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Home My WebLink About198-089• STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED ~E~032010 WELL COMPLETION OR RECOMPLETION REPOF~ ~~pjl~l'~s. Ctn-mtission 1 a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Other ®Abandoned ^ Suspended zoAAC zs.~os zoAAC zs.»o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero 1 b. Well Clarheraq~ ®Development " LJ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Ex loration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 12/31/2009 12. Permit to Drill Number: 198-089 309-319 3. Address: P.O: Box 196612, Anchora e, Alaska 99519-6612 6. Date Spudded: 05/21/1998 13. API Number. 50-029-21635-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 05/26/1998 14. Well Name and Number: PBU 07-23A FNL, 219 FEL, SEC. 33, T11 N, R14E, UM 1986 Top of Productive Horizon: 4903' FNL, 2505' FEL, SEC. 33, T11 N, R14E, UM 8. KB (ft above MSL): 57' GL (ft above MSL): 26.82 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4471' FNL, 2941' FEL, SEC. 33, T11N, R14E, UM 9. Plug Back Depth (MD+TVD): 5766' 5325' Oil Pool 4b. Location of Wetl (State Base Plane Coordinates, NAD 27): Surface: x- 676003 y_ 5948934 Zone- ASP4 10. Total Depth (MD+TVD): 10664' 9052' 16. Property signation: ADL 028309 TPI: x- 673792 y- 5945966 Zone- ASP4 Total Depth: x- 673345 Y- 5946387 Zone- ASP4 11. SSSV Depth (MD+TVD): N/A 17. Land Use Permit: f P f TVD 18. Directional Survey: ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL erma rost ( ): 20. Thickness o 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR 22. Re-DrilULateral Top Window MDlTVD: 9852' (07-23A) 8649' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM `TOP BOTTOM SSE CEMENT{NG RECORD.:' <PUILED ' PI " 4 # " „ „ , , 24. Open to production or injection? ^ Yes ®No 25. TUBING RECORD If Yes, IISt each Interval Open Perforation Size and Number): (MD+TVD of To 8 Bottom SIZE DEPTH SET MD PACKER .SET MD / TVD ; p 4-1/2", 12.6#, L-80 5865' to 9501' MD TVD MD TVD 5-1/2", 17#, L-80 9501' -9625' 9502' / 8388 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,~* ;t,f~~,,~-,~ ~ f ~ ~ ~ ~ DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERIAL USED `' "~ ? ~ ~ is ~ ~ 9243' P&A w/ 18 Bbls Cement 5791' Set EZSV 5788' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVnY-API (CORK): 28. CORE DATA Conventi onal Core(s) Acqui red? ^ Yes ® No Sidewall Core(s) Acquired? ^ Yea ®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, ~re chips, photographs and laboratory analytical results per 20 AAC 250.071. None .Form 10-407 Revised 1212009 CONTINUED ON REVER / Z , Z _GU Submit Original Only 29. GEOLOGIC MARKERS (List all formations and ma encountered): 30. NATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Headed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sadlerochit (From 07-23) 9802' 8610' None Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre-Rig work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoin 's true and correct to the best of my knowledge. ~n [, / Signed: Terrie Hubble Title: Drilling Technologist Date: PBU 07-23A 198-089 309-319 Prepared ay Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Frank Roach, 564-4373 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. Submlt a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Class cation of Service Walls: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submlt Original Only • • 07-23A, Well History (Pre Rig Sidetrack) Date Summary 9/8/2009 T/I/0=1500/750/0. PPPOT-T (PASS), PPPOT-IC (FAIL). Pre Rig. PPPOT-T: Stung into test port (0 psi). Removed internal check. Installed new Alemite External Check. Functioned LDS (N style), all moved freely (1.5"). Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0 psi). Functioned LDS (N style), all moved freely (1.5"). single port, unable to pump through void. Pressured void to 3500 psi for 30 min test, decreased to 800 psi in 5 seconds. Re-torqued LDS to 600 Ib/ft. Re-pressured void to 3500 psi, unable to sustain test pressure, decreased to 800 psi in 5 seconds (FAIL). 9/11/2009 T/I/0= SSV/300/0. Temp= S/I. PPPOT-I/C Stung into test void 0 psi. Pressure tested to 3,500 psi. Lost 2,700 psi. in 1 min. Bled test void to 0 psi. Opened packing port & Re Energized seal w/plastic. Re Torqued LDS. Pressured test void to 3,500 psi. Lost 0 psi. in 15 min. Lost 0 psi. in 30 min. Bled void to 0 psi. (PASSED). 9/19/2009 T/I/0=2300/800/100 Assist S/L (RWO Prep) Pumped 5 bbl 60/40 meth spear & 40 bbls 180° crude down TBG while S/L brushed. Pumped 1.4 bbls crude down TBG to test S/L tool. S/L in control) of well upon departure. DSO & PE notified. FWP=1900/750/420 IA & OA open to gauges. 9/19/2009 WELL S/I ON ARRIVAL. BRUSH & FLUSH TRSV C~ 2,092' SLM. FUNCTION TEST TRSV ~ 2,092' SLM (TRSV FUNCTIONS PROPERLY). RUN 4-1/2" "LOT" TRDP-4A LOCKOUT TOOL & LOCKOUT TRSV C~ 2,092' SLM. FUNCTION TEST TRSV C~ 2,092' SLM (APPEARS TO BE LOCKED OPEN). TAG TOP OF 2-7/8" LINER W/ 2.50" SAMPLE BAILER C~3 9,544' SLM + 6' CORK = 9,550' MD. WELL LEFT S/I, TURN OVER TO PAD OP. 9/23/2009 T/O/1= SI/0/600 TEMP= SI RG 2401 (SURFACE CASING CORK MITIGATION) PJSM. SET UP HYDRO VAC AND JOB SITE. START AND COMPLETE EXCAVATION ON WELL CELLAR. INSTALL 1 PLUG. RDMO. TOP PLATE 10/3/2009 T/I/0= 50/740NAC. Temp= SI. IA FL (pre-FB P&A). AL spool piece dropped. IA FL Q surface. SV, WV = C. SSV, MV= O. IA, OA = OTG. NOVP. 10/3/2009 T/I/0= 2300/600/160 (Infectivity Test) Rig to TBG and Pump 10 bbls 60/40 meth followed by 227 bbls KCL C~ 5 bpm then reduced rate to 3 bpm C~ 1100 psi for 23 bbls then increased rate to 5 bpm for 20 bbls C~3 1200 Psi. Freeze protect TBG with 40 bbls dead crude. RDMO. FWHP= 0/1000/600. Wing = closed. Swab =closed. SSV =open. Master =open. IA and OA open to gauges). Operator notified. 10/10/2009 T/I/O=2380/883Nac Fullbore P&A with SLB Cementers (Pre Sidetrack) Pumped down Tbg with 225 bbls 1 % KCI, 10 bbls chemical wash, 5 bbls neat 15.8 ppg "G" cement, 8 bbls 15.8 ppg cement with 15 ppb aggregate, 5 bbls neat 15.8 ppg "G" cement, followed by 2 bbls fresh water. Diverted flow through ball launcher and pumped down Tbg with 5 bbls fresh water to launch foam wiper ball (6"), followed by 137 bbls diesel to displace cement. Tbg pressure 1250 psi upon shutdown, Monitored TP for 30 mins. TP decreased to 510 psi. Estimating TOC 9450'. Shut- in well RDMO. FWHP's = 556/925/400. 10/13/2009 R/U SLICKLINE. BRUSH TUBING HANGER W/ 4.098" BPV DRIFT, 4-1/2" BLB. TAG TOC W/ 3.70" CENT, 2.5" S.BAILER AT 9,253' SLM. JOB COMPLETE. 10/17/2009 T/I/0= 360/680Nac Temp=Sl MIT-T PASSED to 3500 psi, MIT-IA PASSED to 3500 psi (PRE SIDETRACK). MIT-IA: Pressured up IA with 10 bbls diesel. IA lost 20 psi in 1st 15 mins and 10 psi in 2nd 15 mins for a total loss of 30 psi in 30 min test. Bled pressure back, bled aprox 10 bbls diesel. MIT- T: Pressured up Tbg with 2.5 bbls diesel. Tbg lost 200 psi in 1st 15 mins and 60 psi in 2nd 15 mins for a total loss of 260 psi in 30 min test. Bled pressures back, bled aprox 3 bbls diesel. Final WHPs 260/720Nac WV, SV, SSV =Shut MV, IA, OA =Open Page 1 of 2 • • 07-23A, Well History (Pre Rig Sidetrack) Date Summary 10/19/2009 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O = 500/850/0. SSV = C, MV = O, SW = C, WV = C, IA/OA = OTG. GYRO SURVEY COMPLETED FROM 6000' TO SURFACE. TUBING PUNCHED 3' BELOW FIRST JOINT ABOVE CEMENT. TOC TAGGED AT 9243'. PUNCH INTERVAL: 9231' - 9233' TUBING PRESSURE EQUALIZED WITH IA PRESSURE AT 650 PSI. FINAL T/I/O: 600/700/0 PSI. SSV = C, MV = O, SW = C, WV = C, IA/OA = OTG. JOB COMPLETE, WELL SHUT-IN ON DEPARTURE. 10/19/2009 T/I/0= 480/550Nac Temp= SI Circ-Out TxIA (Pre RWO). Spotted equipment, rigged up to well. Currently standing by for jumper line to be rigged up from 07-23 to 07-24. 10/20/2009 Pumped 922 bbls SW, 151 bbls 80° diesel down the tubing, up the IA through hardline down 07-24 flowline. Freeze protect hardline with 5 bbls 60/40 MW and 5 bbls diesel. CMIT TxIA PASSED to 1000 psi. Pressured up T/IA to 1000 psi with 2.8 bbls diesel. 3rd test results- 1st 15 min T/IA lost 20/20 psi. 2nd 15 min T/IA lost 10/10 psi with a total loss of 60 psi loss in 30 min test. Bled back 3 bbls diesel. MIT OA PASSED to 2000 psi- 1st 15 min OA lost 80 psi, 2nd 15 min OA lost 20 psi with a total loss of 100 psi in 30 min test. Bled back 3 bbls crude. Final WHP's = 0/0/0 Valves as SW, WV, SSV =closed, MV, IA and OA open on departure. 10/24/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O=0/0/0 RIG UP TO JET CUT TUBING. BEGIN RIH WITH 3.65" POWERCUTTER. 10/25/2009 JET CUT 4.5" TUBING AT 5862'. INITIAL T/I/0=0/0/0. AFTER CUTTING T/I/0=0/0/0. WELL LEFT SHUT IN. M =OPEN; S, SSV, W =CLOSED; CSV = OTG. PAD OPERATOR NOTIFIED OF WELL STATUS. FINAL T/I/0=0/0/0 JOB COMPLETE. 10/26/2009 T/I/0=0/0/0 CMIT T x IA to 1000 psi after Tbg cut. Pass (Pre sidetrack). Pumped 3.9 bbls DSL down TBG to pressure up to 1000 psi. TBG/IA lost 0/10 psi in 15 minutes and 0/0 psi in second 15 minutes for a total pressure loss of 0/10 psi. Bled TBG psi (3.3 bbls, all fluid). Tags hung and wellhead valves left in the following positions: SV, WV, SSV = S/I. MV, IA & OA =open. FWP's=0/0/0 Page 2 of 2 • • BP EXPLORATION Page 1 Operations.. Summary Report Legal Well Name: 07-23 Common Well Name: 07-23 Spud Date: 8/20/1986 Event Name: REENTER+COMPLETE Start: 12/26/2009 End: (Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 'Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To Hours Task... Code NPT Phase Description of Operations 12/26/2009 112:00 - 00:00 I 12.001 MOB I N 12/27/2009 00:00 - 13:00 13.00 MOB N 13:00 - 15:00 2.00 MOB P 15:00 - 00:00 9.00 MOB P 12/28/2009 00:00 - 06:00 6.00 MOB P 06:00 - 17:00 11.00 RIGU P 17:00 - 20:30 3.501 RIGU P 20:30 - 21:30 I 1.001 WHSUR I P 21:30 - 00:00 2.501 WHSUR P 12/29/2009 00:00 - 02:00 2.001 RIGU P 02:00 - 04:30 I 2.501 WHSUR I P 04:30 - 05:30 1.00 DHB P 05:30 - 06:30 1.00 DHB N 06:30 - 09:00 2.50 DHB N 09:00 - 10:30 1.501 WHSUR P WAIT PRE 7ES RELEASED FROM W-56 AT 12:00. DISCONNECT PITS MOVE PITS, SHOP, ILLAMNA CAMP TO 7-23. WOW. 32 MPH W/GUSTS TO 41 MPH. WAIT PRE WOW TO LOWER DERRICK AND MOVE SUB FROM W-56 TO 7-23. WIND 32 MPH W/GUSTS TO 41. PRE LAY DERRICK OVER AND MOVE SUB OFF W-56. SECURE WELL. PRE MOVE RIG 7ES SUB FROM W-56 TO 7-23. PRE MOVE RIG 7ES SUB FROM W-56 TO 7-23. PRE RU ON DS 7-23. PLACE MATS, LD HERCULITE BERMS, BACK IN/TIE IN PITS. RAISE DERRICK. TAKE ON HEATED SEAWATER AND ACCEPT RIG AT 17:00. END OF WEATHER INDUCED EXCEPTIONAL RIG MOVE PERIOD. DECOMP RU CELLAR EQUIPMENT AND LINES. RU FLAT TANK AND HARD LINES TO TAKE DIESEL FROM FREEZE PROTECT. BREAK (BOP AND SAVER SUB ON TOP DRIVE, TUBO SCOPE INSPECT QUILL SHAFT. OK. CHANGE OUT DRILLERS SIDE TUGGER LINE. DECOMP PJSM. HOLD PRESPUD W/ALL HANDS, TP, MUD ENGINEER, WSL. DISCUSS WELL PROGRAM. DISCUSS CURRENT DAYS PLAN FORWARD AND CARRYING HSE IMPROVEMENT FORWARD. DECOMP TEST OA WITH DIESEL TO 2000 F/10 MINUTES. TEST IA WITH WATER TO 2000 AND HOLD FOR 10 MINUTES BOTH TEST GOOD. HOLD PRESPUD AT MIDNIGHT TOUR MEETING WITH ALL HANDS, WSL, TP, MUD MAN. DECOMP RU AND TIE IN TO HARDLINE AND TEST HARDLINE TO TIGER TANK TO 2,000 PSI. VERIFY 0 PSI ON IA AND PULL BPV WITH DSM LUBRICATOR. DECOMP REVERSE CIRCULATE 35 BBLS OF DIESEL OUT OF TUBING. SWITCH DIRECTION AND CIRCULATE 120 BBLS OF DIESEL FREEZE PROTECT OUT OF ANNULUS. CBU WITH SAFE SURF O. DECOMP INSTALL TWC AND TEST TO 1 000 PSI FROM BFi OW TEST GOOD. DFAL DECOMP RU AND ATTEMPTED TO TEST TWC TO 3500 PSI FROM ABOVE, BUT DID NOT GET A GOOD TEST. RE-TESTED ON IA AT 200 PSI FROM BELOW WHCIH ALSO FAILED. RIGGED DOWN TEST EQUIPMENT AND WAITED ON DSM TO ARRIVE WITH LUBRICATOR TO CHANGE TWC. DFAL DECOMP PJSM W/ DSM ON RU LUBRICATOR. TESTED WITH DIESEL TO 500 PSI THEN PULLED TWC. A ROLLED SEAL WAS FOUND WHEN PULLING TWC. REBUILT TWC AND INSTALLED WITH LUBRICATOR. TESTED F/ BELOW AT 1,000 PSI FOR 10 MINUTES, AND FROM ABOVE AT 3,500 PSI FOR 10 MINUTES. GOOD TEST. RIGGED DOWN LUBRICATOR AND SUCKED OUT TREE. DECOMP PJSM ON ND TREE. NIPPLED DOWN TREE AND ADAPTOR FLANGE, FUNCTIONED LDS & RETORQUED TO 450 FT LBS, AND INSPECTED HANGER THREADS, 13 3/4 BHT. Printed: 1/11/2010 12:39:15 PM • BP EXPLORATION Page 2 ~ Operations Summary Report Legal Well Name: 07-23 Common Well Name: 07-23 Spud Date: 8/20/1986 Event Name: REENTER+COMPLETE Start: 12/26/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 12/29/2009 10:30 - 14:00 3.50 BOPSU P DECOMP PJSM AND NIPPLE UP BOP AND RIG UP TEST EQUIPMENT. 14:00 - 23:30 9.50 BOPSU P DECOMP TEST BOPE TO 3,500 PSI HIGH, 250 PSI LOW FOR 5 MINUTES WITH 4" AND 4.5" TEST JOINTS; CHART ALL TESTS. TEST ANNULAR TO 2,500 PSI HIGH, 250 PSI LOW WITH 4" TEST JOINT ONLY. ALL TESTS GOOD. BOPE TEST WITNESSED BY JEFF JONES WITH AOGCC AND BP WSL NEWLON AND NAD TP WURDEMAN. 23:30 - 00:00 0.50 BOPSU P DECOMP RIG DOWN TEST EQUIPMENT. 12/30/2009 00:00 - 00:30 0.50 DHB P DECOMP RU DSM LUBRICATOR AND EXTENDER. - PRESSURE TEST TO 500 PSI; TEST GOOD. 00:30 - 01:00 0.50 DHB P DECOMP PULLED TWC AND RIGGED DOWN DSM LUBRICATOR. 01:00 - 01:30 0.50 PULL P DECOMP MU CROSS OVER TO JOINT OF DP. - MU TO TBG HANGER AND BACK OUT LOCKDOWN SCREWS. -UNSEATED TBG HANGER W/ SOK PU WT. 01:30 - 02:30 1.00 PULL P DECOMP CIRCULATE SURFACE TO SURFACE. - 502 BBLS, 500 GPM, 515 PSI. - RU SPOOLER AND DOUBLE-STACK POWER TONGS. - LD CROSSOVER AND HANGER. 02:30 - 04:30 2.00 PULL P DECOMP PJSM AND LD 4.5" NSCT L-80 12.6 #TBG FROM 5 862' TO 3 7_51'. - STOP AT SSSV. 04:30 - 05:00 0.50 PULL P DECOMP RD CONTROL LINE SPOOLER. 05:00 - 08:00 3.00 PULL P DECOMP LD 4.5" NSCT, L-80, 12.6 #TBG FROM 3,751' TO SURFACE. - RECOVERED 53 STAINLESS STEEL BANDS, 140 JTS, 1 GLM, 1 SSSV, 1 PUP JT. - CUT JT = 3.91'. 08:00 - 08:30 0.50 PULL P DECOMP RD 4.5" HANDLING TOOLS AND CLEAN AND CLEAR RIG FLOOR. 08:30 - 09:00 0.50 BOPSU P DECOMP RU TO TEST LOWER 2-7/8" X 5" VBRS. 09:00 - 09:30 0.50 BOPSU P DECOMP ATTEMPT TO TEST, BUT SEALS FAILED ON TEST PLUG. 09:30 - 11:30 2.00 BOPSU N WAIT DECOMP WAIT ON ARRIVAL OF NEW TEST PLUG. 11:30 - 12:30 1.00 BOPSU P DECOMP LOWER 2-7/8" X 5" VBRS WITH 4" TEST JOINT TO EST T _ _ 250 PSI LOW, 3,500 PSI HIGH. -TEST GOOD. 12:30 - 18:30 6.00 CLEAN P DECOMP PU BHA # 1 AND RIH ON 4" DP SINGLES FROM THE PIPESHED TO 5,865'. - TAGGED UP ON 4-1/2" TBG STUMP AT 5,865'. - 122K PU WT, 115K SO WT. - FILL EVERY 25 STANDS. 