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Home My WebLink About197-069r~ XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: ,.~ Grayscale, halftones, pictures, graphs, charts Pages: 1~/ /7/ /~"~ [] Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED [3 .Logs of various kinds o Otl~er Complete COMMENI~: Scanned by: ~e,~.,~ TO RE-SCAN Notes: Re-Scanned by: ~ver~ M~red Damtha Nathan Lowell Date: /s/ STATE DF ALASKA ` ei~"~° ALASK~IL AND GAS CONSERVATION COMIditSSION JUN Y 2 2008 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil ~ ~~s CDnso Commission Anr6~rerara:a Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended 1a 1b. Well Class: . zoAACZS.~os zoaACZS.~,o ~ Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aba 12. Permit to Drill Number BP Exploration (Alaska) Inc. 09/26/2004 197-069 304-284 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 04/27/1997 50-029-20654-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 05/03/1997 PBU E-18A 1853' SNL, 501' WEL, SEC. 06, T11N, R14E, UM 8. KB (ft above MSL): 60.5' 15. Field /Pool(s): Top of Productive Horizon: 2146' SNL, 762' WEL, SEC. 07, T11 N, R14E, UM Ground (ft MSL): 30.25' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 3227' SNL, 879' WEL, SEC. 07, T11N, R14E, UM 10214' 8178' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Zone- ASP4 5975211 64487 y- 6 Surface: x- 12303' 8923' ADL 028304 _ _ __ _ __ y- 5969635 Zone- ASP4 664369 TPI: x- 11. SSSV DeN A(MD+TVD) 17. Land Use Permit: _ _ 5968552 Zone- ASP4 4279 y- Total Depth: x- 66 TVD s ®No ^ Y i l S 19. Water depth, if offshore ): 20. Thickness of Permafrost ( e urvey ona 18. Direct N/A ft MSL 1900' (Approx.) Submit ele tonic and tinted information er 20 AAC 25.050 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP,_ BOTTOM SIZE ....CEMENTING RECORD PULLED.. 20" x 0" In la ed Con c or Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2686' Surface 681' 17-1/2" 3720 cu ft Arcticset II 9-5/8" 47# L-80 Surface 10377' Surface 8317' 12-1/4" 1450 cu ft Class'G' 130 cu ft AS I 7" 26 L-80 9856' 10783' 7888' 8660' 8-1/2" 432 cu ft Class'G' 2-718" 6.16# L-80 1 254' 12303' 8212' 8923' 3-3/4" 145 cu ft Class'G' 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, list each I nterval open d N b i S SIZE DEPTH SET MD PACKER SET MD um er): lze an on (MD+TVD of Top & Bottom; Perforat ' 5-1/2", 17#, L-80 x 9805 MD TVD MD TVD 4-1/2", 12.6#, L-80 9805' - 9965' 9825' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. gy {{~~ Q ~~~~ JUN y O ZUOS DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 10280' Set CIBP (08/15/04) 10214' Set Whipstock (09/26/04) 26. 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 (CORK): PreSS. 24-HOUR RATE 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewall Cores Ac uired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None a " ~'~6 ~'l g °~z~' s ~ t- ~ $,taww_ t..-. Rn Form 10-407 Revised 02/2007 ? ~ 9 C NTINUED ON REVERSE SIDE ~,.~ s ~~ ~ ~7 ~ ~ ~ JUN ~~ 6110D8 2S. GEOLOGIC MARKERS (LIST ALL FORMATIONS ANA "BARKERS ENCOUNTERED): Z9. FORMATION RESTS NAME TVD Well Tested ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top of Sadlerochit /Zone 4B Zone 2A Zone 1 B Zone 1 B Base of Sadlerochit 10790' I 8665' I None 11015' 11120' 11164' 11287' 8807' 8861' 8885' 8936' Formation at Total Depth (Name): 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the forego'ng is true and correct to the best of my knowledge. Signed Terrie Hubble Title Drilling Technologist Date ~~ PBU E-18A 197-069 304-284 Prepared 8y Name/Number. Terrie Hubble, 564-4628 Well Number Permit Nn / Annrnval Nn Drilling Engineer: Mark Johnson, 564-5666 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02!2007 Submit Original Only ,,~,-' E-18A Well History -Abandoned Date Summary 7/26/2004 WELL SHUT IN ON ARRIVAL. R/U RIH W/DRIFT RUN. 7/27/2004 DRIFT,_W/ 2.25 CENT W/ 1.5 SAMPLE BAILER TO 10.400' SLM. TARGET WAS 10,280'. R/D. WELL LEFT SHUT IN. 7/27/2004 T/I/O = 940/360/120 PPPOT-IC =Passed at 3300 psi. All LDS working good. PPPOT-T =Passed at 5000 psi. LDS #3 is out, #2&4 were frozen in, all others working good. 7/29/2004 T/I/0=400/340/120 MIT IA to 2500 psi, Passed on 2nd test. Pressure losses=l st test, 150 psi in 15 min. 2nd test, 40 psi in 15 min. and 10 psi in next 15 min. Pumped 21.4 bbls crude to pressure up. Final W H P=400/600/150. 8/6/2004 T/I/0= 620/400/0 MIT-OA to 2000 psi.-PASSED Pumped 3 bbls diesel to pressure up. Lost 50 psi the first 15 minutes, 70 psi total for 30 minutes. Bled down to zero when finished. Final WHPs= 620/400/0. 8/11/2004 ATTEMPT TO DRIFT W/3 70 DMY WHIPSTOCK (UNABLE TO GET THROUGH TOP OF MERLA PAT~Fi (MIN ID=3.75) ~ 9637' SLM.. BRUSH /FLUSH INSIDE OF PATCH. 8/11/2004 T/I/O = 500/340/100. Assist Slickline (Prep for CTD). Pump 266 BBLs crude down tubing. Final WHPs = 800/440/450. 8/12/2004 DRIFT W/ 9' OF 3.70" DMY WHPSTCK, HAD TO TAP THRU PATCH. TAG LINER TOP, DRIFT W/ 3.74 MILL TO TOP OF PATCH. UNABLE TO WORK THRU. DRIFT W/BAKER 3.625" D-WHPSTCK (19' OAL) THRU TBG. PATCH Q 9633' SLM, NO PROBLEMS, TAGGED LINER TOP C 9838' SLM. 8!13/2004 MU /RIH w/ Baker 2-7/8" motor 3 74" crayola mill. Tag patch ~ 9660' able to roll mill through to lower element C~3 9680'. Slowly mill through tight spots. 8/14/2004 Keep getting stalls, not making progress. POOH. Cut pipe. MU/RIH w/ 2-7/8" mtr, 3.73" string mill w/ 3.60" pilot mill. Drift through patch to 9835'. Ream/backream across patch. Good. POOH. Mill is still with in gage. FP wellbore/flowline w/ water/meth. RDMO. 8/15/2004 DRIFTED W/ 3.70" x 19' LONG WHIP STOCK TO 9834' SLM (DEPLOYMENT SLEEVE). (HAD TO WORK THREW PATCH, HAD -950 P/U WEIGHT). DRIFTED W/ 2.25" SWAGE TO 11286' SLM, STOPPED DUE TO DEV. 8/15/2004 T/I/0=400/320/100. Assist E-line. RDMO before E-line performs chem cut. 8/15/2004 $ET HALIBURTON 2 7/8" Model M CIBP AT 10280', AS PER PROGRAM. PRESSURED UPON TUBING TO VERIFY SEAL. LOST 175 PSI IN 15 MINUTES, IA PRESSURE INCREASED FROM 350 TO 380 PSI. BLEED TUBING TO 500 PSI. CONTINUED REMAINDER OF JOB. SHOT ONE STRAND STRING SHOT FROM 10244' - 10256'. SHOT 2.125" CHC AT 10254', 4' DEEPER THAN PROGRAM TO AVOID PLACING ANCHOR HOUSING IN COLLAR AT SHOT DEPTH. SEVERING HEAD INDICATES GOOD CUT. TOOL DETAILS IN LOG SECTION. WELL SECURE AND SHUT-IN, PAD OP NOTIFIED PRIOR TO DEPARTURE. 8/16/2004 MU/RIH w/ Baker 4" GS fishing string w/ U/D jars/accelerator. Latch fish C 9851'. One jar lick up, liner up IIS free. Pull liner 100' up through tubing patch. Set liner back down 9851'. POOH, FP well to 2500'. RDMO. 8/24/2004 T1O=380/800/100 MITIA PASSED Q 2500 psi. (Well Shut In on Arrival) (Prep for CTD) Installed Integral Flange. IA Pressured up w/ 6.4 bbls Diesel Pumped. IA Lost 80 psi in 15 min, w/ Total Loss of 100 psi in 30 min. Removed Integral and Installed Original Flange, PT'd to 2500 psi. Final WHPs= 400/720/100 Page 1 of 2 . ,' E-18A Well History -Abandoned Date Summary 9/4/2004 T/I/O = 400/840/80, temp = SI. Bleed tubing pressure to 0 psi pre-CTD. Tubing FL @ 200'. Bled tubing from 400 psi to 0 psi in 35. Flowline disconnected; wellhouse off. Monitored WHPs 30 minutes with no change in pressures. Final WHPs = 0+/840/80. 9/5/2004 T/I/0=10/520/80. Temp=Sl. Monitor WHPs, (Prep for CTD). TBG pressure increased 10 psi and IAP decreased 320 psi overnight. 