' (12 deg/100 planned) with resistivity 6. Run 2-3/8" solid liner leaving TOL at 11000' 7. Pump primary cement leaving TOC at 11000', 13 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and MCNL/GR/CCL log 9. Test liner lap to 2000 psi 10. Perforate liner per asset instructions (1200') 11. Freeze protect well, RDMO (~ £ ~ ~f ~ 3~v-Zoe Post Rig: 1. ~ Re-install well house and attach~duction lines • 2. Pull BPV 3. Run GLV's if needed 4. Test separator (~ 1200' of perfs) Sean McLaughlin CTD Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble = 3-1/8" FMC WELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV = 47' BF. ELEV = 23.8' KOP = 1200' Max Angle = 98 ~ 12705' Datum MD = NIA Datum ND = 8800' SS 13-3/8" CSG, 72M, L-80, ID = 12.347" ~ 2830' Minimum ID =1.745" ~ 11628' SEAL ASSY LNR TOP PKR 9-5/8" X 7" TNV LNR HGR 9631' 9-5/8" CSG, 47*, L-80, ID = 8.881 " 9936' I • I SAFETY: FHLITIW HBBP PACKERS HAVE REOIJC PRESSt87ELIMITSINSOMECASE3. CONTACT WIE {x5102) PRIOR TO PRESSURE TOTING. WELL ANGLE> 70° ~ 10097' 8 > 90° ~ 12183'. ORIGINAL 4-112" LNR FFipM PAiiBYT WELL NOT SHOWN ON DIAGRAM 2268' 3-1/2" CAMCO TRDRIA TRSV, ID = GAS LIFT MANDRELS MD TVD DEV TYPE VLV LATCH PORI 9399' H3-12" OTIS X Nom, ID= 11828' -'BKR LNR TOP PKR & SEAL ASSY, ID = 1.745" 11644' 2.70" BKR DEPLOY SLV, ID = 2.250" 11844' EST TOP OF CBVIENT LNR 11718' H~ OVERSHOTASSY, ID = 4.75" (8B11ND PIPq ,~_ TOP OF 41 /2" SLOTTED LNR, 13.51, ®= 3.92" H 11780' 7" LNR, 29*, L-80, .0371 bpf, ID = 6.184" 11830' MECHANICALWHIPSTOCK(O6/18/05) 11882' RA TAG 11870' TOP OF 2-3/8" LNR, 4.88, L-80, ID = 1.941 " 11984' CAP 11998' 2-3/8" SLTOVSOLID LNR, 4.6tr, L-80, O = 1.941" 14045' PERFORATION SUMMARY Fill LOG: M1AAIQINGP GFilROP ON 06/28!05 THIN LOG: GEOLOGY PDC LOG ANGLEAT TOP F'ERF: 93 ~ 12560' Note: Refer to Ptoduction DB for historical p erf data SIZE SPF INTERVAL OpnlSgz DATE 1-9/16" 6 12560 - 13120 O 07/03/05 1-9/16" 6 13190 - 13290 0 07D3105 1-9/16" 6 13400 - 13630 O 07103/05 1-9116" 6 13700 - 13780 0 07103/05 11720' ~ TNV POLISHED RISER W/ 2.813" X- PROFILE (BEHIND 11730' BTM OF TMV OVERSHOT ASSY (BB~BND PIPq 11732' 7" X 4112" TNV S3 PKR, O = 3.00" (BEHIND PIPE MILLED WINDONf (18-128) 11814' - 11871' 12382' H ~ RKER w /PUP JNT ~2-3/8" LNR, 4.7*, L-80, STL, .0038 bpf, ID = 1.92" ~ RIG DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 12123!88 ORIGINAL COMPLETION WELL: 18-128 11/08197 CTDSIDETRACK PERWIT No: `L050730 O7/W/05 NORDK:1 CTDSIDETRACK API No: 50.029-21615-02 07107/05 RMWPJC GLV GO SEC 19, T11 N, R75E, 1166' FNL ~ 407 FWL 01/01/06 GJBRLH DRLGDRAFTCORRECTIONS 0321110 SWGSV GLV GO (03/20/10) BP Ekploration (Alaska) X18-12B TREE = 3-1/8" FMC WELLHEAD= ~ FMC ACTUATOR = AXELSON KB. ELEC/ = 47' BF. ELEV = 23.8' KOP = - - 1200' Max Angle = 98 ~ 12705' Datum MD = WA Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ Minimum ID = 1.745" ~ 11628' SEAL ASSY (LNR TOP PKR) SAFETY NOTES: FHUTIW HBBP PACKERS HAVE REDUC T PRESSURE LIMITS IN SOMECASES. CONTAC E (x5102) PRIOR TO PRESSURE TESTING. WELL ANGLE> 70° ~ 10097' 8 > 90° ~ 12183'. ORIGINAL 4-112" LNR FROM PARENT WELL NOT SHOWN ON DIAGRAM O 2268' 3-112" CA MCO TRDP-1A TRSV, ID = 2.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3790 3503 34 CA-MMG-2 DMY RK 0 03/20!1 9399' ~-{ 3-1 /2" OTIS X NIP, ID = 2.813" X T' TNV LNR HGR ~-{ 9831' TSGR -9710' I 9-5/8" CSG, 47#, L-80, ID = 8.681 " ~ 9936' Top of cement packer 9! 13-1/2" monobore w hipstock I PERFORATION SUMMARY REF LOG: MWLyNGP GR/ROP ON 06/28/05 l1E-IN LOG: GEOLOGY PDC LOG ANGLE AT TOP PERF: 93 ~ 12560' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 1-9/16" 6 12560- 13120 O 07/03/05 1-9/16" 6 13190- 13290 O 07/03/05 1-9/16" 6 13400- 13630 O 07/03/05 1-9/16" 6 13700- 13780 O 07/03/0.5 B7 deg 3-1/2" T8G-PC, 9.3#, N-80, .0087 bpf, ID = 2.992" N 11718' T' LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11830' MILLED WINDOW (18-128) 11864' - 11871' PBTD - 2-3/8" LNR, 4.7#, L-80, STL, .0036 bpf, ID = 1.92" 13914' 11000' Top of 2-3/8" liner, Top of cement 14220' H2-3/8" L-80 liner 11580' I--~3-1/2" cement retainer 11590' Tubing punches 11600' 3-1/2" CIBP 11628' H BKR LNR TOP PKR & SEAL ASSY, ID = 1.745" 11644' ~ 2.70" BKR DEPLOY SLV, ID = 2.250" 11844' EST TOP OF CEMENT LNR 11718' - 1TNV OVERSHOT ASSY, ID = 4.75" (BEHIND PIPE) 11720' TIW POLISHED RISER W/ 2.813" X- PROFILE (BEHI 11730' BTM OF TNV OV ERSHOT ASSY (BEHIND PIPE) 11732' 7" X 4-1/2" TNV SS PKR, ID = 3.00" (BEHIND PIPE) 12382' ~-iMARKERw/PUPJNT _~ 13809' ~ CLEANOUT BY RIG (06/30/05) B weIbore DATE REV BY COMMENTS DATE REV BY COMMENTS 12!23/88 ORIGINAL COMPLETION 11/08/97 CTD SIDETRACK 07/04!05 NORDICI CTD SIDETRACK 07/07/05 RMWPJC GLV GO 01/01/06 GJB/TLH DRLG DRAFTCORRECTIONS 03/21 /10 SWGSV GLV GO (03/20/10) PRUDHOE BAY UNfT WELL: 18-12C PERMT No: 2050730 API No: 50-029-21615-03 SEC 19, T11 N, R15E, 1166' FNL &402' FWL BP Exploration (Alaska ~ 18-12C proposed C TD siletrack •. - ~ ~' Review of Sundry Applications 310-207 BP Exploration (Alaska) Inc. Well PBU 18-12B AOGCC Permit 205-073 Requested Action: BP Exploration (Alaska) Inc. (BPXA) proposes to abandon the subject wellbore to prepare the well for a rig sidetrack. Recommendation: I recommend approval of Sundry Applications 310-207 to allow BPXA to perform this operation. Discussion: BPXA proposes to plug the subject wellbore to prepare the well for sidetracking. The 18- 12B well was brought on production into the high pressure system in July 2005 and has been a poor producer from the start. BPXA states that during drilling the encountered slow drilling, poor quality sands, and unpredicted minor faulting. They also indicated that all available sands in the lateral were perforated. Initial production was 539 BOPD with a GOR over 30,000 SCF/STB. Although the oil rate remained relatively constant before being shut in after a year of production the GOR increased rapidly, reaching 40,000 SCF/STB after just two months of production. The well spent about half the days during that first year on production. The well was then shut in for several months. It was brought back into production in January 2007 but showed no recharge. Initial rates and GOR were essentially the same as when the well was shut in and the GOR again rose quickly, reaching over 60,000 SCF/STB during the five months of more or less continuous production. The well was then shut in for several months and connected into the low pressure system. Again the well's initial production and GOR were comparable to the performance prior to being shut in, indicating no recharge. During the 3 months of sporadic production after the well was brought back into service the oil rate dropped dramatically, from about 400 BOPD to 250 BOPD, while the GOR remained relatively at about 50,000 SCF/STB. A few sporadic attempts to produce the well, with the longest and most successful lasting 9 days in November 2007 where production averaged 150 BOPD and the GOR was approximately 50,000 SCF/STB, have been made since. Cumulative oil production has been approximately 197 MBO. The proposed 18-12C will go pretty much in the opposite direction, to hopefully get away from the high GOR that has plagued the 18-12B well for virtually its entire history, of the 18-12B and is targeting reserves that are not currently being produced by any other well in the area. According to Sean McLaughlin, BPXA CTD Engineer, there are no other wells in the area of the 18-12B wellbore and that it was drilled to test the viability of that portion of the reservoir. Additionally, Mr. McLaughlin stated that references in the application to the subject well making only gas was meant to convey that the well was • ~_ ,, essentially a gas well that produced minor amounts of liquid hydrocarbons and not an absolute declaration that zero oil was being produced. Conclusion: The 18-12B was never a particularly strong producer and has been plagued by high GOR production pretty much from the day it was first put on production, and has shown no to very modest recharge potential when it was shut in.. Since all available sands were perforated when the well was completed there are no real options to try to improve oil recovery from this well. Due to the high GOR and low oil production rates this well is capable of it would spend very little if any time on production and therefore would not recovery any significant reserves from this portion of the pool. Sidetracking the well in an attempt to access new reserves and thus return the well to a useful producer is the prudent option for this well at this time. Therefore, I recommend approving BPXA's requests. ~,<~ David S. Roby ~~~--- Sr. Reservoir Engineer July 14, 2010 12/19/07 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth >~``~~~~ 6~~~a ~~~ ~t 2~ Well Jnh # I nn rlasr~intinn NO. 4525 Company; State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt., Lisburne n~~o al c„L.~ en 15-39A 11661174 MCNL '~ 08/24/07 1 1 14-32 11676961 RST 09/14107 1 1 X-30A 11649992 CH EDIT PDC GR (JEWELRY LOG '} I y 10/06107 1 03-36A 11745217 CH EDIT PDC GR (UStT) ~ ( U1'~- 05103/07 1 15-30A 11767139 MCNL - ~ 09105107 2 1 18-12B 11216204 MCNL 07104106 2 1 E-216 11133205 MCNL ' -/GJ '$ 12/07/05 2 1 P2-56 11686777 RST ~ 08108/07 2 1 H-33 11686792 RST CjL _ "~ 10/20/07 2 1 06-16 11686797 RST _ < 11/15/07 2 1 L2-16 11626482 RST 05!10!07 2 1 D-226 11661167 MCNL Q J~} 08/26/07 2 1 03-14A 11212846 CH EDIT SDCL GR (USIT1 ~(xp ~ QA ~' J ~ 04/24/06 2 1 MPS-21 PROD 11628749 MCNL (MEM PPROF) ~ --~~ ~JS~7 4 j,,l_ _ 01/15/07 2 1 C-22A 40013486 OH MWD/LWD EDIT (~ -Q ~ ~j ~sJ 05110/06 2 1 E-15C 40013555 OH MWD/LWD EDIT ~p ~ (o (~ 'e "~~(~ 06/03106 2 1 r'LCHJC MVlV9VYYLCUVC RCI~CIr' 1 Oi JWIVIIYV AIYU RCIURIVIIVb UIVC {.rVYT CHGn I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. - Anchorage, Alaska 99508 Date Delivered: s~ `R ; ~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • DATA SUBMITTAL COMPLIANCE REPORT 7119/2007 Permit to Drill 2050730 Well Name/No. PRUDHOE BAY UNIT 18-12B Operator BP EXPLORATION (ALASKA) INC MD 13914 TVD 8731 Completion Date 7/4/2005 Completion Status 1-OIL Current Status 1-OIL sy~u. d. hb d ~, ~,,ry.r" API No. 50-029-21615-02-00 UIC N REQUIRED INFORMATION Mud Log No Samples IVo Directional Survey Yes ~~ DATA INFORMATION Types Electric or Other Logs Run: MWD / NGP, GR / ROP (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Fmtt Number Name Scale Media No Start Stop CH Received Comments ;QED D Asc Directional Survey 11856 13914 Open 7/29/2005 IIFR ~ Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / 1~ Daily History Received? ~N Chips Received? '~f7*fi"" Formation Tops vL' N Analysis Y'-TN~ Received? Comments: Compliance Reviewed By: Date: To: State of Alaska WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : 18-12B August 15, 2007 AK-MW-3762573 18-12B: Digital Log Images: 50-029-21615-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 . ,~`~ Dateu ~' -- ~ -- ~~5 "~3 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~ 153g~ STATE OF ALASKA ALAS LAND GAS CONSERVATION COMION WELL COMPLETION OR RECOMPLETION REPORT AN 1~ AlJG ~ ~ ~ilt~~ 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.,os zoAaczs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ~~~~ 1b. Well Class: ~g~lr~p~~atory ^ tra ' r hic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 7/4/2005 12. Permit to rill Number 205-073 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/20/2005 13. API Number 50-029-21615-02-00 4a. Location of Well (Governmental Section): Surface: 1166' SNL 403' EWL SEC 1 11N 7. Date T.D. Reached 6/27/2005 14. Well Name and Number: PBU 18-12B , , . 9, T , R15E, UM Top of Productive Horizon: 3158' SNL, 4880' EWL, SEC. 19, T11N, R15E, UM g, KB Elevation (ft): 47' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 3067' SNL, 601' EWL, SEC. 20, T11N, R15E, UM 9. Plug Back Depth (MD+TVD) 13878 + 8730 Ft 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 692168 y- 5960712 Zone- ASP4 10. Total Depth (MD+TVD) 13914 + 8731 Ft 16. Property Designation: ADL 028321 _ TPi; x- 696694 y- 5958837 Zone-_ASP4 Total Depth: x- 697376 Y- 5958946 Zone- ASP4 11 • Depth where SSSV set 2268' MD 17. Land Use Permit: -----~ - -~--------------- ----~-------- 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD / NGP, GR / ROP 2. CASING, LINER AND CEMENTING RECORD CASING ETTINd EPTH MD ETTINCa EPTH TVD I..IOLE AMOUNT SIZE WT. PER FT. GRADE OP TTOM OP TTOM -SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surface 110' 30" 1610# Poleset i3-3/8" 68# / 72# K-55 / L-80 Surface 2830' Surface 2697' 17-1/2" 500 sx Coldset III, 400 sx CS II 9-5/8" 47# L-80 Surtace 9935' Surface 8303' 12-1/4" 500 sx Class'G', 300 sx CS 7" 29# L-80 9631' 11830' 8153' 8737' 8-1/2" 50 sx Class 'G' 4-1/2" 13.5# N-80 11707' 11864' 8727' 8740' 8-1/2" Uncemented Slotted Liner 2-3/8" 4.7# L-80 11628' 13914' 8721' 8731' 3" 60 sx Class 'G' 23. Perforations open to Produc B I Si tion (MD + N D of Top and " " 24. TUBING RECORD ottom nterval, ze and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 1.56" Gun Diameter, 6 spf 3-1/2", 9.3#, N-80 11730' 11732' MD TVD MD TVD 12560' - 13120' 8761' - 8742' 13190' - 13290' 8740' - 8734' 25. ACID, FRACTURE, :CEMENT SQUEEZE, ETC. 13400' - 13630' 8731' - 8730' 13700' - 13780' 8728' - 8728' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protect w/ 21 Bbls McOH Z6. PRODUCTION TEST Date First Production: July 28, 2005 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 8/3/2005 Hours Tested g.1 PRODUCTION FOR TEST PERIOD OIL-BBL 156 GAS-MCF 5,223 WATER-BBL -0- CHOKE SIZE 56.5 GAS-OIL RATIO 33,391 Flow Tubing Press. 