18:30 - 19:30 1.00 CLEAN P DECOMP CIRCULATE AND MONITOR WELL; WELL STATIC. - 410 BBLS, 500 GPM, 1,900 PSI. - PUMP DRY JOB. - MW = 8.5 PPG. !, 19:30 - 21:30 2.00 CLEAN P DECOMP POH FROM 5,865' TO 291'. 21:30 - 22:30 1.00 CLEAN P DECOMP LD BHA # 1 FROM 291'. 22:30 - 00:00 1.50 DHB P DECOMP PJSM WITH SLB AND HAL FOR E-LINE EZSV RUN AND RU E-LINE. 12/31/2009 00:00 - 01:30 1.50 DHB P DECOMP RIH WITH EZSV AND GR/CCL ON E-LINE TO 5,800'. , 01:30 - 02:00 0.50 DHB P DECOMP LOG ON DEPTH AND SET 7SV AT ~, 7R1' (WIRELINE). - SET 3' ABOVE CASING COLLAR. 02:00 - 02:30 0.50 DHB P DECOMP POH WITH GR/CCL ON E-LINE TO SURFACE. >~ Printed: 1/11/2010 12:39:15 PM • BP EXPLORATION Page 3 ~f9' Operations Summary Report Legal Well Name: 07-23 Common Well Name: 07-23 Spud Date: 8/20/1986 Event Name: REENTER+COMPLETE Start: 12/26/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 12/31/2009 02:30 - 03:00 0.50 DHB P DECOMP PRESSURE TEST 9-5/8" CASING ABOVE EZSV TO 3,500 PSI FOR 30 CHART - FIRST 15 MINUTES 0 PSI LOSS; SECOND 15 MINUTES 0 PSI LOSS. - TEST GOOD. 03:00 - 03:30 0.50 DHB P DECOMP RD SLB E-LINE. 03:30 - 08:00 4.50 WHSUR P DECOMP ND BOP. - REMOVE CAMERON 11"TBG SPOOL AND REPLACE WITH MCELVOY 13-5/8" TBG SPOOL. - PRESSURE TEST PACKOFF TO 3,750 PSI FOR 30 MINUTES (TEST GOOD). 08:00 - 10:30 2.50 BOPSU P DECOMP NU BOP. 10:30 - 12:00 1.50 WHSUR N SFAL DECOMP RESSURE TEST BREAK BETWEEN BOP TBG SPOOL, AND KILL LINE. - 250 LOW PSI / 3,500 HIGH PSI. - LEAK BETWEEN TBG SPOOL AND BOP. 12:00 - 14:30 2.50 BOPSU N SFAL DECOMP UNSUCCESSFUL TEST AFTER MAKING ADJUSTMENTS BETWEEN TBG SPOOL AND BOP. - ND BOP. -CLEANED FLANGE SURFACE AND RING GROOVE. - REPLACED API RING. 14:30 - 16:00 1.50 BOPSU N SFAL DECOMP NU BOP. 16:00 - 16:30 0.50 WHSUR N SFAL DECOMP SET TEST PLUG AND RU TEST EQUIPMENT. 16:30 - 17:00 0.50 WHSUR N SFAL DECOMP PRESSURE TEST BREAK BETWEEN BOP, TBG SPOOL, AND KILL LINE. - 250 LOW PSI / 3,500 HIGH PSI. 17:00 - 17:30 0.50 WHSUR P DECOMP RD TEST EQUIPMENT AND SET WEAR RING. 17:30 - 20:00 2.50 STWHIP P WEXIT PJSM AND PU_WHIPSTOCK BHA # 2 TO 383'. 20:00 - 23:00 3.00 STWHIP P WEXIT RIH TO 5,655'. - PU WT 125K, SO WT 117K. 23:00 - 00:00 1.00 STWHIP P WEXIT SET WHIPSTOCK AT 5 788'. - ORIENT 80 DEGREE LEFT. - TAG AT 5,788'. - SO 20K AND SHEAR ANCHOR. - OVERPULL 15K TO CONFIRM SET. - SO 55K AND SHEARED BOLT (GOOD INDICATION OF SHEAR). - TOW AT 5,766'. ~/ -BOW AT 5,783'. 1/1/2010 00:00 - 01:00 1.00 STWHIP P WEXIT DISPLACED 8.5 PPG SEAWATER WITH 9.8 PPG LSND. - 475 BBL 500 GPM 1 460 PSI. <L ~, 01:00 - 07:00 6.00 P WEXIT MILL WINDOW IN 9-5/8" CASING FROM 5,766' TO 5,783' , AND CONTINUE IN OPEN HOLE TO 5,796'. ~ 7~lc~V - 400 GPM, 1,075 PSI. - 90 RPM, 15K WOM. - TO 5K. - PU WT 125K, SO WT 117K, RT WT 122K. - TOW, 5,766 ;BOW, 5,783'. - MW 9.8 PPG. 07:00 - 07:30 0.50 P WEXIT CBU TO CONDITION WELL FOR PHASE THREE WEATHER CONDITION WORK STOPPAGE. - WORK WINDOW. - POH TO INSIDE 9-5/8" CASING TO 5,763'. rnnt6a: 1/112U1U iz:~aaarnn TREE= 4-1/16" 5000 WELLHEAD= CAMERON ACTUATOR = KB. ELEV = 5T BF. ELEV....- 27.86 KOP = 5766' Max Angle = 39 @ 5100' Datum MD = 8851' Datum TV D = 8800' SS DRLG DRAFT~7~'13B 10.94' PBR, ID = 7.37" H 5598' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2490' TOP OF WHIPSTOCK I"I 5766' ~FETY NOTES: Chrome Lnr 8 tbg. 2,073' ~ 4-1/2" X NIP, ID = 3.813" 5598' 9-5/8"x7" BKR Flex-Lock LNR HNGR &ZXP LTP, ID = 6.151" CHAS t_IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3747 3709 26 KG62 DCK BEK 0 01/12/10 3 6215 5716 20 KG62 DMY BK 0 01/12/10 2 7775 7184 19 KG62 DMY BK 0 01/12/10 1 8795 8146 20 KGB2 DMY BK 0 01/12/10 6282' I~ XO VAMTOP HC Box x TCII Rn Minimum ID = 3.725" @ 9010' 4-1/2" HES'XN' NIPPLE PERFORATION SUMMARY REF LOG: BHCS ON XX/XX/XX ANGLE AT TOP PERF: XX @ XX,XXX' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE $$73' I-~ 4-1/2" X NIP, ID = 3.813" I 8903' 7"x4-1/2" BKR S-3 PKR, ID = 3.850" 8937' ~ 4-1/2" OTIS X NIP, ID = 3.813" 9010' 4-1/2" XN NIP, ID = 3.725" 9021' 4-1/2" TBG, 12.6#, 13Cr-80, Vam Top, " ID = 3.958 9021' WLEG 9016' 11.16' TBR ID = 5.250" ID 9033' 7"x5" BKR Flex-Lock LNR HNGR & ZXP LTP, ID = 3.85" DRIFT 7" LNR, 26#, L-80, TGII x VAM THC, 9204' ID = 6.276" 9878' I-I PBTD 9965' 4-1/2" LNR, 12.6#, 13Cr-80, Vam Top, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/07/87 ORIGINAL COMPLETION 08/23/06 JCMIPAG GLV GO 10/02/94 RWO (SCAB LNR) 01/14/10 N7ES SIDETRACK (07-23B) 05/27/98 CTD SDTRCK 01/25/10 TLH DRLG HO CORRECTIONS 09/26/01 RNITP CORRECTIONS 07/05/05 DRS/TLH 1994 SCAB LNR CORRECTION 05/30/06 DTM WELLHEAD CORRECTION PRUDHOE BAY UNIT WELL: 07-236 PERMfT No: 198-089 API No: 50-029-21635-02 SEC33 T11 N R14E 33 2951.54 FEL 4462.7 FNL BP Exploration (Alaska) , ~ i ` k ~ "~~ ~'~' ~ ~ ~ ~ ' a. ,~ F: ~ ~ `' '~ ,.t ~ ~ h' ' ~ " ~ E~ ~ ` ~ ~ ~ ~ ~ ~ ~ ~ ~~ " p ~ '~~ `~ ~ ~ ~ ~ ~ ~ t~ SEAN PARNELL, GOVERNOR ~ ~ / ~ f ~ µ ~ ~ ~ ~ f ~ ~ h ~ ': ~k ~ € ~ ~~~~ ~ ~~~~ ~ ` ~ ~~r~~ M$ `~, ~ ` ~~~ ~.~, ~~' ~.~~ ~ ~ ~ ~~ ~ ~~ ~;~ k'.~~~~ i~~ ~ ~ ~ ~ I ~~ ~~ ~: ; ~ ~K~--7~ ~IiI tLSL Vra--7 z~~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ER~FATIOI~T COMAIISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ` FAX (907)276-7542 Mr. Greg Hobbs Engin.eering Team Leader I3P Exploration (Alaska), Inc. P.O. Box 196612 ~ ~~ Anchorage, AK 99519-6612 `~~j ~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-23A Sundry Number: 309-319 , ~ .~~ . ~; ~~~i, . . a` ~ ~. k.tii. , Dear Mr. Hobbs: 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 aftPr written notice of this decision, or such further time as the Commission grants for good cause shawn, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. S ~ Chair DATED this Z~ day of September 2009 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION n ,~. ~ ~ ~' '° ~ ~.~~L i ~ S r''~ ~~~'O~ .. ... .~. :J ~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~ ` ~ ~~ 1. Type of Request: ~ Abandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time E~ension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development ^ Exploratory T98-089- 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21635-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 07-23A ' Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028309 ~ 57' - Prudhoe Bay Field ! Prudhoe Bay Oil Pool ~Z• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10664' - 9050' - 10631' 9033' None None Casin Len th Size MD ND Burst Colla se Structural Conductor 80' 20" 80' 80' 1490 470 Surface 2490' 13-3/ " 2490' 2490' 4930 2670 Intermediate 9852' 9-5/8" 9852' 8646' 6870 4760 Produ tion Liner 1117' 2-7/8" 9547' - 10664' 8417' - 9050' 10570 11160 Scab Liner 344' 7-5/8" 5902' - 6246' 5430' - 5704' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10526' - 10605' 8980' - 9020' 4-1/2", 12.6# x 5-1/2", 17# L-80 9625' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SB-3' packer Packers and SSSV MD (ft): 9502' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: November 7, 2009 ^ Oil ^ Gas ^ Plugged ~ Abandoned 17. Verbal Approval: Date: ^~/AG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the for oir~~ is true and correct to the best of my knowledge. Contact Frank Roach, 564-4373 Printed Name Greg H Title Engineering Team Leader Prepared By Name/N~mber: Signature Phone 564-4191 Date Terrie Hubble, 564-4628 • Commission Use Onl Sundry Number: Co itions of approval: No ify Commission so that a representative may witness Plug Integrity L7 BOP Test ^ Mechanical Integrity Test ^ Location Clearance Sd o s~ ~' ^)/~~_ / ~ Other: ~ 3 I~ ~~P ~ ~ ~' /`T / T~'h-'~'~ "~~5~'ja ° ~ QDI~s ~..~/Or'e ~l~- • ~- Z,Sp~ ~o~L ~n~....~~. lts~-` a Subsequent Form Required: / a.~ U!Z APPROVED BY ~/Z l 9 I A roved B: COMMISSIONER THE COMMISSION Date // Form 10-403 Re sed 06/2006' ~ Submit In uplicate ~ ~ ~ ~ I ~~ A L ~ ~~:.~~: ~~~ ~ ~ z~p~ y ~~. ~ ~~' ~ ~ ~ ~~~ ~r ~~.~~~~~~~~~~ 07-23A Sundry Request Well Type: Producer Current Status: This well is completed with 4-1/2" x 5-1/2" L-80 tubing and is currently shut-in. Request: Plug and abandon wellbore in preparation for tvishak sidetrack. Well History: 07-23A was coil sidetracked in May 1998 as a vertical Zone 2B producer. 25' of perfs were initially shot in 24P sand but the well did not flow. The initial 25' was reperfed and 10' of the 25P sand were shot on 6/24/98. The well came on at 1400 BOPD and 10,000 GOR and produced at a steady GOR of 20,000 for 3 years. In May 2005 service coil rigged up to mill an obstruction (assumed to be scale) with the intent of adding perfs in lower 2B above the HOT followed by an RST log. Both slickline and coil had problems getting into the 3-1/2" liner. Coil eventually made it through the liner top after 10 attempts but then couldn't mill past 10,518'. 50 bbls of 12% DAD acid was pumped above the obstruction and it added ~100 bopd but failed to remove the obstruction. Based on the condition of the BHA and the lack of milling success, a liner collapse was suspected at --10518'. The well flowed competitively until early 2007 when the gas rate started increasing sharply and the GOR rose to ~100000. The well was shut-in for high GOR. Another RST/STP log was requested, but in August 2007 slickline couldn't drift through the 3-1/2" liner top; this was the same sticky spot encountered in May 2005. A videolog run Feb 2008 indicated the liner top was in fact damaged, preventing access to the lateral. The damaged liner top and large volume of cement pumped behind the liner during drilling prevent a cut-and-pull for a coil sidetrack. Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the / testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. Scope of Work: The pre-drilling rig work on this well will include the P&A the existing 07-23A well perforations per AOGCC regulations and cutting the existing 4-1/2" x 5-1/2" completion at -5850' MD in preparation for the planned 07- 236 sidetrack. With a drilling rig on the well, the planned work will include pulling the 4-1/2" tubing above the cut at -5850' and change-out the 9-5/8" pack-off prior to installing a CIBP and 9-5/8" whipstock just above the tubing stub which will be used to sidetrack the well to the 07-23B BHL. ~~1~` MASP: 2360 psi ~~~f1 ~ f ~~,~,e~ fi?~ vr~ ~yc~~~e a~^~ (f~ ~~ ~On y~,, rc, ~J ~,r+ 7"CI G~~l CUt~GUI" ~ GPr.' 11 Q/I~,w 0~t ~P ~ .~ ~ ~~ ~~ c~nrA ~ X, ~r~r~y ~~~~~ ~~~ ~ 07-23A Sundry Application 1 9/4/2009 Pre-riq prep work: ~~ ~ W 1 Function tubing and casing LDS. Repair/replace as required. Perform PPPOT-IC to 3500psi and PPPOT-T to 5000 si. S 2 Run fla er checker to confirm SSSV is o en. Drift tubin to to of liner at 9,547'. F 3 Confirm injectivity into the open perfs as required for P&A to follow. If injectivity is sufficient for fullbore P&A, proceed with step 4a, option 1. If not, contact ODE and proceed with step 4b./ F 4a "bullhead" 18.3bb1 (10bb1 excess), 15.8ppg G cement to plug and abandon the current well perforations: Liner Size 6.5# 2-7/8" (.00579 bpf) from 9,550' to 10,664' MD 9.3# 3-1/2" (.00870 bpf) from 9,547'to 9,550' MD Tubing size (Lnr to XO) 17.0# 5-1/2" (.02332 bpf) from 9,481' to 9,547' MD Tubing size (XO to TOC) 12.6# 4-1/2" (.01520 bpf) from 9,450' to 9,481' MD Bottom of plug 10,631' MD Top of plug 9,450' MD Total Footage 1,181' (-8.3 bbls) Top Perf 10,526' MD Bottom Perf 10,605' MD SBHP: 3240 si SBHT: 210 °F F/C 4b Set 4-1/2" cement retainer above the 4-1/2" x 5-1/2" crossover joint at --9480'. Attempt to establish injection. If injection established, proceed with following P&A: Liner Size 6.5# 2-7/8° (.00579 bpf) from 9,550' to 10,664' MD 9.3# 3-1/2" (.00870 bpf) from 9,547'to 9,550' MD Tubing size (Lnr to XO) 17.0# 5-1 /2" (.02332 bpf) from 9,480' to 9,547' MD Tubing size (XO to TOC) 12.6# 4-1/2" (.01520 bpf) from 9,430' to 9,480' MD ""`"(50' cement above retainer) Bottom of plug 10,631' MD Top of plug 9,430' MD Total Footage 1,151' (~8.8 bbls) Top Perf 10,526' MD Bottom Perf 10,605' MD SBHP: 3240 si SBHT: 210 °F S 5 WOC. Drift to TOC. F 6 CMIT-TxIA to 3,500 psi. Pressure test is required for cqmpetent barrier for rig operations. If test fails, contact ODE. Freeze Protect as necessa / E/F 7 Punch tubing above 4-1/2" x 5-1/2" crossover at ~9,480' MD (or as close to TOC as possible) and circulate tubing and IA to clean seawater. Power Jet cut 4-1/2" tubing at ~5,850' MD (try to get cut ~2' below a coupling to help with standoff from the intermediate casing). Establish circulation from the T to the IA. F 8 CMIT TxIA 40 3,500 si. MIT-OA to 2,000 si. If combo fails, contact ODE. D 9 Bleed casin and annulus ressures to zero. V 10 Set a BPV. Remove well house and flow line. Level ad as necessa . Proqosed Drillina Ria Ouerations: 1. MI/RU. 07-23A Sundry Application 9/4/2009 2. CMIT-Tx1A to 2000 psi and MIT-OA to 2000 psi to confirm barriers (10 minute tests - expect both test to pass). 3. Pull BPV w/tested lubricator and circulate out diesel freeze protection and displace the well to seawater. 4. Set and re-test TWC to 1000 psi from below and 3500 psi from above for 10 minutes. 5. As there is path-forward wellhead work to be completed, begin the OA monitoring process (RU to bleeder tank). 6. Nipple down tree. Nipple up and test BOPE to 3500psi. Pull TWC w/tested lubricator. 7. R/U & pull 4~/z" tubing from the cut de,pth at 5850' MD. 8. Test lower set of rams if required. ~ 9. PU drill-pipe and make bit and scraper run to the top of the tubing stub and test wel{ to 3500 psi f/30 min and chart. (NOTE: If we{I does not test to 3500 psi, an RTTS will be RIH to isolate/locate the leak.) 10. Assuming a good pressure test in the previous step, RU E-line and RIH w/EZSV and CCL and set the EZSV at -5781' MD given the location of the nearest casing collar and re-test well to 3500 psi for 10 minutes. 11. With 2 down-hole barriers in place, "split" the stack and change out the 9 5/e" pack-off and "test" per the Cameron wellhead representative. 12. NU Wellhead/BOPE test breaks to 3500 psi. 13. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock and set on EZSV bridge plug at ~5781' MD. Shear off of whip stock. 14. Displace the well to LSND based milling fluid per mud program. 3~~~ 319 (End Work Under Sundry Approval #~cxx-~~x/ Begin Work Under PTD #xxx-xxx) 15. Mill window in 9 5/e" casing at -5770' MD, plus approximately 30' of new hole beyond middle of window and circulate well-bore clean. 