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197-101
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They are available in the original file and viewable by direct inspection. /~'~7""/OI File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original'- Pages: Other - Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type .OVERSIZED [] .Logs of various kinds Other COMMENTS: Scanned b~~/'~-~ M~red- D'a retha TO RE-SCAN Notes: Naa'mn Lowell Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /si ~~,,~. STATE OF ALASKA ~~ ~.., ~ ~~~ ALASKA OIL AND GAS CONSERVATION CONIIeRSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ; :_ ~e ~ Q 2007 1a. WeII Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended 2oAAC 2s.,os 2oAAC 2s.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b. 1Ne~lkGlass ~ " .OnS, OCC1fIliSiE3 ®Developme~t; ,Eycploratory ^ Service ~~Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 11/ 2007 12. Permit to Drill Number 197-101 306-283 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 08/05/1997 13. API Number 50-029-20153-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 08/13/1997 14. Well Name and Number: PBU 02-09B 4064 FSL, 4308 FEL, SEC. 36, T11 N, R14E, UM Top of Productive Horizon: 1516' FSL, 1498' FEL, SEC. 25, T11 N, R14E, UM 8. KB (ft above MSL): 58' Ground (ft MSL): 30.3' 15. Field /Pool(s): r Prudhoe Bay Field / Prudhoe Bay Total Depth: 2825' FSL, 747' FEL, SEC. 25, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 10690 8854 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 687729 y- 5949988 Zone- ASP4 10. Total Depth (MD+TVD) 11680 8814 ~ 16. Property Designation: ADL 028308 TPI: x- 690469 y- 5952790 Zone- ASP4 Total Depth: x- 691186 y- 5954117 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit ele ronic and rioted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 100' S dace 100' 32" 300 sx Permafro t II 13-3/8" 72# MN-80 Surface 2130' Surface 2130' 17-1/2" 661 sx Class 'G' 5300 sx PF II 9-5/8" 47# L-80/500-95/N-80 Surface 9021' Surface 7915' 12-1/4" 750 sx Class 'G' 7" 29# L-80 8726' 9 96' 7673' 8406' -1/2" 1090 sx Class'G' 2-7/8" 6.4# L-80 8724' 11680' 7671' 8814' 3-3/4" 108 sx LARC 23. Open to production or inject ion? ^ Yes ®No 24. TueING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 5-1/2", 17#, L-80 5828' - 8639' 8627' MD TVD MD TVD 4-1/2", 12.6#, N-80 8639' - 8763' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED ~~ ~~~ ~~~ ~ ~d~~ 8649' P&A w/ 26 BBIs Class'G' 4668' Set EZSV 4665' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac uired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results p~ AAG-/2500 None I~...-`~.~~ <~i<~E ~~~~ ~~ ,~~~~~ ;~ ~ 1000 ~ : ~~ ~ll~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE / 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS A KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Zone 4A 9678' 8476' None Zone 3 9772' 8549' Zone 2C 9860' 8619' Zone 2B 9911' 8660' 22TS 10015' 8743' Zone 2A 10057' 8775' Zone 1 B 10136' 8825' Zone 1A 10237' 8860' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~Z ~Zb~ 7 Signed Terrie Hubble Title Drilling Technologist Date v PBU 02-09B 197-101 306-283 Prepared ByName/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Travis Peltier, 564-4511 Permit No. / A royal No. INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • Well History • Well Date Summary 02-096 9/8/2007 T/1/O=SSV/700/700, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre rig. **3 stuck LDS (flagged).** PPPOT-T: Stung into test port with high pressure bleeder tool to to check void pressure (200 psi), bled to 0 psi (gas). Function LDS, 2 pins stuck, all others moved freely with no sign of bent or broken pins. Pumped through void until clean fluid was achieved. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 0 psi in second 15 min (PASS). PPPOT-IC: Stung into test port with high pressure bleeder tool to to check void pressure (500 psi), bled to 0 psi (gas/fluid). Function LDS, 1 pin stuck, all others moved freely with no sign of bent or broken pins. Pumped through void until clean fluid was achieved. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). 02-096 9/9/2007 T/I/O = SSV/760/720. Temp. = SI. Bleed IAP & OAP to 0 psi (free stuck LDS). IA FL @ 75'. Bled IAP to 150 psi in 4 hrs, 45 min (gas & 10 bbls of crude). OAP decreased to 380 psi. SI, monitored for 30 min. IAP increased to 160 psi. OA FL near surface. Bled OAP to 10 psi in 1 hr, 25 min (gas & 12 bbls of crude). SI, monitored for 30 min. OAP increased to 20 psi. Final WHPs =SSV/160/20. 02-096 10/25/2007 WELL S/I UPON ARRIVAL (pre p&a / sdtrk). DRIFT W/ 2.25" CENT. & S. BAILER TO 10,211' SLM, STOP DUE TO DEV. (75 DEG)...S. BAILER EMPTY. WELL LEFT S/I. 02-096 11/9/2007 MIRU CTU #9 w/ 1.75" Coil. Broadcasting. MU 2" BD nozzle. PT all surface equipment. Continued on 11/10/07 WSR. 02-09B 11/10/2007 Continued from 11/10/07 WSR. Coil 9 w/ 1.75" CT, broadcasting. Kill well w/ 10 bbl meth/wtr, 288 bbl KCL. Cap with 150 bbls diesel. Tag CIBP. Reset depth to CIBP depth (-10' correction). Cool perfs w/158 bbls KCL . Park/flag CT @ 8714', 10' above 2 7/8" liner top. Pump 26 bbls class G cement. Get bump @ 8.5 bbl out nozzle. Take returns, qet 100' cement out, lay in cement to 8170', based on returns. Pull to safety @ 7552'. pressure well to 500 psi and hold for 60 min. Clean out to 8635'. Freeze protect with diesel on the way out of hole. AT surface trap 300psi on well. Aprox 3 bbls behind pipe.Preform weekly BOP test. Job complete. 02-096 11/11/2007 T/I/O=SI/0/200. Trouble shoot stuck LDS, tea on tbg hd 1 ea on csg head. Tbg hgr & P/O void @ 0 psi. Function alt LDS on tbg &csg head all function properly. 02-09B 11/11/2007 WELL S/I ON ARRIVAL ***(pre side trk). TAG TOC ~ 8649' SLM W/ 2.25" CENT, S-BAILER. 1 CUP OF PLASTIC COATED TUBING RECOVERED. D10LRS MIT-T TO 2100psi IN PROGRESS. CONTINUED ON 11/12/07. 02-096 11/11/2007 T/I/0= 500/340/200 Temp=Sl ,MIT-T PASSED to 2100 psi.( Pre RWO) Pressured up Tbg with 1.9 bbls crude. Tbg lost 40 psi in 1st 15 min and 20 psi in 2nd 15 min for a total loss of 60 psi in 30 min test. Started bleeding back pressure *** Job continued on 11-12-07 WSR*** 02-09B 11/12/2007 Job continued from 11-11-07 WSR. _CMIT-IAxOA PASSED to 2000 psi.(Pre RWO) Pressured up IA/OA with 27.6 bbls crude. IA/OA lost 80/40 psi in 1st 15 min and IA/OA lost 40/20 psi in 2nd 15 min for a total loss of 120/60 psi in 30 min test. Bleed pressure back. Final WHPs 450/160/200. (IA/OA casing valves open to gauges at time of departure). 02-096 11/12/2007 T/I/0= 340/220/200. Temp= SI. Bleed WHP's to 0 psi (pre-RWO). No A/L line on well. Integral installed on IA & OA. Tubing FL near surface. IA FL @ 36'. OA FL @ 48'. Bled tubing pressure to slop trailer from 340 psi to 0 psi in 20 minutes (fluid to surface). Bled IAP from 220 psi to 160 psi in 1 hour (fluid to surface 123 gallons). During IA bleed OAP decreased 40 psi. Bled OAP from 160 psi to 50 psi in 2 hours (fluid to surface 292 gallons). During OA bleed IAP increased 20 psi. Bled IAP from 180 psi to 25 psi in 4 hours. During bleed OAP decreased 10 psi. Final WHPs= 0+/25/40. 02-09B 11/12/2007 CONTINUED FROM 11/11/07 (pre side track). LRS FINISHED UP MIT-T TO 2100psi PASSED. RDMO. WELL LEFT S/I ON DEPARTURE PAD OP NOTIFIED. • Well History L Well Date Summary 02-09B 11/13/2007 Set 5" FMC BPV 02-098 11/13/2007 T/I/O = 0+/50/50. Temp = SI. Bleed WHP (Pre RWO). IA and OA FLs near surface. Bled IAP to 0+ psi in 1 hr, 45 min (all gas). SI, monitored for 30 min. IAP increased to 10 psi. Re bleed IAP to 0+ psi in 45 min (all gas). SI, monitored for 30 min. IAP increased to 15 psi and would not bleed to 0 psi. Bled OAP to 0+ psi in 1 hr, 15 min (all gas) SI, monitored for 30 min. OAP increased to 5 psi. Final WHPs = 0+/15/5. 