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Home My WebLink About193-200.. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. !<~,.~ -,:::~00File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: scanned by: Beverly~Vincent TO RE-SCAN Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si STATE OF ALASKA~~ ALAS•IL AND GAS CONSERVATION CON~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~~~~ ~~;~ 3 0 200? ~1A~itr~ ~i1 Gres Cons. Co~-issior~ 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAAC zs.los 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 8/30/2007 12. Permit to Drill Number 193-200 307-261 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 01/08/1994 13. API Number 50-029-20318-02-00 4a. Location of Well (Governmental Section): Surface: ' ' T 7. Date T.D. Reached 01/14/1994 14. Well Name and Number: PBU 14-02B 1262 FNL, 1228 FEL, SEC. 09, 10N, R14E, UM Top of Productive Horizon: 4073' FSL, 1606' FEL, SEC. 04, T10N, R14E, UM 8. KB (ft above MSL): 73' Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4680' FSL, 1557' FEL, SEC. 04, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 11576 9012 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 675245 y- 5939078 Zone- ASP4 10. Total Depth (MD+TVD) 11755 9129 16. Property Designation: ADL 028312 TPI: x- 674731 y- 5944404 Zone- ASP4 Total Depth: x- 674764 y- 5945012 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and rinted 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): CHT, GR, CNL, DLL, AC 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD'' SETTING DEPTH 1V0 HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP DOTrOM SIZE CEMENTING RECORD PULLED 20" 94# H-4 Surface 120' Surface 120' 30" 675 sx Arcticset II 13-3/8" 72# N-80 Surface 2732' Surface 2732' 17-1/2" 5904 sx Permafrost II 9-5/8" 47# N-80/RS-951E-80 Surface 9366' Surface 9366' 12-1/4" 1000 sx Class 'G' 692 sx Class'G' 7" 29# NT-80Sl13Cr80 8072' 11615' 7549' 9037' -1/2" 445 sx Class 'G' 23. Open to production or inject ion? ^ Yes ®No 24. TuelNC RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD None 4-1/2", 12.6#, 13Cr80 7000' - 11435' 10594' & 11385' MD TVD MD TVD ~~ NU 9' ~ ~•Z~Q7 L 25, ACID, FRACTURE, CEMENT SQUEEZE, ETC. t1 DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 10064' P&A with 40 Bbls Class 'G' 4479' Set EZSV with Whipstock on top 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUTS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac wired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results p r, 7. None ~~ ~. ~ ~~~_ Iv~i~ ~ ~ 2D07 Form 10-407 Revised 02/2007("'"~ ~ ~ ~ ~ ~ ~ ~ CONTINUED ON REVERSE SIDE ~.~r.-.~ / 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS A KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD 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. Sag River 10838' 8576' None Shublik 10904' 8612' Top Sadlerochit 10982' 8655' Formation at Total Depth (Name): 30. List of Attachments: Pre-Rig Work and Summary of Daily Drilling Reports, Well Schematic Diagram. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondr tewman Title Drilling Technologist Date ~ ~ " ~ (~ - (~ PBU 14-026 193-200 307-261 Prepared ByName/Number. Sondra Stewman, 564-4750 Well Number Drilling Engineer: Ron Phillips, 564-5913 Permit No. / A royal No. (INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the wrresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only Digital Well File . ~ Page 1 of Well: 14-02 Well History Well Date Summary 14-026 8/21/2007 "* WELL S/I ON ARRIVAL *** RUN 3.84" NOGO CENT TO 2205' SLM, ADD PRONG (101" FROM NOGG TO FLAPPER CHECKER), SD @ SAME (2205'), FLAPPER OPEN *** CONTINUED ON 8/22/07 WSR *** 14-026 8/22/2007 *** CONTINUED FROM 8/21/07 WSR *"* (pre-gyro) DRIFT W/ 3.25" CENT TO TOP OF PRONG @ 11416' SLM, NO OTHER RESTRICTIONS *** WELL LEFT S/I ON DEPARTURE *** 14-026 8/24/2007 T/I/0= 360/640/120. Temp= SI. T & IA FL (Pre-MIT). TBG FL @540' (9 bbls). IA FL @ 1122' (60 bbls). 14-02B 8/25/2007 Tll/0= 700!500/60 Assist E-line with SSSV. Pumped 9 bbls 80*f crude to open SSSV Final WHPs 2500/500/60 14-02B 8/25/2007 **** GYRO SURVEY ON 14-02B ***** WELL SHUT IN ON ARRIVAL. T/I/O 200/5001150. GYRODATA SURVEY PERFORMED FROM SURFACE TO 11399 FT. PUMPED 60 BBL DIESEL TO EQUALIZE AND 4000 PSI MIN TO OPEN FLAPPER SSSV **** JOB COMPLETED **** WELL SHUT IN. 14-02B 8/25/2007 **** GYRO SURVEY ON 14-026 ***** WELL SHUT IN ON ARRIVAL. T/I/O 200/500/150. GYRODATA SURVEY PERFORMED FROM SURFACE TO 11,399 FT. PUMPED 60 BBL DIESEL TO EQUALIZE AND 4000 PSI MIN TO OPEN FLAPPER SSSV WELL LEFT SHUT IN. ***JOB COMPLETE*** 14-026 8/25/2007 **** GYRO SURVEY ON 14-02B ***** WELL SHUT IN ON ARRIVAL. T/I/O 200/500/150. GYRODATA SURVEY PERFORMED FROM SURFACE TO 11902 FT. PUMPED 60 BBL DIESEL TO EQUALIZE AND 4000 PSI MIN TO OPEN FLAPPER SSSV **** JOB COMPLETED **** WELL SHUT IN. 14-02B 8/25/2007 ***WELL S/I ON ARRIVAL*** UNABLE TO DO JOB DUE TO OTHER WORK BEING DONE ON LOCATION. ****JOB WAS CANCELED, WILL COME BACK AT LATER DATE**** 14-02B 8/27/2007 T/1/0=750/5001140pen SSSV for S-Line (Rig ST Prep) Pumped 4.8 bbls 60/40 down TBG before pressuring to 3500psi. ***SSSV did not open*** FWHP=400/500/140 14-02B 8/27/2007 T/I/O = 1500/500/240 Assist Slickline w/ locking out SSSV. Pumped 1.8 bbls crude. FWHP's =950/500/100. Annulus valves left open to gauges, stickline still on well upon LRS departure 14-02B 8/27/2007 *"*WELL S/1 ON ARRIVAL*** (lock out trsv, pull ttp) RAN 3.84 CENT ,TAGGED NO GO @ 2204' SLM .RAN 3.84 CENT & 55" FLAPPER CHECKER TO TRSV ,VALVE APPEARS TO BE FUNCTIONING. MADE 2 RUNS W/ 4 1/2" TRDP-4A (HYD) LOCK OUT TOOL TO LOCK OUT 4 1 /2" TRDP-4A TRSSV @ 2206' SLM RAN FLAPPER CHECKER TO 2204' SLM W/ O-PSI ON CONTROL LINE FLAPPER APPEARS TO BE LOCKED IN THE OP_ FN POSITION ***CONTINUED ON 8-28-07*** 14-026 8/28/2007 *** JOB CONTINUED FROM 08-27-07 WSR *** (pull ttp / drift tbg) P - D P-PROM (a7 114 6' M . P 1LLED 4 1/2" PXN PLUG BODY Ca) 11431' SLM DRIFTED TBG W/2.70" CENT,TEL,S.B., TAGGED TD ~ 11,580' CORR ELMD , NO SAMPLE. ***WELL LEFT S/I ON DEPARTURE*** 14-02B 8/29/2007 CTU #8, P&A Perfs; MIRU unit. MU and RIH with 2.0" OD BDN. Tag btm at 11552' ctmd and correct depth to elmd. Fluid pack well with 290 bbls of 1 % KCL and underballance well with 135 bbls of diesel. RU cementers pump truck.... Cont' on WSR 08/30/07 ... 14-026 8/29/2007 CTU# 8 Plug & abandon perfs """""' JOBN IN PROGRESS """"'"' 14-026 8/30/2007 CTU #8, P&A Perfs; ... Cont' from WSR 08/29/07 ... PUmD 40 bbls of 15.8 pqQ class G cement. Park nozzle above perfs at 11470' elmd (corrected from SL tag) and downs ueeze 5 bbls of cement into 7". Open choke and lay in 35 bbls of cement 1:1 to 9200'. PUH to safety an squeeze s o semen m o http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 10/26/200 Digital Well File ~ ~ Page 2 of perfs. WHP climbed from 100 psi to 500 psi. Estimate TOC at appox 9550' elmd. POOH pumping to maintain voidage. Flush surface lines and blow down reel with N2. *** Job Complete *** 14-026 9/1/2007 ***WELL S/I ON ARRIVAL*** (post p&a /pre sdtrk) TD 10064' SLM, 114' BELOW ESTIMATED TOP OF CEMENT ~~ Ta~a~r(~rmts-~ar~sarrs~r~ovv-~'~s~r- **WELL S/I PARTURE*** (NOTIFIED DS 14-02B 9/1/2007 *** WELL FLOWING ON ARRIVAL*** INITIAL T/I/O = 700/450/200 CUT 4.5" TUBING AT 7,000' WITH 3.65" POWER JETCUTTER. _ _ HUT-IN. FINAL T/l/0 = 100/450/200. *** JOB COMPLETED *** 14-026 9/2/2007 T/I/0=400/400/180 Circ Out, CMIT-TxIA PASSED to 3500 psi, MIT OA PASSED to 2000 psi (Pre RWO) Pumped 7.5 bbls meth, 725 bbls 1 % KCL and 160 bbls 80* DSL down TBG, up IA & down FL. U-Tubed DSL to F.P. Tbg & IA. Freeze protected flowline w.10 bbls neat meth, 25 bbls crude & 30 bbls heated DSL. CMIT Tx_ IA to~3000~si...Pressured up T/I w/ 6.1 bbls DSL. T/I lost 50/20 psi in 15 min and 20/0 psi in 2nd 15 min for a~ pressure loss of 70/20 over 30 min. bled TBG & IAP down Flowline. MIT OA to 2000 psi....Pressured up OA w/ 0.8 bbls diesel. OA lost 20 psi 15 min and 20 psi in second 15 min for a total pressure loss of 40 psi over 30 min. Bled OAP. FWHP's=0+/0+/0+ -- OA,IA, Master & SSV left open Wing, Swab & Grove S/I. Needle valves left open to guages & MIT/Load information tags hung--- 14-02B 9/3/2007 Set 5" Gray Model "K" (Pre Nabors 2ES RWO) Print Date: 10/26/2007 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 10/26/200 BP EXPLORATION Page 1 of 32 Opelrations Summalry' Repolrt Legal Well Name: 14-02 ~ `~ ~~ ""~~ ~ W C ll N 1 ~ ommon e ame: 4-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations .9/7/2007 20:00 - 22:00 2.00 MOB P PRE Move sub from East side of pad to 14-02C. Stage sub by well. 22:00 - 00:00 2.00 MOB N WAIT PRE Waiting on trucks held up by rig moves. 9/8/2007 00:00 - 02:00 2.00 MOB N WAIT PRE Waiting on trucks to finish rig move from East side of pad to 14-02C. 02:00 - 11:00 9.00 RIGU P PRE Move rig camp and pits to west side of pad. Spot and set up camp. Stage pits for sub placement. Line up sub on well 14-02. Lay down herculite. Spot sub over well. Spot pits, light duty shop and welding shop. Berm cuttings tank. Hold Pre-Spud meeting. Rig accept at 1100 hours. 11:00 - 13:30 2.50 WHSUR P DECOMP PJSM. Rig up secondary annulus valve. Rig up for OA test. 13:30 - 14:30 1.00 WHSUR P DECOMP PJSM. Test 13-3/8" x 9-5/8" annulus to 2000 psi for 30 minutes. Test OK. Install XO. Change out gripper blocks, saver sub and stabbing guide to 5". 14:30 - 15:30 1.00 WHSUR P DECOMP PJSM. Test DSM lubricator to 500 psi. Test OK. Pull BPV. 15:30 - 18:30 3.00 WHSUR P DECOMP PJSM. Rig up~circulating lines in cellar and reverse circulate 130 bbls diesel freeze protect from tubing. Switch lines in cellar and circulate 170 bbls diesel freeze protect the long way. Shut down and blow down. Remove circulating head. 18:30 - 21:00 2.50 WHSUR P DECOMP PJSM. Install K-plug, BPV with DSM. Run in dart with Cameron to make TWC. Test from below to 1000 psi for 30 minutes and above to 1000 si for 5 minutes, tests OK. Rig down lines and suck out tree. Bleed all voids. Grease choke manifold. 21:00 - 22:00 1.00 WHSUR P DECOMP PJSM. ND tree and adapter flange. Remove from cellar. Screw XO in hanger, 17-1/2 turns to the right. Threads look good. Check all lock down screws. Remove hooks from BOP crane and hook up to BOP stack. 22:00 - 00:00 2.00 BOPSU P DECOMP PJSM. Pick up stack. Attempt to move onto well, no go. Set back on cradle. Adjust chains. Set stack on well head. 9/9/2007 00:00 - 01:00 1.00 BOPSU P DECOMP PJSM. Finish stabbing BOP stack on wellhead and rigging up. 01:00 - 04:00 3.00 BOPSU P DECOMP PJSM. Nipple up BOP stack and equipment. 04:00 - 11:00 7.00 BOPSU P DECOMP Test BOPE to 250 psi low, 3500 psi high. Test Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Chuck Sheve with AOGCC. Test witnessed by WSL Mitch Skinner and Bill Decker, TP John Castle and Ronnie Dalton. 11:00 - 14:30 3.50 DHB P DECOMP PJSM. Pull dart from BPV. Ri u DSM lubricator. Pull BPV. Break and LD DSM lubricator and extention. Pick up and MU lower top drive hydraulic IBOP. Install clamp hook up lines and saver sub. Bring up casing equipment and control line spooler. Make up landing joint and LD in pipe shed. 14:30 - 17:00 2.50 PULL N SFAL DECOMP Remove and re-install lower IBOP hydraulic valve. 17:00 - 18:00 1.00 PULL P DECOMP PJSM. Bring up landing joint. Jay into hanger with 17-1/2 turns to the right. MU top drive. BOLDS. Unseat hanger with 125k. String weight of 80k after pulling free. Pull hanger to floor. Break out and lay down. Rig up XO, TIW and circulating head. 18:00 - 20:00 2.00 PULL P DECOMP PJSM. Circulate surface to surface at 110 gpm with 200 psi. Clear and clean floor. Pump slug. Rig down. 20:00 - 23:30 3.50 PULL P DECOMP PJSMrPull and LD 4-1/2" tubing to SSSV. Rig down and LD control line spooler. Recovered 53 full joints, 1 pup at 5.70, 28 SS bands and 1 SSSV. 23:30 - 00:00 0.50 PULL P DECOMP Pull 4-1/2" tubing. 9/10/2007 00:00 - 01:30 1.50 PULL P DECOMP PJSM. Pull 4-1/2" tubing to 2974'. ', 01:30 - 02:00 0.50 PULL N SFAL DECOMP Skate control panel blew fuse. Replace fuse. Panel had loose Printed: 10!25/2007 1:23:48 PM • • BP EXPLORATION Page 2 of 32 Operations Summary Report , Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 9/10/2007 01:30 - 02:00 0.50 PULL N SFAL DECOMP lock nut. 02:00 - 02:30 0.50 PULL P DECOMP PJSM. Service rig, lubricate top drive. 02:30 - 05:30 3.00 PULL P DECOMP POOH with remaining tubing. Recovered 176 full joints, 1 pup joint at 5.70', 1 SSSV, 2 GLM, 1 cut joint at 5.56' and 28 SS bands. 05:30 - 06:30 1.00 PULL P DECOMP PJSM. Rig down casing equipment and clean floor. 06:30 - 08:00 1.50 BOPSU P DECOMP PJSM. Rig up and test bottom rams and lower IBOP. Test to ~25 psi ow, 0 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Bill Decker and TP Ronnie Dalton. 08:00 - 09:00 1.00 CLEAN P DECOMP PJSM. Pick BHA up beaverslide. 09:00 - 11:00 2.00 CLEAN P DECOMP PJSM. Make up 9-5/8" casing scraper BHA to 310'. 11:00 - 12:00 1.00 CLEAN P DECOMP PJSM. Pick up and RIH with 5" DP to 1161'. 12:00 - 12:30 0.50 CLEAN P DECOMP PJSM. Adjust brakes and inspect draworks. 12:30 - 16:00 3.50 CLEAN P DECOMP PJSM. Pick up remaining 5" DP and RIH to 5496'. Fill pipe at 90 joints. PU a total of 165 joints. 16:00 - 18:00 2.00 CLEAN P DECOMP PJSM. Make up top drive and establish circulation at 600 gpm with 940 psi. Pump sweep surface to surface. Up weight 145k, down 125k, RT 135k. Pump slug. 18:00 - 19:30 1.50 CLEAN P DECOMP PJSM. POOH to 310'. 19:30 - 20:30 1.00 CLEAN P DECOMP PJSM. Rack back collars. Break and fay down scrapers. Empty boot baskets and lay down. 20:30 - 21:30 1.00 EVAL N WAIT DECOMP Waiting on SWS E-line unit. USIT flown in from Kenai. 21:30 - 22:30 1.00 EVAL P DECOMP PJSM with SWS. Spot E-line unit. PU and rig up E-line unit. 22:30 - 00:00 1.50 EVAL P DECOMP RIH with SWS. Run USIT/CCL/GR in cement and corrosion mode. 9/11/2007 00:00 - 07:00 7.00 EVAL P DECOMP Run USIT/CCL/GR in cement and corrosion mode in 9-5/8" casin .Evaluating logs. 07:00 - 09:00 2.00 DHB P DECOMP ~ PJSM, Arm firing head & P/U EZSV 09:00 - 11:00 2.00 DHB P DECOMP RIH w/EZSV set Ca) 4490' L/D Running Tool 11:00 - 11:30 0.50 DHB P DECOMP PJSM, Test EZSV to 1500 psi for 15 min. Good Test 11:30 - 12:00 0.50 DHB P DECOMP Test and Load String Shot 12:00 - 16:00 4.00 CASE P DECOMP PJSM w/SWS Bring Shooting Head to Floor and String shot sleeve - M/U & RIH to 2244' and Fire String Shot - POH Rig Down wireline - Suck out stack - Install plug and close blinds 16:00 - 18:00 2.00 BOPSU P DECOMP PJSM - Close top rams on 9 5/8" Test Jt - Test to 250 Low and 3500 high as per AOGCC -Test Witness waived by Lou Grimaldi AOGCC State Rep. 18:00 - 19:00 1.00 FISH P DECOMP PJSM/ Bring Cutter BHA to Rig Floor M/U on single - L/D Single in Shed, Adjust bail links for elevators 19:00 - 21:00 2.00 FISH P DECOMP PJSM RIH to 2185' - RIH into hole slow as per Baker Service Rep. - Install blower hose - P/U stand, M/U Top Drive, Establish Circulation - Locate Collars @ 2199' and 2237' - P/U 20' @ 221 T - Up wt 73K and DN wt 73K 21:00 - 22:00 1.00 FISH P DECOMP Establish Milling Parameters - 15 RPMS / 3500 ft.rbs. torque Printed: 10!2512007 1:23:48 PM i ~ BP EXPLORATION Page 3 of 32 Operations Summary'Report Legal Well Name: 14-02 Common Well Name: 14-02 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES Date ~ From - To Hours ~ Task (Code ~ NPT Spud Date: Start: 8/23/2007 End: Rig Release: 10/23/2007 Rig Number: 2ES Phase I Description of Operations 9/11/2007 121:00 - 22:00 I 1.001 FISH I P 22:00 - 00:00 I 2.001 CASE I P 9/12/2007 100:00 - 01:30 I 1.501 FISH I P 01:30 - 03:30 I 2.001 FISH I P 03:30 - 06:00 I 2.501 WHSUR I P 06:00 - 06:30 I 0.501 FISH I P 06:30 - 09:00 I 2.501 FISH I P 09:00 - 12:00 3.001 FISH P 12:00 - 18:30 6.50 FISH P DECOMP -Bring pump on @ 90 GPM, 200 psi - Free TO @ 3500 - Begin torque and bring up pump to 239 GPM, 865 psi, RPMS 50 - Cut 9 5/8" torque with cutting 5-15K stall top drive - Back off pump P/U establish RT -Bring up pump and restart cut, PSI drop of 600 psi and torque drop to 1500 - Verify cut ,Well began flowing - ut own an pump - P/U tool jt., monitor well, shut in as per co. rep. - Let PSI stabilize, SHCP = 10 psi, SIDPP = 30 psi DECOMP Displaced to Heated Sea Water ciculating through poor boy degasser conducting well kill drill at the same time - Establish Kill plan and established circulation to choke and degasser @ 119 GPM 360 psi, Pumped full circulation and shut down and monitored well -well is static DECOMP Attempted to Establish Circulation -Pumped to 30 strokes, 2.6 bbls, to 1500 psi, Held 15 min., bled off -Pumped to 30 strokes, 2.6 bbls, to 1500 psi, Held 15 min., bled off -Pumped to 30 strokes, 2.6 bbls, to 1500 psi, Held 5 min., bled off - Unable to establish circulati_onbtwn 13 3/8" and 9 5/8" annulus DECOMP POH - L/D BHA DECOMP Attempt to pull 9 5/8" Upper and Lower Pack off - Pulled up to 15K and would not pull, Dogs popped out -Attempted three times without success DECOMP PJSM L/D Pack Off Retrieving Tool and P/U 9 5/8" Casing tools - M/U floor valve to cross over DECOMP PJSM M/U Spear & spear into 9 5/8" casing - Pull 9 5/8" to Floor, pulled free @ 205K - Unable to circulate - L/D Spear, Hanger, and pup Jt - R/U XO, TIW & screw into top drive - Attempted to break circulation, pressure up to 1500 psi and worked pipe - Bled off pressure and worked pipe - While working pipe gas migrated up through arctic pac. Arctic Pac burped onto floor. Closed annular immediately; no further as mi ration. - Pressure up to 1000 psi and worked pipe OECOMP Clean Arctic Pac off floor & Derrick. DECOMP PJSM -Pressure test Little Red Hot Oil to 3000 psi, Good Test - Reverse. circ. 180 deg. diesel down O/A - 1/2 BPM to 750 psi taking returns to pits Printed: 10/25/2007 1:23:48 PM • • BP EXPLORATION Page 4 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date I From - To I Hours I Task I Code I NPT Phase I Description of Operations 9/12/2007 12:00 - 18:30 6.50 FISH P DECOMP -Bring rates up to 1 bpm 1200 psi - Spot 127 bbfs diesel taking returns to cutting tank - Shut in to let soak 18:30 - 21:00 2.50 FISH P DECOMP Displace Arctic Pack -Open up and pump the long way with 110 deg heated seawater - ICP 240 GPM @ 750 psi, FCP 265 psi - pumped a total of 258 bbls - bled off, left open to stabilize - Pump slug @ 210 gpm & 220 psi bleed off 21:00 - 23:00 2.00 FISH P DECOMP - B{ow Down hoses, R!D cel{ar and blow out lines to cuttings tank -Clear floor of unnecessary equip. - Prepare floor to L/D 9 5/8" casing 23:00 - 00:00 1.00 FISH N RREP DECOMP Rlg Repair -While lowering Top Drive down to break off crossover to 9 5/8" the manrider line hung on Top Drive and broke Kelly Hose _..., _.. ,.... Clamp - Secured scene and inspected visually -Inspected manrider line, Top Drive, and Kelly Hose for damage -All equipment remained intact, no objects dropped 9/13/2007 00:00 - 11:00 11.00 FISH N RREP DECOMP PJSM on Repairing Top Drive - Complete Derrick Inspection - Remove flow tube and upper IBOP and repair actuator valve - Remove Flow tube clamp and repair -Install IBOP and Flow tube -Secure secondary restraints - Change out Off Driller side Manrider Cable - Pressure test Surface Equipment 11:00 - 23:30 12.50 CASE P DECOMP La down 9 5/8" 47# BTC Casin -Connection extremely tight, Rigged up double line on rig tongs to breakout connections, 80-90% of connections galled and damaged - 54 total joints recovered - 9 Bow Spring centralizers recovered - 1 cut joint @ 18.35 feet 23:30 - 00:00 0.50 CASE P DECOMP Rig Down handling equipment - Clear floor of excess equipment - Clean Up Arctic pac around rotary table work area 9/14/2007 00:00 - 03:00 3.00 FISH P DECOMP P/U and Make up BHA -Washpipe shoe , 1Jt. Washpipe, W.O. Boot Basket, Double pin sub, Scraper, Bit sub, Float sub, Lub Bumper sub, Oil jar, 9 Drill collars, Pump out sub 03:00 - 07:00 4.00 FISH P DECOMP R1H to 1325' - @ 852' pumped 25 bbls of hot diesel chased with 75 bbls of hot sea water -Continue to stage in hole and pump diesel to clean up arctic pac - @1325' pumped 25 bbls of hot diesel chased with 75 bbls of hot sea water -Continue to stage in hole and pump diesel to clean up arctic pac Printed: 10/25/2007 1:23:48 PM • • BP EXPLORATION Page 5 of 32 - Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 ,Rig Name: NABORS 2ES Rig Number: 2ES Date From - To ~ Hours ~ Task ~ Code ( NPT ~ Phase Description of Operations 9/14/2007 103:00 - 07:00 I 4.001 FISH I P 07:00 - 07:30 ~ 0.501 FISH ~ P 07:30 - 10:30 I 3.001 FISH I P 10:30 - 14:00 I 3.501 FISH I P 14:00 - 15:00 1.00 FISH P 15:00 - 16:30 1.50 FISH P 16:30 - 18:00 1 1.50 FISH P 18:00 - 20:00 2.00 CASE P 20:00 - 21:30 1.50 CASE P 21:30 - 00:00 2.50 CASE P 9/15/2007 00:00 - 01:00 1.00 FISH P 01:00 - 01:30 0.50 FISH P 01:30 - 02:30 1.00 FISH P 02:30 - 03:00 0.50 FISH P 03:00 - 04:00 l 1.00) FISH ~ P 04:00 - 05:00 I 1.00 FISH P 05:00 - 07:30 ( 2.50 CASE P 07:30 - 14:00 6.50 CASE P DECOMP - @1797' pumped 25 bbls of hot diesel chased with 75 bbls of hot sea water -Continue in to 2174' DECOMP Wash down from 2174' to 2247' -45 rpms / 1k ft/Ibs 252 gpm / 120 psi - PUW 90k /SOW 85k / RtWt 88k Wash over stump without problems DECOMP Circ bottoms up through Poor Boy Degasser -ICP @ 92 gpm = 90 psi / FCP @ 92 gpm = 55 psi -Monitor well, Static -Break circ. with 25 bbls of seawater followed with 25 bbls of diesel, -Displace well to 9.8 ppg brine -Monitor well, static 9.8 ppg brine in/out DECOMP POH to BHA DECOMP L/D Wash Pipe and 13 3/8" Casing Scraper BHA DECOMP M/U Back-off BHA -Bull Nose, 9 x SDC's, XO, Blank sub, Lower Anchor, Power Section, Upper Anchor, XO, POS DECOMP RIH filling pipe with fresh water DECOMP PJSM, Rig Up pump in sub and test pump lines -Set Bottom Anchor @ 2256' -Set Top Anchor @ 2229' -Back off casing @ 3600 psi Cycle Back-off 12x for a total of 6 1 /4 turns Release Anchors and Rig Down Surface equipment DECOMP POH to BHA -Monitor well, static 9.8 ppg brine in/out DECOMP L/D Back off BHA DECOMP M/U 9 5/8 Cut Joint spear assembly -Bull Nose, 9 5/8 spear, Spear Extension, Stop Sub, Bumper Sub DECOMP Pre-Job safety meeting with crew coming back from days off -Unable to have Pre Tour meeting due to late arrival of flight DECOMP RIH DECOMP Latch on to Cut Stub -Rackoff 6 turns, and pull on stub, stub pulled free without resistance -monitor well, static 9.8 ppg in/out DECOMP POH DECOMP L/D Spear BHA and Cut Joint stub (18.80') -Threads are good shape, Screw collar on to verify condition -Clear & Clean Rig Floor DECOMP R/U to run 9 518" casing -PJSM with All Personnel DECOMP Run 9 5/8" Tie-Bac Str' -Baker Screw in sub with Overshot guide -HES BafFle Collar and pup jt, -HES ES Cementer -54 joints of 47# L-80 Hydrill 563 -2 Space out Pup Jts. -26 Bow spring centralizers -Jet Lube seal guard joint compound Printed: 10/25/2007 1:23:48 PM • • BP EXPLORATION Page 6 of 32 -Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date I From - To I Hours ~ Task I Code NPT I Phase I Description of Operations 9/15/2007 104.00 - 15:00 I 1.00 I CASE ~ P 15:00 - 17:00 I 2.001 CEMT I P 18:30 - 22:00 3.50 BOPSUR P 22:00 - 00:00 2.00 BOPSU P 9/16/2007 00:00 - 02:30 2.50 BOPSU P 02:30 - 04:00 1.50 BOPSU P 04:00 - 09:30 5.50 BOPSU P 09:30 - 13:30 I 2.00 BOPSU~P DECOMP -18,000 ft /Ibs of make up torque -PUW 125k / SOW 80K DECOMP Make Top Drive and screw in to casing -12 turns, 10,000 ft/Ibs of torque -Pull 250K on casing -good -While pressuring up to 2000 psi, ES Cementer shifted open @ 1250 psi -Drop Bomb to confirm cementer is in the open position DEGOMP Hold PJSM & RU Cement head and Cementers, CBU, Pump 