16. Pull up into 9 5/e" casing and conduct a FIT. POOH. 17. M/U 8-~h" Dir/GR/Res/PWD assembly. RIH, kick off and drill the 8-~h" intermediate section to the top Sag River target at ~9,200' MD, per directional plan. 18. Circulate, short trip and POOH to run the 7" drilling liner (manage drill-pipe as required). 19. Run and cement a 7", 26.0#, L-80, TC-II intermediate drilling liner (fully, cemented liner w/-150' liner lap to 5,620' MD TOL). 20. After cement has reached a minimum 500 psi compressive strength, test the 9 s/e" casing X 7" liner to 3,500psi for 30 minutes and record the test. 21. M/U 6-%e" motor assembly w/Dir/GR/Res/Neu/Den + insert bit to drill-out the shoe track, displace to the well to the planned drill-in fluid, drill 20' of new hole and run FIT. 22. Drill ahead per the directional plan to TD at ~9960' MD. 23. Circulate, short trip, spot liner running pill. POOH to run the production liner. 24. Run and fully cement a 4-1/2", 12.6#, Vam Top, chrome production liner. 25. After cement has reached a compressive strength of 500 psi, test the well to 3500 psi f/30 minutes and chart. 26. POOH VD all drill pipe. 27. R/U and run 4-~h", 12.6#, 13 Cr-80, VamTop completion tubing. 28. Land the tubing RILDS. 29. Reverse the well to clean seawater to include inhibited seawater to the production packer depth per the plan. 30. Drop ball & rod and set packer and individually test the tubing and annulus to 3,500psi 30 minutes and record each test. 31. Shear the DCK valve and pump each way to confirm shear. 32. Set a TWC and test to 1000 psi from above and below. 33. Nipple down the BOPE. Nipple up the tree and test to S,OOOpsi with diesel (new adapter flange required). 34. Pull TWC w/lubricator. 35. Freeze protect the well to 2,200' TVD with diesel. 36. Install BPV and secure the well. 37. Rig down and move off. Post-Ria Operations: (S-Riser Modification will be Repuired) 1. MI / RU slick line. 07-23A Sundry Application 3 9/4/2009 2. Pull the bali and rod / RHC plug from landing nipple below the production packer. 3. MIRU E-line and perforate production interval zone of interest. 4. Install gas lift valves. 5. Install well house and instrumentation. Estimated Pre-rig Start Date: 11/07/2009 Estimated Spud Date: 11/28/2009 Drilling Engineer: Frank Roach Production Engineer: Alice Kaminski Geologist: Adam Van Holland AT7ACH: Current Well Schematic Post P&A Well Schematic (907) 564 - 4373 (907) 564 - 5676 (907) 564 - 4477 07-23A Sundry Application 4 9/4/2009 TREE _ . CNV GEN 4 07-23A Pre-Ria SAFEfY NOTES: TIGHT SPOT NOTm ON TOP OF LNR ON HO FORM. WEILHEAD= CAMERON ACTUA70R = AX~SON KB. ELEV = 57' BF. El.EV = KOP = 3050' Max Angle = 65 @ 9992' Datum MD = 10278' Datum ND = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 2490~ 4-1/2" TUBING CUT -5800~ 7-5/8" SCAB LNR, 29.7#, L-80, ID = 6.75" 5903~ - 624 Toc -9480' TOP OF 5-1 /2" TBG 9501 ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9501~ Minimum ID = 2.372 @ 9551' 2-7/8" PUP JOINT TOP OF 3-1/2" LNR 9547~ 2112' H4-1/2" CAMCO TRDP-4A SSSV NIP, ID = 3.812" ~ GAS LIFT MANDRELS ST fv~ N D DEV TY PE V LV LATCH PORT DATE 1 4111 4017 37 KBMG-M DMY BK 0 08/23/06 2 7105 6396 35 KBMG-M DMY BK 0 08/23/O6 3 9401 8317 49 KBMG-M DMY BK 0 08/23/06 9469' J-1 4-1/2" OTIS XN NIP, ID = 3.725" ~ 9480~ 4-1/2" X 5-1/2" XO 9501' S-1/2" BAK6~ SEAL ASSY 9502~ 9-5/8" X 5-1/2" BAKER SB-3 PKR . ~ ~ •.„ 9547~ ~~ 3-1/2" BAKER SETfING SLV, ID = 2.935" I3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" ~ 9550' ~ 9550 3-1/2" X 2-7/8 " XO TOP OF 2-7/8" LNR 9550' 9551' 2-7/8 PUP JOINT, ID = 2.372" TOP OF CEMENT 9570' 9610~ 5-1/2" XN NIP, ID = 4.455" (BENIND LNR) 3.75" MILLm OIJT 9624~ 5-1/2" BAKER SHEAROUT SUB (BENIND LNR) 5-1l2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 9625' 9625~ 5-1/2 TUBING TAIL (BEHIND LNR) J~7' E1.MD TT LOGGm 01/24/87 9-5/8" CSG, 47#, L-80, ID = 8.681" 9850~ MILLOUT WINDOW 9852' REF LOG: BHCS ON 09/01/86 ANGLE AT TOP PBZF: 60 @ 10526' Note: Refer to Roduction DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 10526 - 10536 O O6/24/98 2-1/8" 8 10580 - 10605 O 06/24/98 PBTD • 2-7/8" LNR 6.5#, L-80, .00579 bpf , ID = 2.441 " DATE REV BY COMMBJTS DATE REV BY COMMEIVTS 01/07/87 ORIGINAL COMPLETION 08/23/O6 JGWPAG GLV GO 10/02/94 RWO (SCAB LNR) OS/27/98 CTD SDTRCK 09/26/01 RWTP CORRECTIONS 07/05/05 DRS/TLH 1994 SCAB LNR CORRECTION 05/30/06 DTM WELLHEAL CORRECTION PRUDHOE BAY UNIT WELL: 07-23A PERMff No: 98-0890 API No: 50-029-21635-01 SEC33 T11 N R14E 33 2951.54 FEL 4462.7 FNL BP Exploration (Alaska) I 10662' I TREE = CNN GEN 4 W~LHEAD=° CAM@~ON ACTUATOR = AXELSON KB. E1.EV = 57' BF. ~EV = KOP = 3050' Max Angle = 65 @ 9992' ~tum AAD = 10278' Datum ND = 8800' SS ~ 13-3/8" CSG. 72#, L-80, ~= 12.347" F- j 2490' ~-- 7-5/8" SCAB LNR, 29.7#, L-80, ID = 6.75" 5903' - 6246' ~TOPOF 5-1/2" TBG H 9501' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9501' Minimum ID = 2.372 @ 9551' 2-7/8" PUP JOINT TOP OF 3-1/2" LNR 9547' O~-2 3A SAFETY NOTES: TIGHT SPOT NOTED ON TOP OF LNR ON HO FORM. ~ 2112~ H4-1/2" CAMCO TRDP-4A SSSV NIP, ID = 3.812" GAS L~f MANDR~S ST Iv~ ND DEV TYPE VLV LATCH PORT DATE 1 4111 4017 37 KBMG-M DMY BK 0 08/23/O6 2 7105 6396 35 KBMG-M DMY BK 0 08l23/O6 3 9401 8317 49 KBMC--M DMY BK 0 08l23/O6 J46.9' ~ 4-1/2" Ol1S XN NIP, ~= 3.725" ~ J4$0' 4-1/2" X 5-1/2" XO 9501~ 5-1/2" BAK~Z SEAL ASSY 9502' 9-5/8" X 5-1/2" BAKB~ SB-3 PKR 9547' H 3-1/2° BAK~ SEfTiNG SLV, ID = 2.935" ~3-1/2" LMR, 9.3#, L-80, .0087 bpf, ID = 2.992" ~ 9550~ 9550' 3-1/2° x 2-~~s ° xo TOP OF 2-7/8" LNR 9550~ 9551 ~ 2-7/8 PUP JO~Vf, ID = 2.372" TOP OF CEMENT 9570~ 9610~ 5-1 /2° XN Nq~, ID = 4.455" (BE}i9VD LNR) 3.75" MLLm OUT 9624~ 5-1/2° BAK@2 SHEAROUT SUB (BEFiN~D Lf~2) 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 9625~ ~25' 5-1/2 TUBING TAIL (B8-IIND LNR) 9607' ~AAD TT LOGG~ 01/24/87 9-5/8" CSG, 47#, L-80, ID = 8.681" J$5Q' MILLOUf WGVDOW 9852' PB~FORATION SUMIAAARY REF LOG: BF-ICS ON 09/01/86 ANGLE AT TOP PB2F': 60 @ 10526' Note: Refer to H-oduction DB for historical perf data SIZE SPF INTfftVAL Opn(Sqz DATE 2-1/8" 4 10526 - 10536 O O6l24/98 2-1/8" 8 10580 - 10605 O 06/24/98 PsTO H 1 Q631' 2-7/8" LNR, 6.5#, L-80, .00579 bpf , ID = 2.441" H 10662' DATE REV BY CAfuMABVTS DATE REV BY COMW~NfS 01/07/87 ORICaINAL COMPLETION 08/23/O6 JCIWPAG GLV GO 10/02/94 RWO (SCAB LNF~ 05/27/98 CTD SDTRCK 09/26/01 RNffP CARRECTIONS 07/05/05 DRSlTLH 1994 SCAB LNR CARRECTION 05/30/O6 DTM W~LHEAD CORRECTION I 10664' I PRImHOE BAY UNff WElL: 07-23A PERMIT No: 9&0890 A PI No: 50-029-21635-01 SEGi3 T11 N R14E 33 2951.54 FEL 4462.7 FP~ BP 6cploration (Alaska) Ramirez, Darlene V (DOA) From: Foerster, Catherine P (DOA) Sent: Monday, September 21, 2009 9:37 AM To: Ramirez, Darlene V (DOA) Subject: Re: 309-319 Approve Sent from my iPhone On Sep 21, 2009, at 9:12 AM, "Ramirez, Darlene V(DOA)" <darlene.ramirezC~alaska.gov > wrote: > «S45C-209091813421.pdf» > The message is ready to be sent with the following file or link > attachments: > > S45C-209091813421.pdf > > > IVote: To protect against computer viruses, e-mail programs may > prevent sending or receiving certain types of file attachments. > Check your e-mail security settings to determine how attachments are > handled. > <S45C-209091813421.pdf> ~ . ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate ŒJ WaiverD E'",,,,· !¡. E..... L¡)!rA1ri ~J v.:'JIZQ JUN 2 1 2005 §t~~~g" ·;~m.$:.. G¡]mmi: ff,JH"" ~1mf.~:e Time Extension .~ Re-enter Suspended Well D 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D Repair Well 0 Pull TubingD Operation Shutdown 0 PluÇJ Perforations 0 Perforate New Pool D Perforate D 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development []] ExploratoryD 5. Permit to Drill Number: 198-0890 6. API Number 50-029-21635-01-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 57.00 8. Property Designation: ADL-028309 11. Present Well Condition Summary: StratigraphicD ServiceD 9. Well Name and Number: 07-23A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 10664 feet true vertical 9049.5 feet Effective Depth measured 10631 feet true vertical 9032.7 feet Plugs (measured) Junk (measured) Tag TD @ 10523 (05/10/2005) None Casing Length Size CONDUCTOR 80 20" 91.5# H-40 LINER 3 3-1/2" 9.3# L-80 SCAB LINER 344 7-5/8" 29.7# L-80 LINER 1112 2-7/8" 6.5# L-80 PRODUCTION 9822 9-5/8" 47# L-80 SURFACE 2461 13-3/8" 72# L-80 Perforation depth: MD TVD Burst Collapse 30 110 30.0 110.0 1490 470 9547 - 9550 8417.2 - 8419.3 10160 10530 5902 - 6246 5430.2 - 5703.6 6890 4790 9550 - 10662 8419.3 - 9048.5 10570 11160 28 - 9850 28.0 - 8644.3 6870 4760 29 - 2490 29.0 - 2489.9 4930 2670 SCANNED JUL o 7' 2005 Measured depth: 10526 - 10536, 10580 - 10605 True vertical depth: 8980.34 - 8985.36, 9007.62 - 9020 TubinÇJ ( size, Qrade, and measured depth): 4-1/2" 12.6# L-80 5-1/2" 17# L-80 Packers & SSSV (type & measured depth): 4-1/2" Cameo TRDP-4A SSV 5-1/2" Baker SB-3 Packer 7-5/8" Liner Top Packer @ 26 @ 9501 @ 2112 @ 9502 @ 5902 9501 9625 ReDMS 8FL JUN 2 2 20D5 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10526-10536,10580-10605 Treatment descriptions including volumes used and final pressure: 12% DAD Acid pumped @ 3800 psi CTU pressure. 13 Prior to well operation: Subsequent to operation: Oil-Bbl 285 283 Representative Daily Averaqe Production or Injection Data Gas-Met Water-Bbl Casing Pressure 9636 415 0 9627 413 Tubing Pressure 216 275 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ] ServiceD Contact DeWayne Schnorr WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ::~::::ame ~wz;:rr4(!ct..__ ~ Title Petroleum Engineer Phone 564-5174 Date 6/20/05 Form 10-404 Revised 4/2004 :~ :~' ,-/ -0 ~\j 1\ L .. , ) ) 07-23A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/10105 MILL BODY WORN DOWN ON OD. AND FEW SMALL PIECES OF CUT RITE FROM CUTTER MISSING... BHA COVERED WITH SMALL GRAINS OF BROWN SAND...SOLlDS COULD BE HEARD GOING DOWN FLOW LlNE....RIH WI 1-3/4 JSN, STNGR DCV ......TAG 10,523 DOWN....PU @ 10518'... PUMP 50 BBL FLO-PRO FOR FLUID LOSS.... POH. RIH WI 1.75" JSN. TAG 3.5" LINER TOP. COULD NOT PASS. POOH. RIH WI 2" JSN. TAG LINER TOP. COULD NOT PASS THROUGH. POOH...... RIH WI TAPERED JSN 1-1/2 X 2-1/4.......10 ATTEMPTS TO GET IN LINER TOP..... CIRC OUT FLO-PRO..... BTM DEPTH 10,538 DOWN... PU 10,533 CTM... SUSUPECT LINER INTERGRTY PROBLEMS @ 10525' CTM..... PREP FOR ACID TREATMENT... 05/11/05 PRE ACID JOB INJ. RATE 140 PSI @ 1BPM & 750 PSI @ 1.9 BPM... PUMP 5012% DAD ACID FROM 10520'..... OVER DISPLACE 50 BBLS.... POST ACID INJ. RATE 2 BPM @ 710 PSi...... CONTACT DSO SO THAT THEY CAN POP WELL...****JOB COMPLETE**** FLUIDS PUMPED BBLS 162 60/40 METHANOL WATER 40 METHANOL 184 2% KCL WATER 418 1% EXTRA SLICK KCL WATER 50 FLO-PRO 50 12% DAD ACI D 904 TOTAL Page 1 ') CIW GEN 4 FMC AXELSON 57' TREE = W8..LHEAD = A CTl.1A. TOR = KB. ELEV = BF. ELEV = 'Rop""';"" .... ",....,.nww''''·'3ÖS'Õì' 'Max'Ãr,g~ ="M~65@ 99'92' 'ï5atumMí3^;~~"'''^-~-1 Oi7ê/ Dat^ü^mT\l6':;,;",oo""""'''ss6õí"s'§ 113-3/8" CSG, 72#, L-80, D = 12.347' H 2490' Minimu m ID = 2.372 @ 9551' 2-7/8" PUP JOINT 1 TOP OF 5-1/2" TBG H 4-1/2" 1BG,12.6#, L-80, 0.0152 bpf, 10= 3.958" l-f (5'c«b 1111\,.,. S,o,..!. ,1.."1,') 1 TOP OF 3-1/2" L NR 1-1 9547' 07 -23A " ~.. ~---'= 1- 'I ~:¡ \ I &---i 8: @ ~ W" ) SAFETY NOlES: TIGHT SFDT NOlED ON TOP OF LNR ON HO FORfv1. . 2112' H4-1/2" CAMOO lRCP-4A SSSV NP, 10 = 3.812" 1 GA S LIFT MANDR8..S ST MD lVD DEV 1YPE VLV LATCH PORT DATE 1 4111 4017 37 KBMG-M BK 2 7105 6396 35 KBMG-M BK 3 9401 8317 49 KBMG-M BK ~ 9469' 1--1 4-1/2" 011S XN NIP, D = 3.725" 1 9480' 1-1 4-1/2" X 5-1/2" XO 1 9501' 1--1 5-1/2"BAKERSEALASSY I 9502' 1--1 9-5/8" X 5-1/2" BAKER SB-3 PKR I 9547' 1--1 3-1/2" BAKER SEfTNG SL V, 10 = 2.935" 1 13-1/2" LNR, 9.3#, L-80, ,0087 bpf, ID= 2.992" 1-1 9550' '.. 9550' 1 TOP OF 2- 7/8" L NR l-f 9550' 9551' ITOP OF CE3'v1ENT 1-1 9570' 9610' 9624' 5-1/2" TBG, 17#, L-80, 0.0232 bpf,lD = 4.892" H 9625' 9625' 9607' 9-5/8" CSG, 47#, L-80, 10 = 8.681" H 9850' ÆRFORA 110N SUI'v1MARY RS= LOG: BHCS ON 09/01/86 ANGLE AT TOP PERF: 60 @ 10526' Note: Refer to Production DB for historical perf data SIZE SFf= INTERVAL Opn/Sqz DA lE 2-1/8" 4 10526-10536 0 06/24/98 2-1/8" 8 10580-10605 0 06/24/98 1-1 3-1/2" X 2-7/8" XO 1 1--1 2-7/8 RJP JOINT, 10 = 2,372" 1- 5-1/2" XN NIP, 10 = 4.455" (B8-iIND LNR) 3,75" MILLED OUT 1-15-1/2" BAKER SHEAROUT SLB (BEHIND LNR) 1--1 5-1/2 lUBING TAIL (BEHND LNR) H ELMD TT LOGGffi 01/24/87 1 PBlD H 10631' MILLOUT WINOOW 9852' 2-7/8" LNR, 6.5#. L-80, .00579 bpf ,10 =2,441" H 10662' DA lE REV BY COMrvENTS ORlGINA.L COMA..ETlON SIŒTRAO<. CONVERlED TO CANV AS FINA. L CORREC110NS DATE 05127/98 12/11/00 SIS-rvD 02/20/01 SIS-rvD 09/26/01 RN/W REV BY COMrvENTS PRUDt-DEBAY l.J'.J1T WELL: 07-23A PERMT I\b: 98-0890 AR I\b: 50-029-21635-01 SEC33 T11 N R14E33 2951.54 F8.. 4462.7 FNL BP Exploration (Alaska) W~:i-i c~mp'li~nce Report File on Left side of folder 198-089-0 PRUDHOE BAY UNIT 0_~7~23A 50- 029-21635-01 ARCO MD 10664 -~ TVD 09050-' Completion Date: /~6/4~98 Completed Status: 1-OIL Current: Name Interval Sent Received T/C/D .. NGP~MD ~ 945110663 OH 9/9/98 9/9/98 ~o~.,v~ .~9: o, 9~9~9~ 9~9~96 L RST-A /..M~q~ 10610.:9300 CH 5 10/23/98 10/29/980~'/.' T R SRVY RPT ~RRY 9800~10664. OH 6/26/98 7/1/98 T 8653 q~ SCHLUM RST CH 10/23/98 10/29/98 Daily Well Ops 5/~/~fi 4~./,~ ,q/.9',? Are D~ Ditch Samples Required? yes ~ And~no Was the well cored? ye~~ Analysis Description R~_~' no Sampl~ ~o~ .... Comments: Tuesday, May 30, 2000 Page 1 of 1 STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate._~ Plugging_ Per[orate_ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: ARCO Alaska, Inc. 5. Type of Well: Bevelopment _X Exploratory _ Stratagrapic _ Service _ 3. Address: P.O. Box 100360 Anchora~]e, AK 99510-0360 4. Location of well at surface: 1986' SNL, 219' WEL, Sec 33, T11 N, R14E, UM. At top of productive interval: At effective depth: At total depth: 4463' SNL, 2952' WEL, Sec 33, T10N, R14E, UM. 12. Present well condition summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Length Conductor 80' Surface 2433' 10664 feet 9050 feet 10620 feet 9027 feet Size 20" 13-3/8" Production 9795' 9-5/8" Plugs (measured) Junk (measured) 6. Datum of elavation (DF or KB feet): 57' RKB 7. Unit or Property: Prudhoe Bay Unit 8. Well number: 7-23A 9. Permitnumbe#approvalnumber: 98-089 10. APInumber: 50-029-20635-01 11. FielEPool: Prudhoe BayOil Pool FCC to 10620' MD (10/22/98). Cemented Measured depth True vertical depth 1900# Poleset 80' 80' 200 Sx CS III & 2490' 2490' 550 Sx CS II 700 Sx Class G & 9852' 8646' 300 Sx CS I Liner 344' 7-5/8" 6246' 5704' Liner 1117' 2-7/8" 10 Bbls LARC 10664' 9050' measured 10526- 10536'; 10580- 10605' Perforation Depth true vertical 8980 - 8985'; 9008 - 9020' Tubing (size, grade, and measured depth)5-1/2", 17#, L-80, Tbg @ 27' MD;5.1/2,,, 17#, L-80, Tbg @ 9501-4'1/2"'12'6#' L'80' Tbg @ 27' 9501' MD; OR/GINAL9625' MD. Packers and SSSV (type and measured depth) Baker SB-3 Packer @ 9502' MD; 4-1/2" Camco TRDP-4A SSSV @~..2_~. li¢ ~D ! .