02-09B 11/13/2007 T/I/O=SSV/38/19. Temp=Sl. Bleed WHP's to 0 psi. (Pre-RWO). BPV in hole. No Scaffold on the wellhead. Bled OAP from 19 psi to 0 psi in 40 minutes. Bled IAP from 38 psi to 0 psi in 35 minutes. Monitor, OAP increased 2 psi in 1 hour. IAP increased 10 psi in 30 minutes. Bled IAP from 10 psi to 0 psi in 20 minutes. Bled OAP from 2 psi to 0 psi in 10 minutes. IAP increased to 10 psi during OA bleed. Bled IAP from 10 psi to 0 psi in 20 minutes. Monitor for 30 minutes. OAP remained @ 0 psi. IAP @ 0+. Final WHPs=SSV/0+/0. 02-096 11/13/2007 T/I/O =SSV/O+/0+. Temp SI. Monitor WHP (pre RWO). Master Valve Locked for Safe Out. Flowlines removed. WH removed. No scaffolding. 02-096 11/14/2007 T/I/O=SSV/5/4. Temp=S1. Monitor WHPs (pre-RWO). BPV in hole. Well house, scaffolding, and flowline removed. IA & OA have integrals installed. IAP decreased 5 psi, OAP increased 4 psi overnight. • BP EXPLORATION Page 1 of 19 ..Operations Surnrnary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/14/2007 22:00 - 00:00 2.00 MOB P PRE Start Moving Sub From Drill Site 14 to Drill Site 2 11/15/2007 00:00 - 15:00 15.00 RIGU P PRE Continue with Rig Move to Dr'sll Site 2 -Move Sub to DS 02 -Place Herculite and berming -Spot over well -Raise Derrick and pin -Raise Cattle chute -R/U Service Loop and Service lines -Bridle Down -Spot Pits ,Shop & Camp -Finish Rigging up intertconnects and equipment Accept Rig @ 15:00 Hrs 15:00 - 16:00 1.00 WHSUR P DECOMP Conduct Pre-spud meeting with Rig Crew -Take on Seawater 16:00 - 17:00 1.00 WHSUR P DECOMP Rig up to to test Tubing and IA -Rig up Secondary annulus valves 17:00 - 21:00 4.00 WHSUR P DECOMP PJSM with DSM and Rig Crews -R/U DSM Lubricator and test to 1000 psi against master valve -Master Valve leaking tested against Swab Valve -Good Test ', 21:00 - 23:30 2.50 WHSUR P DECOMP PJSM on test Tubing and IA -R/U and Test to to 2125 si on 5 1/2" tubin ~', -Test held for 30 minutes and charted, good test -R/U on IA and test to 2000 osi. 18.5 bbls to pressure up ~~ -OA tracked to 2000 si when testin IA -Test held for 30 minutes and charted, good test -R/D lines and blow down 23:30 - 00:00 0.50 WHSUR P DECOMP Rig Schlumberger slickline unit -PJSM with SWS personnel and NAD crew 11/16/2007 00:00 - 01:30 1.50 WHSUR N SFAL DECOMP Unable to Get Schlumberger slickline unit running -SWS mechanic repaired unit 01:30 - 03:30 2.00 WHSUR P DECOMP Hang sheaves and install Lubricator extension, Pump In Sub, Wireline BOP's, slickline Lubricator 03:30 - 04:30 1.00 WHSUR P DECOMP Pressure test lubricator to 1000 psi, good test -Rig up tools to run downhole 04:30 - 07:00 2.50 PULL P DECOMP RIH with slickline to Pull POGLM at 3944' -Unable to release POGLM, POH 07:00 - 08:30 1.50 PULL P DECOMP RIH to 3944' with 4.55" GR, POH 08:30 - 13:00 4.50 PULL P DECOMP RIH with PRT tool to pull POGLM -Parted Slick line 3928' -Tie Line together and Pull off of POGLM '~ 13:00 - 16:00 3.00 PULL N SFAL DECOMP Switch over to Braided Line ', -Test Lubricator to 1000 psi for 5 min, good test ', 16:00 - 22:00 6.00 PULL P DECOMP RIH and Latch on to POGLM, Jar and released POGLM -POH w POGLM to SSSV 2225', Unable to Pull through -Work on Pulling and Jaring POGLM up throug wi out success -PRT tool unlatched from POGLM POH with PRT to Check Tools 22:00 - 00:00 2.00 PULL P DECOMP Change over tools to 4.55 gauge ring -RIH to top of POGLM @ 2225' Printed: 12/20/2007 11:54:26 AM • • BP EXPLORATION Page 2 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/16/2007 22:00 - 00:00 2.00 PULL P DECOMP -POH with GR -Change over tools to push POGLM down out of SSSV 11/17/2007 00:00 - 03:00 3.00 PULL P DECOMP Finish Changing over tools to Push POGLM down out of SSSV -RIH and Push POGLM out of SSSV 03:00 - 05:00 2.OO) PULL P 05:00 - 08:00 3.00 WHSUR P 08:00 - 12:30 I 4.501 WHSUR I P 12:30 - 15:00 2.50 BOPSU P 15:00 - 17:00 2.00 BOPSU P 17:00 - 20:30 3.50 BOPSU N 20:30 - 22:00 1.50 BOPSU N 22:00 - 23:30 1.50 BOPSU P DECOMP Rig Down SWS slickline unit DECOMP Rig up to tree with circulation lines and displace diesel freeze protect first from the tubing (-50 bbls) and then from the IA (-100 bbls of diesel) with hot (110 degrees) seawater. 3 bpm / 500 psi Taking diesel returns to cuttings tank. Verify the well is dead. DECOMP D Rod BPV -Nipple Down Tree & Adaptor -Hanger Neck Welded -Unable to Seat Blanking plug, Brought out another one and Run in with 9 1/4 turns, Verified retrieval Tool - 8 1/4 Left Hand turns DECOMP Nipple up BOP stack and riser -Hook up Lines and turnbuckles DECOMP PJSM on Testing BOP's With NAD Rig Crews, NAD TP, BP WSL -Rig up to test BOP's, -Attemat to test. Unable to Pressure uo. -Pressure leaking throu h blankin lu SFAL DECOMP Trouble Shoot problem with the Blanking plug leaking -FMC Pulled Plug ,inspected and change out ball -Reinstall Blanking Plug SFAL DECOMP Mobilize DSM, Storm packer for tubing, and 2 7/8" PAC pipe DECOMP R/U Lubricator extension and DSM Lubricator -Test to 1000 psi for 5 min 23:30 - 00:00 0.50 BOPSU N SFAL 11/18/2007 00:00 - 00:30 0.50 BOPSU N SFAL 00:30 - 02:30 2.00 BOPSU N SFAL 02:30 - 03:30 1.00 BOPSU N SFAL 03:30 - 09:00 5.50 BOPSU P 09:00 - 11:00 ~ 2.00 ~ BOPSUF~ N ~ SFAL -R/D DSM Lubricator and Extension DECOMP Rig up to Run Storm packer into 5 1/2" tubing to test BOP's DECOMP R/U to run 2 7/8" PAC pipe below storm packer DECOMP P/U 38 joints of 2 7/8" PAC for weight under HES RTTS DECOMP Set RTTS 60' DECOMP Test BOPE to 250 psi low, 3500 psi high. -Test witness waived by ob o e wit AOGCC. - Test witnessed by WSL Dave Newlon and Joey LeBlanc, TP Bruce Simonson and Charlie Henley -Test 1 Blind Rams, Choke Manifold valves 1,2,3, HCR Kill -Test 2 ,Choke Manifold valves 4,5,6 -Test 3 ,Choke Manifold valves 7,8,9 -Test 4 ,Manual And Super Choke to 1000 Psi -Test 5 ,Choke Manifold valves 10,11 -Test 6 ,Choke Manifold valve 15 Install 5 1/2" Test Joint -Test 7 Annular to 250 low and 2500 psi high Test On Upper Rams Failed DECOMP Change out 3.5" x 6" Variable Rams Bodies. in Upper Pipe Printed: 12/20/2007 11:54:26 AM • • BP EXPLORATION Page 3 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date.. Frorn - To Hours Task Code NPT Phase Description of Operations 11/18/2007 09:00 - 11:00 2.00 BOPSU N SFAL DECOMP Rams 11:00 - 13:00 2.00 BOPSU P DECOMP Finish Testing BOP Test -Test 8, Upper Pipe Rams and Dart -Test 9, TIW Surface Valve, Manual Kill, HCR Choke -Test 10, manual IBOP on TDS ,Manual Choke 13:00 - 16:30 3.50 BOPSU N SFAL DECOMP R/U to Retrieve RTTS -Pick up RTTS Stinger and running tool -Flush debris -Check for pressure under RTTS 16:30 - 19:00 I 2.501 PULL I P 19:00 - 22:30 I 3.501 PULL I P 22:30 - 00:00 I 1.501 PULL I P 11/19/2007 { 00:00 - 02:00 I 2.00 I PULL I P 02:00 - 03:30 I 1.501 PULL I P 03:30 - 05:30 I 2.001 PULL I P 05:30 - 06:30 I 1.001 PULL I P 06:30 - 07:30 I 1.001 PULL I P 07:30 - 15:30 I 8.001 FISH I P 15:30 - 17:00 I 1.501 PULL I P 17:00 - 22:30 I 5.501 BOPSUF4 P -L/D Running Tool and RTTS -L/D 2 7/8 Pac Pipe -RID Running Equipment DECOMP PJSM, with SWS and NAD Rig Crew -R/U SWS, BOP's Pump in sub and Extension -Test to 1000 psi for 5 min, O.K. DECOMP RIH with 4.35 gauge Ring and Junk basket -Ta POGLM 5862 -Set down on POGLM, no movement -POOH, Minimal Rust in junk Basket DECOMP RIH with 4.15 Jet Cutter -Tag POGLM @ 5862' DECOMP POOH with Jet cutter -R/D SWS and clear floor of Wireline equipment DECOMP Rig Up To Pull Tubing