9/8/2004 T/I/0=0+/490/80. Temp=S1. Monitor WHPs, (post TBG bleed). TBG pressure remained the same and IAP decreased 30 psi. 9/15/2004 MIRU. Pull Liner / Underream /Caliper Liner: Perform BOP testing. Bleed IA. RIH w/ 2.23" JSN and begin circ well over to 2% KCL. 9/16/2004 Complete circ kill w/ 2% KCL. Perform 15 min no flow @ btm. POOH. MU/RIH w/ Baker fishing string w/ tears & GS spear Tag liner/deployment sleeve @ 9851'. PU gained 3k#. POOH. Recover 13 joints of 2- 7/8" STL plus 10' of the cut joint. RIH w/ Inteq UR (set up for 7" 26# casing) and Baker 2-7/8" motor. Tag cut liner top and correct CT depth to cut depth of 10254'. UR from 10144' - 10244' (five passes), w/flopro sweeps. No motor work or stalls observed. Open circ sub chase out. Underreamer wear looked normal. MU PDS caliper. 9/17/2004 MU/RIH w/ PDS caliper Could not aet throuah patch @ 9661'. Reconfiaure_BHA w/ centralizer above and below caliper. RIH, no problem going through patch. Loa caliper from 10250'- 9800. Freeze protect well from 2200' w/ 50/50 meth while POOH. At surface w/caliper (no datal -arms did not onen_ Decision made to RDMO & have slickline run caliper when available. Leave well shut in. 9/20/2004 DRIFT W/ 3.7" DUMMY WHIPSTOCK TO 9642' SLM, COULD NOT PASS THRU PATCH. RAN PDS 2 3/4" CALIPER W/ BOW SPRING CENT. LOGGED FROM 10222' SLM TO 9558' SLM. DRIFT W/ 3.65" BAKER DUMMY WHIPSTOCK, TAG @ 10237' SLM, TOP OF CEM-CUT LINER 10254' ELM. 9/24/2004 A BAKER WHIPSTOCK WAS RIH. TRIED TO SET WHIPSTOCK @ 10214', BUT COULD NOT GET WHIPSTOCK TO ORIENTATE CORRECTLY. TRIED TWO DIFFERENT CONFIGURATIONS. POOH WITH TOOL. CHECK ALL WEIGHT BARS. ORIENTATION IS CORRECT. BAKER TO DISCUSS OTHER POSSIBLE CONFIGURATIONS FOR MORNING ATTEMPTS. 9/26/2004 SES BAKER 4-1/2" X 7" GEN II WHIPSTOCK 176 DEG RIGHT OF HIGHSIDE AT 1021.4'. FINAL TOOL CONFIGURATION THAT WORKED WAS WITH A SWIVEL AND 18' OF DE-CENTERED WEIGHT BARS ROTATED 180 DEGREES FROM WHIPSTOCK. JOB COMPLETE. Page 2 of 2 r TRF_E=~ CIW 6 3/8" HEAD = VUF1L FMC _ ACTUATOR= OTIS KB. ELEV = 60.45' ~ BF. ELEV = 31.72' ^ - KOP = " - 2600' Max Angle = 95 @ 11553' Datum MD = ~ 11119' Datum TV D = ~ _ 8800' SS 9-5/8" DV PKR 13-318" CSG, 72#, L-80 BTRS, ID = 12.347" Minimum ID = 2.370" @ 9862' TOP 2-7/8" LNR 21' MERLA TBG PATCH ID = 3.75" 5-1/2" TBG, 17#, L-80 IJ4S IPC, .0232 bpf, ID = 4.892" 4-112" WRP (3.69 OD)(05/02108) SPECIAL CLEARANCED TOP OF 7" LNR I3-1/2" LNR STUB {08/09/05) 4-112" TB, 12.6#, L-80, .0152 bpf, ID = 3.958" TOP OF CEMENT { 12!24/04 CMT BOND LOG) GEN II MECHANICAL WHIPSTOCK (11/02/04) RA TAG 2-7/8" LNR STUB (09/17104) 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" 7" LNR, 26#, L-80 U4S, .0383 bpf, ID = 6.276" 9834' 9965' 10086' PERFORATION SUMMARY REF LOG: ANGLEATTOPPERF: @' Note: Reter to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SAFETY NOTES: MERLA TBG PATCH 9652'-9673' MD, OVER GLM 1, ID = 3.75" 1996' -j SSSV OTIS ROM NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 2891 2821 12 MMIGW DMY RK 0 12/22/03 11 5119 4533 49 MMIGW DMY RK 0 12/22/03 1D 6890 5657 49 MMIGW DMY RK 0 10/14/81 9 6996 5720 50 MMIGW DMY RK 0 10/14181 8 7871 6295 51 MMIGW DMY RK 0 10/14/81 7 7974 6371 52 MMIGW DMY RK 0 10/14(81 6 8549 6808 53 MMIGW DMY RK 0 10/14/81 5 8656 6893 53 MMIGW DMY RK 0 10/14!81 4 9071 7219 54 MMIGW DMY RK 0 10/14/81 3 9177 7301 53 MMIGW DMY RK 0 10/14!81 2 9551 7590 45 MMIGW DMY RK 0 10/14/81 *1 9655 7670 43 MMIGW DMY RK 0 10/14/81 " GLM #1 C:UV tKtU t3Y Mtt{LH I t5t~ F A I l;l-i ' GLM'S # 11 & # 12 =EXTENDED PACKING 9723' S-1/2" BKR L SLIDING SLV, ID = 4.562" 9805' TUBING SEAL ASSY, ID 9$25' 9-5lB" X 4-112" BKR SAB PKR, ID = 3.813" 9856' - ~9-5/8" X 7" BKR HYDRO HGR w /TIEBACK, ID = 6.25" 9$$2' 4-1/2" OTIS X NIP, ID = 3.813" ~4-1 /2" OTIS XN NIP, ID = 3.725" i 9965' -[4-112" BAKER WLEG, ID = 3.958" 9940' ELMD TT LOGGED 05/03/89 10100' 3-112" CIBP (07/15/05) ~ MILLOUT WINDOW (E-18B) 10216' - 10221' 10225' CTMD 3-1(2" PARTED/ DAMAGED LNR ~` 10234' -{ MCCL/GR DEPTH PBTD 3-1J2" LNR, 9.3#, L-80 STL, .0087 bpf, ID = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/14!81 ORIGINAL COMPLETION 08!08/07 GJB/PJC CHEM CUT @ 9990" 05/07/97 RW CTD SIDETRACK "A" 08/10/07 KSB/PJC PULL DEPLOY SLV @ 9914' 11/09104 NORDIC 1 CTD SDTRCK "B" SUSPENDm 10/25/07 JSR/PJC DRLG DRAFT CORRECTIONS 07/15(05 RAC/TLH SET CIBP 11!26/07 JSR/PJC DRLG DRAFT CORRECTIONS 07/19/05 WJHI TL CHEM CUT @ 10073' 05/05/08 KJB/PJC SET WRP (05(02/08) O8/D7/05 JGNVPJC CHEM CUT @ 10060' PRUDHOE BAY UNfT WELL: E-18A PERMIT No: 1970690 API No: 50-029-20654-01 SEC 6, T11 N, R14E, 1853' SNL & 501' WEL BP Exploration (Alaska) E-1 S nna~n~~~, T~®rrn~s ~ ~®®~~ Fporroa Hubble, Terrie L [Terrie.Hubble@bp.com] Bent: Tuesday, December 18, 2007 8:24 AM To: Maunder, Thomas E (DOA) Subject: RE: PBU E-186 (204-139) 1 i Attachrnerats: E-186 Non-Rig Work.pdf r ` ~ ~ r~~ "° Mi "fOm, `C°l~~ere have >",+;:en na rich opc~ratinns since November 200. Here are; tine roan-rig wa~rk aperafiions that have accurr~;d since then. Uayau need anything else? "1"t~~rrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, December 17, 2007 4:16 PM To: Hubble, Terrie L Subject: RE: PBU E-18B (204-139) Fli •1"erri We have dis;cuss~}d thi€; well pr~;vic7usly. 1 have short~:ned the original message we exch~~nged rernovirtir~ refE,reanc~~s to 05.286. I arr~ reviewing the sundry try change tht~ wail from U;~D to Suspended. Are th~:rf~ any opc;rrational reports for activities since the well was C7SD in Navemb~;r 2004'1 1 suspect th~~t you are punning to c;~.~bn~rit ;~uc;h reports with the 407 after the new plug is sat in the weii. is it possibie to send the reports ti•~at currently ~xxist? That would help in the review. Thrynks in advance, 1"orn Maunder, r~E; AfJr~(;C From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Friday, September 07, 2007 2:27 PM To: Maunder, Thomas E (DOA) Subject: FW: PBU E-186 (204-139) I"li 'T'ony, P~.r year c~uestians b~;low... ~ 4'D JUN 2 0 2008 Pk3~f ~-'1 ~~ (P'I-L7 20441 ~9), which is currently in fJps shutdown r~tatus. I have learned that thNre is isaiation fram the reservoir. The 3-1/2" liner was cerr~ented in place and a CI~P was set in the tubing afker the rig moved off. The Pad engineer will ensure that ever~ytl~ring iti pressure tested and I expect to be submitting a iundry sharkly to change the status fmm Ops ;~hutdawn tra ~~uspended. 'T"hanks, `i`errie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] 6/ 19/2008 \~ts ~n~a Friday, August 03, 200' 9009 AM 1T~o Hubble, Terrie L ~co FlecEcenstein, Robert ] (D®A,) ~u~~~~o PBU F-1$B (204-139) and --~-- Terrie, ,'. O w ~q ~ { Bob and !have some questions on these wells.~~ { E-18B -- This weA was granted operational SD via sundry 304-402 dated November 18, 2004 due to an obstruction in the newly cemented 3-1/2" liner. Sundry 305-144 was issued June 13, 2005 to re-start operations. We have 2 transmittal letters in the file labeled E-188 PB. One is L1/VD data and the other survey data received in late 2005. There is no other information in the file. If operations were completed around late November 2005 the completion report should have been submitted some time ago. 1/Voutd you please advise us of the well condition and submit the appropriate reports? Any report should also include the operations information from the activities conducted around November 2004. Also, see comment below. Thanks in advance, Tom Maunder, PE AOGCC 6/ 19/2008 /17-t9G? ( 03/15/05 Schlumberger NO. 3363 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color -' Well Job # Log Description Date Blueline Prints CD f q 3 -r!ly. C-39 10715421 MCNL 08/19/04 1 ~ (t7-H<? E-21A 10670030 MCNL 08/22/04 1 C9&-/70 C-29A .