1,21 Casing Pressure 1,350 CALCULATED 24-HOUR RATE OIL-BBL 615 GAS-MCF 20,548 WATER-BBL -0- OIL GRAVITY-API (CORK) 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 chips; if none, state "none". None COMP! ET;~,if ~ ~+ pper~!! .C~ S 67fi, AUG ~ ~ 1Q0~ VERIFIED Form 10-d117"TT~`~d"`t2/2003 .. ~ lC/ONTINUED ON REVERSE SIDE / X13. GEOLOGIC MARKERS 29' RMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". {From 18-12A) None Sadlerochit 9915' 8295' ~ AUG 0 S ~~ 0 5 ~ + r`~id5~~i lilt & G8~ ~,re3lts~. COtCIf'OISSIO ~SitC~t7i`~r~ly 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terris Hubble Title Technical Assistant Date ~ -OS- PBU 18-126 205-073 Prepared By Name/Number Terris Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeRa~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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. IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". ITeM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION ~ ge 1 of 17 Operations Summary Report ~~~ ~ Z00~ Legal Well Name: 1 8-12 ~18sk~ ~~~ ~ ~ ~ - ~:~t~s ~~:'~~ ~~ Common W ell Name: 1 8-12 Sp~~~?~~11/9/1986 Event Nam e: REENTE R+COMPLETE Start: 6/11/2005 En 7/4/2005 Contractor Name: NORDIC CALISTA Rig Release: 7/4/2005 Rig Name: NORDIC 1 Rig Number: 1 Date From - To Hours ~ Task Code NPT j Phase I Description of Operations 6/12/2005 07:30 - 08:30 1.00 _ _ MOB P PRE Rig released from 05-36A ~ 07:30Hrs on 6/12/2005. Prep to move rig off well. 08:30 - 10:00 1.50 MOB P PRE PJSM. Jack-up rig. Pull rig off well & set down. Clean up location & conduct post operations pad inspection. 10:00 - 12:45 2.75 MOB P PRE PJSM. Install derrick rams. UD windwalls. Scope down derrick. 12:45 - 13:30 0.75 MOB P PRE PJSM. Open up pipe shed. P/U gooseneck with crane & lower down onto trailer. Secure gooseneck on trailer. L/D derrick. 13:30 - 14:00 0.50 MOB P PRE Jack-up rig, hook up camp & prep for move. 14:00 - 14:30 0.50 MOB P PRE Held pre-move safety meeting with crew, security, tool services & CPS. CPS strap & confirm rig's height. 14:30 - 18:00 3.50 MOB P PRE Move rig & camp from 05-36A to DS#18. Meanwhile LRS load & kill 18-12. 18:00 - 00:00 6.00 MOB N WAIT PRE Wait for winds to subside below 20 mph. -Winds at 20 mph, gusting 30-35 mph. 6/13/2005 00:00 - 18:00 18.00 MOB N WAIT PRE Continue to wait on wind. -Winds at +/-20 mph, gusting 30-35 mph. 18:00 - 00:00 6.00 MOB N WAIT PRE Continue to wait on wind. - Winds at +/-20 mph, gusting 30-35 mph. 6/14/2005 00:00 - 07:15 7.25 MOB N WAIT PRE Continue to wait on wind. -Winds at +/-20 mph, gusting 30-35 mph. 07:15 - 07:45 0.50 MOB N WAIT PRE Winds subside to 13mph with 22mph gusts. Decide to move rig & lay herculite. PJSM. Jack-up rig. Pull rig off forward. Lay herculite in front of well 18-12. 07:45 - 18:00 10.25 MOB N WAIT PRE Continue to wait on wind to subside before raising derrick & windwalls -Winds at +/-20 mph, gusting 25 - 30mph. 18:00 - 18:30 I 0.501 MOB I N I RREP I PRE 18:30 - 00:00 5.50 MOB N RREP PRE 5/2005 00:00 - 02:30 2.50 MOB N RREP PRE 02:30 - 03:00 0.501 MOB N RREP (PRE 03:00 - 08:00 5.00 MOB N RREP PRE 08:00 - 16:00 8.00 MOB N RREP PRE 16:00 - 00:00 8.00 MOB N RREP PRE 6/16/2005 ~ 00:00 - 04:00 ~ 4.00 ~ MOB N ~ RREP ~ PRE 04:00 - 05:00 I 1.00 i MOB I N i RREP i PRE 05:00 - 10:00 i 5.00 i MOB N WAIT ~ PRE 10:00 - 14:00 I 4.001 MOB I N I WAIT I PRE Meanwhile repair moving system. Through trouble shooting and discussions with Columbia, determined the front driller's side jack has failed. Repair same. PJSM for removal of the axle wheel assembly. - Still waiting on wind. Remove axle and wheel assembly. Continue to work on removal of axle and wheel assy. Bleed off hydraulic oil from cylinder.Attempt to remove cylinder. No Go Reevaluate plan. Cylinder housing rusted in will not drop out under it own weight. Evaluate options and risk assess options. Weld strapes to prevent cylinder from separating. Will use bottle jacks to seperate cylinder from rig while stabilizing cylinder with rig loader. Weld steering arm to jacking cylinder. Install jack. -- Still Waiting on winds to subside. Consistent 20 - 30 mph winds. Reposition axle and wheel assembly under rig. Land asembly in trunion cradle. Continue to WOW. Complete installation of wheel and axle assembly. Continue to WOW Wind speed 22 with gusts to 30 mph. WC 15. Secure damaged cylinder to base. Function and load test. OK. Continue to wait on wind. Wait on wind. Printed: 7/11/2005 10:20:10 AM BP EXPLORATION ~~ ~~ e 2 of 17 Operations Summary Report ~~~ ~ ~2~i~5 Legal Well Name: 1 8-12 Alaska Vii! ~ ~a~ C~°e"- I;,~t,;;,~t~=9it~s Common W ell Name: 1 8-12 Spy~r~~~jt~g11/9/1986 Event Nam e: REENTE R+COM PLET E Start : 6/11/2005 End: 7/4/2005 Contractor Name: NORDIC CALIS TA Rig Release: 7/4/2005 Rig Name: NORDIC 1 Rig Number: 1 Date ~ From - To , Hours Task ~ Code ' ! NPT I Phase I Description of Operations - - - - - -- 6/16/2005 10:00 - 14:00 4.00 MOB N WAIT - PRE _ - - - - _ Bleed down fA to 1000 psi -gas to 1200' MD as per integrity engineer records. 14:00 - 16:00 2.00 MOB N WAIT PRE Continue to WOW and bleed IA. 16:00 - 16:30 0.50 MOB N WAIT PRE Weather letting up. Gusts at 20 mph. Call out crane. 16:30 - 16:45 0.25 MOB P PRE PJSM for raising derrick 16:45 - 20:15 3.50 MOB P PRE Raise derrick and windwalls. 20:15 - 22:00 1.75 MOB P PRE PJSM Move on to well. 22:00 - 23:30 1.50 MOB P PRE NU BOP's. 23:30 - 00:00 0.50 MOB P PRE Pick up injector. 6/17/2005 00:00 - 00:30 0.50 MOB P PRE Continue to PU injector. 00:30 - 03:30 3.00 RIGU P PRE PU goosneck and stab coil. 03:30 - 12:30 9.00 BOPSU P PRE Test BOP's. AOGCC's John Crisp waived witnessing the BOP test. - Valve #1 failed and rebuilt. 12:30 - 14:00 1.50 WHIP P WEXIT Weld on CTC. Pull test to 35,000 Ibs /pressure test to 3500 psi. 14:00 - 15:30 1.50 WHIP P WEXIT Injector maintenance. 15:30 - 16:00 0.50 WHIP P WEXIT Pump dart. Hit at 38.2 bbls. 16:00 - 17:00 1.00 WHIP P -WEXIT Prep tools for setting whipstock. Open swab and master, 17 turns. - Hole on a vac. Fill hole while RIH. 17:00 - 18:00 1.00 WHIP P WEXIT MU BHA #1. MU injector. 18:00 - 20:30 2.50 WHIP P WEXIT RIH with WS setting BHA 20:30 - 22:15 1.75 WHIP P WEXIT Attempt to tie-in. Erratic MWD signal detection. Adjusting circulating rates. Shut down pump unable to restablish rate pressure at .25 bpm pressure climbing. Decide to POH. 22:15 - 00:00 1.75 WHIP N DFAL WEXIT POH to investigate apparent flow restriction in BHA. POH filling backside 6/18/2005 00:00 - 01:30 1.50 WHIP N DFAL WEXIT Change FAIV, orienter, &MWD probe checked check valves. Frow tested orienter believe it to be partially plugged. Will send orienter in for tear down. 01:30 - 03:30 2.00 WHIP N DFAL WEXIT RIH. 03:30 - 05:30 2.00 WHIP P WEXIT Tie-in log. -20' correction. 05:30 - 06:00 0.50 WHIP P WEXIT RIH to setting depth, Top of WS at 11860'. Orient to 57L. Circluate at 2.36 bpm at 4325 psi for 4 minutes. Bleed off wait 4 minute. Orient to 40L .Attempt to pressure to set WS but getting returns. Attempt to activate FAIV at higher rate. Increase rate to 2.72 bpm at 4570. Return rate 1.70 bpm. Circulate for 4 minutes. Bleed off and wait 4 minutes. Pressure up. Shear at 1700 psi. & .6 bbl of volume. Orientation 23L. PU and set down with 2k. - Preliminary picks: TOWS 11,860', BOWS 11,873' at 23LOHS. 06:00 - 08:00 2.00 WHIP P WEXIT POH 08:00 - 08:45 0.75 ZONISO P WEXIT Lay down BHA. PU cement nozzle. 08:45 - 11:00 2.25 ZONISO P WEXIT RIH with cementing BHA. Correct to flag at 11,605' MD. Tag WS at 11,870' MD. Flag pipe at 11,860' MD. 11:00 - 11:15 0.25 ZONISO P WEXIT Conduct infectivity test. -Well open: Circ 1.0 / 0.7 bpm, losing approximately 0.4 bpm at 550 psi. - Shut in: - Circ 1.0 bpm at 700 psi WHP, 1000 psi Circ pressure. Printed: 7/11/2005 10:20:10 AM BP EXPLORATION ~~~ ®~ L~~SPage 3 of 17 Operations Summary Repor ~la3ka Gii ~ ~~ Gaf3~. Can=s~i;Stuli Legal Well Name: 1 8-12 ~ - J Common W ell Name: 1 8-12 Spud Date: 11/9/1986 Event Nam e: REENTE R+COM PLET E Start : 6/11/2005 End: 7/4/2005 Contractor Name: NORDIC CALIST A Rig Release: 7/4/2005 Rig Name: NORDIC 1 Rig Number: 1 Date From - To I'; Hours - Task ~ Code NPT Phase ~ I , Description of Operations i _ 6/18/2005 - - 11:00 - 11:15 0.25 -- ZONISO - P _ WEXIT _ _ _ _ _ __ _-- - - -Circ 1,5 bpm at 1000 psi WHP, 1700 psi circ pressure. -Open well, decrease rate. 11:15 - 11:30 0.25 ZONISO P WEXIT PJSM for cementing. 11:30 - 12:45 1.25 ZONISO P WEXIT Pump squeeze cement: - Pressure test lines to 4000 psi with fresh water. - Pump 15.8 ppg squeeze cement, 21 bbls total. - Follow with KCI. - Shut in well with 39 bbls away (1 bbl cement}. - Circ 1.5 bpm, 1000 psi, 1300 WIHP to 44 bbls (6 bbls cement) - Circ 1.0 bpm, 1300 psi, 1500 WHP to 48 bbls (10 bbls cement) - Obtained 500 psi squeeze pressure. - Lay in 11 bbls cement, holding 1500 psi WHP to 10,650' MD. 12:45 - 13:00 0.25 ZONISO P WEXIT PUH to safety at 9200' MD, holding 1500 psi WHP, pumpng 1 bpm. 13:00 - 13:20 0.33 ZONISO P WEXIT WOC at safety holding 1500 psi WHP. - Pump 30 bbls 2ppb bio at 1.0 bpm down coil. 13:20 - 13:45 0.42 ZONISO P WEXIT RIH, holding WHP aY1500 psi, pumping 1 bpm. 13:45 - 14:30 0.75 ZONISO P WEXIT Suspect may be pumping cement away. Bleed off pressure. Verify 1:1 returns. OK. Continue to cleanout to flag at 11,860' M D. - Some seepage losses once washed by perfs (0.1 bpm) 14:30 - 16:30 2.00 ZONISO P WEXIT POOH, replacing voidage. - Hole fill indicates minimal to no losses. 16:30 - 17:00 0.50 ZONISO P WEXIT Jet stack. 17:00 - 19:00 2.00 WHIP P WEXIT PJSM. Conduct pipe straightener test. Test postponed until longer sling can be obtained. Current sling is interfering with straightener. 19:00 - 19:45 0.75 STWHIP P WEXIT MU window milling BHA. 19:45 - 22:30 2.75 STWHIP P WEXIT RIH. Correct at flag -14.Tag cement at 11842. 22:30 - 00:00 1.50 STWHIP P WEXIT Mill window 1.52 / 1.49 bpm at 1920 psi, FS = 1700 psi. 6/19/2005 00:00 - 03:50 3.83 STWHIP P WEXIT Continue milling window 1.54 / 1.54 bpm @ 2500 psi. 3K WOB, ROP 1 fph. 11868 BOW 03:50 - 05:45 1.92 STWHIP P WEXIT Mill open hole to 11878. 05:45 - 07:00 i.25 STWHIP P WEXIT Ream window. Dry tag. 07:00 - 09:15 2.25 STWHIP N WAIT WEXIT Wait on trucks for fluid swap. 09:15 - 11:00 1.75 STWHIP P WEXIT POOH with window milling BHA. 11:00 - 11:45 0.75 STWHIP P WEXIT Lay down BHA. - 2.74 go / 2.73 no-go string mill - 2.73 go / 2.72 no-go pilot mill 11:45 - 20:30 8.75 STWHIP P WEXIT PJSM. Commence pipe straightener test. - Bring slings to rig floor. - Add slings to top of injector, eliminate interference with UTIM. -Test straighener at 600, 700, and 800 lbs. No indication of pipe straightening. Mic coil. Straightener "egging" the pipe. - Cut 64' of coil. - PJSM. Remove roller above the guide roller, lengthen the section of pipe being straightened. This allows for too much room between rollers. - Re-install rollers, 2". - Re test increasing the pressure in increments from 1000 Printed: 7/11/2005 10:20:10 AM BP EXPLORATION ~ age 4 of 17 ~u~ a ~ z~o~ Operations Summary Report Legal Well Name: 18-12 ~itC4sJt~yu Common Well Name: 18-12 Spud Date: 11/9/1986 Event Name: REENTER+COMPLETE Start: 6/11/2005 End: 7/4/2005 Contractor Name: NORDIC CALISTA Rig Release: 7/4/2005 Rig Name: NORDIC 1 Rig Number: 1 Date From - To Hours Task ! Code ~ NPT Phase 6/19/2005 11:45 - 20:30 _ - - 8.75 STWHIP~ P ~ WEXIT 20:30 - 21:30 I 1.001 DRILL I P I I PROD1 21:30 - 22:30 1.00 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PRODi 6/20/2005 00:00 - 01:30 1.50 DRILL P PROD1 01:30 - 02:00 0.50 DRILL N DFAL PROD1 02:00 - 04:10: 2.17 DRILL I N DFAL PRODi 04:10 - 05:10 1.00 DRILL N DFAL PRODi 05:10 - 05:30 0.33 DRILL N DFAL PRODi 05:45 - 06:00 0.25 DRILL N DFAL PRODi 06:00 - 08:30 2.50 DRILL N DFAL PRODi 08:30 - 08:45 0.25 DRILL P PROD1 08:45 - 11:00 2.25 DRILL P PROD1 11:00 - 11:45 0.75 DRILL P PROD1 11:45 - 12:30 0.75 DRILL P 12:30 - 13:15 0.75 DRILL P 13:15 - 13:30 0.25 DRILL P 13:30 - 15:15 1.75 DRILL P 15:15 - 17:00 1.75 DRILL P 17:00 - 18:00 1.00 DRILL P 18:00 - 19:00 I 1.001 DRILL I N PROD1 PROD1 PROD1 PROD1 PROD1 PRODi RREP I PROD1 Description of Operations psi,1500psi and 1750 psi. Seeing local dimpling at initial point of contact when force is applied to stationary pipe. At 1750 psi pipe is flattening. The force is being applied with 2" roller positioned approximately midway between 2 2" rollersl8" apart. Hydraulic force applied to a cylinder with assumed 3" dia piston. Estimated bending stress applied approximately 160,000 psi (with 1000 psi hydraulic pressure on 90,000 psi yield material. Flattening pipe.110" ovality but not straightening it any noticable amount. Test terminated. Install weld on coil connector. Pull test to 35000. OK. Pressure test to 3500 psi OK. MU drilling build BHA 2.6 degree motor. RIH to 180'. PU 10+' to check coil for damage, just to be safe. OK. Continue to RIH Continue to RIH. Tag at 11893 uncorrected. Orient to 108E Lost pulser signal. Attempt changing pumps checked pulsation dampners eta POH. Change out MWD pulser & probe. RIH. SHT. Orienter failed. POOH. Change out Orienter. RIH. Orient TF to 90L Directionally drill to 11,925' MD - Free spin: 3300 psi - 3700-4000 psi at 1.5 / 1.5 bpm Tie in. No depth correction required RA at 11,870' MD. -- Observed leak from pits onto herculite. Placed additional spill containment. -- Removed lower panels to evaluate leak path. -- Shut down operation and held plan forward/PJSM. -- Resumed operation and commenced evaluating leak path. Orient TF to 80L. Significant reactive torque. Directionally drill to 11,942' MD. - Free spin: 3300 psi - 3700-4000 psi at 1.5 / 1.6 bpm - 10k CT wt - 60 fph ROP Orient TF again to 50L. Directionally drill to 11,974' MD. - Free spin: 3300 psi - 3700-4000 psi at 1.5 / 1.6 bpm - 12k CT wt - 60 fph ROP Orient TF 80L. Extremely difficult to maintain toolface. Directionally drill to 12,025' MD. - Free spin: 3300 psi - 4000 psi at 1.5 / 1.6 bpm - 8-9k CT wt Circulate bottoms up prior to commencing welding operations. Printed: 7/11/2005 10:20:10 AM BP EXPLORATION ~ Page 5 of 17 Operations Summary Report ~~~ ~ ~ ~~~~ ...r__ Legal Well Name: 18-12 ~~ s•1;~1~~...