5 bbl water, test cement lines to 4000 psi, Pump 15 bbls.10.5 ppg. MudPush, Pump 143 bbls Class G Tail Cement @ 15.8 ppg, Drop plug and kick out with 5 bbls water, Displace cement @ 8 bpm, Slow pumps to 2 BPM 10 bbls prior to bumping plug, Bump Plug on strokes to 2000 psi ,close ES Cementer, Bleed off and check for flowback, Float Holding -15 barrels of cement back to surface -CIP @ 17:00 hrs DECOMP Flush Stack And Rig Down Cementing equipment DECOMP Nipple Down BOP's -Set Slips w/ 100K -Cut 9 5/8 casing with Wachs cutter -set BOP's back on stump -Remove Tubing pool DECOMP Install Lower Packoff, Nipple up New Tubing Spool -N/U BOP's DECOMP Finish Nippling up Tubing Spool And BOP Stack -Test 9 5/8" Packoffs to 3800 psi for 30 min DECOMP Change Top Set of Rams to 3 x 6 Variable DECOMP R/U and Test BOP's PJSM, Continue to Test BOPE, 250 low, 3500 psi high, holding each test for 5 min. 5" Test Joint -Test #1 -Blind Rams, HCR Kill & Choke, -Test #2 -choke manifold valves 1, 2 & 3,14,16 and Kill Manual Valve -Test #3 -choke manifold valves 4, 5, 6 -Test #4 -choke manifold valves 7, 8, 9 -Test #5 -choke manifold valves 10, 11 -Test #6 -choke manifold valves 12, 13, -Test #7 - choke manifold valve 15 -Test #8 -hydraulic choke & manual choke Unable to Get Test Plug to hold pressure SFAL DECOMP Chan eout Test Plu DECOMP Complete BOP Test -Test #9 -Lower Pipe Rams -Test #10 -Annular 250 Low / 2500 High -Test #12 -Top Rams, Inside Mud Cross, lower TIW Valve -Test #13 -Lower Rams, IBOP Perform accumulator Test -3000 psi, bleed down to 1600 psi 200 psi recovery 27 secs Printed: 10/25/2007 1:23:48 PM • • BP EXPLORATION Page.? of 32 Opelrations Sumlrnary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date ~ From - To ~ Hours Task I Code NPT ~ Phase Description of Operations 19/16/2007 111:30 - 13:30 I 2.001 BOPSUR P 13:30 - 14:00 0.50 BOPSUf~P 14:00 - 15:30 1.50 CLEAN P 15:30 - 17:30 I 2.00 I CLEAN I P 17:30 - 19:30 2.00 CLEAN P 19:30 - 20:00 0.50 CLEAN P 20:00 - 21:00 1.00 CLEAN P 21:00 - 21:30 I 0.501 CLEAN ~ P 21:30 - 23:30 2.00 CLEAN P 23:30 - 00:00 0.50 CLEAN P 19/17/2007 100:00 - 00:30 I 0.501 CLEAN I P 00:30 - 01:00 ~ 0.50 i CLEAN ~ P 01:00 - 02:30 I 1.501 CLEAN I P 02:30 - 04:00 1.50 CLEAN P 04:00 - 05:30 1.50 CLEAN P 05:30 - 08:30 3.00 STWHIP P 08:30 - 11:00 I 2.501 STWHIPI P 11:00 - 12:00 1.00 STWHIP P DECOMP Full 3000 psi recovery 1 min 47 sec 6 Bottle of Nitrogen avg. 2100 psi Test witnessed by BP WSL Bill, Decker and Dave Newton NAD TP Ronnie Dalton and Jon Castle Witness of test waived by Lou Grimaldi, AOGCC. DECOMP Service Top Drive & Draw works DECOMP Make up clean out BHA 8 1/2" milt tooth bit, 8 1i2 String mill, 2 Boot Baskets, Scraper, Bit Sub, Bumper Sub, Oil Jar, 9 - DC's DECOMP RIH Picking up Drill pipe 1 x 1 Tag Cement @ 2194' DECOMP Drill Cement, Plugs and Cementer to 2231' -430 gpm / 400 psi, -70 rpm / 2-4 TQ - WOB 10- 25k DECOMP Test Casing to 2000 psi for 5 Min after driafnn through cementer and plugs DECOMP Drill BafFle Plate -430 gpm / 400 psi, -70 rpm / 2-4 TO - WOB 10- 25k DECOMP Pump 20 bbl Hi-Vis sweep -600 gpm / 700 psi Sweep Brought back Residual Arctic Pac and 10% increase in cuttings DECOMP RIH Picking up Drill pipe 1 x 1 Tag Cement (c~ 4480' Stack 25k on EZSV, O.K. DECOMP CBU @ 620 gpm 1020 psi Puw = 125k Sow = 115 k 9.5 ppg Brine in and out DECOMP Finish Circulating Hole Clean -Residual Arctic Pac Returns with Brine 620 gpm / 970 psi DECOMP Test 9 5/8" C i n 3500 si / 30 min Charted test Good Test DECOMP Displace to 9.5 ppg LSND Mud -Pump 50 Bbl Hi-Vis Spacer -620 gpm / 700 psi -25 rpm / 3k Tq. DECOMP Monitor Well, Static 9.5 ppg in /out POH DECOMP L/D Cleanout BHA -Clear Floor WEXIT P/U Whipstock and Window Milling Assembly -PJSM With Baker Fishing hand, HES MWD and NAD Rig Crew -Surface test MWD on first stand of DP, MWD Tested WEXIT RIH to 4361' WEXIT Orient Whipstock @ 69 degrees right of high side Printetl: 10/25/2007 1:23:48 PM ~~ t~{, • • BP EXPLORATION Page 8 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING 1 Rig Release: 10!23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 9/17/2007 11:00 - 12:00 1.00 STWHIP P WEXIT -RIH and Tag ESZV at 4479' -Set Anchor with 25k down, Verify anchor -Shear off Bolt with 40k 12:00 - 23:30 11.50 STWHIP P WEXIT Start Milling TOW @ 4455' BOW @ 4471' - 450 gpm / 1280 psi - 80 rpm / 4- 12k Tq. 275 Ibs of Metal Shaving recovered Mill out to 4493' (22' of Open Hole) 23:30 - 00:00 0.50 STWHIP P WEXIT Pump Super Sweep surface to surface @ 446 gpm / 1280 psi Sweep Brought up 30% Increase in cuttings Dress & Work Window while Circulating, 100 rpm / 4k Tq 9/18/2007 00:00 - 00:30 0.50 STWHIP P WEXIT Finish circulating hole clean - 9.5 ppg MW In 1 Out 00:30 - 01:00 0.50 STWHIP P WEXIT Pull milling assembly into the casing and perform LOT to 12.53 ppg EMW -9.5 PP9 MW -TOW @ 4455 MD / 4320' TVD -Pressure Leak off @ 680 psi -2.6 bbls pump 12.5 return 01:00 - 03:00 2.00 STWHIP P WEXIT POH to BHA 03:00 - 05:00 2.00 STWHIP P WEXIT L/D DC's and BHA -Starting mill 3/16" undergauge, upper mills full gauge 05:00 - 06:00 1.00 STWHIP P WEXIT Pull Wear Bushing -Flush stack for metal cuttings -Function Rams -Flush stack with Wash Tool -Install Wear Bushing 06:00 - 08:30 2.50 DRILL P INT1 PJSM on Safe Handling off the Geopilot Tool, HES Directional and NAD Rig crew in attendance -R/U Bypass lines to Geopilot control manifold -P/U BIT, Geopilot , MWD and Flex NMDC's 08:30 - 09:00 0.50 DRILL P INT1 Surface Test Geopilot and MWD's -450 gpm / 650 psi 09:00 - 12:00 3.00 DRILL P INT1 RIH, -Picking up 5" HWDP and 33 Jts of DP -Ran stands to 4338' 12:00 - 13:00 1.00 DRILL P INTi Slip and cut drilling line 13:00 - 13:30 0.50 DRILL P INT1 Service Top Drive, Draw Works and Crown 13:30 - 14:00 0.50 DRILL P 1NT1 Break Circulation, Establish Parameters -Establish Baseline ECD readings -100 & 120 RPM and 550 gpm = 10.2 ppg ECD -100 & 120 RPM and 600 gpm = 10.3 ppg ECD -80 rpm & 100 rpm / 650 gpm = 10.3, 120 rpm / 650 gpm = 10.4 ppg 14:00 - 14:30 0.50 DRILL P INT1 Wash down to 4475' @ 625 gpm 1400 psi Ream open hole past Bottom of Window 4471 - 4493 Y -45 rpm 3500 ft/Ibs Tor ue 1 :30 - 16:00 1.50 DRILL P INT1 Directional Drill from 4493 to 4576' (4367' tvd) -Stage Rpms up from 80 to 120 RPM's / 4 - 14k fUlbs Torque -625 gpm / 1350 to 1800 psi off bottom PUW - 150k SOW - 120k RtWt - 130k Printed: 10/25/2007 1:23:48 PM V TREE = GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 68' BF. 0.EV = KOP = 3195' Max Angle = 59 @ 9974' Datum MD = 11348' Datum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" I-I 2732' Minimum ID = 3.725" @ 11422' 4-1 /2" HES XN NIPPLE OF 7" LNR I--I 9072' 9-5/8" CSG, 47#, N-80, ID = 8.681" ~~ 9366' PERFORATION SUMMARY REF LOG: BHCS ON 01/16/94 ANGLE AT TOP PERF: 53 @ 11348' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11348 - 11352 S 01/23/94 3-318" 4 11494 - 11510 S 08/30/07 3-3/8" 4 11515 - 11521 S 08/30/07 3-3/8" 4 11526 - 11532 S 0$/30/07 3-3/8" 4 11556 - 11576 S 08/30/07 1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" I-{ 11435' STD -t 11576' ~- 7" LNR, 29#, 13-CR/L-80, .0371 bpf, ID = 6.184° 11615' - TD 11755' DATE REV BY COMMEM'S DATE REV BY COMMENTS 11/78 ORIGINAL COMPLETION 08/06/07 TH/SV CORRECTIONS 01/27/94 LAST WORKOVER 09/01/07 BSE/SV PXN PULLED (08/28/07) 06/28/02 JBlKAK TRSV CORRECTION 09!01/07 JNA/SV P&A (08/30/07). 05(31106 DTM WELLHEAD CORRECT~N 09/17/07 TEL/PJC JET CUT / TAG CMT (09/01107) 07/16/06 CJN/PJC SET PXN TTP 02111/07 CJN/PAG SET' TRSV HOLD OPEN SLEEV E 14 0 2 B SAFETY NOTES: CHROME 4-112" TBG ~ & 7" LNR 2216' 4-1 /2" CAM TRDP 4A SC, ID = 3.813" ® LOCKED OUT (08/27!07) GAS LIFT MANDR0.S ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3235 3232 12 MMGM RK 2 6026 5442 46 MMGM RK 3 7875 6711 47 MMGM RK 4 8777 7338 45 MMGM RK 5 9007 7501 44 MMGM RK 7000' I-IJEf CUT (09101/07) 9-518" MILLOUT WINDOW (14-026) @ 9366' 10064' TOP OF CEMENT (09!01107) 10576' I~ 4-1 /2" HES X NIP, ID = 3.81" g4~-I7" X 4-1/2" BKR SABL-3 PKR W/4-1(2" BKR KBH-22 ANCR SEAL ASSY 11385' 7" X 4-1/2" BKR SABL-3 PKR Wi4-1 /2" BKR ANCHOR SEA L A SSY 114(15 4-112" HES X NIP. ID = 3.81" 11 1x35' I--i4-1/2" WLEG1 11428' 0.MD TT LOGGED (02/30/94) PRUDHOE BAY UNTf WELL: 14-02B PERMIT No: 1932000 API No: 50-029-20318-OZ SEC 9, T10N, R14E, 1556.49' FEL & 593.53' FNL BP Exp{oration (Alaska) . ~1T~1TŒ (ID~ ~~~~[K{~ . AI/ASIiA OIL AND GAS CONSERVATION COltDllSSION SARAH PAUN. GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 /~o \q'J Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-02B Sundry Number: 307-261 Dear Mr. Hobbs: 5'CANNED AUG 1 .42007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this '!l day of August, 2007 Enc!. ell ~ ,t:j. STATE OF ALASKA .. 1_ ALASKA Oil AND GAS CONSERVATION COMM!§ION ~ APPLICATION FOR SUNDRY APPROVAL ~ D 20 AAC 25.280 dz;;¡:ZJ OJ: Fi ;;;;é (:in,;, r', 1. Type of Request: 181 Abandon / o Suspend o Operation Shutdown o Perforate o Time Extension o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 193-200 < 3. Address: D Service D Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20318-02-00 .," 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 14-02B < Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028312 / 73' Prudhoe Bay Field / Prudhoe Bay Pool ; 1;2. wt:LL ; /<... .... ....... i> .. ... ... .. ... Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11755 9129 c 11576 9012 11422 None Casino Lenoth Size MD TVD Burst CollaDse Structural Conductor 120' 20" 120' 120' 1530 520 Surface 2732' 13-3/8" 2732' 2732' 4930 2670 Intermediate 9366' 9-5/8" 9366' 7760' 6870 4760 Production Liner 2543' 7" 9072' -11615' 7549' - 9037' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 11494' . 11576' 8960' - 9012' 4-1/2", 12.6# 13Cr80 11435' Packers and SSSV Type: 7" x 4-1/2" Baker 'SABL-3' packer; I Packers and SSSV MD (ft): 10594' 7" x 4-1/2" Baker 'SABL-3' packer 11385' 13. Attachments: 14. Well Class after proposed work: / 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: / Commencina ODerations: August 14, 2007 DOil DGas D Plugged 181 Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that th~'~9 is true and correct to the best of my knowledge. Contact Ron Phillips, 564-5913 Printed Name Greg .ÞføQf)~. Title Senior Drilling Engineer $,8 Date !J ck Prepared By Name/Number: Signature ~/~ Phone 564-4191 Terrie Hubble, 564-4628 Commission Use Only , I Sundry Number: ( :jt) -¡ -:J1..1J I Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity '~OP Test D Mechanical Integrity Test D Location Clearance Other: 3 SOD ~«> \ \Sa \> -\-e: ":> '\- dJ Subsequent Form Required: 40,\ APPROVED BY Date $,'....1 l' Approved By: ONER THE COMMISSION Form 10-403 Revised 06/2006 \.,../" ..1(.../ Submit In Duplicate ORIGINAL RBDMS BFL AUG I 3 2D07 .A ~.g.tP7 ~~ . . Obp GLJJa6rßy To: AOGCC Date: July 31, 2007 From: Ron Phillips - BPXA GPB Rotary Drilling Subject: Reference: 14-028 Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-20318-02 "'./ Approval is requested for the proposed P&A of PBU well 14-02B. The well produced at low water cut and declining gas fluid ratio until mid 1995 when the water cut began to increase. Upper perforations were added November 1999 with little benefit. Additional perforations were shot February 2000 increasing the gas oil ratio to marginal. Attempts to put the well on production in March 2006 were unsuccessful due to poor outer annulus communication with the casing valve. A diesel flush was done to remove artic pack and the well was put on production. The well has been put on production during 4 subsequent time periods with the last in July 2006 with negative incremental oil rate and high water cut therefore it is shut in long term. v Well 14-02B is a long term shut in well with insufficient remaining benefit to justify a rig work over. A v horizontal two string sidetrack into the Sag River Zone is seen as the best way to maximize value from the wellbore. A 9-5/8" cut and pull will be performed to ensure communication with the 13-3/8" is no longer an issue and to provide long term inner annulus by outer annulus integrity. The sidetrack is currently scheduled for Nabors rig 2ES, beginning around September 09,2007. The pre- rig work for this sidetrack will begin at the Well's Group earliest convenience after sundry approval. Current Condition: ./ Set TTP @ 11,405' 7/16/06 ./ PPPOT- T passed to 5,OOOpsi 7/18/06 ./ PPPOT-IC passed to 5,OOOpsi 7/20/06 ./ MIT OA passed to 2,OOOpsi 1/13/07 ./ MITIA passed to 3,OOOpsi 2/17/07 ./ MITT passed to 3, OOOpsi 2/17/07 ./ Pulled hold open sleeve 3/09/07 Scope Pre-RiQ Operations: 1. Replace all live gas lift valves with dummy valves and fluid pack as necessary for CT P&A. 2. Remove tubing tail plug from 11,405'. 3. RIH with slick line and drift the tbg to 7,500' MD, below the proposed cutting depth. 4. RIH with coil tubing and P&A the 14-02B well bore (215 deg F and 3286psi at TD). Lay in -40 bbls of 15.8 ppg cement, leaving TOC in the 4-1/2" tbg at 9,500' MD. Cement volume calculated on the following parameters: Cement Calculations: 11,576' - 11,435' 7" LNR, 29#, 13-CR-80, 0.0371 bpf - 5.24 bbls 11,435' - 9,500' 4-1/2" tbg, 12.6#, 13-CR-80, 0.0152 bpf -29.45 bbls Total cement 40 bbls, including 5 bbls for squeezing. 5. RU E-line and RIH. Cut the 4-1/2" 13 CR-80 tbg at 7,000' MD with an appropriate jet cutter. 14-02B Application for Sundry ~~ LY ~ "- ~O . . 6. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 7. Function all lock down screws, repair or replace as needed. 8. CMIT TxlA to 3500psi, MIT OA to 2000psi, PPPOT (T and IC) needed within 45 days of drilling rig moving on well. 9. Bleed casing and annulus pressures to zero. 10. Set a BPV in the tubing hanger. Secure the well. 11. Remove the well house, level the pad. Please provide total well preparation cost on the handover form. RiQ Operations: 1. MI I RU Nabors rig 2ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Set and test TWC from above and below. 3. Nipple down tree and adaptor. Nipple up and test BOPE 250psi low and 3,500 psi high. Pull TWC. 4. Rig up, back out lockdown screws, pull hanger. 5. Pull and lay down 4-1/2" tubing from the cut at -7,000'. (the deeper cut is to recover Cr tbg) 6. MU/PU mill assembly. RIH to -6,900' picking up drill pipe, and circulate the well bore. 7. RU e-line, run USIT. Corrosion and cement mode from 5,000' to surface. 8. Determine the depth of the 9-5/8" cut based on USIT interpretation (-2,000). 9. RIH with HES 9 5/8" EZSV bridge plug on E-line and set at -4,522' md, as required to avoid cutting a casing collar while milling the window. POH. RID E·line. 10. String shot 9-%" casing at back off point (-2,000' or where USIT indicates TOC) to ease break out. RD e-line. 11. Change out to 9-%" rams, and test rams. 12. RU a Baker 9-%" cutting assembly. RIH picking up DP. Cut the 9-%" casing per Baker representative instructions. Cut -4' above the string shot casing collar. POOH, UD assembly. 13. BOLDS, RU casing spear assembly, and unseat the 9-%". Circulate the Arctic Pack from the annulus with warm diesel followed by seawater and detergent sweeps. Pull the 9-%" casing from the cut. 14. RU wash over assembly, and 13-%" casing scraper. 15. RIH, clean out the 13-%" casing, and the 9-%" casing stub, POOH, UD the assembly. 16. RU BKR back-off assembly, RIH, and back off the 9-%" casing joint. POOH, UD assembly. 17. RU casing spear assembly, RIH, recover cut stub. POOH. 18. RU 9-%" HES ES Cementer on screw in sub and RIH wI new 9-%", TC-II casing. 19. Install spool, Nipple up BOPE, and test. 20. Shear open ES cementer and cement 9-%" x 13-%" annulus to surface. 21. PU 4" DP and mill tooth bit. Make clean out run through the ES Cementer. 22. Pressure-test the 9-%" casing to 3,500 psi for 30 minutes. Record test. 23. Chan e BOP rams back to VBR's and test rams. 24. P and IH with 9-%" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on EZSV bridge plug. Shear off of whip stock. 25. Displace the well to 9.5 ppg LSND based milling fluid. 26. Mill window in 9-5/8" casing at ± 4,500 cMD, plus approximately 20' from mid window. Circulate well bore clean. ./ 27. Pull up into 9 5/8" casing and conduct an FIT to 12.6 ppg EMW. POOH. (Mud wt. should be weight up to 11.6 ppg before drilling to HRZ) 28. M/U 8-1/2" Dir/GR/RES/PWD assembly. ' 29. RIH to window. Drill ahead per directional plan to the 7" casing point at 10,999'. 30. Circulate the well bore clean. Short trip, circulate the well bore. POOH, UD assembly. 31. Change out to 7" rams and test. 32. RU I MU 166 joints of 7" liner. 33. RIH to bottom on drill pipe, circulate and condition the hole. 34. Cement the entire 7" liner through the 8-1/2" hole and back 150' into the 9-5/8" casing at 4,350'. Set the hanger and packer. Displace cement with mud. 35. Circulate bottoms up, POOH. UD liner running tool. 36. As a Contingency (No money in AFE for Scab liner): a. Scab liner will be run, if USIT results show leaks, or pitting in below the 13-3/8" shoe. b. Run 7" scab liner up to the 13 3/8" shoe or where USIT show appropriate. c. Sting in and establish seal. P/U to expose ports. d. Cement the entire length of the 7" scab liner, bury the seal. 37. Change out to variable rams and test. 14-02B Application for Sundry . . 38. Pick up drill pipe and stand back. 39. MU 6-1/8" cleanout assembly with DIR/GR/RES and an insert bit. 40. RIH to 7" liner landing collar. Test for 30 minutes, and record. Drill out of the cement and float equipment to shoe. 41. Displace to 8.5 ppg Flo Pro drilling fluid. 42. Drill out of the 7" shoe plus 20' of new formation. Pull up into the shoe and conduct FIT to 10.0 ppg mud EMW. 43. Drill 373' to the landing in the Sag River formation at 11,372' MD. / 44. CBU, POOH for 6-1/8" horizontal BHA with a PDC bit, and GR/Res/Azimuth density. Strata steer processing will also be utilized through this section. 45. RIH to the bottom, drill ahead 2,381' to planned TD at 13,753'. 46. CBU, Short trip, circulate and condition the hole for running the 41/2" slotted liner. POOH, UD excess drill pipe. Clear the floor of unnecessary equipment. 47. RU, MU 2,253' of 41/2" slotted liner plus 651' of blank 4 1/2" 12.6#, L-80, IBT-M liner for overlap into the 7" liner. 48. RIH to shoe, circulate string. RIH to bottom, circulate and condition the hole. 49. Release, set packer, circulate bottom up. 50. POOH. UD liner running tool. 51. RU, test BOPE if needed. 52. Test casing and liner. 53. R/U 10,849' of 4-1/2" 13CR, Vam Top completion tubing. 54. RIH, space and land the completion tubing into the 4-1/2" liner top, Run in lock down screws. 55. Reverse circulate to seawater and corrosion inhibitor. 56. Drop ball and Rod, set packer. 57. Test tubing and annulus separately to 3500 psi each, record the test. 58. Install and test TWC. 59. Nipple down BOPE. 60. Nipple up tree and adaptor flange, test tree to 5,000 psi. Pull TWC. 61. Reverse in diesel freeze protect to -2,200' U-tube. Install BPV. 62. Secure well. Release rig. Post-Riq Operations: 1. MI 1 RU slick line. Pull the ball and rod 1 RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Perform static pressure survey. 3. Install well house and instrumentation. Well Coordinates: Surface Northin Offsets TRS Location 5,939,079 4,018' FSL 1 4,052' FWL 10 N, 14 E, See 9 Target Northin Offsets TRS Location 5,938,457 3,317' FSL 1 2,100' FWL 10 N, 14 E, Sec 10 Bottom Northin Offsets TRS Location 5,937,543 2,345' FSL 1 4,536' FWL 10 N, 14 E, Sec 10 Estimated Pre-rig Start Date: 08/07/2007 Estimated Spud Date: 09/09/2007 Ron Phillips Operations Drilling Engineer 564-5913 14-02B Application for Sundry .TREE =. GRA Y GEN 2 WELLHEAD = A CTUA TOR = KB ELBI = KOP= Max Angle = Datum MD = DatumTVD = ~u "'-$ 8800' SS 113-3/8" CSG, 72#, N-80, ID= 12.347" H 2732' Minimum ID = 3.725" @ 11422' 4-1/2" HES XN NIPPLE 14-028 . SAFETY NOTES: CHROME 4-1/2" TBG & 7" LNR 2216' 4-1/2" CAM TRDP4A SC, 10 = 3.813" w /HOLD OÆN SLEBlE, ID = 2.75" . GAS LIFT MANDRELS ST MD TVD OBI TYÆ VLV LATCH PORT DATE 1 3235 3232 12 MMGM RK 2 6026 5442 46 MMGM RK 3 7875 6711 47 MMGM RK 4 8777 7338 45 MMGM RK 5 9007 7501 44 MMGM RK ITOPOF 7" LNR 19-5/8" CSG, 47#, N-80, 10 = 8.681" I 9366' ÆRFORA TION SUMMARY REF LOG: BHCS ON 01/16/94 ANGLEAT TOP ÆRF: 53 @ 11348' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11348 - 11352 S 01/23/94 3-3/8" 4 11494 - 11510 02/17/00 3-3/8" 4 11515 - 11521 11/25/99 3-3/8" 4 11526 - 11532 11/25/99 3-3/8" 4 11556 - 11576 C 02/04/94 DATE 11/78 01/27/94 06/28/02 05/31/06 07116/06 02/11/07 I 9-5/8" MILLOUT WINDOW @ 9366' 7" X 4-1/2" BKR SABL-3 PKR W/4-1/2" BKR KBH-22 ANCR SEAL ASSY 1" X 4-1/2" BKR SABL-3 PKR W/4-1/2" BKRANCHOR SEAL ASSY 14-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, 10 = 3.958" 11435' ELMO TI LOGGED (02/30/94 ) I PBTD H 11576' I 17" LNR, 29#, 13-CR/L-80, .0371 bpf, 10 = 6.184" H 11615' RBI BY COMMENTS ORIGINAL COMPLETION LAST WORKOV ER JB/KAK TRSV CORRECTION DTM WELLHEAD CORRECTION CJNlPJC SET PXN TIP CJNlPAG SET TRSV HOLD OÆN SLEBlE I TO H 11755' DATE RBI BY COMMENTS PRUDHOE BAY UNIT WELL: 14-02B ÆRMIT No: "1932000 API No: 50-029-20318-02 SEC 9, T10N, R14E, 1556.49' FEL & 593.53' FNL BP Exploration (Alaska) TREE :c , ;RAY GEN2 ·14-D2B . SAFETY NOTES: CHROME 4-112" TBG \llÆLLHCAD :c GRAY P:œ-R :g & 7u LNR ACTUA TOR:c AX8.SON KB. 8.EV :c 68' BF. 8.EV :c KOP :c 3195' MIx Angle:c 59 G 9974' Datum M) :c 11348 Datum ND :c 8800' 55 I 13-318" CSG, 72#, N-BO, ID = 12.347" I 2732' ~ ~ Minimum ID = 3.725" @ 11422" 4-112" HES XN NIPPLE -"C:i 17,000' ~I 4 -1¡2" Tub±1g cut I C¡o7Z' 19,500' r-I Top ofP fA cern en~ I TOP OF 7" LNR ..808G' .. I 9-518" MlLOurWNOCNtlG 9366' I I 9-518" CSG, 47#, N-BO, ID == 8.681" 9366' PERFORA TION SUMIIIA RY ...I 10576' -i 4-112" HES X NIP, ID == 3.81" I , ^ REF LOG: BHCS ON 01116/94 ANGLE AT TOP PERF: 53 G 11348' ~ ~ Note: Refer to Production DB for historical perf data " K>~ 10594' 7" X 4-112" BKR SABL-3 PKR W/4-1 12" I SIZE SPF INTERVAL Opn/Sqz DATE BKR KB~22 ANCR SEAL ASSY 3-318" 4 11348-11352 S 01/23/94 3-318" 4 11494-11510 0 02117/00 ~... )/~ 3-3/8" 4 11515-11521 0 11/25/99 ~ ~ 11385' 7" X 4-1/2" BKR SABL-3 PKR 3-318" 4 11526-11532 0 11/25/99 W/4-112" BKR ANCHOR SEAL ASSY 3-3/8" 4 11556-11576 0 02104I94 't '1 XM I 11405' H4-112" HES X NIP, ID == 3.81" I """'-1 x H4-112" HES XN NIP, ID. 3.725" I 11422' ~ ~ I 11435' H4-112" WLEG I I 4-112" TBG, 12.~, 13oCR-80, .0152 bpf, ID· 3.958" I 11435' I ~~I 11428' H ELMD TT LOGGED 02103I94 I I PBTD 11576' I ~ I 7" LNR. 291. 13oCRlL-BO. .0371 bpf, ID == 6.184" 11615' I I"Io..a. I't.V I TO H 11755' DATE REV BY COMvt:NTS DATE REV BY COMVENTS PRUDHOE BAY lNT 11n8 ORIGINAL COMPLETION \llÆLL: 14-02B 01127114 LAST WORKOVER ÆRMT No: ~ 932000 02J02J02 Rf\VTP CORRECTIONS API No: 50-029-20318-02 06128/02 JBIKA K TRSV CORRECTION SEe 9, T10N, R14E, 1556.411 Fa. & 593.53' FNl. 05131106 D1M \llÆLLHCAD CORRECTION .. Exploration CAlaka) 14-02C Proposed . . I SAfETYNOTÐI: CHROME4.112"TBG 2,000 H HES ES Cementer 2,732 H 13-3I8",72tI, N-BO, 0=12.347" 4,350 H 9-518" X T' Baker LNR hanger 4,500- H 9-5/8" IMndow 4,519 I" 4,522 H EZSV ClBP 7,000 H 4-112" Tubing cut 9,500 H Top of Cement I 10,775 H 4-112", 'X' Landing llipple, 10=3.813" I 10,795 H T' X 4-112"Baker S-3 PKR I 10,815 H 4-1/2" 'X' Landing llipple, 10=3.813" I 10,835 H 4-112", 'XN' Landing Nipple, 10=3.725" I 10,849 H 4-1/2" ,12.6#, CR-80 TBG I 10,849 H T' X 4-112" Baker LNR hanger I 10,999 H T',26#, L-BO LNR I I 11,500 H Heel, top of slotted LNR DATE 11nl 01mll4 02102I02 06128102 05131106 C17/18107 REV BY COM\.1ENTS ORIGINAL COMPLETION LAST WOAKDVER RNITP CORRECTIONS JBlKAK TRSV CORREcTION DTM WELLHEAD CORREC11ON RLP Updated W8..LI-EAD .. ACTlJA TOR .. KB. 8..EV .. BF. ELEV .. KOP.. Max Angle '" Datum M) '" Datum lVD '" G 1\ ~ Y OJ I ~ , GRAY AX8..SON 68' 4500' ~7@11172' 8800' 55 I 13,753 H 4-112",12.6#, slottec:llBTLNR DATE REV BY COMIt1ENTS PRUDHOE BAY UNIT WELL: 14-028 PERMT No: ~ 932000 API No: 50-029-20318-02 SEe 9, T1 ON, R14E, 1556.49' Fa & 593.53' FNL BP Exploration (AJuka) . . Review of Sundry Application 307-261 BP Exploration (Alaska) Inc. Well Prudhoe Bay Unit 14-02B Prudhoe Bay Field, Prudhoe Oil Pool AOGCC Permit 193-200 Requested Action: BP Exploration (Alaska) Inc. (BPXA) proposes to plug the existing well to prepare it for sidetracking. Recommendation: I recommend approval of BPXA's request. Discussion: Well 14-02 was originally drilled and completed in 1978. The well produced nearly 26 MMBO before being plugged in preparation of the 14-02A sidetrack in 1993. The 14- 02A sidetrack was successfully drilled, but the well was lost during formation evaluation completing operations and the 14-02B sidetrack immediately commenced. 