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Home My WebLink About197-153XHVZE 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: D GraYScale, halftones, pictures, graphs, charts- Pages: n Poor Quality Original- Pages: Other- Pages: DIGITAL DATA n Diskettes, No. Other, No/Type 'OVERSIZED .Logs of various kinds Other Complete COMMENTS: Scanned by: Beve,y MildredDarelha ~~w~ll TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /si STATE OF ALASKA -O~ ALASK~IL AND GAS CONSERVATION CO SION I~.~ Y i~~Y 2 2 2008 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~taska ~il ~ Gas Cans. Commission 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAAC2s.,os zoAAC2s.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Clas . ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba 4/17/2008 ~ 12. Permit to Drill Number 197-153 - 308-065 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/23/1997 13. API Number 50-029-20272-01-00 " 4a. Location of Well (Governmental Section): Surface: 2036' FNL 7' FWL SEC 7. Date T.D. Reached 01/06/1998 14. Well Name and Number: PBU 07-01A , , . 34, T11 N, R14E, UM Top of Productive Horizon: 3804' FNL, 1012' FWL, SEC. 34, T11 N, R14E, UM 8. KB (ft above MSL): 64'~ Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3150' FNL, 834' FEL, SEC. 33, T11 N, R14E, UM 9. Plug Back Depth (MD+ND) 11816 8994 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 676230 y- 5948888 Zone- ASP4 10. Total Depth (MD+TVD) 11823 8992 ~ 16. Property Designation: ADL 028309 ~ TPI: x- 677279 y- 5947145 Zone- ASP4 Total Depth: x- 675417 y- 5947756 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit el ctronic and rioted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD {-IDLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP' BOTTOM SIZE CEMENTING RECORD PULLED 2 94# H-4 Surface 110' S rface 110' 30" 300 sx Arc i s t 13-3/8" 72# N-80 Surface 2714' Surface 2714' 17-1/2" 5300sxArcticset 9-5/8" 47# N-80 t RS / S00-95 Surface 8670' Surface 8228' 12-1 /4" 1000 sx Class 'G' 7" 29# N-80 337' 9422' 7963' 8846' 8-1/2" 525 x la s'G' 3-1/2" x 2-7/8" 9.2# / 6.4# L-80 8188' 11823' 7841' 8992' 4-1/4" 102 sx Class 'G' 23. Open to production or inject ion? ^ Yes ®No 2a. TuewG RECORD tf Yes, list each interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2", 11.6# / 12.6#, 13Cr 8052' 7917' MD ND MD ND 5-U2", 17# x a-vz°, ,zs#, L-80 / N-80 8047 - 8255' 8132' y~ ~ -f 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~~ y ® p 7 R ~~' -- -~~` ~~~ ~ '"oo" DEPTH INTERVAL MD AMOUNT S~ KIND OF MATERIAL USED 9206' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PfeSS. Casing Press: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac uired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.07{7. . __,..--5 ,~~9~i ry d None ~ ~F~.. JUN 4 0 2008 ~,~ ~ 0 ~ s Form 10-407 Revised 02/2007 ~ ~ ~ ` ~, i /t ~NTINUED ON REVERSE SIDE ~ / c,, 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ 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 9106' 8579' None Zone 2 9494' 8904' Formation at Total Depth (Name): 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. O~/ / ' [ ~ Signed Terrie Hubble Title Drilling Technologist Date ~'7`f PBU 07-01A 197-153 308-065 Prepared ByNameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A rOVal N Drilling Engineer: Mel Rixse, 564-5620 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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. IreM 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the 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 Digital Well File • • Page 1 of 2 Well: 07-01 Well History Well Date Summary 07-01 A 3/24/2008 standby to rig up 07-01A 3/24/2008 *"* WELL S/I ON ARRIVAL *** (pre ctd /drifting for whipstock and cmt retainer) ATTEMPT TO DRIFT TBG WITH 2.68" CENT AND S-BAILER UNABLE TO PASS 1388' SLM (RECOVER HYDRATES) *** CONT ON WSR 03/25/08 *** 07-01A 3/25/2008 T/I/0=2400/375/375 Pump neat meoh down tbg. tbg pressured up after 4.4 bbls work plug to try and get more fluid down. Pumped a total of 17 bbls of neat and 16 bbls of crude to try and free TBG of hydrates. TBG pressured up after the 16 bbls of crude and did not lose any pressure. Bled TBG down to 1500 psi. ANNULUS CASING VALVES TAGGED AND LEFT OPEN ON DEPARTURE. FINAL WHP= 1500/375/375 07-01A 3/25/2008 T/I/O=SSV/350/300, Temp=Sl. Cycle LDS post PPPOT's (pre CTD). Cycled all LDS, all pins moved freely with no sign of bent or broken pins. Torqued to 500 Ib/ft. 07-01A 3/25/2008 ***CONTINUED FROM WSR 03/25/08*** LRS ATTEMPTING TO THAW ICE PLUG IN TBG. ***WELL TURNED OVER TO LRS, DSO NOTIFIED*** 07-01 A 3/26/2008 T/I/0=2500/350/350 Temp=S/I Hot oil TBG wash (CTD prep) Pumped 10 bbls Neat Job in progress continued on 03-27-08 FWHP's=2250/350/350 07-01A 3/27/2008 Continued from 03-26-08 T/I/0=2250/350/350 Temp=S/I Hot oil service (CTD prep) Pumped 10 bbls Neat followed by 72 bbls 180* crude down TBG FWHP's=1220/500/450 Annulus casing valves left open to gauges 07-01A 3/28/2008 *** WELL S/I ON ARRIVAL *** (pre ctd) DRIFTED TUBING TO 9700' SLM, W/ 2.68" CENT, S.BAILER, BAILER EMPTY 625" T Cc~ 9415' SLM W/ 15' 3 . *** LEFT WELL SHUT IN, NOTIFIED PAD OP ON DEPARTURE*** 07-O1A 3/31/2008 INITIAL WHP 2400/380/360 RU AND RIH TO SET A WHIPSTOCK WITH A LOW SIDE ORIENTATION (+/-15 DEG). REACHED SET DEPTH, PREPARE TO SET WHIPSTOCK. *****CONTINUE AWGRS ON 1-APR-08***** 07-01A 3/31/2008 INITIAL WHP 2400/380/360 RU AND RIH TO SET A WHIPSTOCK WITH A LOW SIDE ORIENTATION (+/-15 DEG). REACHED SET DEPTH, PREPARE TO SET WHIPSTOCK. *****CONTINUE AWGRS ON 1-APR-OS***** 07-01A 3/31/2008 (PRESSURE TEST TREE) ***JOB COMPLETE*** T/I/0= 2450/400/400. Pressure tested tree for upcoming CTD work. Had face to face with the pad operator and signed permit. Tested swab, SSV, wing, and master to 5000 psi. FAILED. Notified operator job was complete, signed off permit and left location. NOTE: GREASE CREW TO SERVICE TREE AND RETEST. 07-01A 4/1/2008 *****CONTINUE AWGRS FROM 31-MAR-08***** INITIAL WHP 2400/380/360 SET BAKER 3-3/16" MONOBORE WHIPSTOCK W/ 033 PERMANENT PACKER AT LOW SIDE ORIENTATION (+/-15 DEG). TOP OF WHIPSTOCK SET AT 9206'. RA TAG IN WHIPSTOCK AT 9211'. DID NOT TAG TD. LEFT WELL LEFT SI. ***JOB COMPLETED*** FINAL WHP 2400/380/360 07-01A 4/3/2008 SVC tree with Clare 501 pre nordic. 07-O1A 4/4/2008 T/I/O = 2450/400/400. Temp SI. Bleed TBG <500 psi & shoot TBG FL pre MITT (CTD prep). TBG FL ~ 8065' (187 bbls). Bled TP from 2450 psi to 250 psi in 2.5 hours. IA & OA unchanged during bleed. Monitored for 30 min. No change. Final WHP's = 250/400/400. 07-01A 4/5/2008 Swab presher locked Swab / Unpresher locked swab & open for DHD. 07-01A 4/5/2008 T/I/0=400/370/370 MITT P e CTD) Pumped 145.4 bbls crude down Tbg to pressure up to 2500 psi. Tbg lost 110 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 150 psi over 30 min. PASSED Bled Tbg (4.7 bbls). ***Wellhead valves checked for position and tag hung upon departure*** FWP's=400/370/370 http://digitalwellfile.bpweb.bp.com/WI Info/Reports/ReportViewer.aspx 5/13/2008 Digital Well File • • Page 2 of 2 07-01 A 4/6/2008 Service tree with Clare 501 for Pre CTD. Pressure test tree 4600 PSI pre CTD 07-01A 4/13/2008 T/I/0=400/390/390. Temp=Sl. Bleed WHPs to 0 psi pre-BPV (CTD prep). TBG FL ~ surface, IA, OA FL's near surface. Bled TBGP to bleed tank from 400 psi to 0 psi in 20 min. Bled IAP to bleed tank from 390 psi to 5 psi in 4 hours. Bled OAP to bleed tank from 390 psi to 5 psi in 3 hours. Bled both IA & OA together for 1 hour C~3 5 psi with no decrease in pressures. TBG pressure increased 5 psi. Bleed off TBG pressure in 15 seconds. Monitored 30 minutes. IAP increased 10 psi and OAP increased 15 psi. Continued bleeding IAP and OAP to 0+ psi in 4 hours. Monitored 30 minutes. No change in pressures. ~~ ~~ Final WHPs=O/0+/0+ 07-01A 4/14/2008 T/I/O=0/200/O.,Set 5 1/8" Gray BPV thru tree, pre rig. 1-2' ext used. Tag at 108". 07-01 B 4/17/2008 T/I/O = 0/0/0 Pull 5 1/8" GRAY BPV on Nordic 1 07-01 B 4/25/2008 T/I/0=0/0/0. SET 5 1/8 GRAY BPV C~3 90" 3X5 EXT USED. NO PROBLEMS. COMPLETION, NORDIC 1. 07-016 4/28/2008 T/I/0=0/O/O. Pulled 5 1/8 Gray BPV C~ 108" 1x2' ext used, no problems, Post rig. (NORDIC 1 ) 07-01 B 4/28/2008 ***WELL S/I ON ARRIVAL*** (post ctd/tree c/o ) DRIFT TO SSSV NIPPLE AT 2205' MD WITH 3.84" CENT. CCT 'Z Ai 4" YY DI I I(_ DT 77l1~' ~Af1 ****WELL LEFT S/I, PAD FIED**** 150 PSI IN THE FIRST 15 MIN AND 25 PSI IN THE r°~~ 1 b~~ 07-01 B 4/30/2008 T/I/0= 0/80/180. Temp= SI. Bleed TBG < 200 psi, IA & OA to 0 psi (pre tree c/o). Wellhouse removed, flowline & A/L disconnected. IA FL ~ 228' (10 bbls). Bled IAP from 80 to psi to 0 psi in 45 mins. OA FL 60' (3 bbls). Bled OAP from 180 psi to 85 psi in 1.5 hours (fluid & gas). Out of time, will continue tomorrow. Final WHPs= 0/0+/85. 07-01 B 4/30/2008 set 5" Gray BPV for tree work. 07-01 B 4/30/2008 T/I/0=200/90/140. Temp=Sl. Bleed TP to 200 psi, IA & OA to 0 psi. (Pre-tree C/O). Well head Tech's setting BPV in the tree upon arrival. TBG is fluid packed. 07-01 B 4/30/2008 T/I/0=200/90/140 (TREE REPLACEMENT) Pre iob evaluation completed. Will replace Grev 5 1/8" x 7 1/16" with a NEW FMC Model 120 5 1/8" x 7 1/16" with a Baker actuator. Job is Schedualed for the 07-01 B 5/1/2008 T/I/0=0/50/85. Temp SI. Bleed TBG <200 psi, IA & OA to 0 psi (pre tree c/o). No wellhouse or flowlines in place. Bled OAP from 85 psi to 0 psi in 20 min. Bled IAP from 50 psi to 0 psi in 20 min. Monitored for 10 min. No change. Final WHP's = 0/0/0. 07-01 B 512!2008 (Tree Replacement PROACTIVE) Installed Tree ***Job Complete*** Removed Gray Model "C' (5 1/8" x 7 1/16") w/Axelson, installed New FMC 5 1/8" x 7 1/16" Model 120 w/ Baker Actuator 07-01 B 5/2/2008 T/I/O = SI/0/0 Tree changeout proactive. Remove 5x7 Gray tree and replaced with new FMC model 120 5x7 tree. ***NOTE: Need to set a dart and pressure test.*** *** No flowline attached to tree*** Job is not complete. 07-016 5/11/2008 T/I/O 0/300/100 Pulled 5 1/8" Gray K BPV #604 X108" 1-2" ext. used...no problems. 07-01 B 5/11/2008 T/I/O = 0/300/100 Set 5 1/8 "Gray tree test dart, pressure tested tree to 5000 P.S.I...no pressure Ioss.Attempted to pull 5 1/8" Gray K BPV, during the equalizing process ,pressure on the BPV from above was increased to 3800 P.S.I...but never equalized..... rigged down. 07-01 B 5/12/2008 ***WELL S/I ON ARRIVAL*** (post ctd /tree c/o) EQUALIZE & PULL 4-1/2" XX ~ 2188' SLM PULL 1.5" DGLV'S (RK) FROM STA'S 3 & 4 SET 1.5" GENERIC DESIGN (RK) PULL M!r CATCHER SUB **** RETURN WELL TO DSO, WELL LEFT S/I **** Print Date: 5/13/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx 5/13/2008 • BP EXPLORATION Page 1 of 9 Operations Summary Report Legal Well Name: 07-01 Common Well Name: 07-01 Spud Date: 6/5/1978 Event Name: REENTER+COMPLETE Start: 3/26/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 4/26/2008 Rig Name: NORDIC 1 Rig Number: Date f From - To Hours Task Code NPT Phase Description of Operations 4(15/2008 12:00 - 14:00 2.00 MOB N RREP PRE Remove drive motor and blind off same. 14:00 - 00:00 10.00 MOB N WAIT PRE Still on DS 15-256. Wait on wind to diminish, 30+ mph wind directly toward cellar doors. 4/16/2008 00:00 - 07:30 7.50 MOB N WAIT PRE Wait on wind to open cellar doors 07:30 - 08:00 0.50 MOB P PRE PJSM for moving rig off well & to DS7. 08:00 - 11:00 3.00 MOB P PRE Move rig to DS 7. 11:00 - 13:15 2.25 MOB P PRE Spot matting boards, PJSM & Remove tree cap (due to tree height) .PJSM & Spot rig over well. Accept rig at 11:00 hours- 13:15 - 15:30 2.25 BOPSU P PRE NU BOP. 15:30 - 22:50 7.33 BOPSU P PRE Test BOP. AOGCC rep John Crisp waived witnessing BOP test. 22:50.23:40 0.83 BOPSU P PRE Blind rams not holding pressure. Conduct PJSM for BOP maintenance. Open doors on top set of BOPs to access blind ram bodies. 23:40 - 00:00 0.33 BOPSU P PRE Re-test blind rams, holding good test. Rig up to PT both TIW valves. Test low and high level H2S and LEL alarms, good test. 4/17/2008 00:00 - 02:00 2.00 BOPSU P PRE Lift BPV lubricator to rig floor. Pull BPV. No ressure under it. Close master valve. 02:00 - 02:30 0.50 BOPSU P PRE Break down BPV equipment and send it down beaver slide. Bring BTT motor and window mill onto rig floor. 02:30 - 03:10 0.67 BOPSU P PRE Line up valves to pressure test inner valve. Test 400 / 3,800 psi, good. 03:10 - 03:25 0.25 STWHIP P WEXIT SAFETY MEETING. Discuss procedures, hazards and mitigations for picking up window milling BHA. 03:25 - 03:50 0.42 STWHIP P WEXIT PU BHA #1 - 2.74" Diamond Speed Mill, 2.73" Diamond Reamer, 2.13" Extreme "X" Mud Motor, Circ Sub with 1/2" Ball Seat, Disconnect with 5/8" Ball Seat, 2 jts. of 2-1/16" CSH, Check Valve and Weld on Connector. 03:50 - 05:40 1.83 STWHIP P WEXIT RIH with BHA #1, take crude returns outside to flowback tank. Weight check at 9,000 ft is 29 Klbs. Dry tag whipstock at 9,205 ft, tag a second time at the same spot. Pick up 10 ft and swap well over to 2# biozan. 05:40 - 07:20 1.67 STWHIP P WEXIT Park at 9,195 ft and circulate well to biozan. Getting gas returns, hold 300 psi choke pressure until biozan at surface. C~ ~, ~1°~ 07:20 - 11:30 4.17 STWHIP P WEXIT Tag and flag pipe at 9208.1'. Time Milling window 1ft/hr. ' U7-0~~ 1.76/1.78 bpm ~ 2880 psi. 2380 FS. Mill to 9212 . 11:30 - 14:00 2.50 STWHIP P WEXIT Continue to time mill 1fUhr. Stall at 9214.1 Gas in returns. 1.75/1.74 ~ 2500 psi FS. PU. 14:00 - 15:00 1.00 STWHIP P WEXIT Ream to 9214.1 seen motor work at 9213. 15:00 - 15:30 0.50 STWHIP P WEXIT Mill 9214.1. Milling with little MW 1.61/1.61 BPM ~ 2350 psi.making 5 fUhr min weight on bit .3-.4K. 15:30 - 17:30 2.00 STWHIP P WEXIT Mill rat hole to 9225.1. 1.61/1.61 bpm X2450 psi , 8 fpm..5K WOB. 17:30 - 18:30 1.00 STWHIP P WEXIT Ream window and dry tag same. Clean pass up and down through window with pumps off. 18:30 - 20:00 1.50 STWHIP P WEXIT POOH. Pump 1.7 bpm while POOH. 20:00 - 20:15 0.25 STWHIP P WEXIT Tag stripper. SAFETY MEETING. Discuss procedures, hazards and Printed: 5/15/2008 9:22:22 AM TREY= FMC 5-1/8 x 7-1/16 WELLHEAD = GRAY ACTUATOR= BAKER"C" KB. ELEV = 64' BF. ELEV = ? KOP = 4900' Max Angle = 101° @ 10543' Datum MD = 9423' Datum TVD = 8800' SS DRLG DRAFT 9-5/s" Foc 2335' 9-s/e" Foc 2451' 13-3/8" CSG, 72#, N-80 BUTT, ID = 12.347" Minimum ID = 2.375" @ 10005' TOP 2-7/8" TBG TOP OF 2-3.0" LNR 7g$1' TOP OF CEMENT --~ 7981' 4-1/2" TBG, 11.6#, 13-CR VAM TOP, .0152 bpf, ID = 3.958" TUBING STUB 5-1/2" TBG, 17#, L-80..0232 bpf, ID = 4.892" ~-{ 8144' TOP OF3-1/2" LNR 8138' elm 4-1/2" TBG, 12.6#, N-80, .0152 bpf, ID = 3.958" 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" TOP OF 7" LNR 9-5/8" CSG, 47#, N-80/ S-95 BTC, ID = 8.681" TOP OF CEMENT PERFORATION SUMMARY REF LOG: BRCS ON 07/04/78 ANGLEAT TOP PERF: 95° @ 9870' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 6 9870 - 10000 O 04/25/08 1-11/16" 6 10050 - 10430 O 04/25/08 1-11/16" 6 10640 - 10960 O 04/25/08 07-01 B 7" LNR, 29#, N-80 BUTT, .0371 bpf. ID = 6.184" ~ 9575' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.8" 2-7/8" LNR, 6.4#, L-80, .0058 bpf, ID = 2.441" NOTES: ***CHROMETBG"** 22' ~ 5-112" X 4-1/2" XO, ID = 3.958" 205' 4-1 /2" HES X NIP, ID = 3.813" GA S LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3243 3243 1 MMG DMY RK 0 07/10/07 3 5507 5481 22 MMG DMY RK 0 07110!07 2 6678 6493 30 MMG DMY RK 0 02/02/06 1 7808 7510 25 MMG DMY RK 0 02/02/06 7$$7' 4-1/2" HES X NIP, ID = 3.813" 7917' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.870" 7950' 4-1/2" HES X NIP, ID = 3.813" 8020' 4-1/2" XN NIP, ID= 3.725" 8041' 4-1/2" X 5-1/2" XO.. ID = 3.958" 8047' S-1/2" CAMCO DB-6 NIP. ID = 4.562" 8052' 9-518" X 5-1 /2" UNIQUE OV ERSHOT 8083' 5-1/2" BKR SBR ASSY, ID = ? 8132' 9-5/8" X 5-1/2" BKR SAB PKR, ID = ? 8138' 7" MILLOUT EXTENSION, ID = ? 8144' 6-5/8" X 4-1/2" XO, ID = 3.958" 8188' 3-1/2" BKR DEPLOY SLV, ID = 3.000" 8199' 4-1/2" CAMCO DB-6 NIP, ID = 3.813" $~ 256, 1~4-1/2" TUBING TAIL, ID = 3.958" 8228' ELMD TT LOGGED 07/29!89 8287' 3-1/2" X 3-3/16" XO, ID = 2.79" 8337' 9-5/8" X 7" BOT TIEBK SLV w /LNR HGR, ID = ? 2-318" t~rome crrt'ed and perfed 11025' ' -_~ 1 9206' Mech Packer VJS w R/A tags 7" MILLOUT WINDOW (07-01A) 9423' - 9429' 9942' DAMAGED LNR (REF: MILLING OPER 08/04/07) 9943' FISH- 2-1/2" CIBPDEBRIS (08104/07) 10005' 3-3/16" X 2-718" XO, ID = 2.375" ~ 11816' PBTD, MILLED „-~ OUT 08/19/98 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/78 ROWAN 35 ORIGINAL COMPLETION 01/15/98 N4/3S SIDETRACK (07-01A) 02/07/06 DOYON 16 RWO 04/26/OS NORDICI CTD SIDETRACK 05/05/08 JO/TLH TREE C/O PRUDHOE BAY UNff WELL: 07-01 B PERMIT No: 2080380 AFI No: 50-029-20272-02 SEC 34, T11 N, R14E, 7' FWL & 2037' FNL BP Exploration (Alaska) Page 1 of ~h ~~~ Maunder, Thomas E (DOA) From: Rixse, Mel G [Mel.Rixse@bp.com] Sent: Friday, February 29, 2008 11:24 AM To: Maunder, Thomas E (DOA) Subject: RE: 07-01A (197-153)-again Tom, Here is the revised abandonment procedure for 07-01A. I have recent MIT -OA and MIT-IA. There is an MIT- T after the cement abandonment. Pre-Rig Work: 1. O Functions test LDS 2. O P7 Master & Swab valve to 4000 psi. Drawdown test MV, SV, & SSSV to 0 psi 3. S Drift to 9360'MD for Baker cement retainer & Baker WS set in 3-3/16" liner @ 9206'MD. 4. E Set Baker Cement Retainer at ~ 9332'MD 5. C Stab into retainer, shut in welt, test for infectivity, if infectivity is high, squeeze flo-pro to provide reduced infectivity. 6. C Down squeeze generous amount ~ 20 bbls of 15.8#/gal cement through retainer until lock up 7. C Unsting from cement retainer, lay in 1 bbl cement above retainer, cieanout to 9280' MD w/ 2 ppb Biozan 8. O Wait for 2500 psi UCA on cement, MIT - T 9. E Drift for whipstock 10. E Set Whipstock (TOWS 9206' MD) 11. S With slickline pump bailer, lay in ~1 bbl 15.8#/gal cement above whipstock, TOC no greater than 9186' MD. 12. O Set BPV 13. O Bleed production flow lines and GL lines down to zero and blind flange 14. O Remove wellhouse, level pad. Let me know if this is satisfactory. Thanks. Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (307)564-5620 -Office (907)223-3605 - CeH ~~N APR ~ ~ 20Q8 Fromr. -Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Tues February 26, 2008 4:18 PM To: Rixse, Mel G Subject: RE: 07-01A (1 3)--again Mel, Will there be any pressure test of the wellb rior to m' ' e new window? If so, the procedure does not indicate so. Tom Maunder, PEJ AOGCG From: Maunder, Sent: Tue , To: R' ,Mel G E (DOA) 26, 2008 4:15 PM 2/29/2008 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, February 27, 2008 8:12 AM To: Rixse, Mel G Subject: RE: 07-01A (197-153)--again That would be fine. From: Rixse, Mel G [mailto:Mel.Rixse@bp.rnm] Sent: Wednesday, February 27, 2008 7:18 AM To: Maunder, Thomas E (DOA) Subject: RE: 07-OlA (197-153)--again Tom, Yes there will be a pressure test and a cement packer is planned for the 3-3116" X 7". The abandonment has become more complex due to corrosion in the 3-3/16" liner. Can 1 send a revised procedure to you electronically? Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (907)564-5620 -Office (907)223-3605 -Cell From; Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, February 26, 2008 4:18 PM To: Rixse, Mel G Subject: RE: 07-O1A (197-153)--again Mel, Will there be any pressure test of the wellbore prior to milling the new window? If so, the procedure does not indicate so. Tom Maunder, PE] AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, February 26, 2008 4:15 PM To: Rixse, Mel G Subject: 07-OlA (197-153) Mel, I am reviewing the sundry. One question, was the squeeze proposed in June of last year accomplished. If it was I gather it was not successful based on the scope of your work proposal. Thanks, Tom Maunder, PE AOGCC 4/20/2008 • °~ f`"~ C"" ~..,', ~,.~ fir,-._~ a .3 r~ __ ~~ .,.... )..t L~ ~ { SAR .~ ~„ ~ I~.. AH PAL/N, GOVERNOR CUNSERQ~A7IOH ~ ~~+ I ~ 333 W. 7th AVENUE, SUITE 100 •~ AAAiiiiii 1.~~••~~•~~~111~~•iiliii----777 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mel Rixse CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 ~.. ~ FFg ~ ~ ~~~ Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-OlA Sundry Number: 308-065 Dear Mr. Rixse: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (90'7) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely ff it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day ff the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. / ~ Chair DATED this2~ day of February, 2008 Encl. ~~~-153 ,r"~~~`' STATE OF ALASKA ~ ~ ~~~~' ~® ~LA~ IL AND x O GAS CONSERVATION COM~ION ~ APPLICATI N F ~~ FEB ~ O OR SUNDRY APPROVAL ~a-~, 20 AAC 25.280 Sic Oil ~ Ga ~. rtt(ssr~n 1. Type of Request: ®Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension QCICIIOCB~}B~` _ Y ^ Alter Casing ^ Repair Wefl ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 197-153 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20272-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 07-01A- Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028309- 64' - Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11823 8992 11816 8994 None 9943 asin Len th Size MD TVD Burst Colla se Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2714' 13-3/8" 2714' 2714' 4930 2670 Intermediate 8670' 9-5/8" 8670' 8228' 6870 4760 Production Liner 1085' 7" 8337' - 9422' 7963' - 8846' 8160 7020 Liner 3635' 3-1/2" x 2-7/8" 8188' - 11823' 7841' - 8992' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9610' - 11798' 8979' - 9000' 5-1/2" x 4-1/2" x 5-1/2" x 4-1/2" 13Cr / L-80 / N-80 8255' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SAB' packer; Packers and SSSV MD (ft): 8132 ; 9-5/8" x 4-1/2" Baker'S-3' packer 7917' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: March 31, 2008 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mel Rixse, 564-5620 Printed Name Mel Rixse Title CT Drilling Engineer ,~% Prepared By Name/Number: Signature Phone 564-5620 Dates "~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~t.7es`o ri~+~ tr~v v-` ~~ ~ ~~~ Subsequent Form Required: ~D~ 2 2~ A roved B COMMISSIONER THE COMMISSION Date Form 10-403 ~Re~ed 06f~006 Submit In Duplicate ~~~~ ~~~~ ~~ ~~~, ~ ~ ~~a~ 0 R I G I NA L • • To: Tom Maunder Petroleum Engineer (,~ Alaska Oil & Gas Conservation Commission u From: Mel Rixse CTD Engineer Date: February 14, 2008 Re: DS07-01 A Lateral Abandonment and new CTD Sidetrack Sundry Approval Request Sundry approval is requested for 07-01 A. Cement abandonment of the existing A lateral followed by a new coil tubing drilling sidetrack is proposed. The CTD side track will target a 77 acre drainage area in Zone 2A and Zone 2B1. An 8bbl cement abandonment plug will be squeezed past a whipstock placed at 9200' MD. The whipstock will be set in place for the new CTD sidetrack to follow. Cement volume for the squeeze is based on placing enough cement to fill the existing 805' of 3-3/16" liner volume below the whipstock. ~ ~, HISTORY: ~--~+ Sc~~ ~ c~~cv~~~'o'~~ ~l , S ~~~ `~ ~~-~ ~ ~~. Well 07-01A was drilled in late 1997 as a horizontal ~ne 2A producer. It be an production in February 1998 at 200 BOPD with a watercut of 75%. A total of 600' of Zone 2A perfs were initially shot. Well 07-O1A was nearing marginal GOR in early 2004 when it developed TxIA problems. In August 2004, a calliper log showed extensive damage in the lower quarter of the tubing. Because patching was not an option, a RWO was completed in February 2006 to install new 4-1/2" chrome tubing. In December 2006, aspin/temperature/pressure survey along with a history of high GOR/production that began abruptly in the beginning of 2004 suggested something had broken through in the 3-3/16" liner just outside of the 7" mill out window. A 12/23/06 calliper later confirmed that the 3-3/16" liner was shot, which was providing a straight conduit to gas above the GOC. REASON FOR SUNDRY AND SIDETRACK: 07-01 A currently has very a high GOR and no on time due to a corroded 3-3/16" liner and a severely damaged liner just outside the 7" casing. There are no non-rig intervention options to repair the corroded 3-3/16" liner. The well currently provides minimal value to the field. A cement abandonment plug is required to isolate the new lateral from the gas conduit provided by the corroded/damaged 3-3/16" production liner. The CTD sidetrack will exit the existing 3-3/16" & 7" liners in Zone 4. The well will drill to a TD of 11,350' MD and target reserves Zone 2A and Zone 261. A 2-3/8" liner will be run to TD with the top of liner placed just below the 4-1/2" x 9-5/8" packer placed at 7917' MD. The liner will be fully cemented then perforated in zones of pay. 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. Pre-Rig Work: 1. O Functions test LDS 2. O PT Master & Swab valve to 4000 psi. Drawdown test MV, SV, & SSSV to 0 psi 3. E Drift to 9300'MD for Baker 3-1/2" Monobore Whipstock. 