~ ~ Common Well Name: 18-12 'S~puc~~D"ate: 11/9/1986 Event Name: REENTER+COMPLETE Start: 6/11/2005 End: 7/4/2005 Contractor Name: NORDIC CALISTA Rig Release: 7/4/2005 Rig Name: NORDIC 1 Rig Number: 1 Date From - To Hours Task ~~ Code ~ NPT Phase ~ Description of Operations 6/20/2005 18:00 - 19:00 1.00 DRILL N RREP PROD1 PU to 9500'. 19:00 - 20:00 1.00 DRILL N RREP PROD1 Weld repair pit #3. Three spots repaired. 20:00 - 20:30 0.50 DRILL N RREP PROD1 RIH to 9923'. PIN hole coil. 20:30 - 22:00 1.50 DRILL N DFAL PROD1 POH to swap reels. 22:00 - 23:00 1.00 DRILL N DFAL PROD1 LD BHA. 23:00 - 23:15 0.25 DRILL N DFAL PROD1 PJSM for N2 blow down. 23:15 - 00:00 0.75 DRILL N DFAL PROD1 Blow down reel. 6/21/2005 00:00 - 03:00 3.00 DRILL N DFAL PROD1 Pull back coil to reel. Secure coil. Retact drive pins. 03:00 - 05:00 2.00 DRILL N DFAL PROD1 Wait on arrival of crane. 05:00 - 05:15 0.25 DRILL N DFAL PROD1 PJSM for reel swap 05:15 - 07:00 1.75 DRILL N DFAL PROD1 Swap Reel. 07:00 - 08:00 1.00 DRILL N DFAL PRODi Pull coil to injector. Stab. 08:00 - 09:15 1.25 DRILL N DFAL PROD1 MU CTC. Pressure test hardline. Pull test/pressure test. 09:15 - 10:00 0.75 DRILL N DFAL PROD1 Pump volume dart. Hit at 39.3 bbls. 10:00 - 10:45 0.75 DRILL N DFAL PROD1 PU build BHA with 2.8 deg motor. 10:45 - 13:00 2.25 DRILL N DFAL PROD1 RIH with BHA #7. - SHT at 1100' MD. 13:00 - 14`45 1.75 DRILL P PROD1 Orient. Attempting to orientate. unable to hold tool face if oriented above window. By trial and error able to orient at 11980 to 90L. 14:45 - 15:30 0.75 DRILL P PROD1 Directionally drill 1.55 / 1.46 bpm C~3 3850 psi 3650psi =FSSurface wt 9.6k, ROP 30-50. 15:30 - 16:30 1.00 DRILL P PROD1 Having difficulty getting clicks in open hole.lnproved with higher pump rate. 16:30 - 18:00 1.50 DRILL P PROD1 Directionally drill 1.48 / 1.43 bpm ~ 3800 psi 3450psi =FS Surface wt 8.3 k, ROP 50-70. 18:00 - 18:15 0.25 DRILL P PRODi Directionally drill 1.5 bpm, 4000 psi on btm, 3600 psi off btm WOB increasing 18:15 - 18:40 0.42 DRILL P PRODi Wiper trip to window 18:40 - 20:00 1.33 DRILL P PROD1 Drill directional 1.5 bpm 4000 psi on btm, 3700 psi off btm 20:00 - 20:15 0.25 DRILL P PROD1 Orient TF to 90L Formation likely cause of difficult orientation 20:15 - 21:45 1.50 DRILL P PROD1 Drill directional 1.5 bpm 4000 pis on btm, 3700 psi off btm 21:45 - 22:30 0.75 DRILL P PRODi Wiper trip to window Swap mud system to new Flo-Pro 22:30 - 23:00 0.50 DRILL P PROD1 Orient TF to 90L 23:00 - 00:00 1.00 DRILL P PROD1 Drill directional 1.5 bpm 3900 psi on btm, 3150 psi off btm 6/22/2005 00:00 - 03:00 3.00 DRILL P PROD1 Drill directional 1.9 bpm 3900 psi on btm, 3100 psi off btm Good turns, build ended earlier than expected 03:00 - 05:30 2.50 DRILL P PROD1 POOH for lateral BHA/MHA 05:30 - 06:45 1.25 DRILL PROD1 OOH with BHA/MHA Jet stack: significant amt. of metal shavings coming across shakers Printed: 7/11/2005 10:20:10 AM BP EXPLORATION Page 6 of 17 Operations Summary Report ,~.as~a Oil ~ ~~s t~~~~. ~'~as~=n~ss~s~r: Legal Well Name: 18-12 ~~~~~'~°~~'~ Common Well Name: 18-12 Spud Date: 11/9/1986 Event Name: REENTER+COMPLETE Start: 6/11/2005 End: 7/4/2005 Contractor Name: NORDIC CALISTA Rig Release: 7/4/2005 Rig Name: NORDIC 1 Rig Number: 1 Date From - To Hours ''~, Task ~ Code NPT Phase Description of Operations 6/22/2005 05:30 - 06:45 1.25 DRILL PROD1 in last few hundred feet of trip MU new BHA/MHA 06:45 - 07:30 0.75 DRILL N WAIT PROD1 Wait on orders from Anchorage regarding motor bend. 07:30 - 10:15 2.75 DRILL P PRODi RIH 10:15 - 10:30 0.25 DRILL P PROD1 Tie in to RA tag. Correction -12'. 10:30 - 10:50 0.33 DRILL P PROD1 RIH. Tag at 11432'. 10:50 - 14:30 3.67 DRILL P PROD1 Directionally drill 1.5 / 1.45 bpm at 3550 psi, FS= 3000 psi. 20-40 14:30 - 17:15 2.75 DRILL P PROD1 Wiper to 9700'. No Problem at window. 17:15 - 17:45 0.50 DRILL P PRODi Orient 17:45 - 18:00 0.25 DRILL P PROD1 Directionally drill 1.48 / 1.48 bpm ~ 3575 psi. FS = 3100 psi. Surface wt 6K. ROP: 116 fUhr 18:00 - 18:15 0.25 DRILL P PROD1 Orient 18:15 - 18:50 0.58 DRILL P PROD1 Directionally drill 1.48 / 1.48 bpm @ 3575 psi. FS = 3100 psi. Surface wt 6K, ROP 50+. 18:50 - 19:05 0.25 DRILL P PROD1 Orient 19:05 - 19:20- 0.25 DRILL P PROD1 Directional drill - ~ 1.5/1.5 bpm 3850 psi on btm, 3150 psi off btm Problems getting bit to drill 19:20 - 19:35 0.25 DRILL P PROD1 Short wiper trip to 12400' to clean hole. 19:35 - 19:50 0.25 DRILL P PROD1 Directional drill 1.5/1.5 bpm 3850 psi on btm, 3100 psi off btm Problems with MWD, hard to get a good survey 19:50 - 22:00 2.17 DRILL P PRODi Directional drill & orient TF (50/50 time split). 1.5/1.5 bpm 3800 psi-4000 psi on btm, 3150 psi off btm Problems with MWD, hard to get a good surrey 22:00 - 22:40 0.67 DRILL P PROD1 Wiper trip to window 22:40 - 00:00 1.33 DRILL P PROD1 Directional drill 1.55/1.57 bpm 4100 psi on btm, 3200 psi off btm 6/23/2005 00:00 - 00:30 0.50 DRILL P PRODi Orient 00:30 -04:10 3.67 DRILL P PROD1 Drill directional 1.6/1.2 bpm: losses remain steady at .4 bpm Geo feels fault was hit at 12775'. 4100 psi on btm, 3200 psi off btm. 6K Ib WOB. Problems orienting, most likely formation related. TF not holding, orienting not consist regarding degrees/click. MWD having some problems getting up good surveys. 04:10 - 04:50 0.67 DRILL P PROD1 Wiper trip to window. 04:50 - 05:20 0.50 DRILL P PROD1 Tie-in into RA tag. Correct +4'. 05:20 - 05:45 0.42 DRILL P PROD1 RIH to TD. 05:45 - 06:15 0.50 DRILL P PROD1 Orient. 06:15 - 07:00 0.75 DRILL P PROD1 Pu to 12300. Leak in reel house hard iron. Repair leak .RIH. Printed: 7/11/2005 10:20:10 AM BP EXPLORATION ~ 7 of 17 Operations Summary Report ~~G ~ ~ X005 Legal Well Name: 18-12 Al~~~a L1~@ `~~ ~~~ C~r~~. ~~fT~~~,_,~,IOr Common Well Name: 1&12 Sput~~1/9/1986 Event Name: REENTER+COMPLETE Start: 6/11/2005 End: 7/4/2005 Contractor Name: NORDIC CALISTA Rig Release: 7/4/2005 Rig Name: NORDIC 1 Rig Number: 1 te D Fro - T Ho ' T k C d NPT ' Ph i ti f O D ti a ~ m o urs as o e ase escr p on o pera ons -- 6/23/2005 07:00 - 09:45 2.75 DRILL P PROD1 Directionally drilling 1.5/1.3 bpm C~3 3600 psi. FS = 3100 psi TF 82L. ROP 90, Surface wt 6K. drilled to 12995 stacking Will make wiper to 9700'. 09:45 - 11:45 2.00 DRILL P PRODi Wiper.to 9700. 11:45 - 12:40 0.92 DRILL P PROD1 RIH to 11900 MWD failed. 12:40 - 13:10 0.50 DRILL N DFAL PROD1 POH. MWD restarted. 13:10 - 13:30 0.33 DRILL N DFAL PROD1 RIH to 11900 13:30 - 14:00 0.50 DRILL P PROD1 Continue to complete wiper trip. 14:00 - 15:15 1.25 DRILL P PROD1 Directionally drilling 1.56 / 1.37 bpm ~ 4000 psi. FS = 3100 psi. 140 degree reactive. Drill to 13068'. POH to dial down motor. 15:15 - 18:00 2.75 DRILL P PRODi POH 18:00 - 19:15 1.25 DRILL P PRODi Break down BHA. Jet stack. Bit pulled: 1/3/CT/S/X/CT/BHA 19:15 - 19:45 0.50 BOPSU P PROD1 Function test BOPE: good 19:45 - 21:00 1.25 DRILL P PROD1 PU BHA: 0.8 xtreme motor 2.7 X 3 HCC bit new MWD new MHA 21:00 - 23:30 2.50 DRILL P PROD1 RIH through window 23:30 - 00:00 I 0.501 DRILL I P 6/24/2005 100:00 - 00:15 ( 0.251 DRILL I P 00:15 - 00:30 0.25 DRILL P 00:30 - 02:45 2.25 DRILL P 02:45 - 05:00 2.25 DRILL P 05:00 - 05:30 0.50 DRILL P 05:30 - 06:00 0.50 DRILL P 06:00 - 08:30 2.50 DRILL P 08:30 - 11:30 3.00 DRILL P 11:30 - 12:30 1.00 DRILL P 12:30 - 14:15 1.75 DRILL P 14:15 - 15:00 0.75 DRILL P 15:00 - 15:15 0.25 DRILL P PROD1 Logging up through RA tag PROD1 Log through RA tag. Tie-in at RA tag. Adjust -8'. PROD1 RIH to TD. PROD1 Drill directional & orient: split is dd/orient:5%/95%. TF not holding, acting like orienter is slipping. Losing 0.5 to 0.25 bpm. PROD1 POOH for orienter change. PRODi Make up new orienter. Re-scribe. PROD1 RIH to 1500'. SHT BHA: good. PROD1 RIH PROD1 Orientate to 40 L. Having difficullty holding orientation.Directionally drill 1.54 / 1.42 bpm ~ 3900 psi , ROP 100+ ,Surface wt -5K.Drill to 13163. Having trouble with weight transfer. Existing mud in good shape .3% drill solids but will swap mud .New mud with 4% Iubtex. Circulate to bit still having weight transfer problems. PROD1 Wiper to window. PRODi Directionally drill 1.51 / 1.41 bpm C~3 3700 psi. , FS = 3200 psi. Cleaned up after wiper. drilling off. ROP 150, for a brief interval. Surface wt -8k. Up Wt 28K, Dn Wt 11K.Worked thru shale spudding with -8 surface weight. Making one ft at a time. Broke thru ROP 100+ Surface weight +4K. PROD1 Orient 90R. PROD1 Acts like were are in shale again . Printed: 7/11/2005 10:20:10 AM ~~ of 17 BP EXPLORATION Operations Summary Report ~~~ 0 ~ ~~~~ ~ ~..~ ~"ii ~. ~ I': Legal Well Name: 1 8-12 a ~ .~- ,z~~r~` Common W ell Name: 1 8-12 Spuda#e: 11/9/1986 Event Nam e: REENTER+COMPLETE Start : 6/11/2005 End: 7/4/2005 Contractor Name: NORDIC CALISTA Rig Release: 7/4/2005 Rig Name: NORDIC 1 Rig Number: 1 Date From - To ~' Hours i Task ~ Code i NPT Phase Description of Operations 6/24/2005 15:15 - 15:30 0.25 DRILL P PROD1 Short 300' wiper. 15:30 - 17:30 2.00 DRILL P PROD1 Directionally drill 1.5 / 1.44 bpm ~ 3300 psi, FS = 3050 Still acting shale. GR =100+ 13160 - 13185. Work thru to 13227'. Drill at 1.57/ 1.49 bpm @ 3800 psi , ROP 160+. Drill to 13234. Can't drill. Will try tub pill. - PU wt 27-28k - Dn wt 1 f-12k 17:30 - 19:30 2.00 DRILL P PROD1 Wiper to 9700'. RIH to 11650'. Initial: PU WT: 25.5K Ib, SO WT: 12.6K Ib. Pump 10 bbl Hi Vis, 20 bbp Lub pill, 10 bbl Hi vis sweep. Pill out of bit: PU WT: 24.7K Ib, SO WT: 13.2K Ib. Pill to surface: PU WT: 24.5K Ib, SO WT: 13.2K Ib. EMI 920 pill gave some improvement. Will see how sliding wt. transfer is at TD. 19:30 - 21:30 2.00 DRILL P PROD1 RIH to TD. 21:30 - 23:45 2.25 DRILL P PROD1 Directionally drill WOB: -4100 Ib, 4100 psi on btm, 3500 psi off btm, 1.5/1.35 bpm. wt. stacking, drilling off & getting worse each time. 23:45 - 00:00 0.25 DRILL P PROD1 Wiper trip to window. 6/25/2005 00:00 - 01:00 1.00 DRILL P PROD1 RIH to TD. 01:00 - 02:30 1.50 DRILL P PROD1 Directional drill. Drill to Orient: 50/50. Stacking wt., not drilling off very well. Differential pressure low/non-existent. TF hard to hold with reactive torque (20-40 degrees). 02:30 - 05:00 2.50 DRILL P PROD1 POOH to check mtr. and MU agitator. 05:00 - 07:30 I 2.501 DRILL I P I i PRODi 07:30 - 09:30 I 2.001 DRILL I P I I PRODi 09:30 - 09:45 0.25 DRILL P PRODi 09:45 - 15:00 5.25 DRILL P PROD1 15:00 - 16:30 1.50 DRILL N STUC PRODi 16:30 - 17:15 I 0.751 DRILL I N I STUC I PRODi Make up BHA Add agitator above orienter. RIH to 85' test agitator at 1.1 and 1.4 bpm. Visible vibration in coil. MWD pulsing OK. RIH SHT. OK. Continue to RIH. @ .18 bpm C~3 1483 psi. Tie -in log correction -6'. RIH tag bottom at 13353'. Orient to 110R. 1.40 / 1.34 bpm C~3 3700 psi, FS =3400 psi. Surface wt 6K, ROP 50+. Drill OK. No need to slam to bottom. Agitator working well. Drill to 13372. Stacking. Surface wt -7K. Broke thru shale drilling 1.44/1.41 bpm ~ 3700 psi, FS = 3500 psi Surface wt -3, ROP 60+ Drilled to 13436. Stuck. Pull 57K Hold. Slack off to -SK vary circulation rate 1.6 - .9 bpm Wait on crude. Review inconsistence of SLB procedures on pumping crude. New guide allows for Vapor pressure of <1.99 with FP under 74 degrees versis old guide of Vapor pressure <1.5 psi and no mention of FP. Reviewed with Ed Burrell and SLB TL, BP HSE rep & Co Man. Will proced on a exemption basis. SBL with address issue to be consistent between Service coil and drilling. SLB will test sample of crude to determine FP. Pump 10 bbl crude. Pull free. Printed: 7/11/2005 10:20:10 AM BP EXPLORATION Operations Summary Report ~e 9 of 17 ~,~lG 0 ~ 200 Legal Well Name: 1 Common Well Name: 1 Event Name: Contractor Name: Rig Name: Date `From - To 8-12 8-12 REENTER+COM NORDIC CALIST NORDIC 1 Hours ', Task PLET A ~, Code Alaska Q!~ ~~: t;~iw• u~'~;',~.'~ ~~r Sp X1/9/1986 E Start: 6/11/2005 End: 7/4/2005 Rig Release: 7/4/2005 Rig Number: 1 NPT ~~ Phase i Description of Operations 6/25/2005 17:15 - 17:50 0.58 DRILL P PROD1 Wiper to window. 17:50 - 19:15 1.42 DRILL P PRODi Tie-into RA tag: correction is +9'. RIH to TD. 19:15 - 19:45 0.50 DRILL P PRODi Drill directional 3500 psi off btm, 4100 psi on btm. ROP: 40-60 fUhr. 1.6/1.6 bpm Controlled drilling to hold TF 19:45 - 20:20 0.58 DRILL N STUC PROD1 Lost mtr. work, PU and SO to get it back: Stuck on btm. Overpull 60K Ib., can't pull past 13465' Pumping 10 bbl crude. 20:20 - 21:40 1.33 DRILL N STUC PROD1 Crude at bit: One pull to get free. Wait for crude to get to surface before orienting. 21:40 - 22:30 0.83 DRILL P PRODi Attempt to orient TF to 70 R. 22:30 - 23:00 0.50- DRILL N DFAL PROD1 Couldn't get it to work on btm, PU 300' and attempt again. No go at 300' off btm, 400' off btm, below window or in csg. POOH for orienter change. Flag at 11700' EOP. 23:00 - 00:00 1.00 DRILL N DFAL PROD1 POOH for orienter change. 6/26/2005 00:00 - 01:00 1.00 DRILL N DFAL PROD1 POOH for orienter change. Shop analysis of orienter showed damage to shuttle cam. 01:00 - 01:30 0.50 DRILL P PROD1 Cut 14' off of coil. Flat spots worn on coil due to agitator. 