14-02B was completed in January 1994 and began producing the following month. The well produced on an essentially continuous basis until March 2000. Initial production was approximately 2,900 BOPD at a GOR of about 1,000 SCF/STB and a water cut of about 3%. Oil production began declining and the GOR began climbing almost immediately, the water cut remained relatively constant until October 1995 when it began slowly climbing. In November 1999 the well was re perforated, on two separate occasions, to attempt to improve performance. In the month prior to this work the well produced 73 BOPD at a GOR of 11,600 SCF ISTB and a water cut of 82%. After the first add perfs operation, conducted on November 25th, the post operation well test showed very little change in oil or gas production rates, but the water rate nearly quadrupled. Later that day, according to the Commission's well files, additional perforations were added and the test results were much more encouraging. The well tested at 1,628 BOPD, with a GOR of about 11,500 SCF/STB, and a water cut ofless than 50 percent. However, there was a note on the "Description of Work Completed" submitted with the 10-404, which was not submitted until March 15,2000, that stated "returned well to production and obtained valid welltest data. Well has since gassed out & is currently shut in. Additional work options are currently being evaluated." Production data shows that after November 1999 the well never produced for more than 20 days in a month and the GOR quickly rose to nearly 55,000 SCF/STB, which supports the operator's claim that the well "gassed out". A few attempts have been made in the intervening years to return the well to production, without any additional work to the well, but these have proven unsuccessful. Production . . was never resumed for more than a few days per month and producing GORs were as high as 99,000 SCF/STB. Conclusion: Due to the high GOR and water cut for this well it is apparent that the well is no longer a viable producer. BPXA's proposal to abandon the existing well so that the well can be sidetracked to a more favorable location appears to be the best option for this well. D.S. Roby #~ Reservoir Engi~ August 9, 2007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Per/orate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 68 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1262' FNL, 1226' FEL, Sec. 9, T1 ON, R14E, UM (asp's 675245, 5939078) 14-02B At top of productive interval 9. Permit number / approval number 1200' FNL, 1618' FEL, Sec. 04, T10N, R14E, UM (asp'3674718, 5944409) 193-200 At effective depth 10. APl number 50-029-20318-02 At total depth 11. Field / Pool 594' FNL, 1556' FEL, Sec. 4, T1 ON, R14E, UM (asp's 674764, 5945015) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11755 feet Plugs (measured) Tagged PBTD @ 11560' MD (11/24/1999) true vertical 9128 feet Effective depth: measured 11560 feet Junk (measured) true vertical 9000 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 120' 20" 675 Sx AS II 120' 120' Surface 2664' 13-3/8" 5904 Sx PF II 2732' 2732' Production 9298' 9-5/8" lOOO Sx C~ass G 9366' 7933' Liner 2555' 7" 445 Sx Class G 11 615' 9035' Perforation depth: measured 11494' - 11510'; 11515' - 11521'; 11526'- 11532'; 11556'- 11576'. ~ E true vertical 8958'- 8968': 8971'- 8975'; 8978'- 8982'; 8997'- 9010'.MAR1 5;)000 Tubing (size, grade, and measured depth) 4-1/2"12.6#, 13CR-80 Tbg @ 11435' MD.0il & GU ,'0mrnlss )n Packers & SSSV (type & measured depth) 7" X 4-1/2" BAKER SABL-3 PACKER @ 10595' MD; 7" X 4-1/2" BAKER SABL-3 PACKER @ 11386' MD. 4-1/2" CAMCO TRDP-4A-SC SSSV @ 2217' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 117 1123 702 - 293 Subsequent to operation 1628 18773 1257 - 697 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~,¢"~~'~d~U ~,'";(:;~/'*¢~'l./f Title ARC O Engineering S upe tv is or Date Erin Oba , ,¢ , f Prepared by Paul Rauf 263-4990 L Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 14-02B DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 11/25/1999: MIRU ELU. PT'd equip to 3000 psi. RIH w/perf guns & shot 16' of Add Perforations @: 11494' - 11510' MD (Zone 2C) Reference Log: BHCS 1/16/1994. Used 3-3/8" carriers and all shots @ 4 SPF, random orientation, & 60°/120° phasing. POOH w/guns & verified ASF. RD. Returned well to production and obtained valid welltest data. Well has since gassed out & is currently shut in. Additional work options are currently being evaluated. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1262' FNL, 1226' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 1200' FNL, 1618' FEL, Sec. 04, T10N, R14E, UM At effective depth At total depth 594' FNL, 1556' FEL, Sec. 4, T10N, R14E, UM 5. Type of Well: Development__X Explorato~ Stratigraphic__ Service__ (asp's 675245, 5939078) (asp's 674718, 5944409) (asp's 674764, 5945015) 6. Datum elevation (DF or KB feet) RKB 68 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-02B 9. Permit number / approval number 193-200-0 10. APl number 50-029-20318-02 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 120' 20" Surface 2664' 13-3/8" Production 9298' 9-5/8" Liner 2555' 7" 11755 feet 9128 feet 11560 feet 9000 feet Cemented 675 sx AS II 5904 Sx PF II 1000 Sx Class G 445 Sx Class G Plugs (measured) Junk (measured) Tagged PBTD @ 11560' MD (11/24/1999) Measured Depth TrueverticalDepth 120' 120' 2732' 2732' 9366' 7933' 11615' 9035' Perforation depth: measured 11515' - 11521'; 11526' - 11532'; 11556' - 11576'. RECEIVED true vertical 8971' - 8975'; 8978' - 8982'; 8997' - 9010'. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2"12.6#, 130R-80 Tbg @ 11435' MD. Oil & Comm b. Am~ora0e 7" X 4-1/2" BAKER SABL-3 PACKER @ 10595' MD; 7" X 4-1/2" BAKER SABL-3 PACKER @ 11386' MD. 4~1/2" CAMCO TRDP-4A-SC SSSV @ 2217' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Prior to well operation 60 869 322. Subsequent to operation 78 886 1150 Casing Pressure Tubing Pressure - 260 266 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 ~ C~ ~~ _,~¢/d~. ~,¢¢~¢ Title ARCO Engineering Supervisor Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE~ 14-02B DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 11/24/1999: 11/25/1999: RIH & tagged PBTD @ 11560' MD. MIRU ELU. PT'd equip to 3000 psi. RIH w/perf guns & shot 12' of Add Perforations @: 11515' - 11521' MD (Zone 2C) Reference Log: BHCS 1/16/1994. 11526' - 11532' MD (Zone 2B) Used 3-3/8" carriers and all shots @ 4 SPF, random orientation, underbalanced press, & 60°/120° phasing. POOH w/guns & verified ASF. RD. Returned well to production and obtained valid welltest data. RECEIVED AOGCC individual Well. Geological Materia']s ir_,ventory Page,. · Date · 10/13/95 ~ERMIT r ..... ~ ~ .... RUN DATE_RE CVD 93~200 407 93~200 DALLY WELL OP 93~200 SURVEY ~°3~00= SURVEY 93.-20n BHC/AC/GR 93-200 CNL/GR ~/i0516-i1724, OH-DLL/AC DATE 01/27/94 ' ~I/25/93-01/28/94 9350-I0772 .~ i0580-11724 ~/i0530-i1666 1~58 .-~/, i0550-I1694 9~-~00~, ~ D~ TDT-P 93-~200 DLL/GR/SP / PERF lz00-11580 1 93-200 PFC/CL ~,_, 10870~1i601 1 02/17/s4 02/11/94 02/11/94 02/11/94 02/'11/94 03/18/94 06/19/95 03/18/94 03/'18/'94 03/18/94 q3-200 PFC.!/~/ _ _ ~m~CCL ~ 10870-11560 1 03/~8/94 93--200 SBT/GR/CCL ~ !0900-1!584 1 03/18/94 ~3-200~ SSTVD ~ lO5mo-!1694~ ~ 1 03/18/9R 93~-900 USIT(CEMENT ~/I'i420-11575 ! 03/18/94 93~200 6717 ji1559-i1044 I 07/03/95 Are dry ditch samples required? yes ~ And received?._~~Y~ no ~'~ ' ~1 --~ed? yes ~ Analysis & description r'ec~ived? ~no Was Are well tests required? yes ~ Received? ~no w is ~,~ ,i iance Initial c~Pi~NTS GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9521 Company: 6/1 9/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BI. RF Sepia DIR MWD Disk D.S. 3-22 DUAL BURST TDT-P 950603 1 1 :D.S. 3-29 PROD PROFILE 950530 I 1 D.S. 3-32A PERF RECORD 950609 I 1 D.S. 4-2A DUAL BURST TDT-P 950529 1 1 D.S. 4-35 PERF RECORD 950529 I 1 D.S. 6-19 DUAL BURST TDT-P 950530 1 1 D.S. 9-3 BRIDGE PLUG RECORD 950531 I 1 D.S. 9-39 PERF RECORD 950604 I 1 D.S. 9-50 PROD PROFILE 950602 I 1 D.S, 12-15 GAS LIFTSURVEY 950606 I 1 D.S. 12-17 GAS LIFTSURVEY 950607 I 1 D.S. 14-02B DUAL BURST TDT-P 950531 I 1 D.S. 15-36 DUAL BURST TDT-P 950602 I 1 D.S. 16-11 MI INJECT PROFILE 950605 I 1 D.S. 15-15 951 82 CNT-D 950509 1 D.S. 14-33 951 70 CNT-D 950427 I t-I l SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: JUN 1 9 1995 Alaska 0il & Gas Cms. Commission Anchorage ARCO Alaska, Inc. Date: Feb 16, 1994 P.O. Box 100360, Transmittal #: 94023 iorage, AK Subject: ARCO C~ From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Well Number i 1-24A PWDW 2-1 i 3-20A 3-21 3-25A 3-27 3-32 4-5 4-32 ,~_% 4-46 4-46 '5-35 K9-9 9-9 I 9-11 9-13 9-20 9-34 I11- 16ST1 Log Date (M-D-Y) Tool Type i Run, Scale 12-24-92 PFC/GR 1, 5" 01-24-94 Static pressFFemp I 1, 5" 1-30-94 Perf Record ! 1, 5" 2-5-94 2-2-94 2-4-94 2-4-94 2-3-94 1-25-94 1-26-94 2-2-94 2-6-94 2-6-94 CNL 1, 5" Perf Record CompI Record CompI Record i 1, 5" Contractor i Atlas Sch Sch Sch { 1, 5" Sch ! 1, 5" Sch Sch Prod Profile ! 1., 1 "&5" I Bridge Plug Bi 1 5" Tubing Cutter Comp! Record USlT/Cement PDC & Jewerly Leak Detec i 1 5" 1 5" I 5" 1 5" I 2" I 1, 2"&5" Leak Detec i 1, 1"&5" 2-7o94 2-7-94 Leak Detec 1-26-94 1-24-94 1-29-94 1-24-94 Bddge Plugg,t~'~ ~1, 5"( Sch Sch Sch Sch Sch Sch Sch Sch Sch ?'~ Sch 1-25-94 2-3-94 ~ Bridge Plug Mi Inj Profile !/Bddge Plug b\ Bddge Plug,s, 511 ! 5II 1~ 5II 1 511 Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Atlas Sch Sch c~ i 11-17 tut~ i 12-16A 2.co j,/14-2B ~,,.14-2B ~,~ ~14-31 I~ j 15-9A I ! 6-7 5~ ~ 16-22 ~ ~ 16-29A Number of Records:32 John E. DeGrey 2-5-94 1, 1"&5" 2-2-94 ! 5II 2-3-94 1, 5" 2-4-94 1, 5" 2-4-94 2-6-94 2-6-94 6-16-92 2-3-94 i Leak Detec Perf Record USiT/Cement Perf Record Prod Profile Perf Record Perf Record Casing Collar Gas lift survey Prod Log 1-31-94 511 1 511 1 511 1 511 1~ 1II 1, 1"&5" DS# 1-245T th~ ¢ormo! w~ll nam, i$1-~4^ DS# 11-165T~ tl~ ¢orract ^PI# i~ $0-02g-2~ 581-00 0-.l 2..:z-7. to ARCO Alaska, Inc. Is · Subsidiary of AflantlcRIchfleldCompa~y i 12-01 i 3-06-94 I Prod i 1, 1"&5" Schlumber ~ ~ 1, 5" Schlumber 13-10 ! 2-24-94 ! Perf ~ 2"&5" 14-2B if 1-16-94 i CNUGR ! 1, Schlumber 14-2B ~ 1-16-94 i Sub-Sea i 1, 1"&2" Schlumber 14-2B ~ 1-16-94 i BH~Acoustilo~t~¢-l, 2"&5" Schlumber ! 14-2B i 1-16-94 i DuaiLatedoCGR/~:' 1, 5" Schlumber~ 14-2B 14-2B ! 1-23-94 i PFO/GR/CCL ! 1, 5" Schlumber .14-2B ! 1-23-94 ! PFC/Collar j 1, 5" Schlumber 14-24 f 2-19-94 I Lea~ ! 1, 5" Schlumber J 14-28 ! 3-05-94 i Leak i 1, 1"&5" Schlumberl 14-34 16-08 i 3-07-94 i Prod Prof/Spin i 1, 2"&5" SchlumberI 12.S i 17-21 i 2-24-94 'f¢~ i PWDW i 2-09'94I Water , 1,5" SchlumberI 02-01 Inj/FBS/Templrc¢~ Well 4-24 the correct APl # is 50-029-21508-00 Number of Records: E. DeGrey Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon states,f AlaSka '~- Mobil Please acknowledge receipt by signing and returning a copy of transmittal. By: .,~/'¢//~.~ ~.~ Date: / 0" RECEIVED ARCO Alaska, Inc. Date' Subject: From/Location: Telephone: To/Location: P.O. Box 100360 chorage, AK Mar 15, 1994 Transmittal #: 94029 AR e Finals ~'(,~:::¢ ~ John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 99510~ ~, I Well iL°g DatelNumber (M-D-Y) T°°i Type i RUn'Scale Contractor i 01-02 ! 2-26-94 i Prod/Spin/Temp./¢¢.~ 1,5" Schlumber [ 01-03 i 2-19-94 i Prod~BS/Temp~.~l 1, 5" Schlumber { 01-09 l 3-01-94 ] Tubing Cutter ~ 1, 5" Schlumber i 01-11 i 2-27-94 i Prod Prof/Spin i 1, 5" Schlumber ~ 01-18 { 2-23-94~ Leak Detection ~ 1, 1"&5" ~Schlumber i 01-25 ~ 3-06-94 ~ CNL ~ 1, 5" Schlumber ~03-20A ~ 2-17-94 Peal ~ 1, 5" Schlumber ~03-20A ~ 3-03-94 Dual Burst ~ 1, 5" Schlumber ~ 03-32 ~ 2-26-94 Lea~Pre~emp{ 1, 2" Schlumber ! 03-34A ~ 2-24-94 1 Pro~Pre~empi 1, 2"&5" Schlumber i i 04-01 ~ 2-19-94 ~ Prod ~ 1,5" Schlumberi~eb-~5~t ~%-~,* ~ 04-24 ~ 2-22-94 ~ Prod ~ 1,5" Schlumberi '~bbO¢('%'% i 04-40I ~2'22'94 Peal ~ 1, 5" { 04-46 i, 2-16-94 ~ Rope Peal ~ 1 5" , Schlumber ~/04-47 I 2-18-94 ~ v Peal ~ 1, 5" Schlumber ~ 04-47 ~ 2-15-94~ ¢ CBT-GE ~ 1, 5" Schlumber I%04-47 ~ 2-15-94 v C~-GR ~ 1, 5" Schlumber I 05-06 ~ 2-11-94 Peal ~1,5" Schlumber ~ 05-14A 7-11-93 USlT/Cem&Coff ,5" Schlumber ~ 05-15A ~ 05-15A ~ ~/GR-L~~ 1, 5" Schlumber ~ 05-26 ~ 3-02-94 Dual Burst %~' 1, 5" Schlumber /06-15~ 2-21-94 Prod ~ 1, 5" Schlumber ~ 06-15 t 2-22-94 Comp NeUron 1, 5" Schlumber 06-22A 3-01-94 Peal ~ 1, 5" Schlumber 07-08 3-02-94 Prod~e~~ 1, 5" Schlumber 07-23 3-07-94 Lea~Spi~em~ 1, 5" Schlumber 09-34 2-21-94 Tubin9 C~er ~ 1, 5" Schlumber 11-02 2-10-94 Inj Prof)~ ~f~, 5" Schlumber /'11-04 2-20-94 Tubing C~er ~ ,5" Schlumber . 5" Schlumber ~'~0~o~ ~11-04 ~ 2-17-94 Tubing~A~~,5. 11-7ST 3-06-94 Inj Prof/Spin~lf~ 1, Schlumber ~111- 2-25-94 Lea~Pre~Temp 1, 1"&5" Schlumberj 6ST /Spin/~ ,~111- ~ 3-08-94 Comp/l~l~table i 1, 5" ~Schlumber 6ST ~11-17 ~ 2-20-94 ' Leak ~ 1, 5" Schlumber 1-17 ~ 3-08-94 Prod ~ 1, 5" Schlumber ~- ,~% ~ 11-23 , 8-09-91~ ~D ~ 1,5" Hallibu~on ~ ~11-24A 3-05-94 Ped/G~CCL 1, 5" Schlumber ~!1-24A [ 2-22-94 Comp/Pe~ j 1, 5" Schlumber ARCO Alaska, Inc. Is a 8ub~l(laty of Al~a~tlcRlchfleidCo~ ARCO Alaska, Inc. P.O. Box 100360, A,.~no'rage, AK Date: Feb 4, 1994 Transmittal #: 94017 99510~4~ ~' Subject: ARCO open hole Magnetic tape(s) From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Number of Records:5 Well Number 4-46 14-1A 14-2A 14-2B 15-9A John E. DeGrey PBOE Document Control j Log Date i (M-D-Y) ,~r.4¢ 1-7-94 2-27-93 2-2-93 ! 1-16-94 i 12-1-93 Tape Type Run, Footage DIFL/AC/CN/GR 0{~LL/AC/CN/GR ! DLL/MLL/A C/CN/ DLL/ACICN/GRi DLL/CNIZDL/GR i 10150- 10956 10903- 11523 9525- 11144 10516- 11724 8544-9931 Contractor Atlas/ Atlay / ~tlas ' Distribution: Bob Ocanas Phillips BPX Exxon State of Alaska Please acknpwledge receipt by signing and returning a copy of transmittal. By: .?~~'~C(~../~~'...~ Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 93-200 3. Address f~" ~ r 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 ~ j ~':-~ ~ ': ~ ~' ~ , 50- 029-20318-02 4. Location of well at surface ' ~ '~.,_~ ,~ ~ ~ / i [ 9. Unit or Lease Name 1262' SNL, 1228' WEL, SEC. 9, TION, R14E !~.~.!:. .'i'.!'.:~i~ ~ ' ~]~ ~..*~TiON$ ' Prudhoe Bay Unit At Top Producing Interval i ..... ~,~ ~ ij '~'L-~FJ~:.'D 10. Well Number 14-02B At Total Depth ! ~:~,,i~!) i ~] ~~,~ 11. Field and Pool ...................... ~ ..~,~. .... Prudhoe Bay Field/Prudhoe Bay Pool 593' SNL, 1570' WEL, SEC. 4, TION, R14E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 67.6' I ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 1/8/94 1/14/94 2/4/94 //~/~'~I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey J20. Depth where SSSV set J21. Thickness of Permafrost 11755' MD/9127' TVD 11600' MD/9025' TVD YES [] NO []! 2216' feet MD ! 1900'(Approx.) 22. Type Electric or Other Logs Run CHT/GR/CNI_/DLL/A C, 23. CASING, LINER AND CEMENTING SE'I-rING DEPTH MD CASING SIZE WT. PER Fi'. GRADE TOP Bo'FroM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94~ H-40 Surface 120' 30" 675 sx Arcticset II 13-3/8" 72# N-80 Surface 2732' 17-1/2" 5904 sx Permafrost II 9-5/8" 47# N-8O/RS-95 Surface 9633' 12-1/4" 1000 sx Class "G" 7" 29# Nr-a~/~3CmO 9072' 11615' 8-1/2" 445 SX Class "G" 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) -SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter3-3~8" 4 spf 4-1/2", 13CR80 11435' 11385' MD TVD 11556'-11576' 8997'-9010' 26. ACID, FRACTURE, CEMENT SQUEEZe, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL~ 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 2/4/94 Gas Lift Date of Test Hours Tested ;~RODUCTION FOR OIL-BBL ~AS-MCF WATER-BBL CI-.IOKESIZE IGAS-OIL RATIO rEST PERIOD Flow Tubing Casing Pressure CALCULATED DIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. ~si~ 0tt & G~s Cons. C0mmtss~0~'" A~ch0m~e Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Sag River 10838' 854 7' Shublik 10904' 8610' Top Sadlerochit 10982' 8653' 31. LIST OF A'I-I'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~/~~-~ TitleOri//ino_Eno_ineerSuoervisor Date2'' ] '-(~) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". R E C ~ IV E Form 10-407 FEB 1 1 199~- Ai~,ska Oil & Gas Cons. C0rnmission Anchorage BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DSl4-02A/B BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 11/24/93 09:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 11/25/93 (1) TD:l1560 PB:10435 PULL TBG MW: 0.0 Seawater RU & TAKE ON SW. PULL BPV. PUMP SW, CIRC. INSTL BPV. RD TREE, RU BOPE. TEST PKOFF & BOPE. RU, CBU. LD TBG. 11/26/93 (2) TD:l1560 PB:10435 TRIP OUT TO RUN WHIPSTOCK MW: 0.0 Seawater LD TBG. TRIP IN, PU DP. CBU. REV CIRC. TEST CSG. REV CIRC. TRIP OUT. 11/27/93 ( 3) TD: 9843 PB:10435 MILLING MW: 9.8 KCl POH. RU & RIH, SET PKR. POH. RIH W/GYRO TOOL. POH. RIH W/SURVEY. POH. DISPCL WELL W/KCL FLUID. MILL WINDOW TO 9843. 11/28/93 (4) TD: 9860 PB: 9854 CBU MW: 9.8 KCl MILL WINDOW. CBU, PUMP DRY JOB. POH. RIH, MILL TO 9860. CBU. 11/29/93 ( 5) TD:10150 PB: 9854 DIRECTIONAL DRLG MW: 9.9 KCl CBU, POH. LD MILL ASSY. RIH, TEST MWD. RIH. ORIENT MUD MTR TO WHIPSTOCK. DIRECT. DRILL TO 10150. 11/30/93 ( 6) TD:10547' (10547) POH MW: 9.9 VIS: 55 DRLD TO 10547. CBU. DROP SURVEY, POH. 12/01/93 ( 7) TD:10686' ( 139) 12/02/93 (8) TD:11225' ( 539) 12/03/93 (9) TD: 11225' ( 0) DRLG MW:10.0 VIS: 69 PU ASSY, RIH. INSTLD RUBBERS ON DP. TIGHT HOLE. WASH & REAM. DRLD TO 10686. WORK TIGHT SPOT MW:10.0 VIS: 61 DRLD TO 11225. CBU, SHORT TRIP. POH. CBU, RECIP. POH FOR LOGS. TIGHT SPOT. CBU. POH, WORK TIGHT SPOT. RIH STRIPPING OVER E-LINE MW:10.0 VIS: 64 CONT WORK TIGHT SPOT. RIH, CBU. RECIP. POH. PUMP DRY JOB, POH. RU & RUN LOGS. POH. RU FISHING STRIPPING TOOLS, RIH OVER E-LINE. RECEIYED FEB ! 1994 ijil & Gas Cons. CorHmissior: Anchorage WELL : DS14-02A OPERATION: RIG : DOYON 16 PAGE: 2 12/04/93 (10) TD:11225' ( 0) 12/05/93 (11) TD:11225' ( 0) 12/06/93 (12) TD:11225' ( 0) 12/07/93 (13) TD:11225' ( 0) 12/08/93 (14) TD:11225' ( 0) 12/09/93 (15) TD:11225 PB: 9161 01/04/94 (16) TD: 9657 PB: 9657 01/05/94 (17) TD: 9390 PB: 9657 POH MW:10.0 VIS: 66 CONT RIH. CIRC, ENGAUAGED FISH. POH W/FISH. PU BHA & RIH. TAGGED WHIPSTOCK. POH. PUMP DRY JOB & POH. RIH MW:10.1 VIS: 62 POH, PU BHA & RIH. CBU, POH. LD BHA. RIH. KU & MILL CSG. POH. LD FISHING BHA. RIH. ATTEMPT TO FIND K/O PT. MW:10.0 VIS: 60 CONT TO RIH. PUMP DRY JOB & POH. RIH, WASH & REAM, POH. RIH, TAGGED BTTM OF WHIPSTOCK. ATTEMPT TO FIND KICKOFF PT. WOC TO TAG MW:10.1 VIS: 61 ATTEMPT TO K/O, NO LUCK. POH, LD BHA. TEST BOPES. PU EZSV & RIH. CIRC, TEST LINES. PUMP P+A CMT PLUG. POH, WOC FOR TAG. POH MW:10.1 VIS: 0 WOC. RIH. PUMP CMT. POH. WOC. RIH & TAG TOP OF CMT. POH. LDDP. RIG RELEASED MW: 0.0 KC1 POH, LDDP. FREEZE PROT. CONT POH. RU & LAND TBG HGR. ND BOPS NU TREE & TEST. SECURE TREE. RELSD RIG 21:00 HRS 12-08-93. POOH LD MW:10.1 KC1 MOVE IN. RIG ACCEPTED 1-2-94 @ 1700 HRS. LOAD PIPE SHEAD. PU DP & RIH. DISPLC MUD. MIX & SPOT PILL. POH, CIRC. POH, LDDP. MILL SECTION MW:10.2 KCl POH FOR SECT MILL RUN W/BIT. PU MILL & RIH. BEGIN MILLING SECTION. RIG ENGINES TRIPPING OFF LINE, PU & CIRC. 01/06/94 (18) TD: 9411 PB: 9657 CMT KO PLUG MW:10.3 KCl MILL TO 9411. PUMP SWEEP, CBU. POH, RIH W/CIRC. REV CIRC. WASH TO 9510. CIRC, RU, MIX CMT. CMT KICK-OFF PLUG. 01/07/94 (19) TD: 9411 PB: 9657 RIH W/ KO ASS'Y. MW:10.1 KC1 DISP BALANCED KO PLUG. POOH 15 STDS. SQZ CMT TO 1000 PSI. SQZ'D AWAY 1 BBL. POOH. TEST BOPE. RIH W/ KO ASS'Y. RECEIVEg r. EB 1 i 199 Gas Cons. Col'nmissior, Anchorage WELL : DS14-02A OPERATION: RIG : DOYON 16 PAGE: 3 01/08/94 (20) TD: 9560' ( 0) 01/09/94 (21) TD:10157' ( 597) 01/10/94 (22) TD:10157' ( 0) 01/11/94 (23) TD:10500' ( 343) 01/12/94 (24) TD:10829' ( 329) 01/13/94 (25) TD:l1035' ( 206) 01/14/94 (26) TD:11755' ( 720) DIRECTIONAL DRILL MW:10.0 VIS: 40 RIH W/ KO ASSY. INSTALL RUBBERS ON DP F/ CSG PROTECTON. WASH DOWN TO CEMENT FROM 8967 TO TOC @9158'_ DRILL CEMENT FROM 9158-9366' CBU. CLEAN PITS & FILL W/ NO GEL BIOPOLY MUD. POUMP 40 BBL SEAWATER PREFLUSH & DISPLACE WELL W/ NEW MUD. ORIENT & KICK OFF WELL. DIRECTIONALY DRILL, ROTATING & SLIDING. DRILLING 8.5" HOLE MW:10.2 VIS: 50 DIRECTONAL DRILL, SLIDING & ROTATING FROM 9552-9808'. CIRC, SURVEY. POH, SHORT TRIP TO SHOE @ 9366'. DRILL AHEAD FROM 9808-10158' CIRC. SHORT TRIP TO SHOE @ 9366' DRILL TO 10190' RIH W/ MOTOR & BIT MW:10.2 VIS: 64 DIRECTIONAL DRILL, SLIDE & ROTATE FROM 10190 TO 10351'. CBU, 105 STKS. POH TO SHOE @ 9366'. CUT & SLIP 57.5' DRILL LINE, PUMP DRY JOB. POH FOR BIT #2 & MWD TOOL. CHANGE OUT MWD TOOL & BIT. TEST MWD. RIH, FILL PIPE @ 3000' INTERVALS. MOVE SP RUBBERS 1000' UP DRILL STRING. DRILLING W/ MUD MOTOR MW:10.2 VIS: 76 RIH W/ BIT #3, MOVE DP RUBBERS 1000' UP DRILL STRING. ENCOUNTER TIGHT HOLE @9670' PUMP OUT SINGLES OF DP TO 9542', WASH & REAM TO 9808' HOLE CONDITIONS IMOROVED, RIH TO 9914' STUCK PIPE F/ 1 HR JAR UP TO 9858' PIPE FREE, CIRC & WORK PIPE. REAM 10 JTS DP TO BTTM, FROM 10051-10351' REAMING WAS NOT A PROBLEM, HOLE SEEMS TO BE IN FAIR SHAPE. TAKE SURVEYS @ 10199', 10231', 10261', & 10293' TO CHECK ANADRILL TOOL. DRILL AHEAD W/ DIRECTIONAL ASSY F/ 10351-10500'. P/U LOCKED ASSY TRIP IN MW:10.1 VIS:120 DIRECTIONAL DRILLIN F/ 10499-10829' CIRC BTTMS UP. TRIP OUT TO SHOE TIGHT. PUMP DRY JOB. TRIP OUT. LAYED DOWN MTR & MWD. PICK UP LOCKED UP ASSY TRIP IN. DRILLING @11035' MW:10.0 VIS: 66 TRIP IN HOLE. MOVE RUBBERS UP 500'. FILL PIPE @6435 & 9360'. CIRC & COND MUD @9360' SHOE @9366' TRIP IN TO 10416 BREAK CIRC & WORK PIPE. TRIP IN TO i0445' TIGHT WORK THRU TIGHT SPOT. WASH & REAM TO BTTM AT 10829, TIGHT & ATTEMPTING TO PACKK OFF. BOTTOMS UP RECOVERING LARGE AMOUNTS CUTTINGS OVER SHAKER. DRILLING FROM 10829-11035' DRILLING DRILL FROM 11035-11339' 11339-11755'. MW:10.1 VIS: 53 SHT TRIP 6 STDS. DRILL F/ RECEIYED '~3 '! 'l 199 4 Gas Dons. Commission Anchorage WELL : DS14-02A OPERATION: RIG : DOYON 16 PAGE: 4 01/15/94 (27) TD:11755' ( 0) 01/16/94 (28) TD:11755' ( 0) CUT DRLG LINE MW:10.1 VIS: 54 CBU, SHORT TRIP. CIRC & RECIP. RUN SURVEYS. RU & RUN LOGS. PULL WEAR BUSHING & TEST BOPE. TIH, CUT DRLG LINE. RIH LOG OPEN HOLE MW:10.1 VIS: 63 WASH & REAM TO BTTM. CBU. TRIP OUT, RU & RIH LOG OPEN HOLE. 01/17/94 (29) TD:11755' ( 0) 01/18/94 (30) TD:11755' ( 0) 01/19/94 (31) TD: 0 PB: 0 01/20/94 (32) TD:11755 PB:ll600 01/21/94 (33) TD:11755 PB:ll600 TRIP OUT RUN LINER MW:10.0 VIS: 68 TIH W/LOGS. TOH, LD TOOLS. PU BHA, TRIP IN, BREAK CIRC. REAM. CIRC & RECIP. TRIP OUT FOR LINER. CMT LINER MW: 9.5 VIS: 50 RU & RUN LINER. CIRC. TRIP IN, WORK PIPE. MIX MUD & WORK PIPE. CMT LINER. TRIP OUT TO LOG MW:10.1 KC1 TEST CMT LINES. DISPLC CMT, BUMP PLUG. SET PKR, RELS LINER, CBU. TRIP OUT, TEST PKOFF. PU BHA, DRL CMT. TEST CSG. DRLD TO 11600. CIRC. TRIP OUT TO LOG. TRIP IN BIT & CSG SCPR MW: 9.2 KC1 RU & RUN LOGS. RD, TEST PKR. TRIP IN SET & TEST CSG. SET SEAL ASSY & PKR. PUMP PILL, TRIP OUT. PU BIT & CSG SCRPR, TRIP IN HOLE. TEST LINER MW: 8.5 Seawater CLEAN PITS, TAKE ON SW. TEST CSG. TRIP OUT. REPLACE RAMS. TRIP IN, TEST CSG. TEST LINER. 