4. E Set Whipstock (TOWS 9200' MD) ~~~ 5. C Test for infectivity 6. C Squeeze cement past whipstock. C,~(~p(~ct 7. O Set BPV ` 8. O Bleed production flow lines and GL lines down to zero and blind flange 9. O Remove wellhouse, level pad . Rig Sidetrack Operations: (Scheduled to begin on May 1, 2008) 1. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high 2. Pull BPV. 3. Mil12.74" window at 9,200'. Swap well to Flo-Pro. 4. Drill build/turn section with 3" bicenter bit, and land well. 5. Drill lateral section to 11,350' MD. 6. Run 2-3/8" to TD. Place liner top at 7975' MD 7. Pump 1-2-3/8" liner annular volume of 15.8 ppg cement. 8. Cleanout liner. 9. Run MCNUGR/CCL log 10. Test liner lap to 2000 psi 11. Perforate per geologist. 12. FP well to 2000' with diesel. 13. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 14. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design 4. RU tes separator, flow test well. el Rixse CTD Engineer • CC: Well File Sondra StewmanlTerrie Hubble = ~~ - BRAY GEN 2 '~ R = AX ~N 0 7 -01 A REV = 64' lEV = ? = 4900' Angle = J9 ~ 11763' 9-518" FOC 2335' m ~ _ 9445' m ND = 8800' SS 9-5/8" FOC 2451' 13-3/8° CSG, 72#, N-80 BUTT, to = 12.34T' 2714' Minimum ID = 2.375" ~ 10005' TOP 2-718" TBG 4-112" TBG, 11.6#, 13-CR VAM TOP, .0152 bpf, ID = 3.958" TUBING STUB 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" TOP OF3-1/2" LNR 81 1aa 1 8138' elm AFETY NOTES: """CHROME TBG'"'* - 22' 5-1/2" X 4-1/2" XO, ID = 3.958" 2205' 4-1/2" HES X NIP, ID = 3.813" GAS LIFTMANDRELS iT IVO ND DEV TYPE VLV LATCH PORT DATE 4 3243 3243 1 MMG DMY RK 0 07/10/07 3 5507 5481 22 MMG DMY RK 0 07/10/07 2 6678 6493 30 MMG DMY RK 0 02!02/06 1 7808 7510 25 MMG OMY RK 0 02/02/06 7887' 4-1/2" HES X NIP, ID = 3.813" 7917' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.870" 7950' 4-112" HES X NIP, ID = 3.813" 8020' 4-1/2" XN NIP, 10 = 3.725" 8041' 4-1/2" X 5-1 /2" XO, ID = 3.958" 8047' 5-1/2" CA MOO DB-6 NIP, ID = 4.562" 8052' 9-518" X 5-1 /2" UNIQUE OV ERSHOT 8083' 5-1/2" BKR SBR ASSY, ID = ? 8132' 9-5/8" X 5-1 /2" BKR SA B PKR, ID = ? 8138' T' MILLOUT EXTENSION, ID = ? 8144' 6-5/8" X 4-1 /2" XO, ID = 3.958" 8188' 3-1/2" BKR DEPLOY SLV, ID= 3.000" 8199' 4-1/2" CAMCO D&6 NIP, ID = 3.813" 41/2" TBG, 12.6#, N-80, .0152 bpf, ID = 3.958" 8156' J I 8258' 4-1/2" TUBING TAIL, ID = 3.958" 3-1/2" TBG, s.2#, t-80, .0087 bpf, ID = 2.ssz' 8287' l 8228' ELMD TT LOGGED 07/29/89 TOP OF T' LNR 8337' $2$7' 3-112" X 3-3115' XO, ID = 2.79" 8337' 9-5/8" X T' BOTTIEBKSLV w/LNR HGR, ID=? ~ 9-5/8" CSG, 47#, N-80/ S-95 BTC, ID = 8.681" ~ PERFORATION SUMMARY REF LOG: BHCS ON 07/04/78 ANGLEATTOP PERF: 55 ~ 9610' Note: Refer to Product~n DB for histor~al perf data SQE 5PF INTERVAL OpNSgz DATE 2" 6 9610 -9630 O 07/04/06 1-11 /15' 4 10270 - 10500 O 01 /10198 2" 4 10550 - 10800 O 12!12/00 2" 4 11000 - 11200 O 12/12/ 1-11/16" 4 11280-11851 O 01/10/98 2-1/8' 4 11760-11798 O 08/24/98 7" MILLOUT WINDOW (07-01A) 9423' - 9429' 9942' DAMAGED LNR (REF: MILLING OPER 08/04 9843' FISH- 2-112" CiBP DEBRG (08104/07) 10005' 3-3/16" X 2-7/8" XO, ID = 2.375" 3-3/18° LN2, 8.2M, L-80, .0078 bpf, D = 2.8" 10005 11816' PBTD, MILLED OUT 08/19/98 2-7/8" DATE REV BY COMMENTS DATE REV BY CONMFN'fS 07f18 ROWAN 35 OR1gNAL COMPLETION 05/17/06 JGANPJC RETRIEVE FISH ~ 871T 01!15/88 N4/3S SIDETRACK(07-01A) 07/04/06 RRD/PAG WEATHERFORD IBP, PERF 02/07/06 DOYON 18 RWO 02/28/07 008/TLH PBTD MILLED 8/1998 02/09/06 RWL/PJC ORLG DRAFT CORRECTIONS 07!20/07 TEUPJC GLV CJO (07!10/07) 02/13/06 DTR/PAG GLV C!O (02/08/06) 08/04!07 DMS/PJC MILL CIBP/ FISW DAMAGED LN 03/30/06 JLM/TLH VERBAL GLV CORRECTION 6.4#, L-80, .00.58 bpf, ID = 2.441" 11823' PRUDHOE BAY UNIT WELL: 07-01A PERMIT No: 1971530 API No: 50-029-20272-01 SEC 34, T71 N, R14E, T FWL 8 203T FNL 9P Exploration (Alaska) c I Ua IUFZ = axt15(JN ELEV = 64' F. ELEV = ? OP = 4900' x Angle = . )9 ~ 1 t763' __ tum MD = 8445' tum TV n = RR(1(Y SS P mposed C TD S iiet?ack 9-5/8" FoC 2335' 9-5/8" FOC 2451' 13-3/8" CSG, 72#, N-80 BUTT, ID = 12.347" Minimum ID = 2.375" ~ 10005' TOP 2-7/8" TBG TOP OF 2-3/8" LNR 7975' TOP OF CEMENT 7975' 4-1/2" TBG, 11.6#, 13-CRVAM TOP, 8041' .0152 bpf, ID = 3.958" 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~-~ 8144' TOP OF3-1/2" LNR 8138' elm 7$$7' 4-1/2" HES X NIP, ID = 3.813" 7917' 9-5/8" X 4-1 /2" BKR S-3 PKR, ID = 3.870" 7950' 4-1/2" HES X NIP, ID = 3.813" 8020' 4-1/2" XN NIP, ID = 3.725" 8041' 4-1/2" X 5-1/2" XO, ID = 3.958" 8047' S-1/2" CAMCO DB-6 NIP, ID = 4.562" 8052' 9-5/8"X5-1/2"UNIQUEOVERSHOT 8083' 5-1/2" BKR SBR ASSY, 10 = ? 8132' 9-5/8" X 5-1 /2" BKR SA B PKR, IO = ? 8138' 7" MILLOUT EXTENSION, ID = ? 8144' 6-518" X 4-1 /2" XO, ID = 3.958" $188' 3-1/2" BKR DEPLOY SLV, ID = 3.000" 8199' 4-1/2" CAMCO DB-6 NIP, ID = 3.813" 41/2" TBG, 12.6#, N-80, .0152 bpf, ID = 3.958" ~ 8156' J I 8256' 4-1/2" TUBING TAIL, ID = 3.958" 3-1 /7' TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 8287' l 8228' ELMD TT LOGGED 07/29/89 TOP OF T' LNR 8337' 8287' 3-112" X 3-3/16" XO, ID = 2.79" 8337' 9-5/8" X T' BOT TIEBK SLV w/LNR HGR, ID = ? CSG, 47#, N-80/ S-95 BTC, iD = Two n~ r~i PERFORATION SUMMARY REF LOG: BHCS ON 07/04!78 ANGLE AT TOP PERF: 55 (~ 9610' Note: Refer to FYoduction DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2" 6 9610 -9630 isolated proposed 1-11/15' 4 10270 - 10500 isolated proposed 7' 4 10550 - 10800 isolated proposed 7' 4 11000 - 11200 iso~ted proposed 1-11/15' 4 11280 - 11651 isolated proposed 2-1/8' 4 11760 - 11798 isolated proposed T' LNR, 29#, N-80 BUTT, .0371 bpf, ID = 6.184" ~ 9875' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.8" 2-7/8" LNR, 6.4#, L-80, .0058 bpf, 10 = 2.441" AFETY NOTES: ***CHROME TBG** 22' S-1/2" X 4-1/2" XO, ID = 3.958" 2205' 4-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3243 3243 1 MMG OMY RK 0 07/10!07 3 5507 5481 22 MMG ONIY RK 0 07110!07 2 6678 6493 30 MMG DRAY RK 0 02/02/06 1 7808 7510 25 MMG DMY RK 0 02/02/06 2-3/8" Chrome cmt'ed and perfed 11350' } 9200' ~~ Mech Packer WS w R/A tags ~ T' MILLOUT WINDOW (07-01A) 9423' - 9429' I 9942' DAMAGED LNR (REF: MILLING OPER 08/04/07) 9943' FISH- 2-1/2" CIBP DEBRIS (08/04/07) 10005' 3-3/16" X 2-7/8" XO, ID = 2.375" 11$16' PBTD, MILLED OUT 08!19/98 DATE REV BY COMMENTS DATE REV BY CONMIAENTS 07/78 ROWAN 35 ORIGINAL COMPLETION 05/17/06 JGNVPJC RETRIEVE FISH ~ 811T 01/15/98 N4/3S SIDETRACK (07-01A) 07/04/06 RRD/PAG WEATHERFORD IBP, PERF 02/07/06 DOYON 16 RWO 02/28/07 OOBRLH PBTD MILLED 8/1998 02/09/06 RWVPJC DRLG DRAFT CORRECTIONS 07/20/07 TEUPJC GLV GO (07/10/07) 02/13/06 DTR/PAG GLV GO (02/08/06) 08/04/07 DNIS/PJC MILL CIBP/ FISH/ DAMAGED LN 03/30/O6 JLM/TLH VERBAL GLV CORRECTION PRUDHOE BAY UNIT WELL: 07-01 A PERMIT No: 1971530 API No: 50-029-20272-01 SEC 34, Tt t N, R14E, T FWL 8 203T FNL BP Exploration (Alaska) s 6000 ~ ---- 5000 ' I n u 07-01 A PRUDHOE BAY, PRUDHOE OIL C~~,.,~Q~,~Q (~,,~~~ -- ~- 'L B rt fc.r.c 5~ , SFr Ia~U ~ PBU DS7 -'- S~.fs_ ~ °~~-- ~ se~~~s ~J ~ n 1000 r~ fJ ~~ J 500 100 50 ~• ~' 10~ 51 0 ,~~ 07-01 A o -~-~- Gas Rate (CD) PPT.PRESS Gas /Oil Ratio (Mcf/bbl ) 0 ~ Water Coat (%) ~ Days on Prod Oil Rate (PD) (bbl/d) ----r 1998 99 2000 01 02 03 04 DATE :', . . ", 05 06 07 08 . ~V~VŒ (ID~ L%~L%~æL% / AIfASIiA OIL AlQ) GAS / CONSERVATION COMMISSION . . SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Olivia Bommarito Production Engineer BP Exploration (Alaska) Inc PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, 07-01A Sundry Number: 307 -194 h~ \~"'( ~ SCANNa,)' JUN 1 4 2007 Dear Ms. Bommarito: Enclosed is the unapproved Application for Sundry Approval relating to the above referenced well. We are returning your application for Sundry Approval unapproved. According to the workover operations matrix (highlighted copy attached), the proposed work does not require filing a sundry notice. DATED this~ day of June, 2007 Encl. ~ RECEIVED A STATE OF ALASKA a ~':/~.? ALWAoILANDGASCONSERVATIONCOMM~N JUN 082007 APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. Commission 20 AAC 25 280 1. Type of Request: Suspend U Repair well 0 Pull Tubing 0 Operational shutdown U Plug Perforations 0 Perforate New Pool D 4. Current Well Class: Development ø Perforate U Waiver U Stimulate 0 Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: ~ her~ cement squeeze Abandon U Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. P.O. Box 196612 197-1530 I' 6. API Number: 1~( Service 0 I 50-029-2027 -01-00 ' 8. Well Name and Number: ^/ PBU 07-01A " 10. KB Elevation (ft): 11, Field/Pools(s): / \ / 64 KB / PRUI/iCE Bf Y Fielo/PRUDHOE Oil Pool PRESENT WELL CONDITION SUMMARY / rTotal Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): PIU9ssp:sured): I'Junk (measured): 8992 , 9660 9007~, 9660' None .. Length Size MD TVD '\A Burst Collapse 80 20" 94# H-40 30 110 30 \ (V,>'ì\10 1530 520 2685 13-3/8" 72# N-80 29 271429'1" 271'f___ß930 2670 8642 9-5/8" 47# N-80 28 / 8670 28 'iJ7 8228 6870 4760 1086 7" 29# N-80 830/' 9423 8847 8160 7020 1714 3-3/16" 6.2# l-80 1~87 1009t1 ~~2~3 9043 10160 10530 1820 2-7/8" 6.5# l-80 \110001 1 U'~~2.99 8993 10570 11160 Perforation Depth TVD (ft): ~~ TIJ~g Size:5-1;~/211 #\I Tubing Grade: 13-CR Tubing MD (ft):0'-22' 8979' - 9000' \ 4-1/2" 1 ~1 / 13-CR VAM TOP 22'-8041' - I 5-1/2" ~ l-80 8041'- 8144' - ....., 4-1/2" 1ì.6# N-80 8144'-8255' 9-5/8" Baker S-3 ~ paCke~anc SS DMD (ft): 7917' 9-5/8" Baker SAB PK\ J ) ~ 8132' o ' 0 \_, f\ 0 ~ ~ 0 12. Attachments: DescriDtive Sul, J, ary art ro~ø.........- 13. ~ eX C ss after proposed work: Detailed Operations Program 0 .'~~'p sf<\¡' hI ~ / è~~ t~ 0 Development ø 14. Estimated Date for V7 ( 15. .us after proposed work: Commencing Operations: (6/22/200)' "- -' ¿ ~ Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: \ D te: / WA(\ 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: \ Prepared by \.:Iétry n~ule 564-4944 17. I hereby certify that the foregoing is tr ~ct to the best of m~ knowledge. - Contact Olivia Bommarito Printed Name l Oliv· 0 [n¡.rito Title P.E, Signature fih.~ J;r'" 1 . v.,..., Phone 564-4096 Date 1/\ W / COMMISSION USE ONLY C d" f .II N 1.0 I/.. h ., on IlIons 0 approva: t.V miSSion so t at a representative may witness Plug Integrity D Y BOP Test 0 Mechanical Integrity Test D Exploratory 0 3. Address: Anchorage, AK 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: Stratigraphic 0 No o /" ADlO-028309 ~ 11. Total Depth MD (ft): 11823 ' Casing Conductor Surface Production Liner Liner Liner Perforation Depth MD (ft): 9610' - 11798' - - Packers and SSSV Type: Service 0 6/8/2007 Sundry Number: 3J7 - ¡q1 location Clearance D Other: S,"'"" t Fo~ R"";,",,, 0 ~ Appro'odby. ~J~~ER r \../ V APPROVED BY THE COMMISSION Date: 6-/3-0:¡- - Form 10-403 Revised 06/2006 U k \ G \ r\! M L RBDMS 8Ft. JUN 14 1007 Submit in Duplicate ö .07-01 A Liner Cement Squeeze . To: Jerry Bixby / Clark Olsen, Well Operation Supervisors 6/7/2007 From: Donald Reeves - Wells Engineer Olivia Bommarito - Pad Engineer Subject: 07-01 A Liner Cement Saueeze PBD07WL01-N Est. Cost: $250M lOR: 780 BOPD 1 S D&T CIBP, SBHPS, Set DGLVs in sta# 4 & 3, MITIA to 2500 psi, LLR 2 C Remove CIBP, set composite plug, squeeze liner 3 S Drift to deviation, Run KO GLV design (10 days post squeeze) 4 C Drawdown test, Mill out composite plug (10 days post squeeze) Current Status: Last Production: Deviation: Minimum ID: Last Dowhole Tag: Last TD Tag: Last Downhole Ops: Last SBHP & BHT: Latest H2S value: Natural flow producer making 100% gas 12/19/06: 0 BOPD, 0 BWPD, 17.2 MMCFD Max of 1090 @ 11,763' DD, _450 at 3-3/16" liner holes 2.375" - XO to 2-7/8" liner at 10,005' DD 12/23/06: Slickline tagged 9626' SLM 12/11/00: CT milled to 11,678' CTM with 2.25" mill 12/23/06: Slickline callipered liner 9615'-8188' 3248 psi & 2040 Fat 8800' TVD (07-20A analogy 05/04) Unknown - No Data Objective & BackQround The objective of this procedure is to shut off the gas production leaking into the 3-3/16" liner thru a series of corroded holes. This work will remove the CIBP at 9660', set a composite plug -10,100' to protect lower perfs, acid wash and cement squeeze the liner. After the cement has reached full compressive strength (2-3 days) SL will set a KO GL V design to assist CT to mill out the composite plug. 07 -01 A is a Zone 2 well currently producing 100% gas thru a series of corroded holes in the 3-3/16" liner above the top perforations. A gas entry survey 12/19/06 showed gas entering the liner from 9440'-9540', 70' above the top perforation at 9610'. This correlates with a cement bond log that indicates poor cement in the same intervals. For questions contact Jennifer Julian at 564-5663 (W), 240-8037 (C), 274-0929 (H), Donald Reeves at 564-4080 (W), 980-5490 (C) or Olivia Bommarito at 564-4096. JJ's cell phone may not work if called from the unit, may have to use alternate phone. CC: Well File 1 Job PlanninQ Perforations: .07-01 A Liner Cement Squeeze. 9610'-9630' (20') 10,270'-10,500' (230') 10,550'-10,800' (250') 11 ,000' -11 ,200' (200') 11,280'-11,651' (371') 11,760'-11,798' (38') - Open - Shut-off by CIBP - Shut-off by CIBP - Shut-off by CIBP - Shut-off by CIBP - Shut-off by CIBP & buried in fill Known Liner Holes: 8290' (communicates to 7" liner, not formation), 9474', 9533', 9556',9587',9632' MD. More holes are likely. Gas Lift Design: Tag History: DGLVs at 7808' & 6678', LGLV at 5507' and OGLV at 3243' 12/23/06: 9626' SLM tagged CIBP 12/11/00: 11,678' CTM during liner milling & adperf 08/19/98: 11,821' CTM during landing collar mill-out 05/04/98: 11,750' CTM during mud acid stimulation Volume to top perf: 136 bbls (125 bbls in tubing, 11 bbls in liner) Wellbore Volume: 139 bbls (assuming composite plug is set at 10,100') Fracture Pressure: 5280 psi (assume 0.6 psi/ft) Static: Risk Discussion 3248 psi & 2040 F at 8800' TVD (from 07-20A analogy 05/04) A full column of diesel on the backside will give 132 psi WHP. The liner in this well is in very poor condition (see attached caliper log). However, because the cement quality behind the liner is good except for in a few areas, it is felt this job has a good chance of success. The condition of the liner may lead to inadvertent sidetracking, so all milling operations will require caution and vigilance. Weatherford will provide a special burn-over shoe to retrieve the CIBP currently set at 9660'. Because the CIBP was set in the 3-3/16" liner above a XO to smaller 2-7/8" liner at 10,005', it may be difficult to mill out the CIBP traditionally. If successful, the proposed burn-over shoe will mill out the plug's upper anchors and hold on to the plug body for retrieval. If the burn over shoe is unable to retrieve the plug body, the backup plan is to run a set of up/down hydraulic jars, an impact hammer, and a motor with a 3 blade star bit. The impact hammer will assist in breaking up the CIBP plug body. The 2-7/8" liner has not been entered since a coiled tubing ad-perf was performed 12/11/00. Even though the composite plug will be set 170' above the top perforation in the 2-7/8" liner, a drift to TO in the 2-7/8" liner is recommended. This will ensure no debris from milling the CIBP is obstructing the liner and establish the max depth the composite plug can be pushed down to during post squeeze milling. 2 .7-01 A Liner Cement Squeeze . With a static bottom-hole pressure of only 3248 psi, the well is overbalanced with either 1 % KCI or dead crude. A full column of diesel will only give -132 psi underbalance and could make it difficult to see positive wellhead pressure until squeeze pressure builds. Injectivity into the perfs and liner holes should not be a problem. Fullbore was able to pump 3.2 bpm at 1650 psi during a load and kill for e-line on 12/20/06. We are purposely not placing the cement accelerator "TEA" across the squeeze for this well. While TEA has been shown to accelerate the cement's curing time, testing shows slow curing cement (-10 days) is much stronger than TEA accelerated cement. Pre-Squeeze Slickline 1. RU SL and drift to CIBP at 9660'. Obtain SBHP survey per separate request form. 2. Run OGLVs in Sta #4 at 3243' & Sta #3 at 5507' MD. MITIA to 2500 psi, establish leak rate if MITIA fails. CTU Mill CIBP & Set Composite PluQ 3. RU CTU with squeeze trailer. 4. MU BHA with Weatherford motor and custom burn over shoe for retrieving CIBP. 5. RIH to 9660' and mill over 2-1/2" Weatherford CIBP according to service hand recommendations. Retrieve plug body and POOH. Weatherford built a custom burn over shoe with the purpose of milling over the CIBP upper anchors and catching the plug body inside the shoe. If successful, the shoe will capture and retrieve the plug body without having to mill it into small pieces. This is preferred to milling up the plug and potentially having problems at the XO to 2-7/8" liner at 10,005'. 6. If the custom burn-over shoe is unsuccessful in retrieving the plug body, MU the BHA with a set of up/down hydraulic jars, an impact hammer, and a motor with a 3 blade star bit. Attempt to mill using the impact hammer to assist in breaking up the plug body. Make venturi runs as necessary to retrieve plug body parts. 7. MU and RIH with a 2.25" JSN and drift to TO. The last TO was tagged at 11,678' CTM 12/11/00 during a liner mill out pre adperf. 8. MU and RIH with 2-7/8" Weatherford composite bridqe pluq (plug 00 = 2.120"). Set composite plug inside 2-7/8" liner at 10.100' CTM & POOH. Depth control is not critical, primary depth control is adequate. 9. Perform injectivity test (1500 psi max) to ensure milled CIBP debris has not plugged perfs. 3 .7-01 A Liner Cement Squeeze . CTU Liner Squeeze 10. Call out Dowell cementing seNice & MU BHA with 1.75" fluted no-go cold roll connector and 2" BON (this will be done with no checks). Min. 10 in well = 2.375" 11. Bullhead down backside at max rate with 1 .5x wellbore volume of 1600 F 1 % KCI (-200 bbls) to kill well. Continue pumping at a min rate to keep wellbore liquid packed. KCI should cool the BHT from 2040 F to -1800 F. 12. RIH, tag composite plug at 10,100' & PUH until full string weight is recovered. PUH additional 10' and flag pipe. 13. PUH to 9400' and line up cementers to pump down the coil. Reciprocate across liner holes and perforated inteNal from 9440'-9630' while pumping the following down the coil: · 1000 gallons (23.8 bbls) 3% NH4CI pre-flush · 1000 gallons (23.8 bbls) 12% HCI acid · 1000 gallons (23.8 bbls) 9:1 MUD acid · 1000 gallons (23.8 bbls) 3% NH4CI over-flush · one coil volume spacer water Additives and concentration can be determined per current best practice for a bottom-hole temperature of 1800 F (the real BHT of 2040 F will be cooled down by the KCI kill fluid). 14. RIH to flag and pump flush to ensure all acid is removed from wellbore sump (acid is a cement accelerator). With wellbore flushed, PUH and park at 8100'. 15. Pump a full column of diesel down the backside (-110 bbls) to create positive wellhead pressure of -132 psi (based on SBHP of 3248 psi at 8800' TVD). Do not proceed with squeeze unless the tubinq is liquid packed and qas free and there is some positive wellhead pressure. 16. Batch mix 30 pumpable bbls LARC cement to meet the following specifications: Volume to Pump 30 bbls total Cement Type Liquid Latex Acid Resistant (LARC) with 0-176, 3% BWaC Thickening Time 5-7 hours at 180°F BHT (this considers cooling by the 1600 F KCI) Fluid Loss 75 cc/30 minutes at 180°F BHT Acceptable Range 50-80 cc/30 minutes at 180°F BHT Filter Cake 0.85" firm cake ± 0.15" in lab Rheology YP>5 with no settling or gelation in fluid loss cell 4 .07-01 A Liner Cement Squeeze . 17. Catch a sample of the cement for QC testing and place sample in hot water bath. Line up cementers to the coil. 18. With backside SI, pump the following down the coil: · 10 bbls spacer water (Do Not use J313 Friction Reducer as it will clabber cement) · 30 bbls LARC cement · Displace with spacer water 19. RIH with coil to flag as cement reaches the nozzle and open choke to take returns up the backside. 20. Pump Y2 bbl cement out nozzle before pulling uphole. (Ideally this will place 140' of cement above nozzle to prevent dilution while PUH). After Y2 bbl of cement is out the nozzle, PUH and lay in cement 1: 1. Because capacity in 2-7/8" liner is 173' / bbl, the pump rate will have to be less than 1 bpm in order to pull 1: 1. If pumping less than 1 bpm is not practical due to cement falling out of coil, it's alright to pump 1 bpm and pull as fast as possible. 21. Stop at 8240' (50' above top liner hole at 8290') to prevent cement dilution if perfs are taking cement. 22. Close the choke and reciprocate at 8240' until wellhead pressure rises 500 psi. Do not build squeeze pressure while coil is across holes to prevent getting "noded-in" . 23. Once 500 psi pressure bump is observed, open choke to take returns at 500 psi and begin pulling up, laying in remaining cement 1: 1. 24. Position nozzle at cement top just as last barrel of cement reaches nozzle. 25. PUH at maximum speed to safety of 6900'. NOTE: 30 bbls of cement would extend up the tubing to 7225' DD if no cement goes into the perfs (assuming plug at 10,100'). 26. With coil at safety, close choke, and slowly increase squeeze pressure up to a target of 2500 psi DP at the perfs in 500 psi increments, holding each increment for 15 minutes. Hold 2500 psi for 1 hour. · Account for fluid and cement densities when calculating DP at perfs (SBHP = 3248 psi at 8800' TVD). · Assuming TD = 10,100' and 30 bbls of cement pumped, about 27 bbls of cement can be sQueezed behind pipe before the cement top (poor quality cement) is pumped within 100' of the liner hole at 9474' MD. 5 ·07-01 A Liner Cement Squeeze. The liner hole at 8290' is not across formation rock, it is acceptable if the cement top is pumped below this depth while squeezing the lower holes that are across formation rock. . If unable to achieve at least 1500 psi OP squeeze pressure at perfs, contact Jennifer and plan on contaminating cement and attempting the squeeze again. 27. After one hour at 2500 psi, slowly bleed WHP down over 15 minutes to 500 psi WHP. Minimize surges while bleeding down WHP and during cleanout to prevent nodes from getting displaced. 28. Swap to 1-1/2# biozan and launch a ball. Chase ball to nozzle then RIH at 1: 1 jetting at max CT pressure and clean out to composite plug at 10,100'. Reduce CT pump rate to 1 BPM across liner holes and perfs to avoid damage to nodes. 29. Take barrel count to ensure 1: 1 returns. 30. Switch to friction reduced water. Make 3 down and 2 up passes from 10,100' to the tubing tail at 8041'. Do not use "TEA" as a cement accelerator for this well (see risk discussion section above). 31.Jet uphole at 80% running speed and max CT press. Slow down across jewelry. 32. Freeze protect the top 2000' and leave -500 psi WHP. ROMO. Post-Squeeze Slickline 33. Wait on cement to reach full compressive strength (10 days) and RU SL. 34. Drift to deviation to verify no cement stringers, and run kick-off gas lift design per gas lift engineer. Post-Squeeze Drawdown Test & Coil MillinQ 35. Contact the OS 7 operator (or EOC x5921) and have them perform a drawdown test on the well. This is putting the well on gas lift into the test separator to unload the liquids in the IA and the tubing. By unloading the well, a drawdown is put on the squeezed perfs. If the well produces more gas than is being injected for gas lift, then the squeeze was not successful. In this case an evaluation will be made on repeating the squeeze. 36. Verify well passed drawdown test (above) and RU CTU. 37. MU BHA with motor and mill for removing the 2-7/8" composite plug at 10,100'. 38. RIH and mill out composite bridge plug at 10,100' using gas lift to assist. Push any plug debris to TO. POOH & ROMO. 6 1-01 A Section -Gas Survey 7 8 Cement 9 R s P¡pe: 88 in 6.2 in in 2.800 in l-80 Field: Date: December Joint Comments I .2 10 . ....... I o ...I. » !:: ::J CD ... (') CD 3 CD ::J - en .a c CD CD N CD . ~ 501 $7 uø",:!.oj ==- n.7œ.O ~ 1(1.(10$..0 ~ ~. ,.ft_ .................ü 3.700 3.Ø 3.eoo ~_ u;¡,) 2m 1_ 2.800 3, _ :UW 15110 2.æ5 un :2.:m U1$ '.$11 U1$ U1$ 2..312 U7I ~ ~... ¡s.:-.r P\po i :~~ .. 0... ~ SoaMt ~ DMI~ 30.0 IiOAI :)).0 N N N '.$QO , , .600 ~ ,200 ø t.1 tIII.OO t.HI1 .8' ......1M ÇØ1.f1O 10,(IOI,,ou 10.(1015.03 'O~I 11,:tB7.n " .lI'IIUO II . ì'UO.. I 0 t1.82I.œ U,O .13I!) OMQ 1.113.1110 3.,1"0' O,3UO '.7e::UIiIO (t.lJð) f..no 3O<9ØO 2.000 a.::œ UI):I 3.1100 3.500 :uoo 3.5W 2m 2$& ~ Wfi 2.81& seT"'frØG :IiILSiVE .~~ I'\A$ II ~ X..Q ~ JOINT(S) <-call ~VX-C" I.