- ,~ 10715422 MCNL 08/22/04 1 J' J.G'3· ¡r}..DS 07-33B 10715361 MCNL 11/04/03 1 1 /97-15?;-07-01A 10889151 RST 08/18/04 1 1 ~f.,(;t;C¡ X-27 10724364 RST 03/10/04 1 1 ',- <':: E-18A 10621786 RST OS/22/04 1 1 !¡~7-.P.¥' 7 DS 01-24A 10563108 RST 10/09/03 1 1 , 2- l:;z. E-10A 10621797 RST 06/16/04 1 1 !7>9 -/OL Z-12 10704020 RST 07/06/04 1 1 Zt)l~ 0'1, X-15A 10704021 RST 07/07/04 1 1 1;/;i..~) 1 P1-07 A 10831301 RST 07/03/04 1 1 , q '7.. 07(ŽG-03A 10889210 LDL 02/13/05 1 ~- 'Z.l, L5-17A 10942195 PSP PPROF/DEFT/GHOST 02/28/05 1 "':J -r;J1P1-05 10687701 PPROFPS~DEFTIGHOST 08/13/04 1 .'-fiL/., (/2.. if MPC-42 10889141 RST 07/26/04 1 ht/.{)ß MPC-42 10621815 RST 08/07/04 1 ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Sr- ~ . . . BP Exploration (Alaska) Inc. . vJ1NNE1J,Li P Q "'i Petrotechnical Data Center LR2-1 . !. J. Jo 900 E. Benson Blvd. Anchorage, Alaska 99508 /1 ír¡ni::: ~ ~L!J~l Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK gg5.03-2~3:t: A TTN: Beth ./ Receiv ~AÍ ~ ¿V¿44tPt~ ~_ IV Date Delivered: ! I _311 &J ¡ 0 ç \;-il..t/t t I ~ .J I _L ÐJS ?/2~/1-- ,¡ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 ..qp,~- 1. Type of Request: 0 Abandon 0 Repair Well a Plug Perforations 0 Stimulate 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 8923 11720 8936 11720 Length Size MD TVD Burst 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612. Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 60.5' 8. Property Designation: ADL 028304 11. Total Depth MD (ft): 12303 Casing Structural Conductor Surface Intermediate Production Liner 0 Other 0 Time Extension 4. Current Well Class: 1m Development D Exploratory D Stratigraphic D Service 5. Permit To D.rill Number 197-069 ./ 6. API Number: /- 50- 029-20654-01-00 9. Well Name and Number: PBU E-18A ./ Junk (measured): None Collapse 110' 20" x 30" 110' 110' 2686' 13-3/8" 2686' 2681' 5380 2670 10377' 9-5/8" 10377' 8317' 6870 4760 927' 7" 9856' - 10783' 7888' - 8660' 7240 5410 2448' 2-7/8" 9855' - 12303' 7887' - 8923' 13450 13890 12. Attachments: 1m Description Summary of Proposal D BOP Sketch D Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mark Johnson Title CT Drilling Engineer Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Above Plugs: 11228' - 8914' - 8937' Packers and SSSV Type: 9-5/8" Baker 'SAB' packer: Otis 'ROM' SSSV Nipple ~","'-' , J~~8J004 'Date: -" Tubing Size: 5-1/2". 17# ( 4-112", 12.6# Tubing MD (ft): 9965' Tubing Grade: L-80 Packers and SSSV MD (ft): 9825' 1996' 13. Well Class after proposed work: / D Exploratory 1m Development D Service 15. Well Status after proposed work: DOil DGas DWAG DGINJ D Plugged DWINJ 181 Abandoned D WDSPL Contact Mark Johnson, 564-5666 Signature ~a--h' ¡tit {~ Æo, \'4\.D:S". Phone 564-5666 I Commission Use Only I ) ¡., Prepared By Name/Number Date ~ .1 )t7Jlf Terrie Hubble. 564-4628 I Sundry Number: 304- -;;-ð<{- V D Plug Integrity D BOP Test Conditions of approval: Notify Commission so that a representative may witness D Location Clearance D Mechanical Integrity Test Other: Be I' í: nl~l '" f k þç,fc Jet\... II S (è vE, L J Q ,{ ~ r p ¡£;t C<t dLf t ¡,., <( '-ì) ~ ,'<-L t ' ~I Ç. L-:V'[/l';-t V f d t<. r t. d <-,.. +L L í's. 'C - 4- C"S . Subsequent Form Required: \ C .. 4 t '7 Ori9;na' Sign.. Ðy DAN SEAMf)UNr Approved By: Form 10-403 Revised 06/2004 COMMISSI.oNER APPROVED BY THE COMMISSION id?L4. jUt 2 tI ,no,' Date ORIGINAL .,. BFt ~~$.,~ '* '$>;. : .~ i) ~.:) ~'< . ~ t,. *ø+~~ ~ To: \Vinton Aubert Petroleum Engineer Alaska Oil & Gas Consef\'ation Commission From: I\lark O. Johnson CTD Engineer Date: July 2 L 1004 Re: P&A operations for \\ell E-18A in prep for a CTD sidetrack \\lell E-18A IS scheduled for a through tubing sidetrack \\ith the SLB/Nordic 2 Coiled Tubing Drilling rig. The sidetrack. E-ISB. will cxit..øtrt -ef the existing T' liner from a mechamcal whipstock and target Zone I resef\Cs. The existing 1 7/S'" liner perfs will be abandoned with a CIBP set in the 1 7/8'" at 102S0'md. The following describes \\"ork planned for the P&A and is submitted as an anachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary I) Slickline - Drift tubing. Dummy gas lift \"ah'es. Pressure test IA to 2500 psi. Dnft 2 7/g" liner for (IBP. ~) E-line - Set 1 7/S" CIBP at 1028C)' md. Pressure test \\'cllbore to 1000 psi. P&A is complete. Regardless of pressure test results continu~ with plalUled operations. The old \\ellbore \\ill be isolated by 2 additional cement jobs during the liner completion phases. 3) E-line - Chemical cut 2 7/S" liner abo\'c top of liner cement at 10170' md. -l) SCf\icl: coil- Latch onto d~ploymt:nt slee\"e at 9S55" md and pull check liner to contiI'm free. S~t back down. ... CTD Sidetrack Summary I) I\HRU CTD rig. 2) PuB.2 7/S" lina from chemical cut. 3) Underream T' liner from 10100-10170" md. -l) SL - Log PDS caliper sUf\'ey of 1'" liner to confirm all cement is gone. ~'5) Set-lI,2"'X 1'" whipstock inT'linerat I0250"md. T'.'. to - 40 ~ CL.°l)Ì'ÚV''l.(, 6) 1\1ill 3.8"" 00 windo\\" at 10250' md. N\ 'J --I 7) Drill Kingak shale to -IO-lOO' to TSAG 8) Run and cement 3 3/16"' protecti\"e casing string. 9) Drill 2.1'" x 3" bicenter hole from IO-lOO" to TO at 12525" md with l\nVD/GR. 10) Run 2 3/S" solid and slotted liner completion and cement solid portion in the build section (bonzai completion). II) Cleanout bonzai equipment to TO 12) RDI\IO. ^ ",. The pre CTD \\ork is slated to begin on July 1S. 100-l. ?í~ °rVJ~ l\Iark O. Jolmson (TO Drilling Engin " 56-l-5666.1-l0-S03 CC: \\lell File Sandra Stew manIT errie Hubble TREE = WB.LHEAD = ACTUA. TOR = KB. REV = BF. REV = KOP= M:lx Angle = Datum MD = Datum TVD = cw 63/8" FM: OT6 60 45' 31.7Z 2600' 95 @ 11553' 11119' 8800'SS E-18A SAFETY NOTES: MERLA TBGPATCH 9652'-9673' MD, OVER GLM 1, ID = 3.75" 1996' H SSSV OTIS ROM NP, D = 4.562" I (i) GAS L FT MAI\ORELS ST MD 1V D DBI TYPE V LV LA TCH 12 2891 2821 12 CAMlMI,1IGW DMY RK ~ 11 5119 4533 49 CAMlMI,1IGW OMY RK 10 6890 5657 49 CAMlMI,1IGW DMY RK 9 6996 5720 50 CAM/MI,1IGW DMY RK 8 7871 6295 51 CAM/f'vt..1IGW DMY RK 7 7974 6371 52 CAM/f'vt..1IGW DMY RK 6 8549 6B08 53 CAM/f'vt..1IGW DMY RK 5 8656 6893 53 CAM/f'vt..1IGW OMY RK 4 9071 7219 54 CAM/f'vt..1IGW DMY RK 3 9177 730 1 53 CAM/Mv1IGW DMY RK 2 9551 7590 45 CAM/Mv1IGW DMY RK '1 9655 7670 43 CAM/Mv1IGW . GLM 1 OOVEREO W/lBG PA TCH PORT [)ð, TE 0 12122iÜ3 0 12122iÜ3 0 0 0 0 0 0 0 0 0 ~ 1 13-2.18" CSG. 72#, L-BO BTRS, 10 = 12 347" H 2686' L Minimum ID = 2.370" @ 9862' TOP 2-7/8" LNR 1 TOP PA TCH OVER GLM #1 H 9652' 1 BOTTOM OF MERLA PATCH ID = 3.75" H 9673' I I I I H BKR L SLDING SlV ,ID = 4.56Z' I H TLBINGSEALASSEMBLY I H 9-518" BKRSAB PKR ID= 3.813" H BKR GS ŒPLOYMENf SLV, ID= 3.00" I 9723' 5-1/Z' TBG, 17#, L-80 1J4S IPC, ---1 9805' .0232 bpf, ID = 4.892" ITOPOF 4-1/2" TBG H 9825' 1 r 9805' I .~ P I ........ I ,... II - ~ -2 I J ~ 9825' I TOP OF 2-7/8" LNR 1---1 9855' I TOP OF 7' LNR H 9856' 17" BAKER LNR HA.NGERWfflESAO<. D = 6.25" 9855' 9882' H4-1/Z'Ol1SXNP,ID=3.813"(BEH.LNR) I 9920' H4-1/Z' 011S XN NIP, 10 = 3.725" (BEH. LNR) I 9965' H4-1/2" BAKER lUBING TAIL (BEH. L~) 9940' H ELMD TT LOGGED 05/03/89 I 14-1/2" TB, 12.6#, L-80. .0152 bpf. ID = 3958" H 9965' 19-518" CSG, 47#, L-80 BffiS. ID= 8.681" H 10377' ~ ~ 1 10780' H TOP OF WHPSTOO< 1 ÆRFORA 110N SlJv1MA RY RB= LOG. SS MND'GR ON 05104197 ANGLE AT TOP PERF: 66 @ 11228' Note: Refer to Production œ for historical perf data SIZE SPF INfERv' AL OpnlSqz [)l\ TE Z' 6 11228-11288 0 01120101 Z' 6 11312-11327 0 01/19iÜ1 1-11/16" 4 11500-11700 0 05iÜ7/97 1-11/16" 4 11760 - 11900 C 09/14iÜO 1-11/16" 4 11960-12240 C 03/19/98 7 "MILLOUT WII\DOW - 10783' -1 0789' 1 11720' H BKRCIBP I 1 11816' H BKRCIBPFAILEÐ I I 11920' H2-7/8"HESrvt:>DMOBP I 1 7" LNR 26#, L-80 1J4S H 11263' I 1 2718"6.16#STLL-80.ID=237' H 12303' I DATE 10/14181 05/07/97 04/07/01 11/01/01 09/17/03 12/28103 REV BY COMfllENfS ORIGINAL COMPLETION RW CTe SIŒTRACK a-uKA K CORRECTIONS WBfTP SLRF LOC OORRECTIQN CMOfTLP PERF A NGLE CORRECTION .LJ/PAG GLV C/O 00 Mv1ENTS PRUŒiOE SA Y UNIT W8...L: E-18A ÆRMT No: 1970690 API No: 50-029-20654-01 SEe 6, T11N. R14E, 1853' SNL & 501'W8... DA TE REV BY 8P Exploration (Alaska) T~= W8..LHEAD = ACTUATOR = KB. B.EV = BF. B..EV = KOP= . - - .' . - , ~- ~.~~~- = Datum MD = ------.--- - . Datum lV D = E-18B CrN 63/8" FMC OTIS 60.45' 31.72' 2600' - - .-- - _95 ~. 1 ~ ~~3~ 11119' . -. -~...,.- - . 8800' SS Proposed CTD Sidetrack S~NOTES: MERLATBGPATCH 9652'.9673' MD, OVER GlM 1, ID = 3.75" 8 I 13-3/8" CSG, 72#, L-80 BlRS, D = 12.347" H 2686' ~ 1 TOP PA TCH OVER GLM #1 l-i 9652' I I I BOTTOM OF MERLA PATCH ID = 3.75" l-i 9673' I I 5-1/2" TBG, 17#, L-80 U4S IPC. -i 9805' f } .0232 bpf, ID = 4.892" I TOP OF 4-1/2" TBG l-i 9825' ~ P I TOP OF 7" LNR l-i 9856' I . 17" BAKER LNR HANGER WmEBACK, ID = 6.25" ~ 14-112" TB, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 9965' Il\Aechanical whipstock l-i 10250' ,,/ I Cut and Pull 2-7/8" Liner l-i 10270' 19-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" l-i 10377' CIBP l-i 10280' 7 "MILLOUT WINDOW - 10783' -10789' 1 7" LNR. 26#, L-80 U4S l-i 11263' ÆRFORA TION SUMMARY REF LOG: SS MWDlGR ON 05/04/97 ANGLE AT TOP ÆRF: 66 @ 11228' Note: Refer to A--oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 11228 - 11288 isolated proposed 2" 6 11312 - 11327 isolated proposed 1-11/16" 4 11500 - 11700 isolated proposed 1-11/16" 4 11760 - 11900 isolated proposed 1-11/16" 4 11960 - 12240 isolated proposed DATE 10/14/81 05/07/97 04/07/01 11/01/01 09/17/03 12/28/03 REV BY COMMENTS ORIGINAL COM PLETlON ~ CTD SIDETRACK CHIKAK CORRECTIONS WBfTP SURF LOC CORRECTION CMOffiP PERF ANGLE CORRECTION JLJ/PAG GLV C/O DA TE REV BY L 1996' H SSSV OTIS RQM NIP. [) = 4.562" I GAS LFT MANDR8..S ST MD lVD DEV TYPE VLV LATa; 12 2891 2821 12 CAWWMGW DMY RK ~ 11 5119 4533 49 CAWWMGW DMY RK 10 6890 5657 49 CAWWMGW DMY RK 9 6996 5720 50 CAWMMGW DMY RK 8 7871 6295 51 CAWMMIGW DMY RK 7 7974 6371 52 CAWMMIGW DMY RK 6 8549 6808 53 CAWMMIGW DMY RK 5 8656 6893 53 CAWMMIGW DMY RK 4 9071 7219 54 CAMlMMIGW DMY RK 3 9177 7301 53 CAMlMMIGW DMY RK 2 9551 7590 45 CAMlMMIGW DMY RK .1 9655 7670 43 CAMlMMIGW * GLM 1 COVEREDWfTBG PATCH PORT DATE 0 12/2210 0 1212210 0 0 0 0 0 0 0 0 0 9723' H BKR L SLIDING SL V, ID = 4.562" I l-i l-i 9805' 9825' 9850' 9882' 9900' 9920' TUBING SEAL ASSEMBLY 1 9-5/8" BKR SAB PKR. ID = 3.813" 1 --- l-i Top of 2-3/8" liner & Cerrent I'" 1-i4-1/2" OTIS X NIP, ID = 3.813" l-i Top of 3-3/16" liner & Cerrent I ,/" 1-i4-1/2" OTIS XN NIP, ID = 3.725" (BB-i. LNR) ~ 9965' 1-i4-1I2" BAKER TUBING TAIL (B8-I. LNR) 9940' l-i 8..MD TT LOGGED 05/03/89 I 10400' l-i Bottom of 3-3/16" Liner ;" I 2-3/8" Bonzai co~letion l-i 12525' I 11720' l-i BKR CIBP I 11816' l-i BKRCIBPFAILED I 11920' l-i 2-7/8" HES MOD M CIBP 1 12270' H PBTD I 12303' 1-i2 7/8" 6.16# STL L-80. ID = 2.37" COMMeITS PRUDHOE BAY UNIT W8..L: E-18A PERMIT No: 1970690 API No: 50-029-20654-01 SEC 6, T11 N, R14E. 1853' SNL & 501' W8.. BP Exploration (Alas ka) (-L . ( ì~ \ 1~CA) J ,.. -.:.. (tv 30 1 '-t,) .. - ')i:> ,10' : I ~ I : , : ~ ! , :~ ~ ~ II 11 ; ? ! ~ , "'" , ,- -., / / I (... ~ / ~ ~~ ~) ,~ ~~ '} ~ 't ( ;I ...... '" \ ( ~ <.~ ø ,,- ~ /,,> ~ - .J~'-- \ ~., ('" " .' ( ( :')- ~ ) '"') ~ r :,' 't <'- - ~(~- ~-!t . ;-' J.' -) { ~, ..." } , ./ .... .....'" ."r"" ~ ~,- r- !!Io II. --J> ~ -~- ~- ~" ......-- ," ~'. : J [~ J -I a '> ", , / J "- ~:~ ;' "" - ;) ç' .. J " i- ,.J I ) '- - -r- ,- ) r;.. ,tA IÙ\ f \." S ~~(\ {)I"^f \A~ , I ~I , 1(' 102701 .. ,~ EÞatw -,- ~"t '«ð Z Ið'fþ' ?'~. c,8P (Þt' . ~t ~ 7/fJ ~ 0300 ~ ~< < J - ) , /011$ .~ ( ~~ , . : '<." "'\ ~~- . .....-- ~ .;..:-. ~ '- - ¡~~~> : .--Ir ~- þ> f ~)' r -} '- J.- . ( , . 1,' ~f. \1.. ) \, '» :? '\ \ c.. l I' ~ ) \. '" -~ -' I ..... JIIIIIO I.. ' , " - ~.I 'i'~:,..,' "'~~' .. ~, \ I . --~. '" ' k. :' ~¡'I' I fIiIt.. '--,I L' .'..l~ : . . ',l'Ijr\; ~ '. ,! , ' ' . \ 1:, ,I' &II.. .~.' - ]£' '~""1&18 ~ 1.. .:: -¡!p.. , . I 'ml ':: f~~ - " '....... ~jf:i ;, ~"' -,,~... ,t ' . I , ,i~ '! ~ i ' , I : .~ . I, I Þ- 'i , ":$ ,'~~~~'. .~' ; ~,4 'I i ; , , ~ " ~ '.' :. ." j~ . I' _'II 1 j . ¡ ~:; ! I ' "II~' ',' "I'. r -~"*"" ~ i~~~I!II:m :",:~ _:~ "'I~~~,~:I ~:;I~~~I'-' , i;~i,,:}:!~ , , - 'I. :111 IIJIII: ',II "I', 01' OR BEFORE 001 c.LO~IL~-DOC PERMIT DATA 97-069 EOW SRVY 97-069 NGP-TVD 97-069 NGP-MD 97-069 8066 AOGCC Individual Well Geological Materials Inventory T DATA PLUS ~DRILLEX 10780-12303 ,.T~"871~-8861 /10794-12~03 . ~-PERRY GR/ROP Page: 1 Date: 05/24/99 RUN RECVD 07/21/97 FINAL 08/13/97 FINAL 08/13/97 1-3 08/13/97 10-407 z.~OMPLETION DATE DAILY WELL OPS R @~)/~ TO ~/p /e~ Are dry ditch samples required? yes ~3knd received? Was the well cored? yes ~ADalysis & description received? Are well tests required?i~¥es n~p.Received? ~ Well is in compliance ~ In%tial COMMENTS 17.7'1 y~ T D BOX .... WELL LOG TRANSMITTAL To: State of Alaska August 13, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs E- 18A, AK-MW-70123 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of~ Tan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 E-18A: 2"x 5"MD Gamma Ray Logs: 50-029-20654-01 2" x 5" TVD Gamma Ray Logs: 50-029-20654-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company OF:III--LING To,' .. State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - WELL LOG TRANSMITTAL August 13, 1997 E-18A, AK-MW-70123 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Tun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20654-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, inc. Company STATE OF ALASKA ALASKA (' AND GAS CONSERVATION CC .... MISSION WELL COMPLETION OR RECOMP LETION I-rEPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator ~P Exoloration 3. Address P. O. Box 196612, Anchora.qe, Alaska 99519-6612 4. Location of well at su rface 1853' SNL, 501'WEL, Sec 6, T11N, R14E At Top Producing Interval 1738' SNL, 588' WEL, Sec. 7, T11N, R14E At Total Depth 3226' SNL, 856' WEL, Sec. 7, T11N, R14E 5. Elevation in feet (ind icate KB, DF, etc.) KBE= 60.45 16. Lea~s~a_.ti_~¢ d I Serial No. 7. Permit Number 97-69 8. APl Number 50- 029-20654-01 9. Unit or Lease Name Prudhoe Bav Unit 0. Well Number E-18A 1. Field and Pool Prudhoe Bay ?ield/Prudhoe Bay Pool 12. Date Spudded 4/2 7/97 13. Date T.D. Reached 5/3/97 14. Date Comp., Susp. or Aband. 5/7/97 17. Total Depth (MD+TVD) 12, 303,8861 TVDss 18. Plug Back Depth (MD+T VD) 19. Directional Survey 12,270, 8860'TVDss YES [] NO [] 22. Type Electdc or Othe r Logs Run GR 15. Water Depth,n/aif offShfeet MSL°re 16.0neNO. of Completions 20. Depth where SSSV set 21. Thickness of Permafro st 1996' feet MD 1900'approx. 