~ ,? ~,. 13. Stimulation or cement squeeze summary Intervals treated (measured) Intervals treated (measured) 14. see attached Representitive Daily Average Production or Injection Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1137 22231 181 922 17662 198 Tubing Pressure 445 704 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _X Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~~ "~. ~ Title: Engineering Supervisor Suspended _ Date ,.~ - Service _ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 7-23A DESCRIPTION OF WORK COMPLETED CTU SHMOO-BE-GONE & ACID STIMULATION TREATMENT W/PACKER 10/20/98 - 10/23/98: Pumped a Selective CTU Schmoo-Be-Gone & Acid Stimulation Treatment w/Packer as follows: MIRU CTU & PT equipment. RIH w/nozzle loading the wellbore w/1% KCI Water. Tagged Setting Sleeve at 9545' MD. POOH. RIH w/Inflatable Packer, but could not pass ledge at top of Setting Sleeve at 9551' MD. POOH w/Packer. MU Packer w/Bow Spring Centralizer. RIH w/Packer to sit down at 10521' MD, but needed to be at 10558' MD set point. POOH w/Packer. RIH w/Milling BHA & milled 10521 - 10620' MD while circulating out fill w/biozan. POOH w/BHA. RIH w/Packer w/Bow Spring, and set the packer at 10558' MD, to isolate the lower open perforation interval located at 10580 - 10605' MD. Pumped the Stimulation Treatment to treat the upper open perforation interval located above the Packer at: 10526 - 10536' MD (Z2) Pumped: a) 80 bbls of Schmoo-Be-Gone Solution @ 0.3 bpm, followed by b) Shutdown, for 30 minute soak. Resumed pumping c) 60 bbls Crude displacement, followed by d) 60 bbls 2% NH4CI Water, followed by e) 20 bbls 12% HCI w/10% Xylene, followed by f) 15 bbls 9% HCI - 1% HF, followed by g) 19 bbls 12% HCI w/10% Xylene, followed by h) 47 bbls 2% NH4CI Water, followed by i) 5 bbls 1% KCI Water, followed by j) 40 bbls Meth-Water, followed by k) 60 bbls Crude, followed by I) Shutdown. Deflated & POOH w/Packer. RD. Returned the well to production & obtained a valid welltest. ¼ GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 11596 Companl Alaska Oil & Gas Cons Comm Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501 10/23/98 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape SIGNED:~i/~' Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank OCT 29 igSO DATE: Alaska Oii& Gas ~ns. uommissio~ Anchorage WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 07-23A, September 9, 1998 AK-MW-80236 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of 2 Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21635-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. ,~, Anchorage, Alaska 99501 ~"~ September 9, 1998 RE: MWD Formation Evaluation Logs D.S. 07-23A, AK-MW-80236 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 I).S. 07-23A: 2" x 5" MD Gamma Ray Logs: 50-029-21635-01 2"x 5" TVD Gamma Ray Logs: 50-029-21635-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 98-089 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK99510-0360 .................... ~ . -~- _~_~- 50-029-21635-01 4 Location of well at surface ~ ~..,~., ........ ~ ~ 9 Unit or Lease Name 1986' SNL, 219' WEL, Sec 33, T11N, R14E, UM; (,¢_/,~/}~0¢ ~~ ~ PRUDHOE BAY UNIT At Top Producing interval ......... i 10 Well Number At Total Depth i ~,~-~' > . f f Field and Pool 4463' SNL, 2952' WE[., See 33, T11N, R14E, UM?~?'~ ......... ' ..... PRUDHOE BAY FIELD S Elevation in feet {indicate KB, DF, eto.) ~ Lease Designation and Serial No. 57' RKB ADL 28309 ~RUDHOE BAY OIL POOL 12 Date Spudded t 3 Date I.D. Beached t 4 Date Comp., Susp., or Aband. t S Water Depth, ~ ottshore t ~ No. of Completions 5/21/98 5/26/98 6/4/98 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 10664' MD / 9049.5' TVD 10630' MD / 9032' TVD YES_X NO__ 2112' MD 1900' (approx) 22 Type Electdc or Other Logs Run MWD & GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 91.5# H-40 Surf 80' 30,, 1900# Poleset - 13-3/8" 72# L-80 Surf 2490' 17.5" 200 Sx CS III & 550 Sx CS II - 9-5/8" 47# L-80 Surf 9852' 12.25" 700 Sx Class G & 300 Sx CS I 7-5/8" 29.7# L-80 5902' 6246' 9-5/8" 2-7/8" 6.4# L-80 9547' 10664' 3.75" 10 bbls 15.8 ppg Class G Cement w/Latex 24 Perforations open to Production (MD+-I-VD of Top and Bottom and . 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 5-1/2" Tbg 27' 9502' 10580' - 10605' MD; 9008' - 9020' TVD; @ 4 spf. 4-1/2" Tbg 9501' 10526' - 10536' MD; 8980'- 8985' TVD; @ 4 spf 5-1/2" Tbg 9625' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMT & KIND MATERIAL USED L 27 PRODUCTION TEST ~_ ~ ~-~ Date First Production Method of Operation (Flowing, gas lift, etc.) ~' i \ i [',-,~ : , \,~ ~' 6/25/98 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE I GOR 6/25/98 6.6 TEST PERIOD __J 1142 Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) 269 24 HOUR RATE _X 928 1060 32 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved 5/14/98 (Permit # 98-089). Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, and fluids recovered and gravity, MEAS DEPTH TRUE VERT DEPTH GOR, and time of each phase. Sadlerochit Top 9801' 8607' . (other pic$) 3-1 LISTOF ATTAOHMENTS Summary of 07-23A CT Sidetrack Drilling Operations + Survey. 321 hereby cedify that the foregoing is true and correct to the best of my knowledge Signed . _.~'~.~"~.,/~J~ /'~ ~ ~ ~)[j~'~)~0, ~'~,~ (,~0~ Engineering Supervisor Date '"-7'/~,~--J~ Erin Oba INSTRUCTIONS Prepared by Paul Rauf 263-4990 General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection Gas Injection, Shut-In, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Rev. 7-1-80 DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 5/19/98: MIRU CTU. PT BOPE. State Rep witnessed. 5/20/98: RIH w/BHA & tagged TOC @ 9570' MD. Milled pilot hole to 9761' MD. 5/21/98: Milled pilot hole to 9851.5' MD. POOH. RIH w/window milling BHA & tagged bottom. @ 9850.5' MD. Began milling window 5/22/98: Continued milling the window through the 9-5/8" casing. POOH because of MWD problems. RIH w/BHA & milled to 9856.5' MD. 5/23/98: Drilled ahead to 9865'. Window is from 9851.8' to 9858.5' MD. Backreamed window area. Pumped Biozan pill & POOH w/BHA. RIH w/BHA & drilled formation to 9925'. Displace well to FIo Pro. Performed LOT to EMW 9.5 ppg. Drilled to 10027' & POOH w/BHA. 5/24/98: RIH w/BHA & drilled to 10150'. POOH. RIH & drilled ahead to 10165'. POOH. RIH & drilled to 10280' MD. 5/25/98: Drilled from 10280' to 10660' w/3 trips to surface for BHA c/o's. 5/26/98: Drilled ahead to TD @ 10664' MD w/several short trips to window. POOH. RIH & landed the 1117' 2-7/8" liner @ TD. Pumped 10 bbls of 15.8# Class G Cement w/Latex followed by seawater to set liner from 9547' to 10664' MD. Bumped liner wiper plug, unstung from liner, & cleaned out cement while POOH. RIH w/nozzle & tagged TOL. Worked through TOL w/some difficulty. Cleaned out liner & POOH w/nozzle. RIH w/BHA & tagged TOL @ 9550'. Cleaned out liner to 10630' PBTD. WOC. 5/27/98: POOH w/BHA. RDMOL. 6/01/98: Drifted tbg to 9850' SLM. 6/04/98: MIRU CTU. Tested BOPE. RIH & tagged PBTD @ 10631' MD. POOH. RIH w/perforating guns & tagged PBTD. Shot 25' of perfs as follows: Initial Perforations: 10580'- 10605' MD (Zone 2B) Used 1-11/16' carriers & shot all perfs at 4 SPF, 0 degree phasing, random orientation, & at balanced pressure. Used 10.4" penetration charges. POOH w/perf guns and noted all shots fired. RD. Page 1 r ' ~ ~' 7-23A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 6~24/98: MIRU CTU. RIH w/perforating guns and shot perfs as follows: Reperforated 25': 10580' - 10605' MD (Zone 2B) Add Perforated 10': 10526' - 10536' MD (Zone 2B) Used 2-1/8" carriers & shot all perfs at 4 SPF, 180 degree phasing, random orientation, & at underbalanced pressure. POOH w/guns & noted all guns fired. RDMOL. Placed the well on initial production w/gas lift & obtained a valid well test. Page 2 0 I:11 I--I-- I I~ Oi S ~= I:t~./I C E S 26-Jun-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 07-23A oct Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,800.00' MD 9,851.00' MD 10,664.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company Prudhoe Bay Unit. Alaska State Plane Zone 4 PBU EOA DS 07 07-23A S UR VEY REPORT 26 June, 1998 Your Ref: API-500292163501 Last Survey Date 25-May-98 Job# AKMW80236 KBE- 57.00' sp=nr~-sun DRILLING SERVICES A O~lO~ or DR~SSa~ ]~OUSTIUi~ l~C. Aiaska Oil & ~ Cons. Survey Ref: svy3513 Prudhoe Bay Unit Measured Depth (rt) Incl. 9800.00 9851.00 9880.17 9907.27 9927.69 9962.74 9991.71 10018.69 10045.34 10079.86 10106.11 10141.89 10178.29 10208.87 10240.72 10274.77 10304.67 10339.87 10388.22 10398.42 10431.97 10461.77 10489.09 10523.54 10562.67 10593.08 10624.68 10643.66 10664.00 40.100 40.190 51.060 56.600 61.040 63.790 64.98O 64.860 62.580 60.380 60.290 60.640 60.910 61.700 61.260 61.000 60.290 59.940 60.910 60.820 59.500 59.760 59.680 60.030 59.330 60.380 61.000 59.240 59.000 Azim. 243.300 243.200 250.700 256.100 259.750 266.940 274.320 281.150 287.480 298.200 306.120 316.310 323.690 324.920 329.670 332.830 338,280 341.100 346.020 347.600 345.490 343.O30 341.980 338.280 338.460 335.820 336.350 338.99O 340.000 Sub-Sea Depth (ft) 8549.05 8588.04 8608.42 8624.41 8634.99 8651.23 8663.77 8675.22 8687.03 8703.54 8716.55 8734.23 8752.02 8766.70 8781.91 8798.36 8813.02 883O.56 8844.56 8859.27 8875.96 8891.03 8904.81 8922.11 8941.86 8957.14 8972.61 8982.06 8992.50 Vertical Depth (ft) 8606.05 8645.O4 8665.42 8681.41 8691.99 8708.23 8720.77 8732.22 8744.03 8760.54 8773.55 8791.23 8809.02 8823.70 8838,91 8855.36 8870.02 8887.56 8901.56 8916.27 8932.96 8948.03 8961.81 8979.11 8998.86 9014.14 9029.61 9039.06 9O49.5O Sperry-Sun Drilling Services Survey Report for 07-23A Your Ref: AP1-500292163501 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 2910.37 S 2288,93W 5945970.73 N 673782.79 E -1225.96 2925.17 S 2318.29W 5945955.25 N 673753.78 E 0.217 -1222.68 2933.19 S 2337.47W 5945946.78 N 673734.79 E 41.500 -1219.15 2939.40 S 2358.43W 5945940.08 N 673713.99 E 26.001 -1213.13 2943.04 S 2375.50W 5945936.05 N 673697.00 E 26,578 -1207.03 2946.61 S 2406.33W 5945931.75 N 673666.26 E 19.797 -1193.49 2946.32 S 2432.43W 5945931.44 N 673640.17 E. 23.332 -1179.23 2943.03 S 2456.62W 5945934.16 N 673615.90 E 22,930 -1163.46 2937.14 S 2479.76W 5945939.51N 673592.63 E 22.947 -1146.07 2925.42 S 2507.66W 5945950.57 N 673564.46 E 28.008 -1121.20 2913.30 S 2526.95W 5945962.24 N 673544.90 E 26.214 -1100.61 2892,82 S 2550.32W 5945982.17 N 673521,06 E 24.790 -1070.79 2868.51S 2570.71W 5946005.99 N 673500.10 E 17.707 -1039.33 2846.72 S 2586.36W 5946027.41 N 673483.94 E 4.373 -1012.55 2823.19 S 2601.48W 5946050.58 N 673468.28 E 13.176 -984.57 2797.05 S 2615.82W 5946076.38 N 673453.33 E 8.163 -954.82 2773.34 S 2626.60W 5946099.83 N 673442.00 E 16.062 -929.03 2744.72 S 2637.20W 5946128.19 N 673430.74 E 7.017 -899.20 2721.08 S 2644.17W 5946151.66 N 673423.22 E 15.475 -875.52 2695.40 S 2650.19W 5946177.20 N 673416.60 E 4.580 -850.62 2667.10 S 2656.95W 5946205.33 N 673409.18 E 6.726 -823.11 2642.36 S 2663.93W 5946229.90 N 673401.62 E 7.175 -798.49 2619.86 S 2671.02VV 5946252.23 N 673394.01 E 3.332 -775.71 2591.85 S 2681.14W 5946280.00 N 673383,23 E 9.343 -746.64 2560.45 S 2693.60W 5946311.10 N 673370.05 E 1.832 -713.47 2536.22 S 2703.81W 5946335.08 N 673359.27 E 8.263 -687.54 2511.03 S 2714.98W 5946360.00 N 673347.51 E 2.447 -660.29 2495,81S 2721.24W 5946375.07 N 673340.90 E 15.212 -644.10 2479.46 S 2727.35W 5946391.27 N 673334.41 E 4.422 -627.02 Comment Tie-in Survey Window Point Projected Survey Alaska State Plane Zone 4 PBU EOA DS O7 Continued... 26 June, 1998.5:29 - 2 - DrillQuest Prudhoe Bay Unit Sperry-Sun Drilling Services Survey Report for 07-23A Your Ref: API-500292163501 Alaska State Plane Zone 4 PBU EOA DS O7 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. ,:The Dogleg Severity is in Degrees per 100ft. :'"Vertical Section is from Well Reference and calculated along an Azimuth of 327.520° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10664.00ft., The Bottom Hole Displacement is 3685.94ft., in the Direction of 227.726° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9800.00 8606.05 2910.37 S 2288.93 W Tie-in Survey 9851.00 8645.04 2925.17 S 2318.29 W Window Point 10664.00 9049.50 2479.46 S 2727.35 W Projected Survey 26 June, 1998 - 5:29 - 3 - DrillQuest TONY KNOWLE$, GOVERNOR ALASI~A OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mav 14. 1998 Erin Oba Engineering Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-030 Re; Prudhoe Bav Unit 7-23A ARCO Alaska. Inc. Permit No. 98-089 Sur. Loc. 1986'SNL, 219'WEL, Sec. 33, T1 IN, R14E, UM Btmnhole Loc. 4259'SNL. 2919'WEL, Sec. 33, T11N, R14E, UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill thc above referenced well. The permit to redrill docs not exempt you from obtaining additional permits required by laxv 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 mav be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~David W.~J-6hnston ' Chairman BY ORDER OF THE COMMISSION dlffEnclosures cc; Departmcnt of Fish & Galnc. Habitat Section w/o cncl. Department of Environmental Conservation xv/o encl. STATE OF ALASKA ALASI~A'OIL AND GAS CONSERVATION COMMib%ION PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill_ Redrill X I lb. Type of Well Exploratory_ StratigraphicTest_ Development Oil Re-Entry__ Deepen -I Service_ Development Gas_ Single Zone X Multiple Zone_ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 57' 3. Address 6. Property Designation ,O///'~' 4 CO_ P.O. Box 100360 ,,,-,, ¢_.~0~ P, ul'~,~.~ "Prudhoe Bay Field Anchorage, AK 99510-0360 ~UL.~-~ -~ · :~ o ~ ~!