01/22/94 (34) TD:11755 PB:ll600 CIRC MW: 8.5 Seawater PERFING. RU & RUN PKR. TRIP IN. CIRC TO CLEAN HOLE. CIRC THROUGH PERFS. SPOTTED ACID ON BTTM. MOVING ACID UP ANNULUS. 01/23/94 (35) TD:11755 PB:ll600 01/24/94 (36) TD:11755 PB:ll600 01/25/94 (37) TD:11755 PB:ll600 TRIP OUT MW: 8.5 Seawater TEST LINER. TRIP OUT. PU TEST PKR & SET. TRIP OUT TO CHG PKR. TRIP IN. SET PKR, TEST. TEST CSG. LEAK IN CSG. TRIP OUT. REDRESS & RERUN PERF GUNS MW: 8.5 Seawater TRIP OUT LD TEST PKR. TEST BOPE. TAG BTTM, WASH TO 11600. DRLD CMT TO 11608. REV CIRC HOLE CLEAN. RU & RIH W/PERF GUNS. TRIP IN HOLE MW: 8.5 Seawater REV CIRC. PUMP CMT, DROP PLUG. TRIP OUT, PU BIT & RIH. TRIP IN HOLE, PULL & LDDP. BREAK CIRC. CBU. POH, TRIP IN HOLE W/CSG SCRPR. ECEIVED :~'-~-'~!~.. ] I 1994 ,,,. ~',~:~ ~,,, a (las (;r)ns. Oommisslor: Anchorage WELL : DS14-02A OPERATION: RIG : DOYON 16 PAGE: 5 01/26/94 (38) TD:11755 PB:ll600 MU CONTROL LINES MW: 8.5 Seawater TRIP IN, REV CIRC. TRIP OUT, LDDP. RU & RUN COMPLETION. MU CONTROL LINES. 01/27/94 (39) TD:11755 PB:ll600 RELEASE RIG MW: 8.5 Seawater RUN COMPLETION. SET BPV, ND BOPS, NU TREE & TEST. FREEZE PROT WELL. RD. RELEASE RIG 1-26-94 @ 24:00 HRS. 01/28/94 (40) TD:11755 PB:ll600 EXTRA COST NO SUMMARY AVAILABLE. MW: 8.5 Seawater SIGNATURE: (drilling superintendent) DATE: Gas Cons. Cornmission Anchorage SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 PRUDHOE BAY DRILLING PBU/14-2B 500292031802 NORTH SLOPE COMPUTATION DATE: 1/18/9 DATE OF SURVEY: 011494 ORiGII, iAL JOB NUMBER: AK-EI-40004 KELLY BUSHING ELEV. = 67.60 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 9350 7747.00 7679.40 44 16 9401 7783.71 7716.11 43 38 9496 7849.24 7781.64 49 7 9591 7908.37 7840.77 53 52 9687 7963.02 7895.42 56 43 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. N 2.56 E .00 3991.00N 470.00W N 1.83 E 1.60 4026.37N 468.64W N 2.40 W 6.61 4095.09N 469.10W N .89 E 5.70 4169.39N 470.01W N 1.02 E 2.96 4248.30N 468.69W 3944.12 3979.50 4047.98 4122.01 4200.79 9783 8015.12 7947.52 57 31 9879 8066.17 7998.57 58 13 9974 8115.63 8048.03 59 1 10070 8165.10 8097.50 58 56 10166 8214.99 8147.39 58 26 N 1.20 E .86 4328.91N 467.13W N 1.77 E .88 4410.18N 465.02W N .06 W 1.85 4491.27N 463.82W N 2.30 E 2.11 4573.51N 462.21W N 3.27 E 1.01 4655.43N 458.23W 4281.28 4362.48 4443.43 4525.56 4607.54 10263 8265.41 8197.81 58 54 N 2.84 E .61 4738.17N 453.81W 10359 8315.82 8248.22 57 44 N 2.90 E 1.22 4819.76N 449.72W 10455 8366.94 8299.34 57 54 N 4.79 E. 1.68 4900.83N 444.27W 10551 8418.31 8350.71 57 23 N 5.13 E .62 4981.62N 437.26W 10646 8470.06 8402.46 56 35 N 6.84 E 1.73 5060.84N 428.96W 4690.38 4772.05 4853.29 4934.39 5014.01 10742 8522.47 8454.88 57 13 N 7.65 E .97 5140.63N 418.82W 10838 8574.05 8506.45 57 46 N 8.35 E .84 5220.81N 407.55W 10933 8625.55 8557.95 ~56 33 N 8.40 E 1.29 5299.78N 395.92W 11027 8678.16 8610.56 55 21 N 8.52 E 1.28 5376.82N 384.46W 11121 8732.09 8664.49 54 37 N 7.48 E 1.19 5453.06N 373.74W 5094.33 5175.13 5254.76 5332.44 5409.28 11217 8788.31 8720.71 53 39 N 5.64 E 1.85 5530.34N 364.85W 11313 8845.83 8778.23 52 43 N 3.43 E 2.09 5606.95N 358.76W 11409 8904.61 8837.01 51 46 N 3.13 E 1.02 5682.72N 354.42W 11504 8963.92 8896.32 50 57 N 4.22 E 1.24 5756.77N 349.67W 11600 9025.16 8957.56 49 45 N 1.85 E 2.28 5830.57N 345.74W 5487.01 5563.86 5639.74 5713.94 5787.83 11695 9087.30 9019.70 48 31 N 1.75 E 1.30 5902.39N 11724 9106.56 9038.96 48 15 N 1.68 E .95 5924.06N 343.48W 5859.61 342.83W 5881.27 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5933.98 FEET AT NORTH 3 DEG. 18 MIN. WEST AT MD = 11724 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 4.33 DEG. RECEIVED (}as (;mis. 6ornmissior: Anchorage SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PBU/14-2B 500292031802 NORTH SLOPE COMPUTATION DATE: 1/18/94 DATE OF SURVEY: 011494 JOB NUMBER: AK-EI-40004 KELLY BUSHING ELEV. = 67.60 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 9350 10350 11350 11724 7747.00 7679.40 8311.02 8243.42 8868.24 8800.64 9106.56 9038.96 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 3991.00 N 470.00 W 1603.00 4812.16 N 450.11 W 2038.98 435.98 5636.33 N 357.00 W 2481.76 442.77 5924.06 N 342.83 W 2617.44 135.68 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/14-2B 500292031802 NORTH SLOPE COMPUTATION DATE: 1/18/94 DATE OF SURVEY: 011494 JOB NUMBER: AK-Ei-40004 KELLY BUSHING ELEV. = 67.60 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 DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 9350 7747.00 7679.40 3991.00 N 470.00 W 1603.00 9378 7767.60 7700.00 4010.97 N 469.16 W 1611.10 9524 7867.60 7800.00 4116.88 N 469.80 W 1656.91 9695 7967.60 7900.00 4255.28 N 468.57 W 1727.75 8.10 45.80 70.85 9881 8067.60 8000.00 4412.48 N 464.95 W 1814.11 10074 8167.60 8100.00 4577.66 N 462.04 W 1907.25 10267 8267.60 8200.00 4741.79 N 453.63 W 1999.63 10456 8367.60 8300.00 4901.87 N 444.18 W 2088.64 10641 8467.60 8400.00 5057.13 N 429.41 W 2173.93 86.36 93.14 92.38 89.00 85.29 10825 8567.60 8500.00 5210.68 N 409.03 W 2258.31 11008 8667.60 8600.00 5361.70 N 386.73 W 2340.81 11182 8767.60 8700.00 5502.32 N 367.62 W 2414.44 11348 8867.60 8800.00 5635.49 N 357.05 W 2481.34 11509 8967.60 8900.00 5761.29 N 349.33 W 2542.24 84.38 82.51 73.63 66.90 60.90 11665 9067.60 9000.00 5880.11 N 344.16 W 2597.65 11724 9106.56 9038.96 5924.06 N 342.83 W 2617.44 55.41 19.79 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS RECEIVED FEB 3'1 199 i~,i~ka Oil & Gas Cons. Commis~ior: Anchorage P~E ~. IdI3LL HEAD LOC~TIOH; LAT(IV-S) 0.00 AZIt~ FROM ROYdW~Y T~I~ TO T~ IS TIE IN POINT(TIP) ~ DEl:TH TRU~ ~ERT INCLIHATION AZIMUTH ~TI11.11~(1~-$). ~HPARTt~(E/-W) 9350,00 7747.11 44.28 2,56 3990,64 -467,76 M~(£/-W) 0.00 Gas Coils. Commission Anchorage .., 2 PS 14-02~ DEPTH DEPTH ft ft ft 9350,00 0o0 7747,11 9657.33 307.3 7942,30 9689.57 32.2 7960.01 9721,67 32,1 7977.71 '7/52.70 31.0 7994,76 9783,22 30.5 8011.21 9815.23 32.0 8028,20 9847.70 32,5 8045.44 9878.73 31,0 8061,91 9910,96 32,2 8078,80 9943,24 32.3 8095,~ 997t.72 28,5 8110,21 10003.62 31,? ~i26,69 10037.9~ 34.4 8144.5.1 100~9.85 31.9 ~8161.15 10101.33 31.5 8177.49 10134.61 33.3 8194.74 101/~.8~ 32.3 10199.35 32.5 8228.18 10231.81 32.5 _8244°80- 102&3.70 31.9 fl261.19 10293.51 2%8 10325.53 32.0 10357.75 .32.2 -{{310.8~ 10389.87 32.1 8327.~ 10422.08 32.2 8345.16 10454.31 32.2 83~2.49 10485.62 31.3 ~]79.42 10517.72 32.1 8396,84 10550.06 32.3 8414.37 10581.49 31.4 &431.42 10~13.89 32.4 8449.11 10M5.37 31.5 8466°44 10676,91 31.5 10709.03 32,1 8501.50 10741.30 32,3 8518.9~ 10772.60 31.3 8535,84 TN{GET STATION P. ZIIV. ml 5ELTION IICLH. it de~ deg ~,78 ~,28 41~.16 ~,69 1.~ ~7,~ ~,~ 1,94 4~9,74 ~.90 I~ITUDE BEPARTI~ DISP~ at AZIW. rI~ i)L9 F,/-W ft ft ft de9 lOOft 3990.64 -469,76 4018,19 353.29 4227,14 -442,53 4252°3? 353,76 4254.5 -461.82 4~79,05 3~3.80 2,25 4280.82 -460.7i 4305.54 353.&5 2.26 43~.71 -459.34 4331.14 353.91 4285.44 57,86 3.42 4312.57 58,02 4.05 4'~I0,08 57,83 4,07 4366,37 58,03 3,71 4393,82 58.7& 2,19 43'32,37 -457.83 4356.50 353,97 435~.4~ -456.0~ 4383.24 3~h03 4386.89 -454.12 4410,33 354.09 4413.12 -452.33 4436,24 354.15 4421.42 ~.91 4445.78 ~8.92 44~.07 58,fl8 4502.41 58.51 4~29,57 ~8.67 1.60 44~.15 1.53 4'{~Y2.53 1.88 4519.83 2.38 454%17 3.09 -4F76,~ -450.0! 4490,75 354,25 -449,35; 4514.95 354,29 -448,53 4542,04 354.33 -447,44 4571.12 354,38 -44~.14 4598.03 354.43 4556,48 58,78 4584.94 58,78 4612,54 ~8,82 4640.37 59,19 4668,24 5~,24 3.15 4603.~ -444.~ 4624.&3 354.48 3.55 4631.4! -443.01 4~5'2.75 354.54 2.96 4659.17 -441.44 41:.fl0.03 354.59 2.97 4686,W -440.00 4707.57' 354.64 2.59 4714.82 -438,65 4735.18 354,68 ,1~95.59 58,90 4721.00 58.18 4748.13 5'7.82 477~.42 '57.92 4802.~ 57.78 3.20 4742, PI -437,27 4762,26 354.r3 .1,53 47~,54 -436.22 4787.46 3~.77 2.83 4794.~7 -435.18 4814.38 354.81 3,23 4821.92 -433,74 ' 4841.3~ 354.~6 4.33 4849.0~ -431.95 48&8.26 354,91 4829.83 57.62 4857.01 57.34 4883.34 57.17 4910,31 57.12 4937.48 57,24 3,60. 4876,22 4,63 4903,33 4,02 4729,,56 3,74 4~.,6,4~, 4,24 4983,59 -430.0~ 4895.15 3FYI.?6 '428.11 4921.98 355.01 *~426.13'' 4947.96 355.06 -424.30 4974,62 355,11 -422.41 5001,46 355,16 49~,89 57.07 4~91.02 5~.72 5017.30 5~.49 5O43.58 5~.45 ~70.~9 5~.96 3.94 5009.94 -420.53 5027.56 355.20 3.39 5037.02 -418.7~ 5054.40 355.25 4.84 50~3.23 -416.91 5080.37 355.29 7,28 ~,37 -414.13 5106,20 355.35 7,99 5115.~' -410.5b 5132.43 355.41 5(~7,46 57,40 7,10 5:142,87 5123,80 57.44 7.39 5169.0~ -407,0O 5158,95 355,48 -403,69 5184,77 35'5.53 1.~ 0,20 0,~ 1.64 1.97 0,39 1,02 1,5~ 1.15 1.00 1,94 1,08 2,~ 1.98 2,82 1,73 0,74 1.33 0,94 1,80 3,92 6,44 2.44 2,69 0.64 ................................. N ......... N .... N ...... X i~i~ FI~E BAT ])RLG l~ I~ ~ 14-028 LOCATION 1 ]X~IL]~IT~ 14 L~TION 2 F~ I~T, ~ ~1T: 12-J~-74 I~1~ 0 RECEIVED G~s (;ans. Corrlmission Anchorage ..,, 2 ])S 14-07.B ft TVI) I~JHG OJ~INC_C{~ I_P~TE P~i_CHG D. flP~=CH~ TL~H_R~TE CLOSU~ TOOL_FACE ft deg dKj deo/lOOft deo d~ dc~/lOOft ft deo deo,/lOOft deg/lOOftK~2 9350.0 7747.11 0,00 0,00 0,00 0,00 0o00 0.00 9657,3 7942,30 12.41 12,4I 4,04 -1,48 -1,48 -0,48 9689,6 7960.01 -0.0~ 12,35 -0,18 0.86 -O,&2 2,68 9721.7 7977,71 -0.17 12,18 -0,52 0,85 0,23 2.64 9752.7 7994.76 0+44 12.62 I.41 0.51 0,74 1.65 769.71 0,00 0,00 0.00 780,36 5J5 4,05 1.32 781.68 94.73 2.25 5,6I 182,60 103,54 2,26 0.00 0.00 1.97 0.93 9783,2 8011,21 0,96 13.58 3,15 0,12 0,86 0.39 9815,2 8028.20 0,16 13,74 0.51 0.63 1,49 1+97 9847,7 8045,44 -0,~ 13.55 -0,61 0,02 1,51 0,06 9878,7 8061,91 0.20 13,75 0,66 -0,36 1.15 -1,17 9911o0 8078+80 0,75 i4.50 2,33 -1,52 -0,37 -4.71 9943,2 8095,50 0,13 9971,7 8110,21 0,01 10003,6 8126,69 -0,04 10038,0 8144,54 -0.37 10069,8 8161,15 0,15 14.63 0,39 -0,59 -0.96 -1,82 14,64 0,03 -0,07 -1,03 -0,24 14.60 -0,13 0,35 -0.68 1,10 14.23 -1.07 0.50 -0,18 1,46 14.39 0.49 0,71 0.~ 2.23 783,62 5,85 3,16 3,90 783,90 73.14 1.75 4.43 784,03 177.63 0.62 3,48 784,24 56.33 1.18 1.83 783,19 44,45 4,64 10,72 786,08 76.00 1.60 9.40 787.25 79,79 0.20 4.95 788.50 97.76 0,95 2,35 789.63 130.65 1,64 2.02 784.90 60.21 1,97 1,03 10101.3 8177,49 0,11 14,50 0,36 0,06 0,59 0,19 10134,6 8194,74 0,01 14.50 0,02 0.40 0.99 1,19 10166.9 8211,46 0,03 14.54 0,10 -0,59 0,40 -1,82 10199,4 8228.18 0.37 14.91 1,15 0.01 '0.41 0,02 10231,8 8244.80 0.05 14.96 -0.16 -0,37 0,03 '1,15 7~0,95 23.64 0,39 5,01 791.43 89.19 1.02 1.88 791,~ 86,61 1.56 1.67 792.62 0,00 1,15 .1,27 790.38 75.91 1,00 0,46 10263,7 8261,19 -0,34 14,62 -1,06 0,61 0,64 1,90 10293.5 8276.75 -0,72 13,90 -2,42 -1.67 -1,03 -5,61 10325,5 8293,72 -0,36 13,54 -1,13 1,3t 0.27 4,08 10357,8 8310.86 0.11 13.64 0.33 0.39 0.67 1,22 10389,9 8327.95 -0.15 13.50 -0,46 1,10 1.77 3.44 794,05 123.27 1.94 2,96 794,92 117,29 5,36 11.46 7~.94 108.41 3~4' 5.38 796,56 72.46 1,08 7,92 793.37 81,12 2,95 10422,1 8345,16 -0,15 13,34 -0,48 -0.73 1,04 -2,27 10454,3 8362,49 -0.28 13,06 -0.87 1,02 2,07 3.18 10485.6 8379,42 ..0+17 12.89 =0.56 -0,61 1,46 -1,94 10517,7 8396,84 -0+05 12.84 -0.16 -0.27 1,18 -0.86 10550,1 8414,37 0,12 12,96 0.37 0.49 1,68 1,52 10581,5 8431,42 -0;17 12,79 -0,53 -0.29 1,38 -0,93 10~13,9 8449,11 -0.35 12.44 -1,09 -0.55 0,83 -1.70 10645,4 8466,44 -0.23 12.21 -0+72 1,45 2.28 4+62 I0~76,9 8483,8~ -0.04 12,17 -0,13 2,44 4,72 7.72 10799,0 8501.50 0,51 12,68 1,59 0,71 5,43 2,21 796,99 104,09 1,98 3.00 797.10 108,21 2.82 2.59 797.10 109,01 1,73 3.48 797,31 102,37 0.74 3,08 ~6,82 9%30 1,33 1,82 797.59 124.65 0.94 1.24 7F~.90 127,50 1,80 2,64 798.00 100.~ 3.~2 6.75 797.20 91.79 6,44 7,98 7~7.47 73.83 2.44 12,46 10741,3 8518,99 0,44 13,12 1.3~ -0,89 4,54 -2,76 794,13 59,81 2,69 0,79 10772,6 8535.84 0,04 13,16 0,12 0.23 4,77 0,75 792.80 79,62 0,64 6,55 .......... M ............... K ................................... ~ ......... ku/~/dHHHPZ~/Y~tH~ .............................. M ECE VEC '"EB 't '1994 , Gas Or)ns. 6omrnissior: Anchorage P~E ~. CO~)~A~4Y PRUIN40£ DAY DRI,C ~LL HAME ~ 14-02D LOCATIDH 1 ])RILLSITS 14 I,OP_,A~ 2 PRt.q)HOS BAY~, AZ ~IC DECLINATION ~oDO 12-JAI4..?4 k']~I, ~ 0 ~LL ~ LOCATION,- LAT(H/-S) 0,00 ~Ii~J']tt FRO~ ROT~'Y T/L~Z TO T~ IS TIE IN POINT(TIP) : tISAStJFUID ])BplmH TR~ UERT ~ INCLINATION AZlrILrTH I, ATITUDIi(H/-S) ])~ARTURE(B/-W) 9350.00 7747.11 44,28 3990,&4 -467,76 D~(E/-W) 0.00 RECEIVEg FEB '~ 't 1994 ·/-,i2~sk2, Oil & Gas Grins, C:)~lmissior' Anchorage ~PTH ~Eql~ ft ft ft F350,00 0.0 7747ott %57,33 307,3 7942.30 ' Y]52,70 ~.4 7~4.53 9H7o70 95.0 8045,76 ~43,24 ~,5: &095,88 10037,~ 94,7 8145,~ 10t34,61 96,6 8i95.36 I0~i,81 97,2 8245o41 1039,53 93.7 8294,33 104~,08 96,6 8345,90 1~17,72 ~,6 8.397,47 -10613,8? 96.2 8449,96 10645,37 31o5 8467,29 10772,60 127,2 8536o~ ft cleo deg ft 3943.78 44,28 2.56 3990.64 4180,16 56.69 1.08 4227,14 4259.88 56,90 3.30 4306.87 4339,87 5'7,83 4.07 4386,70 4421,18 58,91 '1,60 44~7,93 LATIIUI)E D~AR'fl.~ DIb"P~ at FJ-W ft ft -469,76 4018.19 -~2.53 4252.37 -~9,48 4331,31 -454,M 4410,16 4502,08 58,51 2,38 4548,85 45M,57 58,78 3,55 4631,25 46~7,fl8 59.24 2.59 4714,46 4747.77 5'7,82 2,83 4794,~ ~29.39 ~,62 3,60 ~,BO AZ. II,ILlTH DIS 353.29 0.00 353.76 4,05 353,9! t,96 354,0? 1,t9 354,24 2,47 4907.~ 5'7,12 3,74 4956,18 4990,49 ~,~ 3,~ ~)36,60 5016,78 ~,~ 4,84 50~2,8t 51~,:37 57,44 7,33 51(>8,86 -43fl.78 4734.83 -435.00 ~13.~ 354,82 t.53 -430,41 4894,76 354.96 0,70 -425.25 4974.3? -420,24 --5054.10 -418,35 5080.07 -407,03 5184,&6 355,10 0,54 355,23 0,52 ;35"5.28 3,92 35,50 1,80 Oil & Gas Gons. Gommissior' Anchorage P~£ HO, 1 P.,]~NY FgJD~E B~Y I)RU; ~LL ~ I~ 14-0~ U2)C~TI~ 1 I)RILLSITE 14 U3C~TION 2 RaJI)iN3~ ~Y~ AK - i~YE: 12-,I~-74 .WELL ~ RECEIVEC FEB '! 'l 19~q/-',- Ui! & Gas Cons. Cornmissior: Anchorage ~-q 14-02B MI) TW I~_lZH~ OJMI~_C1~[; I_~TE AZ,_IYIi; O.elaZM_O~; TUR~_F~ITE ~ TOOL_FACE l)L,q I)LSST ft ft deg deg deg/lOOft deg deg deg/lOOft ft deg deg/lOOft deg/lOOft**2 9350,0 7747,11 0,00 0,00 9657°3 7942.30 12,41 12,4! 97:52,7 7994,53 0,21 12.62 9847,7 8045,76 0,93 13,55 9943,2 8095,88 1,08 14,63 0,00 0,00 0,00 4,04 -1,4~ -1,48 -0,48 0,23 2,22 0,74 2,33 0,77 0,77 1,51 0,81 1,13 -2,47 -0,96 -2,58 769,71 0,00 0,00 0,00 780,36 5,75 4,05 1,32 783,34 84,03 1,96 2,19 784,24 35,14 1,19 0,82 0,00 0,00 2,47 1,35 I0038,0 8145,09 -0,40 14,2:3 -0,42 0.78 -0,18 0,83 10134,6 8195,36 0,27 14,50 0,28 1,17 0,99 1,21 10231,8 8245,41 0,45 14,96 0,47 -0,96 0,03 -0,98 10325,5 8294,33 -1,42 13,54 -1,52 0.24 0,27 0,26 1~22,1 ~5;,?0 -0,20 . 13,34 -0,20 0,77 1.04 0,79 789,68 120,85 0,82 1,74 791,64 74,fl 1,07 0.26 793,47 61,23 0,96 0,11 795,73 171.89 1,53 0.61 786,37 63,39 0,70 0,86 10517,7 8397,47 -0,50 12.84 -0,53 0o14 1,18 0o15 798,23 166.49 0.54 0.17 10613.9 8449,96 -0,40 12,44 -0,42 -0,35 0,83 -0,37 79%31 143.60 0,52 0,03 10645,4 8467,29 -0,23 12,21 -0,72 1,45 2,28 4,62 79%40 100,99 3.92 10,81 I0772,6 8536,66 0,~ 13,16 0,74 2,49 4,77 1,96 796,12 66,30 1,80 1,67 RECEIVED .~.!~:31~ Oft & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIt.,,'~ OVALS APPLICATION FOR SUNDRY APPR Suspend Operation Shutdown Re-enter suspended well Plugging Time extension Stimulate Pull tubing __ -- Variance__ Other 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. Abandon Alter casing __ Repair well __ Change approved program x 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1262' SNL, 1228' WEL, SEC. 9, TION, R14E At top of productive interval 4303' NSL, 1568' WEL, SEC. 4, TION, R14E At effective depth N/A At total depth 4420'NSL, 1559' WEL, SEC. 4, TION, R14E 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service Perforate 6. Datum elevation (DF or KBi ~'/ KBE = 67.6 ',,feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-02B 9. Permit number 93-200 10. APl number 50- 029-20318-02 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) feet feet feet feet Size Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth RECEIVED JAN 1994 A!aska 0il & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 1/3/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby cer)ify that the fore)going is true and correct to the best of my knowledge. SignedI//,/~.x[, ~!~ Title Drifting Engineer Supervisor ' ~"(/. ' ) ~' FOR COMMISSION USE ONLY Conditions of app?lSval: NoJ~fy Commission so representative may witness Plug integrity __ BOP Test__ Location clearance__ Mechanical Integrity Test__ Subsequent form required 10- ,4 c~ 7 Original Signed By Approved by order of the Commission David W. Johnston Form 10-403 Rev 06/15/88 I Appr°val / _~pproved Copy Return(~¢l. Commissioner ~a //~./qV SUBMI~ I~ TRIPLICATE PBU Well 14-02B Permit Number: 93-200 APl Number: 50-029-20318-02 Change of Well Program The desired target location planned for PBU well 14-02B has been changed slightly since the sidetrack was permitted on 12-22-93. Because the desired target location was changed, the kick off point, tangent angle, and bottom hole location also have changed slightly. The proposed changes for approval are shown below. 1) Kick off point: changed from 9450' MD to 9350' MD. 2) Target' changed from 4303' FSL, 1568' FEL at 8945' SS to 4303' FSL, 1568 FEL at 8755' SS 3) BHL: changed from 4420 FSL, 1559 FEL at 9038' SS to 4712 FSL, 1536' FEL at 9028' SS 4) Casing Depth' top changed from 9300' MD/7711 TVD RKB to 9200' MD/7640' TVD RKB. bottom changed from 11525' MD/9105' TVD RKB to 11755' MD/9096' TVD RKB. A new directional plan is attached. RECEIVED JAN -.:5 1994 Alaska Oil & Gas Cons. Commission Anchorage 10:49 FROM GRERI LHND/HNHDMILL IU H~U bNUiNbbNb H,UJ [ PRUOHOE BAY DRILLING GROUP -- ...i..,, .. ii ....... i i ill i i i ~ ~ · · i1 i ii ~, ~,~-~/~o? ~o -,~ ~,, ,,.~ DS ~4-02B P3 ~) ~,oo¢~/~ooc,,,~ ~ ~ ,~oo ~.;~ VERTICAL SECTION V!EN O) TD ~755 ¢096 5934 5~.~g ,Section a(: TVD ScaZe.' ~ ~nch = 50O .....Dep Scale.' ~ ~nch ~ 500 feet 6500 I 6750-- 7000 ...... x ~ ' ' ,,. , 7250- x ~ I , I ~ 7750 ........... ~ ....] i ...... ~ .................. 8 8ooo-. ~ ' ' .... ~ · ..~ % = . . . , -.~-.- ~. ~ I I ' 8750 .................. , .............. · ~ ~. ~r ~/~ ~r ........ r ...................... ~ ..... 9500- - I ,. , ! ~ ~ ". j., ,.. , 9750 ......... J ~ ,oooo- ~ I ! , I RErE VE , J N ~--~ 1994 ' ' [,~ : Anchor~ge---ri ~o~oo . I [ ..... I ... 3000 22~0 ~500 3750 4000 4850 4500 4, -0 5000 ~250 5500 5750 6000 6250 8~00 Section I~J~] Ic)~3 ~3 ~,5~ J0:23'~ ~ ' ' ' ....... 10:49 FROM GREAT LAND×ANADRILL TO PBD ENGINEERS P.06 t .................. PRUD'ROE DRILL I NG GRD-U.,.,p " ii ................. ii , illll, ii , V,~rker[dentific~t, ion MO N/S E/W DS ].4--02B (P3) ~) TI[-[N/KOP 9350 399! 47O 8) £NO OF 6/~00 CURVE 9553 4t46 6) fAR,3EI 11852 5566 353 PLAN VIE~ ~,~, D) TO 1~755 5975 322 'CLOSURE 598~ feet at Azimuth 356.~2 ;DECLINATION.' 29. 883 E ~SCALE - ~ inch ~ ~000 feet [DRAWN. '12/31/93 , . . AnaCj2] Schlumberger 6500~ ......... I ........... i: ........ .......... 6000 .... , ~ ... >50 FT T4fl~F~ ~nf~ .._ 5000--- ~ / .......... 4500 ...... I I 4000-- ~ ~ ..... '" 3000 .... ~, ~ -,, ~ · : ~[oo .................... ~ ...................... ' ~500 ......... ' .. . ' ,. L... ; " ~ ~~ ! I000 ....... ' ' ' ' elk IV~ , ~ : I A ~1 ;i .... 3500 3000 2500 2000 ~500 100 500 0 500 1000 1500 2000 2500 3000 3500 I~r~ Im~J ~ ~.~ ~o: ~a ~ fl : ' ......... ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 December 22, 1993 Terry Jordan Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 14-02B ARCO Alaska, Inc. Permit No: 93-200 Sur. Loc. 1262'SNL, 1228'WEL, Sec. 9, T10N, R14E, UM Btmhole Loc. 4420'NSL, 1559'WEL, Sec. 4, T10N, R14E, UM Dear Mr. Jordan: 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 by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) 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 by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. JohnSon ~ Chairman BY ORDER OF TH~ COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of work Drill [] Redrill E]Jlb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska,/nc. KBE = 67.6' fe et Prudhoe Bay Fie/d/Prudhoe 3. Address 6. Property Designation Bay Poo/ ?. O. Box 196612. Anchora(~e. Alaska 99519-6612 ADL 28312 4. Location of well at surf-ace :7. Unit or property Name 11. Type Bond(me 20 ^^c 25.025) 1262' SNL, 1228' WEL, SEC. 9, TION, R14E Prudhoe Bay Unit At top of .productive interval 8. Well number Number 4303'NSL, 1568' WEL, SEC. 4, TION, R14E 14-02B U-630610 At total depth 9. Approximate spud date Amount 4420'NSL, 1559' WEL, SEC. 4, TION, R14E 12/25/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in pro perty:15. Proposed depth (MD andTVD) property line ADL 28309-858' feet No close approach feet 2560 11525' MD/9105' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (,~, 2o AAC 25.035 (e)(2)) Kickoff depth 9,~5o feet Maximum hole angle ss o Maximum surface 3330 pslg At total deplh (TVD) 8800'/4390 pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity' of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# 13CR/ NSCC 2651' 9300' 7711' 11525' 9105' 460 sx C/ass "G" L-80 EC""' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary DEC 2 '1 199; Total depth: measured 11225 feet Plugs (measured) true vertical 9161 feet AIS, S~,,;~ 0il & Gas Cons. Commission Effective depth: measured 9657 feet Junk (measured) Anchorage true vertical 7962 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Co nd ucto r 120' 20" 675 sx ArcEcset II 120' 120' S u r face 2659' 13-3/8" 5904 sx PF I/ 2732' 2732' Intermediate Pro d u ct i o n 9 760' 9-5/8" 1000 sx "G" 9842' 7761' Liner Perforation depth: measured None true vertical !20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis I-1 Seabed reportl-I 20 AAC 25.050 requirements[] 21. I hereby certif~y that t~f~oreg,oing is true and correct to the best of my knowledge Signed¢~/'J~ Title Dr/I//nE Engineer Supervisor Date/~'-~'J-'~.~ Commission Use Only Permit Number v iAPi number IApproval date ISee cover letter '~X~_~) ~' - ~ ~ o J5 0-(_~__? ~., ~_%~, ';' /o-'"¢~', ~ ~ J /,¢,,~_-~ ¢~ ~,,~_..,~ Jfor other requirements Conditions of approval Samples required [] Yes ~ No Mud log required []Yes ~ No Hydrogen sulfide measures [] Yes [] NO Directional survey required ~ Yes [] NO Required working pressure for BOPE []2M; FI3M; 1~5M; I-I10M; I-I15M; Other: ,.i~'i¢~nai Signed By by order of Approved by ~.'~avid W, ,10hnston Commissioner zne commission Form 10-401 Rev. 12-1-85 Submit in tripli I Well Name: [DS 14-02B Redrill £Ian Summary [Type of Redrill (producer or in~ector): [ Producer tSurface Location: Bottom Hole Location: 4017 FSL 1228 FEL S09 T10N R14E UM 4303 FSL 1568 FEL S04 T10N R14E UM ,Target Location' 4420 FSL 1559 FEL S04 T10N R14E UM [AFgNumber: ]4J8014 [ Estimated Start Date: [ 12/25/93 I [TVD' [Rig: [Doyon#16 Operating days to complete' [9038'ss ] [KBE: [67.60' ] [ Well D.esign (conventional, slimhole, etc.): I sidetrack Objective: T° displace wellbore +600' north from the existing BHL to provide standoff from [ a Zone 4 fault. I Mud Program: A 9.5 - 10.00 ppg Biozan polymer/KCl water based mud will be used. ISpecial design considerations I none Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 9.5 10 15 5 10 10 0 5 tO tO tO tO tO tO tO tO tO 2Z)' 10.0 18 30 15 30 5 0 8 Directional: I KOP: 19450 Maximum Hole Angle:, I 52 degre.es Close Approach Well: NONE The above listed wells will be secured during the close approach. RECEIVED Aiaska Oil & Gas Cons. Commission Anchorage Redrill Plan Summary Page 1 Casing/Tubin Pro ram: Hole Size Wt/Ft Hole Size Csg/ Wt/Ft- Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8.5" 7" 29# 13CR/L80 NSCC 2651 9300/7711 11525/9105 Cement Calculations: I Liner Size: I Basis:I 50% open hole ex~ess, 40' shoe joint, 150' liner lap and 150' excess above line~- with DP. Total Cement Volume: 460 sxs of Class G Blend @ 1.18 ft3/sx Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Redrill Plan Summary RECEIVED DEC 2'1 199b A. iaska 0il a Gas Cons. Commission Anchorage Page 2 Objective: The primary objectives of this sidetrack are: 1) to remedy leaking sqz perfs, and 2) to relocate the borehole away from the faulting associated with the original well. Well 14-02 has been squeezed and re-perforated 5 times since it was drilled in 10/78. High GOR production was initially a result of cement channeling up to a Zn 4 fault cut in the wellbore at -.