íl "IrN ItfUS X-C CMIHO ..IC.IIHf{$) ~~ ~T<.:ou.NI ~..IOIII'a ............. OOIŒ SIC) ~., ~ ~ ...... ...... .07-01A Liner Cement squeeze. I SAFETY NOTES: ***CHROME TBG*** TREE = GRAY G8112 WELLHEëAD = GRA Y ACiUA TOR = AXELSON c=-=>~-------'- KB. ELEV = 64' BF. ELEV = ? KOP = 4900' Max Angle = 109 @ 11763' :----------~ Datum MD = 9445' DatumlVD= 8800'-55 I 13-318" CSG, 7'1#, N-80, ID = 12.347" 07-01A ~ 2714' I Minimum ID = 2.375" @ 10005' I TOP 2-718" TBG 4-112" TOO, 11.6#, 13-CR V AM TOP, .0152 bpf, ID = 3,958" TUBlfIG STUB I 1 5-1/2" TOO. 17#. L-80, ,0232 bpf,lD =4.892" I 8041' 8048' I I TOP OF 3-1/2" LNR I 8138' elm 8144' 4-1/2" TBG, 12.6#. N-80, >0152 bpf, 10 = 3.958" I I TOPOF 3-3116" LNR I I TOP OF 7" LNR H I 9-5/8" CSG, 47#, N-80, ID = 8.681" I I 3-3/16" LI\R, 6,'1#, L-BO, .0076 bpf, ID = 2.8" I I TOP OF 2-7/8" LNR I 1 ~I 1 ( I( ~ 8255' }--..Ì' 8287 I--r-- 8337 1- ~ 8670' r 10001' 10005' PERFORA 110N SUMMARY REF LOG: BHCS ON 07104178 ANGLE AT TOP ÆRF: 55 @ 9610' Note: Refer to Production DB for historical perf data SIZE SPF INTffiV AL OpnlSqz DA TE 2" 6 9610- 9630 0 07/04/06 1-11116" 4 10270 - 10500 C 01/10/98 2" 4 10650 - 10800 C 12112100 2" 4 11000-11200 C 12112100 1-11/16" 4 11280-11651 C 01/10/98 2-1/8' 4 11760 - 11 798 C 08124198 I 7" LNR. 29#, N-80, .0371 bpf.ID = 6.184" I DATE 07178 01/15/98 02107/06 02109/06 02113/06 03130/06 REV BY OOMMENTS ORIGINAL COMPLETION LAST WORKOVER DOYON 16 RWO RWLlPJC LRLG æAFT CORRECTDNS OTR/PAG GLV C/O (02108/06) JLM'TLH VERBAL GL V CORRECllON 9422' I Iiõ:"'"""':: E::....:::: -¡....-- r 1 I I 22' '- -L 2205' H .- ~ ST MD TVD 4 3243 3243 3 5507 5481 2 6678 6493 1 7808 7510 1 ~ r---r r8~_ 1- r--- 1- - [r--r i~ ~~ 8132' ---r--r 8144' t---r--r 8188' r-r--r 8199' '"- -- 8255' -- ........... 8228' -i ~ 8286' -1 .1 101 ---. 9660' ..........~r "'1 10005' ~ 5-112" X 4-1/2" XO,ID = 3.958" 4-1/2" HES X NPR..E, ID= 3.813" ~ GAS LFT PJlANDRELS DEV TYÆ VLV LATCH 1 MMG OOME RK 22 MMG SO RK 30 MMG DMY RK 25 MMG OMY RK FORT DATE 20 02102/06 16 02108106 o 02102/06 o 02102/06 7887 7917 7950' 8020' 8041' 8052' 8047' 8083' 4-1/2" HES X t-IPPLE, D = 3.813" I 9-518" X4-1/2" BAKERS-3 A<R, ID = 3.870" 4-1/2" HES X NIPPLE, ID = 3,813" I 4-1/2" XN NPR.E, ID = 3.725" I H 4-112" X 5-1/2" XO, D = 3.958" I -i9-5I8" X 5-1/2" UNIQUE OVERSHOT I H 5-112"O\MOODB-6NIP,D=4.562" I H 5-112" BKRSBRASSY I 9-518" X 5-112" BAKER SAB A<R I 5-112" X 4-112" XO I 3-112" BAKER ŒA..OY SLV, 10 = 3.000" I 4-112" CAMCO 0B-6 NIP. ID = 3,813" I (BefIND PIPE) 4-112" TUBING TAIL (BefIND PIPE) I ELMD TT LOGGED 07/29189 (BetIND PIPE) 3-112" X 3-3116" XO, 10 = 2,79" I I 7" MILL OUT WINDOW 9423' - 9429' I 2-1/2" WEëA THERFORO CBP (07/04/06) I 3-3116" X 2-718" XO, ID = 2>375"1 11 11816' r FBTD, MILLS) OUT 08/19198 - ---- I 2-7/8" LNR, 6.4#, L-BO. .0058 bpf, 10= 2.441" 11821' DATE REV BY COMMENTS 05117/06 JGM'PJC RETRIEVE FISH @ 8117' 07104106 RRJ:VPAG WEëA THERFORD IBP, FlRF 02128/07 OOBfTLH FBTD MILLS) 811998 PRUDHOE BAY UNIT WELL: 07-01A FERMIT No: 1971530 API No: 50-029-20272-01 SEe 34, T11N, R14E, 834.31' FEL & 3147.65' FNL BP Exploration (Alaska) 12 '0 . STATIC BOTTOM-HOLE PRESSURE SURVEY . Ver1.4, Rev 08112/2004 (JDM) Well: 07-01 A API#: 50-029-20272-01 ......"..................................... .............................. ,,,............................................. Date: Cost Est: .............~!~!~Q«:'!.,.................................... $3M Prod Engr Olivia Bommarito .......................................................".......................................... Office Ph: 564.4096 ..................................m... H2S Level: ............................................................ Home Ph: 677.1879 Unknown - No Data ........................................... ...................................... ........................................ CC or AFE: PBD07WL01-R ............................................................................ Cell/Pager: .....,.~.~~,:~,!.~~,...... WBL Entries S pre coil liner squeeze ..........I.y.p..e ................................................................................................................................. Well Ob'ectives Lo in Notes and S eciallnstructions: This work to be performed before the coil tubing liner squeeze. Check to ensure a reasonable gradient before leaving site. Please perform survey after well is shut in for 5 days. Datum: -8800' SS Well Data Procedure: Last Tag: 9626' SLM Tag date: Max Deviation .m.~.«:'.~..I:>.Ii!.9..t>..... Depth: ..~..1...?.~~.:..~.1:>... 12/2312006 Min. SI Time: ...~....:>..:,¥.~...... Logging Data 1. Make 10 min pressure stop in lubricator 2, Drop below the first pressure-stop requested. Pull-up to specified depth. 3. ElL: Measure pressure until it varies less than 1 psi in 20 min. S/L: Hold guages at depth for time specified 4, ElL: Measure pressure until it varies less than 1 psi in 20 min. S/L: Hold guages at depth for time specified Time 5. ElL: Measure pressure until it varies less than 1 psi in 20 min. .............................................. Requested Stops: MD First 9207' ......................... ........... Second 9326' ....................................... SS 8600' 8700' 15 min S/L: Hold guages at depth for time specified 15 min 6, ElL: Test tool in lubricator at 3000 psi with calibrated test gauge 15 min S/L: Hold guages in lubricator for 10 min stop. Compare to test guage 40min ............................. Third 9443' ...................................................... 9326' 8800' 8700' 7. Leave well shut in if SBHP is less than N/A .................................... Summ~ Dist Well: 07-01 A API#: 50-029-20272-01 ----------------------------- PE Town: Date: Service Co. New Tag: .. 'MD Anch Prod Engr P.D, Center Upper Gauge Lower Gauge Temperature Test Gauge Date Time MD SS Pre-Job Lubricator Pressure 9207' 8600' ......"..."................. ............u....................................................................... ............................... 9326' 9443' 9326' 8700' .............................. ....................................................................................................... 8800' .............................. 8700' ....."".................... Post-Job Lubricator Pressure Type of Pressure Tool SITP (Tubing): ................................................................... ..........................................................psig SICP (9-5/8"): Shut In Date: Comments: ............................................................. and Time: ........................................................................... .................................................................................................................................... .................................................................................. ............ ..... ... ............. .... Total Shut In Time (h..r.~L. . e 0 og escnpt on ae o or P2-37A 11491392 MEM PROD PROFILE 11/15/06 1 Y-23B 11418299 MEM PROD PROFILE 09/06/06 1 NK-07A 11588698 MEM GLS 12/21/06 1 07-01A 11555031 GAS ENTRY SURVEY 12/19/06 1 NK-08A 11485780 MEM GLS 12/20/06 1 NK-27 11588699 MEM GLS 12/22/06 1 NK-43 11513659 PRODUCTION PROFILE 12/22/06 1 DS 09-32 11555530 INJECTION PROFILE 12/16/06 1 P2-14 11539745 MEM PROD PROFILE 12/07/06 1 Y-05A 11539744 MEM INJECTION PROFILE 12/06/06 1 S-02Ä 11285936 MEM PROD PROFILE 08/17/06 1 12-32 11536184 USIT 12/05/06 1 MPS-10A 11486087 COMPOSITE WFULDL 12/14/06 1 Z-19A 11226013 SCMT 10/28/06 1 Y-30L 1 11588700 MEM PROD PROFILE 12/23/06 1 E-11 B 11434757 DSI 10/24/06 1 E-11 B 11434760 DSI 10129106 1 E-11B 11434760 FMI 1 0/29106 1 G-14A 11485777 MEM PROD PROFILE 11127/06 1 G-14A 11485777 SCMT 11127/06 1 SchlullblJPger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WI! ~ ~) ZIJOi 10'1 -¡s:j J b# L D . I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~ JAN 3 () 2007 Anchorage, Alaska 99508 Date Delivered: 01/25/2007 NO. 4125 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay D t CI . CD BL . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: 0\ ~rG q)/C{Jor:. \VEO STATE OF ALASKA . RECE ALASKA Oil AND GAS CONSERVATION COMMISSION SEP 1 4 2006 REPORT OF SUNDRY WELL OPERA Tlq,I'!.~"c. r.nn!l. commission ",ta~I\" -.. Stimulate 0 "nchorag~therŒ] Set CIBP WaiverD Time ExtensionD Re-enter Suspended WellD 1. Operations Performed: Abandon 0 Alter CasingD Change Approved ProgramD 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.00 8. Property Designation: ADL-028309 11. Present Well Condition Summary: Total Depth . Repair Well 0 Pull TubingD Operation ShutdownD PIUR PerforationsD Perforate New PoolO Perforate !K] 4. Current Well Class: Development ŒI 5. Permit to Drill Number: 197.153 6. API Number 50-029-20272-01-00 ExploratoryD StratigraphicO ServiceD 9. Well Name and Number: 07 -01 A 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool measured 11823 feet Plugs (measured) 2-1/2" Weatherford CIBP @ 9660 (07/0412006) Effective Depth true vertical 8992.0 feet Junk (measured) true vertical measured 9660 feet Casing CONDUCTOR SURFACE PRODUCTION Length 80 2684 8642 LINER LINER LINER 1086 1817 1816 Perforation depth: 9007.0 feet Size MD TVD Burst Collapse 20" 94# H-40 30 - 110 30.0 - 110.0 13-3/8" 72# N-80 29 - 2714 29.0 - 2714.0 4930 2670 9-5/8" 47# N-80 & RS & 28 - 8670 28.0 - 8228.0 6870 4760 SOO-95 7" 29# N-80 8337 - 9423 7963.0 - 8847.0 8160 7020 3-1/2" 9.3# L-80 8188 - 10005 7841.0 - 9043.0 10160 10530 2-7/8" 6.4# L-80 10005 - 11821 9043.0 - 8993.0 10570 11160 Measured depth: 9610-9630,10270-10500,10550-10800, 11000-11200, 11280-11651, 11760-11798 True vertical depth: 8979-8991,9050-9035,9032-9029,9033-9034, 9036-9041, 9013-9000 Tubing ( size. grade. and measured depth): 5-1/2" 17# 13-CR @ --- 4-1/2" 11.6# 13-CR VAM TOP @ 22 5-1/2" 17# L-80 @ 8041 4-1/2" 12.6# N-80 @ 8144 Packers & SSSV (type & measured depth): 9-5/8" Baker S-3 PKR @ 7917 9-5/8" Baker SAB PKR @ 8132 - SCANNED SE? 2 C 2006 22 8041 8144 8255 - - - 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr ~~_. æ X // v '-_._1 Form 10-404 Revised 4/2004 l.J f'\ \ tJ \ 1 \1 f\ L 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ Signature RBDMS 8Ft SEP ] 8 2006 Oil-Bbl SI 422 ReDresentative Dailv Averaae Production or Iniection Data Gas-Mef Water-Bbl CasinR Pressure Tubing Pressure 833 1519 o 42381 o o -- -- }1 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: IN/A DevelopmentŒ ServiceD Title Petroleum Engineer Phone 564-5174 Date 9/8/06 07/06/2006 07/04/2006 06/30/2006 06/24/2006 05/21/2006 05/17/2006 05/16/2006 05/15/2006 05/14/2006 BBLS 5 5 . . 07-01A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY TestEvents --- BOPD: 253 BWPD: MCFPD: 38,302 AL Rate: TIIIO 2300/400/475.2.5" WEATHERFORD CIBP SET AT 9660 FT. 2" HSD, 6 SPF, 60 DEGREE PHASING PERFORATED INTERVAL 9610-9630 FT. DEPTH TIED TO SLB RST DATED 18-AUG-2004. ALL SHOTS FIRED. POST PERFORATING TIIIO = 3500/450/475. RDMO. NOTIFIED DSO OF DEPARTURE. *********JOB COMPLETE********* TIIAlOA = 2380/390/450. Temp = SII. Tubing Fluid Level (call-in). Tubing FL @ 7989'. *** Well shut in on arrival *** (pre add perfs) Drift wI sample bailer, 2.25" cent & 2" dummy gun. Stopped due to deviation @ 9742' slm, target depth 9690' ***notify dso of well status, fixed leak on tree cap flange & left master shut & flagged*** ASRC Well Test 954.9 bfpd 461.7 bopd 47.65% WIC 33.915 mmscfld 0 mm GIL 73451 GOR 113 deg WHT 176 Beans (fish IBP) ATTEMPTED TO BLEED TUBING DOWN. RAN A 3.65" BOX TAP WITH MODIFIED BARBS. NEVER ABLE TO GET A GOOD BITE, RAN 2.80 O-SHOT, RECOVERD ENTIRE FISH, RAN 3" X 5' PUMP BAILER WI FINGER BASKET FLAPPER BOTTOM, NO BAND RECOVERY, RAN KJ, 2.25" X 5' PUMP BAILER WI MULE SHOE FLAPPER BOTTOM TO 9,732' WLM, TOOLS STOPPED@ 9,732' WLM, DUE TO HAW, NO BAND RECOVERY ***WELL LEFT SHUT IN *** (NOTIFIED DSO DO NOT FLOW TILL FURTHER NOTICE) **** WELL SHUT IN**** (fish wfd Lb.p. fish) RAN A 3.65" BOX TAP. WAS ABLE TO GET SEVERAL DOZEN BITES, BUT KEPT SLIPPING OFF. MARKS ON BOX TAP INDICATED APPROX. 5" OVER THE TOP OF IBP. (TATTLE TAIL PINS WERE BENT UPWARD) **** JOB STILL IN PROGRESS**** RAN A 3.50" MAGNET. (RECOVERED NOTHING) RAN A 3.50" LIB. HAD A PICTURE OF METAL BANDS AND POSSIBLE MISSING ROLLER DOG. RAN A 3.25" PUMP BAILER WITH 3.60" FINGER CAGE. (RECOVERED TWO METAL BANDS) **** WELL LEFT SHUT IN *** (NOTIFIED DSO OF WELL STATUS) ****WELL SHUT IN **** (pull ibp catcher I drift) PULLED IBP CATCHER, LOOKS LIKE SOMETHING HIT IT, ALL ROLLER DOG SPRINGS BROKE, (1) ROLLER DOG MISSING & TATTLE TALE PINS ARE BENT UP. RAN 3.50 LIB TO 8,030' WLM, RAN 3.625 BAR BELL ASSY TO 8,117' WLM, PICTURE OF WHAT APPEARS TO BE SMASHED BANDS. RAN VARIOUS 3 PRONG WIRE GRABS. NEVER RECOVERED ANYTHING. FLUIDS PUMPED Diesel- PT Surface Equipment TOTAL Page 1 . ~NOTES' ···CHROME T.....· TREE = GRAY GEN 2 I WELLHEAD = GRAY 07 -01 A . ACTUATOR = AXELSON KB. ELEV = 64' -i 5-1/2" X 4-1/2" XO, ID = 3.958" I BF. ELEV - ? I 22' KOP= 4900' ~ 2205' -i 4-1/2" HES X NIPPLE, ID = 3.813" . . ~ Max Angle = 109 @ 11763' I'""" GAS LIFT MANDRELS Datum MD = 9445' ~ ST MD TVD DatumTVD- 8800' SS DEV TYÆ VLV LATCH PORT DATE 4 3243 3243 1 MMG DOME RK 20 02/02/06 I 13-318" CSG. 72#, N-80, 10 = 12.347" I 2714' I L 3 5507 5481 22 MMG SO RK 16 02/08/06 2 6678 6493 30 MMG DMY RK 0 02/02/06 1 7808 7510 25 MMG DMY RK 0 02/02/06 Minimum ID = 2.375" @ 10005' . I """- --r -j I ~I ~ 7887' 4-1/2" HES X NIPPLE, 10 = 3.813" TOP 2-7/8" TBG I - 7917' H 9-5/8" X 4-1/2" BAKER S-3 A<R, 10 = 3.870" """- -- 7950' --i I I 4-1/2" HES X NIPPLE, ID = 3.813" - 4-1/2"TBG, 11.6#,13-CRVAM TOP, 8041' -- 8020' -j 4-1/2" XN NIPPLE, ID = 3.725" I ( -.... -i 4-1/2" X 5-1/2" XO, 10 = 3.958" I .0152 bpf, 10 = 3.958" 8041' I TUBING STUB 8048' I I- i r-~ 8052' -j 9-5/8" X 5-1/2" UNIQUE OVERSHOT I 8047' -j 5-1/2" CAMCO DB-6 NIP, ID = 4.562" I r--r 8083' --i 5-1/2" BKRSBRASSY I ~ Ix --i 9-5/8" X 5-1/2" BAKER SAB A<R I 15-112" TBG, 17#, L-80, .0232 bpf, 10 - 4.892" I 8144' I 8132' - --r 8144' --i 5-1/2" X 4-1/2" XO I I TOP OF 3-112" LNR I 8138' elm I " -... ~ 8188' -i 3-1/2" BAKER DEPLOY SLV, 10 = 3.000" I r-- --r 8199' I 4-1/2" TBG, 12.6#, N-80, .0152 bpf, 10 = 3.958" I J--....¡--.... 4-1/2" CAMCO DB-6 NIP, 10 = 3.813" I 8255' (BEHIND PIPE) I TOP OF 3-3/16" LNR I 8287' r-_ '-- H 4-1/2" TUBING TAIL (BEHIND PIPE) I I 8255' I TOP OF 7" LNR H 8337' 1- ......... ~I 8228' H ELMD TT LOGGED 07/29/89 (BEHIND PIPE) I ~ I 9-5/8" CSG, 47#, N-80, 10 = 8.681" , 8670' 1 8286' H 3-1/2" X 3-3/16" XO, ID = 2.79" I ~) 7" MILLOUT WINDOW 9423' - 9429' I I 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.8" I 10001' ~ 9660' -j 2-1/2" WEA THERFORO CIBP (07/04/06) I --- ~ I TOP OF 2-7/8" LNR I 10005' í 10005' H 3-3/16" X 2-7/8" XO, 10 = 2.375" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 07104/78 ANGLEATTOPÆRF: 55@9610' ~ Note: Refer to Production DB for historical perf data , SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9610 - 9630 0 07/04/06 1-11/16" 4 10270 - 10500 C 01/10/98 I H PBTDI 2" 4 10550 - 10800 C .. 12/12/00 11788' 2" 4 11000 - 11200 C .. 12/12/00 ~, 1-11/16" 4 11280 - 11651 C 01/10/98 2-1/8' 4 11760 - 11798 C 08/24/98 ------- I 7" LNR, 29#, N-80, .0371 bpf, 10 = 6.184" I 9422' I 2-7/8" LNR, 6.4#, L-80, .0058 bpf, ID - 2.441" I 11821' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 07178 ORIGINAL COM PLETION 02/17106 fTLH CORRECTIONS WELL: 07-01A 01/15/98 LAST WORKOVER 03/30/06 JLMfTLH VERBAL GL V CORRECTION ÆRMIT No: '1971530 02/07/06 DOYON 16 RWO 05/07/06 JLJ/PA G FISH PUSH TO 8117' (05/03/06) API No: 50-029-20272-01 08/24/04 LDKlTLP WEATHERFORD IBP 05/17/06 JGMfPJC RETRlEV E FISH @ 8117' SEe 34, T11N, R14E, 834.31' FEL & 3147.65' FNL 02/09/06 RWUPJC DRLG DRAFT CORRECTIONS 07/04/06 RRD/PAG WEATHERFORD IBP, ÆRF 02/13/06 OTRfPAG GLV C/O (02/08/06) BP Exploration (Alaska) _ STATE OF ALASKA _ RECEIVED ALASKA~ AND GAS CONSERVATION COW1ISSION REPORT OF SUNDRY WELL OPERATIONSMAR 0 8 2006 Alaska Oil & Gas Cons. Convnission 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program ----~~~~~-- o Suspend IS! Repair Well IS! Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Other o Re-Enter Suspended Well o Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: IS! Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 197-153 6. API Number: 50-029-20272-01-00 99519-6612 64' 9. Well Name and Number: PBU 07-01 A 8. Property Designation: ADL 028309 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11823 feet true vertical 8992 feet Plugs (measured) 8112 Effective depth: measured 8112 feet Junk (measured) None true vertical 7777 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20· 110' 110' 1530 520 Surface 2714' 13-3/8" 2714' 2714' 4930 2670 Intermediate 8670' 9-5/8" 8670' 8228' 6870 4760 Production Liner 1085' 7" 8337' - 9422' 7963' - 8846' 8160 7020 Liner 3635' 3-1/2" x 2-7/8" 8188' -11823' 7841 ' - 8992' Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 0270' - 11798' 9050' - 9000' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2",11.6#/12.6# 5-1/2", 17# x 4-1/2", 9-5/8" x 5-1/2" Baker 'SAB' packer; 9-5/8" x 4-1/2" Baker 'S-3' packer 13Cr L-80 / N-80 Surface - 8052' 8047' - 8255' 8132'; 7917' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Ft MAH 0 9 2006 Oil-Bbl Re resentative Dail Gas-Mcf Water-Bbl Tubin Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run IS! Daily Report of Well Operations DWell Schematic Diagram 15. Well Class after proposed work: o Exploratory IS! Development 0 Service 16. Well Status after proposed work: IS! Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my nowe ge. Sundry Number or N/A if C.O. Exempt: NIA 17. Printed Name Terrie Hubble Signature /(Ó. Form 10-404 Revised 04/2004 Title Technical Assistant ORIGINAL 03/éÆJ 101 _ Prepared By Name/Number: '. I ( \ÇTerrie Hubble, 564-4628 Submit Original Only e BP EXPLORATION Operations Summary Report legal Well Name: 07-01 Common Well Name: 07-01 Event Name: WORKOVER Contractor Name: DOYON DRilLING INC. Rig Name: DOYON 16 Date I From - To Hours Task Code I m.u.... ....0 ..._.__n P NPT! Phase DECOMP DECOMP DECaMP DECOMP DECaMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECaMP DECOMP 1/21/2006 00:00 - 06:00 6.00 MOB P 06:00 - 10:30 4.50 MOB P 10:30 - 00:00 13.50 MOB P 1/22/2006 00:00 - 12:00 12.00 MOB P 12:00 - 00:00 12.00 MOB P 1/23/2006 00:00 - 10:30 10.50 MOB P 10:30 - 00:00 13.50 MOB P 1/24/2006 00:00 - 06:00 6.00 MOB P 06:00 - 18:00 12.00 MOB 18:00 - 00:00 6.00 MOB 1/25/2006 00:00 - 06:00 6.00 MOB 06:00 - 12:00 6.00 MOB 12:00 - 14:00 2.00 MOB 14:00 - 15:00 1.00 MOB 15:00 - 18:00 3.00 MaS 18:00 - 21 :00 3.00 KILL 21 :00 - 21 :30 0.50 KILL 21 :30 - 00:00 2.50 KILL 1/26/2006 P P P P P P P P P 00:00 - 00:30 Ip 0.50 KILL 00:30 - 01 :00 01 :00 - 04:30 0.50 WHSUR P 3.50 WHSUR P 04:30 - 08:30 08:30 - 10:00 10:00 - 15:00 4.00 BOPSUF P 1.50 BOPSUF P 5.00 BOPSUF P Page 1 of 7 Start: Rig Release: Rig Number: Spud Date: 6/5/1978 End: 1/23/2006 2/4/2006 Description of Operations .n.u..._. __..... _n. ___... __ ___.__.._ Move Rig Off Z-24. Spot Rig on Pad and Lay Over Derrick. Remove BOPE From Cellar. Install Boosters on Rear of Sub. Prepare Sub for Move. Move Rig Off Z-Pad to the Spine Road. Stop Before Crossing Kuparuk Bridges. Temperature Below Lower Threshold. Wait on Weather Wait on weather. Service rig. Wait on weather. Remove rear boosters and button up rig. Wait on Weather. Currently in Phase 2 Level 2. Waiting on Weather. Weather went to Phase 3 at 10:30 hours. Made Crew Change at 12:00 hours with West IMT Approval. Relieved Crew Returned to Camp at 13:00 Hours. Waiting on Weather. Currently in Phase 3 Conditions. Crew Change made with West IMT Approval. Relieved Crew Returned to Camp at 01 :00 Hours. Waiting on Weather. Conditions Lowered to Phase 1. Clearing Roads Before Rig Move. Move Doyon 16 Across Kuparuk River Bridges to DS-7. Move Rig to DS-07. Raise Derrick, Remove Rear Boosters, Rig Up Floor and Derrick. Transfer BOPE to Platform in Cellar. Lay Herculite and Spot Mats. Spot Sub Over Well 07-01A. Secure Cellar. Bridal Down, Hang Bridal Lines, Spot and Berm Cuttings Tank. Install Secondary Annulus Valve. Rig Accepted at 18:00 Hours. Take on 120 Degree Seawater. Rig Up DSM and Pull SPV. BPV Was Frozè Up in Tree. PJSM, Hook Up Lines and Test. Line Up and Circulate Freeze Protect Out of Well. Displace Well With 600 bbls of Clean 120 Degree Seawater. Pump Rate 450 psi at 270 gpm. Displace Well to Clean 120 Degree Seawater. Pump Rate 270 gpm at 450 psi. Unhook Lines from Tree and Blowdown. Nipple Down Tree. Remove Tree from Cellar. Inspect Hanger, Function Lock Down Screws, Test XO, Made Up 18 Turns. Nipple Up BOPE. Rig Up BOP Test Assembly. Test BOPE to 250 psi Low and 3,500 psi High. Test #1 Hydril, Upper IBOP, Kill HCR. Test #2 Lower IBOP, Manual Kill. Test #3 Dart Valve. Test #4 TIW Floor Valve. Test #5 Manual Choke Valve. Test #6 Choke HCR. Test #7 Choke Manifold Valves 1,12,13, and 14. Test #8 Blinds and Valves 9, 11. Test #9 Choke Valves 5,8 and 10. Test #10 Choke Valves 4,6 and 7. Test #11 Choke Valve 2. Test #12 Choke Valve 3. Test Witnessed by Doyon Toolpusher and BPX WSL. Witness Printed: 2/6/2006 1 :30:37 PM e BP EXPLORATION Operations Summary Report Legal Well Name: 07-01 Common Well Name: 07-01 Event Name: WORKOVER Start: 1/23/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 2/4/2006 Rig Name: DOYON 16 Rig Number: Date I From - To Hours Task Code NPT ¡ Phase ----..- .._ ....__n_.. --.....-- . .... 1/26/2006 10:00 - 15:00 5.00 BOPSUF P 15:00 - 16:30 1.50 BOPSUF P 16:30 - 18:00 1.50 BOPSUF P 18:00 - 20:00 2.00 BOPSUF P 20:00 - 21 :00 1.00 BOPSUF P 21 :00 - 23:00 2.00 BOPSUF P 23:00 - 00:00 1.00 BOPSUF P 1/27/2006 00:00 - 01 :00 1.00 CLEAN P 01 :00 - 02:00 1.00 CLEAN P 02:00 - 02:30 0.50 CLEAN P 02:30 - 04:30 2.00 CLEAN P 04:30 - 06:00 1.50 CLEAN P 06:00 - 14:30 8.50 CLEAN P 14:30 - 15:00 0.50 CLEAN P 15:00 - 16:00 1.00 CLEAN P 16:00 - 19:30 3.50 CLEAN P 19:30 - 21 :00 1 .50 CLEAN P 21 :00 - 00:00 3.00 CLEAN P 1/28/2006 00:00 - 00:30 0.50 CLEAN P 00:30 - 01 :00 0.50 CLEAN P 01 :00 - 07:00 6.00 CLEAN P 07:00 - 08:00 1.00 FISH P Page 2 of 7 Spud Date: 6/5/1978 End: Description of Operations ......-.. ____ n. ..._ .........-... .-. .-.... DECOMP of Test was Waived By Chuck Sheave of AOGCC. DECaMP Rig Up and Pull TWC. Had Problems Stabbing Into Dart. DECOMP PJSM with All Personnel Involved, Rig Up SWS Wireline Unit. DECOMP RIH with 4.56" aD Dummy Valve, RIH with Plug Prong, POOH with Running Tool. DECOMP Test Lower Pipe Rams to 250 psi Low and 3,500 psi High. Perform Accumulater Test. 2950 psi Starting Pressure. 1,750 psi After Closing. Regained 200 psi in 13 Seconds, Back to 2,950 psi in 1 Minute and 12 Seconds. DECOMP RIH with Wire line and Pull Prong and Dummy Valve. DECOMP Rig Down SWS Wireline Unit. DECOMP MIU Spear Assembly. DECOMP Spear Into Tubing and Back Out Lock Screws. DECOMP Work Pipe. P/U to 215,000#, SIO to 70,000#. Work Pipe, Increasing Pull. Pipe Pulled Free at 308,000#. Pull Tubing Hanger to Floor. Up Weight 130,000#. DECaMP Lay Down Spear Assembly and Tubing Hanger. DECOMP Circulate Bottoms Up. Pump Rate 334gpm at 460 psi. DECOMP Lay Down 5.5" Tubing (36 clamps, SSSV, 192 Jts). Estimated Top of Fish 6,200'. DECOMP Clean & Clear Rig Floor. DECOMP Install Wear Ring ( Clear Rubber From Stack) DECOMP Load and Tally 2 7/8" Pac DP Into Pipe Shed DECOMP MIU Mechanical Cutter Assembly, DECOMP P/U 2 7/8" PAC DP From Pipe Shed. DECOMP P/U 2 7/8" DP from Pipe Shed F/1871' to 2194'. BHA Consists of 3.75" Mechanical Cutter,4.375" Stabizer 2.875" PAC DP, XO, XO. Total BHA Length 2194.29' DECOMP RID 2 7/8" Handling Equipment, RIU 4" Handling Equipment. DECOMP P/U 4" HT-38 DP Frorn Pipe Shed to 7,945' DECOMP Made up Topdrive and establish parameters. Up WI = 137k, dn WI = 137k, rt WI = 140k, 20 rpm, torque = 1.5k. Worked string down slowly, set down 10k at 7,951' (Sliding Sleeve) attempt to work string past 7,951' no go. Pulled up to 7,945' and establish rotation 20 rpm, 1.5k torque. Work string down with slow rotation, set down at 7,951' stalled topdrive with 4.5K torque, 15k over pull to get free. ( suspect rubber frorn control line clamps in sliding sleeve) Pulled back to 7,945' and establish circulation @ 1.4 bpm @ 470 psi. Pumped 6.5 bbl, string pressured up to 2600 psi. bled off attempt to regain circulation, would not circulate. POH from 7,945' to 7,566' Madeup topdrive every two stands in an attempt to regain circulation, no circulation. RIH from 7,566' to 7,927', Position Baker mechanical casing cutter at 7,927' (rniddle of the first full joint above the sliding sleeve. Begin cutting operations, 100 rpm, torque 2.5k, 1 bpm, 770 psi with full returns. Increased flow rate to 2 bpm 1,250 psi. pressure started dropping steadily to 700 psi, indicating tubing is cut. Shut down rotary and pumps, Pulled up 5' above cut, engaged pump @ 2 bpm 1200 psi slowly worked back down to the cut, pressure dropped to 600 psi as knives entered tubing cut, set 08:00 - 09:00 1.00 FISH P DECOMP 09:00 - 10:00 1.00 FISH P DECOMP 10:00 - 10:30 0.50 FISH P DECaMP Printed: 2/6/2006 1 :30:37 PM , BP EXPLORATION Page 3 of 7 Operations Summary Report Legal Well Name: 07-01 Common Well Name: 07-01 Spud Date: 6/5/1978 Event Name: WORKOVER Start: 1/23/2006 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/4/2006 Rig Name: DOYON 16 Rig Number: I Task i Code I NPT Date i From - To Hours Phase Description of Operations I ....1 I .1 ..