~1~ Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1986' SNL, 219' WEL, Sec 33, T11N, R14E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 383' NSL, 2509' WEL, Sec 33, T11N, R14E, UM 7-23A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 4259' SNL, 2919' WEL, Sec 33, T11N, R14E, UM June, 1998 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line I No Close Approach 10884' MD / 9059' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 9825' MD Maximum hole angle 77° MaxJmurn surface 2800 psig Attotal depth (TVD) 8800' 18. Casing program Setting Depth Size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 4-1/8" 3-3/16" 6.2 L-80 TC II 1310' 9574' 8436' 10884' 9059' 10 bbls I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10580 feet Plugs(measured)Tagged fill @ 10295' MD (5/1/97) true vertical 9169 feet Effective depth: measured 10295 feet Junk (measured) true vertical 8893 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 20" 1900# Poleset 80' 80' Surface 2433' 13-3/8" 200 Sx CS III, 400 Sx 2490' 2490' CS II, & 350 Sx CS I Production 10471' 9-5/8" 700 Sx Class G & 10528' 9137' 300 Sx CS I Scab Liner 344' 7-5/8 5902' - 6246' 5430' - 5703' Perforation depth: measured 10272'-10294'; 10306'-10324' . ~ true vertical 8965'- 8981" 8990'- 9004' 20. Attachments Filing fee __X Properly plat _ BOP Sketch __x Diverter Sketch _ Drilling program .Z_X Drilling fluid program ~ Time vs depth plot Refraction analysis _ Seabed report _ 20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions: Call Steve Ward @ 265-1305. Signed ~::2'~ ,~. ~ Titlle Engineerin9 Supervisor Date ¢- '~' ,~ - Erin Oba Commission Use Only Prepared by Paul Rauf 263-4990 Per~ ~um~be~.~ ._~ C/ I APInumber 50- C) ~- c'/'- ~.~ j ('0 ~-~ ~-- Q) f' I Approval date ~...~¢/~, ~ ,,¢:'~;~1 otherSee coVerrequirementsletter for Conditions of approval Samples required Yes _2(No Mud log required _ Yes L'~No Hydrogen sulfide measures ~'Yes _ No Directional survey required .~/Yes _ No Required working pressure for DOPE _ 2M; _ 3M; _ SM; _ 10M; _ 15M _X 3500 psi for CTU Other: Original Signeo "avid W, Johns~or byordero, .~..~- Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate DS 7-23A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a high angle well from the existing wellbore. Complete with 3-3/16" cemented liner. Perforate and produce. Intended Procedure: · Cement squeeze and plugback the existing completion to - 9600' md. Mill window in 9-5/8" casing at -9825' md. Drill 10' of formation with 8.9 ppg Flopro fluid and perform Leak off test to 9.4 ppg. Directionally drill 3.75" x 1000' high angle well to access Upper Romeo reserves. Build angle to ~ 65° at TD. · Run and cement 3-3/16" liner to TD. · Perforate selected intervals. · Place well on production. APR 2 3 t998 April 23, 1998 AI CO Alaska, Inc. Structure · D.S. 7 Field · Prudhoe Bay Well' 7-23 Location · North Slope, Alaska N WELL PROFILE DATA ..... Po~r~t .....MD Inc D;? TVB Nodh ~'ostV. Sect Dog/lO0 ]qe on 9775.00 40.28 243.788529,89 -2903.19 -2274.48 0.00 0.00 End of Drop/Turn 9825.00 40.15 243.27 8568,07 -2917,55 -2303.38 3,38 0.7(3 End of Build/Turn 9899.18 58,00 250.00 8616,50 -2939.28 -2554,,74 12.65 25.00 End of Build/Turn 9974.70 65.(30 270,00 8652,80 -2950.34, -2419.65 38.18 25.0(3 End of Turn 10010.95 65.00 280.008668.15 -294-7.48 -24,52,31 58.14, 25.00 End of Turn 10065.30 65.00 295.00 8691.23 -2932.72 -2~99.11 95.71 25.00 End of Turn 10101.54,65.00 305.008706.59 -2916.,35 -2527.51 124.79 25.00 T.D, & End of Bu;Id/Turn 1(3885.95 76.88 22.369002,00 -2270.25 -2696.65 76(3.64 9..36 8400 - 8500 - 8600 8700 8800 8900 9000 9100 Tie on - 40.28 Inc, 9775.00 Md, 8529.89 Tvd, -1.69 Vs <- West (feet) 3000 2900 2800 2700 2600 2500 2400 2500 2200 21 O0 2000 1900 1800 1700 . 7-23B ~ 7-23E T.D. & End of Build/Turn - 76.88 Inc, 10883.95 Md, 9002.00 Tvd, 758.95 Vs i I I i i i I i I I i i I I i i i i I I i i i i I i i i i 2200 7-23E 2300 T.D. & End of Build - 9002.00 Tvd, 2270.25 S, 2696.65 W-- 2400 2500 7-23B 2600 0 ~ ~ 2900 ~~ Tie on - 8529.89 Tvd, 2903.19 S, 227¢.48 W 3000 3100 i i i i i 200 1 O0 0 1 O0 200 300 400 500 600 700 800 900 1000 11 O0 1200 1300 1400 1500 Vertical Section (feet) -> Azimuth 327.52 with reference 2@10.38 S, 2288.g2 W from ?-23A 3200 ARCO Alaska, Inc. D.S. 7,7-23 Prudhoe Bay, North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 7-23A CT Sidetrack #2 Last revised : 20-Apr-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 9775.00 40.28 243.78 8529.89 2903.19S 2274.48W 0.00 0.00 673796.84 5945979.15 9800.00 40.21 243.52 8548.97 2910.36S 2288.95W 0.70 1.73 673782.54 5945971.65 9825.00 40.15 243.27 8568.07 2917.58S 2303.38W 0.70 3.38 673768.29 5945964.09 9899.17 58.00 250.00 8616.49 2939.28S 2354.73~ 25.00 12.65 673717.46 5945941.20 9900.00 58.06 250.24 8616.93 2939.52S 2355.40W 25.00 12.80 673716.80 5945940.94 9974.69 65.00 270.00 8652.79 2950.34S 2419.64W 25.00 38.18 673652.84 5945928.63 10000.00 64.93 276.98 8663.51 2948.94S 2442.51W 25.00 51.64 673629.94 5945929.49 10010.93 65.00 280.00 8668.13 2947.48S 2452.30~ 25.00 58.13 673620.12 5945930.72 10065.28 65.00 295.00 8691.21 2932.72S 2499.10W 25.00 95.71 673572.99 5945944.37 10100.00 64.99 304.58 8705.92 2917.12S 2526.36~ 25.00 123.51 673545.37 5945959.34 10101.53 65.00 305.00 8706.56 2916.33S 2527.50W 25.00 124.79 673544.22 5945960.10 10200.00 64.23 315.16 8748.86 2859.17S 2595.46W 9.36 209.51 673474.94 5946015.65 10300.00 64.18 325.56 8792.47 2789.96S 2652.80~ 9.36 298.68 673416.01 5946083.49 10400.00 64.87 335.89 8835.57 2711.35S 2696.84W 9.36 388.64 673370.14 5946161.05 10500.00 66.26 346.06 8877.03 2625.41S 2726.42~ 9.36 477.02 673338.56 5946246.26 10600.00 68.30 355.96 8915.73 2534.45S 2740.75W 9.36 561.45 673322.10 5946336.86 10700.00 70.91 5.55 8950.65 2440.87S 2739.45W 9.36 639.69 673321.21 5946430.43 10800.00 73.99 14.81 8980.87 2347.18S 2722.56g 9.36 709.66 673335.91 5946524.49 10883.94 76.88 22.36 9002.00 2270.25S 2696.65W 9.36 760.64 673360.00 5946602.00 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 7-23A and TVD from Mean Sea Level. Bottom hole distance is 3525.05 on azimuth 229.91 degrees from wellhead. Vertical section is from tie at S 2903.19 W 2274.48 on azimuth 327.52 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ . .C T Drilling Wellhead Detail ~ CT Injector Head ,~ I ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure I _ ---- 7" Riser - Methanol Injection I tis 7" WLA Quick onnect ~ I I I I I I I ~.. Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange . I I I 7 ,.~ (3.5") Cutters or 7-1/16", 5M Ram Type Dual J ~ i ~ , , ~ Combination Cutter/Blinds Gate BOPE ~ ~ ~ Slip/ Pipe rams Flanged Fire Resistant Kelly Hose to Dual HCR Man e Choke Manifold Manual Valves Drilling spool 7-1/16", 5M % by 7-1/16", 5M Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams 2" Pump-In Manual Master Valve 0.458' (5.5") Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus ~~~ R :1 6 _AY 0 UT DS 7-23A CT Sidetrack Proposed Wellbore Sketch 4-1/2" Tubing GLM'S 7-5/8" Scab Liner 5902' - 6246' /2" XN Nipple 9469' Packer 9502' 5-1/2" XN Nipple 9610' Top of 3-3/16" Liner in 5-1/2" Tubing Tail Tbg Tail@ 9625' Window cut in 9-5/8" @ ~ 9825 - 9830' 4.125" open hole with 3.188" liner cemented in place Existing perfs cmt. sqz'd TD @ ~10800' 9-5/8" Casing shoe @ 10528' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Tyce of request: Aband~ _X Suspend _ Opefatim Shutdo';in _ Reenter suspended well _ · AJter casing _ Repair wetl _ F1ugging _X nme extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Othe~ _ 2. Name of Operator. 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 57' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 StratagraP~c_ Anchorage, AK 99510-0360 ~r~ce_ Prudhoe Bay Unit 4. Location of well at sudace: 8. Well number: 1986' SNL, 219' WEL, Sec 33, T11 N, R14E, UM 07-23 At top of productive interval: 9. Permit number. 383' NSL, 2509' WEL, Sec 33, T11N, R14E, UM 86-145 At effective depth: 10. APl number: 50-029-21635 At total depth: 11. Field/Pool: 154' NSL, 2316' EWL, Sec 33, T11N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 10580 feet Plugs (measured) Tagged Fill @ 10295' MD (5/1/97) true vertical 9196 feet Effective Depth: measured 10295 feet Junk (measured) ~.../~ true vertical 8983 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1900# Poleset 80' 80' Sudace 2433' 13-3/8" 200 Sx CS III, 400 Sx 2490' 2490' CS II, & 350 Sx CS I Production 10471' 9-5/8" 700 Sx Class G & 10528' 9137' 300 Sx CS I Scab Liner 344' 7-5/8" 5902' - 6246' 5430' - 5703' Pedoration Depth measured 10272' - 10294': 10306'- 10324' .~1 true vertical 8965' - 8981'; 8990'- 9004' Tubing (size. grade, and measured depth) 5-1/2", 17#, L-80, Tbg @ 27' MD; 4-1/2", 12.6#, L-80, Tbg @ 9501' MD; 5-1/2", 17#, L-80, Tbg @ 9625' MD. Packers and SSSV (type and measured depth) 9-5/8" X 5-1/2" Baker SB-3 Packer @ 9502' MD; 4-1/2" Camco TRDP-4A SSSV @ 2112' MD. 13. Attachments Description summary of proposal _X Detailed operations pro, ram _ BOP sketch _X 14. Estimated date for commencing operation 15. Status of well classification as: May, 1998 Oil _X Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. Questions: Call Steve Ward @ 265-1305. Signed ¢.,/~ "~' ~ Title: Eiqginooring Supervisor Date Erin Oba FOR COMMISSION USE ONLY F'repared by Paul Rauf263-4990 Conditions of approval: Notify Comission so ,epresentrtive may witness Approval No. Mechanical integrety test_ Subsequent form required 10- ~ O 7 fO6 I ,-~ H ~ c.'l',~ ~ Commfssioner Bate Approved by order of the Commissioner ,qe,,Hd t~! ............... Form 10-403 Rev 06~15/88 SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST COMPANY · FIE LD & POOl. __ ~,.. _~'! '0 / ~_-_~ ................ Ir,ll'l' CLASS j~ e__. ,..,' ADMINISTRATION ENGINEERING WEft. NAME P~'(---~- '7-~,.~/:~ PROGRAM:expDdev/~'redrll/~servl-lwellboreseg[ ann GEOL AREA ~ C:~O tlNIl'# ....... j l /,¢.:, .. ~"'C...~ __ ON/OFF SItORE 3 [.Jr~ique well ~ame arid numbe~ 4 Well located m a defined pool ...... 5 Well Iocaled p~ope~ distance from drilling unil boundary 6 Well located proper dislance from other wells . . ~ N 7 Sufficient acreage available in drilling unit ~ N 8 If devialed is wellbore plat ir]cIuded ~ N 9 ()peralor only affected pady. r,~ l(.) (ff~eralor has app~op~ialebondir~lorce ~.N I 1 ['e~n~il c:a~ be issued wilhoul conse~valion orde~ ~ N 12 ['e~n~it can be issued wilt~oul adminislralive approval N l r~ (";~ IXunul be approved before 15-day wait N 14 Conductor stying provided . 15 StJrlace casing protects all known USDWs. . . 1O CMT vol adequale to cuculate on conductor & surf csg. 17 CMI vol adequale to lie-in long string Io suit csg 18 (;MI will cover all known produclive horizons. '19 Casir~g designs adequate for C, 'f. B &permatrost 20 Adeqtlale tankage or rese~e pil ....... 21 I1 a re.drill, has a 10-403 for abandonrnenl been approved. 22 Aduquate wellbole separalion p~oposed . . 23 If diverler required, does it meel regulations 24 l)rilhnfl fltd(I program ~;chenlatic & ecltlip list a(leqt~ale 25 [:Jf)F'[{.'.r,. do tl~ey rneel regulatio~ 26 BC-)I'E p~ess rating appropriate: test lo ~~ 27 Choke manifold complies w/APl RP-53 (May 84) 28 Work will occur wilhoul operation shuldown.. 20 Is [ueserx:e of t I:,S gas probable. REMARKS 30 Pern~il can be issued w/o hydrogen sulfide rr~ 31 Dala p~esenled on potenlial ov~~ 32 Se,s,n,c anal~~,s. 33 Se~~if off-site) , . :,1 (' ~;~ ]~e/pt~or~f for weeklyprogress reports " lezplorJloty only] GEOLOGY Y N Y N Y N Y N '~N Y N .~.'~._~._i~.~-- C~N .(~NN ENGINEERING' COMM. LSSION ~ ~--~--_~/~a~ :W6~~.~ Commentsllnstructions' ,.IDt I.~ RNC~ co CoSl¢ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUFZBERGER ....... COMPANY NAIVZE : ARCO ALASKA INC. WELL NAME : D.S. 7-23A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292163501 REFERENCE NO : 98516 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT-195~16 : 26 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/10/15 ORIGIN : FLIC REEL NAME : 98516 CONTINUATION # : PREVIOUS REEL : COMI~IENT : ARCO ALASKA, INC., DS 7-23A, PRUDHOE BAY, # 50-029-21635-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/10/15 ORIGIN : FLIC TAPE NAME : 98516 CONTINUATION # : 1 PREVIOUS TAPE : COF~4F2FT : ARCO ALASKA, INC., DS 7-23A, PRUDHOE BAY, # 50-029-21635-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAFiE: D.S. 7-23A API NU1TBER: 500292163501 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 15-0CT-98 JOB NUMBER: 98516 LOGGING ENGINEER: D. PALFIER OPERATOR WITNESS: WORTHINGTON SURFACE LOCATION SECTION: 33 TOWNSHIP: liN RANGE: 14E FNL: 1986 FSL: FEL: 219 FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: 57. O0 DERRICK FLOOR: 56. O0 GROUND LEVEL: 27. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 3. 750 2. 875 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (M~ASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT-199~-~6:26 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN ~ER : PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SPERRY SUN BASELINE DEPTH .............. 88888.0 10585.0 10563.0 10546.5 10540.0 10539.5 10476.5 10443.5 10435.5 10363.0 10289.5 10289.0 10247.5 10223.5 10210.0 10204.0 10195.0 10185.0 10173.0 10150.5 10147.0 10106.5 10064.5 10049.0 10048.0 10041.5 10030.0 10024.5 10024.0 10016.0 10015.5 9995.5 9994.5 9972.0 9964.5 9963.5 9934.0 9924.0 9912.5 9911.5 9884.5 9884.0 9871.0 9867.5 9867.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88884.5 88884.5 10581.5 10559.5 10559 . 5 10542.0 10542.0 10537.0 10537.0 10474.0 10474.0 10439.0 10439.0 10431.0 10431.0 10354.0 10354.0 10288.5 10288.5 10247.0 10247.0 10221.0 10221.0 10205.5 10205.5 10200.5 10200.5 10192.0 10192.0 10182.0 10182 . 0 10169.5 10169.5 10149.5 10149.5 10145.5 10145.5 10103.0 10103.0 10061 . 0 10061.0 10045.5 10045.5 10039.0 10026.0 10026.0 10022.0 10022.0 10012.0 10012.0 9992.5 9992.5 9970.5 9970.5 9962.0 9962.0 9931.5 9931.5 9921.5 9922.0 9911.0 9911.0 9882.5 9882.5 9870.0 9865.0 9865.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT_19~6--.~ 6 : 26 9857.5 9855.0 9855.0 9810.5 9810.0 9810.0 9802.5 9804.0 9801.0 9800.5 9800.0 9800.5 9789.5 9788.5 9788.5 9782.0 9781.0 9781.0 9780.0 9778.0 9778.0 9775.5 9774.0 9774.0 9767.5 9766.0 9766.5 9766.0 9755.0 9753.5 9753.5 9744.0 9742.5 9742.5 9741.0 9739.0 9739.0 9736.0 9734.5 9734.5 9732.0 9729.5 9729.5 9700.5 9699.5 9699.5 9699.5 9668.0 9668.5 9668.5 9665.0 9666.0 9666.0 9662.5 9664.0 9659.5 9659.5 9659.5 9571.0 9570.0 9570.0 100.0 99.0 99.0 CONTAINED HEREIN IS THE RST SIGMA-MODE DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 7-23A ON 4-JUN-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT RST SIGMA-MODE PASS #1 GRCH TO THE BASELINE GAF~4A RAY PROVIDED BY THE CLIENT (GR.MWD) ; AND RST SIGMA-MODE PASS #1 SIGM TO GR.MWD. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMFIARY LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT-199~16:26 PAGE: LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10590.0 9482 . 0 RST 10610.0 9482.0 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT-~9~16 : 26 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL O0 000 O0 0 1 1 1 4 68 0000000000 CIRNFIL O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL O0 000 O0 0 1 1 1 4 68 0000000000 BSALRST PPK O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU O0 000 O0 0 1 1 1 4 68 0000000000 SIGM RST CU O0 000 O0 0 1 1 1 4 68 0000000000 DSIG RST CU O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA O0 000 O0 0 1 1 1 4 68 0000000000 CRRARST O0 000 O0 0 1 1 1 4 68 0000000000 GRCH RST GAPI O0 000 O0 0 1 1 1 4 68 0000000000 TENS RST LB O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10632.000 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST -999.250 CRRA.RST GRCH. RST -999.250 TENS.RST -999.250 CCL.RST -999.250 GR.MWD DEPT. 9466.500 NBAC.RST -999.250 FBAC. RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF.RST -999.250 TPHI.RST -999.250 S?FC.RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST -999.250 CRRA.RST GRCH. RST -999.250 TENS.RST -999.250 CCL.RST -999.250 GR.MWD -999.250 -999.250 -999.250 -999.250 -999.250 32.070 -999.250 -999.250 -999.250 -999.250 -999.250 35.240 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT-19~5~=16 : 26 PAGE: **** FILE TRAILER **** FILE NAM~ : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER : 2 DEPTH INCREM~J~T: O. 5000 FILE SUMMzARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10590.0 9286.0 RST 10610.0 9286.0 $ CURVE SHIFT DATA - PASS TO PASS (~EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10583.5 10574.5 10563.5 10554.5 10548.5 10540.5 10539.5 10492.5 10492.0 10476.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88884.5 88884.0 10560.0 10537.0 10489.0 10473.0 10579.5 10570.0 10550.0 10543.5 10536.5 10489.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-OCT-19~b~;i6 :26 PAGE: 10474.0 10471 . 0 10454.0 10449.0 10436.0 10431 . 0 10435.5 10430.5 10411.0 10403.0 10404.0 10385.5 10377.5 10363.5 10353.5 10358.5 10350.0 10347.0 10339.0 10290.0 10288.5 10278.0 10275.5 10260.5 10259.5 10251.0 10250.5 10245.5 10244.0 10237.0 10235.5 10229.0 10226.5 10219.0 10216.0 10218.0 10214.5 10213 . 5 10208.5 10185.0 10181.0 10170.0 10166.5 10162.5 10160.0 10151.5 10150.0 10146.5 10144.5 10115.0 10112.5 10108.0 10104.0 10106.5 10102.5 10075.0 10071 . 0 10049.0 10045.0 10048.5 10045.5 10043.0 10039.0 10025.5 10022.0 10025.0 10022.0 10016.0 10012.0 9999.0 9995.5 9996.0 9992.5 9995.0 9992.5 9975.5 9973.5 9972.5 9970.5 9965.5 9962.5 9964.0 9962.0 9960.5 9957.5 9947.5 9944.5 9935.0 9931.5 9934.0 9931.0 9925.0 9922.0 9924.0 9921.5 9913 . 5 9911 . 0 9911.5 9910.5 9898.0 9896.5 9885.0 9883.0 9882.5 9880.0 9876. $ 9871.0 9869.5 9868.5 9865.5 9865.0 9862.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-OCT-199~t~i~6 : 2 6 PAGE: 9859.0 9845.0 9832.0 9810.5 9805.5 9801.5 9800.0 9795.5 9795.0 9789.0 9775.5 9773 5 9763 5 9762 0 9755 0 9742 5 9737 0 9730 0 9728 0 9716.5 9700.5 9700.0 9668.0 9667.5 9663.0 9660.5 9648.0 9647.0 9617.0 9609.0 9597.5 9585.0 9571.5 9544.5 9541.0 9526.5 951 O. 5 951 O. 0 9505.5 9487.0 100.0 9855.5 9800.5 9795.0 9787.0 9774.0 9764.0 9753.5 9740.5 9734.5 9727.0 9714.5 9699.0 9668.5 9659.5 9648.0 9616.5 9596.0 9570.0 9543.0 9525.5 9509.5 9485.5 98.5 9843.0 9829.5 9809.5 9806.0 9799.5 9794.0 9771.5 9761.0 9726.0 9699.5 9667.5 9664.0 9647.5 9608.5 9583.5 9540.0 9508.5 9502.5 97.0 REM_ARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH; AND PASS #2 SIGM TO PASS #1 SIGM. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT-199~i6 : 26 PAGE: ** 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 O. 5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUM~ NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFI~ SAMP ELE~ CODE (HEX) O0 000 O0 0 2 1 1 4 68 0000000000 DEPT FT NBAC RST CPS O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL O0 000 O0 0 2 1 1 4 68 0000000000 BSAL RST PPK O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT-19~16 : 26 PAGE: 10 ** DATA ** DEPT. 10606. 000 NBAC. RST SFNA. FIL 15. 689 SBFA. FIL IRAT. FIL O. 447 CIRN. FIL SIBF. RST 52.2 64 TPHI. RST SIGM. RST 15. 610 DSIG. RST GRCH. RST -999. 250 TENS. RST DEPT. 9283. 000 ArBAC. RST SFNA. FIL 45. 055 SBFA. FIL IRAT. FIL O. 418 CIRN. FIL SIBF. RST 331 . 485 TPHI.RST SIGM. RST 44. 601 DSIG. RST GRCH. RST - 999. 250 TENS. RST 2260. 131 FBAC. RST 41. 773 SFFA.FIL 1.333 CIRF. FIL 22.268 SFFC. RST O. 634 FBEF. RST 23. 000 CCL. RST 2445. 308 FBAC.RST 51.905 SFFA.FIL O. 428 CIRF. FIL 52. 224 SFFC. RST 2. 047 FBEF. RST 45 . 000 CCL. RST 3835. 294 15. 262 3. 421 15. 600 60. 525 O. 001 2951. 585 44. 990 O. 714 44. 571 74. 925 0.000 SBNA.FIL TRAT. FIL BSAL.RST SFNC. RST CRRA.RST SBNA.FIL TRAT. FIL BSAL.RST SFNC.RST CRRA.RST 52. 727 O. 877 83.736 16. 043 2.160 60.030 1.452 539.350 45.960 2.315 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREPIENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH GRCH 10590.0 RST 10610.0 STOP DEPTH 9304.0 9304.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-OCT-19~b~-~i 6 : 26 PAGE: 11 $ CURVE SHIFT DATA - PASS TO PASS (f4EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS h73FIBER : 2 BASELINE DEPTH 88888.0 10583.0 10563.0 10554.5 10540.0 10539.0 10493.0 10475.5 10473.5 10463.0 10452.5 10435.5 10412.0 10385.0 10358.5 10356.0 10346.5 10341.0 10289.0 10260 5 10242 0 10218 5 10217 5 10204 0 10193 0 10184 5 10169 5 10162.0 10157.0 10147.0 10146.0 10106.0 10077.5 10075.0 10065.5 10063.5 10048.5 10048.0 10042.5 10041.0 10025.0 10024.0 10015.5 9998.5 9995.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88885.5 88884.5 10560.5 10537.5 10489.0 10472.5 10460.5 10431.5 10347.5 10241.0 10216.0 10190.5 10166.5 10154.5 10146.5 10104.0 10077.0 10064.0 10045.5 10039.0 10022.0 9995.5 9992.5 10579.5 10550.5 10536.5 10471.0 10448.5 10431.0 10406.0 10377.5 10350.5 10339.0 10334.0 10288.5 10259.5 10215.0 10200.0 10181.0 10160.5 10144.5 10102.5 10071.5 10060.5 10045.5 10039.0 10021.5 10012.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 12 9994.5 9972.0 9969.0 9964.5 9960.0 9954.5 9934.0 9933.5 9924.5 9912.0 9911.5 9897.5 9888.0 9870.5 9868.0 9864.0 9858.0 9844.0 9838.5 9831.0 9810.5 9810.0 9805.0 9801.5 9799.0 9795.0 9792.5 9783.0 9767.0 9766.5 9751.5 9742.0 9736.0 9720.5 9709.5 9700.5 9699.5 9681.5 9677.0 9672.5 9668.0 9662.0 9660.0 9617.0 9609.0 9595.5 9590.0 9572 5 9560 0 9544 5 9531 0 9510 0 9499 0 9486.5 9465.0 9966.0 9962.0 9957.5 9931.5 9922.0 9910.5 9865.5 9855.5 9837.0 9809.5 9801.0 9794.5 9782.5 9767.0 9749.5 9740.5 9734.5 9699.5 9677.0 9668.5 9659.5 9616.5 9587.5 9558.5 9543.0 9530.0 9485.5 9464.0 9992.5 9970.5 9952.5 9931.0 9910.5 9896.5 9886.5 9869.5 9861.5 9843.0 9829.5 9809.5 9806.0 9799.5 9791.5 9765.5 9719.0 9709.5 9699.5 9682.5 9673.5 9664.0 9608.5 9596.0 9572.0 9508.5 9498.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT-199~6:26 PAGE: 13 9453.0 9452.0 9439.5 9438.5 9430.5 9429.5 9413.0 9412.0 9411.5 9409.0 9405.0 9403.0 9404.0 9403.0 9396.5 9396.0 9389.0 9386.0 9359.0 9359.0 9354.0 9351.5 9353.5 9354.5 100.0 101.0 97.5 RE,NUllS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #3. IN ORDER TO MAXIMIZE THE CORRELATIVE INTERVAL, PASS #3 GRCH WAS DEPTH SHIFTED TO PASS #2 GRCH; AND PASS #3 SIGM WAS SHIFTED TO PASS #2 SIGM. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** 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 11 66 11 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 PAGE: 14 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) DEPT FT 00 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL O0 000 O0 0 3 1 1 4 68 0000000000 CIRNFIL O0 000 O0 0 3 1 1 4 68 0000000000 CIRF FIL O0 000 O0 0 3 1 1 4 68 0000000000 BSAL RST PPK O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RST PU-S O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST CU O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RST UA O0 000 O0 0 3 1 1 4 68 0000000000 CRRA RST O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB O0 000 O0 0 3 1 1 4 68 0000000000 CCL RST V O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10606.500 NBAC.RST 2258.824 FBAC.RST 3892.157 SBNA.FIL SFNA.FIL 14.875 SBFA.FIL 38.811 SFFA.FIL 14.409 TRAT. FIL IRAT. FIL 0.441 CIRN. FIL 1.438 CIRF. FIL 3.603 BSAL.RST SIBF.RST 48.281 TPHI.RST 23.697 SFFC. RST 14.835 SFNC.RST SIGM. RST 14.830 DSIG.RST 0.360 FBEF.RST 61.523 CRRA.RST GRCH.RST -999.250 TENS.RST 46.000 CCL.RST 0.000 DEPT. 9301.500 NBAC.RST 2618.004 FBAC.RST 3065.419 SBNA.FIL SFNA.FIL 46.600 SBFA.FIL 59.429 SFFA.FIL 48.397 TRAT. FIL IRAT. FIL 0.401 CIRN. FIL 0.365 CIRF. FIL 0.629 BSAL.RST SIBF.RST 335.856 TPHI.RST 52.796 SFFC. RST 47.876 SFNC. RST SIGM. RST 47.954 DSIG.RST 1.516 FBEF.RST 71.905 CRRA.RST GRCH. RST -999.250 TENS.RST 38.000 CCL.RST 0.016 57.332 0.902 73.123 15.399 2.176 59.924 1.485 543.332 47.474 2.274 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT-199~6:26 PAGE: 15 **** FILE TRAILER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, RST $ REMARKS: THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 16 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 12 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 NUlVZB SAMP ELEM CODE (HE~) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS O0 000 O0 0 4 1 1 4 68 0000000000 SBNA RSAV CU O0 000 O0 0 4 1 1 4 68 0000000000 SFNA RSAV CU O0 000 O0 0 4 1 1 4 68 0000000000 SBFA RSAV CU O0 000 O0 0 4 1 1 4 68 0000000000 SFFA RSAV CU O0 000 O0 0 4 1 1 4 68 0000000000 TRAT RSAV O0 000 O0 0 4 1 1 4 68 0000000000 IRAT RSAV O0 000 O0 0 4 1 1 4 68 0000000000 CIRN RSAV O0 000 O0 0 4 1 1 4 68 0000000000 CIRF RSAV O0 000 O0 0 4 1 1 4 68 0000000000 BSAL RSAV PPK O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RSAV CU O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RSAV PU-S O0 000 O0 0 4 1 t 4 68 0000000000 SFFC RSAV CU O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RSAV CU O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RSAV CU O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RSAV CU O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RSAV UA O0 000 O0 0 4 1 1 4 68 0000000000 CRRA RSAV O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10606.500 NBAC.RST 2072.549 FBAC.RST SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV SIBF.RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF.RSAV GRCH.RST -999.250 3120. 000 SBNA. RSAV - 999.250 TRAT. RSAV -999. 250 BSAL. RSAV -999 . 250 SFNC. RSAV -999. 250 CRRA~ RSAV -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center I$-00T-199~6:26 PAGE: 17 DEPT. 9481 . 000 NBAC.RST 2308.129 FBAC.RST SFNA.RSAV 50. 601 SBFA.RSAV 55. 717 SFFA.RSAV IRAT. RSAV O. 420 CIRN. RSAV O. 333 CIRF. RSAV SIBF. RSAV 537.306 TPHI.RSAV 53.531 SFFC. RSAV SIGM. RSAV 51.267 DSIG.RSAV 1. 017 FBEF.RSAV GRCH. RST 35. 402 2976. 081 SBNA. RSAV 51. 842 TRAT. RSAV O. 527 BSAL. RSAV 51. 253 SFNC. RSAV 66. 966 CRRA. RSAV 63. 719 1. 511 684. 408 51. 556 2. 418 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILENUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 1 DEPTH INCREMENT: 0.5000 FILE VENDOR TOOL CODE START DEPTH RST 10627.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TDDRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : STOP DEPTH 9445.5 4-JUN-98 8C0-609 1609 4-JUN-98 10631.0 10610.0 9300.0 10610.0 · · LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT-1998 16:26 PAGE: 18 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY RST RESEVOIR SATURATION $ TOOL NUMBER CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 3. 750 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) : SEA WATER 8.34 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL)'. MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: TIED IN TO BHC SONIC LOG, 09-01-86 RST-A RAN IN SIGMA MODE TOOLS RAN WITH COILED TUBING THIS FILE CONTAINS THE RAW RST SIGM-MODE DATA FOR PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT-1998 16:26 PAGE: 19 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 5 1 1 4 68 0000000000 CS PS1 F/HR O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB O0 000 O0 0 5 1 1 4 68 0000000000 NPHVPS1 V O0 000 O0 0 5 1 1 4 68 0000000000 NPDE PS1 V O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS1 V O0 000 O0 0 5 1 1 4 68 0000000000 CRRA PS1 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS1 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS1 S O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS1 V O0 000 O0 0 5 1 1 4 68 0000000000 CPSV PS1 V O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS1 V O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS1 V O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS1 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS1 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS1 O0 000 O0 0 5 1 1 4 68 0000000000 RCAKPS1 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS1 O0 000 O0 0 5 1 1 4 68 0000000000 FPHVPS1 V O0 000 O0 0 5 1 1 4 68 0000000000 FPDE PS1 V O0 000 O0 0 5 1 t 4 68 0000000000 FSCE PS1 V O0 000 O0 0 $ 1 1 4 68 0000000000 FSCR PS1 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS1 S O0 000 O0 0 $ 1 1 4 68 0000000000 SF6P PS1 PSIG O0 000 O0 0 5 1 1 4 68 0000000000 .. LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT-1998 16:26 PAGE: 20 NAME SERVUNIT SERVICE API API API API FILE NUM~ NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) HVPV PS1 V BMCU PS1 UA GDCU PS1 MA EXCU PS1 UA NBEF PS1 UA FBEF PS1 UA NPGF PS1 FPGF PS1 BSTR PS1 BSPR PS1 MARC PS1 XHV PS1 V XPSV PS1 V XP2V PS1 V XI~2V PS1 V RXFR PS1 RXLC PSI RXRC PS1 RXAK PS1 SHCU PS1 MA BSAL PS1 PPK BSAL SIG PPK CIRNPSl CIRF PS1 CIRNFIL CIRF FIL DSIG PS1 CU FBAC PS1 CPS IRAT PS1 IRAT FIL NBAC PS1 CPS SFNA PS1 CU SFFA PSl CU SBNA PS1 CU SBFA PS1 CU SFNA SIG CU SFFA SIG CU SBNA SIG CU SBFA SIG CU SFNA FIL CU SFFA FIL CU SBNA FIL CU SBFA FIL CU SIBF PS1 CU SFNC PS1 CU SFFC PSl CU SIGM PS1 CU SIBF SIG CU SIGM SIG CU TRAT PS1 TRAT SIG O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 $ 1 1 4 68 0000000000 O0 000 O0 0 $ 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 $ 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 I 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-0CT-1998 16:26 PAGE: 21 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) TRAT FIL O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI O0 000 O0 0 5 1 1 4 68 0000000000 RDIX PS1 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PS1 K~Z O0 000 O0 0 5 1 1 4 68 0000000000 CRFI PS1 KHZ O0 000 O0 0 5 1 1 4 68 0000000000 CTM PS1 DEGC O0 000 O0 0 5 1 1 4 68 0000000000 XTM PS1 DEGC O0 000 O0 0 5 1 1 4 68 0000000000 TAV PS1 KV O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS1 AMP O0 000 O0 0 5 1 1 4 68 0000000000 CACU PS1 AMP O0 000 O0 0 5 1 1 4 68 0000000000 BUST PS1 O0 000 O0 0 5 1 1 4 68 0000000000 BUSP PS1 O0 000 O0 0 5 1 1 4 68 0000000000 RSXS PS1 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU O0 000 O0 0 5 1 1 4 68 0000000000 TPHI SIG PU O0 000 O0 0 5 1 1 4 68 0000000000 CCLC PS1 V O0 000 O0 0 5 1 1 4 68 0000000000 RSCS PS1 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS1 AQTM. PS1 CM2 V. PS1 RCAK. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR . PS1 XPSV. PS1 RXLC. PS1 BSAL. PS1 CIRN. FIL IRAT. PS1 SFFA. PS1 SFFA. SIG SFFA. FIL SFNC. PS1 SIGM. SIG GR. PS1 CTM. PS1 CACU. PS1 TPHI. PS1 DEPT. NPDE. PS1 AQTM. PS1 CM2 V. PS1 RCAK. PS1 10627.000 1569.139 0.661 -12.172 0.000 2.000 161.133 28.445 33.836 5.040 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 33 396 101 074 2 598 -999 250 9445.000 1570.245 0.661 -12.211 0.000 CS.PS1 1800.900 TENS.PSi 29.000 NPHV. PS1 NSCE. PS1 2.310 CRRA.PS1 2.143 NSCR.PS1 CHV. PS1 201.581 CPSV. PS1 5.079 CP2V. PS1 RCFR.PS1 0.000 RCLC.PS1 0.000 RCRC.PS1 RTDF. PS1 0.000 FPHV. PS1 1528.322 FPDE. PS1 FSCR.PS1 -0.068 AQTF. PS1 0.661 SF6P.PS1 BMCU. PS1 31.640 GDCU. PS1 59.028 EXCU. PS1 FBEF. PS1 60.954 NPGF. PS1 0.990 FPGF. PS1 BSPR.PS1 1.076 MARC. PSI 0.000 XJtV. PS1 XP2V. PS1 12.012 XM2V. PS1 -12.231 RXFR.PS1 RXRC. PS1 0.000 RXAK. PS1 0.000 SHCU. PS1 BSAL.SIG -999.250 CIRN. PS1 -999.250 CIRF. PS1 CIRF. FIL -999.250 DSIG.PS1 -999.250 FBAC. PS1 IRAT. FIL -999.250 NBAC. PS1 -999.250 SFNA.PS1 SBNA.PS1 -999.250 SBFA.PS1 -999.250 SFNA.SIG SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PS1 SFFC. PS1 -999.250 SIGM. PS1 -999.250 SIBF. SIG TRAT. PSl -999.250 TRAT. SIG -999.250 TRAT. FIL RDIX. PS1 39884.000 CRNI.PS1 454.475 CRFI.PS1 XTM. PS1 100.098 TAV. PSl 94.888 FICU. PS1 BUST. PSI 3.000 BUSP.PS1 3.000 RSXS. PS1 TPHI.SIG -999.250 CCLC. PS1 0.029 RSCS.PS1 CS.PS1 1916.622 TENS. PSi 38.000 NPHV. PS1 NSCE. PS1 2.409 CRRA.PS1 2.314 NSCR.PS1 CHV. PS1 201.823 CPSV. PS1 5.060 CP2V. PS1 RCFR.PS1 0.000 RCLC. PS1 0.000 RCRC. PS1 RTDF. PS1 0.000 FPHV. PS1 1520.997 FPDE. PS1 1574.708 1.269 12.202 0.000 1508.523 134.210 2.762 0.997 200.854 0.000 36.747 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 212.084 2.544 8878.000 8459.000 1577.150 0.320 12.187 0.000 1503.755 LIS TaPe'Verification Listing Schlumberger Alaska Computing Center 15_0CT_19~-'~16 :26 PAGE: 22 FSCE. PS1 1.841 FSCR.PS1 HVPV. PS1 161.482 BMCU. PSl NBEF. PS1 30.517 FBEF. PS1 BSTR.PS1 57.796 BSPR.PS1 XPSV. PS1 5.036 XP2V. PS1 RXLC. PS1 0.000 RXRC. PS1 BSAL. PS1 614.848 BSAL.SIG CIRN. FIL 0.390 CIRF. FIL IRAT. PSl 0.463 IRAT. FIL SFFA.PS1 47.961 SBNA.PS1 SFFA.SIG 2.241 SBNA.SIG SFFA.FIL 48.571 SBNA.FIL SFNC. PS1 49.745 SFFC. PS1 SIGM. SIG 1.444 TRAT. PS1 GR.PSl 30.266 RDIX. PSl CTM. PS1 93.262 XTM. PS1 CACU. PS1 2.594 BUST. PSi TPHI.PS1 52.971 TPHI. SIG -0.085 AQTF. PS1 34.361 GDCU. PS1 70.611 NPGF. PS1 1.273 MARC. PSI 12.032 XM2V. PS1 0.000 RXAK.PS1 15.927 CIRN. PS1 0.568 DSIG.PS1 0.463 1VBAC.PS1 58.451 SBFA.PS1 2.884 SBFA.SIG 59.391 SBFA.FIL 48.064 SIGM. PS1 1.489 TRAT.SIG 73701.000 CRNI.PS1 92.843 TAV. PS1 3.000 BUSP.PS1 2.158 CCLC. PS1 0.661 SF6P. PS1 60.152 EXCU. PS1 1.005 FPGF. PS1 0.000 X~IV. PS1 -12.219 RXFR.PS1 0.000 SHCU. PS1 0.390 CIRF. PS1 0.086 FBAC. PS1 2306.061 SFNA.PS1 56.047 SFNA.SIG 5.008 SFNA.FIL 54.460 SIBF. PS1 48.005 SIBF. SIG 0.053 TRAT. FIL 460.651 CRFI.PS1 94.990 FICU. PS1 3.000 RSXS.PS1 -999.250 RSCS.PSi 133.991 2.762 1.000 200 923 0 000 40 696 0 574 3038 470 46 846 1.339 48.847 425.184 22.376 1.485 199.087 2.554 8878.000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE · 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAIVE : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUFk4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Ta~"Verification Listing Schlumberger Alaska Computing Center 15~0CT-19~9~16 : 2 6 PAGE: 23 RST 10627.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 9248.5 4 -JUN~98 8C0- 609 1609 4-JUN-98 10631.0 10610.0 9300.0 10610.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY RST RESEVOIR SATURATION $ TOOL NUMBER CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 3. 750 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) : SEA WATER 8.34 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): LIS Ta~-e ~Veri fi ca tion Lis ting Schlumberger Alaska Computing Center 15-0CT-19~16:26 PAGE: 24 REMARKS: TIED IN TO BHC SONIC LOG, 09-01-86 RST-A RAN IN SIGMA MODE TOOLS RAN WITH COILED TUBING THIS FILE CONTAINS THE RAW RST SIGM-MODE DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 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 ArUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 6 1 1 4 68 0000000000 CS PS2 F/HR O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB O0 000 O0 0 6 1 1 4 68 0000000000 NPHV PS2 V O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PS2 V O0 000 O0 0 6 1 1 4 68 0000000000 NSCE PS2 V O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS2 O0 000 O0 0 6 1 1 . 4 68 0000000000 NSCR PS2 O0 000 O0 0 6 1 1 4 68 0000000000 AQTM PS2 S O0 000 O0 0 6 i 1 4 68 0000000000 CHV PS2 V O0 000 O0 0 6 1 1 4 68 0000000000 CPSV PS2 V O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PS2 V O0 000 O0 0 6 1 1 4 68 0000000000 CM2V PS2 V O0 000 O0 0 6 1 1 4 68 0000000000 LIS Ta~e~'Verification Listing Schlumberger Alaska Computing Center 15-OCT-19~8"Ji6:26 PAGE: 25 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUBiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RCFR PS2 RCLC PS2 RCRC PS2 RCAK PS2 RTDF PS2 FPHV PS2 V FPDE PS2 V FSCE PS2 V FSCR PS2 AQTF PS2 S SF6P PS2 PSIG HVPV PS2 V BMCU PS2 UA GDCU PS2 MA EXCU PS2 UA NBEF PS2 UA FBEF PS2 UA NPGF PS2 FPGF PS2 BSTR PS2 BSPR PS2 MARC PS2 XHV PS2 V XPSV PS2 V XP2V PS2 V X~2V PS2 V RXFR PS2 RXLC PS2 RXRC PS2 RXAK PS2 SHCU PS2 MA BSAL PS2 PPK BSAL SIG PPK CIRN PS2 CIRF PS2 CIRN FIL CIRF FIL DSIG PS2 CU FBAC PS2 CPS IRAT PS2 IRAT FIL NBAC PS2 CPS SFNA PS2 CU SFFA PS2 CU SBNA PS2 CU SBFA PS2 CU SFNA SIG CU SFFA SIG CU SBNA SIG CU SBFA SIG CU SFNA FIL CU O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Ta~-'e-J%Zerification Listing Schlumberger Alaska Computing Center 15-0CT-19'9~o~16 : 26 PAGE: 26 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELE~f CODE (HEX) SFFA FIL CU O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU O0 000 O0 0 6 1 1 4 68 0000000000 SIBF PS2 CU O0 000 O0 0 6 1 1 4 68 0000000000 SFNC PS2 CU O0 000 O0 0 6 1 1 4 68 0000000000 SFFC PS2 CU O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU O0 000 O0 0 6 1 1 4 68 0000000000 SIBF SIG CU O0 000 O0 0 6 1 1 4 68 0000000000 SIGM SIG CU O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT SIG O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI O0 000 O0 0 6 1 1 4 68 0000000000 RDIX PS2 O0 000 O0 0 6 1 1 4 68 0000000000 CRNI PS2 KHZ O0 000 O0 0 6 1 1 4 68 0000000000 CRFI PS2 KHZ O0 000 O0 0 6 1 1 4 68 0000000000 CTM PS2 DEGC O0 000 O0 0 6 1 1 4 68 0000000000 XTM PS2 DEGC O0 000 O0 0 6 1 1 4 68 0000000000 TAV PS2 KV O0 000 O0 0 6 1 1 4 68 0000000000 FICU PS2 AMP O0 000 O0 0 6 1 1 4 68 0000000000 CACU PS2 AMP O0 000 O0 0 6 1 1 4 68 0000000000 BUST PS2 O0 000 O0 0 6 1 1 4 68 0000000000 BUSP PS2 O0 000 O0 0 6 1 1 4 68 0000000000 RSXS PS2 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU O0 000 O0 0 6 1 1 4 68 0000000000 TPHI SIG PU O0 000 O0 0 6 1 1 4 68 0000000000 CCLC PS2 V O0 000 O0 0 6 1 1 4 68 0000000000 RSCS PS2 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS2 AQTM. PS2 CM2 V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 BSTR. PS2 XP5 V. PS2 RXLC. PS2 BSAL. PS2 CIRN. FIL IRAT. PS2 SFFA. PS2 SFFA. SIG SFFA. FIL SFNC. PS2 10627 000 1574 250 0 441 -12 191 0 000 2 063 160 645 28 098 32.988 5.040 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 CS.PS2 1790.154 TENS.PS2 23.000 NPHV. PS2 NSCE. PS2 2.580 CRRA.PS2 2.141 NSCR.PS2 CHV. PS2 201.823 CPSV. PS2 5.060 CP2V. PS2 RCFR.PS2 0.000 RCLC. PS2 0.000 RCRC. PS2 RTDF. PS2 0.000 FPHV. PS2 1520.997 FPDE. PS2 FSCR.PS2 0.166 AQTF. PS2 0.441 SF6P. PS2 BMCU. PS2 30.761 GDCU. PS2 60.012 EXCU. PS2 FBEF. PS2 60.166 NPGF. PS2 0.990 FPGF. PS2 BSPR.PS2 1.147 MARC.PS2 0.000 XHV. PS2 XP2V. PS2 12.012 3242V. PS2 -12.211 R3fFR.PS2 RXRC. PS2 0.000 RXAK. PS2 0.000 SHCU. PS2 BSAL.SIG -999.250 CIRN. PS2 -999.250 CIRF. PS2 CIRF.FIL -999.250 DSIG.PS2 -999.250 FBAC. PS2 IRAT. FIL -999.250 NBAC.PS2 -999.250 SFNA.PS2 SBNA.PS2 -999.250 SBFA.PS2 -999.250 SFNA.SIG SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PS2 SFFC. PS2 -999.250 SIGM. PS2 -999.250 SIBF. SIG 1586.915 -0.069 12.217 0.000 1509.248 136.769 3.551 0.996 200.370 0.000 24.715 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Ta~=Verification Listing Schlumberger Alaska Computing Center 15_OCT-19'~5~J--'i6:26 PAGE: 27 SIGM. SIG -999.250 TRAT. PS2 GR.PS2 262.444 RDIX. PS2 CTM. PS2 98.633 XTM. PS2 CACU. PS2 2.583 BUST. PS2 TPHI.PS2 -999.250 TPHI. SIG DEPT. 9248.000 CS.PS2 NPDE. PS2 1569.368 NSCE. PS2 AQTM. PS2 1.102 CHV. PS2 CM2V. PS2 -12.182 RCFR.PS2 RCAK. PS2 0.000 RTDF. PS2 FSCE.PS2 1.871 FSCR.PS2 HVPV. PS2 161.691 BMCU. PS2 NBEF. PS2 32.997 FBEF. PS2 BSTR.PS2 57.378 BSPR.PS2 XPSV. PS2 5.045 XP2V. PS2 RXLC. PS2 0.000 RXRC. PS2 BSAL.PS2 530.193 BSAL.SIG CIRN. FIL 0.484 CIRF. FIL IRAT. PS2 0.417 IRAT. FIL SFFA.PS2 44.182 SBNA.PS2 SFFA.SIG 1.320 SBNA. SIG SFFA.FIL 44.019 SBNA.FIL SFNC. PS2 44.477 SFFC. PS2 SIGM. SIG 1.021 TRAT. PS2 GR.PS2 23.891 RDIX. PS2 CTM. PS2 89.844 XTM. PS2 CACU. PS2 2.597 BUST. PS2 TPHI.PS2 52.783 TPHI.SIG -999.250 TRAT. SIG 91414.000 CRNI.PS2 98.633 TAV. PS2 3.000 BUSP.PS2 -999.250 CCLC.PS2 1798.617 2.440 201.823 0.000 0.000 -0.144 35.888 75.546 1.316 12.037 0 000 12 394 0 779 0 418 54 002 3 784 57 285 43. 633 1.488 132791.000 89.809 3.000 1.732 TENS. PS2 CRRA. PS2 CP5V. PS2 RCLC.PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 XM2 V. PS2 RXAK. PS2 CIRN. PS2 DSIG. PS2 NBAC. PS2 SBFA. PS2 SBFA. SIG SBFA. FIL SIGM. PS2 TRAT. SIG CRNI. PS2 TA V. PS2 BUSP. PS2 CCLC. PS2 -999.250 442.415 95.031 3.000 0.029 45.000 2.289 5.050 0.000 1513.673 1.102 60.035 0.995 0.000 -12.215 0.000 0.482 0.208 2372.156 49.896 4.028 51.519 43.631 0.043 442.860 95.001 3.000 -999.250 TRAT.FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS.PS2 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P.PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA. PS2 SFNA. SIG SFNA. FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS. PS2 RSCS.PS2 -999.250 206.614 2.500 8878.000 8463.000 1573.488 -0.416 12.187 0.000 1500.741 133. 680 2. 649 O. 996 200. 785 0.000 26.364 0.778 3090.727 43.898 1.355 43.497 321.646 13.114 1.488 193.434 2.566 8878.OOO 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Ta~ Verification Listing Schlumberger Alaska Computing Center 15-0CT-19~i6:26 PAGE: 28 FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUM~L~RY VENDOR TOOL CODE START DEPTH RST 10626.0 $ LOG HEADER DATA STOP DEPTH 9267.0 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 RST RESEVOIR SATURATION $ 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): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 4-JUN-98 8C0-609 1609 10631.0 10610.0 9300.0 10610.0 1800.0 NO TOOL NUMBER CGRS-A RST-A 3. 750 SEA WATER 8.34 THERMAL SANDSTONE 2.65 4 -JUN-98 LIS TapS'verification Listing Schlumberger Alaska Computing Center PAGE: 29 TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: TIED IN TO BHC SONIC LOG, 09-01-86 RST-A RAN IN SIGMA MODE TOOLS RAN WITH COILED TUBING THIS FILE CONTAINS THE RAW RST SIGM-MODE DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE ~LUE .............................. 1 66 0 2 66 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 .?T 11 66 2 12 68 13 66 14 65 15 66 16 66 1 0 66 I ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT O0 000 O0 0 7 1 1 4 68 0000000000 CS PS3 F/HR O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB O0 000 O0 0 7 1 1 4 68 0000000000 NPHVPS3 V O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tap~-~Verification Listing Schlumberger Alaska Computing Center 15-0CT-19-'~o~16: 26 PAGE: 30 NAME SERV UNIT SERVICE API API A_PI API FILE NUM~ NU?4B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFZB SAMP ELEM CODE (HEX) NPDE PS3 V NSCE PS3 V CRRA PS3 NSCR PS3 AQTM PS3 S CHV PS3 V CP5V PS3 V CP2V PS3 V CM2V PS3 V RCFR PS3 RCLC PS3 RCRC PS3 RCAK PS3 RTDF PS3 FPHV PS3 V FPDE PS3 V FSCE PS3 V FSCR PS3 ' AQTF PS3 S SF6P PS3 PSIG HVPV PS3 V BMCU PS3 UA GDCU PS3 MA EXCU PS3 UA NBEF PS3 UA FBEF PS3 UA NPGF PS3 FPGF PS3 BSTR PS3 BSPR PS3 MARC PS3 XHV PS3 V XP5V PS3 V XP2V PS3 V XM2V PS3 V RXFR PS3 RXLC PS3 RXRC PS3 RXAK PS3 SHCU PS3 MA BSAL PS3 PPK BSAL SIG PPK CIRN PS3 CIRF PS3 CIRN FIL CIRF FIL DSIG PS3 CU FBAC PS3 CPS IRAT PS3 IRAT FIL NBAC PS3 CPS O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 I 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Table'Verification Listing Schlumberger Alaska Computing Center 15-0CT-19~o~/16:26 PAGE: 31 NAME SERVUNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELE~ CODE (HEX) SFNA PS3 CU O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS3 CU O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS3 CU O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS3 CU O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU O0 000 O0 0 7 1 1 4 68 0000000000 SFNA FIL CU O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU O0 000 O0 0 7 1 1 4 68 0000000000 SBNA FIL CU O0 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS3 CU O0 000 O0 0 7 1 1 4 68 0000000000 SFNC PS3 CU O0 000 O0 0 7 1 1 4 68 0000000000 SFFC PS3 CU O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI O0 000 O0 0 7 1 1 4 68 0000000000 RDIX PS3 O0 000 O0 0 7 1 1 4 68 0000000000 CRNI PS3 KHZ O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS3 K~Z O0 000 O0 0 7 1 1 4 68 0000000000 CTM PS3 DEGC O0 000 O0 0 7 1 1 4 68 0000000000 XTM PS3 DEGC O0 000 O0 0 7 1 1 4 68 0000000000 TAV PS3 KV O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS3 AMP O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS3 AMP O0 000 O0 0 7 1 1 4 68 0000000000 BUST PS3 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS3 O0 000 O0 0 7 1 t 4 68 0000000000 RSXS PS3 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS3 V O0 000 O0 0 7 1 1 4 68 0000000000 RSCS PS3 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 10626.000 CS.PS3 613.079 TENS.PS3 46.000 NPHV. PS3 NPDE. PS3 1572.229 NSCE. PS3 2.551 CR3A~.PS3 2.185 NSCR.PS3 AQTM. PS3 0.661 CHV. PS3 201.581 CPSV. PS3 5.069 CP2V. PS3 CM2V. PS3 -12.172 RCFR.PS3 0.000 RCLC. PS3 0.000 RCRC. PS3 RCAK. PS3 0.000 RTDF. PS3 0.000 FPHV. PS3 1520.997 FPDE. PS3 FSCE. PS3 2.065 FSCR.PS3 0.158 AQTF. PS3 0.661 SF6P. PS3 HVPV. PS3 161.865 BMCU. PS3 31.640 GDCU. PS3 59.356 EXCU. PS3 NBEF. PS3 28.693 FBEF. PS3 62.699 NPGF. PS3 1.000 FPGF. PS3 BSTR.PS3 33.483 BSPR.PS3 1.137 MARC. PS3 0.000 Xhq;.PS3 1589.357 -0.055 12.231 0.000 1505.586 137.025 3.156 1.002 200.854 LIS Ta~=~"Verification Listing Schlumberger Alaska Computing Center 15-OCT-19~-W'~16 : 26 PAGE: 32 XP5 V. PS3 RXLC. PS3 BSAL. PS3 CIRN. FIL IRAT. PS3 SFFA. PS3 SFFA. SIG SFFA. FIL SFNC. PS3 SIGM. SIG GR. PS3 CTM. PS3 CACU. PS3 TPHI. PS3 DEPT. NPDE. PS3 AQTM. PS3 CM2 V. PS3 RCAK. PS3 FSCE. PS3 HVPV. PS3 NBEF. PS3 BSTR . PS3 XP5 V. PS3 RXLC. PS3 BSAL. PS3 CIRN. FIL IRAT. PS3 SFFA. PS3 SFFA. SIG SFFA. FIL SFNC. PS3 SIGM. SIG GR. PS3 CTM. PS3 CACU. PS3 TPHI. PS3 5. 