P/U Handling equipment from outside Power Tongs, Slips and elevators Make up Spear DECOMP PJSM -Spear Tubing and Pull to confirm Latch -Back out Lock Down Screws and Control line Tubes -Attempt to Pull Tubing hanger to Floor, Pulling 220k -Pull 120k and Pulled han er to floor DECOMP CBU @ 485 gpm / 350 psi, -Monitor well, Static -8.5 Seawater in and out DECOMP UD Tubing Spear and Lay Down Landing Joint -Break out Hanger and Lay Down -Rig up control line Spooling Unit DECOMP Lay Down 5 1/2" #17 L-80 8 round tubing -145 full joints, (jt # 98 was tubing punched) -2 pup joints, -SSSV Landing Nipple 4 S.S. bands and 29 control line clamps -1 cut joint @ 20.92', Flared to 6.25" DECOMP Rig Down Handling equipment and Clean Floor of extra tools and equipment DECOMP PJSM on testing BOP's -Install Test Plug, Attempted to test, Leaking past test plug -Pull Test plug and inspect, no visible deficiencies seen -Make up another plug that was brought out by FMC tech Printed: 12/20/2007 11:54:26 AM • 0.50 CLEAN P 1.50 CLEAN P 2.50 CLEAN P 1.25 EVAL P 0.25 EVAL N BP EXPLORATION Page 4 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/19/2007 17:00 - 22:30 5.50 BOPSU P DECOMP Ran one 6 1/4"SDC, Double pin XO on bottom of Test plug RIH with test joint ,Seat Test Plug and lock in Test Too and bottom set of Rams to 250 osi low and 3500 osi 22:30 - 00:00 I 1.501 PULL I P 11/20/2007 00:00 - 01:30 I 1.50 FISH P 01:30 - 05:00 3.50 FISH P 05:00 - 05:30 I 0.501 FISH I P 05:30 - 09:00 3.50 FISH P 09:00 - 12:00 3.00 FISH P 12:00 - 14:30 2.50 FISH P 14:30 - 16:00 1.50 FISH P 16:00 - 17:00 17:00 - 18:30 18:30 - 20:30 20:30 - 00:00 11 /21 /2007 00:00 - 01:00 01:00 - 02:00 02:00 - 03:00 1.00 CLEAN P 1.50 CLEAN P 2.00 CLEAN P 3.50 CLEAN P 1.00 CLEAN P 1.00 CLEAN P 1.00 CLEAN P 03:00 - 03:30 03:30 - 05:00 05:00 - 07:30 07:30 - 08:45 08:45 - 09:00 09:00 - 15:30 15:30 - 17:15 17:15 - 18:00 18:00 - 21:30 6.501 EVAL I P • Test Bag to 250 Low and 2500 psi high All Good tests, All test held for 5 minutes and charted Test Witnessed by NAD TP Bruce Simonson, BP WSL Dave Newlon, Witnessing of test waived by AOGCC Bob Noble R/D Test Equipment, Plug, SDC & XO Install Wear Ring, 9" ID DECOMP PJSM on Picking up BHA -Make up overshot fishing BHA DECOMP Finish picking up Fishing BHA to 868'. DECOMP RIH picking up 4" DP to 5809'. Install blower hose. Rack back one stand and pick up DP single. DECOMP Up weight 145k, down 130k, RT 140k. Free torque 3.5k. Pump at 126 gpm with 130 psi. Wash and ream over fish with 1-3k WOB. DECOMP Pull and Jar pipe with 300k to 375k up. Max dead pull 400k. continue to jar with no success. Perform blind back off. Pick up DECOMP PJSM. Perform inspection of derrick, top drive and draworks. DECOMP POOH to 868'. Change out handling equipment. DECOMP POOH with 5-1/2" fish at 18.38'. Pin looking down. Break and lay down overshot and fish. Clear and clean floor. DECOMP Wait on orders from town. DECOMP PJSM. Pick 9-5/8" casing scraper BHA up beaver slide. Steam and prep tools.. DECOMP PJSM. Make up 9-5/8" casing scraper BHA to 888'. Change out handling equipment. DECOMP RIH picking up 4" DP to 5558'. Up weight 140k, down 125k. DECOMP RIH picking up 4" DP to 5828'. Tag top of 5-1/2" tubing. Rack back one stand. DECOMP Pump hi-vis sweep surface to surface at 500 gpm with 1700 psi. Pump dryjob, blow down top drive. DECOMP PJSM. Cut and slip 95' of drilling line. Lube Elmago Splines. Inspect traction motor brushes. DECOMP Service top drive, crown and draworks. DECOMP POOH with 9-5/8" scraper assembly to 888'. DECOMP POOH with 9-5/8" scraper BHA. Clear floor. DECOMP PJSM. Spot E-line unit. PU and rig up for logging run. DFAL DECOMP Troubleshoot USIT which failed during surface test. Change out USIT cartridge and re-test - OK. DECOMP RIH and loa ua from 5000' with USIT/CCL/GR in cement and 1.75 DHB P DECOMP Make up lubricator extension, pump in sub, pack off and EZSV tools. Trouble with surface test. 0.75 DHB N DFAL DECOMP Troubleshoot tools. Replace GR tool. Make up EZSV. Pressure test to 500 psi - OK. 3.50 DHB P DECOMP RIH with EZSV on E-line and set with top at 4668'. POOH. CO tools. 21:30 - 00:00 ~ 2.50 ~ DHEOP ~ P ~ ~ DECOMP ~ Pressure test to 500 psi - OK.. RIH with string shot to 2020'. Printed: 12/20/2007 11:54:26 AM • • BP EXPLORATION Page 5 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date: I From - To Hours Task I Code I NPT Phase Description of Qperations 11/21/2007 21:30 - 00:00 2.50 DHEOP P DECOMP Shoot from 2014' to 2026'. POOH. Rig down E-line unit. 11/22/2007 00:00 - 01:30 1.50 ZONISO P DECOMP Make up 9-5/8" RTTS and RIH on 4" DP. 01:30 - 03:00 1.50 ZONISO P DECOMP Purge system of air. Set RTTS at 2350'. Test casing to 3500 psi for 30 minutes. Test - OK. Pull up to 2299'. Test casing patch at 2309'. Test - OI<. Pull up to 2256'. Test FO at 2266. Test failed. Leak in bottom FO at 2266'. 03:00 - 04:00 1.00 ZONISO P DECOMP POOH to RTTS. 04:00 - 04:30 0.50 ZONISO P DECOMP Break out and lay RTTS down beaver slide. 04:30 - 06:00 1.50 FISH P DECOMP PJSM. PU/MU casing cutter, XO, stabilizer, DC and HWDP to 834". 06:00 - 07:00 1.00 FISH P DECOMP RIH to 1957'. Install blower hose. 07:00 - 08:30 1.50 FISH P DECOMP Pump at 170 gpm with 300 psi. Torque 1k at 30 rpm. Up, down and RT weight 90k. Wash down and tag collar at 2021' for verification. Pull up and cut casing at 2001'. Pump at 200 gpm with 410 psi. Torque 1.4k to 3.2k at 30 rpm. Increase to 365 gpm with 610 psi. Open OA to cuttings tank and establish pumpulation. Shut in OA. Blow down top drive and remove blower hose. 08:30 - 13:00 4.50 FISH P DECOMP PJSM. Rig up head pin and circulating lines to top drive. Pressure test LRS lines to 3000 psi - OK. Displace drill pipe with diesel. Close bag. Line up and pump 160 bbls of 140 degree diesel displacing arctic pak from OA to cuttings tank at 63 gpm with 400 psi. Follow with 30 bbl soap pill and displace OA with clean 110 degree seawater. Pump seawater at 190 gpm with 450 psi. Rig down and blow down circulating lines. Monitor well -static. OA = 0 psi. 13:00 - 14:00 1.00 FISH P DECOMP POOH to 834'. Change out handling equipment. 14:00 - 15:30 1.50 FISH P DECOMP POOH with cutter BHA. Lay down cutter. Pull wear ring. 15:30 - 17:00 1.50 BOPSU P DECOMP Make up 9-5/8" packoff running tool. PJSM. RIH and J into packoff. De-energize packoff with 2 left hand turns. Back out lock down screws, (BOLDS). Pull packoff with 20k. Pull to rig Floor and LD. 17:00 -18:00 1.00 BOPSU P DECOMP Shut down for Thanksgiving dinner. 18:00 - 21:00 3.00 BOPSU P DECOMP Chan a out to set of rams to 9-5/8". Rig up test joint and plug. Hang 1 stand of HWDP below. Test 9-5/8" rams to 250 psi low, 3500 psi high as per AOGCC. Witness waived by John Crisp with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Bruce Simonson. Rig down test equipment. 21:00 - 22:00 1.00 FISH P DECOMP Make up 9-5/8" spear with 1 joint of 4" DP. Engage 9-5/8" casing. 22:00 - 00:00 2.00 FISH P DECOMP Break flange on bottom of tubing spool. Pull BOP stack and tubing spool to gain access to 9-5/8" emergency slips. Attempt to pull casing free staging to 150k up. No go. Make several attempts with no success. Wrap wellhead and apply steam. Pull 130k up and let steam heat up wellhead and slips. 11!23/2007 00:00 - 01:30 1.50 FISH P DECOMP Continue to steam wellhead and hold PJSM. Pull on 9-5/8" casing, staging up to 250k up, (130k over). Attempt several times working pipe.,Pioe nulled free at 240k u~. Free up weight 110k. Pull up and lift emergency slips with casing collar and remove slips. Clean out flange and seal ring grooves. 