01:30 - 02:15 0.75 DRILL P PROD1 Weld on and pull test CT connector. Passed test. 02:15 - 02:40 0.42 DRILL N DFAL PRODi MU new BHA: New MHA and orienter. 02:40 - 05:45 3.08 DRILL N DFAL PROD1 RIH to 1000'. SHT: good. RIH, tag bottom, correct -14'. 05:45 - 07:30 I 1.75) DRILL I P I I PROD1 07:30 - 08:00 0.50 DRILL P PROD1 08:00 - 08:20 0.33 DRILL P PROD1 08:20 - 08:40 0.33 DRILL P PRODi 08:40 - 09:30 0.83 DRILL P PROD1 09:30 - 11:00 1.50 DRILL P PRODi 11:00 - 11:30 0.50 DRILL P PRODi 11:30 - 11:45 0.25 DRILL P PROD1 11:45 - 13:00 1.25 DRILL P PRODf 13:00 - 14:00 1.00 DRILL P PROD1 14:00 - 16:30 2.50 DRILL N DFAL PROD1 16:30 - 17:45 1.25 DRILL N DFAL PROD1 17:45 - 18:00 I 0.251 DRILL I N I DFAL I PROD1 Directionally drill 1.47/1.49 bpm ~ 4040 psi, FS = 3750 psi, Surface wt -3k, rop 90. Orient from 90R to 65R Directionally drill 1.46/1.39 bpm @ 4100 psi, FS = 3750 psi, Surface wt neutral, ROP 65. Drill to 13565. Stacking. 300' wiper. Directionally drill 1.46/1.39 bpm @ 4100 psi, FS = 3750 psi, Surface wt neutral, ROP 40. Drill to 13600. WiII trip to 9700.Need to check injector. Wiper to 9700'. RIH to window Inspect injector RIH Directionally drill 1.39/1.37 bpm ~ 4050 psi, FS = 3750 psi, Surface wt -4KI, ROP 65. Drill to 13624. Orienter quit. POH for orienter Change out orienter (seal leaking oil). Reposition agitator from above orienter to above motor. Shop analysis showed ?. RIH. Printed: 7/11/2005 10:20:10 AM BP EXPLORATION /~U~ ~ ~ L005 Page 10 of 17 Operations Summary Rep~~t as~~ ~;I ~ C~~ ~~~s. I~~n~r~;~~i~n Legal Well Common W Event Nam Contractor Rig Name: Date i Name: 1 ell Name: 1 e: Name: From - To 8-12 8-12 REENTE NORDIC NORDIC Hours R+COM CALIST 1 Task PLET A Code E NPT ' Start Rig Rig Phase ~ ~~~ `" Spud Date: 11/9/1986 : 6/11/2005 End: 7/4/2005 Release: 7/4/2005 Number: 1 Description of Operations 6/26/2005 18:00 - 20:30 2.50 DRILL N DFAL PROD1 RIH. Tie-in to RA tag. Correct -10'. 20:30 - 21:00 0.50 DRILL P PRODi On btm, orienting. 21:00 - 23:00 2.00 DRILL P PROD1 Drill directional & Orient. 50/50 time split. FS high ~ 3750. Pump Flo-tube pill TF holding. 1.4/1.0 bpm 23:00 - 00:00 1.00 DRILL N STUC PRODi Stuck pipe. No warning from drilling parameters. Pump 10 bbl. pill of crude. Slow pumps when out of bit, pull 55K Ib. After 5 min, pulled free. 6/27/2005 00:00 - 01:00 1.00 DRILL P PRODi Drill ahead. off btm: 3900 psi, on btm: 4100 psi. 0.5 bbl/min losses. WOB gradually stacking out. 01:00 - 02:00 1.00 DRILL N STUC PROD1 Stuck pipe. Pump 10 bbl. crude pill Pull 55K Ib and pipe free after pill out of bit. 02:00 -04:00 2.00 DRILL P PROD1 Drill directional off btm: 3400 psi, on btm: 4000 psi 1.5/1.3 bpm in/out. Stacking WOB. ROP: 22.5 fUhr. 04:00 - 06:15 2.25 DRILL P PROD1 Wiper trip to 12000'. Orient around on way down. 06:15 - 10:40 4.42 DRILL P PROD1 Directionally drilling 1.46 /1.23 ~ 3950psi. FS = 3800 psi -8k surface wt, Drill to 13850. Second loss zone at 13750'. Loss rate increased to .4 bpm. 10:40 - 12:40 2.00 DRILL P PROD1 Wiper to 9700'. 12:40 - 13:15 0.58 DRILL P PROD1 Tie - in log. Correction +22'. 13:15 - 14:00 0.75 DRILL P PROD1 Continue to RIH. Tag at 13866. 14:00 - 16:00 2.00 DRILL P PROD1 Directioally drilling 1.45 / 1.09 bpm C~3 4030 psi, FS = 3800 psi, -5K sufface wt. ROP 30-60.Adding new mud with 5% lubricants. 16:00 - 17:00 1.00 DRILL P PROD1 Directioally drilling 1.45 / 1.09 bpm ~ 3900 psi, FS = 3800 psi, -9K sufface wt. ROP 20. Drilled to 13912'. Called TD. 17:00 - 18:00 1.00 DRILL P PROD1 Wiper to window for final tie-in. 18:00 - 18:10 0.17 DRILL P PROD1 Tie-in. +8' correction. 18:10 - 19:00 0.83 DRILL P PROD1 RIH to TD. 19:00 - 19:50 0.83 DRILL P PROD1 POOH laying in 60 bbl. of Flo-Pro @: 1.4 bpm in/1.15 bpm out, 60 fUmin, (0.5 bbl/min filling below bit, rest cleaning hole). 19:50 - 21:30 1.67 DRILL P PROD1 POOH at 115 ft/min. 1.5 bpm in/1 bpm out Flag pipe at 11500' EOP. Flag pipe at 9500' EOP. At surface test losses: 0 bpm. 21:30 - 22:30 1.00 DRILL P PROD1 LD BHA & bit. Bit: 1 /4/BC/G/X/1 /PN/T D. Nozzle was plugged with .75" X .5" rubber (black, came off of Printed: 7/11/2005 10:20:10 AM BP EXPLORATION ~ 1~t 17 Operations Summary Report ~~~ ~ ~ ZO~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 6/27!2005 21:30 - 22:30 22:00 - 22:30 22:30 - 23:00 23:00 - 00:00 6/28/2005 100:00 - 02:30 02:30 - 05:00 05:00 - 06:00 06:00 - 10:45 ,.-iiin.i~rf A~6! 4';i.. is±'n t.d~ :i.~ F (S i7;,i: ~+i 18-12 ~~ St~,,t« 18-12 Spud ['Ce`.~~"1~~/1986 REENTER+COMPLETE Start: 6/11/2005 End: 7/4/2005 NORDIC CALISTA Rig Release: 7/4/2005 NORDIC 1 Rig Number: 1 Hours ask Code', NPT Phase Description of Operations 1.00 DRILL P 0.50 CASE P 0.50 CASE P 1.00 CASE P 2.50 CASE P 2.50 CASE P 1.00 CASE N 4.75 CASE P 10:45 - 12:15 1.50 GASE P 12:15 - 15:30 3.25 CASE P 15:30 - 16:00 0.50 CEMT P 16:00 - 16:30 0.50 CEMT P 16:30 - 17:15 0.75 CASE P 17:15 - 19:00 19:00 - 19:15 19:15 - 19:30 19:30 - 19:45 1.751 CASE I P 0.25 CASE P 0.25 CLEAN P 0.25 CLEAN P PROD1 RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RREPIRUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD rounded object). Rig up for running liner. Safety meeting for running liner. RIH with casing. MU float assembly per well plan. Drift every joint per town. Fill at 35 jts. down. Pup joint bft 47 and 48. RIH with casing. MU float assembly per well plan. Drift every joint per town. Fill at 35 jts. down. Pup joint b/t 47 and 48. MU liner deployment per well plan. RIH with liner on coil. Pumped out 9 bbl of water to avoid formation damage. Tie-in to 9500' EOP flag, correct -15'. Flag now at 11769.8' EOP. 1 motor down on rig. Unable to go down into open hole. Bad switch to undervoltage/over frequencyshut down to gen #1 on line in SCR found to be cause. No replacement available electrician jumpered around it. Run thru window into open hole circulating at .6 bpm @ 2200 psi.Took 1300 psi to break circulation. Set down 13294,13399,1ose ground to 13300, work back to 13435, Increase rate to .94 bpm ~ 2450 psi. Pump 20 bbl. RIH without pump to 13617. Set down. Circulate .93 bpm C 2450 psi. Pump 20 bbl. RIH w/o pump to 13781. Set down. RIH to 13814. Circulate at 1 bpm C~? 2600 psi. Pump 10bb1. Lost 7'. Pump 20 bbl. Attempt to RIH. No.Go. Pump 25 bbl to shoe. Attempt to rih. Lost ground to 13800. Pump 17bb1 crude outside pipe Attempt to RIH. RIH to 13845. Continue to work pipe lost ground back to 13806. Pump 4 additional bbl crude .RIH to 13908. Thats it!!. Circulate out crude. Drop ball. Swap to KCI. Liner deployed at 3400 psi. Mix Bio-zan pill. Safety meeting with cementers and rig crew. Cement. Pump 12.4 bbl. of cement per well plan. Drop dart. Bumped plug at 47.2 bbl, 2800 psi. 9.8 bbl in annulus. Sting out of liner. POOH for cleanout assembly C 100fpm pumping Q 0.40bpm to replace CT voidage only. OOH. PJSM. S/B injector & L/D LBRT. R/U to P/U cleanout mill/motor & 1" CHS tbg. PJSM on P/U &RIH cleanout BHA. Printed: 7/11/2005 10:20:10 AM BP EXPLORATION ~~~~~12of17 Operations Summary Report ~~~~~~ ~~~ ~ ~~~ ~o~s, Cor~l~,~~J~ia: Legal Well Common W Event Nam Contractor Rig Name: Date ; Name: 1 ell Name: 1 e: Name: From - To ~~~ i 8-12 8-12 REENTE NORDIC NORDIC Hours R+COM CALIST 1 Task ~: PLET A Code I E NPT Start Rig Rig Phase Spud Date: 11/9/1986 : 6/11/2005 End: 7/4/2005 Release: 7/4/2005 Number: 1 Description of Operations 6/28/2005 19:45 - 20:30 0.75 CLEAN P RUNPRD M/U cleanout BHA #15 with 1.875" mill & 1-11/16" straight motor, lower MHA, XO, & 20 jts of 1" CSH tbg. 20:30 - 21:15 0.75 CLEAN N WAIT RUNPRD Observe worn dies on hand slips. W.O. replacement hand slips from BOT. 21:15 - 23:10 1.92 CLEAN P RUNPRD Continue M/U 60 jts of 1" CSH tbg, XO & upper MHA. M/U injector. 23:10 - 00:00 0.83 CLEAN P RUNPRD RIH with cleanout BHA #15. 6/29/2005 00:00 - 00:50 0.83 CLEAN P RUNPRD Continue RIH with cleanout BHA #15 to 11000'. 00:50 - 06:00 5.17 CLEAN P RUNPRD W.O. C. to get to 500psi compressive strength. Meanwhile conduct injector chain inspections. C/O 5 cracked pins & grease injector. 06:00 - 08:30 2.50 CLEAN P RUNPRD RIH. Tag at 13580'. Unable to get past. Spud 10K Ib over, vary pump rates, no go. No motor work. Multiple runs at obstruction. Still no go. 08:30 - 11:15 2.75 CLEAN N DPRB RUNPRD POOH for depth check, motor check. Depth good. 11:15 - 12:15 1.00 CLEAN N DPRB RUNPRD Rack back 80 jts CSH. 12:15 - 13:00 0.75 CLEAN N DPRB RUNPRD Break down BHA/mtr. Bit good. Old mtr. o.k. but replaced anyway. 13:00 - 14:00 1.00 CLEAN N DPRB RUNPRD Jet stack. (Took minimal cmt. back during intitial cleanout attempt). 14:00 - 16:15 2.25 CLEAN N DPRB RUNPRD Make up new mtr. Make up CSH. 16:15 - 16:40 0.42 CLEAN N DPRB RUNPRD MU injector head onto CSH. 16:40 - 18:30 1.83 CLEAN N DPRB RUNPRD RIH. 18:30 - 19:15 0.75 CLEAN N DPRB RUNPRD Hit same obstruction at 13580'. Attempt to mill down -not getting any motor work. 19:15 - 20:00 0.75 CLEAN N DPRB RUNPRD Swap well to double-slick 2% KCL fluid. 20:00 - 21:00 1.00 CLEAN N DPRB RUNPRD Continue to time mill & grind on obstruction & finally mill thru. 21:00 - 21:10 0.17 CLEAN N DPRB RUNPRD Mill obstruction from 13581' with 0.9bpm & 1600psi & fall thru C~? 13585'. P/U clean C~? 31 k. 21:10 - 21:20 0.17 CLEAN N DPRB RUNPRD RIH clean & tag up C~ 13618'. PUH clean to 13580' RBIH & ease-into milling from 13617'. 21:20 - 23:40 2.33 CLEAN N DPRB RUNPRD Mill obstruction from 13615' with 0.9/0.9bpm, 1700/i800psi & up to 5k drag. Pump down 8bbls of 1 ppb bio-KCL pill. Getting little cement fines C the shakers. Attempt to mill from 13622' with 0.9bpm/1800psi -stacking out with up to 10k drag. PUH to 13450' with +!-2k drag & 200psi motorwork. Try to RBIH but set down with so much drag. 23:40 - 23:50 0.17 CLEAN N DPRB RUNPRD Continue PUH with 1-2k drag to 13161'. Establish freespin @ 0.92bpm/1680psi. 23:50 - 00:00 0.17 CLEAN N DPRB RUNPRD RBIH C~? 0.27bpm/300psi & 10fpm. Tag up C~ 13375'. 6/30/2005 00:00 - 01:00 1.00 CLEAN N DPRB RUNPRD Check trip to 11500' (above TOL). 01:00 - 02:25 1.42 CLEAN N DPRB RUNPRD RBIH. Meanwhile pump down 45bbls of 1%bio-KCL water to the mill C~? 13375'. Seeing little wt bobbles from 13400'. Set down Q 13666'. P/U &RBIH. Set down @ 13676', 13681' & several other depths. Continue washing & drifting in hole turning the pump on/off as required & picking up frequently. Tag up @ 13794'. Decide to spot crude in the liner to improve wt transfer to the mill. 02:25 - 02:30 0.08 CLEAN N DPRB RUNPRD PUH to 13780'. Will P/test wellbore before pumping crude to ensure no potential for well control Printed: 7/11/2005 10:20:10 AM BP EXPLORATION Operations Summary Report Legal Well Name: 18-12 Common Well Name: 18-12 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ~ From - To '-, Hours ! Task 'Code ~- - 6/30/2005 102:30 - 03:00 0.50 CLEAN N 03:00 - 04:00 1.001 CLEAN ~ N 04:00 - 05:00 1.00 CLEAN N 05:00 - 05:40 I 0.671 CLEAN I N 05:40 - 06:00 0.33 CLEAN N 06:00 - 09:00 3.00 CLEAN N 09:00 - 11:00 I 2.001 CLEAN I N 11:00 - 13:00 I 2.001 CLEAN I N 13:00 - 18:00 5.001 CLEAN ( P 18:00 - 18:45 I 0.751 CLEAN I P 18:45 - 19:15 I 0.501 CASE I P 19:15 - 19:45 I 0.501 PERFOBI P 19:45 - 20:00 0.25 PERFOB~ P 20:00 - 21:00 1.00 PERFO P 21:00 - 21:15 0.25 PERFOB~ P 21:15 - 23:15 2.00 PERFO P Start: 6/11 /2005 Rig Release: 7/4/2005 Rig Number: 1 ~ ~ ~ Q P ~~ ~ 1''3'"of 17 Rf~~~a a;i ~~ - ~, Spud Date: 11/9/1986 End: 7/4/2005 NPT '~ Phase ~; Description of Operations DPRB RUNPRD Cement > 2000psi compressive strength. Test for well control purposes to check for leaks. Pump down the CT & P/test wellbore for 10mins as follows: Time WHP CTP IAP OAP Onset 4 0 342 216 0 1278 1200 343 217 10 1078 1000 342 216 DPRB RUNPRD Pump down 6bbls of crude (Reid vapor pressure <ipsi @ 100F). Circ out 2bbls out of the mill. DPRB RUNPRD Work pipe in hole to 13801'. Circ out rest of crude. Work pipe without much progress. PUH, RBIH & tag C~ 13700'. DPRB RUNPRD Pump down 17bbls flopro pill with 4% lubetex C~3 0.92bpm/2000psi. DPRB RUNPRD Wash & drift in hole & tag up @ 13801'. DPRB RUNPRD Pump perf pill with 4% Lube-Tex On btm: 3100 psi. Scalloped circulating and WOB graphs indicating bit bounce? Stacking wt., when pumping looks like we're pumping off. DPRB RUNPRD POOH to top of liner at 6 fUmin. Try to RIH to 13800' for dry tag to simulate pert. run. Dry tag o.k. at 13809'. WAIT RUNPRD Change of perforating strategy per town team. Wait on SLB perforating to redo perforating guns per town orders. Wait on 1 #lbbl Bio-Zan w! 3% Lube-Tex to arrive (pill per town orders). RUNPRD Pump 10 bbl. per pill, chase w/ Bio-zan Lay 10 bbl of pert pill. 0.33 bpm, 60 ft/min. Top off with 1 Ib/bbl Bio-zan, double-slick with 3% Lube-tex 1 bpm, 60 ft/min. Flag pipe at 8,500 EOP. RUNPRD Rack back CSH. LD mtr, Circ sub and bit. RUNPRD Line up & P/test wellbore/liner lap for 30mins as follows: Time WHP CTP IAP OAP Onset 18 0 342 203 0 2000 0 343 210 11 1022 0 343 209 26 850 0 342 205 30 780 0 342 204 _> Failed: Leaked 61% of test pressure in 30 mins. Will set LTP. LOWERI R/U to run pert guns. M/U safety jt with TIW valve. Prepare a 2.62" no-go to land locate on TOL (deployment sleeve). Agree with ANC to lay out btm gun jt with 4.69' loaded partial & 16.01' of blank to give more room to position guns on depth. LOWERI PJSM on perforation job #1. LOWERI M/U 18jts of 1.56" HSD 6spf 1606PJ guns & blanks with BCF firing system. LOWERI Held PJSM for P/U 1" CSH. LOWERI Drift MHAs, WOs & no-go with 1/2" ball - OK. Strap & M!U lower disconnect, X/O, 61 jts of 1" CSH tbg, X/O, no-go sub & Printed: 7/11/2005 10:20:10 AM BP EXPLORATION Operations Summary Report ~~-~~°age 14 of 17 .