040 O. 000 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 153 619 99 121 2 598 -999 250 9266. 500 1569 940 1 102 -12 221 2 000 1 871 161 637 32 725 53 661 5. 042 0.000 543. 556 O. 423 0.436 45. 440 1. 517 45.398 47. 057 1. 195 30. 519 89. 844 2. 604 52.382 XP2V. PS3 12.012 XM2V. PS3 RXRC. PS3 0.000 RXAK. PS3 BSAL.SIG -999.250 CIRN. PS3 CIRF.FIL -999.250 DSIG.PS3 IRAT. FIL -999.250 NBAC.PS3 SBNA.PS3 -999.250 SBFA.PS3 SBNA.SIG -999.250 SBFA.SIG SBNA.FIL -999.250 SBFA.FIL SFFC. PS3 -999.250 SIGM. PS3 TRAT. PS3 -999.250 TRAT. SIG RDIX. PS3 150793.000 CRNI.PS3 XTM. PS3 97.168 TAV. PS3 BUST. PS3 3.000 BUSP.PS3 TPHI.SIG -999.250 CCLC. PS3 CS.PS3 1842.800 TENS.PS3 NSCE.PS3 2.473 CRRA.PS3 CHV. PS3 201.823 CPSV. PS3 RCFR.PS3 0.000 RCLC. PS3 RTDF. PS3 0.000 FPHV. PS3 FSCR.PS3 -0.244 AQTF. PS3 BMCU. PS3 35.761 GDCU. PS3 FBEF. PS3 75.936 NPGF. PS3 BSPR.PS3 1.116 MARC. PS3 XP2V. PS3 12.035 XM2V. PS3 RXRC. PS3 0.000 RXAK. PS3 BSAL.SIG 13.148 CIRN. PS3 CIRF. FIL 0.663 DSIG.PS3 IRAT. FIL 0.436 ArBAC.PS3 SBNA.PS3 61.793 SBFA.PS3 SBNA.SIG 3.816 SBFA.SIG SBNA.FIL 59.155 SBFA.FIL SFFC. PS3 44.969 SIGM. PS3 TRAT. PS3 1.456 TRAT. SIG RDIX. PS3 195008.000 CRNI.PS3 XTM. PS3 90.332 TAV. PS3 BUST. PS3 3.000 BUSP. PS3 TPHI.SIG 1.878 CCLC.PS3 -12.191 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 449.416 95.031 3.000 0.019 36.000 2.320 5.040 0.000 1516.114 1.102 60.077 1.001 0.000 -12.211 1.000 0.424 0.850 2605.169 56. 680 3. 973 54. 265 44.941 0.046 443.964 95.003 3.000 -999.250 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA. PS3 SFNA. SIG SFNA. FIL SIBF. PS3 SIBF. SIG TRAT. FIL CRFI.PS3 FICU. PS3 RSXS.PS3 RSCS.PS3 NPHV. PS3 NSCR.PS3 CP2V. PS3 RCRC. PS3 FPDE.PS3 SF6P. PS3 EXCU. PS3 FPGF. PS3 XI-IV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA. PS3 SFNA. SIG SFNA. FIL SIBF.PS3 SIBF. SIG TRAT. FIL CRFI.PS3 FICU. PS3 RSXS.PS3 RSCS.PS3 0.000 24.065 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 205.668 2.515 8878.000 8463.000 1577.150 0.165 12.187 0.000 1502.725 134.278 2.604 1.004 200.903 0.000 36.444 0.669 3096.577 47.294 1.574 46.183 336.105 14.545 1.461 191.330 2.571 8878.000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS TapE" Verification Listing Schlumberger Alaska Computing Center 15-0CT-1~9~' 16:26 PAGE: 33 **** TAPE TRAILER **** SERVICE NAFiE : EDIT DATE : 98/10/15 ORIGIN : FLIC TAPE NAM~ : 98516 CONTINUATION # : 1 PREVIOUS TAPE : COMFIENT : ARCO ALASKA, INC., DS 7-23A, PRUDHOE BAY, # 50-029-21635-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/10/15 ORIGIN : FLIC REEL NAME : 98516 CONTINUATION # PREVIOUS REEL : COFk4F2TT : ARCO ALASKA, INC., DS 7-23A, PRUDHOE BAY, # 50-029-21635-01 * ALASKA COMPUTING CENTER * * ....... SCHLUlVI~ERGER ....... * ****************************** COMPANY NAME : ARCO ALASKA INC. WELL NAME : D.S. 7-23A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292163501 REFERENCE NO : 98516 Sperry-Sun Drilling Services LIS Scan Utility Wed Sep 02 10:24:15 1998 Reel Header Service name ............. LISTPE Date ..................... 98/09/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/09/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: DS 07-23A 500292163501 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 02-SEP-98 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MW-80236 AK-MW-80236 AK-MW-80236 D. LONG K. ALLEN K. ALLEN A. BASS A. BASS A. BASS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: MWD RUN 4 MWD RUN 5 MWD RUN 6 AK-MW-80236 AK-MW-80236 AK-MW-80236 K. ALLEN B. JANN B. JA_HN A. BASS A. BASS A. BASS MWD RUN 7 AK-MW-80236 MWD RUN 8 AK-MW-80236 LOGGING ENGINEER: B. JAHN B. JA_HN OPERATOR WITNESS: A. BASS A. BASS SURFACE LOCATION SECTION: 33 TOWNSHIP: liN RANGE: 14E FNL: 1986 FSL: FEL: 219 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 57.00 DERRICK FLOOR: 57.00 GROUND LEVEL: .00 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 5.500 27.0 4.500 9501.0 5.500 9625.0 3.750 10664.0 REMARKS: B. JAHN A. BAS S 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL MWD RUNS ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILATION TYPE DETECTORS (SGRD). 3. GAMMA RAY DATA IS LOGGED BEHIND CASING UNTIL THE WINDOW AT 9858.50'MD, 8593.5'SSTVD. 4. SROP DATA IS MEASURED AFTER DRILLING (MAD) FOR THE FOLLOWING DEPTH INTERVALS AND IT IS SMOOTHED TOOL SPEED WHEN NOT DRILLING (SRAT) : 9675.50'MD, 8443.00'SSTVD - 9681.50'MD, 8448.00'SSTVD. 9776.00'MD, 8531.00'SSTVD - 9850.50'MD, 8587.00'SSTVD. 5. SGRD DATA IS MEASURED AFTER DRILLING (MAD) FOR THE FOLLOWING DEPTH INTERVALS: 9639.50'MD, 8412.00'SSTVD - 9651.00'MD, 8422.00'SSTVD. 9747.00'MD, 8505.00'SSTVD - 9821.00'MD, 8565.00'SSTVD. 6. MWD RUNS 1 THROUGH 9 REPRESENT WELL DS 07-23A, API# 50-029-21635-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10663'MD, 8992'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9466.5 10632.0 ROP 9565.5 10658.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9466 5 9570 9602 9648 9651 9659 9661 9662 9664 9665 9667 9668 9680 9696 9699 9702 9728 9735 9736 9749 9753 9766 778 781 793 794 797 804 805 808 810 813 838 850 658 9 9 9 9 9 9 9 9 9 9 9 9 10 0 5 5 5 5 0 5 0 5 0 .5 .0 0 5 0 5 0 5 5 0 0 5 0 0 5 0 0 5 0 0 5 5 5 5 GR 9475 9579 9608 9652 9654 9660 9662 9664 9666 9667 9669 9670 9684 9699 9702 9704 9730 9736 9739 9753 9756 9769 9781 9783 9794 9797 9798 9806 9807 9809 9811 9815 9839 9854 10662 .5 .0 .0 .0 .5 .5 .5 .0 .5 .5 .0 .5 .0 .0 .0 0 5 5 5 0 5 0 5 0 5 5 5 .0 0 5 5 5 5 5 5 EQUIVALENT UNSHIFTED DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP 1 9451.0 2 9665.0 3 9851.0 4 9856.0 5 9865.0 6 10025.0 7 10150.0 8 10165.0 9 10324.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 9665.0 9851.0 9856.0 9865.0 10025.0 10150.0 10165.0 10324.0 10663.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9466.5 10658.5 10062.5 2385 9466.5 ROP 3 1134 57.4417 2168 9565.5 GR 20.92 224.13 44.4006 2332 9466.5 Last Reading 10658.5 10658.5 10632 First Reading For Entire File .......... 9466.5 Last Reading For Entire File ........... 10658.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comraent Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9475.5 9639.0 ROP 9574.5 9664.0 $ LOG HEADER DATA DATE LOGGED: 19-MAY-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MSC 1.32 SPC 5.74 PCD 3.00e MEMORY 9665.0 9451.0 9665.0 TOOL NUMBER NGP SPC 65 3.800 3.8 SEA-WATER .00 .0 .0 MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 0 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 84.4 First Name Min Max Mean Nsam Reading DEPT 9475.5 9664 9569.75 378 9475.5 GR 9.79 77.28 59.4631 328 9475.5 ROP 12.3 73.32 41.2492 180 9574.5 Last Reading 9664 9639 9664 First Reading For Entire File .......... 9475.5 Last Reading For Entire File ........... 9664 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9651.5 9746.5 ROP 9682.0 9775.5 $ LOG HEADER DATA DATE LOGGED: 20-MAY-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MSC 1.32 SPC 5.74 PCD 3.00e MEMORY 9851.0 9665.0 9851.0 TOOL NUMBER NGP SPC 65 3.800 3.8 SEA-WATER .00 .0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH]VfM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 0 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 84.4 First Name Min Max Mean Nsam Reading DEPT 9651.5 9775.5 9713.5 249 9651.5 GR 30.72 172.41 62.3758 191 9651.5 ROP 14.73 177.66 37.6176 188 9682 Last Reading 9775.5 9746.5 9775.5 First Reading For Entire File .......... 9651.5 Last Reading For Entire File ........... 9775.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMNARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9821.5 9832.5 ROP 9851.0 9854.0 $ LOG HEADER DATA DATE LOGGED: 21-MAY-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MSC 1.32 SPC 5.74 PCD 3.00e MEMORY 9856.0 9851.0 9856.0 TOOL NUMBER NGP SPC 63 3.800 3.8 SEA-WATER .00 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 .0 0 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 82.0 First Name Min Max Mean Nsam Reading DEPT 9821.5 9854 9837.75 66 9821.5 GR 23.37 25.3 24.3522 23 9821.5 ROP 1 10.19 4.12571 7 9851 Last Reading 9854 9832.5 9854 First Reading For Entire File .......... 9821.5 Last Reading For Entire File ........... 9854 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9832.5 9842.5 ROP 9859.0 9866.0 $ LOG HEADER DATA DATE LOGGED: 22-MAY-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH {FT) : BOREHOLE CONDITIONS MUD TYPE: MSC 1.32 SPC 5.74 PCD 3.00e MEMORY 9865.0 9856.0 9865.0 TOOL NUMBER NGP SPC 65 3.800 3.8 SEA-WATER MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 .00 .0 .0 0 .0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 84.4 First Name Min Max Mean Nsam Reading DEPT 9832.5 9866 9849.25 68 9832.5 GR 22.62 31.77 25.5319 21 9832.5 ROP 4.34 44.02 16.9733 15 9859 Last Reading 9866 9842.5 9866 First Reading For Entire File .......... 9832.5 Last Reading For Entire File ........... 9866 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Con~nent Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9838.5 9997.0 ROP 9867.5 10024.5 $ LOG HEADER DATA DATE LOGGED: 23-MAY-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 51.1 MAXIMUM ANGLE: 64.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MSC 1.32 SPC 5.74 PCD 3.00e MEMORY 10025.0 9865.0 10025.0 TOOL NUMBER NGP SPC 63 3.750 3.8 MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ............. ~ ........ 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 FLO-PRO 8.80 56.0 9.0 7.4 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 65.5 First Name Min Max Mean Nsam Reading DEPT 9838.5 10024.5 9931.5 373 9838.5 GR 23.46 166 38.2773 318 9838.5 ROP 19.48 112.3 45.259 315 9867.5 Last Reading 10024.5 9997 10024.5 First Reading For Entire File .......... 9838.5 Last Reading For Entire File ........... 10024.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9645.5 10122.5 ROP 9675.0 10151.0 $ LOG HEADER DATA DATE LOGGED: 23-MAY-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 60.3 MAXIMUM ANGLE: 64.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMYkA PROBE $ BOREHOLE ~qD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : MSC 1.32 SPC 5.74 PCD 3.00e MEMORY 10150.0 10025.0 10150.0 TOOL NUMBER NGP SPC 65 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 FLO-PRO 8.80 56.0 9.0 7.4 .000 .000 · 000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 API 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 68.0 First Name Min Max Mean Nsam Reading DEPT 9645.5 10151 9898.25 1012 9645.5 GR 21.57 176.04 45.7609 319 9645.5 ROP 2.4 6746.95 161.558 317 9675 Last Reading 10151 10122.5 10151 First Reading For Entire File .......... 9645.5 Last Reading For Entire File ........... 10151 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9638.5 10130.5 ROP 9675.5 10165.0 $ LOG HEADER DATA DATE LOGGED: 23-MAY-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : MSC 1.32 SPC 5.74 PCD 3.00e MEMORY 10165.0 10150.0 10165.0 TOOL NUMBER NGP SPC 65 3.750 3.8 Dat BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: a Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 FLO-PRO 8.80 56.0 9.0 7.4 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 API 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 68.0 First Name Min Max Mean Nsam Reading DEPT 9638.5 10165 9901.75 1054 9638.5 GR 29.1 128 59.1395 81 9638.5 ROP 7.72 360 65.9406 77 9675.5 Last Reading 10165 10130.5 10165 First Reading For Entire File .......... 9638.5 Last Reading For Entire File ........... 10165 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10129.5 10296.5 ROP 10158.5 10324.5 $ LOG HEADER DATA DATE LOGGED: 24-MAY-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 60.9 MAXIMUM ANGLE: 61.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): MSC 1.32 SPC 5.74 PCD 3.00e MEMORY 10324.0 10165.0 10324.0 TOOL NUMBER NGP SPC 65 3.750 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9653.0 10636.0 ROP 9682.0 10662.5 $ LOG HEADER DATA DATE LOGGED: 25-MAY-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 59.5 MAXIMUM ANGLE: 59.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA MSC 1.32 SPC 5.74 PCD 3.00e MEMORY 10663.0 10324.0 10663.0 TOOL NUMBER NGP SPC 65 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX~DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.750 3.8 FLO-PRO 8.80 56.O 8.9 6.3 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 API 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 70.3 First Name Min Max Mean Nsam Reading DEPT 9653 10662.5 10157.8 2020 9653 GR 20.92 168.92 36.6527 709 9653 ROP 3.14 123.52 76.1333 703 9682 Last Reading 10662.5 10636 10662.5 First Reading For Entire File .......... 9653 Last Reading For Entire File ........... 10662.5