-8705' TVDSS. The squeezes have failed to deliver long lived Iow GOR oil production. An earlier attempt to sidetrack 14-02 was unsuccesful. E-Line I.ogs were obtained though, but after evaluation it was determined to abandone the original 14-02A location. Scope: 1) Mill window in existing 9 5/8" casing. 2) Set kickoff plug and drill 8 1/2" hole 3) Run full'suite of OH logs, GR/DLL/BHCS/CNL. 4) Cement 7,' liner in place. 5) Run4 1/2"tubing. Timing: Doyon #16 will be making a well to well move from well DS 14-01A to DS 14-02B on or about December 25, 1993. DS 14-02B SUMMARY PROCEDURE: 1. MIRU workover rig. Test intermediate packoff to 5000 psi. 2. ND dry hole tree. J NU BOP's. Install tree test plug. Test BOP's to 5000 psi. Pull tree test plug and BPV. . 4. Pull and lay down tubing hanger. , RIH with a 9-5/8" section mill and displace well to Xanvis milling fluid - spot 18 ppg hi-vis pill from PBTD at 9657' to base of proposed 9-5/8" section. Cut a @ 45' section in the 9-5/8" casing starting at +/- .9450' MD. POOH. RECEIVED A.l~ska 0il & Gas Oon$. Co~r~r~ission /~nchorage , . , o 10. 11. !2. 13. 14. 15. 16. RIH with open-ended DP. Mix and pump a minimum of 175 sacks of cement to spot balanced kick-off plug from 100' below the base of the section (@ 9550') to 200' above the top of the section (@ 9250'). RIH with ~-1/2" steerable drilling assembly and dress off cement to 5' below the top of section. Kickoff well and directionally drill to align well with target. Drill with a 8'1/2" directional assembly to total depth of 1 !525' MD/9105' TVD or 150' MD below the ,HO/T. Multi-Shot survey w/Sperry-Sun ESS on final trip out of the hole for AOGCC survey requirements. RU Atlas w/reline and Icg with the triple combo (GFFCNI._/BHCS/Micro SFL/DLL/4- Arm Caliper). In the event that tight hole conditions exist - reduce logging sonde length and perform 20.H. logging passes. Upon completion of logging make wiper trip prior to running 7" liner. (Note: Use four arm caliper to calculate your cement volumes) Run 7" 29# 13CR80 NSC(::) standard liner assembly to TD with liner top packer and +150' lap. XO to 7" 29# L80 liner +300' md above top of Sadlerochit @ 10808'md/8663' tvd. Liner top oacker and hanger assembly are to be plain 4140 grade carbon steel. Cement liner calculating cement volume by using information obtained from 4-Arm caliper run while logging. L/D extra 5" DP - that will not be required for clean out run. Use 20% excess over ca//per volume for open hole. Clean out liner to PBTD and test to 3500 psi. Change over to clean inhibited seawater. Test to 3500 psi for 30 minutes. RIH with 4-1/2" 12.6# 130RL80 NSCT completion string w/Z" packer positioned +200' md above top of Sadlerochit. Sad/erochit top is est/mated @ 10808'md/$$63 vd.. ( Reference DS 14-02BA completion diagram in Well Plan attachments ). M/U tubing hanger- test SSSV lines to 5000 psi for 10 mins. Orient SSSV balance line -towards reserve pit. Land tubing hanger and RILDS. Test tubing hanger packoff to 5000 psi. Back out & L/D the landing joint. Set blanking plug. N/D BOPE. N/U tubing head adaptor and 5" tree. Test control lines to 5000 psi. Test 5" tree and adaptor to 5000 psi. Pull the test plug with a lubricator. Pressure up on the .4-1/2" 12.6# 13CR80 tubing to 4000 psi to set the production packer. Maintain tubing pressure at 4000 psi for 30 minutes after setting packer and record as the tubing test. RECEIVED DEC 2 1 1995 u~t & Oas Cons. Co~'~mission Anchorage 17. 18. Bleed off 4-1/2" tubing pressure to +1500 psi. Pressure test tubing x 9-5/8" annulus to 3500 psi for 30 minutes. Record the test on a Barton chart. Bleed off the annular pressure prior to bleeding off the tubing pressure. Bleed off the tubing pressure. Pressure up to 2900 psi on the annulus to shear out the RP valve in the top GLM position. Displace the tubing w/enough diesel to freeze protect the annulus to 2200' tvd. Allow the diesel to U-tube to the tubing. If possible have the well freeze protected by gas by the PE's in the WOA or Drill Site Maintenance in the EOA. A potential gas source nearby will be required - high GOR well or artificial gas lift line. RECEIVED DEC 2 Ai~ska Oil & Gas Cons. Commission Anchorage PRU'DHOE BAY DR T LL T NS GROUP Narker Identification MD BK8 SECTN INCLN A) TIE-iN g~50 7B~g 40!~ 44.2~ B) END OF 6/I00 CURVE 2579 7G04 4t09 51.91 C) IARGET 1~375 90~3 5523 5~.g~ DJ TO I~585 9t05 564t 5~.91 D.S ~4-02B (P2) VERTICAL SECTION VIEW Section at: 4.33 TVD Scale.' ~ inch = 500 feet 65oo. Dep Scale · ~ ~nch = 500 fee[ 675,0 -. i .............. I x i ' I ) .......... -~--, ....\ ,..~ ..... ~i... , I .......................... '"/ i i I '", [. '- }_I ~ ................. · ............ , ..... ,,. ~.*~*--,:.*=::~-'::: F:: :::::~: :::: ':-'-"--'~,:: :=~:: :: ~::::: .... ::-: ~:_. '-'r ....... '~ ..... r ", ....~'"~-.- .... ~ ............ . .......... 2 .... F ~ 9250--~4~¢.F-~ ................................................... - ..~.,.-? .- ~ ~.-~'== ..... ~- - - . ........ -- - ~750 ...................................... . .................. RE(lIVED ~ .... ~ DEC 2 ~ , I 8250 ........... ~ ~le, S ~ 0ii & (as Cons. ~mmT~si i ~ ~chorage ~oo ' · ................ ~ ................. j ....... ~ '1 ...... 1 3000 3~50 3500 3750 4000 4~50 ~500 ~750 5000 5~50 5500 5750 ~000 6250 6500 ~aor~ll I'clg3 ~40~P2 B].52 5: i~ PN il <;8' d S~=I=IN 19N:~ CISd OJ. -Iq I ;alFjUNU/CINU-1 J. U3;ND HOH_-I EE: 80 £6E, 1;-1;E-Dzff-J PRUDHOE BAY i DS 4-026 (P2) PLAN VIEW , CLOSURE · 5694 feet at Azimuth 356.54 DECLINATION.' 29.888 E SCALE ' 1 ~nch = 500 faet DRAWN ' 12/20/93 DRILLING GROUP N~rker IdenLj~cat~on t4D N/S A) TIE-iN 9450 4060 466 D) ENO OF 6/100 CURVE 9579 4156 459 C) IARGEi ~ 1375 5566 353 D) TD ]!525 5683 3a4 7000 6750- 6500-- I ~ I . 6250-- '' i ' ; · 6000 pMn FT TARgeT R4nf[ fi ,r I : i i i 5750 .............................................. 5500 I ' , , ' 5250- - ' 7- ' ! I 4750 [ I ................................ ~00-- -- i . ~ .......... 4250- - .. .......... ! ............... I ,~ DEC I , A ~ ' .... i, I · , ... II ~ Ancf~or~e .... I % ......... . 3750 .......... ]. : ...... I ...... : ~oo I"' I " !I "' ] I I ,I ~750 ~500 1~50 t000 75r 500 250 0 ~50 500 75( ~090 ]250 ]500 ]750 <- KEST · EAST -> ~ ..... ~,.. · TOTRL P.O? AL~$~ OIL AND ~AS CONSERYATIOM COMMIS$10~M . APPLICA'[ .)N FOR SUNDRY APl:' ,OVALS ,.,e of Request: Abandon x ' Suspend ~ Operation Shutdown ~ Re-enter suspended well~ Alter casing Repair well~ Plugging z Time extension__ Stimulate Change approved program .., Pull tubing Variance~ Perforate ~ Other x __ Plugback for redrlll Z. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development~ KBE = 67.6' feet Exploratory 3. Address Stra~Jgraphic~ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 sen4ce Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1262' SNL, 1228' WEL, SEC. 9, TION, R14E At top of productive interval At effective depth At total depth 3439' NSL, 1792' WEI.., SEC. 4, TION, R14E 14-02A 9. Permit number 93-168 10. APl number 50- 029-20318.01 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 120' Surface 2659' Intermediate 9760' Production ~ Liner Perforation depth: measured None 11225 feet 9161 feet 9657 feet 7962 feet Size 20" 13-3/8" 9-5/8" true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Plugs (measured) Junk (measured) Cemented 675 sx AS II 5904 sx PF I! 1000 sx C/ass "G" Measured depth True vertical depth 120' 2732' 9842' 120' 2732' 7761' RECEIVED DEC 2 '1 1993 Alaska 0il & Gas Cons. Commission /~ch0rage 13, Attachments ... Description summary of proposal × Detailed operations program BOP sketch 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver B. Wondzefl 12/6/93 Date approved 15. 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 ~/~/ ~;~'~~ 'Frtle DrillingEngineerSupervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Co~mission so representative may witness I Approval Plug integrity__ ' e; ~~ Mechanical Inte~ ~~~ I Approved by order of the Commi Commissioner Form 10-403 Rev 06/15/88 Date Date SUBMIT IN TRIPLICATE ITEM A~PROVE DATE (1) Fee E2 ~hru 8~ (3) Admi n, :.,- .cL. ,' /'' (4) Casg ** CHECK LIST FOR NEW WELL PERMITS ** Company YES 1. Is permit fee attached ............................................... /,. 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper dis%ance from other wells ..................... 5. Is sufficient und~dicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8 Can permit be approved before 15-day wait ............... (5) BOPE [9~thru [10 S 13] [14 thru 22]! 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. Is lease number appropriate .......................................... 13. Does well have a unique name & number ................................ 14. Is conductor string provided ......................................... 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. 16. Is 17. Wi 18. Wi 19. Wi 20. Is 21. Is 22. Is 23. Is 24. 25. 26. 27. 28. enough cement used to circulate on conductor & surface ............ ll cement tie in surface & intermediate or production strings ...... ll cement cover all known productive horizons ..................... ll all casing give adequate safety in collapse, tension, and burst. well to be kicked off from an existing wellbore ................... old wellbore abandonment procedure included on 10-403 ............. adequate wellbore separation proposed ............................. a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~-¢:~p psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... [23 thru REMARKS (6) Other ~/?,-'¢' ¢¥ /L, /<~ ..... . ,,, .... ~_, y ,~?, <:_/~., [29 ~hru (7) Contact/~; .... [32] (8) Addl geo 1 ogy' DWJ ~ TAB FOR EXPLORATORY $ STRATIGRAPHIC WELLS: 29. Are data presented on potential overpressure zones ................... 30. Are seismic analysis data presented on shallow gas zones ............. 31. If offshore loc, are survey results of seabed conditions presented... 32. Name and phone number of contact to supply weekly progress data ...... rev 6/93 jo/6.011 33. Additional eng i nee r i ng: _ ~ 'R~D-]~ I?-' ~.Z-- t~l~ 193 - requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE · ,~' ,/ ~ ~'~ :~ ? ~:,.- . MERIDIAN' ?' remarks' UM )~' SM WELL TYPE' Exp/~ Redrill~ Inj Rev 0 ~0 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. Tape Subfi]'e 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6128.00 J. DAHL SEE REMARKS D.S. 14 - 02B 500292031802 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 24-JAN-94 RUN 2 RUN 3 9 10N 14E 1262 1228 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 9.625 9366.0 PRODUCTION STRING 8.500 11755.0 REMARKS: DLL/AC/CN/GR Pipe Conveyed. LOGS WITNESSED BY: R. REINTS & E. POTTER. CIRCULATION STOPPED AT 11:00, 15-JAN-94. CURVES SPIKING ON REPEAT PASS DUE TO PIPE CONVEYED LOGGING SET-UP. GAMMA RAY ON REPEAT PASS HIGH DUE TO NEUTRON SOURCE ACTIVATION. SOME ACOUSTILOG CYCLE SKIPPING ON REPEAT PASS IN SHALE SECTIONS. ACOUSTILOG CASING CHECK AFTER LOG VERIFICATION NOT DONE DUE TO PCL OPERATIONS. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, 8.5" BOREHOLE CORRECTION, CHISM FILTERING ACTIVE, NO CASING OR SALINTY CORRECTIONS APPLIED. 67.60 67.60 42.90 FILE HEADER · FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; cased hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DLL 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5OOO START DEPTH STOP DEPTH 10516.0 11662.0 10578.0 11724.0 10548.0 11692.0 10526.0 11666.0 GR (MEASURED DEPTH) BASELINE DEPTH DT 10492.0 10492.0 10558.5 10566.5 10567.0 10572.5 10575.5 10618.5 10619.0 10626.0 10625.5 10626.5 10636.5 10636.0 10648.5 10661.0 10661.0 10678.0 10677.0 10681.5 10680.5 10682.5 10681.5 10684.5 10683.5 10685.0 10688.5 10688.5 10690.5 10691.0 10699.5 10699.5 10708.0 10724.5 10725.0 10725.0 10745.5 10745.5 10746.0 10761.5 10760.5 10762.0 10771.0 10771.5 10771.5 10777.5 10777.5 10797.0 10796.0 10802.5 10801.5 10804.5 10809.0 10834.5 10835.0 10834.0 10872.5 10873.0 10873.5 10881.5 10890.0 all runs merged; no EQUIVALENT UNSHIFTED DEPTH .......... LL3 NPHI 10492.0 10492.0 10559.5 10567.0 10576.0 10627.0 10725.5 10746.5 10762.0 10771.5 10834.5 10567.0 10571.5 10576.0 10618.5 10626.0 10648.5 10662.0 10678.0 10685.5 10691.5 10700.0 10708.5 10726.0 10746.0 10762.0 10771.0 10804.0 10808.5 10834 10872 10881 10889 .0 .5 .5 .5 10906.0 10906.5 10907.5 10914.5 10916.5 10920.5 10922.5 10923.0 10937.0 10947.5 10949.0 10950.5 10956.0 10960.0 10962.0 10966.5 10968.0 10968.5 10969.5 10970.0 10973.0 10977.5 10978.0 10988.5 10990.5 10996.5 10997.5 10998.5 11008.0 11008.5 11044.0 11054.0 11057.0 11062.0 11074.0 11075.5 11083.0 11115.5 11141.0 11142.0 11142.5 11148.0 11149.5 11156.5 11159.0 11161.0 11161.5 11166.0 11174.5 11175.0 11179.0 11181.5 11182.0 11189.5 11191.5 11192.0 11196.5 11203.0 11219.0 11232.0 10907.0 10916.5 10919.5 10921.5 10950.5 10961.0 10966.5 10968.5 10970.5 10973.0 10978.0 10988.5 10998.5 11008.5 11044.5 11054.0 11062.5 11116.0 11142.0 11148.0 11157.0 11160.0 11162.5 11166.5 11174.5 11182.5 11189.0 11192.0 11196.5 11202.5 11219.0 11232.0 10905.5 10913.5 10916.0 10922.0 10936.0 10947.5 10956.0 10960.0 10968.0 10970.0 10973.5 10990.5 10997.0 11007.5 11056.5 11062.0 11075.5 11082.5 11115.5 11143.0 11148.5 11179.0 11202.0 11219.0 11232.0 10908.5 10916.5 10948.5 10956.5 10960.0 10969.5 10973.0 10978.0 10996.0 11007.5 11055.5 11062.5 11074.0 11115.0 11142.0 11149.0 11156.0 11159.0 11162.5 11174.5 11181.5 11192.0 11237.0 11255.5 11256.0 11273.0 11274.0 11288.5 11295.0 11309.5 11351.0 11393.0 11256.5 11274.5 11237.0 11255.5 11272.5 11309.5 11351.0 11430.5 11430.5 11491.0 11491.5 11491.5 11492.0 11523.0 11523.5 11523.5 11527.0 11528.5 11529.0 11537.5 11536.5 11550.0 11551.0 11551.0 11556.5 11557.0 11570.0 11570.0 11577.0 11578.0 11584.5 11586.0 11594.0 11623.5 11236.5 11289.5 11294.5 11586.0 11590.0 11594.0 11594.5 11603.5 11623.5 11624.0 11627.5 11628.5 11634.5 11643.0 11650.5 11655.5 11734.0 $ MERGED DATA SOURCE PBU TOOL CODE GR GR BCS BCS DLL DLL 2435 2435 $ REMARKS: 11351.0 11394.0 11430.5 11491.0 11550.0 11623.5 11627.0 11628.5 11643.0 11656.0 11655.0 11734.0 11734.0 11584.5 11589.0 11594.0 11602.5 11623.5 11634.5 11650.0 11734.0 RUN NO. PASS NO. MERGE TOP MERGE BASE 1 2 10516.0 10833.0 1 3 10833.0 11662.0 1 2 10578.0 10830.0 1 3 10830.0 11724.0 1 2 10548.0 10800.0 1 3 10800.0 11692.0 1 2 10526.0 10833.0 1 3 10833.0 11666.0 MAIN PASS. DATA FROM THE TOP OF THE REPEAT PASS WAS SPLICED ONTO THE MAIN PASS FOR AS COMPLETE DATA COVERAGE AS POSSIBLE. LLD, SP, MTEM, TEND, & TENS WERE SHIFTED WITH LL3. FUCT & NUCT WERE SHIFTED WITH NPHI. /??MATCH1.OUT CN WN FN COUN STAT / ? ?MATCH2. OUT / ??MATCH3. OUT $ : ARCO ALASKA INC. : D.S. 14 - 02B : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units 1 GR BCS 68 1 GAPI 2 DT BCS 68 1 US/F 3 TEND BCS 68 1 LB 4 TENS BCS 68 1 LB 5 LL3 DLL 68 1 OHMM 6 LLD DLL 68 1 OHMM 7 SP DLL 68 1 MV 8 MTEM DLL 68 1 DEGF 9 NPHI 2435 68 1 PU-S 10 FUCT 2435 68 1 CPS 11 NUCT 2435 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 44 * DATA RECORD (TYPE# 0) Total Data Records: 119 1014 BYTES * Tape File Start Depth = 11734.000000 Tape File End Depth = 10492.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 29821 datums Tape Subfile: 2 362 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape S~bfile 3 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 3 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10712.0 11665.0 AC 10814.0 11727.0 DLL 10744.0 11696.0 2435 10718.0 11670.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): 16-JAN-94 FSYS REV. J001 VER. 1.1 1100 15-JAN-94 759 16-JAN-94 11755.0 11731.0 10530.0 11724.0 1200.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWVL ISOL ISOL CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS MIS AC $ SWIVEL SUB BRIDLE ISOLATOR BRIDLE ISOLATOR CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG TOOL NUMBER 3944XA 3997NA 3997NA 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229MA/1229EA 3967XA 1603MA/1609EB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 9366.0 0.0 BOREHOLE CONDITIONS MUD TYPE: KCL POLYMER MUD DENSITY (LB/G): ~MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS; LOGGED UP. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 14 - 02B : PRUDHOE BAY : NORTH SLOPE : ALASKA 10.10 67.0 8.9 6.0 199.0 0.142 0.052 0.109 0.000 0.174 0.000 THERMAL SANDSTONE 0.00 8.500 2.0 68.0 199.0 68.0 0.0 68.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 Name Tool Code Samples Units GR AC 68 1 GAPI AC AC 68 1 US/F ACQ AC 68 1 CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RS DLL 68 1 OHMM RD DLL 68 1 OHMM ED DLL 68 1 MV ES DLL 68 1 MV ID DLL 68 1 A IS DLL 68 1 A SP DLL 68 1 MV TEMP DLL 68 1 DEGF CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 40 514 81 0 4 39 859 45 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 23 415 80 5 4 84 503 82 1 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 19~ SSN 2435 68 1 CPS 4 4 83 368 34 1 * DATA RECORD (TYPE# 0) Total Data Records: 350 966 BYTES * 76 Tape File Start Depth = 11734.000000 Tape File End Depth = 10686.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 83861 datums Tape Subfile: 3 435 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 2 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10515.0 11662.0 AC 10577.5 11724.0 DLL 10547.0 11694.0 2435 10526.0 11668.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWVL ISOL ISOL CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS MIS AC $ SWIVEL SUB BRIDLE ISOLATOR BRIDLE ISOLATOR CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 16-JAN-94 FSYS REV. J001 VER. 1.1 1100 15-JAN-94 624 16-JAN-94 11755.0 11731.0 10530.0 11724.0 1200.0 TOOL NUMBER 3944XA 3997NA 3997NA 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229MA/1229EA 3967XA 1603MA/1609EB 8.500 9366.0 0.0 KCL POLYMER 10.10 67.0 MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS; LOGGED DOWN. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 14 - 02B : PRUDHOE BAY : NORTH SLOPE : ALASKA 8.9 6.0 199.0 0.142 0.052 0.109 0.000 0.174 0.000 THERMAL SANDSTONE 0.00 8.500 2.0 68.0 199.0 68.0 0.0 68.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 GR AC 68 1 GAPI AC AC 68 1 US/F ACQ AC 68 1 CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RS DLL 68 1 OHMM RD DLL 68 1 OHMM ED DLL 68 1 MV ES DLL 68 1 MV ID DLL 68 1 A IS DLL 68 1 A SP DLL 68 1 MV TEMP DLL 68 1 DEGF CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 40 514 81 0 4 4 39 859 45 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 23 415 80 5 4 4 84 503 82 1 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 - 76 * DATA RECORD (TYPE# 0) Total Data Records: 414 966 BYTES * Tape File Start Depth = 11732.000000 Tape File End Depth = 10492.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 129042 datums Tape Subfile: 4 497 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS 94/ 1/24 01 **** REEL TRAILER **** 94/ 1/24 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 24 JAN 94 11:35p Elapsed execution time = 51.41 seconds. SYSTEM RETURN CODE = 0 ALASKA COMPUTING CENTER · ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 14 - 02B FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-20318-02 REFERENCE NO : 952~ ALASKA COMPUTING CENTER * ........ SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 14 - 02B FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-20318-02 REFERENCE NO : 95211 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1995 10:30 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 95/06/29 ORIGIN : FLIC REEL NAME : 95211 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, DS 14-02B, PRUDHOE BAY, 50-029-20318-00 **** TAPE HEADER SERVICE NAME : EDIT DATE : 95/06/29 ORIGIN : FLIC TAPE NAME : 95211 CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, DS 14-02B, PRUDHOE BAY, 50-029-20318-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 14 - 02B API NUMBER: 500292031802 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 29-JUN-95 JOB NUMBER: 95211 LOGGING ENGINEER: G. JOHNSON OPERATOR WITNESS: J. JULIAN SURFACE LOCATION SECTION: 9 TOWNSHIP: 10N RANGE: 14E FNL: 1262 FSL: FEL: 1228 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 67.69 DERRICK FLOOR: 67.69 GROUND LEVEL: 42.99 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9.625 9366.9 2ND STRING 7.999 11615.9 3RD STRING 4.599 11435.9 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) 47.99 29.99 12.69 PAGE: 0'IOI S'~SOII 0'E90I~ S'SLOII 0'9SIII S'I9III O'SLIII S'96~I~ 0'SSSI~ S'OSS~I O'~SSII S'~6888 H±d2q Q2±~IHSNn IN~qVAIn~2 0Z:0I S66I-NRF-6a S'IOI O'SSOII S'ZSOII 0'6EIII O'SLIII S'60ZII S'SSZII S'98~I 0'96~II 0'86~I S'68888 S'S~OII S'9SOII 0'I90II 0 SS~I~ 0'09III 0'88I~I .0'S6~I~ 0'86III S'6~EII O'/S~II 0 89~I S'OISII S'IESI~ 0'88888 H3~O HI~Q 3NIq2SV8 :~SH~N SS¥8 :~QOD ~A~D QMqq $98 :~GOD qO0± 9MQq SJ~IHS ~0~ ~A~D ~NIq~S¥8 J~gu~D 5u!gnd~oD eHselV J~SJ~q~nl4oS 6ulgs!q uolge~!}!~A ~del SI9 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1995 10:30 $ REMARKS: The depth adjustments shown above reflect cased hole GR to open hole GR and cased hole SIGM to open hole GR. All other TDTP curves were carried with the SIGM shifts. $ $ =,=* FILE HEADER **=, FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 9S/96/29 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 9.5999 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GR PASS NUMBER: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: This file contains TDTP Pass #1. No pass to pass shifts were applied to this data. $ LIS FORMAT DATA LIS Tape Veri{ication Listing Schlumberger Alaska Computing Center 29-JUN-lgg5 10:30 ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 SET TYPE - CHAN ** PAGE: 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 506527 00 000 ~ 0 1 I 1 4 68 000000~000 SIGM TDTP CU 506527 00 0~0 00 0 1 1 I 4 68 0000000000 TPHI TDTP PU-S 506527 00 000 00 0 1 1 1 4 68 0000000000 SBHF TDTP CU 506527 00 000 00 0 1 1 1 4 68 000000~000 SBHN TDTP CU 506527 00 000 00 0 1 1 1 4 68 0000000000 SIGC TDTP CU 506527 00 000 00 0 1 1 1 4 68 0000000000 SIBH TDTP CU 506527 00 000 00 0 1 1 1 4 68 0000000000 TRAT TDTP 506527 00 000 00 0 1 1 1 4 68 0000~90000 LC01 TDTP 506527 00 900 90 0 1 ~ ~ 4 68 00000~0000 SDSI TDTP CU 506527 00 000 90 0 1 1 1 4 68 90~0000~00 BACK TDTP CPS 506527 00 000 00 0 ~ ~ 1 4 68 000000~000 FBAC TDTP CPS 506527 00 0~0 00 0 ~ 1 ~ 4 68 000~000000 TCAN TDTP CPS 506527 0~ 000 00 0 ~ ~ ~ 4 68 000~0~000~ TCAF TDTP CPS 506527 00 090 00 0 ~ 1 1 4 68 00~09~0000 TCND TDTP CPS 506527 00 000 0~ 0 1 ~ ~ 4 68 0000000000 TCFD TDTP CPS 506527 00 000 00 0 1 ~ ~ 4 68 ~000000000 TSCN TDTP CPS 506527 00 000 00 0 1 1 ~ 4 68 9000099000 TSCF TDTP CPS 506527 00 000 00 0 ~ 1 1 4 68 0000090~0~ INND TDTP CPS 506527 00 000 00 0 ~ ~ 1 4 68 0000090900 INFD TDTP CPS 506527 00 000 00 0 ~ ~ 1 4 68 9000000000 GRCH TDTP GAPI 506527 00 000 00 0 ~ 1 ~ 4 68 0000000900 TENS TDTP LB 506527 00 000 00 0 ~ ~ ~ 4 68 0000090000 CCL TDTP V 506527 00 000 00 0 1 ~ ~ 4 68 0000000000 GR BCS GAPI 506527 00 000 00 0 ~ ~ 1 4 68 0000000000 0'~0II Hl8~O 801S ss~d 4~e 000S'0 p~dd!lo pue ~gIS HDa9 2003 9001 A~V~NS ~9I~ :IN~DNI :~8~NN SSV8 p~!qs q~d~O S~A~ND :~28~NN : 39I~ ISV9 09 : 38Ai 39I~ PEOI : 3ZIS D3a XV~ 6~/90/S6 : IODI00 : NOIS~3A DIq~ : ~DIA~S E00' ±IQ3 : 3~VN 39I~ : 3qI~ IS¥9 09 : 38A~ 39I~ PEOI : 3ZIS 33~ XVM 6~/90/S6 : 3iVO IODI00 : NOIS~3A DIqd : 3DIA~3S I00' 1I~3 : 3~¥N 3qI~ ~6S'9Z SDS'~O 0SE'666- 81QI'qDD 0S~'666- 0Sa'666- 8IQI'O~NI 0S~'666- 8iOI'ONNI 0S~'666- 0Sg'666- dlOl'G~l 0S~'666- 81OI'ONDI OSg'666- 0Sg'666- ~lfll'DY8g 0Sg'666- ~£fll'~DY8 OSg'666- 0Sg'666- ~l~.L'lYal 0Sg'666- ~I~.L'HRIS OSg'666- 0Sg'666- 8i(kL'~HBS 0Sg'666- 81OI'IH81 0Sg'666- ~S~'SI 81QI'DY8~ g08'0~ 81~l'~DV8 96S'0 SI6'I 81CLL'I¥SI Sig'69 81(].L'H8IS 9gg'g 9g~'6g 81(]1'~H8S S~9'0~ 81CLL'IHSI ssg'sI :3DV8 0~:0I S66I-NhF-6E ** VIVO ~0 ON3 81OI'SN31 0Rg'666- 81QI'HDSO dlCLL'dDSI 0Sg'666- 81OI'NDSI 8101'~V31 0Sg'666- 8101'NYDI 81Ol'DOI$ 0Sg'666- 81~I'NHBS dlOI'SN31 0Sg'666- dlQI'HD~O dlOI'~DSI ~O~'LSZ6 dlQI'NDSI ~IOI'~¥DI 69~'SII9~ ~IGI'NYDI alOJ.'ISOS ~Ig'g alQJ.'IOD9 alCLL'39IS S~'6~ alQI'NH~S dlOI'~OlS 000'09SII 'la3O ** ¥±¥q J~ueD 6u!