~~G 0 $~ Zu05 .;, ~ ~ ~~ ~ ~ ~ ~~~~ ~ Legal Well Name: 18-12 ~ .,, ~' ~ t Common Well Name: 18-12 ~~ e: 11/9/1986 puc~ Event Name: REENTER+COMPLETE Start: 6/11/2005 End: 7/4/2005 Contractor Name: NORDIC CALISTA Rig Release: 7/4/2005 Rig Name: NORDIC 1 Rig Number: 1 Date ~ From - To Hours ~ Task 6/30/2005 21:15 - 23:15 2.00 PERFC 23:15 - 00:00 0.75 PERFC 7/1/2005 00:00 - 01:30 1.50 PERFC 01:30 - 02:30 1.00 PERFC 02:30 - 05:00 05:00 - 05:30 05:30 - 06:00 06:00 - 06:15 06:15 - 09:30 09:30 - 11:00 11:00 - 14:30 14:30 - 16:30 16:30 - 18:30 18:30 - 19:00 19:00 - 00:00 2.50 0.50 0.50 0.25 3.25 1.50 3.50 2.00 2.00 0.50 5.00 7/2/2005 00:00 - 00:30 0.50 CLEAN 00:30 - 02:30 2.00 CLEAN 02:30 - 02:45 0.25 CLEAN 02:45 - 04;45 2.00 CLEAN 04:45 - 05:05 0.33 CLEAN 05:05 - 07;00 1.92 CLEAN 07:00 - 08;00 1.00 CLEAN Code NPT Phase Description of Operations P LOWERI upper MHA. M/U injector. P LOWERI RIH with perforating BHA#17 to 6500'. P LOWERI Continue RIH with perforating BHA#17 circ pert pill C~ min rate. Correct CTD by -15.7' @ the flag. Wt check ~ 11500': Up = 29.8k, Down = 17k. RIH into Inr C~ 50fpm. Set down C~3 13453'. Up wt = 31 k, Down wt = 16k. N DPRB LOWERI Work pipe to 13457' with 16k set down wt. P/U with 5-9k O/Pull. PUH to 13250'. RBIH & tag Cam? same depth. SI choke and pressure up back side to 1000psi. Dump pressure & try to surge guns past restiriction. Continue pressuring/surging the backside & work guns down to 13462'. Attempt to work guns further in hole with no progress. Decide to POOH. N DPRB LOWERI POOH with pert gun BHA#17 filling via the backside with 70psi WHP. Paint EOP flag ~ 10000'. N DPRB LOWERI OOH. S/D pump & flowcheck well for 30 mins -well stable. Meanwhile held PJSM for R/B 1"CSH. N DPRB LOWERI S/B injector. UD MHAs & R/B 1" CSH tbg. N DPRB tOWER1 PJSM. UD 18jts of 1.56" HSD 6spf 1606PJ guns & blanks with BCF firing head. N WAIT LOWERI Wait on orders from ANC Wait on mill and motor from Baker for milling out 3.5" csg. N DPRB LOWERI PU mill and motor. Put rollers back on injector after taking off straightener. N DPRB LOWERI RIH with 2.80" mill and 2.18 Baker Xtreme motor to cleanout 3.5" csg. RIH past 2.813 nipple at 9399' with .5 bpm rate @ 5 fUmin. No problems. Start RIH with rate at 1.5 bpm ~ 20 fUmin. N DPRB LOWERI Motor work 11,218' - 11,225. FS = 1600 psi, differential 0-400 psi. 1,5 bpm Mtr. work at 11,318' - 11391' FS 1600 psi, differential 300 psi. 1-3 ft/min. Minimal cement returns just before POOH. N DPRB LOWERI POOH to change to 2.8" parabolic mill. N DPRB LOWERI S/B injector. UD cleanout BHA. N DPRB LOW ER1 Perform bi-weekly ROPE pressure/function test. Pressure test inner reel valve. AOGCC test witness waived by Chuck Scheve. Service greased kill line valve & Choke manifold valves 7 & 12 & retested OK. N DPRB LOWERI M/U cleanout BHA #19 with 2.8" parabolic mill & 2.13" straight motor, MHA & CTC. M/U injector. N DPRB LOW ER1 RIH cleanout BHA #19. Wt check - up = 28k & down = 16k. Establish freespin ~ 1.6bpm/1680psi. N DPRB LOWERI Wash down from 11200' @ i.6/1.6bpm, 1670/1740psi. Tag C~3 11396'. P/U & ease back in. N DPRB LOWERI Wash down from 11396' to 11600' with 1.6bpm/1820psi & 110fph. Wt check - up = 26.5k & down = 14.4k. Continue washing in hole. Tagged TOL Cam? 11656'. N DPRB LOWERI Wiper trip to 11200'. RBIH to TOL tagged @ 11656'. N DPRB LOWERI Paint EOP flag @ 11000' & POOH with cleanout BHA#19. N DPRB LOWERI LD milling BHA. Printed: 7/11 /2005 10:20:10 AM BP EXPLORATION Operations Summary Report Legal Well Name: 18-12 Common Well Name: 18-12 Event Name: REENTER+COMPLET Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task t Code ~__ , 7!2/2005 107:00 - 08:00 ~ 1.00 ~ CLEAN I N 08:00 - 09:10 1.17 CLEAN N 09:10 - 13:30 4.33 CLEAN N 13:30 - 14:00 I 0.501 CLEAN I N 14:00 - 17:00 I 3.001 CLEAN I N 18:05 - 18:30 0.25 PERFOBI N 18:30 - 18:45 0.25 PERFO N 18:45 - 19:30 0.751 PERFO N 19:30 - 19:45 0.25 PERFOB~ N 19:45 - 20:45 1.00 PERFO N 20:45 - 22:55 I 2.171 PERFOBI N 22:55 - 23:10 I 0.251 PERFOBI P 23:10 - 00:00 I 0.831 PERFOBI P 7/3/2005 100:00 - 00:50 I 0.831 PERFOBI P 00:50 - 01:15 I 0.421 PERFOBI P 01:15 - 02:50 I 1.581 PERFOBI P 02:50 - 03:20 I 0.501 PERFOBI P 03:20 - 04:30 I 1.171 PERFOB P 15 of 17 AJG 0 ~ 2J05 Spume: X1/9/1986 Start: 6/11/2005 End: 7/4/2005 Rig Release: 7/4/2005 Rig Number: 1 NPT ' Phase Description of Operations DPRB LOWERI PU nozzle. RU for running drillstring. DPRB LOWERi RIH with CSH. DPRB LOWERI RIH with nozzle. Clean out liner at 20-30 ft/min. Made it to 13850' before pressured up and stacked wt. DPRB LOWERI Pull up to liner top. RIH to 13810'. DPRB LOWERI POOH laying in 10 bbl. of pert pill. Flo-Pro with 6% Lube-Tex Pump in new 2% KCI with 1# Bio-zan, double-slick, 3% Lube-Tex on trip to surface. DPRB LOWERI Rack back 1" CSH DPRB LOWERI R/U to run pert guns. M/U safetyjt with TIW valve. Add another 5' pert gun jt (4.69' loaded partial & 1.01' of blank) to replace the btm 20.7' gun jt that was previously laved out. Perf intervals for run #1 is now 13400' - 13630' & 13700' - 13780'. DPRB LOWERI PJSM on perforation job #1. DPRB LOWERI M/U 19jts of 1.56" HSD 6spf 1606PJ guns & blanks with BCF firing system. DPRB LOWERI Held PJSM for P/U 1"CSH. DPRB LOWERI Drift MHAs, X/Os & no-go with 1/2" ball - OK. Strap & M/U lower disconnect, X/O, 29 stds of 1" CSH tbg, X/O, no-go sub & upper MHA. M/U injector. DPRB LOWERI RIH with perforating BHA#21 circ pert pill C~3 min rate. Lost SLB electronic depth tracking C~ +/-8300' due to computer lock up. Reset CTD using mechanical depth counter. Wt check ~ 11600': Up = 29.5k, Down = 16.8k. RIH into Inr ~ 50fpm. Correct CTD by -18.5' C~ the flag. RIH past 13457' (previous held up depth). LOWERI Locate no-go sub on TOL with btm BHA C«2 13822'. Pull to P/U wt (3i k) C~ 13818' & correct CTD to 13811.7' (as per CTD tally). R/U sonogram detector to choke manifold for shot detection. PUH to ball drop postion @ 13789'. LOWERI Pump 10bb1 pert pill ahead. Load 1/2" AL ball. Blow ball into CT with 5bbls pert pill behind. Chase ball C~ 1.45bpm/3300psi. Slow to 0.5bpml830psi C 28bbls. Ball on seat after 38.8bbls away. PUH very slowly & ramp up to 4800psi with btm shot @ 13780'. Observe guns fire with good pressure drop indication & sonogram detection. Perforated interval = 13400' - 13630' & 13700' - 13780'. LOW ER1 POOH with pert gun BHA C~3 45fpm pumping down the CT ~ 0.91bpm/1700psi. POOH to 11600'. Trip data indicate Obbls loss/gain while POOH to TOL. LOWERI S/D pump &flowcheck well for 20 mins -well stable. Paint EOP flag C~3 9000'. LOWERI POOH with pert gun BHA @ 50fpm pumping down the CT @ 0.9bpm/1530psi. Trip data indicate Obbls loss/gain while POOH from TOL to surface. LOWERI OOH. S/D pump &flowcheck well for 30 mins -well stable. Meanwhile held PJSM for R/B 1"CSH. LOWERI S/B injector. UD MHAs & R/B 29 stds of 1"CSH tbg. Number E & separate 15 stds for next pert run. Printed: 7/11/2005 10:20:10 AM BP EXPLORATION Operations Summary Report Legal Wetl Name: Common Well Name Event Name: Contractor Name: Rig Name: Date ~ From - To 18-12 18-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Hours Task ;Code I' NPT ~__ _ ~_ 04:30 - 04:45 0.25 PERFO P 04:45 - 05:00 0.25 PERFO P 05:00 - 06:30 1.50 PERFO P 06:30 - 08:00 1.50 PERFO P 08:00 - 09:00 1.00 PERFO P 09:00 - 11:00 2.00 PERFO P 11:00 - 12:00 I 1.001 PERFOBI P 12:00 - 13:30 I 1.501 PERFOB P 13:30 - 14:25 0.92 PERFOB~ P 14:25 - 14:40 0.25 PERFOB~ P 14:40 - 17:15 2.58 PERFO LP 17:15 - 17:30 0.25 PERFO P 17:30 - 18:30 1.00 PERFO P 18:30 - 18:45 0.25 PERFO P 18:45 - 21:00 2.25 PERFO P 21:00 - 21:15 0.25 CASE P 21:15 - 21:30 0.25 CASE P 21:30 - 21:50 0.33 CASE P 21:50 - 00:00 2.17 CASE P 7/4/2005 00:00 - 00:40 0.67 CASE P 00:40 - 01:10 0.501 CASE P 01:10 - 02:10 1.00 CASE P 02:10 - 03:00 I 0.831 CASE I P Page 16 of 17 '~~~ ~I~~k~ t~p~cGrf~r~3~fi °i~<o Start: 6/11/2005 End:~~~~~r3~~4/2005 Rig Release: 7/4/2005 Rig Number: 1 Phase Description of Operations ~_ _ __ __ LOWERI R/U to UD perf guns. LOWERI PJSM for UD perf guns. LOWERI UD 19 jts of pert guns & blanks. ASF! LOWERI PU 771.5' of pert guns and blanks. LOWERI RIH with 15 stands of 1"CSH. LOWERI MU coil onto 1"CSH. RIH with coil. At flag at 9000' EOP, correct -8.5'. LOWERI Tag liner top on depth. PU to PU wt. and correct 0'. LOWERI Pump 10 bbl. of pert pill. Drop 1/2" ball. 5 bbl. of pert pill behind. Ball on seat at 48 bbl. Possible detonation at 2000 psi. LOWERI POOH b/c unsure of detonation and wanted to avoid getting stuck. Filling on backside to prevent out of zone detonation. Pulling at 60 ft/min to prevent swapping from no-go. (2.62" OD in 2.992" ID) LOWERI Flow check: good. LOWERI POOH b/c unsure of detonation and wanted to avoid getting stuck. Filling on backside to prevent out of zone detonation. Pulling at 60 fUmin to prevent swapping from no-go. (2.62" OD in 2.992" ID) LOWERI Flow check: good. LOWERI Set back injector head. POOH racking back CSH. LOWERI PJSM for UD perf guns. LOWERI UD 36 jts of pert guns & blanks. ASF! Load out pert guns. RUNPRD R/U to run LTP. P/U tools into rig floor. RUNPRD Held PJSM for M/U &RIH LTP. RUNPRD M/U BHA #23 with Bkr seal assy, 1 jt of 10' 2-3/8" tbg pup, KB Packer, GH R/Tool, 2 jts of 2-1/16" CSH tbg & MHA. M/U injector. RUNPRD RIH with Baker 3-1/2" KB LTP BHA #23. RUNPRD Continue RIH with Baker 3-1/2" KB LTP BHA #23 to 11500'. Up wt @ 11500' = 30k, Dwn wt = 16k. RUNPRD RIH circ ~ 0.2bpm/750psi. Observe seal assy stinging into deployment sleeve Q 11647.9'. S/D pump & locate C~? 11650.3'. Set down 10k C~3 11653.3'. P/U to wt breakover 11646.7'. Repeat process 3x & confirm depths. RUNPRD P/U to ball drop position ~ 11640'. Drop/launch 5/8" phenolic ball. Chase ball C~3 0.95bpm/1300psi. Slow down to 0.25bpm/720psi @ 27bbls away. Ball on seat at 33.2bbls. Bleed off CTP. Sting back into PBR & set down 10k C~3 11653.3'. P/U 1144.7' (2' off btm). Set slips with 2200psi. S/O 10k @ 11649.9'. Bleed off CTP & stack 10k @ 11651.3' -seal locator is 2' above landing profile. RUNPRD Line up to backside & P/test LTP to 2000psi as follows: Time WHP CTP IAP OAP Onset 18 0 341 154 Printed: 7/11/2005 10:20:10 AM BP EXPLORATION ~ ~e 17 of 17 Operations Summary Report ~~~ ~- ~ ~Q05 Legal Well Name: 18-12 "v~+4~'iV 1r' i6 v,_: :.; :..+ Uvfi.:. ~^'~3~l l.~li4'SJfVr4 Common Well Name: 18-12 S'~t.~"~e: 11/9/1986 Event Name: REENTER+COMPLETE Start: 6/11/2005 End: 7!4/2005 Contractor Name: NORDIC CALISTA Rig Release: 7/4/2005 Rig Name: NORDIC 1 Rig Number: 1 Date ~ From - To ~ Hours ~, Task Code NP T Phase_ Description of Operations 7/4/2005 02:10 - 03:00 0.83 CASE P RUNPRD 0 2000 0 341 154 10 1908 0 341 154 20 1886 0 341 154 45 1880 0 341 154 _> Passed: Leaked 6% of test pressure in 45mins. 03:00 - 03:15 0.25 CASE P RUNPRD Set CT in neutral wt. Press up to 3400psi & release from KB Packer. Top of 4-1/2" KB Packer C~3 11627.66'. 03:15 - 05:00 1.75 CASE P RUNPRD POOH with LTP running tools. 05:00 - 05:50 0.83 CASE P RUNPRD OOH. S/B injector & UD LTP running tools. 05:50 - 06:00 0.17 WHSUR P POST MU Nozzle. RIH to 2500' to FP well. 06:00 - 07:30 1.50 WHSUR P POST POOH, FP well laying in 21 bbl of methanol. 07:30 - 09:00 1.50 WHSUR P POST Nipple down BOPE. Nipple up & pressure test tree cap. Empty tanks and cuttings box. Prepare for rig move. Rig released 7/04/2005 at 09:00 hrs. Moving to DS15-31 B. Printed: 7/11/2005 10:20:10 AM Halliburton Sperry-Sun North Slope Alaska BPXA 18-126 Job No. AKMW3762573, Surveyed: 27 July, 2005 Survey Report 14 July, 2005 Your Ref.• API 500292161502 Surface Coordinates: 5960712.22 N, 692168.21E (70° 17' 49.8449" N, 148° 26' 37.3999" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 47.OOft above Mean Sea Level ~~~r~~'~UI'1 CiRILLtNG 5ERVI~ES R HailSkusfon Company 9e- as ;rte CQ ~~ - '- v o A z~ K ra _ ~„~, Survey Ref: svy4635 • Halliburton Sperry-Sun Survey Report for 18-126 Your Ref.• API 500292161502 Job No. AKMW3762573, Surveyed: 27 July, 2005 North Slope Alaska Measured Depth (ft) 11856.00 11862.60 11893.84 11914.21 11952.12 11985.00 12016.44 12048.81 12082.28 12111.87 12142.63 12182.96 12213.80 12242.12 12277.46 12314.25 12344.58 12372.24 12400.14 12434.83 12465.43 12495.50 12533.35 12562.84 12576.96 12620.09 12646.88 12679.85 12705.38 12746.04 12784.20 12809.01 12825.69 12871.63 12902.02 Incl 84.600 85.020 80.150 81.560 82.680 86.920 87.450 89.740 82.820 80.630 85.690 93.780 87.620 90.610 90.260 89.560 89.480 93.600 91.550 92.720 89.740 91.760 93.080 92.720 92.810 True Azim. 114.300 112.630 104.780 99.620 90.030 83.550 77.580 69.490 61.570 50.540 40.310 26.420 17.090 9.020 354.260 343.710 330.000 320.680 311.020 300.820 295.370 290.100 283.770 278.850 274.270 Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 8692.01 8739.01 2739.08 S 6199.35 E 8692.61 8739.61 2741.70 S 6205.38 E 8696.65 8743.65 2751.63 S 6234.69 E 8699.89 8746.89 2755.88 S 6254.34 E 8705.10 8752.10 2759.03 S 6291.71 E 8708.08 8755.08 2757.19 S 6324.38 E 8709.62 8756.62 2752.04 S 6355.34 E 8710.42 8757.42 2742.88 S 6386.34 E 8712.59 8759.59 2729.07 S 6416.70 E 8716.86 8763.86 2712.76 S 6440.96 E 8720.54 8767.54 2691.35 S 6462.67 E 8720.72 8767.72 2657.77 S 6484.77 E 8720.35 8767.35 2629.18 S 6496.18 E 8720.78 8767.78 2601.62 S 6502.57 E 8720.51 8767.51 2566.39 S 6503.58 E 8720.57 8767.57 2530.33 S 6496.56 E 8720.83 8767.83 2502.51 S 6484.67 E 8720.08 8767.08 2479.79 S 6468.97 E 8718.83 8765.83 2459.82 S 6449.58 E 8717.53 8764.53 2439.51 S 6421.54 E Global Coordinates Northings Eastings (ft) (ft) 5958132.55 N 698435.57 E 5958130.09 N 698441.66 E 5958120.91 N 698471.22 E 5958117.17 N 698490.97 E 5958114.97 N 698528.41 E 5958117.64 N 698561.02 E 5958123.58 N 698591.84 E 5958133.53 N 698622.60 E 5958148.11 N 698652.60 E 5958165.05 N 698676.43 E 5958187.00 N 698697.58 E 5958221.13 N 698718.82 E 5958250.01 N 698729.50 E 5958277.72 N 698735.18 E 5958312.96 N 698735.29 E 5958348. 