----- I . .____n_ . . -- -... -.--.--. - - __n... 1/28/2006 10:00 - 10:30 0.50 FISH P DECOMP down 7k on knives to confirm top of cut. 10:30 - 13:30 3.00 FISH P DECOMP Blow down top drive, POH with casing cutter to 2194' 13:30 - 15:30 2.00 FISH P DECOMP Monitor Well, Fluid Weight 8.5 ppg. POOH and UD 2.875" PAC DP, UD Cutter Assembly. 15:30 - 16:00 0.50 FISH P DECOMP Clean and Clear Rig Floor. 16:00 - 19:00 3.00 FISH P DECOMP P/U Overshot BHA to 962.68', 19:00 - 21 :00 2.00 FISH P DECOMP RIH w/4" HT-38 DP to 6140' 21 :00 - 22:30 1.50 FISH P DECOMP MIU Top Drive to Establish Parameters, 147,000# Down Weight, 147,000 # Down Weight, 185 gpm at 280 psi. Wash to 6229', Tag up at 6229', Pressure increase to 390 psi, SIO to 130,000#, P/U TI 147,000#, Rotate Slowly 3,000# Torque, SIO t/ 120,000#, Pressure increase to 750 psi, PIU t/ 147,000#, SIO t/ 105,000#, P/U t/ 150,000#, SIO t/ 105,000#, P/U t/ 160,000#, P/U t/ 200,OOO#,S/O t/ 125,000#, P/U t/ 200,000#, Jarred P/U t/ 210,000#, SIO t/ 125,000#, P/U t/ 210,000# Jarred P/U t/ 225,000#, SIO t/ 125,000#, P/U t/ 225,000# Worked at 225,000# Tubing Came Free, Up Weight 175,000#. 22:30 - 00:00 1.50 FISH P DECOMP Monitor Well Fluid Weight 8.5 PPG, POOH. 1/29/2006 00:00 - 01 :30 1.50 FISH P DECaMP POOH f/3808' t/BHA 01 :30 - 02:30 1.00 FISH P DECaMP Stand back BHA and CIO Handling Equipment, UD Intensifier, Stand Back DIC, UD Jars and XO 02:30 - 03:00 0.50 FISH P DECOMP UD 1 joint 5.5" Tubing and Grapple 03:00 - 03:30 0.50 FISH P DECOMP RIU to Laydown 5.5" Tubing, MIU Floor Valve, Clear Rig. 03:30 - 06:30 3.00 FISH P DECOMP Lay Down 5.5" Tubing. Recovered 51 joints, plus cut joint 27.30' 06:30 - 07:30 1.00 FISH P DECOMP Rig down 5.5" tongs and handling equipment, rig up 2 7/8" tongs and handling equipment. 07:30 - 08:00 0.50 FISH P DECOMP Service rig and Topdrive 08:00 - 08:30 0.50 FISH P DECOMP Make up BHA #4 , 27/8" bull nose, 3 3/4" Multi string csg. cutter, 2 XOs, 5 joints 2 7/8" Pac DP, 2 XOs. 08:30 - 09:00 0.50 FISH P DECOMP Rig down 2 7/8" tongs and handling equipment. 09:00 - 13:00 4.00 FISH P DECOMP RIH with 3 3/4" casing cutter on 4" DP to 5,922'. RIH picking up 4" DP from pipe shed to 7,908' 13:00 - 14:00 1.00 FISH P DECOMP Make up topdrive and establish parameters, up wt = 147k, dn wt = 144k, rt wt = 145k. Slack off slowly from 7,908' set down 5k on tubing stub at 7,927' attempt to enter tubing stub, by rotating string slowly, no go repeat several times with no sucsess. Pulled up to 7,920 engage pumps to clear any debris from cutters. pressured up on string to 1,500 psi, no circulation. made several attempts to establish circulation by surging string no success. 14:00 - 18:30 4.50 FISH P DECOMP POH with casing cutter. F/7927' T/166'. Pulled Wet, Plugged BHA. 18:30 - 19:30 1.00 FISH P DECOMP Rig Up to Handle 2 7/8", Lay Down BHA. 19:30 - 20:00 0.50 FISH P DECOMP Clean Rig Floor. 20:00 - 21 :00 1.00 FISH P DECOMP Change Out Saver Sub 21 :00 - 22:30 1.50 FISH P DECaMP Make Up BHA, Rig Down 2 7/8" Handling Equipment. RIH wlClean Out Assembly.3.75" Junk Mill, Bit Sub, 5 jts 2.875" PAC DP, XO, XO PxP, 7" Boot Basket, 7" Boot Basket, Bit Sub, 4.75 Bowen Oil Jar, Pump Out Sub, XO. Total BHA = 189.77'. 22:30 - 00:00 1.50 FISH P DECOMP RIH Frorn 190' to 3642' Up Weight 95,000#, Down Weight e Printed: 2/6/2006 1 :30:37 PM BP EXPLORATION Operations Summary Report i Phase I ...m._1 DECOMP 93,000#. DECOMP RIH wlClean Out Assembly.3.75" Junk Mill, Bit Sub, 5 jts 2.875" PAC DP, XO, XO PxP, T' Boot Basket, 7" Boot Basket, Bit Sub, 4.75 Bowen Oil Jar, Pump Out Sub, XO. Total BHA = 189.7T. DECOMP Cut and Slip Drilling Line, 94' DECOMP Wash Down fl 7385' t/7,92T. Parameters, Up Weight 147,000#, Down Weight 145,000#, Rotating Weight 146,000#. 178 gpm at 600 psi Pump Pressure. 20 rpm at 2,000 ft/lbs Torque. Work Into Top of 5.5" Tubing at 7,92T. Wash and Ream from 7,92T to 8,083'. Circulate 40 bbl High Vis Sweep Around. 390 gprn at 2,040 psi. Monitor Well. Fluid Weight 8.5 ppg. POOH from 8,083' to 189' Lay Down Clean Out BHA. Clean Out Junk Baskets. Recovered Sand and Cernent. Clear and Clean Rig Floor. Make Up Mechanical Cutter BHA. BHA Consists of 2.875" Regular Bull Nose, 3.75" Multi-String Cutter. XO, XO, 5 Joints 2.875" Pac Drill Pipe, XO, XO. BHA Total Lenght Equals 166.7T DECOMP RIH with 4" HT-38 Drill Pipe from 166' to 7,844'. DECOMP Establish Parameters. Up Weight 146,000#, Down Weight 143,000#, Rotating Weight 146,000#, 20 rpm at 2,000 ft/lbs Torque, 106 gpm at 300 psi. Locate Collars at 8,028' and 8,06T. Position Cutter 8,044', Engage Rotary at 10 rpm, Engage Knives 153 gpm at 660 psi, Increase Rotary to 80 rpm, Rotary Torque 4,500 ft/lbs. Positive Indication Cut was Made, Shut Off Pumps, Pick Up 5' Engage Pumps Slack Off 5' Set Down 5,000# to Confirm Cut. Monitor Well Fluid Weight 8.5 ppg, Pump Dry Job, POOH to 166'. UD 3.75 Cutter BHA Assembly. Clear and Clean Rig Floor. Make up Overshot BHA. BHA Consists of 8.125" Overshot, 6.25" Bowen Bumper Sub, 6.25" Bowen Jar, XO, 9 Drill Collars, XO, 6.25" Bowen Int, XO, 21 Joints Heavy Weight DP. Total Length 963.16'. RIH to 7870'. Established Parameters Up Weight-176,OOO#, Down Weight-164,OOO#, Rotating Weight-173,000#, 20 RPM at 2,500 Torque. Wash Over Fish at 792T w/10 rprn, 4,000 ft/lbs Torque, 178 gpm, at 300 psi. Saw Increase in Pump Pressure to 600 psi. Picked up to 225,000# Jarred, Slack of to 140,000#, Picked up to 225,000# Jarred, Slacked of to 140,000#. Picked up to 235,000# Jarred. Slacked off to 140,000#. Picked up to 245,000# Came Free. 10,000# Over Up Weight. Circulate Bottoms Up. Pump Rate 355 gpm, 1100 psi. Monitor Well, Fluid Weight 8.5 ppg. POOH f/9727 to 963' Stand Back BHA, UD Grapple and Release Fish. UD 5" Cut Joint, Lenght 15.48' and Sliding Sleeve Assembly, 2 Joints of 5.5" Tubing. RID Tubing Handling Equipment, Clear and Clean Rig Floor. Legal Well Name: 07-01 Common Well Name: 07-01 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 I I· I I Date .j~~om - To Hours. Tas_k ___~~d~ I NPT. 1/29/2006 22:30 - 00:00 1.50 FISH P 1/30/2006 00:00 - 02:00 2.00 FISH P 02:00 - 03:00 03:00 - 04:30 1.00 FISH 1.50 FISH P P 04:30 - 06:30 2.00 FISH P DECOMP 06:30 - 08:00 1.50 FISH P DECOMP 08:00 - 11 :00 3.00 FISH P DECOMP 11 :00 - 12:30 1.50 FISH P DECOMP 12:30 - 13:00 0.50 FISH P DECOMP 13:00 - 14:00 1.00 FISH P DECOMP 14:00 - 17:00 17:00 - 18:00 3.00 FISH 1.00 FISH P P 18:00 - 21 :00 3.00 FISH P DECOMP 21 :00 - 22:00 1.00 FISH P DECOMP 22:00 - 22:30 0.50 FISH P DECOMP 22:30 - 00:00 1.50 FISH P DECOMP 1/31/2006 00:00 - 03:00 3.00 FISH P DECOMP 03:00 - 04:00 1.00 FISH P DECOMP 04:00 - 04:30 0.50 FISH P DECOMP 04:30 - 06:00 1.50 FISH P DECOMP 06:00 - 08:30 2.50 FISH P DECOMP 08:30 - 10:30 2.00 FISH P DECaMP 10:30 - 11 :30 1.00 FISH P DECOMP 11 :30 - 12:00 0.50 FISH P DECOMP Page 4 of 7 Start: Rig Release: Rig Number: Spud Date: 6/5/1978 End: 1/23/2006 2/4/2006 Description of Operations __ _.n... __..___... Printed: 2/6/2006 1 :30:37 PM BP EXPLORATION Operations Summary Report Legal Well Name: 07-01 Common Well Name: 07-01 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date I From - To Hours Task Code NPT I 1/31/2006 12:00 - 13:00 1.00 FISH P 13:00 - 15:30 2.50 FISH P Page 5 of 7 Spud Date: 6/5/1978 End: Start: 1/23/2006 Rig Release: 2/4/2006 Rig Number: i Phase I ________1.__ _.. ..___ __. _________...._ DECOMP P/U and Break Down Over Shot, Prepared Dress Off BHA. DECOMP Make Up and RIH with Dress Off BHA. 8.5" OD x 5.5" ID Dress Off Shoe, Wash Pipe Extension, Dress Off Mill w/4.875" Stinger, Wash over Boot Basket/Triple Conn, Double Pin Sub,7" Boot Basket, 1" Boot Basket, 95/8" Casing Scraper, Bit Sub, XO, Bowen Jar, XO, 9 - 6.25" Drill Collars, XO, XO, 21 Joints of HWDP. BHA Total = 970.81' DECOMP RIH From 970' to 7970' w/4" HT DP. DECaMP Established Parameters-184,000# Up, 161,000# Down, Pump On 184,000# Up, 160,000# Down, Pump Rate 355 GPM, 1,260 psi, Rotating Weight 174,000#, 20 RPM, Torque 3,000#. Milled f/8,044' to 8,055' With Maximum of 5,000# WOB. Slid On And Off Tubing Stump Several Times Without Pumps or Rotating, No Problems. Pumped 40 bbl Hi-Vis Safe Clean Sweep at 390 gpm and 1150 psi. RIU To And Reverse Circulated Well at 355 gpm and 1620 psi. RID Reversing line, Blew Down Top Drive and Kill Line. POOH From 7973 to BHA. UD HWDP to Pipe Shed, 14 Joints P/U Storm Packer, Set at 38' and test to 1,000 psi. Pulled Wear Ring. Attempt to Retrieve Pack Off Though The BOP Stack Unsuccessful. Nipple Down BOPs to Change Out 9 5/8" Pack Off. Attempt to Pull Pack-Off Through Tubing Spool With RetievingTool. Retrieving Tool Dogs Failed, Nipple Down Tubing Spool, Working On Removing Pack Off From Tubing Spool, Cleaning Tubing Spool Profile. Installing New 9 5/8" Pack-Off Nipple Up Tubing Spool and Test to 5,000 psi. Nipple Up BOPs R/U to Test Tubing Spool and BOPE - Test 250 psi Low, 3,500 psi High. RID BOP Test Equipment, Pull Test Plug and Install Wear Ring. RIU to Retrieve Storm Packer and Lay Down Same. POOH and UD 6.25" Drill Collars. UD Baker Tools Clean and Clear Rig Floor. P/U and MIU BHA. BHA Consists of 3.625" RSJB wi 3.75" aD Shoe, Bit Sub, 2 Joints 2.875" DP, XO, 4.75" Bowen Jar, Pump Out Sub, XO, 6 Joints HWDP. BHA Length =269.38'. RIH From 270' to 8,040' MIU Top Drive and Establish Parameters, 151,000# UP, 146,000# Down, Rotating 151,000#,20 rpm, Torque 3,000 fVlbs, Pump On Weight Up 151,000#, Down 148,000#, 178 gpm, 2000 psi, Wash and Ream From 8,040' to 8,105' Pump 40 bbl Hi-vis Sweep at 178 gpm, Pump Pressure 1980 psi. Pump Dry Job. Blow Down Top Drive. Monitor Well, Fluid Weight 8.5 ppg. POOH Laying Down Drill Pipe Laying Down 4" HT-38 Drill Pipe. Laying Down Clean Out BHA. 15:30 - 18:00 18:00 - 18:30 2.50 FISH 0.50 FISH P P 18:30 - 20:00 1.50 FISH P DECaMP 20:00 - 20:30 0.50 FISH P DECaMP 20:30 - 21 :00 0.50 FISH P DECaMP 21 :00 - 00:00 3.00 FISH P DECOMP 2/1/2006 00:00 - 00:30 0.50 FISH P DECaMP 00:30 - 01 :00 0.50 FISH P DECaMP 01 :00 - 02:00 1.00 FISH P DECOMP 02:00 - 03:00 1.00 FISH P DECOMP 03:00 - 04:00 1.00 FISH P DECOMP 04:00 - 05:30 1.50 FISH P DECOMP 05:30 - 07:00 1.50 FISH P DECOMP 07:00 - 07:30 0.50 FISH P DECaMP 07:30 - 09:00 1.50 FISH P DECaMP 09:00 - 10:30 1.50 FISH P DECOMP 10:30 - 11 :30 1.00 FISH P DECOMP 11 :30 - 12:30 1.00 FISH P DECOMP 12:30 - 13:30 1.00 FISH P DECOMP 13:30 - 16:00 2.50 FISH P DECaMP 16:00 - 16:30 0.50 FISH P DECOMP 16:30 - 17:00 0.50 FISH P DECOMP 17:00 - 20:00 3.00 FISH P DECOMP 20:00 - 20:30 0.50 FISH P DECOMP 20:30 - 23:00 2.50 FISH P DECOMP 23:00 - 00:00 1.00 FISH P DECaMP 2/2/2006 00:00 - 06:30 6.50 P DECOMP 06:30 - 07:30 1.00 FISH P DECOMP Description of Operations - ..---------.-----. ... . "n.._ _____ Printed: 2/6/2006 1 :30:37 PM BP EXPLORATION Operations Summary Report Page 6 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2/2/2006 07:30 - 08:00 08:00 - 08:30 08:30 - 10:00 07-01 07-01 WORKOVER DOYON DRILLING INC. DOYON 16 From - To ! Hours Task I Code I NPT ¡ __.___L____ . 0.50 FISH P 0.50 FISH P 1.50 FISH P Start: Rig Release: Rig Number: I Phase I 1/23/2006 2/4/2006 Spud Date: 6/5/1978 End: Date Description of Operations 10:00 - 10:30 10:30 - 12:30 12:30 - 00:00 0.50 FISH P 2.00 RUNCO 11.50 RUNCO DECOMP Rig Down 2 7/8" Handling Equipment. DECOMP Clear and Clean Rig Floor. DECOMP Pull Wear Ring, MIU Landing Joint and Tubing Hanger, Make Dummy Run. DECOMP Break Off Tubing Hanger, Lay Down Landing Joint. RUNCMP RIU To Run 4.5" Chrome Tubing. RUNCMP RIH With 4.5" Chrome Tubing, 11.6#, 13CR-95,VAM TOP. To 8,042'. Up Weight 118,000#. Down Weight 117,000#. Ran a Total of 191 Joints, 4 Gas Lift Mandrels, 3 x Nipples, 1 XN Nipple, and Unique Over Shot and Packer. 2/3/2006 00:00 - 00:30 0.50 RUNCO RUNCMP Rig Up Circulating head and lines. 00:30 - 01 :30 1.00 RUNCO RUNCMP Washed Down Over Tubing Stump, Pumping at 3 BPM w/150psi. Saw Pressure Increase As Overshot Swallowed Tubing Sturnp 3 BPM To 250 psi, Observed pins Shear 6,000#, Continued to Wash Down to No-Go at 8,064'. 01 :30 - 02:00 0.50 RUNCO RUNCMP UD Circulating Head, UD Joints #191 and #190. 02:00 - 03:00 1.00 RUNCO RUNCMP MIU Tubing Hanger and Space Out Pups and Land Tubing Hanger, RILDS. 03:00 - 07:00 4.00 RUNCO RUNCMP Pump 145 bbl Clean Sea Water heated to 120 Deg, Followed By 431 bbl Of Clean 120 deg Sea Water Treated wlCorrosion Inhibitor at 3 BPM At 710 psi. 07:00 - 07:30 0.50 RUNCO RUNCMP Rig down circulating head, blow down lines. 07:30 - 08:00 0.50 RUNCO RUNCMP Drop 1 7/8" ball and rod, back out and lay down landing joint. Service rig. 08:00 - 10:00 2.00 RUNCO RUNCMP Pressure up on tubing to 3,500 psi to set Packer and test tubing for 30 min record on chart. 150 psi loss in 30 min. Bled tubing pressure to 2,000 psi. Pressured up on annulus, to 3,500 psi. Once annulus pressure reached 2,000 psi both annulus and tubing pressure increased to 3,500 psi at the same rate. Held 3,500 psi for 5 min, bled annulus pressure to zero, tubing pressure bled off to 3,000 psi at the same rate as annulus then held 3,000 psi. bled tubing pressure to zero. Opened blind rams and drained stack, sucked fluid from tubing. Pressured up on annulus to 1000 psi, observed fluid leaking up tubing, pressure bled to 410 psi in 5 min. 10:00 - 12:30 2.50 ZONISO N DPRB INTERV Blow down all lines and test manifold, Wait on slick line unit to arrive on location. 12:30 - 13:00 0.50 ZONISO N DPRB INTERV Held PJSM, Spot Schlumberger slick line unit. 13:00 - 14:30 1.50 ZONISO N DPRB INTERV Held PJSM, Rig up Slick line unit. 14:30 - 15:30 1.00 ZONISO N DPRB INTERV RIH with Slip stop catcher and set @ 3382' POH, Lay down catcher running tool. 15:30 - 18:30 3.00 ZONISO N DPRB INTERV Pickup and RIH with DCR valve pulling tool, pull valve from upper GLM @ 3240', POH and lay down valve, Make up and set dummy in upper GLM @ 3,240', POH with setting tool, Make up Slip stop catcher pulling tool and pull catcher. POH. 18:30 - 20:00 1.50 ZONISO N DPRB INTERV Test TBG 1/3500 psi f/30 min. Bled TBG 1/2000 psi. Pressure Test Annulus 1/3500 psi f/30 min. Good Test. Blow Down Surface Lines. 20:00 - 21 :30 1.50 ZONISO N DPRB INTERV MIU Catcher Assembly RIH Set at3,408'. POOH Printed: 2/6/2006 1 :30:37 PM BP EXPLORATION Operations Summary Report Page 7 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 07-01 07-01 WORKOVER DOYON DRILLING INC. DOYON 16 I I I . Hours Task, Code NPT Spud Date: 6/5/1978 End: Start: 1/23/2006 Rig Release: 2/4/2006 Rig Number: I Phase I Description of Operations .. ........ _.... __... __ _ .... ..... ....'h·__ __ 2/3/2006 1.00 ZONISO N 1.50 ZONISO N 0.50 ZONISO N 1.00 WHSUR P 21 :30 - 22:30 22:30 - 00:00 00:00 - 00:30 00:30 - 01 :30 DPRB INTERV DPRB INTERV DPBR INTERV OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP MIU Retieving Tool RIH Retrive Dummy Valve, POOH MIU Catcher Assembly RIH and Retrieve Catcher. RID Wire Line RIU Drill Site Maintenance, Set Two Way Check, Test 1000 psi f/5 rnin. PJSM Nipple Down BOPE. Clean Tubing Spool, R/U Adapter Flange, RIU Tree and Test Same. RIU To Test Adapter Flange. Test Adaper Flange and Tree to 5000 psi.Blank Flange Leaked. Re-Tightened Blank Flange. Test Tree, Blank Flange Leaked. CIO Blank Flange. Test Tree, Leaked. CIO Blank Flange. Test Tree and Adapter Flange to 5000 psi for 30 min. RIU Pull TWC and Test Dart. PJSM With Little Red. Test Lines To 3500 psi. Leak on I/A Valve Stem Packing. Repair Valve Stern Packing. Test Lines to 3500 psi. Pump Freeze Protect. 140 bbl at 3 bpm 200 psi. U- Tube. Blow Down Lines R/U DSM Set BPV Test t/1000 psi. Blow Down and Rig Down Lines Rig Down DSM and Little Red. Secure Well Move Slop Tank Prepare For Rig Move. Rig Released 15:00 hrs. 2/4/2006 1.50 BOPSU P 2.50 WHSUR P 01 :30 - 03:00 03:00 - 05:30 0.50 WHSUR P 0.50 WHSUR P 05:30 - 06:00 06:00 - 06:30 0.50 WHSUR P 0.50 WHSUR P 0.50 WHSUR P 0.50 WHSUR P 0.50 WHSUR P 0.50 WHSUR P 0.50 WHSUR P 0.50 WHSUR P 06:30 - 07:00 07:00 - 07:30 07:30 - 08:00 08:00 - 08:30 08:30 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 - 10:30 0.50 WHSUR P 1.00 WHSUR P 10:30 - 11 :00 11 :00 - 12:00 1.00 WHSUR P 1.00 WHSUR P 0.50 WHSUR P 0.50 WHSUR P 12:00 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 15:00 Printed: 2/6/2006 1 :30:37 PM TREE = GRA Y GEN 2 WELLf'tEA:D = GRA Y e ACTUA TOR = AXELSON KB. ELEV = 64' BF. ELEV = KOP = 4900' Max Angle = 109 @ 11763' Datum MD = 9445' Datum TVD = 8800' SS I 13-3/8" CSG. 72#, N-80, ID = 12.347" Minimum ID = 2.375" @ 10005' TOP 2-7/8" TBG 07-01A e Actual Completion 4-1/2" HES 9Cr X- NIP, ID - 3.813" PKG Bore GAS LIFT MANDRELS TVD DEV TYÆ VLV LATCH 3241 1 MMG 0 0 5480 23 MMG DMY RK 6491 30 MMG DMY RK 7507 26 MMG DMY RK PORT DATE o Feb,2 06 o Feb,2 06 o Feb,2 06 o Feb,2 06 4-1/2" HES 9Cr X - NIP, ID = 3.813" PKG Bore 9 S/8" X 4 1/2" Baker S-3 Packer, 3.870" ID 4-1/2" HES 9Cr X - NIP, ID = 3.813" PKG Bore I 4-112" TBG, 11.6#, 13Cr-95, .01554 bpf, ID = 4.00" 4-1/2" HES 9Cr XN - NIP, ID = 3.72S",RHC Plug 9 5/8"x 5-1/2" UMI Chrome Overshot I 5-1/2" 17# L-80 Tubing stub 5-1/2" BKR SBR ASSY 1 IS-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 1 TOP OF 4-1/2" TBG 1 3-3/8" WEATHERFORD IBP SET 08/24/04 9-S/8" X S-1/2" BAKER SAB PKR 1 S-1/2" X 4-1/2" XO I 3-1/2" BAKER DEPLOY SLV, ID = 3.000" TOP OF 3-1/2" LNR I I 4-1/2" TBG, 12.6#, N-80, .0152 bpf, ID = 3.958" 1 8228' 4-1/2" CAMCO DB-6 NIP, ID = 3.813" (BEHIND CT LNR) ELMD TT LOGGED 07/29/89 I 4-1/2" TUBING TAIL (BEHIND CT LNR) TOP OF 3-3/16" LNR H 8287' I TOP OF 7" LNR I 9-S/8" CSG, 47#, N-80, ID = 8.681" H 8670' 1_ 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.8" I I TOPOF2-7/8"LNRI 3-1/2" X 3-3/16" XO, ID = 2.79" 1 ~ -i 3-3/16" X 2-7/8" XO, ID = 2.375" 1 7" MILLOUT WINDOW 9423' - 9429' Note: SIZ E 1·11/16" 2" 2" 1-11/16" 2-118' PERFORATION SUMMARY REF LOG: BHCS ON 07/04/78 ANGLE AT TOP PERF: 92@ 10270' Refer to Production DB for historical erf data SPF INTERVAL 0 n/S z DATE 4 10270 - 10500 C 01/10/98 4 10550-10800 C 12/12/00 4 11000·11200 C 12/12/00 4 11280 -11651 C 01/10/98 4 11760 - 11798 C 08/24/98 T' LNR, 29#, N-80, .0371 bpf, ID = 6.184" I 2-7/8" LNR, 6.4#, L-80, .0058 bpf,ID=2.441" 1 DATE 07/78 01/15/98 09/20/01 08/19/04 08/21/04 08/23/04 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER RNITP CORRECTIONS LDKlTLP SET BAKER IBP DFRlTLP 3-1/2" LNR ELMD LDKlTLP SET BAKER IBP@ 8111' DATE 08/24/04 03/30/05 10/12/0S 11/13/05 02/03/06 REV BY COMMENTS LDKlTLP WEATHERFORD IBP @ 8111.S' 1WClTLH CORRECTIONS GJB/PJC TBG PUNCH GJB/PJC CHEM CUT TBG BJB Doyon 16 RYVO PRUDHOE BAY UNIT WELL: 07-01A ÆRMIT No: "'1971530 API No: SO-029-20272-01 SEC34, T11N, R14E. 834.31' FEL & 3147.6S' FNL BP Exploration (Alaska) (C( 7 -(53 03/15/05 Schlumberger NO. 3363 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: 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 ¡ q.3 -cr-lý. C-39 10715421 MCNL 08/19/04 1 '1/.. ¡:'{7-R<? E-21A 10670030 MCNL 08/22/04 1 19,,- nc' C-29A .~ 10715422 MCNL 08/22/04 1 Y J.G'3· i!:)..DS 07-33B 10715361 MCNL 11/04/03 1 1 F-tJ-153-07-01A 10889151 RST 08/18/04 1 1 ;~f . 9 X-27 10724364 RST 03/10/04 1 1 ^""ð' "W 10621786 RST OS/22/04 1 1 .~ .--: E-18A !.~7:C:,¥· I DS 01-24A 10563108 RST 10/09/03 1 1 , l- I~ E-10A 10621797 RST 06/16/04 1 1 ¡?it¡ -/02- Z-12 10704020 RST 07/06/04 1 1 ZOI~ Oc¡, X-15A 10704021 RST 07/07/04 1 1 7:Þi..C?:>1 P1-07 A 10831301 RST 07/03/04 1 1 '1-1.. C7{):G-03A 10889210 LDL 02/13/05 1 4Ç';i·ll? L5-17A 10942195 PSP PPROFIDEFTlGHOST 02/28/05 1 '"(:J ~fJJ1P1-05 10687701 PPROF PSPIDEFT/GHOST 08/13/04 1 ;-t¡r.¡~ (/2- 'i MPC-42 10889141 RST 07/26/04 1 ?()tJ.{}ß MPC-42 10621815 RST 08/07/04 1 ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 (;;:.r ¡, ~\!h.íY::Vc: ð. Pi'-{ t.2\.¡J-\h,:r'tb~= t., ,< " c;.!) n fF:; t; (,0.)....'0 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 995...03-28~38 . ATTN: Beth . / -~:/I I Receiv~:_.. IV LA. 'a/¿41/fi~ Date Delivered: JjlV 105 07-01A (PTD #1971530) Classified as Problem Well Subject: 07-01 A (P'ft)"#'.,..1'Š30j Classified as Problem Well From: "NSU, ADW Wen Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> Date: Mon, 16 Aug 2004 22:52:48 -0800 ':>':~í~ë~hine:'T«tW"~:~' ""aTW@BP,coni*':1't~Îla. FS3T§~~:!:<G:PBFS3~P!~Þfu.> ' , , """""""'~', ;,,",' '"",,' J'A'":¡-",i';:¡~:",,, ":':'.'"":",,,,"""""!:",~,:,';'" ;R St~yen" <Ro,' @BP,coW:>;~;:I~SUr:~W WêU!iQPeratiQ UperviSt)Ïf!i~!:,,!!~;' ,,:,',,' ~' WW"'il'l.ap' ','",,' " w6ì\n'rw:¡:i..:::;¡ ';'G:':rih:,W' 11",¡,i~ 'E' :' '", ":':":,.",:/,"':;i:':;,t::!';;,¡!:.",;-- "'" ,i,: : "e eratlOns , so"~f~~'"\QJ.>, "';I'i~f.'" e s;!'~~~':' "";;;:¡:i!:'i;:\",r:"'I?:'~~~~:~,\:: :,' ~r:~?WèllsoptEng@BP,coAOGCG'an:Regg (B~~l)" <jiII1~re, " ,'::':~';~t~te,ak~u~M;{:(!i!i:¡,:: '."""":'"Wi~tonAubert(E- )"<wintØU:,'aub': ii,.i',"~~$tateiák,ù"" "\i':;!ii/,i':'" ,wLii::i'S:,;' ", ..: :":", ," " " ,',;:::'",:": ,~:" ;:" " ',"'i' ' ,,:"'!::~'~!'\ ""', , " ::: S~Crvi,sor" '<NS " WW~Gornplclion,,: or@a~þom:;:.i~::!~!,~(W, ,::: DS ' ,,' "!:",,,:::,"<~~äFS'3bS~'" "', ':;';'!:',! '",,',.":":!i':)¡¡¡lj¡(!):: );!{:::::r,..;, , '::::,; .~~SU, APW WellTnt SUADWWe:,:~~gritYiÎìg¡ ,P:¿ :',:"i':", ,",", "": ' , " ':",ii:',i:",',""" ,','""" ' ,J~,:i~!'<RèevesDf@BP.cO" ":,,', , ',,/ '¡:!!ii¡::;i~:,:' i,'~'~:~:':~' ,,::, ~ \1P- \cf< )ßV All, Well 07-01A (PTD #1971530) has been found to have sustained casing pressure on the IA. The TIO's on 08/15/04 were 2400/2350/1360 when operations continued to prepare to set an IBP to secure the well. The well had been secured with fluid before operations began to fish the failed pack-off GLMs from the well which have been recovered. The plan forward for this well is as follows: 1. SL: Fish POGLMs 2. SL: Drift, caliper - DONE 3. EL: Set IBP A wellbore schematic has been included for reference. «07-01A.pdf» The well has been classified as a Problem well. Please questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 call if you have any Content-Description: 07-01A.pdf Content-Type: application/octet-stream Content-Encoding: base64 QeceJ- f(òJ-w:-~ I~~ Prt'S5W'eS , ð.:J<.... (B/3l-) eM> ~cF) w~) íÍA,!:,¡1 --zA.oofS', ¡1'Wo4 J~o 0 0 6l~4- Ù D 0 JÄ- Z3SD~; c) çl~4-- Ù 0 0 D oA l"5bCf'>i 41ZID4- 0 ù 0 0 "3\'Zð)4 /£:'(1'13 bt3¡'YìCJ¡ 1t..,l'b<>¡ 2.-3 71~4 3'1, ß<¿ -z. ~'-ù 'J3I." 30, 1')41 2-7 IIZð04 45¡ ;-2-3 74tt¡ 1'=>3 43 I 7b'b 3/ 1 of 1 I z, "ZOo 3> z=:¡ (,ßo 4'12, '1% by7% 31 ' ~MT^/f Uol,;' 1 30'1 Z r>; è~ 24"(.1 f~; i:J.I-- 8/24/200410:47 AM TREE = GRAY GEN 2 \^ÆLLHEAD = GRAY ACTl.Lð.TOR = AXELSON KB, ELEV = 64' BE ELEV = ? KOP= 4900' Max Angle = 109 @ 11763' DatumMD= 9445' DatumTVD = 8800' SS 07-01A -- 13-3I8"CSG, 72#, N-BO, ID= 12,347" Minimum ID 2,375" @ 10005' TOP 2-7/8" TBG 5-1/2" TBG, 17#, L-80, 0,0232 bpf,lD = 4,892" TOP OF 4-1/Z' TBG 8144' TOP OF 3-1/2" LI'R 8188' 8188' 8199' 4-112" TBG, 12,6#, N-BO, 0,0152 bpf,lD = 3,958" 8255' 8255' 8228' 8286' TOP OF 7" LNR 9-5/8" CSG,47#, No80, ID= 8,681" 7" MILLOUT WINDOW 9423' - 9429' 3-3/16" LNR, 6.2#, L-BO, ,0076 bpf, ID = 2.8" TOPOF2-7/8" LI'R 10005' FERFORA TON SU~RY RET LOG: BHCS ON 07104/78 Afol3LEATTOPÆRF: 92 @ 10270' Note: Refer to Production DB for historical peñ data SIZE SPF NTERV A L Opn/Sqz DATE 1-11/16' 4 10270-10500 0 01/10/98 2" 4 10550-10800 0 12/12/00 2" 4 11000-11200 0 12/12/00 1-11/16' 4 11280-11651 0 01/10/98 2-1/8' 4 11760-11798 0 08/24/98 7" LI'R, 29#, N-BO, 0,0371 bpf,lD = 6,184" 9422' 2- 718" LNR, 6.4#, L-80, .0058 bpf, ID = 2,441" DAìE REV BY COMtv'ENTS DATE REV BY COMVIENfS 07/78 ORiGNAL COMR.EOON 01/15/98 LAST WORKOVER 12/04100 SIS-M) CONVERlED TO CANVAS 01/22/01 SIS-LG REVISION 09120/01 RNITP CORREClIONS SAFElY NOìES; 4" RESTRlClION@ 7942' 11/19/97 5-112" CAMCO BAL-O SSSV NIP,ID =4,562" GAS LIFT MANDRELS DEV TYÆ VLV LAlCH PORT Dð.