23. CASING, LINER AND CEMENTING RECORD SE'FI'lNG DEPTH ME: WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORE AMOUNT PULLED 6. 16# L-80 9700 12,270 , 3-3/4 145 c.f. CASING SIZE 2-7/8" i 24. Perforations open to interval, size and number ) 11,500-11,700, 8888-8884' 1-11/16" 4SPF 11,760-11,900, 8884-8868' 1-11/16" 4SPF 11,960-12,240, 8865-8860' 1-11/16" 4SPF Production (MD+TVD of Top and Bottom and 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SOJEEZE, ETD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flow ing, gas lift, etc.) 5/17/97 I GL Date of Test PRODUCTION FOR OIL-BBL GAS-MCF Hours Tested TEST PERIOD ~ ~ Press.FI°w Tubing 'Casing Pressure CALCULATED24_HOUR RATE J~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO WATER-BBL O L GRAVITY-APl (corr) 28. CORE DATA Brief description of lith ology, porosity, fracture s, apparent dips, and pre sence of oil, gas or wate r. Submit core chips. ORIGINAL Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE _~9. -, 30. ~ GEOLOGIC MARKER~ '"'-~-qMATION TESTS Include interval data, all fluids recovered and gravity, tested, NAME pressure MEAS. DEPTI- TRUE VERT. DEPTI- GOR, and time of each pha se. Shublik 10428 8300 TSAD 10512 8372 Ivishak 11218 8942 31. LIST OF A~ACHMENTS 32. I hereby cedi~ that the foregoing is true and co rrect to the best of my k nowledge Signed ~~ ~ Title ~oilTtlDin~Drillin~TA Date General: This form is des igned for submitting a co all types of lands and le ases in Alaska. Item 1' Classification of Service Wells: Gas injec water disposal, water sup ply for injection, observ Item 5: Indicate which el evation is used as refere given in other spaces on this form and in any atta Item 16 and 24 · If this completion), so state in in item 27. Submit a sep data pertinent to such in well is completed for sep item 16, and in item 24 s arate form for each addit terval. Item 21' Indicate whether from ground level (GL) o Item 23: Attached supplem ental records for this we lng and the location of t he cementing tool. Item 27: Method of Operat ion: Flowing, Gas Lift, R jection, Gas Injection, S hut-in, Other-explain. Item 28: If no cores take n, indicate "none". INSTRUCTIONS mplete and correct well c tion, water injection, st ation, injection for in-s nce (where not otherwise chments. arate production from mcr how the producing interva ional interval to be sepa r other elevation (DF, KB II should show the detail od Pump, Hydraulic Pump, ompletion report and log on eam injection, air inject ion, salt itu combustion. shown) for depth measurem ents e than one interval (mult iple Is for only the interval reported rately produced, showing the , etc.). s of any multiple stage c ement- Submersible, Water In- Form 10-407 Daily Operations Well E-18A Accept 4/26/97 Field: Prudhoe Bay Spud: 4/28/97 APl 50-029-20654-01 Release 5/6/97 Permit: 97-69 CTD Unit Nordic #1 Date Day Depth 4/27/97 1 Move rig from H pad to E pad from 0930 - 1430 hrs. Total of 5 hrs for 10 miles. Raise derrick, pick up windwalls. Remove snow from in front of well. SI E-32 (twinned with E-18) and depressure flowlines and E-18 WHP to 200 psi. Spot rig over well. Remove tree cap. Accept rig for operation at 2200 hours 4/26/97. NU BOPE. Spot misc equipment. RU injector. Fill pits w/SW. Stab CT into injector. 4/28/97 2 10788 Install CTC. Bleed WHP to zero, Well is dead. Perform BOPE pressure and function tests. M/U Milling BHA #1. RIH with 3.72" dimple CTC mill with flexjt and 2 jts of tubing. RIH slow thru Merla Tubing Patch at 9652 ff. [ ID = 3.75"]. Tag whipstock and correct CTD to 10782 ft and start milling window. Mill 3.72' OD window from 10782.3 - 10788'. POOH for BHA and had gassy returns. At surface found that wing, manual choke and check valve were leaking LDF pressure. SI lateral. Change BHA. RIH w/BHA #2 (3.72" string reamer and formation mill). No bobbles thru patch. Ream on window. 4/29/97 3 10955 Dress window with string reamer. Drill to 10790 fl. Turn well over to FIoPro drilling fluid. POOH. M/U directional drilling BHA. RIH with 1.25 deg bent motor and 3.69" M58X bit. Test Sperry tools, Cont. RIH. Orient TF to high side and drill build section from 10790 - 10955'. POOH for bit. 4/30/97 4 11411 Change bit and MWD tools. RIH with BHA #.4. Tie-in with GR. Drill build section from 10,955 - 11,201 ft BKB. Short trip to window. Hole OK. RIH and drill build section from 11,201 - 411' Short trip to window. Tie-in, add 10.0'. Unable to make anymore hole. POOH for bit and motor. Change bit, motor and MWD tools. RIH w/BHA #5. 5/1/97 5 12037 Continue RIH w/BHA #5. Drill horizontal hole from 11,411 - 11,556 FT. Short trip to window and check depth at RA tag. Add 1.5'. Drill to 11729'. Short trip to window. Displace used FIo Pro with new mud. Drill to 11859'. Short trip to window. Tie into RA marker-add 14.0'. Drill to 12037'. Short trip to window. 5/2/97 6 12303 Tie-in to GR marker-add 7.0'. Drill horizontal hole in Zone 1, from 12037 - 12081 ft BKB. Short trip to window. Tie-in with RA tag. RIH and drill horizontal hole from 12081 - 12256 fl BKB. Short trip to window. RIH and drill Horizontal hole in Zone 1 from 12256 - 12287'. Geology determined we have enough clean sand and called well at TD. Short trip to window. Tie-in with GR at PA. Add 16.0'. RIH to finish short trip. Set down at 11730' and work by with some effort. Set down at 11927' and work to 11945'. Unable to continue RIH. BHA was hanging up in hot shales (no motor work). POOH to lay down drilling BHA. Tie in, add 7.3', flag CT, POOH. RIH w/BHA #6 (motor and bit). Correct depth at flag. RIH to TD at '12303'. POOH for liner. LD BHA. 5/3/96 7 123O3 RU to run liner. Run 81 jts of 2 7/8", STL, 6.16# liner with TIW float equipment and Baker GS running sleeve. Set liner in slips and run 1 ¼" CSH workstring with 2" TIW stinger. Deploy liner with Baker CTLRT on CT. RIH with liner on CT to 10900' and set down at 10890'. Work to 10900' and unable to get deeper. POOH w/liner and running tools. LD Baker CTLRT and sleeve. Standback CS Hydril workstring (wet). 5/4/97 8 Finish stand back workstring. Pull 2 7/8" liner and stand back in doubles. Remove excess turbolizers, leave one per Jt. on Jts. #38 - 65. Found 2 turbolizers badly bent from POOH. RIH with 3.69" bit, 3.65" string reamer on tandem motor. RIH thru Merla tubing patch, OK. RIH and set down at window, ream in hole and stalled at 10,887, 10,927, 11,300, 11,370, 11,415, 11703, and 11689'. Packing off, pulling tite (swelling clay). Backream from 11696' to window while waiting on mud materials to weight up. RIH from 10750' and set down on top and bottom of whipstock. Ream in hole while weighting up to 9.8 ppg. Ream tite hole from 11698-765' and backream until clean. Ream rite hole from 11890-11911'. No motor work, no progress. Backream trip to window. 