83 N 698727.35 E 5958376. 34 N 698714.75 E 5958398. 65 N 698698.47 E 5958418. 12 N 698678.58 E 5958437. 70 N 698650.03 E Dogleg Vertical Rate Section Comment (°/100ft) -6777.50 Tie On Point 25.987 -6784.07 Window Point 29.386 -6814.89 25.949 -6834.57 25.230 -6870.02 23.480 -6899.14 19.040 -6925.36 25.965 -6950.00 31.374 -6972.16 37.620 -6987.72 36.881 -6998.90 39.832 -7005.51 36.238 -7004.35 30.383 -6999.03 41.776 -6985.68 28.739 -6964.65 45.202 -6942.51 36.823 -6918.95 35.359 -6893.13 29.575 -6859.27 8716.87 8763.87 2425.11 S 6394.57E 5958451.41 N 698622.70E 20.294 -6828.77 8716.48 8763.48 2413.50 S 6366.85E 5958462.31 N 698594.69E 18.767 -6798.72 8714.88 8761.88 2402.49 S 6330.69E 5958472.39 N 698558.26E 17.069 -6761.21 8713.39 8760.39 2396.71 S 6301.82E 5958477.43 N 698529.25E 16.707 -6732.47 8712.70 8759.70 2395.10 S 6287.81E 5958478.68 N 698515.21E 32.405 -6719.01 90.880 265.660 8711.31 8758.31 2395.13 S 6244.75E 5958477.55 N 698472.16E 20.447 -6679.65 92.900 270.580 8710.43 8757.43 2396.01 S 6217.99E 5958475.99 N 698445.44E 19.843 -6655.55 96.680 269.880 8707.68 8754.68 2395.88 S 6185.15E 5958475.28 N 698412.60E 11.658 -6625.46 98.090 277.260 8704.39 8751.39 2394.30 S 6159.90E 5958476.21 N 698387.31E 29.193 -6601.74 94.220 285.000 8700.03 8747.03 2386.50 S 6120.27E 5958483.00 N 698347.50E 21.181 -6562.35 91.670 289.220 8698.06 8745.06 2375.29 S 6083.86E 5958493.27 N 698310.82E 12.908 -6524.52 90.180 290.450 8697.66 8744.66 2366.87 S 6060.53E 5958501.09 N 698287.27E 7.787 -6499.78 91.410 293.430 8697.43 8744.43 2360.64 S 6045.06E 5958506.92 N 698271.65E 19.326 -6483.11 90.180 297.650 8696.79 8743.79 2340.84 S 6003.62E 5958525.66 N 698229.72E 9.567 -6437.21 89.780 303.910 8696.80 8743.80 2325.29 S 5977.52E 5958540.53 N 698203.24E 20.641 -6407.05 a~ z t,, c~ rc ;~: _u+'-+,` BPXA • i b /A h ~,~. `\ J ,..~ :~ 14 July, 2005 - 16:17 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 18-12B Your Ref: API 500292161502 Job No. AKMW3762573, Surveyed: 27 July, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 12934.32 89.470 297.830 8697.02 8744.02 2308.73 S 5949.81E 5958556.38 N 698175.11E 18.848 -6375.00 12967.33 90.180 291.500 8697.12 8744.12 2294.96 S 5919.83E 5958569.38 N 698144.79E 19.296 -6342.01 12996.62 91.490 287.110 8696.69 8743.69 2285.28 S 5892.20E 5958578.35 N 698116.92E 15.639 -6312.83 13034.19 91.410 277.970 8695.74 8742.74 2277.14 S 5855.58E 5958585.56 N 698080.10E 24.321 -6276.05 13067.56 90.350 272.690 8695.22 8742.22 2274.04 S 5822.37E 5958587.80 N 698046.82E 16.136 -6244.43 13102.95 89.820 271.640 8695.17 8742.17 2272.70 S 5787.00E 5958588.24 N 698011.43E 3.323 -6211.55 13134.19 90.530 265.840 8695.08 8742.08 2273.39 S 5755.78E 5958586.75 N 697980.24E 18.704 -6183.29 13167.13 92.990 264.080 8694.07 8741.07 2276.28 S 5722.99E 5958583.02 N 697947.53E 9.181 -6154.48 13199.38 90.790 262.670 8693.00 8740.00 2280.00 S 5690.9$ E 5958578.49 N 697915.62E 8.101 -6126.72 13230.54 94.440 267.290 8691.58 8738.58 2282.72 S 5659.98E 5958574.97 N 697884.71E 18.881 -6099.49 13266.23 95.100 271.810 8688.61 8735.61 2283.00 S 5624.43E 5958573.78 N 697849.17E 12.755 -6067.09 13295.03 92.900 276.210 8686.60 8733.60 2280.99 S 5595.77E 5958575.06 N 697820.48E 17.047 -6040.08 13320.55 92.370 277.440 8685.43 8732.43 2277.96 S 5570.46E 5958577.44 N 697795.10E 5.243 -6015.72 13353.20 91.760 280.950 8684.25 8731.25 2272.75 S 5538.26E 5958581.83 N 697762.77E 10.905 -5984.16 13383.58 90.090 285.170 8683.76 8730.76 2265.89 S 5508.68E 5958587.93 N 697733.02E 14.937 -5954.33 13414.06 88.730 288.640 8684.07 8731.07 2257.03 S 5479.52E 5958596.04 N 697703.65E 12.227 -5924.09 13442.46 87.710 291.330 8684.96 8731.96 2247.33 S 5452.85E 5958605.06 N 697676.74E 10.126 -5895.77 13466.17 88.940 295.020 8685.65 8732.65 .2238.00 S 5431.06E 5958613.82 N 697654.72E 16.398 -5872.08 13495.19 90.000 298.180 8685.92 8732.92 2225.01 S 5405.12E 5958626.15 N 697628.45E 11.485 -5843.09 13527.58 90.000 303.100 8685.92 8732.92 2208.51 S 5377.26E 5958641.93 N 697600.18E 15.190 -5810.94 13559.77 90.610 307.670 8685.75 8732.75 2189.87 S 5351.02E 5958659.89 N 697573.48E 14.323 -5779.40 13592.59 92.370 312.950 8684.89 8731.89 2168.66 S 5326.01E 5958680.46 N 697547.93E 16.952 -5747.94 13638.40 92.200 312.950 8683.07 8730.07 2137.47 S 5292.51E 5958710.78 N 697513.64E 0.371 -5704.68 ~; 13668.00 92.470 317.040 8681.86 8728.86 2116.56 S 5271.60E 5958731.15 N 697492.21E 13.836 -5677.09 ,~ 13697.33 91.050 320.510 8680.96 8727.96 2094.51 S 5252.28E 5958752.69 N 697472.33E 12.778 -5650.50 ~ ~ ~y C ~~! 13730.09 89.470 325.250 8680.81 8727.81 2068.40 S 5232.52E 5958778.29 N 697451.91E 15.251 -5621.85 ~ ~ r 13763.18 89.740 328.940 8681.04 8728.04 2040.63 S 5214.55E 5958805.60 N 697433.23E 11.181 -5594.16 -- ~' ~' 13794.12 90.180 332.810 8681.06 8728.06 2013.60 S 5199.49E 5958832.23 N 697417.49E 12.589 -5569.45 G ' ~`~ 13825.94 88.680 337.730 8681.38 8728.38 1984.71 S 5186.18.E 5958860.77 N 697403.45E 16.163 -5545.58 ~ °' 13855.78 88.420 340.720 8682.13 8729.13 1956.82 S 5175.60E 5958888.38 N 697392.16E 10.055 -5524.61 ® ; . y - :_r+ ~ 13888.73 88.070 345.290 8683.14 8730.14 1925.34 S 5165.98E 5958919.61 N 697381.73E 13.904 -5503.05 13914.00 88.070 345.290 8683.99 8730.99 1900.91 S 5159.57E 5958943.86 N 697374.70E 0.000 -5487.29 Projecte~C Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. "` Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are rel ative to NAD27 Alaska State Planes, Zone 4. 14 July, 2005 - 16:17 Page 3 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 18-126 Your Ref.• APl 500292161502 Job No. AKMW3782573, Surveyed: 27 July, 2005 North Slope Alaska The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 293.900° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13914.OOft., The Bottom Hole Displacement is 5498.60ft., in the Direction of 110.225° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11856.00 8739.01 2739.08 S 6199.35E Tie On Point 11862.60 8739.61 2741.70 S 6205.38E Window Point 13914.00 8730.99 1900.91 S 5159.57E Projected Survey BPXA Survey tool program for 18-12B From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 13914.00 8730.99 Survey Tool Description MWD Magnetic (18-12) ~_, ,~ ~ O ~ 9y~ ~ °~ LJ • 14 July, 2005 - 16:17 Page 4 of 4 DrillQuest 3.03.06.008 TREE = 3-1 /8" FMC WELLHEAD= FMC AC_TUATOR = AXELSON _ KB. ELEV = 47' BF. ELEV = 23.8' KOP = 11862.6' Max Angle =_ Datum MD = 98°_@ 12.705' WA Datum TV D = 8800' SS 13-3l8" CSG, 72#, L-80, ID = 12.347" ~-~ 2830' Minimum ID =1.92" @ 11651' 2-3/8" STL LNR 9-5/8" X 7" TM/ LNR HGRI 9631' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9935' BOT DEPLOY SLEEV E, 6' LONG, 2.25" ID 11644' TOP OF 2-3/8" LINER CEMENT +/-11644' 3-1/2" TBG-PC, 9.3#, N-80, .0087 bpf, ID = 2.992" 11718' TOP OF 4-112" SLOTTED LNR, 13.5#, ID = 3.92" I-1 11780' f 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11830' rMECHANICAL WHIPSTOCK 11862' WINDOW --r 11864' - 11871' RA PIP TAG 11870' TOP OF 2-3/8" LNR, 4.6#, L-80, ID = 1.941" 11984' 11 PERFORATION SUMMARY REF LOG: MWD/NGP GR/ROP OF 6/2812005 TIE-IN LOG: GEOLOGY PDC LOG ANGLE AT TOP PERF: 92.7° @ 12560' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 12560' - 13120' Opn 07/03/05 1.56" 6 13190' - 13290' Opn 07/03/05 1.56" 6 13400' - 13630' Opn 07/03/05 1.56" 6 13700' - 13780' Opn 07/03/05 4-1/2" LNR, 13.5#, N-80, .0152 bpf, ~ = 3.920" ~--~ 12191' 18-12B CTD Sidetrack I I SAFl~TES: FHUTIW HBBP PACKERS HAVE REDUCED TEST PRESSURE LIMITS IN SOME CASES. CONTACTWIE(x5102)PRIORTO PRESSURE TESTING. WELL ANGLE>70°@ 10097' 8 > 90° @ 12048'. 2268' ~--~ 3-1 /2" CA MCO TRDP-1 A TRSV , ID = 2.812" (:A R I IFT MA NfIRFI R ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3790 3503 34 CA-MMG-2 SO RK 20 11/24/97 3-1/2" OTIS X NIP, ID = 2.813" 11628' -j TOP OF 'KB' LNR TOP PACKER + 10' 2-318" P/JT 11644' TOP OF 2-3/8" LINER 11718' TM/ OV ERSHOT ASSY, ID = 4.75" 11720' TNV POLISHED RISER W/ 2.813" X- PROFILE 11730' BTM OF TNV OVERSHOT ASSY 11732' 7" X 4-1/2" TM/ SS PKR, ID = 3.00" 12382' -j MARKER 10' PUP JOINT 13878' 2-3/8" LINER CMTED & PERFED ~~ 13914' 11983' -I 2.70" BKR DEPLOYMENT SLV, ID = 1.995" 4-1/2" LNR SIDETRACK WINDOW 11991' - 11999" (OFF CMT RAMP) 12013' TOP OF 2-3/8" SLID LNR, ID = 1.941" ~`~ ~`~ AUG 0 8 2005 `~ `~ Al~:ka Oil ~ Gas Cons. ~~R1r;~itrsi0=i ~ ~ ~i~~.iiv'i 3~t~i ~ ~ 14015' BTM OF 2-3/8" SLID LNR ~ ~ ~ ~ 2-3/8" BKR PACKOFF BUSHING. ID = 1.00" 14015' `~ ~ 2-3/8" LNR, 4.6#, L-80, FL4S, .0039 bpf, ID = 1.941" 1404$' \ DATE REV BY COMMENTS DATE REV BY COMMENTS 12/23/86 ORIGINAL COMPLETION 11/08/97 CTD SIDETRACK 10/20/01 CH/KAK CORRECTIONS 09/13/03 CMO/TLP DATUM MD CORRECTION `"~` "~~' JUF NORDIC-1 CTD SIDETRACK PRUDHOE BAY UN(r WELL: 18-12B PERMfr No: 205-073 API No: 50-029-21615-02 SEC 19, T11 N, R15E, 1166' FNL 8 402' FWL BP F~cploration (Alaska) • • 15-Jul-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 18-12B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and "`.PDF files. Tie-on Survey: 11,856.00' MD Window /Kickoff Survey: 11,862.60' MD (if applicable) Projected Survey: 13,914.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 r ~', Date ~~s Si ned ~' ~ ~./~'~ -7-v-~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ ~ ~ ~ ~ ~ 4 ~ ~ -:; ~ ~ ~ FRANK H. MURKOWSKI, GOVERNOR m., ~' ~ ~ ~1W ~ t][0~7 ~' 333 W. 7TM AVENUE, SUITE i00 ~T -~ttr 1~T COl`S~~~~ii0" COr~IIssi~1` ? ' ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 18-12B BP Exploration (Alaska) Inc. Permit No: 205-073 Surface Location: 1166' FNL, 403' FWL, SEC. 19, T11N, R15E, UM Bottomhole Location: 3118' FNL, 378' FWL, SEC. 20, T11N, R15E, UM Dear Mr. McLaughlin: 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 it ess any required test. Contact the Commission's petroleum field inspector at ~3~~},6,59-3 7 ger). DATED this3~ day of May, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASk OiL AND GAS CONSERVATION C~Iv1MISSlO I~/~ED PERMfT TO DRILL ~y~~ ~ ~ ~~~~ 20 AAC 25.005 f ia. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class g p ^ Exploratory ~D _ l ~~tTa ~ (~j,q~It~p~A;~On ^ Strati ra hic Test ^ Service tie-v~e7o ment a "Q`SIn°~fb i`i 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Na tuber: PBU 18-12B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13925 TVD 8691 12. Field /Pool(s): Prudhoe Bay Field !Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1166' SNL 403' EWL SEC 19 T11N R15E UM 7. Property Designation: ADL 028321 Pool , , , . , , Top of Productive Horizon: 3158' SNL, 4880' EWL, SEC. 19, T11 N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: i June 4, 2005 Total Depth: 3118' SNL, 378' EWL, SEC. 20, T11N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 28,000` 4b. Location of Well (State Base Plane Coordinates): Surface: x- 692168 - 5960712 Zone- ASP4 10. KB Elevation (Height above GL): 47' feet 15. Distance to Nearest well Within Pool 500' 16. Deviated Wells: Kickoff Depth: 11860 feet Maximum Hole Angle: 91 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3300 Surface: 2420 ~ 18. ng rogram: Size Specifications Setting Depth To Bottom uanbty o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 2265' 11660' 8676' 13925' 8691' 53 sx Class 'G' 19. PRESENT WELL CONDITION SUMM ARY (To be completed for Redrill-AND Re-entry Operations) Total Depth MD (ft): 14046 Total Depth TVD (ft): 8798 Plugs (measured): None Effective Depth MD (ft): 14046 Effective Depth TVD (ft): 8798 Junk (measured): None Casin Len th Size Cement Volume MD TVD r r on r 110' 20" 1610# Poleset 110' 110' 2830' 13-3/8" 2500 sx Coldset lll, 400 sx CS II 2830' 2697' 9935' 9-5/8" 500 sx Class 'G', 300 sx CSI 9935' 8303' ro 'r n 2199' 7" 50 sx Class 'G' 9631' - 11830' 8153' - 8737' Liner 290' 4-1/2" Uncemented Slotted Liner 11707' - 11991' 8727' - 8753' Liner 2063' 2-3/8" Uncemented Slotted Liner 11983' - 14046' 8752' - 8798' Perforation Depth MD (ft}: 11780' - 14015' Perforation Depth TVD (ft): 8732' - 8797' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaugh4in, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Prepared By NamelNumber: Si nature ~Lr~ Phone 564-4387 Date S OS Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: z.o S-~ ~ API Number: 50- 029-21615-02-00 Permit Approval Date: 5~3, a ~" See cover letter for other requirements Conditions of Approval: Sample Required rr Hydr gen Sulfide Measures Other: ~ ~' ~, t ~ ~ f ~$ S O (~ ~=' ~.," A roved [J'~ Yes ', No Mud Log Required ^ Yes ~ No Yes ~; No Directional Survey Required es ~ No APPROVED BY THE COMMISSION Date ~~~ Form 10-401 Rid ~2~ S~bmit bh Duplicate BP 1$-12B Sidetrack CTD Sidetrack Summary 1) Run mechanical WS 2) Plugback 18-12A 3) Mill window off whipstock 4) Drill sidetrack 5) Run liner, cement and perforate Mud Program: • Well kill: 8.4 - 8.9 ppg ~ne • Milling/drilling: 8.5 - ppg used Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • 2 3/8" solid cemented liner completion 116 13925'. • The liner cement volume is planned to be 1 bbls of 15.8 ppg class G. ~ Casing/Liner Information ] 3-318", L-80, 72#, Burst 5380, collapse 2670 psi 9-5/8", L-80, 47#, Burst 6870, collapse 4750 psi 7", L-80, 29#, Burst 8160, collapse 7020 psi 4-1/2", L-80, 13.5#, Burst 9022, collapse 8537 psi Planned Liner 2 3/8" L-80 STL 4.6#, Burst 11200 psi; collapse 11780 psi (hole size 3.0") ~ 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. Max. planned hole angle is 91 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line: 28000 ft • Distance to nearest well within pool: 500 ft Logging • MWD directional and Gamma Ray will be run over all of the openhole section. Hazards • DS 18 is not designated as an HZS site. ~ • There are no planned fault crossings. • Lost circulation risk is considered low. Reservoir Pressure • Res. press. is estimated to be 3300 psi at 8800'ss (7.2 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2420 psi. r TREE= 3-1/8" FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV - 47~ BF. ELEV...