ìE 1 AVA-DWP BK-2 29 AVA-DWP BK-2 5-1/2" CAMCO DB-6 NIP, ID = 4,56Z' 5-1/2" BKR SBRASSY 9-5/8" X 5-112" BAKERSAB PKR 5-1/2" X 4-112" XO 3-1/2" BAKER ŒPLOY SLV, ID = 3,000" 4-1/2" CAMCO DB-6 NIP, ID = 3,813" (BEHND CT LNR) 4-112" TUBlfol3 TAIL (B8-1I1'oI) cr LNR) H ELMDTT LOGGED 07/29/89 I 3-112" X 3-3/16" XO, ID= 2,79" 3-3/16" X 2- 7/8" XO, ID = 2.375' PRUŒlOEBAY UNIT \llÆLL: 07-01A ÆRMT No: 97-153 APt No: 50-029-20272-01 see 34,TlN,R14E 834,31 FEL 3147.65 HI. E§) Expbratlon (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 64 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2035' FNL, 5272' FEL, Sec. 34, T11 N, R14E, UM (asp's 676230, 5948888) 07-01A At top of productive interval 9. Permit number / approval number 3690' FNL, 4336' FEL, Sec.34, T11 N, R14E, UM (asp's 677209, 5947258) 197-153 At effective depth 10. APl number 50-029-20272-01 At total depth 11. Field / Pool 3148' FNL, 834' FEL, Sec. 33, T1 1N, R14E, UM (asp's 675417, 5947756) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11823 feet Plugs (measured) PBTD tagged (12/11/2000) @ 11678' MD. true vertical 8992 feet Effective depth: measured 1 1678 feet Junk (measured) true vertical 9035 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 300 Sx AS 110' 110' Surface 2650' 13-3/8" 5300 Sx AS ~ 2714' 2714' Production 8606' 9-5/8" lOOO Sx C~ass G 8670' 8227' Liner 1085' 7" 525 Sx Class G 9422' 8846' Liner 3635' 3-1/2/2-7/8" 21 bbls Class G 11823' 8992' Perforation depth: measured 10270' - 10500'; 10550'- 10800'; 11000'- 11200'; 11280' - 11651'; 11760' - 11791" 11793'- 11798'. true vertical 9050' - 9035'; 9033' - 9029'; 9033' - xxxx'; 9036' - 9041" 9013' - 9002'; 9002' - 9000'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 NPCT @ 8144' MD; 4-1/2", 12.6#, N-80 NPCT @ 8255' MD. RECECVED Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER SAR PACKER @ 8132' MD. 5-1/2" CAMCO BAL-O SSSV @ 2228' MD. "]/~ r~ 0 5 ~ 0 01 13. Stimulation or cement squeeze summary Alaska 0it & Gas Cons. Corr~ssJofl Intervals treated (measured) (see attached) Anchorage Treatment description including volumes used and final pressure 14. Representative Da y Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1141 3984 392 292 Subsequent to operation 610 2006 2433 307 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations .__X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title DS 07 Surveillance Engineer Date /- ~, --Off Bob Gerik /"/~ ~ ~ Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 07-01A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 11/28/2000: 12/09/2000: 1 2/10/2000: 12/11/2000: 1 2/1 2/2000: RIH & drifted to 9760' SLM (HAW). MIRU CTU#5 & work platform. PT'd LUB/BOP/HL to 4000 psi. Load & killed well w/1% KCL Water. RIH & tagged BTM @ 10416' MD. Logged w/GR/CCL & POOH. RIH w/CT nozzle & washed down to 11690'. Sticky spot encountered @ 10435'. POOH w/nozzle. RIH w/PDS & logging tools &tagged up @ 11423'. POOH. RIH w/1.69" Mill w/Mem GR/CCL tools & navigated tight spot w/no problems. POOH. RIH w/2-1/4" tapered mill & milled to 11676' w/no restrictions. Milled to 11678'. Swept liner w/FIo Pro & POOH. RIH/w logging tools & logged f/11300' to 10300'. POOH w/logging tools. RIH w/2" CT conveyed perforating guns & shot 450' of Add Perforations located @' 10550' - 10800' (Zone 2A) Reference Log: BHCS 7/4/1978. 11000' - 11200' (Zone 2A) All shots @ 4 SPF, random orientation, & overbalanced press. POOH w/guns - ASF. FP'd well. RD CTU & work platform. Placed well BOL & obtained a representative well test. RECEIVED JAN 0 5 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pedorate _ Pull tubing _ Alter casing _ Repair well _ Other_X (POGLMS) 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2035' FNL, 5272' FEL, Sec. 34, T11N, R14E, UM At top of productive interval 3690' FNL, 4336' FEL, Sec.34, T11 N, R14E, UM At effective depth At total depth 3148' FNL, 834' FEL, Sec. 33, T11N, R14E, UM 5. Type of Well: Development __X Explorato~ Stratigraphic__ Service__ (asp's 676230, 5948888) (asp's 677209, 5947258) (asp's 675417, 5947756) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 07-01A 9. Permit number / approval number 197-153 10. APl number 50-029-20272-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2650' Production 8606' Liner 1085' Liner 3635' 11823 feet Plugs (measured) 8992 feet PBTD tagged (8/24/1998) @ 11800' MD. 11800 feet Junk (measured) 8999 feet Size Cemented Measured Depth 20" 3oo Sx AS 110' 13-3/8" 530O Sx AS H 2714' 9-5/8" 1000 Sx C~ass G 8670' 7" 525 sx cbss G 9422' 3-1/2/2-7/8" 21 bbls Class G 11823' ORIGINAL True vertical Depth 110' 2714' 8227' 8846' 8992' Perforation depth: measured 10270' - 10500'; 11280' - 11651'; 11760' - 11791'; 11793' - 11798'. true vertical 9050' - 9035'; 9036' - 9041'; 9013' - 9002'; 9002' - 9000'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 NPCT @ 8144' MD; 4-1/2", 12.6#, N-80 NPCT @ 8255' MD. Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER SAB PACKER @ 8132' MD. 5-1/2" CAMCO BAL-O SSSV @ 2228' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation (shut in) Subsequent to operation 1264 Representative Daily Avera.qe Production or Injection Data Gas-Mcr Water-Bbl 2029 1264 Casing Pressure Tubing Pressure . 275 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed :~x~ '~' 6~t~,.,~ Title PAl Wellwork Design & Optimization Supervisor Erin Oba Date 5-~. ¢- ~--)~"~-.~) Prepared by Pau/ Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 07-01A DESCRIPTION OF WORK COMPLETED SET POGLMS Date Event Summary 2/10/2000: 3/31/2000: 4/21/2000: 4/28/2000: 5/05/2000: RIH & ran LDL. Results: leak @ 6670' & possibly @ 6410' MD. Ran Kinnley Caliper Log f/8122' SLM. RIH & drifted w/dummy POGLM to 7000' SLM - no problems. MIRU ELU. PT'd equip to 3000 psi. RIH (2 runs) & set 2 POGLM's, first one @ 6704' & the second one @ 3373' MD. Both POGLM's have 1" DGLV-BK's installed. POOH. RD. MITIA to 3000 psi - passed. Placed well BOL & obtained a representative well test. Page I oN oR BEFORE ANUARY 03 2001 c.~O~mt~.D°c Well Report ,~oomp. O1 /11 /1998 197-153-0 ARCO PRUDHOE BAY UNIT 07-0 IA 029-20272-01 Completion Status: 1-OIL Current Status MD/~g_~ '~'~ ~ TVD 08992 Name Interval Sent Received BO 8245 ~ 1-16 SPERRY GR 2/18/98 2/18/98 8246 b.,,tS' 1-8 SPERRY GRPB1 2/18/98 2/18/98 8925 6,-"1<' 1 SCHLUM MCNL 1t/3/98 11/6/98 MCNL oJ~'~INAL 7968-11788 11/4/98 11/6/98 T MWD SRVY e'~ t,,~PERRY 9560.14-11823.00 2/19/98 3/23/98 MWD SRVZ ~R~- '~'ERRY 9560.14-11823. 1/29/98 2/4/98 MWD SRVZ 4(~- ~ERRY 9300.-9917. PB1 1/29/98 2/4/98 NGP-MD ~L"~FINAL 9370-11823 2/18/98 2/18/98 D NGP-MD ~.~FINAL 9370-9918PB1 2/18/98 2/18/98 D NGP/TVD //I~ FINAL 8754 8944 2/18/98 2/18/98 D NGP/TVD ~ FINAL 8754-8974PB1 2/18/98 2/18/98 D Daily Well Ops )~///~/¢/~ 3'//?//g0° Are Dry Ditch Samples Required? yes ~_~ And Received7 ~ycg no~ Was the well cored7 yes ~ Analysis Description Rece~ Sample~erg'---'-'~-~'~ Comments: ' Monday, January 10, 2000 Page 1 of 1 --.- STATE OF ALASKA ,,SKA OIL AND GAS CONSERVATION OOMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Pedorate _X Pull tubing Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 64' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Sb'atagrapic_ Anchorage~ AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 7' E & 2036' S of NW cr Sec 34, Tll N, R14E, UM. 07-01A At top of productive interval: 9. Permit number/approval number: 945' E & 1590' N of SW cr Sec 34, T11N, R14E, UM. 97-153 At effective depth: 10. APl number: 50-029-20272-01 At total depth: 11. Field/Pool: 3148' FNL, 834' FEL, Sec 33, T11N, R14E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 11823 feet Plugs (measured) PBTD Tagged at 11800' CTM (8/24/98). true vedical 8992 feet Effective Depth: measured 11800 feet Junk (measured) true vertical 8999 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 300 Sx Arcticset 110' 110' Surface 2650' 13-3/8" 5300 Sx Arcticset II 2714' 2714' Production 8606' 9-5/8" 1000 Sx Class G 8670' 8227' Liner 1538' 7" 525 Sx Cement 9422' 8846' Liner 1817' 3-1/2" 21 Bbls Class G 10005' 9043' Liner 1818' 2-7/8 .......... 11823' 8992' Perforation Depth measured 10270' - 10500'; 11280' - 11651 '; 11760' - 11791'; 11793'- 11798' . ~ '~ ~ ~ ' true vertical 9050'-9035';9036'-9041';9013'-9002'; 9002'-9000' '""*-,J i ~.-." I~,~ / Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPC Tbg @ 8144' MD; 4-1/2", 12.6#, N-80, NPC Tbg @ 8255' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 8132' MD; Camco BaI-O SSSV @ 2228' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Alaska 0il & 8as Cons. Co Intervals treated (measured) Anchorage 14. ReDresentitive Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 224 548 388 288 Subsequent to operation 1461 802 880 - 279 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed__~/~'~-,"~'~--'");'J/I o ~ Title: Engineering Supervisor Date Erin Oba Prepared b/Paul Raui 263-4990 D mission Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 07-01A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 8/24/98: MIRU & PT BOPE to 4000 psi. RIH & performed GR, CCL, & Borax CNL logs. POOH w/logging tools. RIH w/ perforating guns & shot 15' of perforations as follows: Reperf: 11781'- 11787' MD (Z2) Ref. Log: BHCS 7/4/78 Add perf: 11788' - 11791' MD (7_2) Add perf: 11793' - 11798' MD (7_2) Used a 2-1/8" & 1-11/16" carder. All shot at 4 SPF, random orientation, 0 degree phasing, & overbalanced press. POOH w/perf gun. Noted guns fired. RD. Returned the well to production & obtained a valid well test. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIOr~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator: 15. Type of Well: ARCO Alaska, Inc. I Development..~ 3. Address: Explorato~/_ P.O. BOX 100360 Stratagrapic _ Anchorage, AK 99510-0360 Service_ 4. Location of well at surface: Operation Shutdown _ Stimulate_~ Plugging_ Perforate _ Pull tubing _ ,Nter casing _ Repair well _ Other _ 6. Datum of elavation (DF or KB feet): 64' RKB 7' E & 2036' S of NW cr Sec 34, T11 N, R14E, UM. At top of productive interval: 945' E & 1590' N of SW cr Sec 34, T11N, R14E, UM. At effective depth: At total depth: 3148' FNL, 834' FEL, Sec 33, T11N, R14E, UM. 12. Present well condition summary Total Depth: measured 11823 feet Plugs (measured) true vertical 8992 feet 7. Unit or Property: Prudhoe Bay Unit 8. Well number: 7-01A 9. Permit number/approval number: 97-153 10. APl number: 50-029-20272-01 11. Field/Pool: Prudhoe Bay Oil Pool Effective Depth: measured 11788 feet Junk (measured) true vertical 9004 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 300 Sx Arcticset 110' 110' Surface 2650' 13-3/8" 5300 Sx Arcticset II 2714' 2714' Production 8606' 9-5/8" 1000 Sx Class G 8670' 8227' Liner 1538' 7" 525 Sx Cement 9422' 8846' Liner 1817' 3-1/2" 21 Bbls Class G 10005' 9043' Liner 1818' 2-7/8 .......... 11823' 8992' Perforation Depth measured 10270 - 10500'; 11280- 11651'; 11760 - 11787' true vertical 9050 - 9035'; 9036- 9039'; 9012- 9006' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPC Tbg @ 8144' MD; 4-1/2", 12.6#, N-80, NPC Tbg @ 8255' MD .~, .. ,¥~. ..~.~ Packers and SSSV (~pe and measured dep~) Baker SAB Packer ~ 8132' MD; Camco BaI-O SSSV ~ 2228' MD ~ -,.f ~> ~... 13. Stimulation or cement squeeze summary Intervals treated (measured) Intervals treated (measured) see attached i'_';,i i ~, ..:..¥'. 14. Representitive Daily Average Production or Injection Data Prior to well operation Subsequent to operation OiI-Bbl 274 Gas-Mcf Water-Bbl Casing Pressure 5615 652 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X 292 969 16. Status of well classification as: Oil _X Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~ "~, ~ Title: Engineering Supervisor Form 10-404 Rev 06/15/88 922 Tubing Pressure 287 274 Suspended _ Service _ Date SUBMIT IN DUPLICAT 7-01A DESCRIPTION OF WORK COMPLETED ACID STIMULATION TREATMENT WITH INFLATABLE PACKER OF ZONE 2 5/4/98: An Acid Stimulation of the inverted Zone 2 toe was performed using an Inflatable Packer as follows: MIRU CTU & PT equipment to 4000 psi. Loaded the wellbore w/Crude, then RIH w/Inflatable Packer. Inflated & set the packer in the 2-7/8" liner at 11710' MD, to isolate the upper perf intervals located at: 10270- 10500' MD (Zl) 11280- 11651' MD (Zl) Pumped treatment fluids to treat the lower open perforation interval located below the packer at: 11760- 11787' MD (Z2) Pumped: a) 31 bbls 60% Diesel / 30% Xylene / 10% Mutual Solvent @ .3 - .7 bpm, followed by b) 45 bbls 12% HCI w/10% Xylene w/3% Acetic Acid @ .8 bpm, followed by c) 31 bbls 9% HCI - 1% HF w/3% Acetic Acid @ .8 - 1.4 bpm, followed by d) 47 bbls 12% HCI w/10% Xylene w/3% Acetic Acid @ 1.5 bpm, followed by e) 100 bbls 2% NH4CI Water @ 1.5 bpm. Displaced treatment away to formation w/41 bbls Meth Water. Noted a large pressure break back when HCL-HF hit the perfs. Deflated & POOH w/Packer minus two rubber elements lost in hole. RD. 5/7/98 - 5/8/98: Attempted to fish rubber elements; no recovery. Placed the well on production & obtained a valid welltest. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well,>' Oil_X Gas__ Suspended__ Abandoned__ Service__ ~'~ 2 Name of Operator 7 Permit Number , . ARCO Alaska, Inc. 97-153 ' '~.:' 3 Address 8 APl Number P.O. BOX 100360, Anchorage, AK 99510-0360 50-029-20272~,0.1 . 4 Location of well at surface ~ 9 Unit or Lease Name ':'~ At Top Producing interval - t ~~,~ ] 10 Well Number 945' E & 1590' N of SW cr Sec 34, T11N, R14E, UM ~:L.;j ~': , ,..'~¢,~,..~ 7-01A At Total Depth i'. · ~__..~ 11 Field and Pool 3148' FNL, 834' FEL, Sec 33, T11 N, R14E, UM. ' "~'"' ~'~ ..... ~- ;~/- -I ~. H. PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 64' RKB ADL28309 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 116 No. of Completions 12/23/97 1/6/98 1/11/98 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 11823' MD / 8992' TVD 11788' MD / 9004' TVD YES_X NO__ 2228' feet MD 22 Type Electric or Other Logs Run MWD, GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 94# H-40 Surf 110' 30" 300 Sx Arcticset 13-3/8" 72# N-80 Surf 2714' 17.5" 5300 Sx Arcticset II - 9-5/8" 47# N-80 & RS & Surf 8670' 12.25" 1000 Sx Class G - S00-95 7" 29# N-80 8337' 9422' 8.5" 525 Sx Cement 3-1/2" 9.2# L-80 8188' 10005' 4.25" 21 BBls Class G Cement 2-7/8" 6.4# L-80 10005' 11383' 4.25" / 3.8 ...... 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 4-1/2" Tbg 8255' 8132' 10270 - 10500' MD; 9050- 9035' TVD I 11280 - 1165.1' MD; 9036 - 9039' TVD 11760 - 11787' MD; 9012 - 9006' TVD 2~ ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMT & KIND MATERIAL USED n'lGi ^L .RODUCT ON TEST tJ I I 1/'t Date First Production Method of Operation (Flowing, gas lift, etc.) 2/11/98 Flowing Date of Test Hours Tested i PRODUCTION FOR OIL - BBL GAS- MCF WATER- BBL CHOKE SIZE GOR 2/11/98 (Initial Test) 3.3 TEST PERIOD__ 20910 Flow Tubing Press Oasing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) 294 24 HOUR RATE _X 242 5060 763 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. · This 10-407 submitted as directed per the 10-401 form approved 8/15/97 (Permit # 97-153). Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate NAME Top Sadlerochit GEOLOGIC MARKERS MEAS DEPTH 9106' TRUE VERT DEPTH 8557' FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase, N/A 31 LIST OF ATTACHMENTS Summary of 7-01A C°il Tubing Sidetrack Drilling Operations. 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~~ ~"/~' ~ En(]ineerino Suoervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection Gas Injection, Shut-In, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 7-01A DESCRIPTION OF WORK COMPLETED CT SIDETRACK DRILLING OPERATIONS 12/18/98- 12/19/97: MIRU CTU. ND tree. PT BOPS. RIH w/milling BHA & tagged cement plug top at 8330' MD. a pilot hole through cement to 8444' MD. POOH w/BHA. Milled 12/20/97: RIH w/3.75" milling BHA. Tagged PBTD at 8444' MD, then circulated Crude out of the 9-5/8 x tubing annulus through POGLM holes. Drilled cement to 9350' MD & swept clean w/biozan. POOH w/BHA. RIH w/3.8" milling BHA & reamed pilot hole to 8469' MD. 12/21/97: Reamed cement to 8544' MD. POOH w/BHA. RIH w/milling BHA. Resumed milling 3.8" pilot hole to 9350' MD. POOH w/BHA. RIH w/milling BHA & milled pilot hole to 9396' MD. 12/22/97: Continued milling pilot hole to casing wall at 9425' MD. POOH w/BHA. Standby (-45 F ambient). 12/23/97: Wait on weather (-41 to -46 F). RIH w/window milling BHA. through the 7" liner. Milled window to 9423' MD. Started milling a 3.8" window at 9422' MD 12/24/97: Milled window to 9424' MD. POOH w/BHA. RIH w/window milling BHA. Milled window to 9425' MD. 12/25/97: Completed milling window to 9429' MD. POOH w/BHA. RIH w/window finishing BHA. dressed window smooth; window located at 9423- 9429' MD. POOH w/BHA. PT BOPS. Reamed & 12/26/97: RIH w/drilling BHA. RIH w/drilling BHA. smooth to 9410' MD. Couldn't orient BHA through window. Displaced well to FIo Pro & POOH w/BHA. Tagged window bottom lip at 9429' MD. Milled to 9436' MD, then backreamed POOH. RIH w/drilling BHA to 9436' MD, then drilled 3.8" build to 9575' MD. 12/27/97: Completed drilling build section to 9746' MD. POOH w/BHA. RIH w/drilling BHA & drilled horizontally to 9915' MD w/periodic short trips to window to sweep hole. POOH w/BHA. 12/28/97: RIH w/drilling BHA. Tagged bottom at 9915' MD; hole very sticky. POOH w/BHA. RIH w/2.5" nozzle & tagged up at 9775' MD; could not get to bottom. Pumped 9 bbls of Neat 17 ppg Class G cement to plugback hole. Cleaned out cement to 9445' MD. POOH & WOC. 12/29/97: RIH w/4.25" Bi-center bit drilling BHA. Increased mud weight to 9.6 ppg. Tagged TOC at 9460' MD, then drilled soft cement to 9490' MD. WOC. Attempted to kick off drilling a new sidetrack hole at 9491' Drilled to 9592' MD w/out a start on a new sidetrack. POOH w/BHA. RIH w/3.75" PDC bit drilling BHA. Attempted to kickoff new sidetrack hole at 9593' MD. WOB indicated new sidetrack started at 9596' MD. 12/30/97: Drilled 3.75" build section to 9640' MD. POOH w/BHA. RIH w/4.25" Bi-center bit drilling BHA & drilled build to 9898' MD w/periodic trips to window. POOH w/BHA. 12/31/97: RIH w/3.75" PDC bit drilling BHA. Drilled from 9898' to 10026' MD, then circulated in new FIo Pro. POOH w/BHA. RIH w/drilling BHA. Drilled to 10326' MD w/periodic short trips. 7-01A DESCRIPTION OF WORK COMPLETED CT SIDETRACK DRILLING OPERATIONS 1/1/98: Continued drilling horizontal hole to 10758' MD. POOH w/BHA. 1/2/98: Tested BOPS. RIH w/drilling BHA. Drilled to 10880' MD. 1/3/98: Drilled to 10908' MD. 1/4/98: RIH w/drilling BHA. POOH w/BHA. POOH w/BHA. RIH w/drilling BHA. Drilled to 11100' MD. POOH w/BHA. Circulated in new FIo Pro, then drilled to 11338' MD w/periodic trips to window. 1/5/98: RIH w/drilling BHA. Drilled to 11689' MD w/periodic sweeps to window. 1/6/98: Drilled to TD at 11823' MD. POOH displacing w/new FIo Pro. Displaced mud w/Seawater from 1800'. 1/7/98: PT BOP stack. MU & prep to run 2-7/8" x 3-1/2" liner assembly. 1/8/98: RIH w/liner & landed liner on bottom at 11823' MD. Sheared off liner & pumped 21 bbls of Class G cement to set the liner at 8188 - 11823' MD. POOH displacing well to Seawater. 1/9/98: MU & RIH w/2.3" milling BHA. Milled & cleaned out liner to 11717' MD, then POOH circulating in new FIo Pro to 9800' MD. PT BOP equipment. RIH w/no-go to tie into tubing tail prior to perforating. 1/10/98: POOH w/no-go. PT liner from surface to 2000 psi; tested good. RIH w/1-11/16" strip perforating guns & tagged landing collar at 11788' MD. Shot initial perforation intervals at 4 spf at 90 degree phasing at: 11280 - 11651' MD 11760 - 11787' MD POOH w/perf guns. Noted ASF. 1/11/98: RIH w/#2 run of 1-11/16" strip perf guns. 10270 - 10500' MD Shot additional initial perfs at 4 spf at 90 degree phasing at: POOH w/perf guns. Noted ASF. RIH w/nozzle & circulated Crude down 9-5/8 from TOL. 1/12/98: RD CTU. ND BOP stack. NU & PTtree. MOL. POOH. 2/7/98: Reinstalled POGLM's at 3777' & 6708' MD. Placed the well on initial production & obtained a valid welltest. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA. PAGE I ~R~O ALASKA, INC. PBU / 7-01A 500292027201 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 010698 MWD SURVEY JOB NUMBER: AKMW80057 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9560.14 8950.06 8886.06 50 35 S 50.30 W .00 1800.80S 975.90E -1353.03 9593.00 8969.61 8905.61 56 22 S 55.00 W 21.01 1816.78S 954.90E -1336.12 9629.22 8990.33 8926.33 53 57 S 44.67 W 24.33 1835.88S 932.21E -1318.26 9659.89 9007.11 8943.11 59 40 S 47.66 W 20.35 1853.63S 913.69E -1304.17 9689.54 9020.79 8956.79 65 22 S 50.13 W 20.59 1870.91S 893.86E -1288.70 9705.24 9026.92 8962.92 68 39 S 47.33 W 26.57 1880.44S 883.01E -1280.24 9719.59 9031.72 8967.72 72 10 S 47.18 W 24.55 1889.62S 873.08E -1272.61 9739.72 9036.90 8972.90 78 1 S 50.35 W 32.76 1902.43S 858.45E -1261.21 9779.27 9042.38 8978.38 86 1 S 50.93 W 20.30 1927.24S 828.19E -1237.25 9805.87 9043.28 8979.28 90 5 S 55.04 W 21.71 1943.24S 806.97E -1220.14 9831.62 9042.51 8978.51 93 20 S 57.15 W 15.05 1957.60S 785.62E -1202.52 9856.69 9040.76 8976.76 94 39 S 63.30 W 25.03 1970.01S 763.92E -1184.14 9876.99 9039.31 8975.31 93 31 S 65.83 W 13.64 1978.70S 745.64E -1168.26 9905.84 9038.18 8974.18 90 58 S 69.28 W 14.86 1989.71S 719.00E -1144.74 9938.09 9038.55 8974.55 87 42 S 71.03 W 11.47 2000.65S 688.67E -1117.62 9965.59 9040.04 8976.04 86 5 S 72.55 W 8.07 2009.23S 662.59E -1094.11 9997.67 9042.66 8978.66 84 33 S 74.84 W 8.57 2018.21S 631.91E -1066.21 10039.02 9046.21 8982.21 85 35 S 79.65 W 11.86 2027.30S 591.74E -1029.08 10074.19 9048.50 8984.50 86 55 S 81.76 W 7.07 2032.97S 557.11E -996.59 10101.37 9049.75 8985.75 87 48 S 85.98 W 15.84 2035.87S 530.12E -970.92 10126.84 9050.61 8986.61 88 19 S 88.08 W 8.50 2037.18S 504.71E -946.44 10157.77 9051.23 8987.23 89 22 N 88.93 W 10.24 2037.41S 473.79E -916.35 10190.29 9051.38 8987.38 90 5 N 87.52 W 4.85 2036.41S 441.29E -884.45 10231.34 9051.03 8987.03 90 52 N 84.00 W 8.79 2033.37S 400.36E -843.87 10249.72 9050.64 8986.64 91 34 N 84.00 W 3.81 2031.45S 382.08E -825.63 10289.37 9049.12 8985.12 92 48 N 81.90 W 6.13 2026.59S 342.77E -786.22 10339.14 9046.11 8982.11 94 7 N 79.61 W 5.30 2018.61S 293.74E -736.65 10372.82 9043.97 8979.97 93 9 N 77.32 W 7.37 2011.89S 260.81E -703.05 10404.09 9042.19 8978.19 93 20 N 74.51 W 8.99 2004.29S 230.54E -671.85 10436.34 9039.75 8975.75 95 21 N 72.05 W 9.85 1995.04S 199.74E -639.76 10465.12 9037.25 8973.25 94 34 N 69.59 W 8.95 1985.62S 172.66E -611.27 10495.19 9035.07 8971.07 93 46 N 66.60 W 10.26 1974.44S 144.84E -581.65 10527.12 9033.t8 8969.18 92 59 N 63.09 W 11.25 1960.89S l16.00E -550.51 10560.32 9032.34 8968.34 89 54 N 61.68 W 10.20 1945.51S 86.59E -518.41 10589.79 9032.48 8968.48 89 33 N 59.40 W 7.83 1931.02S 60.94E -490.17 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, iNC. PBU / 7-0iA 500292027201 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 010698 MWD SURVEY JOB NUMBER: AKMW80057 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10618.52 9032.83 8968.83 10658.67 9033.32 8969.32 10683.97 9033.27 8969.27 10721.74 9032.54 8968.54 10751.14 9031.85 8967.85 89 1 89 33 90 41 91 29 91 13 N 57.29 W 7.57 1915.94S 36.49E N 52.19 W 12.77 1892.78S 3.72E N 49.90 W 10.11 1876.87S 15.95W N 47.09 W 7.73 i851.85S 44.23W N 45.68 W 4.88 1831.58S 65.51W -462.98 -425.87 -403.14 -370.00 -344.73 10779.49 9030.58 8966.58 10809.19 9028.39 8964.39 10838.44 9026.73 8962.73 10870.52 9026.71 8962.71 10890.39 9027.62 8963.62 93 52 94 35 91 55 88 9 86 34 N 43.93 W 11.17 1811.49S 85.46W N 41.54 W 8.38 1789.74S 105.56W N 41.19 W 9.17 1767.82S 124.85W N 40.18 W 12.17 1743.50S 145.76W N 40.06 W 8.02 1728.32S 158.55W -320.80 -296.36 -272.66 -246.85 -231.00 10926.79 9029.63 8965.63 10949.27 9030.75 8966.75 10978.29 9032.08 8968.08 11010.12 9032.96 8968.96 11037 . 92 9033.09 8969.09 87 5 87 11 87 32 89 18 90 10 N 40.06 W 1.46 1700.51S 181.94W N 39.18 W 3.93 1683.21S 196.26W N 39.71 W 2.19 1660.83S 214.68W N 38.30 W 7.08 1636.10S 234.70W N 37.25 W 4.93 1614.13S 251.73W -201.99 -184.18 -161.23 -136.20 -114.70 11063.07 9032.70 8968.70 11097.14 9031.60 8967.60 11129.92 9031.19 8967.19 11163.07 9032.16 8968.16 11198.39 9033.49 8969.49 91 34 92 7 89 18 87 21 88 19 N 37.25 W 5.57 1594.12S 266.95W -95.39 N 37.20 W 1.59 1567.00S 287.55W -69.27 N 38.65 W 9.67 1541.15S 307.69W -43.86 N 42.17 W 12.12 1515.92S 329.17W -17.30 N 45.16 W 8.89 1490.40S 353.53W 12.15 11231.49 9034.17 8970.17 11256.24 9034.63 8970.63 11300.42 9037.07 8973.07 11321.47 9038.81 8974.81 11375.77 9041.06 8977.06 11419.12 9041.81 8977.81 11439.77 9042.54 8978.54 11488.99 9044.80 8980.80 11525.42 9046.48 8982.48 11546.32 9047.24 8983.24 89 18 88 35 85 4 85 25 89 48 88 13 87 42 87 0 87 42 88 9 N 46.74 W 5.60 1467.39S 377.32W 40.46 N 49.20 W 10.34 1450.83S 395.69W 62.07 N 48.50 W 8.10 1421.80S 428.90W 100.92 N 48.32 W 1.87 1407.88S 444.59W 119.32 N 45.60 W 9.49 1370.86S 484.23W 166.21 o N 48.22 W 7.06 1341.26S 515.88W 203.67 N 50.78 W 12.64 1327.85S 531.57W 221.96 N 53.07 W 4.86 1297.54S 570.27W 266.44 N 55.00 W 5.63 1276.17S 599.72W 299.91 N 54.07 W 4.92 1264.05S 616.73W 319.20 11592.79 9047.31 8983.31 11630.89 9043.87 8979.87 11659.84 9038.96 8974.96 11701.77 9029.83 8965.83 11736.37 9020.17 8956.17 91 40 98 41 ** 48 ** 19 .u N 54.12 W 7.58 N 55.53 W 18.82 N 60.98 W 19.93 N 56.23 W 13.88 N 53.60 W i3.11 1236.80S 654.36W 361.96 1214.96S 685.35W 397.05 1199.95S 709.60W 424.04 1178.65S 744.53W 462.83 1159.57S 771.71W 493.59 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. PBU / 7-01A 500292027201 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 010698 MWD SURVEY JOB NUMBER: AKMW80057 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11762.82 9011.66 8947.66 ** 25 N 53.24 W 5.15 1144.64S 791.82W 516.52 11801.69 8998.89 8934.89 ** 55 N 56.77 W 8.67 1123.59S 821.89W 550.53 11823.00 8992.03 8928.03 ** 37 N 58.70 W 8.69 1112.82S 838.95W 569.56 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1393.63 FEET AT SOUTH 37 DEG. 0 MIN. WEST AT MD = 11823 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 282.89 DEG. TIE-IN SURVEY AT 9,560.14' MD WINDOW POINT AT 9,593.00' MD PROJECTED SURVEY AT 11,823.