01.:30 - 02:30 1.00 BOPSU P DECOMP PJSM. NU spool and install BOP stack turnbuckles and riser. 02:30 - 03:00 0.50 BOPSU P DECOMP Close bag and test flange break against well to 250 psi low, 2500 psi high. Printed: 12/20/2007 11:54:26 AM • BP EXPLORATION Page 6 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/23/2007 03:00 - 11:30 8.50 FISH P DECOMP PJSM. Rig up false bowl and power tongs. Break and lay down landing joint. Break out cut stump and lay down spear. Pu11 9-5/8" casing from cut at 2002'. Average break out torque 13k. Recovered 11 bow spring centralizers, 49 full joints and cut joint of 21.28'. Rig down, clear and clean floor. 11:30 - 12:30 1.00 BOPSU P DECOMP PJSM. Change upper rams back to 3-1/2" x 6" variables. 12:30 - 14:30 2.00 BOPSU P DECOMP Make up 4" test joint, install test plug. Test top rams to 250 psi low, 3500 psi high as per AOGCC. Pull test plug. Install wear ring. Rig down test equipment. 14:30 - 17:30 3.00 FISH P DECOMP PU spear, break off bull nose and cup, lay down. Pick scraper and subs up beaver slide. MU jars, bumper sub, scraper boot basket, float sub, XO, drill collars and HWDP to 859'. 17:30 - 18:30 1.00 FISH P DECOMP RIH above stub at 2002'. Hook up blower hose. Run in and tag stub at 2002'. Up and down weight 90k. 18:30 - 19:00 0.50 FISH P DECOMP Pump soap pill surface to surface at 500 gpm with 675 psi. 19:00 - 20:00 1.00 FISH P DECOMP POOH to 859'. 20:00 - 21:00 1.00 FISH P DECOMP Stand back HWDP and drill collars. Break and lay down bit, boot basket, scraper and jar/bumper sub assembly. 21:00 - 23:00 2.00 FISH P DECOMP PJSM. Bring up tool basket. Rig up false bowl. Pick up washpipe shoe assembly. PU jar/bumper sub assembly. Make up junk basket, double pin sub, drill collars and HWDP to 891'. 23:00 - 00:00 1.00 FISH P DECOMP RIH to 1890'. PU drill pipe single. Hook up blower hose, MU last stand. 11/24/2007 00:00 - 01:00 1.00 FISH P DECOMP PJSM. Make up top drive. Establish circulation at 140 gpm with 72 psi. Free torque at 1-2k with 40 rpm. Up weight 90k, down 90k, RT 93k. Run last stand in, tag top offish at 2002'. Wash over fish to 2022'. Tag collar mill o centralizer at 3-5k WOB with 5-14k for ue. Work up and down several times. Wash down to no-go at 2032', work up and down several times. 01:00 - 03:00 2.00 FISH P DECOMP Circulate sweep surface to surface at 200 gpm with 100 psi. Rotate and reciprocate at 40 rpm. 03:00 - 04:00 1.00 FISH P DECOMP PJSM. Rack back one stand. Lay down single of DP. Remove blower hose. POOH to 891'. Change out handling equipment. 04:00 - 06:00 2.00 FISH P DECOMP PJSM. Stand back HWDP and drill collars. Lay down washpipe BHA. 06:00 - 07:00 1.00 FISH P DECOMP PJSM. lay tool basket down beaver slide. Clear and clean floor. Pick up backoff BHA. 07:00 - 09:30 2.50 FISH P DECOMP PJSM. PU one stand of collars. MU bull nose. RIH with remaining collars, BHA and one stand of HWDP. Fill pipe on the fly to 869'. Change out handling equipment. 09:30 - 11:00 1.50 FISH P DECOMP RIH to 2022' filling every 5 stands. 11:00 - 14:00 3.00 FISH P DECOMP Make up head pin and test pump. Space out top anchor at 2010' and bottom anchor at 2036'. Up weight 90k, down 95k. Set bottom anchor with 1200 psi, top anchor with 4000 psi. Slack off string weight. Casing collar broke with 1200_ psi. Cycle back-off tool 5-1/2 turns to the left. Bleed pressure, PU 95k and verify release of tool. Drop dart to open circ sub. Displace diesel to cuttings tank. Rig down. 14:00 - 15:00 1.00 FISH P DECOMP POOH to 869'. 15:00 - 17:00 2.00 FISH P DECOMP Stand back HWDP. Break and lay down XO, upper anchor, power section, lower anchor, blanking sub, XO and circ sub. Stand back DC and break bull nose. 17:00 - 17:30 0.50 FISH P DECOMP PJSM. Pick up jar/bumper sub assembly. Make up spear and Printed: 12/20/2007 11:54:26 AM BR EXPLORATION Page 7 of 19 Operations :Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT .Phase Description of Operations 11/24/2007 17:00 - 17:30 0.50 FISH P DECOMP bull nose. Lay down jar. Make up circ sub and XO to 21'. 17:30 - 18:30 1.00 FISH P DECOMP RIH to 2002'. Up weight 55k, down 60k. 18:30 - 19:00 0.50 FISH P DECOMP Swallow flash to the no go and confirm latch. Turn string to the _ left 4 turns and PU free. - 19:00 - 20:00 1.00 FISH P DECOMP POOH to 21'. 20:00 - 22:00 2.00 FISH P DECOMP Rig up tongs and back out spear, break and lay down spear and cut casing of 20.00'. Threads look good for screw in. Clear floor and lay tools down beaver slide. 22:00 - 23:00 1.00 FISH P DECOMP Change out top drive saver sub and adjust grabber. 23:00 - 23:30 0.50 FISH P DECOMP Make up magnet, bit sub, bumper sub and XO to 15'. 23:30 - 00:00 0.50 FISH P DECOMP RIH to 764'. 11/25/2007 00:00 - 01:30 1.50 FISH P DECOMP PJSM. RIH to 1978'. PU stand, MU to top drive. Slack off, hang up at 2020', continue to slack off and tag top of stump at 2022'. Pick up. Circulate at 525 gpm with 600 psi. Clean off 9-5/8" box. Shut down, slack off and hang up again at 2020', continue to slack off and tag top of stump at 2022'. Rack back 1 stand. Blow down top drive. 01:30 - 02:00 0.50 FISH P DECOMP PJSM. POOH to 15'. Change out handling equipment. 02:00 - 02:30 0.50 FISH P DECOMP Pull magnet to floor. Recover metal shavings. Break out magnet. Lay down magnet and bumper sub. Clear and clean floor. 02:30 - 03:00 0.50 FISH P DECOMP Lay magnet and XO down beaver slide. PU mule shoe BHA. 03:00 - 04:00 1.00 FISH P DECOMP Make up 7"mule shoe with bow spring centralizer to 27'. 04:00 - 05:00 1.00 FISH P DECOMP RIH and tag top of 9-5/8" stump at 2022' with no hang up. Work down into 9-5/8" and tag up at 2034'. Pull up above stump. Slack off and work into stump at 2022' with no problems, continue to slack off and tag up 2' lower at 2036'. Set down 10k then pull off. 05:00 - 06:00 1.00 FISH P DECOMP PJSM. POOH to 27'. Change out handling equipment. 06:00 - 07:00 1.00 FISH P DECOMP PJSM. Break and lay down mule shoe and centralizer. Clear and clean floor. Pump out stack. 07:00 - 07:30 0.50 BOPSU P DECOMP PJSM. Pick up test joint. Make up wear ring running tool. Remove wear ring. Install test plug. Remove joint. 07:30 - 08:30 1.00 BOPSU P DECOMP PJSM. Change out top rams to 9-5/8". Fill stack and check for leaks. 08:30 - 09:00 0.50 BOPSU P DECOMP PJSM. Make up TIW, dart valves, 4 and 5 inch test joints. 09:00 - 16:30 7.50 BOPSU P DECOMP PJSM. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witnessed by John Crisp with AOGCC. Two lower mud cross valves failed. 16:30 - 20:30 4.00 BOPSU N SFAL DECOMP PJSM. Remove and replace lowewr mud cross valves. Troubleshoot manifold pressure gauge on Koomey unit. 20:30 - 21:00 0.50 BOPSU N SFAL DECOMP Re-test lower mud cross valves to 250 psi low, 3500 psi high. Inner valve passed, outer valve failed. 21:00 - 21:30 0.50 BOPSU N SFAL DECOMP Replace outside lower mud cross valve. 21:30 - 22:00 0.50 BOPSU N SFAL DECOMP Retest outside lower mud cross valve to 250 psi low, 3500 psi high. Pull test plug. Blow down BOP equipment. 22:00 - 00:00 2.00 CASE P DECOMP PJSM. Change out bales. Pick up and rig up 9-5/8" casing equipment. 11/26/2007 00:00 - 01:00 1.00 CASE P DECOMP Continue rigging up to run 9 5/8" casing 01:00 - 01:30 0.50 CASE P DECOMP PJSM for running casing. 01:30 - 05:00 3.50 CASE P DECOMP Run 49 jts 9 5/8" 47# L-80 H r' ' h screw in sub and E cementer. Clear floor. 