- _ _ 23.8'. KOP = 1200' Max Angle = 94 @ 13405' Datum MD = WA Datum TVD = 8800' SS ~ 18-12A I 13-3/8" CSG, 72#, L-80, {D = 12.347" I--~ 2830' Minimum ID = 1.941" @ 11984' TOP OF 2-3/8" 4.6# LNR 9-5/8" X 7" TN1l LNR HGR 9631' ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 3-1 /2" TBG-PC, 9.3#, N-80, .0087 bpf, ID = 2.992" ~--i 11718' OF 4-1/2" SLOTTED LNR, 13.5#, ID = 3.92" 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11780' ~ ~ I I 11830' 1 ~ PERFORATION SUMMARY REF LOG: ARRAY SONIC on 12/01/86 ANGLE AT TOP PERF: 85 @ 11780' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/Z" SLTD 11780 - 11996 O 12/23/86 2-1/2" 6 11830 - 11983 O 11!13/99 2 3/8" SLTD 12013 - 14015 O 11/08/97 NOTES: FHUTIW HBBP PACKERS HAVE REDUCED TEST PRESSURE LIMITS IN SOME CASES. CONTACT W IE (x5102) PRIOR TO PRESSURE TESTING. WELL ANGLE>70°@ 1009T & > 90° @ 12048'. 2268' i-( 3-1/2" CAMCO TRDP-1A TRSV, ID= 2.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3790 3503 34 CA-MMG-2 SO RK 20 11/24/97 9399' 3-1l2" OTIS X NIP, ID = 2.813" 11718' -{ TM/ OV ERSHOT ASSY, ID = 4.75" 11720' TM/ POLISHED RISER W/ 2.813" X- PROFILE 11730' BTMOFTNVOVERSHOTASSY 11732' 7" X 4-1/2" TNV SS PKR, ID = 3.00" ~ `• ~ ~ ~~ C ~ \~ ' ~ ~ f 2-3/8" BKR PACKOFF BUSHING, ID = 1.00" ~-j 14015' ~ 2-3/8" LNR, 4.6#, L-80, FL4S, .0039 bpf, ID= 1.941" 14045' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/23/86 ORIGINAL COMPLETION 11/08/97 CTD SIDETRACK 10/20/01 CWKAK CORRECTIONS 09/13/03 CMO/TLP DATUM MD CORRECTION BTM OF 2-3/8" SLID LNR II PRUDHOE BAY UNIT WELL: 18-12A PERMfr No: 1971230 API No: 50-029-21615-01 SEC 19, T11 N, R15E, 1166' FNL & 402' FWL BP Exploration (Alaska) 'TREE _ 3-1 /8" FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 47' BF. ELEV = 23.8' KOP = 1200' Max Angle = 94 @ 13405' Datum MD = N/A Datum TV D = 8800' SS ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" I 1 V ~ ~ ~ ~ ~ NOTES: FHUTIW HBBP PACKERS HAVE REDUCED TEST PRESSURE LIMITS IN SOME Proposed CTD Sidetrack CASES. CONTACT WIE (x5102) PRIOR TO PRESSURE TESTINCs WELL ANGLE> 70° @ 10097' & > 90° @ 12048'. Minimum ID = 1.941" @ 11984' TOP OF 2~/8" 4.6# LNR 9-5/8" X 7" TMI LNR HGR 9631' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9935' 3-1/2" TBG-PC, 9.3#, N-80, .0087 bpf, ID = 2.992" 11718' I TOP OF 4-1 /2" SLOTTED LNR, 13.5#, ID = 3.92" I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 11780' I TOP OF 2-3/8" LNR, 4.6#, L-80, ID = 1.941" ~ 11984' IBP 11990' PERFORATION SUMMARY REF LOG: ARRAY SONIC on 12/01/86 ANGLE AT TOP PERF: 85 @ 11780' Ncte: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" SLTD 11780 - 11996 isolated proposed 2-1/2" 6 11830 - 11983 isolated proposed 2 3/8" SLTD 12013 - 14015 isolated proposed ~ 4-1/2" LNR, 13.5#, N-80, .0152 bpf, ID = 3.920" I 226$' 3-1/2" CAMCO TRDP-1A TRSV, ID = 2.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3790 3503 34 CA-MMG-2 SO RK 20 11/24/97 3-1/2" OTIS X NIP,ID = 2.813" 11660' Top of 2-3/8" Liner 11660' Top of Cement 11718' TNV OVERSHOTASSY, ID = 4.75" 11720' TM/ POLISHED RISER W/ 2.813" X- PROFILE 11730' BTM OF TM/ OV ERSHOT ASSY 11732' 7" X 4-1/2" TNV SS PKR, ID = 3.00" 2-3/8" cmt'ed and perfed ~-~ 13925' ~ ~ Mechanical Whipstock 11860' 11983' 2.70" BKR DEPLOYMENT SLV, ID = 1.995" 4-1/2" LNR SIDETRACK WINDOW 11991' - 11999" (OFF CMT RAMP) ` 12013' TOP OF 2-3l8" SLID LNR, ID = 1.941" ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~\ 14015' ~ ~ ~ ~ 2-3/8" BKR PACKOFF BUSHING, ID = 1.00" 14015' ~ ~ 2-3/8" LNR, 4.6#, L-80, FL4S, .0039 bpf, ID = 1.941" -x14045' ~ i DATE REV BY COMMENTS DATE REV BY COMMENTS 12/23/86 ORIGINAL COMPLETION 11/08/97 CTD SIDETRACK 10/20/01 CWKAK CORRECTIONS 09/13/03 CMO/TLP DATUM MD CORRECTION BTM OF 2-3/8" SLID LNR ~ PRUDHOE BAY UNfr WELL: 18-12A PERMfT No: 1971230 API No: 50-029-21615-01 SEC 19, T11 N, R15E, 1166' FNL 8 402' FWL BP 6cploration (Alaska) ~p ~ Baker Hughes INTEQ~ Baker Hu hes INTE Plannin Re ort g Q g P 1!L'N'TE+[~ Company: BP Amoco Field: Prudhoe Bay Site: PB DS 18 Well: 18-12 WeHpath: Plan #6, 18-126 Date: 5/2/2005 Time: 11:58:54 Page: 1 Co-ordinate(NE) Reference: Well: 18-12, True North Vertical (TVD) Reference: 23:12 11/9/1986 00:00 47.0 Section {VS) Reference: Well (O.OON,O.OOE,293.90Azij Survev Calculation Method: Minimum Curvature Db: Orade Field: Prudhoe Bay - -_ - North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagneric Model: bggm2004 Site: PB DS 18 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5959213.15 ft Latitude: 70 17 35.252 N From: Map Easting: 691583.44 ft Longitude: 148 26 55.555 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.46 deg Well: 18-12 Slot Name: 12 18-12 Well Position: +N/-S 1484.17 ft Northing: 5960712.60 ft Latitude: 70 17 49.849 N +E/-W 621.88 ft Easting : 692167.25 ft Longitude: 148 26 37.428 W Position Uncertainty: 0.00 ft Wellpath: Plan #6, 18-12B Drilled From: 18-12A 500292161502 Tie-on Depth: 11732.00 ft Current Datum: 23:12 11/9/1986 00:00 Height 47.00 ft Above System Datum: Mean Sea Level Magnetic Data: 5(212005 Declination: 24.90 deg Field Strength: 57649 nT Mag Dip Angle: 80.88 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 31.00 0.00 0.00 293.90 Plan: Plan #6 Date Composed: 5/2/2005 copy Lamar's plan#6 Version: 8 Principal: Yes Tied-to: From: Definitive Path Targets Name 18-126 Polygon -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 18-126 Target 2 18-12B Target 1 Description TVD Dip. Dir. ft 47.00 47.00 47.00 47.00 47.00 8737.00 8767.00 Map Map +N/-S +E!-W Northing Eastlng ft ft ft ft -2415.79 6541.50 5958465.00 698768.00 -2415.79 6541.50 5958465.00 698768.00 -1242.05 4144.59 5959577.00 696342.00 -1864.44 4228.71 5958957.00 696442.00 -2912.77 6337.71 5957963.00 698577.00 -1950.63 4938.78 5958889.00 697154.00 -2482.04 6393.75 5958395.00 698622.00 <_~ Latitude --> <-- Longitude ---> Deg Min Sec Deg Min Sec 70 17 26.062 N 148 23 26.811 W 70 17 26.062 N 148 23 26.811 W 70 17 37.622 N 148 24 36.637 W 70 17 31.501 N 148 24 34.196 W 70 17 21.176 N 148 23 32.761 W 70 17 30.649 N 148 24 13.505 W 70 17 25.412 N 148 23 31.118 W Annotation MD TVD __ _ __ - I ft ft 11856.00 8739.01 -_ __ TIP 11860.00 8739.39 KOP 11880.00 8741.01 End 9°/100' DLS 11980.00 8748.90 4 12110.00 8758.85 5 12343.42 8767.31 6 12743.42 8761.99 7 12893.42 8758.14 8 13443.42 8745.54 9 13925.00 8737.41 TD ` ~ ~ Baker Hughes INTEQ~ Baker Hughes INTEQ Planning Report t~iTEC~ Company: B P Amoco Date: 5!2/2005 Time: 11:58:54 Page: 2 j Field: P rudhoe Bay Co-ordinate(NE) Reference: Well: 18-12, True Nort h Site: P B DS 18 Vertical (TVD) Reference: 2 3:12 11 /9/1986 00:00 47.0 Well: 18-12 Section (VS) Reference: Well (O.OON,O.OOE,293 .90Azi) Wellpath: P lan #6, 18-126_ ___ Survey Calculation Method: Minimum Curvature _ Db: Oracle J Plan Section - Information - - -- - -- r MD lncl Azim TVD +N/-5 --- +E/-W -- - - DLS Build Turn ------ TFO Target ft deg _ deg ft _ ft ft deg(100ft deg/100ft deg/100ft deg 11732.00 85.60 114.30 8728.42 -2688.26 6086.74 0.00 0 .00 0.00 0 .00 11856.00 84.60 114.30 8739.01 -2739.10 6199.34 0.81 -0 .81 0.00 180 .00 11860.00 84.57 114.28 8739.39 -2740.74 6202.97 0.90 -0 .75 -0.50 213 .57 11880.00 86.13 113.38 8741.01 -2748.80 6221.20 9.00 7 .80 -4.51 330 .00 . 11980.00 85.11 78.29 8748.90 -2758.79 6318.83 35.00 -1 .02 -35.09 267 .00 12110.00 86.57 32.68 8758.85 -2687.23 6422.80 35.00 1 .13 -35.08 270 .00 12343.42 90.00 311.00 8767.31 -2475.44 6392.27 35.00 1 .47 -34.99 270 .50 12743.42 91.48 279.03 8761.99 -2308.49 6034.53 8.00 0 .37 -7.99 272 .80 12893.42 91.45 267.03 8758.14 -2300.58 5885.06 8.00 -0 .02 -8.00 270 .00 13443.42 91.04 311.04 8745.54 -2125.64 5377.95 8.00 -0 .07 8.00 90 .00 13925.00 90.82 272.50 8737.41 -1950.40 4939.16 8.00 -0 .05 -8.00 270 .00 Survey MD Inc! Azim SS TVD N/S E/VV MapN MapE DLS VS TFO ` Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 11732.00 85.60 114.30 8681.42 -2688.26 6086.74 5958181.01 698320.38 0.00 -6653.95 0.00 M W D 11750.00 85.45 114.30 8682.82 -2695.65 6103.09 5958174.04 698336.92 0.81 -6671.90 180.00 MWD 11775.00 85.25 114.30 8684.85 -2705.90 6125.80 5958164.37 698359.88 0.81 -6696.81 180.00 MWD 11800.00 85.05 114.30 8686.96 -2716.15 6148.51 5958154.71 698382.84 0.81 -6721.72 180.00 MWD 11825.00 84.85 114.30 8689.16 -2726.40 6171.20 5958145.04 698405.79 0.81 -6746.63 180.00 M W D 11850.00 84.65 114.30 8691.45 -2736.65 6193.89 5958135.38 698428.73 0.81 -6771.52 180.00 MWD 11856.00 84.60 114.30 8692.01 -2739.10 6199.34 5958133.06 698434.24 0.81 -6777.50 180.00 MWD 11860.00 84.57 114.28 8692.39 -2740.74 6202.97 5958131.52 698437.91 0.90 -6781.48 213.57 MWD 11875.00 85.74 113.60 8693.66 -2746.81 6216.63 5958125.81 698451.72 9.00 -6796.42 330.00 M W D 11880.00 86.13 113.38 8694.01 -2748.80 6221.20 5958123.94 698456.34 9.00 -6801.41 330.06 M W D 11900.00 85.79 106.37 8695.42 -2755.57 6239.95 5958117.64 698475.26 35.00 -6821.30 267.00 M W D 11925.00 85.46 97.60 8697.33 -2760.74 6264.31 5958113.09 698499.74 35.00 -6845.67 267.49 MWD 11950.00 85.23 88.82 8699.36 -2762.14 6289.17 5958112.33 698524.62 35.00 -6868.95 268.16 M W D 11975.00 85.12 80.04 8701.47 -2759.73 6313.94 5958115.38 698549.32 35.00 -6890.62 268.88 MWD 11980.00 85.11 78.29 8701.90 -2758.79 6318.83 5958116.44 698554.19 35.00 -6894.71 269.62 M W D 12000.00 85.15 71.26 8703.60 -2753.56 6338.04 5958122.16 698573.26 35.00 -6910.16 270.00 M W D 12025.00 85.29 62.48 8705.68 -2743.78 6360.93 5958132.52 698595.89 35.00 -6927.13 270.60 MWD 12050.00 85.55 53.71 8707.68 -2730.62 6382.07 5958146.21 698616.68 35.00 -6941.12 271.33 M W D 12075.00 85.91 44.94 8709.55 -2714.39 6400.96 5958162.92 698635.15 35.00 -6951.81 272.03 MWD 12100.00 86.37 36.18 8711.23 -2695.46 6417.16 5958182.26 698650.86 35.00 -6958.96 272.69 M W D 12110.00 86.57 32.68 8711.85 -2687.23 6422.80 5958190.63 698656.29 35.00 -6960.78 273.28 M W D 12125.00 86.63 27.42 8712.74 -2674.27 6430.30 5958203.78 698663.45 35.00 -6962.38 270.50 MWD 12150.00 86.80 18.66 8714.17 -2651.33 6440.06 5958226.96 698672.62 35.00 -6962.01 270.81 MWD 12175.00 87.03 9.90 8715.52 -2627.16 6446.21 5958251.28 698678.15 35.00 -6957.84 271.32 MWD 12200.00 87.34 1.15 8716.75 -2602.33 6448.61 5958276.16 698679.92 35.00 -6949.98 271.79 MWD 12225.00 87.71 352.40 8717.83 -2577.42 6447.20 5958301.03 698677.87 35.00 -6938.60 272.22 MWD 12250.00 88.13 343.65 8718.74 -2553.00 6442.02 5958325.30 698672.07 35.00 -6923.97 272.60 M W D 12275.00 88.60 334.91 8719.46 -2529.65 6433.19 5958348.42 698662.65 35.00 -6906.44 272.91 M W D 12300.00 89.09 326.17 8719.96 -2507.91 6420.91 5958369.84 698649.81 35.00 -6886.40 273.16 MWD 12325.00 89.61 317.44 8720.24 -2488.28 6405.47 5958389.06 698633.87 35.00 -6864.33 273.34 M W D 12343.42 90.00 311.00 8720.31 -2475.44 6392.27 5958401.56 698620.36 35.00 -6847.06 273.44 MWD 12350.00 90.03 310.47 8720.30 -2471.15 6387.29 5958405.72 698615.26 8.00 -6840.77 272.80 MWD 12375.00 90.12 308.48 8720.27 -2455.26 6367.99 5958421.12 698595.57 8.00 -6816.69 272.80 MWD 12400.00 90.22 306.48 8720.20 -2440.05 6348.15 5958435.81 698575.35 8.00 -6792.39 272.80 MWD 12425.00 90.32 304.48 8720.08 -2425.54 6327.79 5958449.80 698554.63 8.00 -6767.90 272.79 M W D 12450.00 90.41 302.48 8719.92 -2411.74 6306.94 5958463.05 698533.43 8.00 -6743.25 272.78 MWD 12475.00 90.51 300.49 8719.72 -2398.69 6285.63 5958475.55 698511.79 8.00 -6718.47 272.77 M W D 12500.00 90.61 298.49 8719.47 -2386.38 6263.87 5958487.30 698489.72 8.00 -6693.59 272.75 MWD 12525.00 90.70 296.49 8719.19 -2374.85 6241.69 5958498.26 698467.26 8.00 -6668.64 272.73 MWD 12550.00 90.80 294.49 8718.86 -2364.09 6219.13 5958508.44 698444.43 8.00 -6643.65 272.71 M W D ' ~, ' ~ Baker Hughes INTEQ~ Baker Hu hes INTE Planain Re ort g Q g P ><;~rEC~ Company: BP Amoco Date: 5!2!2005 Time: 11:58:54 Page: 3 Field: Prudhoe Bay Co-ordioate(NE) Reference: Well: 18-12, True North Site: PB DS 18 Vertical {TVD) Reference: 23:12 11/9/1986 00:00 47.0 ~, Well: 18-12 Section (VS) Reference: Well (O.OON,O.OOE,293.90Azi) Wellpath: Plan #6, 18-126 Snrvey Calculation Method: Minimum Curvature Db: Oracle Survey ---- ---- -- -- - -- - r MD Inch Azim SS TVD N/S E/W MapN MapE DL5 VS TFO Tool ~i ft deg deg ft ft ft ft ft deg/100ft ft deg 12575.00 90.89 292.49 8718.49 -2354.12 6196.20 5958517.82 698421.26 8.00 -6618.66 272.68 MWD 12600.00 90.98 290.50 8718.09 -2344.97 6172.95 5958526.38 696397.78 8.00 -6593.68 272.66 MWD 12625.00 91.07 288.50 8717.64 -2336.62 6149.39 5958534.11 698374.02 8.00 -6568.76 272.62 MWD 12650.00 91.16 286.50 8717.15 -2329.11 6125.55 5958541.02 698349.99 8.00 -6543.93 272.59 MWD 12675.00 91.25 284.50 8716.62 -2322.43 6101.46 5958547.08 698325.75 8.00 -6519.20 272.55 MWD 12700.00 91.34 282.50 8716.06 -2316.59 6077.16 5958552.29 698301.31 8.00 -6494.62 272.51 MWD 12725.00 91.42 280.50 8715.46 -2311.61 6052.67 5958556.64 698276.70 8.00 -6470.21 272.46 MWD 12743.42 