~ndmoD eMselv JeSJeqmnl4oS Su!~s!9 u°!~eo!~!JeA ~del SI9 S'~88~ 0'88~II 0'66ZII S'£O~II 0'9L~II S'88~II O'Z6~I 0'60SI$ S'EISII S'O~SII 0'SZSII 0'OSS~I 0'~6888 S'@SCIT S'~9ZIT S'09SIT O'19ZTI S'~9CTT S'99~IT S'~LKII O'LSZII S'98S~ S'06SIT S'~6CTT S'~O~TT S'90~IT S'O~TT S'8~IT S'SS~II S'99~%I S'O/~IT S'SL~I S'98~II S'08~I~ O'~6~IT S'~6~IT S'90SIT 0'OTSTT S'80STT S'OTSTI S'STSTT S'aaSTT S'9ESIT S'OSSIT s'gbsTT S'OSSTT S'68GG8 0'858G8 ~OIS HOBO HI~3Q 3NIq3SYB .......... H£83O Q3I~IHSN~ £N39YAI~3 :~3B~N SSVd :3OOD 3A~RD ~aG9 $±~IHS BO~ 3AWED 3NIq35V8 (H±d3G G3WRSV3~)$$Vd O± SSVd - V±VG ±~IH$ 3ABhD ua~u~3 8u!~ndaoD e~selV u~6u~q~nlq3S OZ:OI S66I-NaP-6E 8u[~s!q uo!~eo!~!u~A ~de± SIq O'ISIII O'SSIII 0'$9~II O'ILIII S'6LIII S'96III S'00EII O'60ZII 0'gsEII 0'88~I S'66EII 0'8E£II 0'gs~II 0'SLI~I O'~6EII S'SSI~ S 99II~ S 9LI~I S 8LIII S'86III S 90~ S S'99E$~ S'SIEI$ S ~8EII S 98EI$ S 88E$~ S S 9ISII S'8~S$~ S OZ:OI S66I-N~P-6a ~u~D Su!$nd~oD eHselV ~aSJ~q~nlqoS Su!~s!q uo!~eo!~!J~A ~deI SIq ~ 99 0 ~ 99 9~ 89 99 SI 0 99 ~ 89 al ~ 99 ~ id S9 6 S'0 89 8 99 S T 99 ~ ~6 ~L ~ 0 99 a 0 99 T 3~9¥A 300D ~d3B 3d~1 ** B3~9 - 3d~1 13S ** ** OWOD3W NOIIYDI~ID3aS IYM~O~ ¥1¥~ ** :3~Vd $ '~# ssed ~OIS o~ ~ ssed ~OIS pue T~ ssed HD~O o~ ~ ssed HDBO ~3~l~J a^oqe u~oqs s~!qs 4~d~P ~ql '~# ssed d£al su!e~uoo el!~ s!ql S'00T S'00I O'SLOIT S'BLOII S'980IT 0'060TT S'~60IT O'LOTTT S'OIIIT O'SITII O'LETIT O'LSIII 0'6CTII :S~¥~3~ $ 0'00I S'~LOTT S'$LOTT S'980TI S'060II S'~60II S'EOIII S'90III S'OITTI S'9ETII S'9ZTII S'8ZIIT gZ:OI S66T-NRF-6~ 6U!~S!9 u°!~e:!~!J~A adel ~9S'9S86 S~9'~ Z66'~ ~8'~ 68~'9~6 SSS'S~ £86'~ d~O~'~¥aZ 000 0 ~90 669 8Z6 99 ~8Z dlQ£'QNNI 8~'69Z~ dl~l'~DSl Z~E'9868 dlQI'NDSI dZQI'ON31 LgS'glLgg diQi'tYOi Ig~'LgLg~ dlQI'NVDI dlQI'HSIS ~SA'O dlOi'DOIS 99E'SS dlQI'NHSS diQl'IHdl 686'0I dZQi'~OIS 00S'0SOII 'ld~Q 000'0 dZQZ'qDD 000'0IZI dl~l'$N3l 0Sg'666- dlGI'HD~O ~OI'~gI dlQI'~DVB 86Z'0 dlQI'ISQS 6S9'E dlQl'IODq £6~'9Z d£qi'HSIS Z~L'E diql'DOIS ~6~'9Z dlQI'NHSS ** VLYQ ** 0000000000 89 ~ I I g 0 00 000 00 ZgS9~S SdD dlq± DVSJ 0000000000 89 ~ I I g 0 00 000 00 ZES90S ~g dlQI HSIS 0000000000 89 ~ I I g 0 00 000 00 ZES90S ~D dlOl DOIS 0000000000 89 ~ I I g 0 00 000 00 Z~S90S ~D dlOl ~HSS 0000000000 89 ~ I I g 0 00 000 00 Z~S90S $-~d d£Ol IHdl 0000000000 89 ~ I I g 0 00 000 00 ZgS90S ~D diOl ~OIS 0000000000 89 ~ I I g 0 00 000 00 ZES90S 1~ ld~G (X3H) 3qoD ~393 d~¥S 8~N QO~ SS¥q3 3dil 90q # ~3Q~O qI SS3DO~d ~d3a 3ZlS B~RN B~N 3qI~ Id¥ Id¥ Id¥ Id¥ 3DIAB3S IIN~ A~3S 3~¥N :lOrd OZ:OI S66I-NaF-6g ** NYHD - ~dXl ±3S ** ~u~g 6u!~nd~oD e~Sel¥ J~SJ~q~nlqoS 6u!~s!q uo!3e~!$!a~A ~de± SIq 0'90SI~ 0'60S~ S'90SZ~ 0'6~S~ S'9~S~ O'SSS~ S'~6888 0'06888 0'88888 ~DI$ HD~9 H±~G ~NIq2SVQ Hl~3O Q31HIHSN~ IN3qYAI~3 :~38~RN $SV~ :3003 3ABRD $iHIHS BOH 3ABED 3NIq3$VB (Hl~30 03~$V3~)$$V~ Ol SSV~ - ViVO 19IHS 3ABED $ 0'0S~%I O'6SSII 0'0SOII O'~SZI HD~D Hld3O dOIS Hid3Q I~V±$ 3OOD 9001 D~Q9 ABV~n$ 39IH 000S'0 :iN3~3~DNI HI83Q ~ :~38~N SSV~ · S~l!~ ~eJed~$ um ssed 4~e~ ~o~ s~^Jno p~dd!lo pue p~!4s 4~d~o S3A~D Q31103 ~ :~38~N 3qI~ B30¥3H 3qI~ :30Vd OZ:OI S661-NRF-6a : 3qlJ ISVq Oq : 3dA± 39IJ ~EOI : 3ZIS D3~ XV~ 6~/90/S6 : 31VQ IODI00 : NOISa3A DIq~ : 3DIA~3S Z00' lIO3 : 3~VN 39I~ **** ~3OV3H 3qI~ **** : 39IH 09 : 3dXi 3qIH ~0I : 3ZIS D3~ XV~ %0DI00 : NOIS~3A DIqH : 3DIAB3$ g00' lIO3 : 3~VN 39Id J~u~D 6u!qnd~oD eMselV 6u!qs!q uo!~eo!$!a~A ~deI S'96~II 0'00ZII O'SOZII 0'6~ZII S'09ZII S'89ZII S'08Z$I S'88ZII 0'96Z~I S'80~I S'9S~I s'gs~II S'89~II S'08~II S'SS~I 0'06~II 0' 86~II S'8£EII O'Z8~II 0'80ZII 0'9IZII S'18glI 0'00SII S'9L~II S'SL~II S'08~I S'~8~II S'P6~II S'86~II S'00Z~I S'9ESII S'9~E~I S'~SZII S'~9Z~ S 99ZI~ S 89Z~I S OLZ~I S'8LZ$I S'06~II S'~6ZII S'86EII S 90~II S'OS~II S'998II S'OL~II S'8L~I~ S'98~II S'06~II S'~6~II S'96~II 0Z:0I S66~-N~F-6E a~u~D 6u!~nd~oD eHSelV ~6~qanlqoS 5u!~s!q uo!~e3!~!~eA ~deI SIq 0'080~ S'880~ 0'~60~ 0'960~ S'00~ 0'69I~I O'LL~I~ S'S8~II 0'06I~ S'9~EII S'89EII S'SLEII S'LLEII O'ZOII~ S'LOI~I O'SRIII S'8ZIII S'OSI~I O'SSIII O'ILIII S'O£EII S'8LOII S'~80II S'980II S'060II S'~60~ S'$80II S'00II~ S'80III S'OI~ZI S'SIIII S'99~II S'89II~ S'O/III S'9L~II S'08III S'98I~I S'06III S'86~II S'90EII S'OIEII s'gE~II S 99EII S S9~II S Oi~II OZ:OI S66I-NflF-6E ~e~ueD 8u!~nd~oD eHSel¥ ~eS~eqmnlqoS 6u!~s!q uo!~e2!~!~A edeI SIq LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1995 10:30 11074.5 11076.5 11070.5 11073.0 11066.5 11068.5 10~.0 102.5 102.0 REMARKS: This file contains TDTP Pass #3. The depth shifts shown above relect GRCH pass #3 to GRCH pass 01 and SIGM pass 03 to SIGM pass 01. $ LIS FORMAT DATA PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *= TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER 0 LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 506527 90 999 99 9 3 1 1 4 68 SIGM TDTP CU 596527 99 999 99 0 3 1 1 4 68 TPHI TDTP PU-S 596527 99 999 99 9 3 1 1 4 68 SBHF TDTP CU 596527 99 999 99 9 3 1 1 4 68 SBHN TDTP CU 596527 99 999 99 9 3 1 1 4 68 SIGC TDTP CU 596527 99 999 99 0 3 1 1 4 68 SIBH TDTP CU 596527 90 999 99 9 3 1 1 4 68 TRAT TDTP 596527 90 999 99 9 3 1 1 4 68 LCOI TDTP 596527 90 999 99 9 3 [ ~ 4 68 SDSI TDTP CU 596527 90 909 99 0 3 [ ~ 4 68 : BgI~ ~0~ : BZIS DB~ X¥~ 6~/90/S6 : I0~00 : NOIS~B^ DIq~ : BDIAM~S ~00' ±Iq2 : 3~¥N 39IH I69'I6~ 8~'I~6 I69'I 99~'8~ S9~'0~ i06'I 000'0 81GI'qDD 000 8101'O~NI L~L'~68I 8101'ONNI ZZI ~%~i'HHSS S8~'~ ~£Q~'IH~% S90 ** V£VQ JO QN3 ** S6~% dlOl'SN~l 0S~'666- d%al'Hg~D Z~O~ dlQI'~DSI 9SZ'~S8 d%Q%'NDS% ~6~0~ dial'dYDl S~S'SB9~ d~O±'NVPl ** ViVd ** (X3H) 3dOD ~393 8~VS 8~RN dO~ SSVqD 3dA± OOq ~ ~3d~O $S~0~ ~ ~ZIS 8~RN 8~RN ~lI~ I~¥ I~¥ I~V I~V ~DIA~$ IINR A~$ ~¥N ae~ueD Su!~ndmoD eHselV ae6Jeqmn142S Og:OI S66I-NRF-6E Su!~s!9 uo!~e2!$!JeA ede± SI9 S'69~ S'99~I~ 0'S6~II S'E6~II 0'00SII S'96~II S'~OSII S'86~II S'OISII S'90SII O'ISSII S'9~SII S'E6888 S'06888 0'88888 ~OlS H3~O HI~3Q 3NIq3SV8 'HI~3Q O3i~IHSN~ IN3qVAI~3 :N3fl~dN SSV~ :2d03 ~A~D SI~IHS ~0~ 3A~D 3NIq~SV8 (HI~3Q Q~W~SV~)SSV~ 01 0'96811 :~38~nN SS¥~ · S~l!~ ~d~s Ul ss~d q~ ~o~ s~^~no p~ddJl~ pue p~!qs q~dad S3AN~D O31Iq3 :N3B~N 39I~ ~3Q¥3H 39I~ SI OZ:OI S66I-N~F-6E : 3qI~ 1S¥9 09 : 38,k.L 39I~ ~0I : 3ZIS D3~ X¥~ 6~/90/S6 : IODI00 : NOIS~3A 3Iq~ : 3DIA~3S P00' 1I~3 : 3~¥N 3qI~ **** a3q¥3H 3qId aa~u~D 6u!~ndmoD e~Sel¥ 6u!~s!q uo!~e~!~!aaA ~de± T 99 0 T 99 9T 89 99 ST 0 99 CT 89 ~T TT 99 ~T 1~ S9 6 S'0 89 8 S9 Z ~L 9 99 S T 99 ~ 88 gL ~ 0 99 ~ 0 99 T 3~gVA 300D ~d3~ 3dA1 ** B3~9 - 3dA1 135 ** ** OBOD3~ NOIIV3I~ID3dS 1¥~0~ V±¥Q ** 9T :30¥d VIVO IV~NOd $ 'SI~IHS 3H1 HII~ O3INNV2 3B3~ S3AN~2 dlOl B3HIO 99V '~OI$ SSVd 3SVB 01 ~OlS T# SSVd XV~OB QNV HD~O T# SSYd 3SVB 01 HD~O T# SSVd XV~O8 ±D39~3~ 3AOBV N~AOHS SNOIID3~OD Hld3O 3HI 'diql 3H± ~0 ~# SSVd XVNO8 SNIVINO3 39I~ SIHI o S LT~TT S O'L~T S'8~T S'9S~ 0'~9~T S'~OT :SHBV~3a # $ 0' 00[ S'9~b~T OS:OT S66I-NRF-6E u~u~D 5ul~nd~og e~selV J~Su~qmnl4aS BUl~Sl9 uo!~eol~!J~A ~del SIq ** ViVa ~0 0S~'666- 9~.L'6~06 L6L'PS9~P ~0L'6S 0Sa'666- 6~0'~9~ Z90'6S911 899'I 18a'09 dlal'Hg~O IL9'£8~ dial'adNI 6L8'806I dlal'aNNI dlal'dHaS 9~S'SI dial'IHdl 96~'0I dlal'~$IS 000'0 dlfll'qDD dlQl'HDaO 69I'60~ dlOl'OdNI ZZ9'818I dlOI'GNNI dlal'ND$1 ~86'SSS~ dlal'adgl 9~9'IS9SI dldl'aNDl dl~l'l¥~l 96~'811 dlal'HdI$ 69E'0 diql'gOI$ dial'dHaS 9al'aS dial'IHdl 90I'6I dlal'~$IS 000'S0~1 dlal'$NRl S61'0 dlfll'ISqS 900'11 dlfll'NHaS L9Z'S6SI dldl'dDSl EZI'dLLL diqi'dYDl ZT9'O di~I'ISGS 6SS'11 dlOI'NHdS 000'09SII 'ldRa ** ViVa ** 0000000000 89 ~ T I ~ 0 00 000 0000000000 89 ~ I I ~ 0 00 000 0000000000 89 ~ T I ~ 0 00 000 0000000000 89 ~ I I ~ 0 00 000 0000000000 89 ~ I I ~ 0 00 000 0000000000 89 ~ I ~ ~ 0 00 000 0000000000 89 ~ T T ~ 0 00 000 0000000000 89 ~ T ~ ~ 0 00 000 0000000000 89 ~ T T ~ 0 00 000 0000000000 89 ~ I I ~ 0 00 000 0000000000 89 ~ I T ~ 0 00 000 0000000000 89 ~ T T ~ 0 00 000 0000000000 89 ~ I T ~ 0 00 000 0000000000 89 ~ T T ~ 0 00 000 0000000000 89 ~ T T ~ 0 00 000 0000000000 89 ~ I I ~ 0 00 000 0000000000 89 ~ T T ~ 0 00 000 0000000000 89 ~ T I ~ 0 00 000 0000000000 89 ~ I T ~ 0 00 000 0000000000 89 ~ I I ~ 0 00 000 0000000000 89 ~ I I ~ 0 00 000 0000000000 89 ~ I T ~ 0 00 000 00 LaS90S Gq dial SNRI 00 LaS90S IdVO dial 00 Lafi90S SdD dial GNNI 00 /ES90S SdD dial 00 L~S90S SdD dial aND± 00 LES90S idg dial 00 LES90S SdD dlOl NVDI 00 L~S90S idD dial 00 /aS90S fid dial ISQS 00 LaS90S dl~L 00 LES90S ~D dlCLL HBIS 00 LaS90S nD dlQl DOI$ 00 1~S90S RD dl(1L 00 /gS90S S-~d dl(LL IHdl 00 LES90S ~g dl(ll. LT Ja~ueD 6u!~ndmoD e~Sel¥ JaS~qmnlqoS 0S:0~ S66I-NRF-6E iu!~s!q uo!~eol$l~A ~del SIq O'SOSII S'90SII 0'OISII 0'SISII S'O~SII S'8~SII S'~ZSII S'SSSI~ 0'Z6888 0'96888 '90SII 9~SII OSSII 88888 .......... Hi~2Q Q2I~IHSN~ ±N2qVAI~2 :N28~N SS¥~ :3GOD 3AN~D $~IH$ WO~ 3ABED 3NIq3SYB 0'9$ZII 0'$SS~I ~DIS 0'96~I O'~SII Hid30 dOIS Hld3O 1~¥1S 3003 900± O~Oq A~¥~S 3qIJ 000S'0 :£N3~3~DNI H±a3O S :B38~flN SSYd 'S~l!~ ~eJed~s u~ ssed 4oe~ do~ s~^dno p~dd!lo pue p~3~!qs 43d~0 S3ANflD q31IO3 S :~3B~N 39I~ B3O¥3H 39I~ 8I :39¥d OZ:OI S66I-N~F-6~ : 39I~ iSVq ~0I : 3ZIS D3N XV~ 6~/90/S6 : 31¥d ~0D~00 : NOIS~3A DI9~ : 3DIA~3S S00' £IO3 : 3~¥N 39I~ : 39IJ 09 : 3ak£ 39IJ PEOI : 3ZIS D3~ X¥~ 6~/90/S6 : 31¥0 ~0DI00 : NOIS~3A DIq~ : 3DIA~S ~00' ±I(33 : 3~VN 3qI~ Su!~s!q uo[~eo[~!u~A ede± SIq T. 99 0 T 99 9T 89 99 :ST 1-1 q9 0 99 ~T. 89 T.T. 99 .L..-I S9 6 q'O 89 8 S9 8L 9 99 S T 99 t, 88 ~/ 0 99 0 99 T 3flgVA 3OOD ~d~ 3dXl ** QaOD3a NOI±VDIdID~S IV~aOd V±V~ ** 6I VIV~ IV~Od SI9 $ 'SI~IHS ~OIS 3HI HII~ Q2INNVD 3N3~ S3AN~D dlQl N3HIO 99V '~OlS T# SSVd 3SV8 Ol ~OIS ~ SSVd XVt08 ~NV HD~O T~ SSVd ~SV8 Ol HD~O ~# SSV8 XVt08 ID39d~ ~AOSV N~OHS SNOIID~OD HId~Q 3HI 'dlGl ~HI dO a# SSVd XVt08 SNIVINOD ~9Id SIHI O'COT 0'9~TI 0'OC~TT O'A~TI O'CS~IT o'sg~TI S'69~II 0'98~II S'06~II S'86~II S'LOT 0'88~II S'E6~IT $ S'ST~TT S'9E~TT S'~C~TI S'~TI S'9~TI S OS~IT S S 99~TT S S 08~IT S'98~TI S'~6~IT 08:0I s661-Nnr-6a ua~uaD 6ulqndmoD e~SelV u~6ueqmnlq~S : 391~ IS¥9 09 : 3dXl 39IH ~gO~ : 3ZIS 33B X¥~ 6g/90/S6 : 3iVO IOD~00 : NOIS~3A DIqd : 3DIA~3S S00' 1I~3 : 3~¥N 39I~ ** VlVO ~0 ON3 ** 000'0 alql'qDD 000'00PI d±QI'SN31 0SE'666- a±Ol'HOaO 90~'~6S alOl'O~NI 6S~'S96I alOI'ONNI 6S0'£9SI 9SI'69IS dlQI'NDSI 0E9'0£S~ d±Ol'O~D± L~'~SB~I d±Ol'qNgl ~S6'60Z~ 99~'I d±O£'l¥~l ffS~'~EI dlQI'HBIS IL~'O ~iQi'D~IS SZ8'I8 d±Q±'NH~S 9ZZ'P9 ~IOI'~HBS Z66'SE dlOl'IHdl £Z8'6I ~IOI'~$IS 000'09S~$ ** VlVO ** 0000000000 89 ~ I I S 0 00 000 00 0000000000 89 ~ I I S 0 00 000 00 0000000000 89 ~ I I S 0 00 000 00 A~S90S ~D dl~l DOIS 0000000000 89 ~ I I S 0 00 000 00 ZES90S ~g d±Ol NHB$ (X3H) 3OOD ~393 ~¥S B~RN OO~ SS¥9D 3aX£ 909 ~ a3OBO SS3DOW4 aa3B 3zIs B~N B~RN 39I~ Ia¥ Ia¥ Ia¥ I4V 3DIAW3S lINh Aa3S 3~¥N 0~ :39Va OZ:OI S66I-N~F-6a ** NYHD - 3~ii 139 *= J~u~D 8u!~nd~oD eHselV ~8J~qmnl4oS 6u!~slq uo!~eo!~!u~A ~de± SIq 0'09~II S'L9~I S'SZ~II 0'08~II 0'68~II O'Z6~I~ 0'60SI~ 0'8~SII O'~SSII S'I6888 S'06~II 0'ff6888 8S~I 99~II 8Z~II S 98~II S 06~II S'~6~I S'90SII S'OISI~ S'8ZS~1 S'OSS~ 0'88888 ~OIS H3~O Hld3a 3NIq3SV8 Hld3a O31~IHSNN IN3qVAIN~3 :~38~N SSVd :3aOD 3A~RD O~a9 $1~IHS WO~ 3A~3 3NIq3SV8 (HldBa aBNnsvB~)ssvd oi ssv8 - viva I~IHS BANND 0'96~II O'6SSZI ~DIS 0'96S~I O'~ZSII HD~ Hld3a dOgS Hld3a INVIS 3a03 qO01 000S'0 :IN3~2~DNI HIS~Q 9 :~8~N SSV8 '$el[~ ~J~d~$ u! ss~d qa~e ~o~ $~^Jn: pedd!l~ pu~ S~A~N3 a~lla~ 9 :~38~RN ~qI~ ~3OV3H 39I~ OZ:OI S66I-N~P-6E : 39IJ ISVq Oq : 3dii 39IJ V~OI : 3ZIS D3~ XV~ 6E/90/S6 : 31Va IODI00 : NOIS~3A DIq~ : ~DIA~S 900' llO3 : 3~VN 39I~ J~U~D 8u[~ndmo3 e~SelV a~flueqmnlqoS Su!~s!q uo!~e~!k!J~A edeI SIq LIS Tape Verification Listing Schlumberger Alaska Computing Cen%er 29-JUN-1995 10:30 11454.5 11455.5 11450.5 11452.0 11446.~ 11447.5 11442.5 11443.5 11438.5 11439.0 11426.5 11427.0 11422,5 11423.5 11418.5 11421.0 11414.5 11416.5 10~.~ 1~6.0 102.0 $ REMARKS: THIS FILE CONTAINS BORAX PASS #3 OF THE TDTP. THE DEPTH CORRECTIONS SHOWN ABOVE REFLECT BORAX PASS #3 GRCH TO BASE PASS #1 GRCH AND BORAX PASS #3 SIGM TO BASE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFTS, $ LIS FORMAT DATA PAGE: 22 DATA FORMAT SPECIFICATION RECORD ** ** set TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I 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 506527 00 000 00 SIGM TDTP CU 506527 eO 000 00 0 6 1 1 4 68 00000000¢0 0 6 1 1 4 68 OSa'666- Lg~'SSS@ Ll9'Oggg~ ~'~ 9S~'~9 OSg'666- ~SZ'SSSg LTT'SSZ~T 00S'T 6S8'~Z 000'0 diOI'qDD ~00'S685 di~I'$NBI dlqi'HD~O E08'08~ dlO±'OSNI IZ~'~Og dlOI'ONNI g~S'I00S dlql'SDS± diOl'l¥~± S6S'~0I d±OI'HSIS I6I'0 dlOi'30IS 6IS'ZZ d±GI'NHOS dlGi'SHSS 686'~I dlOl'IHdl II~'OI dlOl'~OIS 000'SBZIT 'ld3O 000'0 dlG±'qDD 000'S0~I dlGI'SN3I dlGI'HD~O LIS'gLg diOI'OSNI 696'~L8I dlQI'QNNI ~zg'sIEI dlQi'dDS± dl~l'NVgl SSS'Z~ dlOl'gVO~ 869'68I dlOi'~gVB IZ8'O dlQI'ISQS diOi'lYRi ZS6'9SI diGi'HOIS 960'0 d±Ol'gOlS Zzz'g8 dlQi'NHOS diGI'SHBS g~O'6g dlOl'IHdl 9Pg'Ig dlOl'~OIS 000'09SII 'ldBO ** ¥.LV(] ** 0000000000 89 ~ I I 9 0 00 000 00 Lgsgos A dlQl qDD 0000000000 89 ~ I T g 0 00 000 00 Lgsgos Bq dlql SN~I 0000000000 89 ~ I I 9 0 00 000 00 AES90S Id¥~ dl~l HD~O 0000000000 89 ~ L T 9 0 00 000 00 0000000000 89 ~ I I 9 0 00 000 00 ZES90S SdD dl~l QNNI 0000000000 89 ~ I I 9 0 00 000 00 0000000000 89 ~ I T 9 0 00 000 00 LES90S SdD dlGl NDS± 0000000000 89 ~ I I 9 0 00 000 00 0000000000 89 ~ T I 9 0 00 000 00 ZES90S Sdg dlq. L 0000000000 89 ~ I I 9 0 00 000 00 ZES90S Sdg dl~l ~VDI 0000000000 89 ~ T T 9 0 00 000 00 ZES90S SdD dlQl NVDI 0000000000 89 ~ I I 9 0 00 000 00 0000000000 89 ~ I I 9 0 00 000 00 ZES90S SdD 0000000000 89 ~ I I 9 0 00 000 00 ZES90S aD did± ISQS 0000000000 89 ~ I I 9 0 00 000 00 ZES90S 0000000000 89 ~ I I 9 0 00 000 00 AES90S fig dlQl HBI$ 0000000000 89 ~ T I 9 0 00 000 00 LgS90S aD di~i DOIS 0000000000 89 ~ I I 9 0 00 000 00 LES90S aD diq. L NHBS 0000000000 89 ~ I T 9 0 00 000 00 ~gS90S aD di(li 0000000000 89 ~ I I 9 0 00 000 00 lZS90S S-ad d£(LL IHdi (X3H) 3OOD ~393 d~VS B~aN qO~ SSVqD 3dAJ. 009 # ~3O~0 SS3DO~d Nd3N 3ZI$ B~hN B~N 39I~ IdV Id¥ IdV IdV 3DIAN3S lINh AN3S 3~¥N :30¥d 08:0I S66I-N~F-6g ao%uoD 6u!gndmoD eMselV ao6a~q~nlqoS 6u!gs!q u°!~e~!&!a°A ~del SIq LIS Tape Verification Listing Schlumberger Alaska Computing Center **-* FILE TRAILER ***~ FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 95/06/29 MAX EEC SIZE : [024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .007 SERVICE : FLIC VERSION : GeiCO1 DATE : 95/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 29-JUN-1995 PAGE: 24 FILE HEADER FILE NUMBER: 7 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass i Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.50~0 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS SZGM l, 2, $ REMARKS: The arithmetic average of passes 1,2,~ 3 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 2 66 3 73 4 66 5 66 6 73 o o 84 i la9'a AVNd'IODq 6~a'0~ ~8a'S906 AVNd'NOS~ £aa'8686 ~66'~s9~ AVNd'NV~ 6~6'~ AVNd'£V~Z 9~9'Z8 ~S~'~8 AVNd'~HaS S~S'O~ AVNd'O~NI ~00'8a6~ AVNd'ONNI AVNd'Qd3± 6IZ'~O66a AVNd'QN)I AVNd'HfllS Z89'~ AVNd'3OIS AVNd'IHd~ ~'SI AVNd'~OIS 0S~'666- dlO~'H~O ~S9'8S~ AYNd'93$I /i~'g~i/~ AVNd'gVD~ S~'0 AVNd'ISQS 9S9'Z~ AVNd'NHSS ** VIVQ ** 0000000000 89 ~ I ~ Z 0 0000000000 89 ~ ~ I Z 0 0000000000 89 ~ I I L 0 0000000000 89 ~ ~ I Z 0 0000000000 89 ~ I I Z 0 0000000000 89 ~ I I Z 0 0000000000 89 ~ I I Z 0 0000000000 89 ~ I I Z 0 0000000000 89 ~ ~ I Z 0 0000000000 89 ~ I I L 0 0000000000 89 ~ I I L 0 0000000000 89 ~ I I Z 0 0000000000 89 ~ ~ I L 0 0000000000 89 ~ I I ~ 0 0000000000 89 ~ I I Z 0 0000000000 89 ~ I I Z 0 0000000000 89 ~ I I Z 0 0000000000 89 ~ ~ I ~ 0 0000000000 89 ~ I I Z 0 0000000000 89 ~ I I ~ 0 0000000000 89 ~ I I Z 0 00 000 00 00 000 00 00 000 00 ZES90S S~D AVNd QNNI 00 000 00 ~ES90S 00 000 00 LES90S Sd3 AVNd NDS± 00 000 00 Z~S90S 00 000 00 /~S90S 00 000 00 ZES90S SdD AVNd 00 000 00 AES90S AD AVNd ISQS 00 000 00 ~S90S AVNd 00 000 00 Z~S90S hD AVNd HBIS 00 000 00 £~S90S hD AYN8 ~OIS 00 000 00 £ES90S RD AVNd NHBS 00 000 00 A~S90S 00 000 00 LES90S S-Rd AVN~ IHdl 00 000 00 AES90S ND AVNd ~OIS 00 000 00 AES90S Id 1~30 (X3H) 3002 R333 d~VS B~NN SS3DONd Nd3~ 3ZIS B~NN B~RN 39Id IdV Id¥ IdV IdV 3DIAN3S IIN~ AN3S 3~VN ** NVHD - 3dA± 13S ** I 99 0 T 99 94 89 99 St 0 99 89 ET 99 It 1~ S9 6 S'0 89 8 S9 3~qYA 3003 ~d3~ 3d,k_L OE:OI S66I-NhF-6E J~%u~D Bu!%ndmoD eMsel¥ ~6~q~nlqoS 8u!~s!q uo[%e~!~]J~A ~de± SIq LIS Tape Verification Listing Schlumberger Alaska Comput|ng Center 2g-JUN-1995 10:30 DEPT. 11043.000 SIGM.PNAV -999.259 TPHI.PNAV -999.259 SBHN.PNAV -999.259 SIGC.PNAV -999.259 SIBH.PNAV -999.259 SDSI.PNAV -999.259 BACK.TDTP 124.133 FBAC.TDTP 21.165 TCAF.PNAV -999.259 TCND.PNAV -999.259 TCFD.PNAV -999.259 TSCF.PNAV -999.259 INND.PNAV -999.259 INFD.PNAV -999.259 GRCH.TDTP -999.259 END OF DATA SBHF.PNAV TRAT.PNAV TCAN.PNAV TSCN.PNAV LC91.PNAV PAGE: 26 -999.259 -999.259 -999.259 -999.259 -999.259 **** FILE TRAILER **** FILE NAME : EDIT .907 SERVICE : FLIC VERSION : 9~1C91 DATE : 95/96/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .908 SERVICE : FLIC VERSION : 001C91 DATE : 95/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.590~ FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP llSS9.M $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL BOTTOM LOG INTERVAL (FT): 11944.0 31-MAY-g5 42.2 1939 31-MAY-gS 11579.0 11562.9 19959.0 11558.9 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1995 10:30 LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 1800.0 NO TOOL NUMBER TDTP GAMMA RAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY $ CGRS-A-862 CPLC-A-867 TDIC-A-817 TNC-P-X2 TNG-P-21 BOREHOLE AND CASING DATA OPEN HOLE BlT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 9366.0 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): BORAX WATER 47.0 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): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO USIT DATED 2/3/94 *** JOB SEQUENCE ~ ) PUMPED 250 BBLS CRUDE 2) MADE [ST BASE PASS PAGE: 27 LIS Tape Veri{ication Listing Schlumberger Alaska Computing Center 29-JUN-1995 10:30 3) PUMPING AT 1 BPM 4) MADE 2ND AND 3RD BASE PASSES 5) MADE 1ST BORAX Pass - 2o BBLS OF BORAX WATER INTO PERFS $ LIS FORMAT DATA PAGE: 28 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPe - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 73 66 0 14 65 FT 75 66 68 16 66 1 0 66 1 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 API AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 506527 00 000 00 0 8 1 I 4 68 0000000000 SIGM PS1 CU 506527 ¢0 000 00 0 8 1 1 4 68 0000000000 TPHI PS1 PU 5~6527 00 0~0 00 ~ 8 1 1 4 68 0000~00~00 SBHF PS1 CU 506527 00 0~0 ~0 0 8 1 1 4, 68 0090000000 SBHN PS1 CU 596527 99 0~9 ~9 9 8 1 1 4 68 9990909909 SIGC PS1 CU 506527 90 000 90 0 8 1 1 4 68 9999909009 SIBH PSI CU 506527 99 900 00 0 8 1 [ 4 68 9099999999 TRAT PSI 596527 09 009 99 0 8 1 1 4 68 0099999999 LCO[ PSI 506527 99 900 99 0 8 1 ~ 4 68 9099999909 SDSI PSI CU 596527 00 000 00 0 8 ~ ~ 4 68 0099999099 BACK PSI CPS 506527 00 009 00 0 8 1 1 4 68 9099999990 FBAC PSI CPS 596527 00 099 00 9 8 1 1 4 68 0000909000 TCAN PS1 CPS 506527 00 009 90 9 8 1 1 4 68 0990999909 TCAF PS1 CPS 506527 00 ~09 00 9 8 1 1 4 68 9990009909 TCND PS1 CPS 506527 00 000 00 0 8 1 [ 4 68 9000909999 TCFD PS1 CPS 506527 e9 009 9~ 9 8 1 1 4 68 0099999999 : 39I~ 1S¥9 09 : ~8i± 39I~ ~EOI : ~ZIS D~ XV~ 6E/90/S6 : IODI00 : NOIS~A DIq~ : ~DIA~3S 600' ±I~ : ~¥N : 39I~ ISV9 09 : 3~AI 39I~ ~gOI : ~ZIS DR~ XV~ 6g/90/S6 : RIVG IODI00 : NOIS~A DIq~ : 3DIA~S 800' IIG3 : 3~VN ~qI~ S9L'I68 S89'I 98L'Z 6RI'Ag ** VlVO ~0 ON~ ** 000'0 ISa'qDD 906'0g ~Sa'~O 000'S8II ISa'SN~I ISS'O~NI SSff'ZE6I IS~'ONNI 6IZ'~SES IS~'~DSI 6I~'O~IA ISS'NDS± ISd'O~gl S98'6gSSg ISd'ONDI ~Z6'EO$SI ISd'~¥Dl Z~g'SZ9~Z ISd'NYDI IS~'D¥8~ ZZI'~I ~S~'~D¥8 £8E'0 ~S~'ISOS ~6I'~ IS~'IODq IS~'I¥~I 9g8'89 IS~'HSI$ SOI'I IS~'DOIS EIO'ZS IS~'NHSS 000'0 ISd'qDD 8Z~'ZS ISd'~O 000'S9~I ISd'SNBI ISd'O~NI 80I'IA8I ISd'ONNI 68g'I99Z ~Sd'~DSI ~8g'0S88 ISd'NDSI IS~'O~DI ~Z6'~986g ~S~'ONDI Z6g'~ggSI IS~'~¥DI ~6R'gSO~ IS~'NYDI ISd'gVBd I69'IZ ISd'~gVB ~BZ'O ISd'ISQS ZI~'E IS~'IOOq IS~'IV~I 689'S~ IS~'HBIS OS~'E ISd'DOIS 689'SE IS~'NHBS ISS'~HSS 616'Rg ISS'IHS± 08~'SI ISS'MOIS 000'09SI~ '±d3O ** V±VO ** I 8 0 00 000 00 LgS90S Bq IS~ SN31 I 8 0 00 000 00 £gS90S S~D IS~ ND$1 (X3H) 3003 ~393 ~VS B~N 00~ SSVqD 3~ki 009 ~ B3OBO OI $$3D0~ ~3~ 3ZIS B~N B~N 3qI~ I~¥ I~¥ I~¥ I~¥ 3~IA~3S IIN~ A~35 3~¥N 6g :3OVd OR:OI S66I-N~F-6g Je~ueD 8u!~ndmoD eMSel¥ JeS~eqmnl4~S 8u!~s!q uo!~e~!~!~A ~de± SI9 LIS Tape Verification Listing Schlumberger Alaska Computing Cen%er 29-JUN-1995 10:30 PAGE: FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in las% file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP $ LOG HEADER DATA 11559.0 11050.0 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) VENDOR TOOL CODE TOOL TYPE 31-MAY-95 42.2 1030 31-MAY-g5 11579.0 11562.0 10050.0 1800.0 NO TOOL NUMBER TDTP GAMMA RAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY $ 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 CGRS-A-862 CPLC-A-867 TDIC-A-817 TNC-P-X2 TNG-P-21 9366.0 BORAX WATER 47.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-~995 ~0:30 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): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO USIT DATED 2/3/94 *** JOB SEQUENCE *** 1 ) PUMPED 250 BBLS CRUDE 2) MADE 1ST BASE PASS 3) PUMPING AT 1BPM 4) MADE 2ND AND 3RD BASE PASSES 5) MADE 1ST BORAX PASS - 20 BBLS OF BORAX WATER INTO PERFS $ LIS FORMAT DATA PAGE: 31 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I~9'I0~ 06~'~ S6S'I 8~'~ 6S6'~S6 60Z'~ 86S'~ CSd'Q~NI CSd'QJ31 CSd'DVSH ~Sd'lVal ~Sd'HHaS ~Sa'QJNI ~Sa'HHaS 000'0 £~'~I6I 0~'S~Z9~ 90S'I~I 0~9'S9 SZ6'6I 000 0 ~9I L08I 6SS LPI SS6 Lg LLP L~ ~Sa'qD3 ES~'GNNI 8E~'O6E~ ESa'QNDI ~9E'96E~E ~S~'~DV8 ~'0 ~S~'HGIS 6~9'0 gSd'IHdl SOL'II ~S8'qDD 88P'OL ~SS'QNNI ~EI'S6S~ ~Sd'ON31 I6Z'8I~6I ~S8'~D¥8 98Z'0 ~Sd'HSIS ~SL'~ gS~'IH~± S69'~I ~$~'~DSi I68'~98 ESS'NDSI ~Sd'~VDI I~I'SS8~ ~Sd'NVDI ~Sd'IS~S ~IO'E ~Sd'IODq ES~'DOI$ Asg'~s ES~'NMSS ESd'HDIS 00S'L~OII 'ld~Q ESa'~O 000'008I ~Sa'~DSI ILL'8668 ESa'NDSI ~S~'~VDl I68'~SZ8~ ~Sd'NVDI ~SS'DOIS SS6'LZ ~SS'NHSS ~S~'HDIS 000'09SII 0000000000 89 ~ I I 6 0 00 000 0000000000 89 ~ I I 6 0 00 000 0000000000 89 ~ I I 6 0 00 000 0000000000 89 ~ I I 6 0 00 000 0000000000 89 ~ I I 6 0 00 000 0000000000 89 ~ ~ I 6 0 00 000 0000000000 89 ~ I I 6 0 00 000 0000~00000 89 ~ I I 6 0 00 000 0000000000 89 ~ I I 6 0 00 000 0000000000 89 ~ I I 6 0 00 000 0000000000 89 ~ I I 6 0 00 000 00 L~S90S SSD ~S8 JDSI 00 LES90S SdD ~Sd ONDI 00 L~S90S SSD ~Sd NVDI 00 L~S90S SdD ESd DVS~ 00 L~S90S SdD Egd ~DV8 00 /~fi90fi ESd 00 LES90S ~D ESd DOIS 00 /ZS90S ~D ESd NHSS 00 LES90S ~d ESd IHd£ 00 L~S90S ~D ~Sd 00 LES90S IH ld3Q (X~H) ~OOD M~93 dM¥S 8H~N OOM SSYqD ~dA_L OOq ~ a~OaO OI SS~DO~d ~8~ ~ZIS 8~N 8~N ~9I~ IdV IdV IdW Id¥ ~DIA~S IIN~ A~S ~VN :~DVd OZ:OI S661-NRF-6E ** NYHD - 3dAi 13S ** u~u~D 6ui~nd~oD eMsel¥ us6u~qmnlq~S 6ul~s!q uo!