05:00 - 06:30 1.50 CASE P DECOMP MU XO from casing to 4" HT-40 DP and screw top drive into Printed: 12/20/2007 11:54:26 AM • BP EXPLORATION Page 8 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date:. From - To Hotars Task Code.. NPT Phase ` Description of Operations 11/26/2007 05:00 - 06:30 1.50 CASE P DECOMP XO. Rotate string and engage screw in sub in casing coupling at 2022' DPM. MU with 10 klbs torque. Pull test to 150 klbs over string weight - OK. 06:30 - 07:45 1.25 CASE P DECOMP RU lines and cement head. Test casing to 2000 psi for 30 minutes - OK. increase pressure to 2800 psi & open ES cementer. 07:45 - 09:00 1.25 CASE P DECOMP Circ heated seawater to warm up well to get 80+ degree returns prior to cementing. 09:00 - 09:15 0.25 CASE P DECOMP PJSM with crew and service company personnel prior to job. 09:15 - 10:00 0.75 CASE P DECOMP Air up & prime up cementers. Pump 5 bbls water and test lines to 4500 psi. Pump 40 bbls MudPush spacer at 10 ppg. 10:00 - 10:30 0.50 CASE P DECOMP Switch to cement. Mix & pump 136.5 bbls (655 sx) 15.8 ppg Class Gslurry - 5 bpm @ 850 psi start. 5 bpm at 980 psi end. 10:30 - 11:00 0.50 CASE P DECOMP Release closing plug for ES cementer and displace cement with seawater. 6 bpm @ 650 psi start. 6.5 bpm @ 1350 psi at 140 bbls away. Slow to 2 bpm andland closing plug in cementer at 150.4 bbls away. Increase pressure to 2100 psi 11:00 - 11:15 I 0.251 CASE I P 11:15 - 13:00 1.75 CASE P 13:00 - 17:00 4.00 BOPSU P 17:00 - 22:30 I 5.501 BOPSUaP 22:30 - 00:00 I 1.501 BOPSUF~P 111/27/2007 100:00 - 01:00 I 1.001 BOPSUFYP 01:00 - 03:00 I 2.001 CLEAN I P 03:00 - 04:00 I 1.00 ~ CLEAN I P 04:00 - 06:00 2.00 CLEAN P 06:00 - 07:00 I 1.001 CLEAN I P DECOMP Hold pressure to ensure cementer is closed. Bleed off pressure and verify no flowback - OK. Cementer closed. Got bac -15 bbls cement slurry to surface. CIP - 1100 hours. DECOMP Rig up supersucker hose and suck casing out to ground level. Suck out stack. Rig down false bowl. Clear floor of casing equipment. DECOMP Rig up bridge crane to BOP stack. Split and raise stack and tubing spool. Install emergency slips with primary packoff. Up weight 210k, slack off and set slips with 100 klbs over string weight. Run in lock down screws. Rig up WACHS cutter and cut casing. Lay down mouse hole and cut joint. Stand BOP stack back. Pull old tubing spool and romove from cellar. DECOMP Prep 9-5/8". Install secondary packoff and new tubing spool. Torque up. Test void and packoff to 3800 psi for 10 minutes - OK. PJSM. NU BOP stack. Install secondary annulus valve. Install 3-1/2" x 6" variable rams in top set. DECOMP Make up test joint. Install test plug. Fill stack and test flange, rams and doors to 250 si low, 3500 si hi has er AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Bruce Simonson. Pull test plug. Run in wear ring. DECOMP PJSM. Run in lock down screws. Break out wear ring running tool and TIW. Lay down test joint. Pick up clean out BHA. DECOMP PJSM. PU up mills. Break out upper mill. Lay down flex joint and window mill. Pick up jars and BHA to bit. Pick up collars and HWDP to 864'. Change out handling equipment. DECOMP PJSM. RIH to 1987'. Make up top drive. Fill pipe at 375 gpm with 420 psi. Wash down. Install blower hose. DECOMP Pump at 500 gpm with 730 psi. Up, down and RT weight 90k. Wash down and tag TOC at 1997'. Rotate at 70 rpm with 1 k torque off bottom. 'Drill plug and cement to baffle collar with 5-10k WOB and 2-4k torque. Drill through baffle collar and work through to 2030'. Blow down top drive. DECOMP RIH to 4600'. Fill pipe. Up weight 125k, down 115k. Slack off to Printed: 12/20/2007 11:54:26 AM • • BP EXPLORATION Page 9 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours .Task Gode NPT Phase Description of Operations 11/27/2007 06:00 - 07:00 1.00 CLEAN P DECOMP and push junk from 4602' to 4665'. Set down 30k. Pick up then slack off and verify EZSV with junk at 4665' with 30k down. Pick up 20 . 07:00 - 10:00 3.00 CLEAN P DECOMP Pump hi-vis sweep followed by 9.2 ppg LSND milling fluid at 465 gpm with 1150 psi. At bottoms up the H2S alarm went off showing 11 ppm. Shut down pump and shut in well. Both casing and DP showed 0 psi. Monitor showed 0 ppm in pits but hand held monitor held directly over mud in trough showed 11 ppm. Suspect sour mud causing H2S alarm. Held safety meeting with hands and truck drivers. Rigged up to take returns through gas buster out to cuttings tank. Continue displacement with no more H2S readings. Pump until 9.2 ppg LSND milling fluid all the way around. Pump dry job. Shut down and blow down top drive. 10:00 - 11:00 1.00 CLEAN P DECOMP POOH to 864'. Change out handling equipment. 11:00 - 13:00 2.00 CLEAN P DECOMP POOH. Lay down drill collars and clean out BHA. Clear floor. PU whi stock tools. 13:00 - 14:00 1.00 DHB P DECOMP Test casin to 3500 si for 30 minutes. Test - OK. 14:00 - 16:30 2.50 STWHIP P WEXIT Make up window mill, lower mill, flex joint, upper mill, single HWDP, float and MWD tools. Scribe, install probe and set back. Pick up whipstock slide. MU bull nose and set in table. Install brass lug and check shear pins. RIH. MU bumper sub, drill collars, HWDP and first stand. Perform surface test at 500 gpm with 750 psi - OK. 16:30 - 20:30 4.00 STWHIP P WEXIT RIH to 3771'. Fill pipe and pulse test at 500 gpm with 1250 psi - OK. RIH to 4516'. 20:30 - 21:30 1.00 STWHIP P WEXIT Orient and hook up blower hose. Make up last stand. Up weight 125k, down 115k. Run in and tag at 4665'. Set down 20k and set bottom anchor at 25 to 30 degrees right. Pick up and confirm set. Set down 35k and shear off whipstock slide. 21:30 - 00:00 2.50 STWHIP P WEXIT Mill 8-1i2" hole in 9-5/8" casing to 4647'. Pump at 500 gpm with 1370 psi. Rotate at 90 rpm with 3.5k to 10.5k torque. WOB 2-5k. TOW 4644' BOW 4661' 11/28/2007 00:00 - 04:00 4.00 STWHIP P WEXIT PJSM. Mill window to 4681'. Pump at 500 gpm with 1390 psi. Rotate at 90 rpm with 5k torque off bottom, 5-8k torque on bottom. WOB 5-15k. Work through window several times with rotary. Kill rotary slack off and work through window with no problems. Up weight 127k, down 115k. Recovered 350 Ibs of metal. 04:00 - 05:00 1.00 STWHIP P WEXIT Pump hi-vis super sweep at 500 gpm with 1400 psi surface to surface. Shut down pumps. Slack off and work through window. Window in good shape. Rack back stand. 05:00 - 05:30 0.50 STWHIP P WEXIT PJSM. Perform FIT to 12.5 paa with 750 osi. Good test. 05:30 - 07:30 2.00 STWHIP P WEXIT Remove blower hose. Install rubbers. Blow down top drive. Install air slips. POOH to 915'. Change out handling equipment. Monitor well. Rack back HWDP. Stab TIW. Hold PJSM. 07:30 - 10:00 2.50 STWHIP P WEXIT Lay down drill collars. Break out mills. Upper mill in gauge. Lay down mills and 1 joint HWDP. 10:00 - 12:00 2.00 STWHIP P WEXIT PJSM. Pick up test joint and make up wear ring running tool. Remove wear ring. Make up stack jetting tool. Flush stack. Printed: 12/20/2007 11:54:26 AM • • BP EXPLORATION Page 10 of 19 Operations Summary Report Legal Well Name: 02-09 Common Well Name: 02-09 Spud Date: 7/19/1976 Event Name: REENTER+COMPLETE Start: 11/15/2007 End: 12/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/14/2007 Rig Name: NABORS 2ES Rig Number: Date From- To Hours Task Code NPT Phase Description of Operations 11/28/2007 10:00 - 12:00 2.00 STWHIP P WEXIT Function all BOPE. Blow down choke and kill lines. Install wear ring. Lay down test joint. Lay mills and BHA down beaver slide. PU 8.5" BHA. Clear and clean floor. 12:00 - 15:30 3.50 STWHIP P WEXIT PJSM. PU motor and make up bit. Install float. Make up MWD tools and scribe offset. PU flex drill collars, ball catcher and CCV. Run HWDP, jars and XO to 824'. Pulse test MWD at 500 gpm with 900 psi. 15:30 - 17:00 1.50 STWHIP P WEXIT PJSM. Pick up drill pipe to 2600'. 17:00 - 18:30 1.50 STWHIP P WEXIT RIH to 4563'. Fill pipe at 3771' and 4563'. Pump at 500 gpm with 1500 psi. Orient to pass through window. 