5/5/97 9 Finish backream trip to window. Ream in hole to max depth of 11948 ft. POOH. Change out bit and remove reamer. RIH with BHA #9. One of the four reel drive pins broke at a weld while RIH at 4400 ft. Secure reel and call DS welders. Repaired borken drive pin and continue to RIH. Set down on window, correct depth. Ream open hole okay to 11942'. Ream thru shales to 12060' then RIH to TD. Lay high vis pill in open hole while POOH for liner. LD cleanout BHA. PU liner out of derrick and RIH. Land in BOP slips. PU CS Hydril wi TIW stinger and RIH in liner. Sting into seal bushing and space out. Install Baker liner sleeve and CTLRT. RIH wi 81 jts 2-7/8" 6.16# L-80 STL liner on CT to TD. Circ. 5/6/97 10 Pump ball, Released CTLRT, Check up wt. Liner is released. R/U Cementing trucks, Pump 25.4 bbls of 15.8 PPG, G cement and displace with dart and Flopro. Bump dart 1 bbl early, pull stinger out and flush liner. POOH to top of liner and WOC until 300 PSI compressive strength. RIH and flush liner to PBTD of 12,270 FT. Lay in 20 BBL of New Flopro and POOH to 9800 ft. Finish POOH and recover Flopro and to leave tubing full of seawater to 9000'. MU 762' of SOS 1-11/16" perfguns loaded with 4 spf. RIH on CS Hydril doubles. MU CTC and RIH w/perf guns on CT. 5/7/97 11 Continue RIH w/perfguns. Tag PBTD and correct CTD to 12,270 ft BKB. Position perfguns. Drop 5/8" steel ball. Fire guns and perforate 11,500 - 11,700, 11,760 - 11,900, 11,960 - 12,240 ft BKB. A total of 620 ft of perfs at 4 SPF. POOH. Freeze protect 5.5" tubing to 2000 ft and CT capacity with 50/50 MEOH. Layout SWS perf guns. Recover all guns. All shots fired. Close master and swab valves. Service CT injector head. N/D BOP Stack off of Swab valve. Moved off well. Rig Released at 2200 hours 516197. Move CTD Unit to G-03A 1E-18^EOW.×,, E-18 A END OF WELL SURVEYo ~'7' ~~ 6,3,97 5:06PM BP EXPLORATION ALASKA INC, END OF WELL SURVEY REPORT FOR THE E-18A SIDETRACK JUNE 3, 1997 i i VERTICAL SECTION USED I! * 193.46° RELATIVE TO TRUE NORTH NOTE I i i I GRID N/S AND EAN OFFSETS ALSO GRID ASP X AN~ Y ARE R LATIVE TO GRID NORTH I i i: OFFSETS ARE CALCULATED TO GRID AND TRUE NORTH AS INDICATED GRID CONVERGENCE { ! !: 1.26° I i i I ~REPARED BY: ] i DRILEX , i I I DATES: i i . I:APRIL 28, 1997 i i I ] DIRECTIONAL CO. I i i: DRILEX SYSTEMS, INC. ! { II I MWD CO. I ' i I: SPERRY SUN i ! ! I I! deg deg ft flJ N/S! E/-W deg/100 deg/100 deg/100 ~ I ~'W 10780.00i I T~e~n 35.20 183.3~ 85~5.6oI -11.30-5309.40i -109.00 0.00 0.00 0.00 7.80 5969901.001 664495.00 ,:0~' 10788.0o 37.60 183.36 8602.201 -6.70,-5314.20i 7.60 5969896.50 664494.80 -5309.90 t _ -10~.301 30.00 0.00~ 30.00-5314.60I __ I 10831.00)43.40! t86.26 8634.90{ 20.90i-5342.00i -111.70 13.50 6.70 14.20 -5342.501 5.90 5969868.501 664493.10 I 10~94.00i! [ 52.20,1 1~°'981' 8677.30i_ 67.40 -5387.901i -119.4011 14.501 2.10 14.60-5388.50 -0.90 5969822.50i 664486.30 I 8727.301 -140.90] 6.30l 14.10 -5456.70 -20.90 5969754.50 664466.30 I 10981.00i 57.40 203.76 138.20i -5455.60i 13.30 11010.00i 59.10 212.26 8742.50i 162.10i .-5477.301 -152.501 5.90 29.30 25.60 -5478.70 -32.00 5969732.50 664455.20 111039.001 59-701 216.26i 8757.30! 185.40i-5497.90i -166.501 2.10 13.80 12.10ij -5499.601 -45.6O 5969711.50i 664441.60 11076.00 59.30 221.861 8776.101 214.10/ -5522.701 -186.60 -1.10 15.10 13.10i -5524.80 -65.101 5969686.50/ 664422.10 i 11100.00 58.50 226.06 8788.501 231.801 .-5537.501 -200.90 -3.301 17.50 15.30 -5539.90 -79.00 5969671.50J 664408.20 _ i 11129-00i 56.401 231.26 8804.101 251.801-5553.6Oi -219.20 -7.20 17.90 16.80 -5556.40 -97.00 5969655.00{ 664390.20! i 11165.00i58.60/ 226.86 8823.501 276.50!-5573.50i -242.10 6.10 -12.20 12.00{ -5576.80 -119.50 5969634.50 664367.70 I 11191'00i 61'901` 223.06[ 8836'40i' 295'7011 '5589'50i '258'001 12.70, -14.60 17.90 -5593.20 -135.00 5969618.00i 664352.10 - i 11226.00I 65.30[ 217.86 6851.901 323.60-5613.30[ -27830 9.70! -14.90 16.50 -561~.50 -154.80 5969593.50[ 664332.30 - I 11253.00i 68.30[ 213.261 8862.601 346.6o/-5633.501 -2921801 11.10] -17.00 19.20 -5637.90 -168.80 5969573.00i 664318.30 111284.00 72.t0 209.06 6873.101 374.401-5858.501 -307.80 12.30 -13.50 17.70 -5663.20 -183.30 5969547.50 664303.80 i 1131o.oo 76.60 206.46 8880.10i 3,98.701-5880.601 -319.50 17.30 -10.00 19.80 -5685.60 -194.50 5969525.00 664292.60 i 11341.00 81.40i 204.~i 8886.oo 426.401-57~.10i -332.501 15.50 -6.80 16.90 -5713.40 -206.90 5969497.00 664280.20 11371.00i ~.101 2o2.26t 88~.aol 457.80/-5735.50 -344.30 15.701 -7.00 17.10[ -5741.00 -218.10 5969469.50i 664269.00 11401.001 89.60i 199.56i 8890.40i 487.50i-5763.50] -355.00 11.701 -9.00 14.70] -5769.20 -228.20 5969441.50' 664258.90 ' -364.40 5.70 -5796.901 -236.90 5969414.00 664250.20 11~.001 90.00~ 197.96, 8890.50i 516.40t-~90.90i 1.40/ -5.50 196.061 -5820.60i -373.40 11461.00) 91.008890.20i 3.201 -6.10 690~ -245.30 547.30i -5826.70 5969384.00 664241.80 t 11492.00i 92.20 194.861 8889.301 578.30i-5850.501 -381.70) 3.90 -3.90 5.50) -5856.80 -252.90 5969354.00 664234.10 ~ . ! i ! i ,, i / I 1901661 540i -5884.10i -259.005969326.50 664228.00 11520.001 93.70i 19286 6887.90l 606.30!-6877.60l -388.40 -7.10 8.90 11553.00l 94.90/ 8~5.40l 639.101 -5909.80( .-395.10 3160 -6.70! 7.60 -5916.4o] -265.00 5969294.00 664222.00 11680.00) 93.40 188.461 8883.501 666.001-5936.40i -399.6O -5.60 -6.10. 9.80 -5943.10] -268.90 5969267.50 664218.10 -- 11617.00i 94.10 186.36 8881.10~ 702.701 -5973.001 -404.30 1.90 -5.70; 6.00 -5979.80i -272.90 5969231.00 664214.20 ! 11640'00I 94'50i 184.26 8879.30 725.401 -5995.801 -406.40 1.70 -9.10 9.30 -6002.60 -274.50 5969208.00 664212.60 94.20 11672.00 183.96 8876.90 756.901 -6027.601 -408.70 -0.901 -0.90 1.30 -6034.50 -276.10 5969176.00 664211.00 I 11710.00 92.80 184.26 8874.601 794.30] .-6065.50i -411.50 -3.70 0.80 3.80: -6072.40 -278.00 5969138.00t 664209.10 !] 11729.001 91.20[ 184.661 8873.90t 813.10-6084.40i -412.90 -8.40 2.10 8.70 -6091.40 -279.0015969119.00i 664208.10 11761.~l 90.~{ 182.581 8873.60i 844.60 -6116.301 -414.90{ -3.70, -6.6O 7.60 -6123.30 -280.30 5969087.00)664206.80 11798.00 90.20 16O.061 8873.50] 86o.80!-6153.30i -415.80, 0.50t -6.80 6.80 -6160.30 -280.40 5969050.00l 664206.70 I 1-6194.30t -415.001 -5.60 -6201.30 11839.00) 92.101 177.76i 8872.701 920.40J 4.6OI 7.30 -278.70 5969009.00l 664208.40 i 11681.ooI 93.10! 177.561 8871.70i 941.6oi-6216.30)- -414.10i 4.501 -0.90 4.60 -6223.20 -277.30i5968987.00i 664209.80 - ( 11891.001 93.801 17496' 8869.90) 970.20i-6246.10~ -41220{ 2.30l -8.70 9.00l -6253.00 -274.70 5968957.00t 664212.40 111911.001. 93.50/ 174.26 8868.601 989.101-6266.00i, ' -410.30] ' J -1.501 -3.50 3.80 -6272.90 -272.40 5968937.00j 664214.70 ORIGINAL 2E-18AEOW-xls E-18 A END OF WELL SURVEY~ 6~97 5:06PM COMMENTS i. MDi inc. j Diri $$ DEPTHi V$1, TRUE TRUEI BuildI Turn DoglegI GRID i GRID1 ASP Yi ASP X 11998.00{ 90.20i 174.761 8866.20{ 1070.801 -6352.40i -400.30 -2.101 7.90/ 8.20 -6359.00 -260.50 5968851.001 664226.60 - 12036'00t 90.40 173.861 8866.40/ 1106.701-6390.20 -396.60 -2.401 -2.40/ 3.301 -6396.70 -255.90 5968813.50 664231.20 12069.001 173.06i 8866.50/ 1137.701 -6423.00 -392.80 -6453.701 -388.90 1.90 2. -6460.10 -:2461§5596-8750.50 i 6~4240.30 _ ~2~00.00 91.001 8~.10/ ~r~.701 , -1.901 ' , I ~19~.8° 12127.001 92.10 171.661 8865.40 -385.20 4.10 -3.00 5.00[ -6486.70 -242.50 664244.60 12181.00i 93.60 172.86i 8862.40 1241.60 -~533.701 -376801 0.70 11.10 11.101 -6539.80 -233.00 5968671.00] 664254.10 12212.00i 91.70 t71.761 ~.00 1270.50-65~4.401 -372.60-6.40 -3.5O 7.1oI -6570.40 -228.20 5966640,50 664258.90 , 12246.001 ~0.20 .16~.C~I ~0.40 1301.901-~.00! -3~7.20 -4.40 ~.20 7.60 -6603,80 -222.00 5968607.00 664265.20 1353,301 -~Cx~3.70 -355.30 -4.40 -6.00 -6659.20 -208.90 596655'1.501 664278.30 TD ! 