91.48 279.03 8714.99 -2308.49 6034.53 5958559.30 698258.48 8.00 -6452.35 272.41 MWD 12750.00 91.48 278.50 8714.82 -2307.48 6028.03 5958560.14 698251.96 8.00 -6446.00 270.00 MWD 12775.00 91.48 276.50 8714.17 -2304.22 6003.25 5958562.77 698227.11 8.00 -6422.03 269.99 M W D 12800.00 91.48 274.50 8713.53 -2301.82 5978.37 5958564.53 698202.18 8.00 -6398.32 269.93 M W D 12825.00 91.47 272.50 8712.88 -2300.30 5953.43 5958565.42 698177.21 8.00 -6374.89 269.88 M W D 12850.00 91.47 270.50 8712.24 -2299.64 5928.45 5958565.43 698152.22 8.00 -6351.79 269.83 MWD 12875.00 91.46 268.50 8711.60 -2299.86 5903.46 5958564.58 698127.24 8.00 -6329.03 269.78 MWD 12893.42 91.45 267.03 8711.14 -2300.58 5885.06 5958563.39 698108.87 8.00 -6312.50 269.73 M W D 12900.00 91.45 267.55 8710.97 -2300.89 5878.49 5958562.91 698102.31 8.00 -6306.62 90.00 M W D 12925.00 91.45 269.55 8710.34 -2301.52 5853.51 5958561.64 698077.35 8.00 -6284.03 90.01 M W D 12950.00 91.45 271.55 8709.70 -2301.28 5828.52 5958561.24 698052.37 8.00 -6261.09 90.06 M W D 12975.00 91.44 273.56 8709.07 -2300.16 5803.55 5958561.72 698027.38 8.00 -6237.81 90.11 MWD 13000.00 91.43 275.56 8708.45 -2298.18 5778.64 5958563.06 698002.43 8.00 -6214.23 90.16 M W D 13025.00 91.43 277.56 8707.82 -2295.32 5753.81 5958565.28 697977.54 8.00 -6190.38 90.22 M W D 13050.00 91.42 279.56 8707.20 -2291.61 5729.10 5958568.37 697952.74 8.00 -6166.28 90.27 MWD 13075.00 91.40 281.56 8706.59 -2287.03 5704.53 5958572.32 697928.06 8.00 -6141.96 90.31 MWD 13100.00 91.39 283.56 8705.98 -2281.59 5680.14 5958577.12 697903.54 8.00 -6117.46 90.36 MWD 13125.00 91.38 285.56 8705.37 -2275.31 5655.95 5958582.78 697879.20 8.00 -6092.80 90.41 M W D 13150.00 91.36 287.56 8704.78 -2268.19 5631.99 5958589.29 697855.07 8.00 -6068.01 90.46 M W D 13175.00 91.34 289.56 8704.19 -2260.23 5608.30 5958596.64 697831.18 8.00 -6043.13 90.51 M W D 13200.00 91.32 291.56 8703.61 -2251.46 5584.90 5958604.81 697807.57 8.00 -6018.18 90.56 M W D 13225.00 91.30 293.56 8703.04 -2241.87 5561.82 5958613.81 697784.25 8.00 -5993.19 90.60 M W D 13250.00 91.27 295.56 8702.48 -2231.48 5539.09 5958623.61 697761.27 8.00 -5968.20 90.65 M W D 13275.00 91.25 297.56 8701.92 -2220.31 5516.73 5958634.21 697738.63 8.00 -5943.23 90.69 M W D 13300.00 91.22 299.56 8701.38 -2208.36 5494.78 5958645.59 697716.38 8.00 -5918.32 90.74 M W D 13325.00 91.20 301.56 8700.86 -2195.65 5473.26 5958657.75 697694.55 8.00 -5893.50 90.78 M W D 13350.00 91.17 303.56 8700.34 -2182.20 5452.20 5958670.65 697673.15 8.00 -5868.79 90.82 MWD 13375.00 91.14 305.56 8699.84 -2168.02 5431.61 5958684.30 697652.21 8.00 -5844.23 90.86 M W D 13400.00 91.10 307.56 8699.35 -2153.13 5411.54 5958698.67 697631.76 8.00 -5819.84 90.90 MWD 13425.00 91.07 309.56 8698.88 -2137.55 5392.00 5958713.75 697611.83 8.00 -5795.66 90.94 MWD 13443.42 91.04 311.04 8698.54 -2125.64 5377.95 5958725.29 697597.48 8.00 -5778.00 90.98 M W D 13450.00 91.04 310.51 8698.42 -2121.34 5372.97 5958729.46 697592.39 8.00 -5771.70 270.00 M W D 13475.00 91.04 308.51 8697.96 -2105.44 5353.68 5958744.86 697572.71 8.00 -5747.63 269.99 MWD 13500.00 91.04 306.51 8697.51 -2090.22 5333.86 5958759.57 697552.50 8.00 -5723.33 269.95 MWD 13525.00 91.04 304.51 8697.06 -2075.70 5313.51 5958773.56 697531.79 8.00 -5698.85 269.92 M W D 13550.00 91.03 302.51 8696.60 -2061.90 5292.67 5958786.82 697510.60 8.00 -5674.21 269.88 M W D 13575.00 91.03 300.51 8696.15 -2048.84 5271.36 5958799.33 697488.97 8.00 -5649.43 269.85 M W D 13600.00 91.02 298.51 8695.71 -2036.53 5249.61 5958811.08 697466.91 8.00 -5624.56 269.81 MWD 13625.00 91.01 296.51 8695.27 -2024.99 5227.44 5958822.06 697444.45 8.00 -5599.61 269.77 M W D 13650.00 91.00 294.51 8694.83 -2014.22 5204.58 5958832.24 697421.63 8.00 -5574.63 269.74 M W D 13675.00 90.99 292.51 8694.39 -2004.25 5181.96 5958841.62 697398.46 8.00 -5549.63 269.70 MWD 13700.00 90.98 290.51 8693.96 -1995.09 5158.70 5958850.18 697374.98 8.00 -5524.66 269.67 MWD 13725.00 90.96 288.51 8693.54 -1986.74 5135.14 5958857.93 697351.22 8.00 -5499.74 269.63 MWD 13750.00 90.95 286.51 8693.12 -1979.22 5111.31 5958864.83 697327.20 8.00 -5474.90 269.60 MWD 13775.00 90.93 284.51 8692.71 -1972.54 5087.22 5958870.90 697302.95 8.00 -5450.17 269.57 MWD ~, ' i Baker Hughes INTEQ~ Baker Hu hes INTE Plannin Re ort g Q g P iHr~c~ Company: BP Amoco Date: 5/2/2005 f Time: 11:58:54 Page: 4 ~ Field: Prudhoe Bay Co-ord3nate(NE) Reference: UVell: 18-12, True North ~ Site: PB DS 18 Vertical (TVD) Reference: 23:12 11!9/1986 00:00 47.0 Well: 18-12 Section (VS) Reference: Well (O.QON,O.OOE,293.90Azi) Wellpath: Plan #6, 18-1 2B Survey Calculation Method: ------ --- --- Minimum Curvature - -------- Db: ---- Orade - -- - Survey' ~- MD ----Intl -- Azim SS TVD N/S E/~'V MapN MapE DLS -VS - TFO-- -_- Tool - ft - deg - deg - ft -- ft ,_. ft ft ---- ft degl100ft - ft --- deg - _ _,--~ 13800.00 90.92 282.51 8692.31 -1966.70 5062.92 5958876.11 697278.51 8.00 -5425.59 269.53 MWD 13825.00 90.90 280.51 8691.91 -1961.72 5038.42 5958880.47 697253.89 8.00 -5401.17 269.50 MWD 13850.00 90.88 278.51 8691.52 -1957.59 5013.77 5958883.96 697229.15 8.00 -5376.96 269.47 MWD 13875.00 90.86 276.51 8691.14 -1954.33 4988.99 5958886.59 697204.29 8.00 -5352.98 269.44 M W D 13900.00 90.84 274.51 8690.77 -1951.93 4964.11 5958888.35 697179.36 8.00 -5329.26 269.41 M W D 13925.00 90.82 272.51 8690.41 -1950.40 4939.16 5958889.24 697154.38 8.00 -5305.83 269.38 M W D BP Amoco weurwtx °f9uEs rl.n fe, 161E SOOS93181003 r9nnt w«Ir.r9: 1an2w rl. on Iff: 1+na.oo Roralo + R11. OM9~ill: 23: 12 +1NMiM000:00 lT.OOR V.foelbn ONNR0In O In f1.Hl~rIqt wnpN NU~f •W From TVD _ 291.M' 0.00 0.00 D1.00 REFERENCE INFORMATION Coartllnate (N/E) Reference: Well Centre: 18-12, True NoAh Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Slot - 12 (O.OON O.OOE) Measured Depth Reference 23 12 11/9/1966 00.OC 47 00 Ca:'culalion Mefhod. M~nimuni Curvature sECTwN DETwNf s« rf 1.9 . . 0119 rF991 v99c T9ryM + 111]1.00 05.89 1 BOt AY 363!39 Om M6].95 e1a9:i: m>ta 'a ii~e6'"9a w ~iii°9:ii samt> ~en12a ~num 629+39 a9912+ s i+°wa o9 a++]+ liia ss.n nn23 saaT1 w> a:2• smt9 «99.n 'i 99e9 111m m.n iim 2n9 ±nVA2 91M 3N3~ 801161 _ ~ M3126 o ~2111~ 91A13 D1~A1] .T1i6.N 81n~oe l.OmO 90.00 OT>1320 11 +]9H.00 9022 1+5.30 0800.11 .1950A0 1919.13 9m f>O.ro 3]M2] TVD MO wn„O1209n ~~ `~~ ..ti ~ ~ s -~k !093.0111858.00 Ir O~OO^ A00 118TH d3! ~~~ 0693.]911880.00 ROr rit1B T~,~ytt ~ 0091.01 11080.00 En09'HOO'Oaf s>ov99119eo.o9 1 n++.es u11 o.09 s 0TS0.]t 12313.13 6 0111.9912]03.13 T 0]11.11 15093.12 0098.5113113.12 0090.111]825.00 TD -1200 -1300 - -1400 -- -1$00_ . ._ -1600- -- C -1700-_ O -1600 0 r ~~-1900 /\ -. -2500 -2600 --~~ -2700 by LEGEND - 1&12 78-, 2) 1e-1z 1&1Zl1 Plan 1&12B -- Plan #6 T Azimuths to True North Plen: Plan #6 (1&12/Plan #6, 18-128) M Magnetic North: 24.90° Created ey: Bill Michaelson Date: 5/2/zoos Maggnetic Field t;r,macl Informer n Shen9ih: 57649nT ,lames Ohlingar Dip Angle: 80.88° Direa. (907)267-6610 Date: 5/2/2005 Ccll (907) 250-7375 Model: bggm2004 j E-waif jamesohlinger@irteq rom • West(-)/East(+) [100ft/in] I 1 6200 6300 6400 6500 6600 tz.-s ~~ -- , i450-6400-6350-6300-6250-6200-6150-6100-6050-6000-5950-5900-5850-5800-5750-5700-5650-5600-5550-5500-5450-5400-5350-5300-5250 Vertical Section at 293.90° [50ft/in] t '_1.1-1 F. ti) I ~I PM • • are from top i ~_ ~ 18-12B of bag BAG of bag middle of slips Blind/Shears TOTs ~ middle of pipes 2° COmbl ram/SIIpS Mud Cross Mud Cross of flow cross of blind/shears 2 3/8~~ ram TOTs ~ of pipe/slips 2~~ combi ram/slips Flow Tee TERRIE L RUBBLE BP EXPLORATION AK 1NC ,. ss-si,2sz 19.7 PO BOX_196612 IVIB 7-5 Mastercard Check" ANCHORAGE, AK 99519-6612 DATE D PAY TO THE / ORDER OF nj~ $ ~~' ~~ ~1~,_ First ational Bank Alaska DOLLAR& Anchorage, AK .99501 MEMO-I ~~ ~ Z,g ~: L 2 5 2 0 0 0 6 0 ~: 9 9 14 ~~~ 6 2 2 7 ~~i 1 5 5 6 ~~• 0 19 7 • • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME o_ l /fir-/~-d' CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect 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. DRY DITCH All dry ditch sample sets submitted to the SAMPLE 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. Rev: 04/01/05 C\j ody\trans m ittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 18-128 -Program DEV Well bore seg ^ PTD#:2050730 Company 8P EXPLORATION (ALASKA] INC Initial ClasslType DEV ! 1-0IL GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal ^ Administration 1 Permit-fee attached- - - - - - Yes - - - - - - - - - - - 2 Lease number appropriate----__- -_____-.__-_-_- --____- -_-_--Yes-------- -----_ - - - - - - - 3 Uniquewelt_nameandnumbe[_______________________________ _______Yes---___--_- ----------------------------------------------------------------- 4 Well located in a-defned_pool - - - - - Yes - - - - - - 5 Well located properdistance_ftomdrillingunitboundary-------------__- __---_Yes-_-_--_-_-_-_-__--____-,-_-_-_-__-_---_-_-_-_-__--_-._---_-__-_-_- -_- 6 Well locatedproperdi_stance_fromotherwells______________________ ______Yes__-___-___._-_-__-___-___-__-.__-_,__ - - - 7 Sufficient acreageavail_ablein-drilling unit-___-___________________ ______Yes-_---__-___-_-__-_-_____-__----_--_-_,_ ---------------------------------- 8 If_deviated,is_wellboreplat_included____________________-___-_- --_-__Yes-__-_-_-_----_-_-_-___-.-_---_ - - - 9 Operator only affected party- - - - - - - - -Yes - - - - - - - - - - - - - - - 10 Operator has-appropriate bond infgrce ----------- ------------- --- --Yes-------- - ------------- ----------- -- --- ---------- - --- ------ --- - 11 Permit_canbeissuedwithoutconservationorder-__-_-______________ _____Yes-_-___-, __-_-_--_____--_--__-______-_-_-______-___----_---_---__-_--- Appr Date 12 Permit_canbeissuedwithoutadministrative-approval__________________ _______Yes_-_-__.-_-__--__--_--__-_-________-_-_-_-__-_-- ------------------------ RPC 51912005 13 Can permit be approved before 15-day wait Yes 14 Well located wtthiq area and strata authorized by-Ipjecti9n Orde[ # (putlQ# in_comm ents)-(Fpr- Nq_ _ , _ - - _ _ - - - _ _ _ - _ - _ _ _ - _ - - - - - - - - - - - - - - - - - - - - - - - - _ - - - - - _ - - _ 15 All wells withint~4_milear@a-ofreyiewidenttfied(FOrservieewe!!only)________ _______ NA_-_-_----___---_-_,____-_-_--_____-____--_ -- 16 Pre-produced injector; duration of pre~rroduetion less than $ moMhs_(For_seruice well onty) _ NA_ _ _ - - - _ . ---------------------------------------------------------------- 17 ACMP_Finding of Consisteney_haS been issued_forthis project- - - - - - - - - - - - - - - NA- - _ _ - -------------------------------------------------------------- Engineering 18 Conducts[str-ing_p_rovided____-_-_______-__.__-__-___-_ --__--NA--_-__-___-_---_ - - - - - - - - 19 Surface casing_protectsalLknownUSDWs__._---.------------ - -_--NA-.______-_-_-____-__-___-___---____-------------------- - -- 20 CMT-votadequate-tocirculate_on conductor__&surfcsg____---___-__- __-___- NA__________________________-_-__--_--_. - - 21 CMT vol adeguate_totie-in long string to surf csg_ _ - - - _ . - _ _ - _ _ - _ - NA_ _ _ - 22 C_MT_willcoyerallknow_n-productiyehorizons_______-__-__-__-_ -__-_Y_es-___-_._ ------------------------------------------------------------------ 23 Casing designsadequaieforG,TB&-permafrost-------------------- -- ----Yes--------------------------------------.-------------------------_ --_ 24 Adequatetankage_orreservepit___________________--__--__-- - -__.-Yes----_--CTDU.-_---______-_ - - - - - 25 Ifa_re-drill,has_a10-403forabandonmentbeen approved________________ _____Yes--_----*-_-___-__---_____-__-___-___-._--_---_--_-_-_---_-_---___-- _ _ _ 26 Adequateweflboreseparation_proposed__________________________ _______Yes.__-_-__-__-__-_-_-_-____--__-_______-__ ----------------------------------- 27 Ifdiverterrequired,dQesitmeetregulations_______________________ __-_-_ NA_,-____Sidet[ack.__-___-__-__--______---_-___-___-_____--_-__--_---_--_-- Appr Date 28 Drillingfluid-programschematic&equiplistadequate_-_-_--__-___-_ -__-_-_Yes--___-Max MW-8,9ppg,______-_-__---_-___---_.__--_--_-_-__-_-_---_--- WGA 5!10!2005 29 BQPEs,dotheymeetregulation___---------------------- --_ ---Yes,-----------------------------------------------.-------------- ---- 3D BOPE_pressratingappropriate;testto_(putpsigincomments)-_-____---- ___-___Yes___-._Testio35QOpsi.MSP2420psi.-_-______-_________________----___--_---_--- 31 Choke-manrfoldcomplies wlAPl_RP-53(May84)___--________________ ______Yes--_-_._----_-__-_ - - - - - - - 32 Work willoccutwithoutoperatianshutdown_________________________ _____Yes.___-_-_--._ ------------------------------------------------------------- 33 Is presenceof H2S gas probable - - - - - - No- - - . _ Notan H2$ pad. - - - - - - - - - - - - - - - - - 34 Mecha_nits!conditionofwellswithinAQRyeri_fied(For_se[vicewellon_IyJ________ ______NA_____-___---___-_____-_-_____-____-----_---_ - - - - - Geology 35 Permit_eanbeissuedwlohyd[ogen-sulfidemeasures_,___------------- ------ No__--_-___-___-_-__.____--_ 36 Data_presentedon_pote_ntialoyerpressurezones_-___________________ ______NA__-___-----_-___-__ Appr Date 37 Seismic analysis-of shallpwgas-zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA - --- - RPC 519!2005 38 Seabed conditionsuryey_(ifoff-shore)__________________________ - - - - - - - - - - - ______ NA__-_ - - ------------------------------------------------------------------ 39 -Contact namelphone-for weekly progress-reports [exploratory only]- _ - - _ _ - - _ - NA_ _ - _ - _ - _ - - Geologic Engineering Pu Date: Date Date Commissioner: Co Commissioner: •