18:30 - 19:30 1.00 STWHIP P WEXIT PJSM. Cut and slip 77' of drilling line. Lube Elmago Spline. Inspect brakes and draworks. 19:30 - 20:00 0.50 STWHIP P WEXIT Service to drive. Install blower hose. 20:00 - 21:30 1.50 DRILL P INT1 Pass window at 4644' with no problem. Wash from 4665' to 4681'. Directional drill ahead to 4765'. Up weight 130k, down ~~.Q~ 110k, RT 120k. WOB 10-15k. Pump at 500 gpm with 1450 psi off bottom, 1590 psi on bottom. Rotate at 60 rpm with 5k torque. AST .8, ART .1 Mud weight in and out 9.3 ppg. 21:30 - 00:00 2.50 DRILL N DFAL INT1 Trouble shoot MWD pulse failure. Pressure increase on connection. Signal stopped. Try various pump rates. Cycle pumps on an off several times. Jar and work pipe. No signals. Pump fresh water pill to try and flush MWD tools. Pressure dropped off as water went through tool but no signal recovery. Mix dry job. 11!29/2007 00:00 - 02:00 2.00 DRILL N DFAL INT1 PJSM. Monitor well. Pump dry job. Remove blower hose. Blow down top drive. Install rubbers and air slips. POOH to 823'. Mud weight in and out 9.3 ppg. Up weight 130k, down 105k. 02:00 - 03:00 1.00 DRILL N DFAL INT1 PJSM. Change out handling equipment. Stand back HWDP. Lay down CCV. Stand back Flex drill collars. POOH to TM. 03:00 - 06:30 3.50 DRILL N DFAL INT1 Plug in MWD, turn off tool. Unplug and pull pulser. Break out TM, put in mousehole. Install new pulser and TM tool. Second TM tool failed. Swap TM tool. Plug in, test - OK. 06:30 - 08:00 1.50 DRILL N DFAL INT1 PJSM. Make up flex collars. Pick up CCV and 1 stand HWDP. MWD found partially shattered poppet in pulser. Break out HWDP and stand back. Lay down CCV and stamd bacl flex collars. POOH to bit and break out. Check for debris, none found. Break float and check motor shaft, nothing found. Make up top drive and circulate at 500 gpm with 550 psi to flush motor. Shut down and blow down top drive. Make up bit and BHA to 824'. Change out handling equipment. PU 1 stand DP. 08:00 - 09:30 1.50 DRILL N DFAL INT1 MU top drive. Surface test MWD at 500 gpm with 960 psi - OK. 09:30 - 10:30 1.00 DRILL N DFAL INT1 RIH to 4750'. 10:30 - 13:30 3.00 DRILL P INT1 Directional drill ahead to 4870'. Pump at 550 gpm with 1670 psi off bottom, 1950 psi on bottom. Rotate at 90 rpm with torque 4-6k off bottom, 5-7k on bottom. WOB 5-7k. Mud weight in and out 9.3 ppg. 13:30 - 14:30 1.00 DRILL N DFAL INT1 Trouble shoot MWD detection problems. Switch modes. Hardboot Sperry computers. Reduce mud pump pulsation. dampners. Stagger pump speeds.. Able to achieve on the fly logs but limited success on correctable surveys. 14:30 - 00:00 9.50 DRILL P INT1 MWD detection improving. Directional drill ahead to 5774' MD, 5458' TVD. Pump at 600 gpm with 2370 psi. off bottom, 2550 psi on bottom. Torque 5-6k off bottom, 6-8k on bottom at 100 Printed: 12/20/2007 11:54:26 AM TREE = Cameron WELLHEAD= FMC ACTUATOR KB. ELEV = 60.43 BF. ELEV = 31.93 KOP = _ Max Angle = 4597 92 ~ 11381 Datum MD = Datum ND = 8800' SS DRLG DRAFT 02-09C X' fipple GAS LIFT MANDRELS 9-5/8", 47#, L-80, HY DRIL 563 2025' ES Cementer ~ 2011' Open FO w ith cement bebw to 2300' 2~6' 13-3/8" CSG, 72#, N~80, D = 12.347" ~" 2~'~ 7"x9-5/8" Liner Top ZXPPacker w / PBR 3013' Min. ID = 3.275" @ 8869' XN nipple ~ ¢sv s-1 /r' stub GA S LIFT MANDRELS fCH PORT DATE K 0 11I07l02 = 4.562" 8507' ssemby 8607' '.~-,/ti- % 5-1%1` t3a Ker SAB PdCker $627' 5-112" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.89T' 8639' TOP OF 41 /2" TBG-PC 8639' 4112" Otis XN Nipple, ID = 3.725" 8702' TOP OF3-1/2" LNR 8724' 3-112" LNR, 9.3#, L-B0, ID = 2.992" $72$' TOP OF 2-7/8" LNR 8728' 41/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" 8763' TOP OF 7" LNR 8726' 9-5/8" CSG, 47#, N-80, ID = 8.681" 9021' 7" LNR, 29#, L-80, .0371 bpf, ~ = 6.184" 9596' 2-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" 11680' 8774' -~ X' Nipple ~ 8805' 7"x4- t /2" S3 PACKER 8839' X' Nipple 8869' Xtf Nipple 1 8876' 4v2" Liner t 9030' 7" L-80, 26#, ID=6.276" 11383' r~To 11469' 4tn- L-so, 12.611. ~a.sse" 0690 CTM D i--I 2-7/8" HES MODEL M CIBP 1161x' 2-7/8" LANDING COLLAR 11678' 2-7/8" DAMS LYNCH BULLET NOSE FLOAT SHOE DATE REV BY COMMENTS DATE REV BY COMMENTS 1997 ORIGINAL COMPLETION 08119/99 WORKOV ER 12114!07 N2ES SIDt7RACK PRUDHOE BAY UNff WELL: 02-09C Roposed PERMIT No: 1971010 API No: 50-029-20153-03 SEC 36, T11 N, R14E, 1216' FNL & 971' FWL BP Exploration (Alaska) ST MO N D DEV TYPE V L V LATCH PORT DATE 4 2838 2837 0 KBG2-1 R EMPTY BK 12/14!07 3 5251 4995 27 KBG2-1 R OMY BK 0 12/14/07 2 7078 6603 26 KBG2-1 R OMY BK 0 12/14/07 1 8654 7995 27 KBG2-1 R DMY BK 0 12/14/07 .0751 DPT, R.1 = RE: O~zBH~"(P~I~.-#~?~}=~j-In~1 Waiver Cancellation -Corrected to~09B (PTD #19?1010) Page 1 of 1 Regg, James B (DOA) ~~~, , From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~,, ;,~ (zl~~~~ Sent: Thursday, December 13, 2007 6:08 AM To: NSU, ADW Well Integrity Engineer; Regg, James 6 (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, Wells Opt Eng Cc: NSU, ADW WI Tech; Dean, James A Subject: RE: 02-09C (PTD #2071390) Internal Waiver Cancellation -Corrected to 02-09B (PTD #1971010) `'~ All, ~~ ~~~ 02-CJ ~ i3 i The internal waiver was originally issued for 02-098 (PTD #1971010) and has been cancelled. '"'~ Thank you, Andrea Hughes ~~~~~ JAN ~ ~ ZG~8 From: NSU, ADW Well Integrity Engineer Sent: Saturday, December O8, 2007 9:57 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); 'bob_fleckenstein@admin.state.ak.us'; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; GPB, Wells Opt Eng Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Dean, James A Subject: 02-09C (PTD #2071390) Internal Waiver Cancellation All, An internal waiver was issued for IAxOA communication on well 02-09C (PTD #2071390) on 12/10/05. The rig placed ~' and cemented a 7" liner in the well on 12/03/07, thus restoring production casing integrity. The rig sidetrack is currently in progress and the well will be reclassified as Operable upon completion. Until that time, the well is classified as Not Operable. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907} 659-5102 Pager: (907) 659-5100 x1154 12/18/2007 11/27/07 ~chfumb~rr~er NO. 4517 Alaska Data & Consulting Services ~~~ nfn" ~ ~ ~Ory~ 2525 Gambell Street, Suite 400 IV U v U Company: State of Alaska Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth ` 333 West 7th Ave, Suite 100 ~ ~, t Anchorage, AK 99501 ~~ Field: P.Bay, Milne Pt., Lisburne wen JOb 7F Lo De,&c i ~L40L~. Date BL Color CD MPL-33 11661179 MEM INJ PROFILE (REVISED) 11/13/07 1 L1-15A 11661181 MEM PROD PROFILE ~ 11121/07 1 MPH-08 11686799 USIT ~ _ 11/18/07 1 02-09B 11890327 USIT 11/21/07 1 LGI-04 11686752 RST ~ OSi27/07 1 1 PLEASE ACKNOWLEDGE RE CEIPT BY SIGN ING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 - 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~~~~ :~~ ~ ';~f~~~~~ ~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 /~ ATTN: Beth ~ n r Received by • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, November 21, 2007 11:16 AM To: 'Hobbs, Greg S (ANC)' Cc: Honas, Kristopher Subject: RE: 02-09C (207-139) Change in Kick Off Point 14'1-\O oa -053 Greg, Thanks for the additional information. That answers my questions. It appears that the Ivishak has been successfully isolated per the plan. The additional wellbore interval will be isolated by the EZSV that will support the whipstock. Changing the plans is acceptable. Cafl or message with any questions. Tom Maunder, PE Anrr~ From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs~bp.com] Sent: Wednesday, November 21, 2007 9:42 AM To: Maunder, Thomas E (DOA} Cc: Honas, Kristopher Subject: RE: 02-09C (207-139) Change in Kick Off Point ~~° ~', ~®~ ~ ~~~7 Tom- I grabbed Eli and have him here as we respond as he is the 'second string" vith Travis ~ra..vaEation. '~'tt~ removal of the Pack-off Gas Lift Mandrel was the first step of the Rig operations' ~lf~i-e-~2ig operations per the permit were completed. The ID of the Pack-off Gas Lift Mandre! was 2.3" and this was not big enough to get a jet or chemical cutter through. For this reason. we attempted to pull it with Jlickiine to cut the tubing deep at the planned KOP. We were able to move it, but not pull it through the SSSV nipple. !t was then pushed as deep as possible, and a tubing cut was made above it. ~J~le then attempted a blind back-off and retrieved only the bottom 20' of the joint of tubing that we cut. We then moved for`rvard with a higher KOP. One of the contingencies for this wail as it was planned with the asset was a higher kick-off based on not being able to remove the Pack-off Gas Lift Mandrel. At this time, we can drill new hole faster than vve can make the multiple runs to cut the tubing to the originally planned kick-off point given the pack-off gas lift mandrel still being stuck at about X800' MD. The new i~OP was picked at ~5~0' M[~ to be in a competent formation for a shoe. Below is the pre-rig work request with completion dates as well as the digital well rEle summaries denoting the kill operations as well as the post abandonment pressure tests. Let me know if you need anything rise- Sarry about the confusion- and have a nappy Thanksgiving! Greg 1 ~ S ~ Drift tubing to CIBP at 10,690' if possible. DONE 10/2S/07 Lay in 13 bbls of cement from CIBP at 10,690' to the 4-1/2" x 5-1/2" crossover at 8639'. SBHP: 3300 psi SBHT: 190 °F 11 /23/2007 '' Volume of 2-7/8" from 10,690' to 8724': 0.0058 bpf, 1966' = 11.4 bbls Volume of 4-1/Z" from 8724' to 8639': 0.0152 bpf, 85' = 1.3 bbls If unable to tag 10,690' due to fill or junk, contact ODE and discuss adjustment of cement volume to compensate for tagged bottom and potential for bullheading 2 C cement. Use squeeze pressure of 1000 psi if operations allow. This plug is for zonal isolation. Wash down cement top to crossover at 8639'. Freeze rotect tubin with diesel to 2200' TVD. DONE 11/10/07 3 S WOC, drift to TOC, DONE 11/12/07 Test tubing to 2125 psi (reduced for tubular corrosion). Test IA and OA to 2000 psi. Pressure tests are required for competent barriers for drilling operations. 4 F tf test fails due to tubing issue, contact ODE. Note: 67% corrosion in tubing at 4,375' with > 20% corrosion in 109 other joints. DONE 11i12l07 5 F Bleed casing and annu!~~s pressures to zero. Done 11/13/2007 What work has been accomplished so far? According to the steps in the operations plan with the permit to drill, pulling the POGLM was number 1. Does the inability to pull the POGLM affect the coil cementing plans for 02- 096 (197-101) as approved by sundry (306-283)? Based on the proposed KO depth "shallowing up" by about 2000', it would appear that access deeper into the well may not be possible. If the well service work reports are available, I'd appreciate them being submitted. Thanks in advance for your reply. Call or message with any questions. Tom Maunder, PE AOGCC From: Vazquez, Eleazar [mailto:vazge0@BP.com] Sent: Wednesday, November 21, 2007 8:58 AM To: Maunder, Thomas E (DOA) Cc: Honas, Kristopher; Hobbs, Greg S (ANC) Subject: 02-09C Change in Kick Off Point Tom, During decomptetion operations for Well 02-09G a Pack Off Gas Lift Mandrel needed to be pulled out from 3944' MD. More time than what had initially been anticipated was spent pulling out this Pack Off Gas Lift Mandrel without success; therefore, an alternative solution, which included a change in Kick Off Point, was agreed upon. The new Kick Off Point is 4650' MD which is located in the SV Sands. A 10.7 ppg FIT wilt be needed. A new directional plan was created and it passes all collision risks. Operations proceed as orignally plan and targets remain the same. Attached you can find a copy of the new directional plan together with the new anti-collision report. Please let me know if I can be of any further help, Eleazar "Eli°° Vazquez 11/23/2007 v4-v~~.. ~.iiuLi~a, iii iu~.n vii a vui~ • , BP Exploration Alaska GPB Rotary Drilling Engineer Direct: 907.564.5918 Mobile 1:907.240.8137 Mobile 2: 915.346.6430 «02-09C Wp09 comp.txt» «02-09C WP09 AC Report.pdf» «02-09C WP09 DRAFT.pdf» «02-09C WP09 AC Plot.pdf» 11 /23/200'7 . u~~. i Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, September 28, 2007 4:27 PM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC} Subject: RE: 02-09C Sundry oa-o~. ~ Travis, I have no objections. Tom Maunder, PE AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.comJ Sent: Friday, September 28, 2007 11:06 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: 02-09C Sundry Tom, This ^~"U procedure looks to address r cur concerns from the previous procedure. The cement will be squeezed, and the tubing test follows the P&A guidelines for 0.25psi/ft to the casing shoe (8400' TVD). Please look it over and let me know if this is acceptable with the state. -Travis Peltier PS Have a great weekend. 02-09C Operations Summary Current Status: o CIBP at 10690' MD. o CMIT - IAxOA -Passed to 3000 psi (3/19/07) 0 1 joint of 5-1/2" tubing corroded 63% @ 4,375' MD [wall penetration only] (3/5/06) o Fluid in cellar (fresh water) (12/13/05) Pre Rig Operations 1. SLICK: Pull POGLV at 3944' MD. 2. COIL: Drift tubing through GLM at 7080' MD to CiBP at 10,690', if possible. 3. COIL: Lay in 13 bbls of cement from CIBP at 10,690' to the 4-1/2" x 5-1/2" crossover at 8639'. 11 /23/2007 i~u. v~ viv vu..uaJ Volume of 2-7/8" from 10,690' to 8724': 0.0058 bpf, 1966' = 11.4 bbls Volume of 4-1/2" from 8724' to 8639': 0.0152 bpf, 85' = 1.3 bbls If unable to tag 10,690' due to fill or junk, contact ODE and discuss adjustment of cement volume to compensate for tagged bottom and potential for bullheading cement. Use squeeze pressure of 1000 psi if operations allow. This plug is for zonal isolation. Wash down cement top to crossover at 8639'. SBHP: 3300 psi SBHT: 190 °F 4. COIL: Freeze protect tubing with Diesel to 2200' TVD. 5. Test tubing to 2,125 psi (reduced for tubular corrosion). Test IA and OA to 2000 psi. Pressure tests are required for competent barrier for rig operations. If test fails due to tubing issue, contact ODE. 6. Bleed casing and annulus pressures to zero. 7. SLICK: Drift to TOC. Be aware of GLM at 7080'. 8. Function tubing and casing LDS. Repair/replace as required. 9. Test tubing packoff to 5000 psi. Test 9-5/8" casing packoff to 3800 psi (80% of collapse resistance 47# L-80). 10. Set a BPV. Remove well house and flow line Level pad as necessary From: Maunder, Thomas E (DOA} [_~?ai~=~~`~r~_~?'~!_~^~'~~@a'~s'`a-~'~"17 Sent: Monday, September 24, 2007 5:06 PM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC); aogcc prudhoe_bay@admin.state.ak.us Subject: RE: 02-09C Sundry Travis, Sorry I am late in my reply. Yes, it is appropriate to rearrange the procedural steps as you propose. You will likely have to allow time for the cement to set prior to the pressure test unless you plan to employ some sort of retainer. Although you don't say a squeeze is necessary, it may be appropriate to bump the cement with a Tittle pressure. That shouid insure that there are no voids. With the passible tubing compromise is it advisable to test above the cement to 3500 psi? If the tubing fails, then the 9-5/8" and possibly 13-3/8" casing could be exposed to pressures higher than you might desire. Please have the rig supervisor contact the inspector for possibie witness of the plug pressure test. Call or message with any questions. A copy of this message should be available at the rig. Tom Maunder, PE AOGCC .:: - _ - -- .: From: Peltier, Travis M T-~-••- ~° ~ ~ .