12303,001 87.70 166.26 [ 8~ .50 THESE SURVEYS ARE TRUE AND CORRECT TO THE BEST OF MY KNOWLEDGE. I I I BIMO HADIPUTRO ~31STRICT MANAGER - DRILEX SYSTEMS, INC. r . TONY KNOWLE$, GOVERNOR ALASI~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 17, 1997 Ted Stagg Coiled Tubing Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Prudhoe Bay Unit E-18A BP Exploration (Alaska) Inc. Permit No 97-69 Sur. Loc.: 1853'SNL. 501'WEL, Sec. 06, T11N, R14E, UM Btmhole Loc: 2741'SNL, 879'WEL, Sec. 07, T11N, R14E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. .. Chairman ~ - BY ORDER OF THE COMMISSION dlffenclosures CC~ Department of Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA ALASKA (:'--' AND GAS CONSERVATION CC ...... MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill Re-Entry 2. Name of Operator BP F~,nlnr~tion 3. Address P lO Rny 1.qRR1;2 Annhnr~n~. Al~.~k~ .q.q.~l.q-RR12 4. Location of well Et su rf~c~ 1853' SNL, 501' WEL, SEC. 06, T11N, R14E, UPM At top of productive inte rval 1738' SNL, 588' WEL, SEC. 07, T11N, R14E, UPM At total depth 2741'SNL, 879' WEL, Sec. 7, T11N, R14E 12. Distance to nearest 13. Distance to nearest w ell property line J ADL 028305 @ 2538 feet J no close approach feet /16. To be completed for d eviated wells I Kickoffdepth ~o,843 feet Maximum hole angle 9o o 18. Casing program size [] Redrill [~Jlb. Type of weJl. Exploratory [] Stratigraphic Test [] Development Oil [] [] DeepenI~J Service [] Development Gas [] Single Zone [] Multiple Zone [] Hole Casing 3 3/4" I 2 7/8" 5. Datum Elevation (DF or KB) KBE = 60.45 AMSL feet 6. Property Designation ~ 028304 7. Unit or property Name I Prudhoe Bay Unit 18. Well number E-18A 9. Approximate spud date 4/25/97 14. Number of acres in pr 2560 17. Anticipated pressure Maximum surface operty 10. Field and Pool Prudhoe Bay Field/Prudhoe Bay Pool 11. Type Bond (see 20 AAC 25.025) Number 2S 100302630-277 Amount $200,000.00 Top Bottom 15. Proposed depth (MD and TVD) 12,285' 8861' TVD feet (see 20 AAC 25.035 (e)(2) ) Specifications Weight 3330 psig At total depth (TVD) Setting Depth RR.gl3' /.'~glgR psig Quantity of cement 6.16# Grade Coupling L-80 ST-L Length 2390' 19. To be completed for R edrill, Re-entry, and Dee pen O Derations. Present well condition su mmary Plugs (measured) M D TVD 9895' 7858' M D TVD 12285' 8861' (include stage data) 95 c.f. 1997 Total depth: measured 11265 feet Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical BKB 9039 feet measured 11155 feet true vertical BKB 8954 feet Length Size Junk (measured) Cemented 110 20X30 8 c.v. 2657 13 3/8 3720 c.f. 10348 9 5/8 1580 c.f. tiff at 11155' MD (7/89) Measured depth True Verticaldepth BKB 139 139 2686 2681 10377 8316 1409 7 432 c.f. 9856-11265 7887-9039 measured 11080'-11176'4intervals 11000'-11080' sqzd true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirement 21. I hereby ce~~oing is true an d correct to the best of my knowledge Signed Title Coiled Tubing Drilling Engineer Date Commission Use Only Permit Number IAPI number JApprov~a~ date See cover letter ~,~'- ~ ~ j50- a ~-. '~ - ~ o ~' .5' ~7"'- O /i -~-/,-'~- / "/-~ ¢ "~ Ifor other requirements Conc~itions of approval Samples required [] Yes ,~No Mud log required []Yes '¢~/No Hydrogen sulfide measures [] No Required working pressure Other: by order of comm,ss,on t/r// Approved by me Date Form 10-401 Rev. 12-1~85 ~' Yes [] No Directional survey requir ed ,~ Yes forBOPE []2M; []3M;/ 1~5M; ~10M; ~15M; Ur~gmat ~gi~.uu ~ ~ ~'~'"/ul' Commissioner David W, Johnston Submit in yil:51icJ~te ' ALAF ..... OIL AND GAS CONSERVATION COMMIS .... .hN APPLICA'I FOR SUNDRY AP. ROVALS of Request: Abandon x Suspend __ Operation Shutdown ~ Re-enter suspended well __ Alter casing __ Repair well __ Plugging x Time extension __ Stimulate __ Change approved program Pull tubing __ Variance Pedorate ~ Other __ 2. Name of Operator BP Ex[Noration (Alaska) Inc. · .~ 5. Type of Well: 6. Datum elew .tion (DF or KB) Development x . KB = 60.45 AMSL Exploratory~ 7. Unit ~r Prol: rty name Stratigraphic __ Service__ "~rudh~e, B~ Unit ( 8' ~N9.~P-eell nutt'rr:)E-18 At top of productive interval ~-~ rmit num ~er 1738' SNL, 588'WEL, SEC. 07, T11N, R14E, UPM /' At effective d_e, pth /' 2110' SNL, 625 WEL. SEC. 07, T11N, R14E, UPM ~ At l,ota, depth, ~ 12. Present well condition summary ~ Total depth: measured 112~5 feet Plugs (measur ~eg,~ true vertical BKB 90~9 feet / / Effective depth: measured 11/~55 feet Junk- (meaCed) fill at 11155' MD (07/89) truevertical BKB 89~4 feet Casing Length Size~,, Ceme~ed Measured depth True vertical depth Structural .. ~ BKB Conductor 110 20x30 8 c.y. 139 139 Surface 2657 13 3/8 3720 c.f. 2686 2681 Intermediate 10348 9 5/8 1580 c.f. 10377 8316 3. Address P. O. Box 196612, Anchora.qe, Alaska 99519-6612 4. Location of well at surface 1853' SNL, 501' WEL, SEC. 06, T11N, R14E, UPM Production Liner 1409 7 432 c.f. 9856-11265 7887-9039 Perforation depth: measured I1080'-11115', 11123'-11141', Sqzd: 11000'-11037', 11043'-11056', 11149'-11165', 11171'-11176' true vertical subsea feet 11070'-11080' Tubing (size, grade, and measured depth) 5 1/2" L-80 to 9805' with 4 1/2" tailpipe to 9965' Packers and SSSV (type and measured depth) 9 5/8" Baker SAD packer at 9805'; 5 1/2" SSSV at 1996:'~lask~t 0il & ija. s Corls,. _ 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 4/15/97 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas~ Suspended~ Service 17. ! hereby certify that th_e foregoing is true and correct to the best of my knowledge. Signed ~__..~-~,/~/ Title Coiled Tubinc~ Drillin~ Enc~ineer ~ ,~,¢ FOR COMMISSION USE ONLY Date iConditions of approval: Notify Commission so representative may witness Plug integrity ~/' BOP Test Mechanical Integrity Test~ Subsequent form required 10- /,./07 Approved by order of the Commission "~._ Form 10-403 Rev 06/15/88 I Approval No.,~ ¢ "~,.-' ~ 7,.~ Commissioner Date ~'~"' / //~ SUBMIT IN TRI BPX E-18A Sidetrack Summary of Operations: The well is being sidetracked to reduce GOR and improve PI. This sidetrack will be conducted in two phases. Phase 1: Cut Window: Planned for 4/15/97. - The existing Ivishak perforations will be cement squeezed. - A whipstock will be set on ELine at approximately 10,837' MD. - A window will be cut in the 7" liner and 10 ft of formation will be drilled. Phase 2: Drill Directional Hole: Planned for 4/25/97. - Directional drilling coil tubing equipment will be rigged up and utilized to drill the directional hole as per attached plan to planned TD of 12,285' MD (8,861' TVDss). Mud Program: - Phase 1: Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 9895' MD and cemented with approx. 17 bbls. cement. The well will then be perforated with coil tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 10,843' MD (8648' TVD ss) - TD: 12,285' MD (8861' -I-VD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging - A Gamma Ray Icg will be run over all of the open hole section. are tentatively scheduled. Open hole Resistivity logs TREE: CIW 6-3/8" WELLHEAD: FMC ACTUATOR: OTIS E -18A Proposed Completion KB. ELEV = 60.45 BF. ELEV = 31.72 13-3/8", 72 CC/fi, L-80, BTRS KOP: 2000' MAX ANGLE: 53° @ 6800' FOC-- 5-1/2", 17CC/ft, L-80, IJ4S, IPC TUBING TUBING ID: 4.892" CAPACITY: 0.0232 BBL/FT MERLA TUBING PATCH 9652-9673 MD COVERS GLM STA. 1 ;3.75 IN. I.D. TOP OF I 7" LINER 9856 9-5/8", 47#/ft, L-80, BTRS 110377 2 718" cemented liner with cement top approx. 