%eo!~ia~A ~de£ SIq LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE TRAILER **~* FILE NAME : EDIT .009 SERVICE : FLIC VERSION : ~01C~1 DATE : 95/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .O10 SERVICE : FLIC VERSION : 001C01 DATE : 95/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 29-JUN-1995 10:30 PAGE: 33 FILE HEADER FILE NUMBER RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP $ LOG HEADER DATA 11559.0 11050.0 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) VENDOR TOOL CODE TOOL TYPE 31-MAY-9S 42.2 1030 31-MAY-g5 11579.0 11562.0 10~50.0 llSSS.M 1800.M NO TOOL NUMBER TDTP GAMMA RAY CGRS-A-862 TDTP THERMAL DECAY CPLC-A-867 TDTP THERMAL DECAY TDIC-A-817 TDTP THERMAL DECAY TNC-P-X2 TDTP THERMAL DECAY TNG-P-21 TDTP THERMAL DECAY LIS Tape Veri¢ication Listing Schlumberger Alaska Computing Cen%er 29-JUN-1995 10:30 PAGE: 34 TDTP THERMAL DECAY TDTP THERMAL DECAY $ 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): 47.0 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): 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): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO USIT DATED 2/3/94 · *** JOB SEQUENCE 1 ) PUMPED 250 BBLS CRUDE 2) MADE 1ST BASE PASS 3) PUMPING AT 1BPM 4) MADE 2ND AND 3RD BASE PASSES 9366.0 BORAX WATER 5) MADE 1ST BORAX PASS - 20 BBLS OF BORAX WATER INTO PERFS LIS FORMAT DATA LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Computing Cen~er 29-JUN-[995 [0:30 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ~ 66 0 2 66 0 3 73 92 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT ~1 66 11 12 68 13 66 0 14 6~ FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** PAGE: 35 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 506527 00 000 00 0 10 1 1 4 68 0000000000 SIGM PS3 CU 506527 Oe 000 00 0 10 1 1 4 68 0e00000000 TPHI PS3 PU 506527 00 000 ~0 0 10 1 1 4 68 0000000000 SBHF PS3 CU 506527 00 000 00 0 1~ 1 1 4 68 0000000000 SBHN PS3 CU 506527 90 999 99 9 19 1 1 4 68 9999999999 SIGC PS3 CU 596527 99 999 99 9 19 1 1 4 68 9999999999 SIBH PS3 CU 596527 99 999 99 9 19 1 1 4 68 9999999999 TEAT PS3 596527 99 999 99 9 19 ! 1 4 68 9999990999 LC91 PS3 596527 99 999 99 9 19 1 1 4 68 9999999999 SDSI PS3 CU 596527 99 999 99 9 19 1 1 4 68 9999999999 BACK PS3 CPS 596527 99 999 99 9 19 1 1 4 68 9999999999 FBAC PS3 CPS 596527 99 999 99 9 19 1 1 4 68 9999999999 TCAN PS3 CPS 596527 99 999 99 9 19 1 1 4 68 9999999999 TCAF PS3 CPS 596527 99 099 99 0 10 1 1 4 68 9999~90999 TCND PS3 CPS 596527 99 999 99 9 19 1 1 4 68 9999999999 TCFD PS3 CPS 596527 99 999 99 9 19 1 1 4 68 9999999999 TSCN PS3 CPS 596527 99 999 99 9 19 1 1 4 68 9999999999 TSCF PS3 CPS 596527 99 999 99 9 19 1 1 4 68 9999999999 INND PS$ CPS 596527 99 999 99 9 19 1 1 4 68 9999999999 INFD PS3 CPS 596527 99 999 99 9 19 1 1 4 68 9999999990 TENS PS3 LB 596527 99 999 99 9 19 1 1 4 68 9999999999 GR PS3 GAPI 596527 99 999 99 9 19 1 1 4 68 9999999999 CCL PS3 V 596527 99 999 99 9 10 1 1 4 68 9999990990 LIS Tape Verification Listing Schlumberger Alaska Computing Center DATA 29-JUN-1995 10:30 DEPT. 11560.009 SIGM.PS3 15.125 TPHI.PS3 SBHN.PS3 36.196 SIGC.PS3 2.685 SIBH.PS3 LCO1.PS3 2.505 SDSI.PS3 9.429 BACK.PS3 TCAN.PS3 46699.742 TCAF.PS3 18643.922 TCND.PS3 TSCN.PS3 9078.324 TSCF.PS3 3624.337 INND.PS3 TENS.PS3 1299.009 GR.PS3 ?9.750 CCL.PS3 ** END OF DATA 27.844 36.196 187.862 29715.344 1992.917 9.099 SBHF.PS3 TRAT.PS3 FBAC.PS3 TCFD.PS3 INFD.PS3 PAGE: 36 27.172 1.852 49.814 9667.557 485.862 · **, FILE TRAILER ,,,, FILE NAME : EDIT .919 SERVICE : FLIC VERSION : 991C91 DATE : 95/96/29 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT SERVICE : FLIC VERSION : 991C91 DATE : 95/96/29 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 11 RAW CURVES Curves and log header data ~or each pass in separate Giles; raw background pass in last ~ile PASS NUMBER: 4 DEPTH INCREMENT: 0.50~9 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 11559.9 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): 11396.9 31-MAY-95 42.2 1939 31-MAY-95 11579.9 11562.9 LIS Tape Veri{ication Listing Schlumberger Alaska Computing Center 29-JUN-~995 10:30 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 10050.0 11558.0 1800.0 NO TOOL NUMBER TDTP GAMMA RAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY $ CGRS-A-862 CPLC-A-867 TDIC-A-817 TNC-P-X2 TNG-P-21 BOREHOLE AND CASING DATA OPEN HOLE BlT SIZE (IN): DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 9366.0 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): BORAX WATER 47.0 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): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): O FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): O NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO USIT DATED 2/3/94 JOB SEQUENCE PAGE: 37 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1995 1B:3e 1 ) PUMPED 25B BBLS CRUDE 2) MADE 1ST BASE PASS 3) PUMPING AT 1 BPM 4) MADE 2ND AND 3RD BASE PASSES 5) MADE lST BORAX PASS - 2B BBLS OF BORAX WATER INTO PERFS $ LIS FORMAT DATA PAGE: 38 ** DATA FORMAT SPECIFICATION RECORD ** SET tYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 B 3 73 88 4 66 5 66 6 73 7 65 8 68 9 65 FT 12 68 ~3 66 B 14 65 FT 15 66 68 16 66 B 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 5B6527 BO OBB Be e ll 1 I 4 68 0000000000 SIGM PS4 CU 506527 Be oBe Be 0 il 1 1 4 68 0B00000000 TPHI PS4 PU 506527 00 eBB 00 0 ll 1 1 4 68 0000000000 SBHF PS4 CU 506527 Be eBB Be 0 11 1 1 4 68 eBeBeBBBBB SBHN PS4 CU 5B6527 Oe oeo Be e ll 1 1 4 68 ooeeeoBooe SIGC PS4 CU 506527 Be e00 00 e 11 1 1 4 68 00000000B0 SIBH PS4 CU 506527 Be 000 00 0 11 1 1 4 68 000Booe000 TEAT PS4 506527 eo 00e Be 0 11 1 1 4 68 oeeeeoeoee SDSI PS4 CU 5B6527 Be 00B eo 0 11 1 1 4 68 e000000000 BACK PS4 CPS 506527 Be eoe oB e 11 1 1 4 68 00000000B0 FBAC PS4 CPS 506527 Be B00 00 e ll 1 1 4 68 00e0000000 TCAN PS4 CPS 5B6527 Be Bee oe e ll ~ 1 4 68 BOOOeOOOBO TCAF PS4 CPS 5B6527 Be oee 00 0 ~ ~ ~ 4 68 OBOOOB0000 TCND PS4 CPS 5B6527 Be BBO Be 0 ll 1 ~ 4 68 0000eOB000 : 39I~ 09 : 38A± ~0I : 3ZIS D3W X¥~ 6~/90/S6 : 3±¥0 IODI00 : NOISW3^ DI9~ : EIO' 1103 : 3~VN : 3qI~ 1SV9 09 : 38A£ 39I~ ~EOI : 3ZIS D3B XV~ 6E/90/S6 : 3lVO IODI00 : NOIS~3A IIO' lIO3 : 3~VN 39I~ ** VlVO dO ON3 ** 000'SEmi S6A'8Z88 96Z'I £66'SS 000'00~I II0'0~8 606'8~Z~ SS6'0 SS0'88 ffSS'SN3I 818'E6~ PSS'NDSI 0I~'S0~0I ~SS'NVDI E9P'IS ~Sd'l¥~l LIE'LOI ~SS'~HBS ~68'~ ~S8'SN3i Z~S'S65 ~Sd'NDSi ~S8'1¥~1 668'S~I ~SS'O~NI SlO'S~O~ ~SS'ONNI ZZS'S~ES ~SS'dDSI ~SS'O~DI 8SL'8L~E ~SS'ONDI ~Z9'L9ZSE ~SS'~VDI ~Sd'D¥8~ LSs'IgI ~SS'~DV8 99I'0 ~SS'ISOS ~SS'HSIS 89I'0 ~SS'DDIS 00~'6L ~SS'NHSS PSS'IHSI 9SL'OI ~SS'HOIS 00S'Z6ZII '1830 000'0 ~S8'qDD 000'8Z ~S8'O~NI SS9'8~8I ~S8'ONNI 9SE'6L$ ~S8'O~DI LS6'I619 ~S~'ONDI LIE'IgIs ~S8'3V8~ SZS'S8~ ~S8'~DV8 L88'0 ~SS'ISGS ~Sd'HBIS ES~'O ~Sd'DOIS L~O'~OI ~SS'NHSS ~Sd'IHdl SSS'~ ~Sd'ROIS 000'0gsII '1830 ** V1VO ** 0000000000 89 P I I II 0 00 000 00 0000000000 89 P I I II 0 00 000 00 0000000000 89 P I I II 0 00 000 00 LES90S B9 ~S8 SN3I 0000000000 89 ~ I I II 0 00 000 00 LES90S S~D ffS~ O~NI 0000000000 89 ~ I I II 0 00 000 00 LES90S SSD ~S8 ONNI 0000000000 89 ~ I I II 0 00 000 00 /ES90S 0000000000 89 ~ I I II 0 00 000 00 LES90S SSD ~S8 NDS± 0000000000 89 ~ I I II 0 00 000 00 /ES90S SSD (X3H) 3003 R393 dM¥S eMnN OOM SSVq3 3dkl OOq $ ~30~0 OI SS3DO~d ~d3~ 3ZIS 8~nN 8~nN 39I~ IdV IdV IdV IdV 3DIA~3S lINn A~3S 3MVN 6Z :30V8 OS:OI S66I-N~F-6E ue~ueD 6ui~ndmoD e~Sel¥ ue6u~qmnl4oS 6u!%s!9 u°!~e°!~!ue^ edel SI9 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1995 10:30 PAGE: 40 FILE HEADER FILE NUMBER RAW CURVES Curves and log header data for each pass in separa%e files; raw background pass in las% file PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP $ LOG HEADER DATA 11559.0 ~[396.0 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) VENDOR TOOL CODE TOOL TYPE 3J-MAY-95 42.2 1030 31-MAY-95 [[579.0 [[562.0 10050.0 1800.0 NO TOOL NUMBER TDTP GAMMA RAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY $ 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 CGRS-A-862 CPLC-A-867 TDIC-A-817 TNC-P-X2 TNG-P-2I 9366.0 BORAX WATER 47.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-~995 10:30 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): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30090 TOOL STANDOFF (IN): REMARKS: TIED INTO USIT DATED 2/3/94 · ,. JOB SEQUENCE ,~* 1 ) PUMPED 259 BBLS CRUDE 2) MADE 1ST BASE PASS 3) PUMPING AT 1BPM 4) MADE 2ND AND 3RD BASE PASSES 5) MADE 1ST BORAX PASS - 29 BBLS OF BORAX WATER INTO PERFS $ LIS FORMAT DATA PAGE: 41 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ~* TYPE REPR CODE VALUE 1 66 9 2 66 9 3 73 88 4 66 5 66 6 73 7 65 8 68 9.5 9 65 FT 12 68 13 66 9 14 65 FT 15 66 68 16 66 0 66 ** VL¥O ~00N~ 000'S68~ 86S'S~$8 ~86'~6~ 90~'~ ~S~'09 000'0I~I 9~8'0 ~S6'L8 SS~'SN~I LZ~'SS~ SS~'NV31 SS~'1¥~1 LIZ'80~ SS~'~HSS 606'~I SS~'SN~I 6LL'90~ SS~'NDSI 860'9IIE SS~'NVDI 6SI'ES SSd'lV~l 6SS'SS~ SSd'~HSS S80'0~ 000'0 SS8'qDD S~9'E8 SS8'~9 SS8'OdNI AIS'E~OE SS8'QNNI 618'I9IS SSd'dDSI SSd'O~3± I'~9'8~8I~ SS~'QNDI zzg'~698E SS~'HSIS S8I'O SS~'D~IS I8A'SZ SS~'NHSS SSd'IHdl ~S~'OI SSd'~OIS 000"S6ZII 000'0 SSS'qD3 SL8'09I SSS'Q~NI ~ZZ'~SSI SSS'QNNI ISE'l~ SSS'BDS£ SSS'Q~DI ~O~'LISS SSS'GNDI ~8~'9ZIS SSS'~VDI SS~'DVS~ E00'~ SS~'~DV8 SO~'I SS~'ISQS SS~'HSIS ESL'O SS8'30IS gSS'III SS~'NHSS SS~'IH~l 89~'LE SS~'~OIS 000'09SII ** VIVO ** 0000000000 89 ~ I I ~I 0 00 000 00 0000000000 89 ~ I ~ ~I 0 00 000 00 A~S90S 8q SS~ SN~I 0000000000 89 ~ I I ~I 0 00 000 00 L~S90S SdD SSd Q~Dl 0000000000 89 ~ I I EI 0 00 000 00 ZES90S S~D SS~ NVDI 0000000000 89 ~ I I ~I 0 00 000 00 ZES90S 0000000000 89 ~ I Z EI 0 00 000 00 ZES90S SS~ IV~I 0000000000 89 ~ I I ~I 0 00 000 00 ZES90S ~D SS~ DOIS (X3H) 300D ~393 a~VS B~RN qO~ SSVqD 3ail 009 $ B3qaO OI SS3gOaa ~a3~ 3ZIS B~RN B~N 39I~ IaV IaV IaV I~V 3DIA~3S ±INR A~3S 3~VN E~ :30V~ OZ:OI S66I-N~F-6E ** NVHD - 3d,k_L 13S ** ue~u~g 6u!~ndmoD e~selV 6u!~s!9 uo!~eo!~!UeA ~del LIS Tape Verification Listing Schlumberger Alaska Computing Center *-*, FILE TRAILER *,*- FILE NAME : EDIT .012 SERVICE : FLIC VERSION : ~iC~l DATE : 95/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 29-JUN-1995 10:30 PAGE: 43 **** FILE HEADER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : 001C01 DATE : 95/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 13 RAW CURVES Curves and log header data for each pass in separate files; rawbackground pass in last file PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP $ LOG HEADER DATA 11559.0 11396.0 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) VENDOR TOOL CODE TOOL TYPE 31-MAY-95 42.2 1030 31-MAY-95 11579.0 11562.0 10050.0 ii558.9 1899.9 NO TOOL NUMBER TDTP GAMMA RAY CGRS-A-862 TDTP THERMAL DECAY CPLC-A-867 TDTP THERMAL DECAY TDIC-A-8i7 TDTP THERMAL DECAY TNC-P-X2 TDTP THERMAL DECAY TNG-P-21 TDTP THERMAL DECAY LIS Tape Verifica%ion Lis%lng Schlumberger Alaska Computing Cen~er 29-JUN-1995 10:30 PAGE: 44 TDTP THERMAL DECAY TDTP THERMAL DECAY $ 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): 47.0 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): BLUELINE COUNT RATE NORMALIZATION IN OIE 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): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO USIT DATED 2/3/94 *** JOB SEQUENCE *** 1 ) PUMPED 250 BBLS CRUDE 2) MADE 1ST BASE PASS 3) PUMPING AT ~ BPM 4) MADE 2ND AND 3RD BASE PASSES 9366.0 BORAX WATER 5) MADE 1ST BORAX PASS - 20 BBLS OF BORAX WATER INTO PERFS $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-%995 10:3e DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 PAGE: 45 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 506527 00 000 00 0 13 1 I 4 68 e000000000 SIGM PS6 CU 506527 00 000 00 0 13 I I 4 68 00000e0000 TPHI PS6 PU 506527 00 000 00 0 13 I I 4 68 0000000000 SBHF PS6 CU 506527 00 ' 000 00 0 13 1 I 4 68 0000000000 SBHN PS6 CU 506527 00 00~ 00 0 13 1 1 4 68 0000000000 SIGC PS6 CU 506527 00 009 99 9 13 1 1 4 68 0999999999 SIBH PS6 CU 596527 90 999 99 9 13 1 1 4 68 9990999999 TRAT PS6 596527 90 999 99 9 13 1 ! 4 68 9999999999 SDSI PS6 CU 596527 99 999 09 9 13 1 1 4 68 0999999999 BACK PS6 CPS 596527 90 999 99 9 13 1 1 4 68 9999999999 FBAC PS6 CPS 596527 90 999 09 9 13 1 1 4 68 9999999999 TCAN PS6 CPS 596527 99 990 99 0 13 1 1 4 68 0999999999 TCAF PS6 CPS 596527 99 990 09 9 13 1 1 4 68 9999999999 TCND PS6 CPS 596527 99 999 99 9 13 1 1 4 68 0999999999 TCFD PS6 CPS 596527 99 999 09 9 13 1 1 4 68 9999909999 TSCN PS6 CPS 596527 90 999 99 9 13 1 1 4 68 9999099999 TSCF PS6 CPS 596527 99 099 90 9 13 1 1 4 68 0999999990 INND PS6 CPS 596527 99 099 09 9 13 1 1 4 68 0909999099 INFD PS6 CPS 596527 99 999 90 9 13 1 1 4 68 9999999999 TENS PS6 LB 596527 90 099 09 9 13 1 1 4 68 9999999999 GR PS6 GAPI 596527 99 999 99 9 13 1 1 4 68 0999999099 CCL PS6 V 596527 99 099 90 9 13 1 1 4 68 9000999999 00-SIZOE-6~O-OS 'A¥8 30HQ~ '8~0-~I SQ 'DNI ¥~S¥9¥ OD~¥ : ±N3~OD : q~ S~OIA~8 : ~ NOI±¥hNI±NOD II,S6 : 3~¥N 933B DIqJ : NIOIBO 6E/90/S6 : 31¥0 lIO3 : 3~VN 3DIA~3S 00-SIZOE-6ZO-OS 'AV8 30HQR~d 'B~O-~I SO 'DNI V~SVqV OD~V : IN3~OD : ~VI SROIA~ I : # NOIIVRNI±NOD ~I~S6 : 3~VN 3dVl DIq~ : NI~I~O 6~/90/S6 : 31VQ lI~ : ~¥N ~DIA~S : 39I~ IS¥9 09 : 3dXi 39I~ ~0~ : 3ZIS D3W X¥~ 6~/90/S6 : IOD~00 : NOIS~3A DIq~ : 3DIA~3S ZIO' IIQ3 : 3~VN 39I~ ** VIVQ ~0 ON3 ** 000'S0~ EZ6'LSSB 9S9'8ZSE~ 80P'I ~09'09 000'S8SI SP8'0 Egg'sB 9~ :30¥d 9Sd'SN3I OL~'SLP 9Sd'NDSI ~SS'6966 9Sd'NVDI I99'0~ 9Sd'lV~l SZ~'ZOI 9S~'~H8S S9I'SI 9Sd'SN31 9Sd'NDSI 9Sd'NVD1 9$d'£V~l ~Z6'9~I 9Sd'dhBS LB~'S 000'0 9Sd'qDD 890'SOI 9Sd'~O 9Sd'Q~NI 6~I'~96~ 9Sd'ONNI SSO'9SOS 9Sd'JDSl 9Sd'~dDl 99~'~SI~ 9Sd'ONDI 60~'S~6~ 9Sd'~¥Ol 9Sd'DVS~ ES6'SSI 9Sd'~DV8 ZZ~'O 9Sd'ISQS 9Sd'HSIS ~I'0 9Sd'DOIS 910'£Z 9Sd'NHSS 9Sd'IHdl 8~Z'OI 9Sd'~OIS 00S'~6EII 'ld3q 010'0 9Sd'qDD 00S'~9~ 9Sd'~O 9Sd'G~NI S~S'L~8I 9Sd'QNNI 6~9'8IZ 9Sd'~DSI 9Sd'Q~DI SSI'888~ 9Sd'QNDI 8E~'L6SI 9Sd'DVSJ 06g'S0~ 9Sd'~DV8 9~0'~ 9Sd'ISQS 9Sd'HSIS 000'0 9S~'DOIS 9IS'ZII 9Sd'NHSS 9Sd'IHd± 6Eg'II 9Sd'~OIS 000'09SII 0~:0I S66I-NaF-6a ** ¥1Vq ** a~u~D 8ul~nd~oD e~selV J~6a~qmnl4~S Sul~s!9 uol~e~l$la~A ~del LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE . 97/10/23 ORIGIN : FLIC REEL NAM~ : 97486 CONTINUATION # : PREVIOUS REEL : CO~_I~T : ARCO ALASKA INC., PRUDHOE BAY, D.S. 14-2B, API# 50-029-20318-02 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/10/23 ORIGIN . FLIC TAPE NA~iE : 97486 CONTINUATION # : 1 PREVIOUS TAPE : CO~fENT : ARCO ALASKA INC. j PRUDHOE BAY, D.S. 14-2B, API# 50-029-20318-02 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 14-2B API ~ER: 500292031802 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 23-0CT-97 JOB NU~4~ER: 97486 LOGGING ENGINEER: J. SPENCER OPERATOR WITNESS: K. MARTIN SURFACE LOCATION SECTION: 9 TOWNSHIP: 1 ON RANGE: 14E FNL : 12 62 FSL : FEL: 1228 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 67.60 DERRICK FLOOR: 67.60 GROUND LEVEL: 42.90 WELL CASING RECORD 1ST STRING 2NDSTRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 13.375 2732.0 72.00 9.625 9366.0 47.00 7.000 11615.0 29.00 4.500 11435.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (M~EASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUAIBER: PASS AU3BiBER: DATE LOGGED: 16-JAN-94 LOGGING COMPANY: WESTERN-ATLAS BASELINE DEPTH 88888.0 11550.5 11549.5 11547.0 11539.0 11537.0 11533.5 11524.5 11519.5 11518.0 11513.0 11510.0 11503.5 11491.0 11489.0 11480.5 11465.5 11457.0 11450.0 11448.0 11440.5 11432.0 11411.0 11410.5 11408.0 11406.5 11390 5 11389 0 11378 0 11357 0 11349 5 11346 0 11342 5 11315.0 11314.5 11312.5 11310.0 11307.0 11301.0 11271.5 11271.0 11254.0 11253.5 11232.5 11223.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88889.0 88892.0 11550.5 11541.5 11538.5 11523.5 11519.0 11512.5 11504.0 11491.5 11479.0 11464.5 11448.5 11413.5 11410.0 11391.5 11380.5 11351.5 11348.0 11317.0 11315.0 11309.5 11303.0 11274.0 11256.0 11225.5 11554.5 11550.5 11538.0 11524.0 11512.5 11491.5 11457.5 11450.0 11440.5 11434.0 11413.5 11409.5 11391.5 11358.5 11343.5 11317.0 11312.5 11274.0 11256.0 11234.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 11218.0 11219.5 11215.0 11217.0 11195.0 11197.0 11194.0 11196.5 11188.0 11189.5 11187.0 11189.5 11176.5 11178.5 11176.0 11177.0 11173.5 11175.0 11155.0 11156.5 11154.5 11156.5 11146.5 11148.0 11148.0 11141.0 11142.5 11118.0 11119.0 11114.5 11115.5 11115.5 11093.5 11095.5 11081.5 11082.5 11074.5 11075.5 11075.5 11068.5 11070.5 11066.5 11068.0 11062.5 11062.5 11061.0 11062.0 11053.5 11054.5 11053.0 11054.5 11043.0 11043.5 11042.0 11043.5 11008.0 11008.0 11007.5 11008.5 10995.0 10997.0 10994.5 10997.0 10987.0 10988.0 10986.0 10988.0 10984.5 10986.5 10981.0 10982.5 10980.5 10982.5 10977.5 10978.0 10976.5 10977.5 10975.5 10975.5 10972.0 10972.5 10971.5 10972.5 10969.0 10970.0 10961.5 10962.0 10959.0 10959.5 10955.0 10956.0 10954.5 10956.0 10942.0 10943.5 10943.0 10939.5 10940.0 10940.0 10936.5 10937.5 100.0 101.0 100.5 $ CONTAINED HEREIN IS THE LDWG FORMATTED 3 PASS CASED HOLE CNTG DATA ACQUIRED ON ARCO ALASKA'S D.S. 14-2B. THE DEPTH ADJUST~IENTS SHOWN ABOVE REFLECT CASED HOLE PASS #1 GR TO OPEN HOLE BCS GR, AND PASS #1 NPHI TO OPEN HOLE BCS GR CARRYING ALL CNTG CURVES WITH THE PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center NPHI SHIFTS. $ 23-0CT-1997 14:49 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTgM~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASSNUM~ER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11560.0 10934.0 CNTG 11562.0 10934.0 $ CURVE SHIFT DATA - PASS TO PASS (M~J~StUAED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS AK]M~ER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA TABLE TYPE : CONS TONI VALU DEFI CN FN WN APIN FL SECT ARCO ALASKA INC. PRUDHOE BAY DS 14-2B 50-029-20318-02 1262' FArL & 1228' FEL 9 Company Name Field Name Well Name API Serial Number Field Location Section LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 5 TONI VALU DEFI TOWN iON Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation WITN K. MARTIN Witness Name SON 1102687 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 67.60001 Above Permanent Datum EKB FT 67.60001 Elevation of Kelly Bushing EDF FT 67.60001 Elevation of Derrick Floor EGL FT 42.9 Elevation of Ground Level TDD FT 11571. Total Depth - Driller TDL FT 11569. Total Depth - Logger BLI FT 11562. Bottom Log Interval TLI FT 10932. Top Log Interval DFT WATER AND CRUDE Drilling Fluid Type TLAB 0309 23-AUG-97 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. ENPH Epithermal Neutron Porosity CPHI Compensated Neutron Poro., SS matrix, tool & Environ. Corr. IFRAT Neutron Ration Non-Dead time Corrected (N/F) CRAT Neutron Ratio, Dead Time Corrected (RN/RF) ENRA Epithermal Neutron Ratio Calibrated NCNT Raw Near Detector Count Rate, Dead Time Corrected FCNT Raw Far Detector Count rate, Dead Time Corrected CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate CNEC Corrected Near Epithermal Counts CFEC Corrected Far Epithermal Counts GRCH Gamma Ray in Casing TENS Surface Tension CCL CCLAmplitude GR API-Corrected Gamma Ray LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 68 66 1 66 0.5 FT 15 0 FT 68 1 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1102687 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11600.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23~0CT-1997 14:49 PAGE: GR. BCS 33. 989 DEPT. 10900.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG ArRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG GR.BCS 83.680 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE : 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA2~E : EDIT .002 SERVICE . FLIC VERSION · O01CO1 DATE . 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE 1VU~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS N-J~i~ER : 2 DEPTH INCRE~iF2~f: 0.5000 FILE SUNk~IRY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11558.0 10932.0 CNTG 11562.0 10932.0 $ CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUAi~ER : 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PA GE: BASELINE DEPTH GRCH CNTG 88888.0 88890.0 88885.0 11557.5 11554.5 11550.5 11547.0 11548.5 11550.5 11542.5 11545.5 11539.0 11541.5 11536.5 11538.0 11535.0 11533.5 11524.0 11524.0 11520.5 11519.5 11519.5 11520.0 11496.5 11497.5 11490.5 11491.5 11486.5 11489.0 11483.5 11485.0 11481.0 11483.0 11475.0 11478.5 11474.0 11475.5 11469.0 11470.0 11458.0 11459.0 11456.5 11456.0 11452.5 11453.5 11443.0 11443.5 11429.0 11430.5 11427.5 11429.0 11418.0 11419.5 11415.5 11417.0 11417.0 11406.0 11408.5 11402.0 11404.5 11401.0 11402.5 11396.0 11396.5 11390.0 11391.5 11377.0 11378.5 11373.0 11375.5 11369.5 11370.0 11353.0 11353.0 11350.0 11352.0 11346.0 11346.5 11343.0 11343.5 11337.0 11337.5 11329.0 11330.0 11315.5 11317.0 11313.0 11315.0 11301.0 11303.5 11297.5 11299.5 11293.0 11295.5 11272.0 11274.0 11271.5 11274.0 11262.0 11265.0 11254.5 11256.5 11253.5 11256.0 11245.5 11247.0 11232.0 11234.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 11231.0 11233.0 11229.0 11230.0 11225.0 11227.0 11217.0 11218.5 11215.5 11217.5 11213.0 11215.5 11198.5 11200.5 11195.0 11197.5 11188.0 11189.5 11187.5 11189.5 11173.5 11175.0 11173.0 11175.0 11165.0 11167.0 11162.0 11163.5 11157.0 11159.0 11154.5 11156.5 11156.5 11150.0 11152.0 11143.5 11145.5 11140.0 11142.5 11114.0 11115.5 11113.5 11115.5 11109.0 11110.5 11105.0 11106.0 11101.5 11104.0 11098.5 11100.0 11092.5 11095.5 11081.0 11083.0 11074.0 11075.5 11073.5 11076.0 11071.0 11074.0 11066.0 11067.5 11061.0 11062.5 11060.0 11062.5 11052.5 11054.5 11052.0 11055.0 11045.0 11047.5 11042.5 11044.0 11042.0 11045.0 11014.5 11016.0 11007.5 11009.5 11005.5 11008.5 10996.5 11000.0 10994.5 10997.5 10985.5 10988.0 10984.5 10988.0 10979.0 10982.5 10975.0 10978.0 10972.0 10975.0 10969.5 10972.5 10967.5 10970.0 10967.0 10969.5 10966.0 10968.0 10964.5 10967.0 10957.0 10959.5 10954.0 10956.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 10 10951.0 10953.5 10947.5 10950.0 10946.0 10942.5 10940.5 10937.5 100.0 102.5 $ 10948.5 10945.0 10943.0 10940.0 102.5 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN PASS #2 GRCHAND PASS #1 GRCH, AND NPHI PASS #2 AND NPHI PASS #1 CARRYING ALL CNTG CURVES WITH NPHI SHIFTS. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 14-2B Well Name APIN 50- 029 -20318- 02 API Seri al Number FL 1262' FNL & 1228' FEL Field Location SECT 9 Se c t i on TOWN 1 ON Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN K. MARTIN Wi tness Name SON 1102687 Service Order Number PDAT MSL Permanent da turn EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 67.60001 Above Permanent Datum EKB FT 67. 60001 Elevation of Kelly Bushing EDF FT 67. 