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA -PAGE 4 ARCO ALASKA, INC. PBU / 7-0lA 500292027201 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 010698 JOB NUMBER: AKMW80057 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9560.14 8950.06 8886.06 10560.14 9032.34 8968.34 11560.14 9047.56 8983.56 11823.00 8992.03 8928.03 1800.80 S 975.90 E 610.08 1945.59 S 86.75 E 1527.80 917.72 1255.95 S 627.91 W 2512.58 984.78 1112.82 S 838.95 W 2830.97 318.38 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA .PAGE 5 ARCO ALASKA, INC. PBU / 7-0lA 500292027201 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 010698 JOB NUMBER: AKMW80057 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9560.14 8950.06 8886.06 9583.19 8964.00 8900.00 9620.14 8985.02 8921.02 1800.80 S 975.90 E 610.08 1812.06 S 961.42 E 619.19 9.11 1830.76 S 937.50 E 635.12 15.93 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA,=N~. PBU / 7-01APBI 500292027270 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 122797 MWD SURVEY JOB NUMBER: AKMW80057 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9300.00 8742.30 8678.30 32 0 S 3.00 W .00 1664.50S 1031.90E -1377.21 9400.00 8827.67 8763.67 30 45 S 5.00 W 1.63 1716.43S 1028.29E -1385.27 9490.34 8901.25 8837.25 41 2 S 33.20 W 21.32 1764.71S 1009.86E -1378.08 9529.92 8929.97 8865.97 46 4 S 45.00 W 24.12 1785.71S 992.62E -1365.96 9560.14 8950.06 8886.06 50 37 S 50.20 W 19.77 1800.90S 975.94E -1353.09 9592.87 8969.53 8905.53 56 21 S 55.00 W 21.12 1816.83S 955.03E -1336.26 9628.59 8987.66 8923.66 62 39 S 61.70 W 23.89 1832.91S 928.84E -1314.31 9657.29 8999.93 8935.93 66 48 S 69.10 W 27.43 1843.68S 905.25E -1293.73 9682.89 9009.29 8945.29 70 16 S 71.60 W 16.32 1851.68S 882.82E -1273.65 9707.82 9016.83 8952.83 74 31 S 75.40 W 22.43 1858.42S 860.04E -1252.95 9724.52 9020.76 8956.76 78 16 S 78.00 W 27.08 1862.15S 844.25E -1238.38 9755.64 9025.94 8961.94 82 31 S 80.50 W 15.79 1867.86S 814.11E -1210.28 9784.52 9028.66 8964.66 86 39 S 79.60 W 14.63 1872.83S 785.80E -1183.79 9807.97 9029.02 8965.02 91 34 S 84.50 W 29.60 1876.07S 762.59E -1161.89 9861.69 9026.02 8962.02 94 49 S 88.20 W 9.16 1879.49S 709.08E -1110.49 9893.07 9023.57 8959.57 94 7 S 89.70 W 5.26 1880.06S 677.81E -1080.13 9917.00 9021.79 8957.79 94 24 S 88.30 W 5.94 1880.48S 653.95E -1056.97 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1990.94 FEET AT SOUTH 19 DEG. 10 MIN. EAST AT MD = 9917 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 282.89 DEG. TIE-IN SURVEY AT 9,300.00' MD WINDOW POINT AT 9,429.00' MD PROJECTED SURVEY AT 9, 917.00' MD ORIGIN,a,£ SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA .PAGE 2 ARCO ALASKA, iNC. PBU / 7-01APB! 500292027270 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 122797 JOB NUMBER: AKMW80057 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9300.00 8742.30 8678.30 9917.00 9021.79 8957.79 1664.50 S 1031.90 E 557.70 1880.48 S 653.95 E 895.21 337.51 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, iNC. PBU / 7-0iAPB1 500292027270 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 122797 JOB NUMBER: AKMW80057 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9300.00 8742.30 8678.30 9325.59 8764.00 8700.00 9443.19 8864.00 8800.00 9583.23 8964.00 8900.00 1664.50 S 1031.90 E 1678.04 S 1031.19 E 1739.06 S 1022.94 E 1812.18 S 961.41 E 557.70 561.59 3.89 579.19 17.60 619.23 40.04 9917.00 9021.79 8957.79 1880.48 S 653.95 E 895.21 275.98 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS WELL LOG TRANSMITTAL roi State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 February 18, 1998 RE: MWD Formation Evaluation Logs D.S. 7-0lA & 7-0lA PB1, AK-MW-80057 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin. Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 7-0lA: 2" x 5" MD Gamma Ray Logs' 50-029-20272-01 2" x 5" TVD Gamma Ray Logs: 50-029-20272-01 DS 7-0lA PBI: 2" x 5" MD Gamma Ray Logs' 50-029-20272-70 2" x 5" TVD Gamma Ray Logs' 50-029-20272-70 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Ino. Company WELL LOG TRANSMITTAL To: State of Alaska February 18, 1998 Alaska Oil and Gas Conservation Comm. Attn.- Lori Taylor ~'~9 ,/' 3001 Porcupine Dr. ,/ .~/'9 Anchorage, Alaska 99501 ~v~ ~b(~ MWD Formation Evaluation Logs - D.S. 7-0lA & 7-0lA PB1, AK-MW-80057 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: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20272-01 & 50-029-20272-70. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 29-Jan-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 7-01APB1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,300.00' MD 9,429.00' MD 9,917.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, inc. Company III:IICI--lNG 29-Jan-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re' Distribution of Survey Data for Well 7-01A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,560.14' MD 9,593.00' MD 11,823.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johns~-~~'~ DATE: Chairman-/~ January 8, 1998 THRU: FILE NO: Blair Wondzell, P. I. Supervisor FROM: John Spaulding,~,~.,.,. SUBJECT: Petroleum Insp. v ag81ahfe.doc Confidential: Yes BOP Test DS/Nabors 4/3ES PBU DS 7-01 PTD 97-153 ,NoX Thursday Jan. 8, 1'998: I traveled to ARCO's PBU DS-7 well 1 to witness the BOPE Test on DS / Nabors Coiled Tubing Drilling Rig 4 / 3ES. The AOGCC BOPE Test Report is attached for reference. As noted on the report no failures were observed. The rig was found to be in very good shape. Summary: I witnessed the successful BOPE Test on DS / Nabors rig 4 / 3ES, 22 valves, 0 failures, 3.5 hours test time. Attachments: ag81ahfe.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION COILED TUBING DRILLING BOPE TEST OPERATION: Drlg: X Workover:~ Drlg Contractor: Nabors/Schlumberger Operator: ARCO Well Name: 7-01A Casing Size: 2 7/8" Set @ Test: Initial Weekly Rig No. 4/3ES PTD # Co. Rep.: Rig Rep.: 11,823' Location: Sec.~ X Other DATE: 1/8/98 97-153 Rig Ph.# 659-5515 Gary Goodrich Dave Duerr 34 T. 11N R. 14 Meridian Umiat Test MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted ok Well Sign NA Drl. Rig ok Hazard Sec. ok . FLOOR SAFETY VALVES: Quan. Pressure P/F Ball Type I I 350/3500 I P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Quan. Test Press. P/F I 250/2,500 P 1 350/3,500 P 1 35073,500 P I 35O/3,5OO P P 350/3,500 350/3,500 P 350/3,500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Ted Pressure P/F 14 250/3000 P 37 250/3000 P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure MUD SYSTEM: Visual Alarm 200 psi Attained After Closure ~ minutes 8 sec. Pit Level Indicators ok ok System Pressure Attained minutes 26 sec. Meth. Gas Detector ok ok - Blind Switch Covers: Master: X Remote: X H2S Gas Detector ok ok , Nitgn. Btl's: 4 ~ 2000 avg. 2,950 P 2,400 P Psig. Number of Failures: 0 ,Test Time: 3.5 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within 0 days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector FI-021L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Ag81ahfe.xls , ohn t4. Spnulding TONY KNO WLE$, G OVERNOi~ ALASI~A OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Au_oust 15. 1997 Erin M Oba Engineering Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage. AK 99510 Re; Prudhoe Bay Unit 7-0lA ARCO Alaska. Inc. Permit No. 97-153 Sur. Loc. 7'E & 2036;S ofNW cr Sec. 34. TllN. R14E.. UM Btmnhole Loc. 838:E & 1208'N ofSW cr Sec 34. T11N, RI4E. UM Dear Ms Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required bx' law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blow, out prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given ctor on the North Slope pager at 65%3607. ?.av}d W. Johnston k Chairman -.~ BY ORDER OF THE COMMISSION d ltTE n closures Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ! STATE OF ALASKA ALASr~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll_ Redrill X I lb. Type of Well Exploratory_ Stratigraphic Test Development Oil Re-Entry__ Deepen -I Service_ Development Gas_ Single Zone ~X Multiple Zone _ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 28309 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 7' E & 2036' S of NW cr Sec 34, T11 N, R14E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 945' E & 1590' N of SW cr Sec 34, T11N, R14E, UM. 7-01A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 838' E & 1208' N of SW cr Sec 34, T11 N, R14E, UM. September, 1997 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line I No Close Approach 10100' MD / 9240' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 9300' MD Maximum hole angle 90° Maximum surface 2800 psi,c] At total depth (TVD) 8840' 18. Casing program Setting Depth Size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 4-3/8" 3-1/2" 9.3 L-80 FL4S 3185' 8515' 8136' 11800' 8840' 33 bbls 19. To be completed for Redri[l, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9880 feet Plugs(measured) true vertical 9242 feet Effective depth: measured 9657 feet Junk (measured) true vertical 9049 feet Casing Length Size Cemented Measured depth True Vedical depth Conductor 110' 20" 300 Sx Arcticset 110' 110' Surface 2650' 13-3/8" 5350 Sx Arcticset 11 2714' 2714' Production 8606' 9-5/8" 1000 Sx Class G 8670' 8227' Liner 1538' 7" 525 Sx Class G 9875' 9238' Perforation depth: measured 9502 - 9508'; 9586 - 9592'; 9631 - 9641' 7 ]997 true vertical 8915- 8920'; 8987- 8993'; 9026- 9035' ~lcq~C~ .0i! .& Gas 00l'is, 20. Attachments Filing fee __x Property plat_ BOP Sketch x Diverter Sketch _ Ddlling program x Ddlling fluid program Time vs depth plot Refraction analysis Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge (~. u e.S~¢[o~, ,& ~ ~o..tlS%,~ Wo~r--J. ~, ?_¢ ~'-/. Signed ~ ~ '~. ~ Titlle Engineerin,0 Supervisor Date 2- '7 - ~ 7 - Commission Use Only ~,,~m ~ APInumber Approvaldate %)1 lO)3 See cover letter for · - - other requirements Conditions of approval Samples required_'~es ,,~No Mud log required'- _ Yes ..~No Hydrogen sulfide measures ,,~'Yes _ No Directional survey required '~'Yes _ No Required working pressure for BOPE _2M; _3M; _5M; _10M; _15M X 3500 psi for CTU Other: .., ,~,~l-;, .... ~.,.,. ~......... ~ by order of ~ Approved by David W. Johnston Commissioner the commission Date ( ........ Form 10-401 Rev. 7-24-89 ~ 2mit in triplicate DS 7-lA CT Sidetrack and Completion Intended Procedure Objective: Cut off existing 4-1/2" tubing tail. Plugback existing wellbore. Dh'ectionally drill a horizontal well from the existing wellbore. Complete with 3-1/2" cemented liner. Install POGLMs and produce. Intended Procedure: · Cut/mill off existing 4-1/2" tubing tail at - 8144'md. · Cement squeeze and plugback the existing completion to - 8144' md. Mill window in 7" casing at -9430' md. Drill 10' of formation with 8.9 ppg Flopro fluid and perform Leak off test to 9.4 ppg. Directionally drill 4.5" x 2200' horizontal well to access Lower Romeo reserves. Build angle to -107° at TD. · Run and cement 3-1/2" liner to TD. · Perforate selected intervals. · Re-run POGLMs. Place well on production. August 6, 1997 DS 7-1A Proposed CT Sidetrack Horizontal 5-1/2" Tubing 5-1/2" DB-6 Nipple @ 8O47' Packer 8132' 7" Liner To¢--'-'-~ 8337' 5-1/2" POGLMs@ 6665'& 3735' 9-5/8" Casing shoe @ 8670' Top of 3-1/2" Liner in 5-1/2" Tbg. Initial Perfs Window cut in 7" at ~9430' - 9435' 4-1/2" Open hole Current perforations cement squeezed 3-1/2" liner TD @ - 11800' DRILE _ _ ARCO ALASKAINC. 8400 -- 8600 8800 9000 9200 1 Tie IN Di24~, 923400~ ;;';; 95° KOP [ '"~"-- I I°/1 O0 Tf 60° Arco Alaska Inc. DS 7-O1 A Pmdhoe I~¥ Alaska 7-01 AT -800 'k ~ 7 '~, - ~ x~ ~ ~,. ~ o o ~ '%~ ~ ~%~.~ - o o o ~%. % ~~ 6o0 [~ Scale ~ Inch · 400 ~ 4 DI 4.08°/100 Tf 89.2° 5 D1.75°/100 Tf 92.4° I I I North Ref. to True N, 6 DI 6°/100 Tf-50° /--~ True (+0) ,,~ Mag (+28.46) 7 TD O I~ .I~ O3 (30 --~ -~ --~ --~ --~ I'O O O O O O hO 4~ O3 OO O O O O O O O O O O O O O O O O O O O Vertical Section Scale 1 inch · 200 ft PLANE OF VERT SECTn 282.89° RELATIVE TO TRUE NORTH FILE NAME ' C:\ARCOALK\7-01A\7-01AA1.DW2 DRAWN BY ' BIMO FIADIPUTRO DATE ' AUG 5 1997 1 7-01a.xls 7-0'1 A REV, 2 8/5/97 11:26AM ARCO 7-01 A SIDETRACK AUG 5, 1997 Revision 3 MD Inc. Dlr SS DEPTH' VS NI-S EI-W Build Turn Do_gleg ASP Y ASP X Comments __ ft deg --deg ft ft ft ft degll00 degll00 degll00 ft ft ___ 9300,00 32.00 183,00 8694.50 0.00 -1664.50 1031,90 0,00 0,00 0.00 5947248.00 677300,20 1. Tie in Point Actual Survey __ 9400,00 32.00 183.00 8779.30 -9.10 -1717.40 1029.10 0.00 0.00 0.0C 5947195.00 677298.70 9430.00 32.00 -- 183,00 8804.70 -11.80 -1733,30 1028,30 0.00 0,00 0.00 5947179.00 677298.20 2. KOP 2501100' 95° Tlc - 9460,00 32.10~ 196.59 8830.20 -12.70 -1748.90 1025.60 0.30 45.30 24.00 5947163.50 677295~90'3. 24°/100' 60° TFC 9500.0~ ...... -3-7.7---~ 210.24 8863.00 -8.30 -71769.70 1016.40 14.10 34,10 24,00 5947142.50 677287.10 9600.00 56.04 231,89 8931.50 27.40 ---1822,50 967,60 18,30 21.60 24.00 5947088.50 677239.60 9700.00 76.73 245.29 8971.50 93.00 -1869.10 889,70 20.70 13.40 24.00 5947040.00 677162,80 ,- -$2.40 90.00 252.32 8978.70 144,30 ~891.40 832.00 21,30 11.20 24.00 5947016.50 677105.60 4. EOB 4.08°1100' 89.2° TFC ....... - O0.00 90.02 253,85 8978.70 176.90 -1902.30 796.10 0.10 4,10 4.10 5947005.00 677070.00 ...... 9900.00 90.08 25-7.93 8978,60 265,90 -1926.70 699,10 0,10 4,10 4,10 5946978.00 676973.60 1~0' ~'~b~0- ........ -90.1--:~ .... -~62.01 8978.40 358,06 .... --~44.10 600, 60 0,10 4.10 4.10 5946958, 50 676875,60 10100,00 90,19 266,09 8978.10 452.60 -1954.50 501.20 0.10 4.10 4,10 5946945.50 676776,40 -- 1--0-2-0-(~'(~ .......... -9-0.2--~ ..... ~7--0.-~7 8977.80 549,30 -1957.80 401.30 0,10 4.10 4.10 5946940.00 676676.60 10300.00 90.30 274.25 8977.30 647,(~)' -1953.90 301,40 0,10 4.10 4,10 5946941.50 676576,60 '~0-~'(~0--,~ ....... 90.---~5- 278.33 8976.70 746.9~- -1943.00 202,00 0.10 4,10 4,10 5946950.50 676477.00 ---10--~0-~0- ........ ~-0.--~ .... ~8-~ ,~-~- - 8976,10 846, 80 -1925,00 103.70 0.10 4,10 4.10 5946966.00 676378.30 '--~ 06-- ~-.'(~ ....... -~0.'-~5 286.4-~8- 8975,30 946, 70 - 1900.00 6.80 0,00 4.10 4,10 5946988.50 676280.90 ..... ¥~)~7-0~'(~ ........... -9-(~.'~"0- ...... ~90.56 8974.50 1046.2~- -1868,30 :8-~i00 0,00 4.1(~ 4.10 5947018.00 676185,40 -- 10--~0~)- ......... -~-0~7 294.64 8973.60 1-~74,70 -1829,80 ---- .--1-~3-~ 0,00 4.1-~ ........... 7~----~-94--~0-5-~,..~-----~76092.30 .... 1-~8-~7-.-(~ ........... ~0-7~' 296.18 8973.20 1181.40 -1813,70 -214,20 0.00 4.10 ........ -~,-¥~- 5947070.00 676057,90 5. Inter. Tgt 2.50°/100' 92.5°--~=-~ .... ---10--~0-~b-~' .......... ~)~4-§- --'--29--~ .-~' ~' -'-- 8972.70 1242.~- ----~1-'~5,40 -269,80 :0.i0 2,50 2.50 5947096.50 676001,60 ---1-~ 00--~,'(~'~ ........... 90.--~ ....'~0--0, 2--~ .... 8971.90 1338.00 -1737.00 -357.30 -0.10 2,50 2.50 5947143.00 675913,10 ~ ............. ---~ 1--1-0-(~)-~ ...... --~.-2-~- 30--2.--~'~ 8971.30 143-2.-~-~ ...... ~8--4.80 -442.60 -0,10 2.50 .......... 2,--5~- -~)-~-~-~3.--~- 675826,60 .................... ---11--;~0-~; ....... -9'0~"~- ------~0--~.-~ ' ' 8971.00 1526,10 -1628.90 -525, 50 ~0.10 2,5~' 2.50 5-947247.50 675742,40 ---1-13--0-(~,'0'~ .......... -9-~ ,-~ ....... ~73-~ .-~'~- ----8970.80 .... -J -6-~-7-~-~ .... 71-5-~9 .-~ ....... 7~-~ :0: i 0 ..... -2~5-~ .......... ~[ ~-~~---~§?4-~'~-~[~ 675660,-~0- --'11-~'667~b' .......... §~7~- ...... ~10.--~- 8970,80 1707,~0-- -1506,50 -683,60 -0.10 -2,-5-~ ........ ~,'8~---~473---~"6,--0~ 675581.40 --~1-~5-.5'~ ........... -8-~.-§~-..... -~'~A0 '-- 8971,00 --{773.60 -1457.20 -740,10 -0,10 2.50 2,50 5947414.00 675523,90 6. B,ild uptoTD6°ll00' ~00.00 91.35 312.1--~' 8970.70 1795.40 -1440,40 .758.60 6,00 0,00 6.00 5947430.00 675504,90 ~( 30~' ......... 9- ?.-~5- ..... --~12.10 8963.10 1882,40 ..... --~"373:60 -832,60 .... 6.00 ..................................... 0.00 ......... -~.-0-~ -- 5947495.50- 675429.4'0 1 l'/b-0-~-0~- ........ '~]~a- .... ~-~-~2.1---0- --- 8945.20 1968.20 -1307,70 -905,50 6.00 0,00 6,00 5947559.50 675354.90 11800.0-0- ........ 10--~.35 312.10 8917,10 2051,90 -----1243.40 -976,70 6.00 0,00 6.00 5947622.00 675282.30 ---~§5--3-.-~ ........ ~-12.55 312.10 8898.00 2095.40 -1210,00 -1013.60 --- 6,00 0,00 6,00 5947654.50 675244,60 7. TD Total footage 2553' VERTICAL SECTION USED 282.89'~ R~lative to true North ..................... RKB ....... ~'_-_'_'_ _~&-~_ _-~. _ -47.88' . _ _ _~_~_'_-.-_- -_i- - ~_ ......................... NOTE ~. . _[ Relative Coordinates are oflTo_-~__tr_--ue_~N_~ort~---__h~-A-~P are relative to ~Fi~-~l-o-rt-~- ............... _ ................... ~-~--C~-I~ i~-~-~-~ ~... ~ 1.34° _ ............................ MAGNETIC DECLINATION 28,470 SURFACE X ~, ..... 67622__~9.. _6.4_ SURFACE YI 5948887,91 , ,, C T Drilling Wellhead Detail Otis 7" WLA Quick Connect ~ '~ CT Injector Head Stuffing Box (Pack-Off), 10,000 psi Working Pressure -- 7' Riser Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold \ Annular BOP (Hyddl),7-1/16" ID 5,000 psi working pressure Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manual'over Hydraulic 7-1/16' ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger 9-5/8" Annulus 13-3/8" Annulus Mu( Tanks 60/401 I TrplxI Ext. Fuel Shop Boilers Water Pump Root Fire Ext. Ext. ,~Pipe rack EDOWell Drilling [ quipment Trailer Preferred Major Equipment Layout for CT Drilling · WELL PERMIT CHECKLIST COMPANY ,~,/--~-~--, WELL NAME ./~_,~'~-¢'_ 7-~.,//~ PROGRAM: exp I-I dev [] redrll~serv [] wellbore seg r_} ann.. disposal para req FIELD & POOL (~ (--/d~j/,_~'/'~ INIT CLASS Zg~'_.~...,/ /--~--~., J/ GEOL AREA ~ ~'~_~ UNIT# //~'~_~'C) ON/OFF SHORE C~4 ,) ADMINISTRATION , 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. , . ~ Permit fee attached ....................... N Lease number appropriate ................... N Unique well name and number .................. N Well located in a defined pool ................... N Well located proper distance from drilling unit boundary .... N Well located proper distance from other wells .......... ,N Sufficient acreage available in drilling unit ............ N If deviated, is wellbore plat included ............... N Operator only affected party ................... N Operator has appropriate bond in force ............. N Permit can be issued without conservation order ........ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... N ENGINEERING DATE 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... (~N 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... (,~ N 22. Adequate wellbore separation proposed ............. ~ N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to 27. Choke manifold complies w/APl RP-53 (May 84) ........ 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 ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. //Y N 34. Contact name/phone for weekly pro_aress reports ...... /¢ Y N [exploratory only] REMARKS GEOLOGY: ENGINEERING: COMMISSION: BEW~,~..~ g [(,-, DWJ ~ ,¢ J DH,..-----~ R N C,Z~,/~ Commentsllnstructions: i HOW/Ijt - A:\FORMS\cheklist rev 07/97 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. * ALASKA COMPUTING CENTER * . . ****************************** *_ * ....... SCHLUlW~ERGER * ............................. COMPANY NAME : ARCO ALASKA INC. WELL NAI~iE : DS 7~O1A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292027201 REFACE NO : 98553 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 98/11/ 2 ORIGIN : FLIC REEL NAM~ : 98553 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, PRUDHOE BAY, DS 7-O1A, API #50-029-20272-01 PAGE **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 2 ORIGIN : FLIC TAPE NAM~ : 98553 CONTINUATION # : 1 PREVIOUS TAPE COMMENT : ARCO ALASKA, PRUDHOE BAY, DS 7-O1A, API #50-029-20272-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 7-O1A API NUMBER: 500292027201 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 2-NOV-98 JOB NUMBER: 98553 LOGGING ENGINEER: J SPENCER OPERATOR WITNESS: SANT/FULLER SURFACE LOCATION SECTION: 34 TOWNSHIP: 1 iN RANGE: 14E FNL: 2036 FSL: FEL: FWL: 7 ELEVATION(FT FROM MSL O) KELLY BUSHING: 47.88 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 3.188 10001.0 6.20 2ND STRING 2. 875 11821.0 6.40 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: FDN LDWG CURVE CODE: GR RUN NUMBER: PASS NUFiBER : DATE LOGGED: JUL-78 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 9392.0 9387.5 9385.0 9383.5 9380.5 9378.0 9375.5 9369.5 9367.0 9361.5 9354.0 9348 5 9342 0 9338 5 9332 0 9331 5 9329 0 9323 5 9323 0 9321 0 9316.0 9315.5 9310.5 9306.0 9305.5 9303.5 9303.0 9299.0 9295.0 9294.0 9293.5 9290.0 9284.5 9275.0 9267.5 9263.5 9256.5 9256.0 9252.0 9250.0 9246.0 9238.5 9235.5 9235.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNT 88887.0 88889.5 9393.5 9386.5 9383.5 9381.0 9377.0 9374.0 9364.0 9359.5 9352.5 9347.5 9340.0 9331.0 9327.0 9322.5 9318.0 9314.0 9308.0 9304.0 93 O1.0 9297.5 9292.0 9286.0 9281.0 9270.5 9267.0 9260.5 9255.0 9250.0 9243.5 9234.0 9376.5 9371.0 9341.5 9331.5 9322.5 9314.0 9304.0 9301.5 9294.5 9292.0 9255.0 9250.0 9237.5 9234.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9232.5 9230.5 9230.5 9226.5 9228.0 9224.5 9202.5 9201.5 9199.5 9198.5 9198.5 9187.5 9186.0 9171.5 9170.0 9168.0 9167.5 9164.0 9162.5 9161.0 9159.0 9160.0 9159.0 9158.0 9156.5 9157.0 9155.5 9152.0 9151.0 9145.5 9144.0 9144.0 9143.5 9134.5 9134.0 9131.0 9131.5 9128.5 9127.5 9128.0 9127.5 9126.0 9123.5 9125.0 9124.0 9123.0 9121.5 9121.5 9119.5 9117.5 9117.0 9116.0 9114.5 9114.5 9112.5 9114.0 9112.5 9111.0 9109.5 9110.0 9109.5 9108.0 9107.5 9107.0 9105.0 9105.5 9105.0 9102.5 9101.0 9101.0 9100.5 9099.0 9094.5 9094.0 9088.0 9085.5 9084.5 9083.5 9083.5 9081.5 9080.5 9073.5 9072.0 9072.0 9063.5 9061.5 9050.5 9048.5 9045.5 9043.5 9039.0 9040.0 9035.0 9036.0 9027.5 9027.5 9027.0 9027.5 9020.5 9020.5 9017.0 9016.5 9014.0 9013.5 9013.5 9013.5 9008.0 9006.5 8999.5 8998.5 8981.5 8981.0 8981.0 8975.0 8974.0 8965.0 8963.5 8961.0 8961.0 2-NOV-1998 16:18 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 8958.5 8948.0 8941.0 8920.5 8909.5 8909.0 8905.5 8893.5 8890.5 8881.5 8869.5 8864.0 8853.5 8835 0 8834 5 8816 5 8816 0 8808 5 8808 0 8793 5 8782 5 8779.0 8778.0 8768.0 8745.5 8745.0 8739.5 8738.5 8702.0 8686.5 8673.0 8671.5 8662.5 8644.5 8613.5 8568.5 8561.0 8552.0 8547.0 853 O. 0 8522.5 8513.5 8511.0 851 O. 0 8493.5 8492.0 8486.0 8484.5 8480.5 8473.5 8462.0 8457.5 8453.0 8447.0 8446.5 8442.5 8947.0 8940.0 8921.5 8909.5 8892.5 8881.5 8863.0 8835.0 8815.5 8807.5 8794.0 8778.0 8746.0 8740.0 8673.0 8663.0 8613.5 8561.0 8552.5 8546.5 8531.0 8524.0 8517.0 8512.5 8493.5 8480.5 8474.0 8461.5 8458.0 8453.5 8447.5 8957.5 8940.0 8909.0 8902.5 8889.5 8868.0 8863.0 8853.0 8835.0 8815.0 8807.5 8794.5 8783.5 8778.0 8767.5 8746.0 8740.0 8703.0 8686.5 8673.5 8644.5 8569.0 8510.5 8493.5 8487.0 8484.5 8458.0 8447.5 8442.0 2-NOV-1998 ~6:18 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 8437.0 8437.5 8426.5 8426.0 8426.0 8426.0 8412.5 8412.5 8402.5 8402.5 8402.0 8402.0 8384.5 8385.5 8378.5 8378.5 8361.0 8360.5 8357.0 8358.0 8354.5 8356.5 8326.0 8326.5 8318.5 8318.5 8315.0 8315.5 8315.5 8304.5 8304.0 8304.0 8304.5 8289.0 8289.0 8288.5 8289.0 8283.5 8284.0 8275.5 8274.5 8269.5 8270.5 8249.5 8250.0 8250.0 8242.5 8243.5 8229.0 8230.5 8221.5 8222.0 8220.5 8222.0 8210.5 8211.0 8205.5 8206.0 8205.0 8206.0 8195.0 8196.0 8194.5 8194.0 8178.0 8179.5 8174.0 8176.5 8171.0 8171.5 8165.0 8165.0 8163.0 8162.5 8153.5 8154.5 8150.5 8152.5 8147.0 8147.0 8135.5 8137.5 8133.0 8133.0 8116.0 8118.5 8068.0 8069.0 8061.5 8062.0 8060.0 8061.5 8052.5 8053.5 8046.5 8048.0 8036.5 8037.5 8036.0 8037.5 8027.5 8027.5 8016.5 8017.5 8005.0 8006.5 7999.5 8000.5 7987.0 7988.0 100.0 101.5 101.0 2-NOV-1998 16:18 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE MCNL DATA AQUIRED ON ARCO ALASKA'S DS 7-O1A WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE FDN GAF~4A RAY, ALSO BASE PASS #1 NRAT AND THE FDN GAMMA RAY, CARRYING ALL MCNL CURVES WITH THE NRAT SHIFTS. THE FDN GAMMA RAY IS THE TIE-IN GR FROM THE PARENT HOLE DS 7-01. THE CORRELATIONS WERE MADE DOWN TO THE TIE-IN POINT AT 9400'. THIS LOG IS THE PRIMARY DEPTH CONTROL PER DD SCHWARTZ. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: I EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMF2VT: 0.5000 FILE SGY4MARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11751.0 7975.5 CNT 11751.5 7975.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUM~ER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNT REMARKS: THIS FILE CONTAINS CASED HOLE MCNL BASE PASS #1. ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT GAPI O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 FCNTCNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11751.500 GRCH. CNT -999.250 NCNT. CNT 5338.040 FCNT. CNT NRAT. ClVT 12.613 DEPT. 7975.000 GRCH. CNT -999.250 NCNT. CNT 1894.508 FCNT. CNT NRAT. CNT 30.951 311. 940 69.383 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center * ** * FILE TRAILER * * * * FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 2-NOV-1998 16:18 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE ~ER FILE ~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~JL~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9759.5 9358.0 MCArL 9758.5 9361.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFiBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNT 88888.0 88887.5 88888.5 9755.5 9756.0 9754.0 9753.5 9751.5 9752.5 9743.0 9744.0 9739.0 9740 . 5 9735.5 973 6.5 9731 . 5 9730.0 9729.5 9731.5 9727.0 9728.0 9726.5 9724.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 9720.5 9719.5 9715.0 9716.5 9704.0 9703.0 9699.0 9698.5 9696.5 9696.0 9694.0 9693.0 9692.5 9694.0 9691.0 9690.0 9689.5 9690.5 9687.0 9685.5 9682.0 9681.0 9681.0 9679.0 9676.0 9675.5 9674.5 9672.5 9670.5 9671.0 9668.5 9668.0 9666.5 9664.5 9664.5 9666.5 9660.5 9659.0 9659.0 9661.0 9655.5 9656.0 9655.0 9655.0 9651.0 9652.5 9644.5 9644.0 9640.5 9642.0 9639.0 9636.5 9636.5 9638.0 9635.0 9635.5 9634.5 9632.5 9626.5 9628.0 9624.0 9625.0 9619.0 9617.5 9614.5 9615.5 9610.0 9609.0 9611.0 9607.5 9605.0 9599.5 9597.0 9598.5 9598.5 9593.0 9591.5 9585.0 9586.5 9582.0 9583.0 9581.0 9580.5 9578.0 9579.5 9577.0 9575.5 9574.5 9572.5 9576.0 9571.5 9572.5 9567.5 9569.0 9566.0 9564.5 9567.0 9557.5 9557.0 9559.0 9554.0 9554.0 9550.5 9551.5 9550.0 9551.0 9542.0 9541.0 9541.5 9542.5 9540.0 9539.0 9537.5 9537.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 10 953 6.5 9535.5 9534.0 9533.0 9529.5 9529.0 9524.0 9521.5 9519.0 9517.0 9515.5 9505.0 95O4.0 9502.0 9491.5 9488.5 9488.0 9481.5 9472.5 9471.5 9470.0 9465.0 9462.0 9459.0 9457.5 9452.5 9450.0 9446.0 9440 0 9439 5 9437 5 9435 0 9418 5 9414 0 9412 5 9410 0 9407 5 9406.5 9405 5 9404 0 9399 5 9396 5 9385 0 9379 5 9374 5 9370 0 9364 5 9364 0 93 61.5 100.0 REMARKS: 9538.0 9534.0 9532.0 9534.0 9529.0 9530.0 9525.5 9520.0 9522.5 9517.0 9515.0 9515.5 9504.5 9505.5 9502.5 9491.0 9488.5 9489.0 9483.0 9474.0 9470.0 9471.0 9461.0 9459.0 9455.5 9459.0 9453.0 9450.5 9448.0 9436.5 9441.0 9434.0 9436.0 9416.5 9410.0 9413.5 9406.5 9410.0 9403.5 94O7.0 9405.0 9401.5 9394.5 9386.5 9379.0 9375.5 9371.0 9365.0 9362.0 93 63.0 98.0 101.5 THIS FILE CONTAINS CASED HOLE MCNL PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NRAT PASS #2 AND NRAT LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 11 PASS #1, CARRYING ALL MCNL CURVES WITH THE NRAT SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUN~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNT GAPI O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 ArRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9759.500 NRAT. CNT -999.250 DEPT. 9358.000 1FRAT. CNT -999.250 GRCH. CNT 34.343 NCNT. CNT -999.250 FCNT. CNT GRCH. CNT 22.163 NCNT. CNT -999.250 FCNT. CNT -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 12 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11750.5 10047.5 CNT 11751.5 10048.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NU~iBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH CNT 88888.0 88886.5 88889.5 11745.5 11744.0 11745.0 11746.5 11739.5 11739.0 11731.0 11732.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 13 11728.5 11722.5 11720.0 11716.0 11713.0 11709.5 11706.0 11699.0 11695.5 11694.5 11685.0 11679.0 11677.0 11673.0 11664.0 11658.5 11651.0 11644.0 11632.5 11631.0 11623.0 11612.0 11598.5 11591.5 11588.5 11586.5 11583.0 11571.0 11569.0 11556.0 11554 5 11549 5 11543 5 11535 5 11529 5 11525 0 11522 0 11519 0 11513 5 11511 0 11508 5 11501 5 11497 5 11497.0 11481.5 11479.5 11471.5 11462.5 11461.5 11451.5 11443.5 11441.5 11435.5 11421.0 11420.5 11728.5 11721.0 11715.0 11712.5 11709.0 11697.5 11694.0 11683.5 11676.5 11657.0 11650.0 11645.0 11634.0 11588.0 11582.5 11569.0 11544.5 11535.5 11529.5 11518.5 11509.5 11498.0 11478.0 11460.5 11443.5 11419.5 11724.5 11716.0 11707.5 11696.0 11679.0 11675.5 11666.0 11660.0 11631.5 11624.5 11613.5 11598.0 11592.0 11588.0 11572.0 11557.5 11555.5 11551.5 11525.5 11523.0 11515.5 11512.0 11503.0 11499.0 11483.0 11473.0 11463.0 11452.5 11443.0 11436.5 11421.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 14 11409.5 11403.5 11400.5 11398.0 11396.5 11388 0 11387 0 11385 0 11381 5 11374 5 11371 0 11369 5 11367 0 11364 5 11358 5 11347 0 11342 5 11337 0 11327 5 11317 5 11308.5 11294.5 11292.5 11287.5 11285.0 11278.0 11273.0 11270.0 11267.0 11265.5 11260.0 11254.0 11253.0 11252.0 11235.0 11231.0 11228.5 11226.5 11218.0 11216.0 11213.0 11212.5 11205.5 11199.0 11193.0 11180.0 11178.5 11172.0 11171.0 11159.5 11154.5 11148.0 11139.0 11121.0 11113.5 11402.5 11397.5 11387.0 11381.0 11369.5 11363.5 11342.0 11325.5 11314.5 11292.5 11286.0 11284.5 11271.0 11269.0 11266.0 11252.5 11236.0 11230.5 11229.0 11217.0 11212.5 11204.0 11197.5 11176.0 11170.5 11157.5 11147.0 11137.5 11112.0 11410.0 11402.5 11398.0 11389.5 11386.0 11375.5 11370.5 11368.5 11358.5 11347.5 11338.5 11309.5 11294.5 11280.0 11267.5 11261.5 11256.5 11254.0 11228.5 11218.0 11213.5 11194.0 11180.0 11173.0 11157.5 11122.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 15 11106.5 11105.5 11100.0 11072.0 11071.0 11054.5 11049.0 11040.0 11029.5 11011.5 11007.0 10999.0 10987.5 10981.5 10978.5 10975.0 10973.5 10961.0 10950.5 10931.0 10930.5 10928.5 10920.5 10916.0 10910.0 10908.5 10902.5 10893 0 10882 5 10880 0 10878 0 10863 5 10857 0 10853 0 10849 0 10844 5 10842 0 10839 0 10820 5 10807 0 10805 5 10796 0 10787 5 10786 5 10783.0 10777.0 10759.0 10741.0 10738.5 10731.0 10713.0 10710.5 10691.5 10689.0 10687.0 11104.5 11068.5 11044.5 11008.5 11004.5 10974.5 10971.0 10960.0 10951.0 10931.5 10930.5 10921.5 10917.5 10911.0 10908.0 10902.5 10876.5 10873.5 10853.0 10845.5 10838.0 10819.0 10803.0 10785.5 10781.0 10774.0 10756.0 10734.5 10729.0 10712.5 10709.5 10690.0 10686.5 11107.0 11101.5 11072.5 11055.5 11042.0 11031.0 11000.5 10989.5 10981.5 10975.5 10932.0 10910.0 10894.5 10882.5 10865.0 10855.5 10847.0 10841.5 10808.5 10797.0 10790.0 10762.5 10744.0 10712.5 10690.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 16 10675 5 10673 0 10668 0 10654 5 10650 0 10642 5 10636.0 10632 5 10631 0 10620 0 10614 0 10610 5 10604 5 10594 5 10593 0 10581 5 10581 0 10575 5 10561 0 10557.0 10545.0 10540.5 10530.0 10522.5 10518.5 10513.5 10509.0 10502.5 10500.5 10489.0 10487.0 10481.5 10475.5 10469.0 10467.0 10460.5 10456.5 10455.5 10447.5 10439.0 10419.0 10416.5 10414.5 10409.0 10398.5 10394.0 10384.0 10365.0 10364.5 10359.0 10346.0 10343.5 10335.0 10334.5 10330.0 10675.0 10668.5 10655.0 10648.0 10634.5 10630.5 10619.5 10612.5 10602.5 10591.5 10579.0 10572.0 10552.5 10538.5 10522.0 10516.5 10512.0 10503.5 10489.0 10487.5 10473.0 10468.0 10456.0 10412.5 10397.5 10392.0 10362.5 10342.5 10331.0 10327.5 10674.5 10643.5 10632.5 10611.5 10596.0 10583.5 10562.0 10543.5 10531.5 10519.5 10507.5 10499.5 10489.0 10482.5 10465.5 10459.5 10454.0 10447.0 10438.0 10419.5 10417.0 10407.5 10384.5 10367.0 10359.5 10347.5 10344.5 10335.5 10331.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 17 10322.0 10318.5 10317.0 10310.0 10306.0 10301.5 10296.5 10293.0 10282.0 10276.5 10273.0 10266.5 10257.0 10244.0 10242.0 10241.0 10238.0 10227.5 10226.0 10226.0 10223.0 10219.0 10213.5 10212.0 10208.0 10203.0 10198.0 10196.5 10194.0 10193.5 10190.0 10190.5 10180.0 10158.0 10152.0 10151.0 10150.0 10148.0 10143.0 10134.0 10131.0 10131.5 10110.5 10110.0 10107.5 10101.5 10100.0 10092.0 10087.5 10080.5 10079.0 10078.0 10068.5 10067.5 10062.0 10058.5 10058.0 100.0 99.5 $ 10318.0 10302.5 10297 0 10294 5 10283 0 10277 5 10273 0 10267 5 10258 0 10244 5 10238.5 10228.5 10222.5 10218.5 10210.5 10204.0 10190.0 10181.5 10159.5 10151.5 10148.5 10144.5 10135.5 10108.5 10093.0 10088.5 10081.5 10079.0 10062.0 10058.5 100.0 REMARKS: THIS FILE CONTAINS CASED HOLE MCNL BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #1 AND GRCH BASE PASS #1, ALSO NRAT BORAX PASS #1 AND NRAT BASE PASS #1, CARRYING ALL MCNL CURVES WITH THE NRAT SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 18 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 ?T 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNT GAPI O0 000 O0 0 3 1 1 4 68 0000000000 NCNTCNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 FCNTCNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11751.500 GRCH. CNT -999.250 NCNT. CNT 4755.033 FCNT. CNT NRAT. CNT 12.876 DEPT. 10047.500 GRCH. CNT 29.381 NCNT. CNT -999.250 FCNT. CNT NRAT. CNT -999.250 272. 804 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 19 **** FILE TRAILER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION . O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INC~: 0.5000 FILE SOF~N~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11776.5 10058.0 CNT 11777.0 10059.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUAi~ER : 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH CNT 88888.0 88886.5 88889.0 11746.0 11747.0 11745.0 11743.5 11733.0 11732.0 11725.0 11726.5 11715.0 11716.0 11714.0 11712.5 11705.0 11703.0 11702.0 11703.0 11701.0 11700.5 11694.5 11693.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 20 11689.0 11682.5 11674.0 11661.0 11659.5 11658.0 11648 5 11647 5 11643 0 11637 0 11636 0 11624 5 11623 5 11606 0 11605 0 11585 0 11558 5 11556 0 11555 0 11550 0 11543 0 11538 5 11526.0 11523 5 11522 0 11512 5 11503 5 11502 5 11500 5 11496.0 11482 0 11471 0 11462 5 11461 5 11451 5 11445 5 11438 5 11433 5 11431 0 11425 5 11423 5 11415 0 11413 5 11411 5 11408 0 11405 0 11400 5 11388 5 11388 0 11381 0 11380 0 11377 0 11375 5 11368 5 11366.0 11683.5 11658.5 11649.0 11635.5 11626.5 11608.0 11559.0 11526.5 11506.5 11461.0 11443.5 11411.5 11409.5 11384.0 11377.5 11373.0 11364.0 11690.0 11675.0 11662.0 11659.5 11650.0 11643.0 11636.0 11624.5 11606.5 11586.0 11560.0 11555.5 11551.5 11544.5 11540.5 11525.5 11523.0 11513.5 11504.5 11500.0 11494.5 11483.0 11472.0 11463.0 11453.0 11440.0 11436.5 11434.0 11428.0 11424.5 11414.0 11407.5 11405.5 11402.5 11389.5 11381.5 11375.5 11369.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 21 11364.5 11366.0 11363.5 11361.0 11362.5 11363.0 11344.5 11346.0 11341.0 11342.0 11339.0 11340.0 11331.5 11332.0 11328.5 11328.0 11315.0 11314.5 11304.5 11303.5 11300.0 11300.0 11297.0 11297.5 11293.0 11294.5 11290.0 11289.5 11287.0 11287.0 11275.5 11275.5 11272.5 11272.5 11271.5 11271.0 11266.0 11266.0 11267.0 11253.5 11253.5 11251.0 11249.0 11241.5 11241.0 11236.5 11236.0 11231.5 11233.0 11218.0 11217.0 11218.0 11213.5 11214.0 11198.0 11198.0 11193.0 11194.5 11187.0 11186.0 11178.5 11179.0 11170.0 11173.0 11167.5 11166.0 11163.0 11162.0 11159.0 11157.5 11154.0 11154.0 11148.0 11149.5 11144.5 11143.5 11137.0 11135.5 11121.0 11122.5 11114.0 11112.0 11115.5 11105.5 11107.0 11100.5 11102.0 11074.0 11074.0 11071.5 11072.5 11070.5 11071.5 11069.0 11068.5 11056.0 11056.0 11055.0 11055.0 11052.5 11053.5 11040.0 11039.0 11034.5 11035.5 11029.0 11030.5 11020.5 11020.0 11018.5 11020.0 11018.0 11018.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 22 11006.0 11006.0 11005.5 11005.0 11001.0 11002.5 10998.5 11000.5 10992.0 10992.5 10987.5 10989.5 10982.5 10984.0 10976.5 10979.5 10971.5 10973.5 10969.5 10970.5 10964.0 10964.0 10959.5 10959.5 10956.0 10957.5 10938.0 10939.0 10931.5 10930.5 10929.5 10931.5 10915.5 10917.0 10913.5 10914.0 10905.0 10907.5 10882.5 10882.0 10880.5 10882.5 10872.5 10875.5 10866.5 10868.0 10863.5 10865.0 10863.0 10863.0 10851.0 10851.0 10846.5 10847.5 10819.5 10818.5 10816.5 10817.0 10800.0 10801.0 10786.0 10788.0 10784.0 10785.5 10774.0 10773.5 10770.5 10769.5 10766.0 10768.0 10762.0 10765.0 10759.0 10762.5 10757.0 10756.0 10747.5 10746.0 10740.0 10744.0 10731.0 10728.5 10717.0 10714.5 10711.0 10713.0 10709.0 10706.5 10689.5 10691.0 10678.5 10675.0 10662.5 10661.0 10662.0 10664.0 10656.5 10659.0 10655.0 10656.0 10653.0 10650.0 10641.0 10643.0 10640.0 10637.5 10632.0 10630.5 10597.5 10596.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 23 10584.5 10583.5 10579.0 10582.0 10563.5 10561.0 10556.0 10553.0 10546.0 10547.5 10510.0 10509.0 10507.5 10507.5 10505.5 10503.5 10498.0 10499.0 10497.0 10495.5 10482.0 10485.0 10480.5 10482.5 10468.0 10468.5 10462.0 10464.0 10460.0 10460.0 10458.5 10457.5 10454.0 10456.0 10416.0 10417.0 10391.0 10392.0 10383.5 10384.5 10380.5 10383.0 10375.0 10376.5 10366.5 10369.0 10343.0 10344.5 10333.5 10335.5 10329.0 10331.5 10324.5 10326.5 10316.5 10318.0 10314.5 10315.5 10301.0 10302.5 10288.0 10289.0 10281 . 5 10283 . 0 10276.0 10277.5 10271.5 10274.5 10268.0 10269.0 10256.0 10258.0 10243.0 10244.5 10236.5 10239.0 10217.0 10218.5 10209.5 10210.0 10202.5 10204.0 10193.5 10193.0 10189.5 10189.5 10188.0 10190.5 10184.5 10186.5 10181.0 10180.0 10164.5 10168.0 10154.0 10154.5 10150.5 10153.0 10145.5 10147.5 10144.0 10145.5 10143.0 10144.5 10139.0 10139.5 10137.0 10136.5 10130.5 10132.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 24 10126.5 10128.5 10109.0 10110.0 10106.5 10108.5 10098.0 10099.5 10094.5 10096.5 10080.5 10081.5 10077.0 10077.0 10079.0 10065.0 10066.5 100.0 100.0 101.5 $ REM_ARKS: THIS FILE CONTAINS CASED HOLE MCNL BORAX PASS H2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH BORAX PASS H2ANDGRCH BASE PASS Hi, ALSO NRAT BORAX PASS H2 AND NRAT BASE PASS Hi, CARRYING ALL MCNL CURVES WITH THE NRAT SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNT GAPI O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 25 NAN1E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) FCNTCNT CPS O0 000 O0 0 4 1 1 4 68 0000000000 ATRAT CNT O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11777.000 NRAT. CNT 14.582 DEPT. 10058.000 NRAT. CNT -999.250 GRCH. CNT -999.250 NCNT. CNT 3708.562 FCNT. CNT GRCH. CNT 27.809 NCNT. CNT -999.250 FCNT. CNT 198.551 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION · O01CO1 DATE · 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJM~ER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS CNT 1, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 26 REMARKS: THIS FILE CONTAINS THE ARITHPIETIC AVERAGE OF BASE PASSES 1 & 2. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 5 1 1 4 68 0000000000 GRCH CNAV GAPI O0 000 O0 0 5 1 1 4 68 0000000000 CVEL CNAV F/HR O0 000 O0 0 5 1 1 4 68 0000000000 NCNT CNAV CPS O0 000 O0 0 5 1 1 4 68 0000000000 FCNT CNAV CPS O0 000 O0 0 5 1 1 4 68 0000000000 NRAT CNAV O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11751.000 GRCH. CNAV 196.874 FCNT. CNAV -999.250 NRAT. CNAV -999.250 CVEL.CNAV -999.250 NCNT. CNAV -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 27 DEPT. 7975.500 GRCH. CNAV 49.001 CVEL.CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 NRAT. CNAV -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE ·FLIC VERSION ·O01CO1 DATE · 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NLFMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NTRVlBER: 1 DEPTH INCREMeNT: 0.1000 FILE SUAR~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11783.0 7956.0 MCNL LOG HEADER DATA DATE LOGGED .. SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) 24-AUG-98 RELOO31A 11821.0 11791.0 7974.0 11776.0 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 28 VENDOR TOOL CODE TOOL TYPE GR GA~A RAY MCNL MEMORY COMP NEUTRON $ TOOL NUMBER GR MCNL BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10001.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): REMARKS: 1. Depth correlated to Sperry-Sun MWD log dated 6-Jan-98. 2. Well schematic referenced showed: a. Top-of-liner at 8188 ft MD (It appears to be at 8138 ft MD). b. 3 1/2" x 3 3/16" x-over at 8286 ft MD (It appears to be at 8238 ft MD). c. 3 3/16" x 2 7/8" x-over at 10005 ft MD (It appears to be at 9956 ft MD). 3. 311 bbls crude was pumped prior to logging main Baseline pass. 1.5 bbl/min crude was pumped during logging of this pass. 498 bbls of crude and 45 bbls Borax was pumped prior to logging Repeat Section Baseline pass. (No Borax was into formation at this time). LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 29 3 bbls/min Borax was pumped during logging of this pass. A total of 352 bbls Borax was pumped before prior to logging Borax pass #1. (Approx. 191 bbls Borax was into the formation at start of log). Pumped 1.7 bbls/min during pass. 4. Final presentation of log format was selected by Dwight Warner. 5. Tagged T at 11791 ft I4D on Borax Pass #2 only. Stopped higher on previous passes due to weight stacking. 6. Ail perforations are open. 7. Ail passes were loged at 30 FPM. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 $ 66 6 73 7 65 8 68 O. 1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELEM CODE (HEX) DEPT FT O0 000 00 0 6 1 1 4 68 0000000000 CVEL PS1 F/HR O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI O0 000 O0 0 6 1 1 4 68 0000000000 NCNTPS1 CPS O0 000 O0 0 6 1 1 4 68 0000000000 FCNTPSl CPS O0 000 O0 0 6 1 1 4 68 0000000000 ArRAT PS1 O0 000 O0 0 6 1 1 4 68 0000000000 CCLD PS1 V O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 3O ** DATA ** DEPT. 11783.000 CVEL.PS1 -999.250 GR.PS1 -999.250 NCNT. PS1 FCNT. PS1 -999.250 NRAT. PS1 -999.250 CCLD.PS1 -999.250 DEPT. 7956.000 CVEL.PS1 -999.250 GR.PS1 -999.250 NCNT. PS1 FCNT. PS1 -999.250 NRAT. PS1 -999.250 CCLD.PS1 85.104 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE · 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.1000 FILE SUPmL~RY VENDOR TOOL CODE START DEPTH MCNL 9778.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: STOP DEPTH .......... 9344.5 24-AUG-98 RELOO31A LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 31 TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 11821.0 11791.0 7974.0 11776.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMFiA RAY MCNL ~ORY COMP NEUTRON $ TOOL NUMBER GR MCNL BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10001.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOF~E (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): 1. Depth correlated to Sperry-Sun MWD log dated 6-Jan-98. 2. Well schematic referenced showed: a. Top-of-liner at 8188 ft ~D (It appears to be at 8138 ft ~D). b. 3 1/2" x 3 3/16" x-over at 8286 ft ~D (It appears to be at 8238 ft MD). c. 3 3/16" x 2 7/8" x-over at 10005 ft ~D (It appears LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 32 to be at 9956 ft ~4D). 3. 311 bbls crude was pumped prior to logging main Baseline pass. 1.5 bbl/min crude was pumped during logging of this pass. 498 bbls of crude and 45 bbls Borax was pumped prior to logging Repeat Section Baseline pass. (No Borax was into formation at this time). 3 bbls/min Borax was pumped during logging of this pass. A total of 352 bbls Borax was pumped before prior to logging Borax pass #1. (Approx. 191 bbls Borax was into the formation at start of log). Pumped 1.7 bbls/min during pass. 4. Final presentation of log format was selected by D~ight Warner. 5. Tagged T at 11791 ft f4D on Borax Pass #2 only. Stopped higher on previous passes due to weight stacking. 6. All perforations are open. 7. Ail passes were loged at 30 FPM. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 O. 1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 33 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SgMP ELt~I CODE (HEX) DEPT FT O0 000 O0 0 7 1 1 4 68 0000000000 CVEL PS2 F/HR O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI O0 000 O0 0 7 1 1 4 68 0000000000 NCNTPS2 CPS O0 000 O0 0 7 1 1 4 68 0000000000 FCNTPS2 CPS O0 000 O0 0 7 1 1 4 68 0000000000 NRAT PS2 O0 000 O0 0 7 1 1 4 68 0000000000 CCLD PS2 V O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9778.000 CVEL.PS2 -999.250 GR.PS2 -999.250 NCNT. PS2 FCNT. PS2 -999.250 NRAT. PS2 -999.250 CCLD.PS2 -999.250 DEPT. 9344.500 CVEL.PS2 -999.250 GR.PS2 -999.250 NCNT. PS2 FCNT. PS2 -999.250 1FRAT. PS2 -999.250 CCLD.PS2 84.581 -999.250 -999.250 ** EArD OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NA~4~ : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 34 DEPTH INC~: 0.1000 FILE SU~mL~RY VENDOR TOOL CODE START DEPTH 11786.0 MCNL LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~iE LOGGER ON BOTTOM: TD DRILLER (FT) '. TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO) TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY MCNL MEMORY COMP NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) '. DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 10031.5 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 24-AUG-98 RELOO31A 11821.0 11791.0 7974.0 11776.0 1800.0 TOOL NUMBER GR MCNL 10001.0 THERMAL LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 FAR COUNT RATE HIGH SCALE (CPS): 2200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): 1. Depth correlated to Sperry-Sun MWD log dated 6-Jan-98. 2. Well schematic referenced showed: a. Top-of-liner at 8188 ft FiD (It appears to be at 8138 ft MD). b. 3 1/2" x 3 3/16" x-over at 8286 ft MD (It appears to be at 8238 ft MD). c. 3 3/16" x 2 7/8" x-over at 10005 ft f4D (It appears to be at 9956 ft MD). 3. 311 bbls crude was pumped prior to logging main Baseline pass. 1.5 bbl/min crude was pumped during logging of this pass. 498 bbls of crude and 45 bbls Borax was pumped prior to logging Repeat Section Baseline pass. (No Borax was into formation at this time). 3 bbls/min Borax was pumped during logging of this pass. A total of 352 bbls Borax was pumped before prior to logging Borax pass #1. (Approx. 191 bbls Borax was into the formation at start of log). Pumped 1.7 bbls/min during pass. 4. Final presentation of log format was selected by Dwight Warner. 5. Tagged T at 11791 ft MD on Borax Pass #2 only. Stopped higher on previous passes due to weight stacking. 6. All perforations are open. 7. Ail passes were loged at 30 FPM. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #1. $ LIS FORMAT DATA PAGE: 35 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 8 1 1 4 68 0000000000 CVEL BX1 F/HR O0 000 O0 0 8 1 1 4 68 0000000000 GR BX1 GAPI O0 000 O0 0 8 1 1 4 68 0000000000 NCNTBX1 CPS O0 000 O0 0 8 1 1 4 68 0000000000 FCNTBX1 CPS O0 000 O0 0 8 1 1 4 68 0000000000 NRAT BX1 O0 000 O0 0 8 1 1 4 68 0000000000 CCLDBX1 V O0 000 O0 0 8 1 1 4 68 0000000000 PAGE: 36 ** DATA ** DEPT. 11786.000 CVEL.BX1 -999.250 GR.BX1 -999.250 NCNT. BX1 -999.250 FCNT. BX1 -999.250 NRAT. BX1 -999.250 CCLD.BX1 -999.250 DEPT. 10031.500 CVEL.BX1 FCNT.BX1 -999.250 NRAT. BX1 -999.250 GR.BX1 -999.250 NCNT. BX1 -999.250 CCLD.BX1 85.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 37 **** FILE HEADER **** FILE NAFiE : EDIT .009 SERVICE 'FLIC VERSION ·O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASSNUMBER: 4 DEPTH INCREMENT: 0.1000 FILE S~Y VENDOR TOOL CODE START DEPTH MCNL LOG HEADER DATA DATE LOGGED: 11812.0 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 10042.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY MCNL M~MORY COMP NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 24-AUG-98 RELOO31A 11821.0 11791.0 7974.0 11776.0 1800.0 TOOL NUMBER GR MCNL 10001.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 38 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): THERMAL BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): REMARKS: 1. Depth correlated to Sperry-Sun MWD log dated 6-Jan-98. 2. Well schematic referenced showed: a. Top-of-liner at 8188 ft ~ID (It appears to be at 8138 ft MD). b. 3 1/2" x 3 3/16" x-over at 8286 ft MD (It appears to be at 8238 ft MD). c. 3 3/16" x 2 7/8" x-over at 10005 ft ~4D (It appears to be at 9956 ft MD). 3. 311 bbls crude was pumped prior to logging main Baseline pass. 1.5 bbl/min crude was pumped during logging of this pass. 498 bbls of crude and 45 bbls Borax was pumped prior to logging Repeat Section Baseline pass. (No Borax was into formation at this time). 