200 ft above the window. Whipstock PERFORATION SUMMARY REF: LOG: CBL 10-31-81 SIZE SPF INTERVAL (:~PEN/SQZ'D _>-5/8 8 11000-11033 SQZ'D 3-3/8 6 11033-11037 SQZ'D Z-5/8 8 11043-11047 SQZ'D 3-3/8 6 11047-11056 SQZ'D ~_-5/8 8 11070-11080 SQZ'D 3-3/8 4 11080-11115 OPEN 3-3/8 4 11123-11141 OPEN 3-3/8 8 11149-11165 OPEN 3-3/8 8 11171-11176 OPEN I SSSV LANDING 1996 I NIPPLE (OTIS "RQM"} {4.562" ID) GAS LIFT MANDRELS (CAMCO MMIGW/RK LATCH) N° MD(BKB) TVDss 12 2891 11 5119 10 6890 9 6996 8 7871 7 7974 6 8549 5 8656 4 9071 3 9177 2 9551 1 9655 PATCHED SLIDING SLEEVE BAKER "L" (4.562" MIN. ID) TUBING SEAL ASSY. 9-5/8" PACKER I (BAKER SAB)(3.813"1D) 4-1/2", 12.6#/ft, L-80 TAILPIPE 4-1/2 ....X" NIPPLE (OTIS) (3.813" ID) 4-1/2 ....XN" NIPPLE (OTIS) (3.725" ID) 4-1/2" TBG TAIL (BAKER) (ELMD) 9723 9805 9825 9882 9920 9965 9940 3.69" open hole 8900 Ve~ical Section Path Distance (Feet) E~18 200 400 600 800 1,000 1,200 1,400 1,600 1,800 2,000 2,200 2,400 Angle@K.O.= 36 deg MD:10843 DL 1 = 13 deg/100 GOC 63 deg ..... -8, -13N. DL 2= 14 deg/100 -8,885 90 895O 9O0O 12285 TD Tot Drld:1442 ft Marker Depths ~Orig Wellbore 13N I 8,8701ftTVD 8,8601 8,8601ft 'I-VD 8,8851 S,S8SlftTVO I Kick Off I 8,648 ft 'I-VD I 10,843 ft MD Deprtr ~KO 5,362 ft 10,843I 1442 I 12,2851 8,86~I MD KO Pt MD New Hole Total MD TVD TD Build Rt deg/100 MD (ft) 10.0 270 10.0 271 0.0 200 0.0 200 6.0 150 -6.0 150 1.0 1 0.0 200 Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 Curve 6 Curve 7 Curve 8 1,442 Drawn: 4/8/97 10:34 Plan Name: Case 1 E-18 Plan -1 -5,000 -5,200 -5,400 -5,600 ~ -5,800 ~ -6,ooo -6,200 -6,400 -6,600 -6,800 -7,000 )00 -800 -600 -400 -200 X distance from Sfc Loc 200 400 600 Well Name E-18 I CLOSURE Distance 6,178 ft I Az 182 deg I NEW HOLE Kick Off TD State Plane Surface Loc E/W(X) N/S (Y) 51 -5,347 -221 -6,174I 664,266 5,969,037 664,487 5,975,211 Az Chg MD (ft) 10.0 270 -10.0 271 6.0 200 -6.0 200 0.0 150 0.0 150 1.0 1 6.0 200 Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 Curve 6 Curve 7 Curve 8 1,442 Drawn: 4/8/97 10:34 Plan Name: Case 1 !~-18A CT Drilling & Completion BOP 22.5" 2 3/8" CT ~'11 Pack-Off 18"! 38" 7 t/16" Annular Blind/Shear 7 1/16" Pipe/Slip -~ 2 3/8" ~~ , , [~7 1/16" x 5,000 psi l/ii -~ 2 Pipe SWAB OR MASTER VALVE WELL PERMIT CHECKLISToo Y POOL lC t.<o GEOL AREA PROGRAM: expo dev~ redrl~servO wellbore segO ann disp para reqO o./oFP sHoRE o ,.J ADMINISTRATION ENGINEERING 1. Permit fee attached ................. . N 2. Lease number appropriate .............. '. N 3. Unique well name and number .............. N 4. Well located in a defined pool ............ N 5. Well located proper distance from drlg unit boundary. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N REMARKS 14. Conductor string provided ................ Y 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf cng.. Y 17. CMT vol adequate to tie-in long string to surf cng . . . Y 18. CMT will cover all known productive horizons ...... .~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. .Y N 22. Adequate wellbore separation proposed .......... ~) N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate .................... '~ N 26. BOPE press rating adequate; test to ~~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ .~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y /N 32. Seismic analysis of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... /. Y N 34. Contact name/phone for weekly progress reports . ./f.. . Y N [exploratory only] GEOL~G~Y: ENGINEERING: COMMISSION: BEW~~ DWJ~ Comments/Instructions: Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Aug 11 08:14:13 1997 Reel Header Service name ............. LISTPE Date ..................... 97/08/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/08/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UAUK~OWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MW-D/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MW RUN 1 AK-MW-70123 BUD JAHN WHITLOW/SEVI ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: AUG '1 3 1997 ~M~a Oil & Gas Co;ts. Anchora§e E-18A 500292065401 BP EXPLO~TION (ALAS~) , INC. SPERRY-S~ DRILLING SERVICES 11 -AUG- 97 MWD RUN 2 MWD RUN 3 AK-MW-70123 AK-MW-70123 BUD JAHN BUD JAHN WHITLOW/SEVI WHITLOW/SEVI 6 llN 14E 1853 501 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2686.0 9.625 10377.0 7.000 10789.0 3.690 12303.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUNS 1 THROUGH 3 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM D. DOUGLAS FOR TRACY LOVE OF BP EXPLORATION (ALASKA), INC. ON 5/15/97. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12303'MD, 8861'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10764 . 5 12276 . 0 ROP 10790 . 5 123 02 . 5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. BIT RUN NO MERGE TOP MERGE BASE 1 10794.0 10955.0 2 10955.0 11412.0 3 11412.0 12303.0 $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10764.5 12302.5 11533.5 3077 10764.5 GR 15.69 256.2 58.6409 3024 10764.5 ROP 13.18 2520 81.264 3025 10790.5 Last Reading 12302.5 12276 12302.5 First Reading For Entire File .......... 10764.5 Last Reading For Entire File ........... 12302.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10764.5 ROP 10790.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10930.0 10955.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHIO4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet 29 -APR- 97 MSC 1.32 NGP 5.74, DEP 2.041, S2 MEMORY 10955.0 10794.0 10955.0 35.2 55.9 TOOL NUMBER NGP SPC 315 3.690 3.7 FLO PRO 8.80 65.0 9.0 6.1 .000 .000 .000 .000 58.6 .3 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10764.5 10955 10859.8 382 10764.5 GR 17.93 256.2 33.1959 332 10764.5 ROP 13.18 2520 43.1166 330 10790.5 Last Reading 10955 10930 10955 First Reading For Entire File .......... 10764.5 Last Reading For Entire File ........... 10955 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10930.5 11384.5 ROP 10955.0 11411.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHlVIM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 29 -APR- 97 MSC 1.32 NGP 5.74, DEP 2.041, S2 MEMORY 11412.0 10955.0 11412.0 55.9 89.7 TOOL NUMBER NGP 233 3 .690 3.7 FLO PRO 8.90 68.0 9.0 5.5 .000 .000 .000 .000 60.9 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nseum Reading DEPT 10930.5 11411 11170.8 962 10930.5 GR 15.69 149.86 41.4416 909 10930.5 ROP 14.06 252 81.0482 913 10955 Last Reading 11411 11384.5 11411 First Reading For Entire File .......... 10930.5 Last Reading For Entire File ........... 11411 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11385.5 12276.0 ROP 11413.0 12302.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 01-MAY-97 MSC 1.32 NGP 5.74, DEP 2.041, S2 MEMORY TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMLTM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHIVIM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 123 03 . 0 11412.0 12303 . 0 87.7 94.9 TOOL NUMBER NGP SPC 315 3.690 3.7 FLO PRO 8.90 68.0 9.0 5.5 .000 .000 .000 .000 63 .3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 11385.5 12302.5 11844 1835 GR 26.22 221.05 72.1334 1782 ROP 18.82 491.83 88.5951 1780 First Reading 11385.5 11385.5 11413 Last Reading 12302.5 12276 12302.5 First Reading For Entire File .......... 11385.5 Last Reading For Entire File ........... 12302.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ...... ~ .............. 97/08/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/08/11 Origin ................... STS Reel Name ................ LrNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File