60001 Elevation of Derrick Floor EGL FT 42.9 Elevation of Ground Level TDD FT 11571. Total Depth - Driller TDL FT 11569. Total Depth - Logger BLI FT 11562. Bottom Log Interval TLI FT 10932. Top Log Interval DFT WATER AND CRUDE Drilling Fluid Type TLAB 0309 23-AUG-97 Time Logger at Bottom LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 11 TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. ENPH Epithermal Neutron Porosity CPHI Compensated Neutron Poro., SS matrix, tool & Environ. Corr. NRAT Neutron Ration Non-Dead time Corrected (N/F) CRAT Neutron Ratio, Dead Time Corrected (RN/RF) ENRA Epithermal Neutron Ratio Calibrated NCNT Raw Near Detector Count Rate, Dead Time Corrected FCNT Raw Far Detector Count rate, Dead Time Corrected CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate CNEC Corrected Near Epithermal Counts CFEC Corrected Far Epithermal Counts GRCH Gamma Ray in Casing TENS Surface Tension CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 16 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 23-0CT-1997 14:49 PAGE: 12 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD N[¢4~ SAMP ELEM CODE (HEX) DEPT FT 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1102687 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11560.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 48.719 TENS.CNTG -999.250 CCL. CNTG DEPT. 10934.500 NPHI.CNTG 23.421 ENPH. CNTG 17.631 CPHI.CNTG NRAT. CNTG 2.798 CRAT. CNTG 2.687 ENRA.CNTG 3.259 NCNT. CNTG FCNT. CNTG 860.437 CNTC. CNTG 2289.821 CFTC. CNTG 876.500 CNEC. CNTG CFEC. CNTG 1324.777 GRCH. CNTG 136.250 TENS.CNTG 2950.000 CCL.CNTG -999.250 -999.250 -999.250 -999.250 25.360 2250.095 4318.053 0.053 ** END OF DATA ** **** FILE TRAILER **** FILE NA~iE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 13 **** FILE HEADER **** FILE NA~iE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUAiBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NU~BER: 3 DEPTH INCRE~!ENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11558.0 10936.0 CNTG 11562.0 10936.0 $ CURVE SHIFT DATA - PASS TO PASS (f~EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: 1 BASELINE DEPTH 88888.0 11552.0 11550.0 11544.5 11542.5 11540.5 11537.0 11536.0 11525.0 11524.5 11519.5 11519.0 11513.5 11505.5 11498.0 11494.0 11474.0 11462.0 11457.5 11451.0 11441.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG 88888.5 88890.5 11554.5 11550.5 11545.5 11542.0 11540.0 11538.0 11533.5 11523.5 11524.0 11519.5 11518.0 11513.0 11504.0 11497.5 11493.0 11473.5 11462.0 11457.5 11450.0 11442.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 14 11437.5 11438.0 11433.5 11434.0 11431.5 11432.5 11427.5 11429.0 11418.0 11420.0 11415.5 11417.5 11409.5 11410.0 11409.0 11410.0 11401.0 11403.0 11390.5 11391.5 11390.0 11391.5 11377.5 11378.5 11376.0 11377.5 11375.0 11376.0 11374.0 11375.5 11367.0 11367.5 11351.0 11352.5 11349.5 11351.5 11345.5 11346.5 11343.0 11343.5 11328.5 11330.0 11321.0 11322.5 11316.0 11317.0 11313.0 11315.0 11308.5 11310.0 11306.5 11307.0 11293.0 11295.0 11275.5 11276.5 11272.0 11274.0 11271.5 11274.0 11270.0 11272.5 11259.5 11261.0 11255.0 11256.0 11254.0 11256.0 11240.5 11241.5 11236.5 11237.5 11234.5 11236.5 11231.5 11233.5 11227.0 11228.5 11221.0 11223.0 11219.0 11220.0 11215.5 11217.0 11214.0 11215.5 11213.0 11215.0 11211.5 11211.5 11198.0 11199.5 11193.5 11195.0 11190.5 11192.5 11187.5 11189.5 11184.5 11186.0 11182.5 11184.0 11177.0 11177.5 11173.5 11175.0 11171.5 11172.5 11165.5 11167.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 15 11162.5 11163~5 11159.0 11160.0 11155.0 11156.5 11151.0 11152.5 11146.5 11148.0 11144.0 11145.0 11141.0 11142.0 11138.0 11139.0 11131.5 11132.0 11127.0 11128.5 11114.0 11115.5 11115.5 11103.5 11105.5 11092.5 11096.0 11089.0 11092.0 11085.0 11087.0 11074.5 11076.0 11076.0 11062.0 11062.5 11060.0 11062.0 11053.0 11054.5 11052.5 11054.5 11043.0 11045.0 11042.5 11043.5 11041.5 11043.0 11037.5 11039.5 11033.0 11034.5 11034.0 11024.0 11025.0 11015.0 11016.0 11008.0 11009.5 11006.5 11008.5 11006.0 11007.0 10998.5 11000.5 10997.5 11000.0 10995.0 10997.5 10986.5 10988.0 10985.5 10988.0 10984.5 10986.5 10979.5 10982.5 10976.5 10978.0 10975.5 10976.0 10974.0 10975.0 10971.0 10973.0 10969.0 10970.0 10968.0 10969.5 10967.0 10967.5 10960.5 10962.0 10958.0 10959.5 10955.0 10956.0 10956.0 10948.5 10950.5 10947.0 10948.5 10943.5 10945.5 10941.5 10943.0 10937.5 10939.0 100.0 102.0 101.5 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 16 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCHPASS #3 AND GRCH PASS #1, AND NPHI PASS #3 AND NPHI PASS #1 CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA TABLE TYPE : CONS TONI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Fi el d Name WN DS 14-2B Well Name APIN 50- 029 ~20318- 02 API Serial Number FL 1262' FNL & 1228' FEL Field Location SECT 9 Secti on TOWN 1 ON Township RANG 14E Range COUN NORTH SLOPE Court ty STAT ALASKA State or Province NATI USA Na ti on WITN K. MARTIN Witness Name SON 1102687 Service Order Number PDAT MSL Permanent da tum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 67.60001 Above Permanent Datum EKB FT 67. 60001 Elevation of Kelly Bushing EDF FT 67.60001 Elevation of Derrick Floor EGL FT 42.9 Elevation of Ground Level TDD FT 11571. Total Depth - Driller TDL FT 11569. Total Depth - Logger BLI FT 11562. Bottom Log Interval TLI FT 10932. Top Log Interval DFT WATER AND CRUDE Drilling Fluid Type TLAB 0309 23-AUG-97 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT NPHI ENPH CPHI NRAT CRA T ENRA NCNT Depth Compensated Neutron Porosity, SS Matrix, cali & dead time corr. Epi thermal Neutron Porosity Compensated Neutron Poro., SS matrix, tool & Environ. Corr. Neutron Ration Non-Dead time Corrected (N/F) Neutron Ratio, Dead Time Corrected (RN/RF) Epithermal Neutron Ratio Calibrated Raw Near Detector Count Rate, Dead Time Corrected LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 17 DEFI FCNT Raw Far Detector Count rate, Dead Time Corrected CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate CNEC Corrected Near Epithermal Counts CFEC Corrected Far Epithermal Counts GRCH Gamma Ray in Casing TENS Surface Tension CCL CCLAmplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 64 66 1 0.5 FT 16 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 EIVRA CNTG 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUME SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) CNEC CNTG CPS 1102687 O0 000 O0 0 3 1 I 4 68 0000000000 CFEC CNTG CPS 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1102687 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11564.500 NPHI.CNTG 48.558 ENPH. CNTG 56.303 CPHI.CNTG NRAT. CNTG 4.469 CRAT. CNTG 4.066 ENRA.CNTG 6.916 NCNT. CNTG FCNT. CNTG 307.589 CNTC. CNTG 1274.473 C?TC. CNTG 323.774 CNEC. CNTG CFEC. CNTG 333.119 GRCH. CNTG -999.250 TENS.CNTG 2875.000 CCL.CNTG DEPT. 10937.500 NPHI.CNTG 22.917 ENPH. CNTG 18.594 CPHI.CNTG NRAT. CNTG 2.802 CR~T. CNTG 2.660 ENRA.CNTG 3.378 NCNT. CNTG FCNT. CNTG 797.040 CNTC. CNTG 2335.113 C?TC. CNTG 880.303 CNEC. CNTG CFEC. CNTG 1339.487 GRCH. CNTG -999.250 TENS. CNTG 2865.000 CCL.CNTG 46.323 1132.198 2304.013 0.059 25.957 2219.676 4524.925 0.001 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~I~ : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 19 DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUFIBERS CNTG 1, 2, 3, $ REMARKS: THIS FILE CONTAINS THE ARI77H4~TIC AVERAGE OF 3 CASED HOLE CNTG PASSES. ALL CLIPPING AND DEPTH SHIFTING WAS PERFORMED BEFORE AVERAGE WAS MADE. $ LIS FORMAT DATA TABLE TYPE : CONS TONI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 14-2B Well Name APIN 50-029-20318-02 API Serial Number FL 1262' FNL & 1228' FEL Field Location SECT 9 Sec ti on TOWN 1 ON Township RANG 14 E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN K. MARTIN Wi tness Name SON 1102687 Service Order Number PDAT MSL Permanent da rum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 67.60001 Above Permanent Datum EKB FT 67. 60001 Elevation of Kelly Bushing EDF FT 67. 60001 Elevation of Derrick Floor EGL FT 42.9 Elevation of Ground Level TDD FT 11571. Total Depth - Driller TDL FT 11569. Total Depth - Logger BLI FT 11562. Bottom Log Interval TLI FT 10932. Top Log Interval DFT WATER AND CRUDE Drilling Fluid Type TLAB 0309 23-AUG-97 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. IV-RAT Neutron Ration Non-Dead time Corrected (N/F) LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 20 DEFI CPHI Compensated Neutron Poro., SS matrix, tool & Environ. Corr. CRAT Neutron Ratio, Dead Time Corrected (RN/RF) ENPH Epithermal Neutron Porosity ENRA Epithermal Neutron Ratio Calibrated NCNT Raw Near Detector Count Rate, Dead Time Corrected FCNT Raw Far Detector Count rate, Dead Time Corrected CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate CNEC Corrected Near Epithermal Counts CFEC Corrected Far Epithermal Counts GRCH Gamma Ray in Casing ** DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 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 SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 C~T CNAV 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 21 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NI3MB SAMP ELEM CODE (HEX) FCNT CNAV CPS 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1102687 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11561.000 NPHI.CNAV -999.250 ArRAT. CNAV CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA.CNAV FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV CFEC. CNAV -999.250 GRCH. CNTG 58.375 -999.250 CPHI.CNAV -999.250 NCNT. CNAV -999.250 CNEC. CNAV -999.250 -999.250 -999.250 DEPT. 10934.500 NPHI. CNAV -999.250 NRAT. CNAV -999.250 CPHI.CNAV -999.250 CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA. CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV -999.250 CFEC. CNAV -999.250 GRCH. CNTG -999.250 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NA~iE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER RAW CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 22 Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTG 11563.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIf4E 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 10930.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CNTG COMPENSATED 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): 21-AUG-97 CP42.2 309 23 -AUG-97 11571.0 11569.0 10932.0 11562.0 1800.0 NO TOOL NUMBER SGT L 1009 CNC-GB-125 11615.0 WATER AND CRUDE EP I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 23 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): 1.0 REMARKS: CORRELATED TO W.A. BHCA DATED 16-JAN-94. TAGGED TD @11569' IZlD. MADE 3 PASSES AT 1800 FPH WELL WAS BACK FLOWED WITH WATER DURING LOGGING TO KEEP IT FLUID PACKED. THE DEPTH ABOVE TUBING TAIL (11427' BiD) ARE OFF DUE TO THE EFFECT OF FLOW RATE CHANGE. THIS FILE CONTAINS RAW CNTG PASS #1. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 14-2B Well Name APIN 50- 029-20318- 02 API Serial Number FL 1262' FNL & 1228' FEL Field Location SECT 9 Sec t i on TOWN 1 ON Town ship RANG 14 E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN K. MARTIN Wi tness Name SON 1102687 Service Order Number PDAT MSL Permanent da turn EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 67.60001 Above Permanent Datum EKB FT 67. 60001 Elevation of Kelly Bushing EDF FT 67. 60001 Elevation of Derrick Floor EGL FT 42.9 Elevation of Ground Level TDD FT 11571. Total Depth - Driller TDL FT 11569. Total Depth - Logger BLI FT 11562. Bottom Log Interval TLI FT 10932. Top Log Interval DFT WATER AND CRUDE Drilling Fluid Type TLAB 0309 23-AUG-97 Time Logger at Bottom LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 24 TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. ENPH Epithermal Neutron Porosity TNPH Thermal Neutron Porosity TNRA Thermal Neutron Ratio Calibrated RTNR Raw Thermal Neutron Ratio ENRA Epithermal Neutron Ratio Calibrated CFEC Corrected Far Epithermal Counts CNEC Corrected Near Epithermal Counts RCEF Raw Corrected Epithermal Far Counts RCEN Raw Corrected Epithermal Near Counts RCNT RAW NEAR CNT COUNTS RCFT RAW FAR CNT COUNTS CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate NPOR Neutron Porosity from an Application Program GR API-Corrected Gamma Ray TENS Surface Tension CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 8 9 11 12 13 14 15 16 0 0.5 FT 13 65 68 65 66 68 66 0 65 FT 66 68 66 1 66 ! LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 25 ** SET TYPE - CHAN ** NA~iE SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) O0 000 O0 0 5 1 1 4 68 0000000000 DEPT FT 1102687 NPHI PS1 PU 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 RTAFR PS1 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 E1VRA PS1 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PS1 CPS 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 RCENPS1 CPS 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 GR PSi GAPI 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1102687 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11590.000 NPHI.PS1 51.041 ENPH. PS1 55.598 TNPH.PS1 TNRA.PS1 4.202 RTNR.PS1 4.270 E2VRA.PS1 6.866 CFEC. PS1 CNEC. PS1 2410.087 RCEF. PS1 328.105 RCEN. PS1 2152.319 RCNT. PS1 RCFT. PS1 368.063 CNTC.PS1 1642.433 CFTC. PSi 398.811 NPOR.PS1 GR.PS1 63.313 TENS.PSi 2530.000 CCL.PS1 0.013 DEPT. 10932.000 NPHI.PS1 23.734 ENPH. PS1 18.737 TNPH. PS1 TNRA.PS1 2.705 RTNR.PS1 2.879 EalrRA. PS1 3.396 CFEC.PS1 ClVEC. PS1 4372.739 RCEF. PS1 1173.484 RCEN. PS1 3864.063 RCNT. PS1 RCFT. PS1 773.541 ClFTC. PS1 2314.692 CFTC.PSi 866.472 NPOR.PS1 GR.PS1 173.125 TENS.PSi 2925.000 CCL.PS1 0.018 49.416 351.022 1593.777 49.416 26.236 1287.767 2265.251 25.943 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE : 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 26 **** FILE HEADER **** FILE NA~iE : EDIT .006 SERVICE : FLIC VERSION : 001 CO1 DATE : 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTG 11563.0 $ LOG H~ER DATA STOP DEPTH 10930.0 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) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTG COMPENSATED 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) : 21 -AUG-97 CP42.2 309 23-AUG-97 11571.0 11569.0 10932.0 11562.0 1800.0 NO TOOL NUMBER ........... SGT L 1009 CNC-GB-125 11615.0 WATER AND CRUDE LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-i997 14:49 PAGE: 27 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): EPITHERMAL SANDSTONE 2.65 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): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): 1.0 REMARKS: CORRELATED TO W.A. BHCA DATED 16-JAN-94. TAGGED TD @11569' FID. MADE 3 PASSES AT 1800 FPH WELL WAS BACK FLOWED WITH WATER DURING LOGGING TO KEEP IT FLUID PACKED. THE DEPTH ABOVE TUBING TAIL (11427' FiD) ARE OFF DUE TO THE EFFECT OF FLOW RATE CHANGE. THIS FILE CONTAINS RAW CNTG PASS #2. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN FL SECT TOWN RANG COUN STAT NATI WITN SON PDAT EPD FT LMF ARCO ALASKA INC. PRUDHOE BAY DS 14-2B 50-029-20318-02 1262' FNL & 1228' FEL 9 1 ON 14E NORTH SLOPE ALASKA USA K. MARTIN 1102687 MSL O. Company Name Field Name Well Name API Serial Number Field Location Section Township Range County State or Province Nation Wi tness Name Service Order Number Permanent da rum Elevation of Permanent Datum Log Measured From LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 28 TUNI VALU DEFI APD FT 67. 60001 EKB FT 67. 60001 EDF FT 67. 60001 EGL FT 42.9 TDD FT 11571. TDL FT 11569. BLI FT 11562. TLI FT 10932. DFT WATER AND CRUDE TLAB 03 09 23-AUG-97 Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Type Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. ENPH Epithermal Neutron Porosity TNPH Thermal Neutron Porosity TNRA Thermal Neutron Ratio Calibrated RTNR Raw Thermal Neutron Ratio ENRA Epithermal Neutron Ratio Calibrated CFEC Corrected Far Epithermal Counts CNEC Corrected Near Epithermal Counts RCEF Raw Corrected Epithermal Far Counts RCEN Raw Corrected Epithermal Near Counts RCNT RAW NEAR CNT COUNTS RCFT RAW FAR CNT COUNTS CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate NPOR Neutron Porosity from an Application Program GR API-Corrected Gamma Ray TENS Surface Tension CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 29 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 13 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 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 TNR~ PS2 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 ENNA PS2 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 RCENPS2 CPS 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1102687 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11590.000 NPHI.PS2 51.793 ENPH.PS2 52.388 TNPH. PS2 TNRA.PS2 4.244 RTNR.PS2 4.250 ENRA.PS2 6.630 CFEC. PS2 CNEC. PS2 2340.258 RCEF. PS2 316.845 RCEN. PS2 1973.482 RCNT. PS2 RCFT. PS2 318.756 CNTC. PS2 1404.645 CFTC.PS2 347.780 NPOR.PS2 GR.PS2 48.250 TENS.PS2 2300.000 CCL.PS2 0.066 DEPT. 10930.000 NPHI.PS2 21.588 ENPH.PS2 18.855 TNPH. PS2 TNRA.PS2 2.585 RTNR.PS2 2.716 ENRA.PS2 3.410 CFEC. PS2 CNEC. PS2 4329.979 RCEF. PS2 1200.714 RCEN. PS2 3945.753 RCNT. PS2 RCFT. PS2 860.437 CNTC.PS2 2262.241 CFTC. PS2 892.811 NPOR.PS2 GR.PS2 190.250 TENS.PS2 2895.000 CCL.PS2 -0.007 48.060 352.990 1366.361 47.932 24. 201 1269. 765 2160. 311 24. 733 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 30 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION · O01CO1 DATE : 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE · 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 3 DEPTH INCREMENT: 0.5000 FILE SUPmff4RY VENDOR TOOL CODE START DEPTH STOP DEPTH 11563.0 10930.0 CNTG LOG HEADER DATA DATE LOGGED: 21-AUG-97 SOFTWARE VERSION: CP42.2 TINGE LOGGER ON BOTTOM: 309 23-AUG-97 TD DRILLER (FT) : 11571.0 TD LOGGER (FT) : 11569.0 TOP LOG INTERVAL (FT) : 10932.0 BOTTOM LOG INTERVAL (FT) : 11562.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE '. 31 GR CNTG $ GAM~A RAY COMPENSATED NEUTRON SGT L 1009 CNC-GB-125 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 11615.0 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) : WATER AND CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 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): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): 1.0 REMARKS: CORRELATED TO W.A. BHCA DATED 16-JAN-94. TAGGED TD @11569' ~ID. MADE 3 PASSES AT 1800 FPH WELL WAS BACK FLOWED WITH WATER DURING LOGGING TO KEEP IT FLUID PACKED. THE DEPTH ABOVE TUBING TAIL (11427' ~D) ARE OFF DUE TO THE EFFECT OF FLOW RATE CHANGE. THIS FILE CONTAINS RAW CNTG PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 32 TABLE TYPE : CONS TONI VAL U DEF I CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 14-2B Well Name APIN 50-029-20318~02 API Serial Number FL 1262' FNL & 1228' FEL Field Location SECT 9 Secti on TOWN 1 ON Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN K. MARTIN Wi tness Name SON 1102687 Service Order Number PDAT MSL Permanent da tum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 67.60001 Above Permanent Datum EK~ FT 67. 60001 Elevation of Kelly Bushing EDF FT 67. 60001 Elevation of Derrick Floor EGL FT 42.9 Elevation of Ground Level TDD FT 11571. Total Depth - Driller TDL FT 11569. Total Depth - Logger BLI FT 11562. Bottom Log Interval TLI FT 10932. Top Log Interval DFT WATER AND CRUDE Drilling Fluid Type TLAB 0309 23-AUG-97 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT NPHI ENPH TNPH TNRA RTNR ENRA CFEC CNEC RCEF RCEN R CNT RCFT CNTC CFTC NPOR GR TENS Depth Compensated Neutron Porosity, SS Matrix, cali & dead time corr. Epithermal Neutron Porosity Thermal Neutron Porosity Thermal Neutron Ratio Calibrated Raw Thermal Neutron Ratio Epithermal Neutron Ratio Calibrated Corrected Far Epithermal Counts Corrected Near Epithermal Counts Raw Corrected Epithermal Far Counts Raw Corrected Epithermal Near Counts RAW NEAR CNT COUNTS RAW FAR CNT COUNTS Corrected Near Detector Count Rate Corrected Far Detector Count Rate Neutron Porosity from an Application Program API-Corrected Gamma Ray Surface Tension LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 32 TABLE TYPE : CONS TONI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 14-2B Well Name APIN 50-029-20318-02 API Serial Number FL 1262' FNL & 1228' FEL Field Location SECT 9 Section TOWN iON Township RANG 14E Range COON NORTH SLOPE County STAT ALASKA State or Province NA TI USA Nat i on WITN K. MARTIN Wi tness Name SON 1102687 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 67.60001 Above Permanent Datum EKB FT 67.60001 Elevation of Kelly Bushing EDF FT 67.60001 Elevation of Derrick Floor EGL FT 42.9 Elevation of Ground Level TDD FT 11571. Total Depth - Driller TDL FT 11569. Total Depth - Logger BLI FT 11562. Bottom Log Interval TLI FT 10932. Top Log Interval DFT WATER AND CRUDE Drilling Fluid Type TLAB 0309 23-AUG-97 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT NPHI ENPH TNPH TNRA RTNR ENRA CFEC CNEC RCEF R C EN R CNT RCFT CNTC CFTC NPOR GR TENS Depth Compensated Neutron Porosity, SS Matrix, cali & dead time corr. Epithermal Neutron Porosity Thermal Neutron Porosity Thermal Neutron Ratio Calibrated Raw Thermal Neutron Ratio Epithermal Neutron Ratio Calibrated Corrected Far Epithermal Counts Corrected Near Epithermal Counts Raw Corrected Epithermal Far Counts Raw Corrected Epithermal Near Counts RAW NEAR CNT COUNTS RAW FAR CNT COUNTS Corrected Near Detector Count Rate Corrected Far Detector Count Rate Neutron Porosity from an Application Program API-Corrected Gamma Ray Surface Tension LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 33 DEFI CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 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 NUNiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD~ SAMP ELE~ CODE (HEX) DEPT FT 1102687 O0 000 O0 0 7 1 1 NPHI PS3 PU 1102687 O0 000 O0 0 7 1 1 ENPH PS3 PU 1102687 O0 000 O0 0 7 1 1 TNPH PS3 PU 1102687 O0 000 O0 0 7 1 1 TN-RA PS3 1102687 O0 000 O0 0 7 1 1 RTNR PS3 1102687 O0 000 O0 0 7 1 1 ENRA PS3 1102687 O0 000 O0 0 7 1 1 CFEC PS3 CPS 1102687 O0 000 O0 0 7 1 1 CNEC PS3 CPS 1102687 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 1102687 O0 000 O0 0 7 1 1 4 68 0000000000 RCENPS3 CPS 1102687 O0 000 O0 0 7 1 1 4 68 0000000000 RCNTPS3 CPS 1102687 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1102687 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1102687 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1102687 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 1102687 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1102687 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1102687 O0 000 O0 0 7 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-0CT-1997 14:49 PAGE: 34 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CCL PS3 V 1102687 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11590.000 NPHI.PS3 47.197 ENPH.PS3 50.841 TNPH. PS3 TArRA.PS3 3.992 RTNR.PS3 3.971 ENRA.PS3 6.513 CFEC.PS3 CNEC.PS3 2357.363 RCEF.PS3 359.500 RCEN. PS3 2127.656 RCNT. PS3 RCFT.PS3 322.197 CNTC. PS3 1397.639 CFTC.PS3 342.126 NPOR.PS3 GR.PS3 60.750 TENS.PS3 2300.000 CCL.PS3 0.000 48.849 361.973 1398.448 47.237 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION : O01CO1 DATE : 97/10/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/10/23 ORIGIN : FLIC TAPE NANiE : 97486 CONTINUATION # : 1 PREVIOUS TAPE : C0~4~7f : ARCO ALASKA INC., PRUDHOE BAY, D.S. 14-2B, API# 50-029-20318-02 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/10/23 ORIGIN : FLIC REEL NA~E : 97486 CONTINUATION # : PREVIOUS REEL : CO~ff4ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 14-2B, API# 50-029-20318-02