3 bbls/min Borax was pumped during logging of this pass. A total of 352 bbls Borax was pumped before prior to logging Borax pass #1. (Approx. 191 bbls Borax was into the formation at start of log). Pumped 1.7 bbls/min during pass. 4.Final presentation of log format was selected by Dwight Warner. 5. Tagged T at 11791 ft MD on Borax Pass #2 only. Stopped higher on previous passes due to weight stacking. 6.Ail perforations are open. 7.Ail passes were loged at 30 FPM. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-NOV-1998 16:18 PAGE: 39 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 O. 1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) DEPT FT O0 000 O0 0 9 1 1 4 68 0000000000 CVEL BX2 F/HR O0 000 O0 0 9 1 1 4 68 0000000000 GR BX2 GAPI O0 000 O0 0 9 1 1 4 68 0000000000 NCNTBX2 CPS O0 000 O0 0 9 1 1 4 68 0000000000 FCNTBX2 CPS O0 000 O0 0 9 1 1 4 68 0000000000 NRAT BX2 O0 000 O0 0 9 1 1 4 68 0000000000 CCLDBX2 V O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 11812.000 CVEL.BX2 -999.250 GR.BX2 -999.250 NCNT. BX2 -999.250 FCNT. BX2 -999.250 NRAT. BX2 -999.250 CCLD.BX2 -999.250 DEPT. 10042.000 CVEL.BX2 -999.250 GR.BX2 -999.250 NCNT. BX2 -999.250 FCNT. BX2 -999.250 NRAT. BX2 -999.250 CCLD.BX2 85.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE . FLIC VERSION : O01CO1 DATE : 98/11/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 2-NOV-1998 16:18 PAGE: 40 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 2 ORIGIN : FLIC TAPE NA~E : 98553 CONTINUATION # .. 1 PREVIOUS TAPE : COM~IE~f : ARCO ALASKA, PRUDHOE BAY, DS 7-O1A, API #50-029-20272-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 2 ORIGIN : FLIC REEL NAi~E : 98553 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, PRUDHOE BAY, DS 7-O1A, API #50-029-20272-01 Sperry-Sun Drilling Services LIS Scan Utility Tue Feb 10 14:33:13 1998 Reel Header Service name ............. LISTPE Date ..................... 98/02/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Date~~~,~.~,~ Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/02/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-I~W-80057 W. JACKSON GARY GOODRIC DS 7-0lA PB1 500292027270 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 10-FEB-98 MWD RUN 4 AK-MW-80057 A. WORTHINGT DAN KARA MWD RUN 7 AK-MW-80057 A. WORTHINGT DAN KARA JOB NUMBER: LOGGING ENGINEER: OPEkATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: kANGE: FNL: FSL: FEL: MWD RUN 8 AK-MW- 80057 A. WORTHINGT DAN KARA liN 14E 2036 FWL: 7 ELEVATION (FT FROM MSL 0) KELLY BUSHING: -47.90 DERRICK FLOOR: .00 GROUND LEVEL: .00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 7.000 9429.0 PRODUCTION STRING 3.800 9918.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUB-SEA TRUE VERTICAL DEPTHS (SSTVD) . 3. MWD RUNS 1-9 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINITILLATION DETECTOR. MWD RUNS 2,3,5,6, AND 9 MADE NO FOOTAGE AND ARE NOT PRESENTED. 4. DEPTH SHIFT/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ROBERT MORSE OF ARCO ALASKA, INC. AND R KALISH OF SPERRY-SUN DRILLING SERVICES ON 02/10/98 (OWING TO INSUFFICIENT GR CORRELATION). 5. MWD RUNS 1,4,7, AND 8 REPRESENT WELL 07-lA PB1 WITH API#: 50-029-20272-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9918'MD, 8974'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 ....... 98/02/10 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 ROP 9370.0 9917.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: MEASURED DEPTH) - EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 9370.0 9421.0 4 9421.0 9439.0 7 9439.0 9748.0 8 9748.0 9918.0 MERGED MAIN PASS. $ 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 9342 9917.5 9629.75 1152 9342 GR 13.62 807.93 75.7576 1096 9342 ROP 7.5 1180.02 56.7578 1096 9370 Last Reading 9917.5 9889.5 9917.5 First Reading For Entire File .......... 9342 Last Reading For Entire File ........... 9917.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/10 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 Numbez ........... 1.0.0 Date of Generation ....... 98/02/10 Maximum Physical Record..65535 File T?pe ................ 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 STA2~T DEPTH GR 9342.0 ROP 9370.0 $ 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: MAXIt~JM ANGLE: STOP DEPTH 9392.5 9420.5 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) : I~UD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 21-DEC-97 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 9421.0 9370.0 9421.0 .0 .0 TOOL NUMBER NGP SPC 176 3.800 3.8 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 80.0 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 .3 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 9342 9420.5 9381.25 158 9342 GR 16.62 23.81 19.0424 102 9342 ROP 7.5 1180.02 51.6551 102 9370 Last Reading 9420.5 9392.5 9420.5 First Reading For Entire File .......... 9342 Last Reading For Entire File ........... 9420.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/10 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 ....... 98/02/10 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: 4 DEPTH INCREMENT: .5000 FILE SUMY~3~Y VENDOR TOOL CODE START DEPTH GR 9393.0 ROP 9421.0 $ 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 A/~GLE: STOP DEPTH 9412.5 9438.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMYiA PROBE $ BOREHOLE A_ND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: PrUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: 24-DEC-97 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 9439.0 9430.0 9439.0 .0 .0 TOOL NUMBER NGP SPC 164 3.800 3.8 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 77.3 .3 $ 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 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9393 9438.5 9415.75 92 9393 GR 13.62 20.27 17.71 40 9393 ROP 10.86 225 38.9233 36 9421 Last Reading 9438.5 9412.5 9438.5 First Reading For Entire File .......... 9393 Last Reading For Entire File ........... 9438.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/10 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 ....... 98/02/10 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: 7 DEPTH INCREMENT: .5000 FILE S~_RY VENDOR TOOL CODE START DEPTH GR 9413.0 ROP 9439.5 $ LOG HEADER DATA DATE LOGGED: S O FTWARE 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 9720.5 9748.0 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 (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: I~UITRIX DENSITY: HOLE CORRECTION (IN): TOOL STA~qDOFF (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 26-DEC-97 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 9748.0 9439.0 9748.0 41.0 78.3 TOOL NUMBER NGP SPC 164 4.250 4.3 FLO-PRO 9.10 .0 9.3 8.0 .000 .000 .000 .000 63.3 .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 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9413 9748 9580.5 671 9413 GR 19.8 807.93 64.3288 616 9413 ROP 10.38 1123.39 56.229 618 9439.5 Last Reading 9748 9720.5 9748 First Reading For Entire File .......... 9413 Last Reading For Entire File ........... 9748 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9721.0 9889.5 ROP 9748.0 9917.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO 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 (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX:' MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 26-DEC-97 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 9918.0 9748.0 9918.0 82.5 94.8 TOOL NUMBER NGP SPC 209 4.250 4.3 FLO-PRO 9.10 .0 9.0 7.5 .000 .000 .000 .000 60.9 .3 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 8 AAPI 4 1 68 ROP MWD 8 AAPI 4 1 68 Code Offset 0 4 8 Channel 1 2 3 Name Min Max Mean Nsam DEPT 9721 9917.5 9819.25 394 GR 25.93 198.29 120.571 338 ROP 14.17 593.06 61.2621 340 First Reading 9721 9721 9748 Last Reading 9917.5 9889.5 9917.5 First Reading For Entire File .......... 9721 Last Reading For Entire File ........... 9917.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/02/10 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 ..................... 98/02/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File sperry-Sun Drilling Services LIS Scan Utility Wed Feb 11 15:54:28 1998 Reel Header Service name ............. LISTPE Date ..................... 98/02/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/02/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPEgATOR WITNESS: MWD RUN 1 AK-MW-80057 W. JACKSON GARY GOODRIC M C OF LM D , DS 7-0lA 500292027201 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES il-FEB-98 MWD RUN 4 AK-MW- 80057 A. WORTHINGT DAN KARA MWD RUN 7 AK-MW- 80057 A. WORTHINGT DAN KARA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 11 AK-MW- 80057 A. WORTHINGT DAN KARA MWD RUN 12 AK-MW- 80057 A. WORTHINGT DAN KARA MWD RUN 13 AK-MW- 80057 A. WORTHINGT DAN KARA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 14 AK-MW-80057 A. WORTHINGT ARVELL BASS MWD RUN 15 AK-MW-80057 A. WORTHINGT ARVELL BASS MWD RUN 16 AK-MW- 80057 A. WORTHINGT ARVELL BAS S JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 17 AK-MW-80057 W. JACKSON ARVELL BASS MWD RUN 18 AK-MW-80057 W. JACKSON ARVELL BASS MWD RUN 19 AK-MW-80057 W. JACKSON ARVELL BASS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 20 AK-MW-80057 W. JACKSON ARVELL BASS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: File Header liN 14E 2036 -47.90 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 9429.0 3.800 11823.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUB-SEA TRUE VERTICAL DEPTHS (SSTVD) . 3. MWD RUNS 1-20 ARE DIRECTIONAL WITH NATURAL GAN~L~ PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. MWD RUNS 2,3,5,6,9,AND 10 MADE NO FOOTAGE AND ARE NOT PRESENTED. 4. DEPTH SHIFT/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN R. MORSE OF ARCO ALASKA, INC. AND R. KALISH OF SPERRY-SUN DRILLING SERVICES ON 02/10/98: NO CORRELATABLE GAMMA DATA IS AVAILABLE. 5. MWD RUNS 1,4,7, AND 11-20 REPRESENT WELL 7-0lA WITH API#: 50-029-20272-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11823'MD, 8944'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 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 SUMY~RY PBU TOOL CODE START DEPTH STOP DEPTH GR 9342.0 11797.0 ROP 9370.0 11822.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH .... BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 9370.0 9421.0 MWD 4 9421.0 9439.0 MWD 7 9439.0 9593.0 MWD 11 9592.0 9637.0 MWD 12 9637.0 9898.0 MWD 13 9898.0 10026.0 MWD 14 10026.0 10728.0 MWD 15 10728.0 10908.0 MWD 16 10908.0 11095.0 MWD 17 11095.0 11337.0 MWD 18 11337.0 11581.0 MWD 19 11581.0 11651.0 MWD 20 11651.0 11823.0 $ REMARKS: MERGED MAIN PASS. $ 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 I~D FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 9342 11822.5 10582.2 4962 GR 13.62 1293.66 46.472 4911 ROP 1.09 2330.56 94.8279 4906 First Last Reading Reading 9342 11822.5 9342 11797 9370 11822.5 First Reading For Entire File .......... 9342 Last Reading For Entire File ........... 11822.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Cormment 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 STOP DEPTH GR 9342.0 9392.5 ROP 9370.0 9420.5 $ LOG HEADER DATA DATE LOGGED: 21-DEC-97 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 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 9421.0 9370.0 9421.0 MINIMUM ANGLE: FLAX II~JM oA]~GLE: 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 (OH~{M) 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 31.1 32.5 TOOL NUMBER NGP SPC 176 3.800 3.8 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 80.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP I~D 1 FT/H 4 1 68 4 2 GR MWD 1 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9342 9420.5 9381.25 158 9342 ROP 7.5 1180.02 51.6551 102 9370 GR 16.62 23.81 19.0424 102 9342 Last Reading 9420.5 9420.5 9392.5 First Reading For Entire File .......... 9342 Last Reading For Entire File ........... 9420.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 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: 4 DEPTH INCREMENT: .5000 FILE SUFR4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9393.0 9412.5 ROP 9421.0 9438.5 $ LOG HEADER DATA DATE LOGGED: 24-DEC-97 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: 33.4 MAXIMUM ANGLE: 34.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 9439.0 9430.0 9439.0 TOOL NUMBER NGP SPC 164 BOREHOLE 'AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 3.800 3.8 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 AAPI 4 I 68 8 3 77.3 First Name Min Max Mean Nsam Reading DEPT 9393 9438.5 9415.75 92 9393 ROP 10.86 225 38.9233 36 9421 GR 13.62 20.27 17.71 40 9393 Last Reading 9438.5 9438.5 9412.5 First Reading For Entire File .......... 9393 Last Reading For Entire File ........... 9438.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Conunent Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE S~RY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9413.0 9593.0 ROP 9439.5 9593.0 $ LOG HEADER DATA DATE LOGGED: 26-DEC-97 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: 41.0 M3~XIMUM ANGLE: 78.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE .~D CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 9748.0 9439.0 9748.0 TOOL NUMBER NGP SPC 164 4.250 4.3 FLO- PRO MUD DENSITY (LB/G) : l~fgD VISCOSITY S) : MUD PH: ]~fUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 9.10 .0 9.3 8.0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 7 FT/H 4 1 68 4 2 GR MWD 7 AAPI 4 1 68 8 3 63.3 First Name Min Max Mean Nsam Reading DEPT 9413 9593 9503 361 9413 ROP 21.52 101.37 52.437 308 9439.5 GR 21.72 155.36 44.2639 361 9413 Last Reading 9593 9593 9593 First Reading For Entire File .......... 9413 Last Reading For Entire File ........... 9593 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9593.0 ROP 9593.0 $ 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: STOP DEPTH 9610.0 9637.0 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 N~JD TYPE: MUD DENSITY (LB/G) : I~UD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 29-DEC-97 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 9637.0 9592.0 9637.0 53.2 53.2 TOOL NUMBER NGP SPC 209 3.750 3.8 FLO-PRO 9.50 .0 9.5 8.0 .000 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: I~UD CAKE AT MT: NEUTRON TOOL MATRIX: M~ATRIX 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 ,000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT ~- FT 4 1 68 0 1 GR MWD 11 AAPI 4 1 68 4 2 ROP MWD 11 FT/H 4 1 68 8 3 58.6 First Name Min Max Mean Nsam Reading DEPT 9593 9637 9615 89 9593 GR 25.78 63.29 36.9569 35 9593 ROP 1.09 1064.42 51.6451 89 9593 Last Reading 9637 9610 9637 First Reading For Entire File .......... 9593 Last Reading For Entire File ........... 9637 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... !.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUI~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9610.5 9869.0 ROP 9637.5 9895.5 $ LOG HEADER DATA DATE LOGGED: 30-DEC-97 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: 59.7 MAXIMUM ANGLE: 94.7 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 9898.0 9637.0 9898.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GA/V[MA PROBE $ TOOL NUMBER NGP SPC 209 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 4.250 4.3 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): IvfUD AT MAX CIRCULATING TERMPERATURE: !qUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.60 .0 11.0 6.2 .000 .000 .000 .000 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REIfARKS: $ 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 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 12 AAPI 4 1 68 4 2 ROP MWD 12 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9610.5 9895.5 9753 571 9610.5 GR 14.905 231.24 65.8348 518 9610.5 ROP 8.42 1459.1 78.4947 517 9637.5 Last Reading 9895.5 9869 9895.5 First Reading For Entire File .......... 9610.5 Last Reading For Entire File ........... 9895.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUmmARY VENDOR TOOL CODE START DEPTH GR 9870.5 ROP 9896.0 $ 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: STOP DEPTH 9998.5 10025.5 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 (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: 30-DEC-97 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 10026.0 9898.0 10026.0 86.1 91.0 TOOL NUMBER NGP SPC 242 4.130 4.1 FLO- PRO 9.60 .0 9.3 8.5 .000 .000 .000 .000 60.9 .3 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 13 AAPI 4 1 68 4 2 ROP MWD 13 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9870.5 10025.5 9948 311 9870.5 GR 26.94 48.56 33.1742 257 9870.5 ROP 30.94 2235.53 188.844 260 9896 Last Reading 10025.5 9998.5 10025.5 First Reading For Entire File .......... 9870.5 Last Reading For Entire File ........... 10025.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FI LE SUMI~aARY VENDOR TOOL CODE START DEPTH GR 9999.0 ROP 10026.0 LOG HEADER DATA DATE LOGGED: S O FTWARE 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 10700.5 10728.0 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 (OH_M~)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL I~LATRIX: ]¢~TRIX 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 01-JAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 10728.0 10026.0 10728.0 85.6 95.4 TOOL NUMBER NGP SPC 242 3.750 3.8 FLO- PRO 9.60 .0 9.0 6.4 .000 .000 .000 .000 68.0 .3 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 14 AAPI 4 1 68 4 2 ROP ~4D 14 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9999 10728 10363.5 1459 9999 GR 24.67 94.82 36.6457 1404 9999 ROP 7.75 2330.56 97.7241 1405 10026 Last Reading 10728 10700.5 10728 First Reading For Entire File .......... 9999 Last Reading For Entire File ........... 10728 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 15 DEPTH INCREMENT: .5000 FILE SUI~ARY VENDOR TOOL CODE GR ROP $ START DEPTH STOP DEPTH 10701.0 10880.5 10728.5 10907.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL {FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO 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 (OH]VIM) 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 lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacin9 ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 02-JAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 10908.0 10728.0 10908.0 91.2 94.6 TOOL NUMBER NGP SPC 242 3.750 3.8 FLO-PRO 9.50 .0 9.5 5.4 .000 .000 .000 .000 68.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 15 AAPI 4 1 68 ROP MWD 15 FT/H 4 1 68 Name Min Max Mean Nsam DEPT 10701 10907.5 10804.2 414 GR 28.82 101.96 50.272 360 ROP 17.22 522.87 53.0091 359 First Reading 10701 10701 10728.5 Last Reading 10907.5 10880.5 10907.5 First Reading For Entire File .......... 10701 Last Reading For Entire File ........... 10907.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 16 DEPTH INCREMENT: .5000 FILE SUI~WARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10881.0 11068.0 ROP 10908.0 11095.5 $ LOG HEADER DATA DATE LOGGED: 03-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: NGP 5.74, DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11095.0 DEP 2.042 TOP LOG INTERVAL (FT) : BOTTOM LOG iNTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM _~GLE: IcLAY~II~JM .~d~GLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL G~ PROBE $ BOREHOLE ~D CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 10908.0 11095.0 86.8 92.1 TOOL NUMBER NGP SPC 164 3.750 3.8 FLO- PRO 9.50 .0 9.0 10100 5.0 .000 .000 .000 .000 70.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 16 AAPI 4 1 68 4 2 ROP MWD 16 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam DEPT 10881 11095.5 10988.2 430 GR 28.16 278.5 59.7571 375 ROP 27.53 1710.14 77.9493 376 Reading Reading 10881 11095.5 10881 11068 10908 11095.5 First Reading For Entire File .......... 10881 Last Reading For Entire File ........... 11095.5 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 17 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11068.5 11306.5 ROP 11096.0 11337.5 $ LOG HEADER DATA DATE LOGGED: 03-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (M~ORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 85.1 MAXIMUM ANGLE: 92.1 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 11337.0 11095.0 11337.0 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 (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 TOOL NUMBER NGP SPC 164 3.750 3.8 FLO-PRO 9.60 .0 8.9 13200 5.9 .000 .000 .000 .000 70.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 17 AAPI 4 1 68 4 2 ROP MWD 17 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11068.5 11337.5 11203 539 11068.5 GR 28.29 1293.66 50.0265 477 11068.5 ROP 35 1002.87 87.1498 484 11096 Last Reading 11337.5 11306.5 11337.5 First Reading For Entire File .......... 11068.5 Last Reading For Entire File ........... 11337.5 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 18 DEPTH INCREMENT: .5000 FILE SUMP[ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11313.0 11550.0 ROP 11342.0 11581.0 $ LOG HEADER DATA DATE LOGGED: 04-JAN-98 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: 85.4 IW3AXIMUM ANGLE: 90.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 11581.0 11337.0 11581.0 TOOL NUMBER NGP SPC 242 3.750 DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 3.8 FLO-PRO 9.60 .0 9.0 5.7 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 18 FT/H 4 1 68 4 2 GR MWD 18 AAPI 4 1 68 8 3 75.0 First Name Min Max Mean Nsam Reading DEPT 11313 11581 11447 537 11313 ROP 32.84 2232 126.542 479 11342 GR 29.69 123.77 44.0799 475 11313 Last Reading 11581 11581 11550 First Reading For Entire File .......... 11313 Last Reading For Entire File ........... 11581 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF File Header Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.012 Comment Record FILE HEADER FILE NUMBER: 13 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 19 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11551.0 11625.5 ROP 11581.5 11651.0 $ LOG HEADER DATA DATE LOGGED: 04-JAN-98 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: 90.8 MAXIMUM ANGLE: 100.2 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 NUJD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 11651.0 11581.0 11651.0 TOOL NUMBER NGP SPC 258 3.750 3.8 FLO-PRO 9.60 .0 8.8 NfJD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MJ~X 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 5.6 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR ]~WD 19 AAPI 4 1 68 4 2 ROP MWD 19 FT/H 4 1 68 8 3 75.0 First Name Min Max Mean Nsam Reading DEPT 11551 11651 11601 201 11551 GR 23.66 37.11 30.7649 150 11551 ROP 56.39 555.8 172.115 140 11581.5 Last Reading 11651 11625.5 11651 First Reading For Entire File .......... 11551 Last Reading For Entire File ........... 11651 File Trailer Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.014 Physical EOF File Header Service name ............. STSLIB.014 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record,.65535 File Type ................ LO Previous File Name ....... STSLIB.013 Comment Record FILE HEADER FILE NUMBER: 14 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 20 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE STAJ~T DEPTH GR 11626.0 ROP 11651.5 $ 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 11797.0 11822.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAF94A PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 05-JAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 11823.0 11651.0 11823.0 100.8 109.4 TOOL NUMBER NGP SPC 258 3.750 3.8 FLO-PRO .00 .0 8.8 5.6 .000 .000 .000 .000 75.0 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 ,3 Name Service Order Units Size Nsam Rep.Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 20 AAPI 4 1 68 4 2 ROP MWD 20 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11626 11822,5 11724,2 394 11626 GR 24,03 173,98 69,3047 343 11626 ROP 21,78 1333,04 98,0157 343 11651,5 Last Reading 11822.5 11797 11822.5 First Reading For Entire File .......... 11626 Last Reading For Entire File ........... 11822.5 File Trailer Service name ............. STSLIB,014 Service Sub Level Name,,, Version Number ........... 1,0,0 Date of Generation ....... 98/02/11 Maximum Physical Record,,65535 File Type ................ LO Next File Name ........... STSLIB,015 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/02/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/02/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File