________ ____:_ _.___ Sent: Monday, September 24, 2007 4:50 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: FW: 02-09C Sundry :~ ., - ..emu f... fem.. ... ~r~~j~4t~h .`4~~aj~ ' From: Peltier, Travis M Sent: Friday, September 21, 2007 9:55 AM l l /23/2007 1W. VL-V/ii Ut.L..tLi ~' To: 'tom maunder@admin.state.ak.us` Cc: Hobbs, Greg S (ANC) Subject: 02-09C Sundry Tom, I am looking to change my order of operations for the Pre-Rig work listed on the Sundry Application for 02-09C (see pages 4 and 6 of attached Sundry}. Upon reviewing the Sundry's pre-rig ops and the current schematic far 02-09B, there is no isolation from the top perfs to successfully test the tubing to 3500 psi. I would like to cement the perfs up to 8639' and then test the tubing integrity rather than test the tubing and cement the perfs (see below). Please let me know if this is acceptable. -Travis Peltier (907)564-4511 Current Status: . ClBP at 10690' MD. ^ CMIT - IAxOA -Passed to 3000 psi (3/19/07} ^ 1 joint of 5-1/2° tubing corroded 63% @ 4,375' [wall penetration only) (3/5/06} ^ Fluid in cellar (fresh water) (12113105) Pre Rsg Operations 1. SLICK: Pull POGLM at 3944' MD. t=^'~14~~`?=" ?;~=';~? 2. COIL: Drift tubing through POGLM at 7080' MD to CtBP at 10,690', if possible. 3. COIL: Lay in 13 bbls of cement from CIBP at 10,690' to the 4-1/2" x 5-1/2" crossover at 8639'. Voiume of 2-7/8°' from 10,fi90' to 8724': 0.0058 bpf, 1966' = 11.4 bbls Volume of 4-112" from 8724' to 8639': 0.0152 bpf, 85' = 1.3 bbls If unable to tag 10,690' due to ftll, adjust cement to adjust for tagged bottom. Squeeze pressure is not required. This plug is for zonal isolation. Wash down cement top to crossover at 8639'. 4. Test tubing to 3500 psi. Test IA and OA to 2000 psi. {'=-,P~~=~! `' ?) Pressure tests are required for competent barrier for rig operations. 5. SLICK: Drift to TOC. Drift tubing to top of POGLM at 7080' for upcoming jet cut. 6. E-L{NE:.let cut 5-1/2" tubing in the middle of the first full joint above the POGLM at 7080'. 7. Circulate well to seawater through the cut until returns are clean. 8. Bleed casing and annulus pressures to zero. Freeze protect with Diesel to 2200' TVD. 9. Function tubing and casing LDS. Repair/replace as required. 10. Test 9-518" casing packoff to 500 psi. 11. Set a BPV. Remove welt house and flow line. Level pad as necessary. 11123/200'7 FW: 02-09C Sundry . . Page 1 of~ d-t5fYlf4 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, September 24, 2007 5:09 PM To: Maunder, Thomas E (DOA); 'Peltier, Travis M' Cc: Hobbs, Greg S (ANC) Subject: RE: Well name should be 02-098 \~~-VO \ Travis, I missed this prior to sending my reply. The correct well name should be 02-098 rather than 02-09C. According to the convention we use, all activities occur in 02-098 until the window is milled. FYI. Tom Maunder, PE AOGCC _.,--~-~~.~,--------------,-_._--"-~."--~--~_._._-~-----,----------------- From: Maunder, Thomas E (DOA) Sent: Monday, September 24,20075:06 PM To: 'Peltier, Travis M' Cc: Hobbs, Greg S (ANe); 'aogcc_prudhoe_bay@admin.state.ak.us' Subject: RE: 02-09C Sundry Travis, Sorry I am late in my reply. Yes, it is appropriate to rearrange the procedural steps as you propose. You will likely have to allow time for the cement to set prior to the pressure test unless you plan to employ some sort of retainer. Although you don't say a squeeze is necessary, it may be appropriate to bump the cement with a little pressure. That should insure that there are no voids. With the possible tubing compromise is it advisable to test above the cement to 3500 psi? If the tubing fails, then the 9-5/8" and possibly 13-3/8" casing could be exposed to pressures higher than you might desire. Please have the rig supervisor contact the Inspector for possible witness of the plug pressure test. Call or message with any questions. A copy of this message should be available at the rig. Tom Maunder, PE AOGCC '---~-'--'------~~------~'~-- From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Monday, September 24,20074:50 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANe) Subject: FW: 02-09C Sundry ~C~NED SEP 252007 Tom, Do you concur that the changes stated below would be alright with the state? I ,!,,~s unsure if you received my previous email. . Thanks a bunch. -T From: Peltier, Travis M Sent: Friday, September 21, 20079:55 AM 9/24/2007 FW: 02-09C Sundry . . Page 2 of ~ Jfð!)4 To: 'tom_maunder@admin.state.ak.us' Cc: Hobbs, Greg S (ANC) Subject: 02-09C Sundry Tom, I am looking to change my order of operations for the Pre-Rig work listed on the Sundry Application for 02-09C (see pages 4 and 6 of attached Sundry). Upon reviewing the Sundry's pre-rig ops and the current schematic for 02-098, there is no isolation from the top perfs to successfully test the tubing to 3500 psi. I would like to cement the perfs up to 8639' and then test the tubing integrity rather than test the tubing and cement the perfs (see below). Please let me know if this is acceptable. -Travis Peltier (907)564-4511 Current Status: o CI8P at 10690' MD. o CMIT - IAxOA - Passed to 3000 psi (3/19/07) o 1 joint of 5-1/2" tubing corroded 63% @ 4,375' [wall penetration only) (3/5/06) o Fluid in cellar (fresh water) (12/13/05) Pre Rig Operations 1. SLICK: Pull POGLM at 3944' MD. {FORMERLY 2,3,4} 2. COIL: Drift tubing through POGLM at 7080' MD to CIBP at 10,690', if possible. 3. COIL: Lay in 13 bbls of cement from CI8P at 10,690' to the 4-1/2" x 5-1/2" crossover at 8639'. Volume of 2-7/8" from 10,690' to 8724': 0.0058 bpf, 1966' = 11.4 bbls Volume of 4-1/2" from 8724' to 8639': 0.0152 bpf, 85' = 1.3 bbls If unable to tag 10,690' due to fill, adjust cement to adjust for tagged bottom. Squeeze pressure is not required. This plug is for zonal isolation. Wash down cement top to crossover at 8639'. 4. Test tubing to 3500 psi. Test IA and OA to 2000 psi. {FORMERLY 1} Pressure tests are required for competent barrier for rig operations. 5. SLICK: Drift to TOC. Drift tubing to top of POGLM at 7080' for upcoming jet cut. 6. E-LlNE: Jet cut 5-1/2" tubing in the middle of the first full joint above the POGLM at 7080'. 7. Circulate well to seawater through the cut until returns are clean. 8. Bleed casing and annulus pressures to zero. Freeze protect with Diesel to 2200' TVD. 9. Function tubing and casing lDS. Repair/replace as required. 10. Test 9-5/8" casing packoffto 500 psi. 11. Set a 8PV. Remove well house and flow line. Level pad as necessary. 9/24/2007 j:::J ; ~¡ , .~. '!^ . í / ·LJ FRANK H. MURKOWSKI, GOVERNOR AI{ASIiA. OILAlQ) GAS CONSERVATION COMMISSION ' j 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, 02-09B Sundry Number: 306-283 SCANNED AUG 2 92DGB Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced welL Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may 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, o Chairman DATED this "'~ay of August, 2006 EncL ,C11- 10\ 1. Type of Request: p~ T/22jh . c(f9J{fi~OFALASKAhG ~/ð6 ALA OIL AND GAS CONSERVATION COM ZION AUG 1 820U6 APPLICATION FOR SUNDRY APPROV A1H.ska Oil & G 20 MC 25.280 as Cons. rlO. o Suspend 0 Operation Shutdown 0 Perforate 0 Time ExtJm1èørafle o Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Pull Tubing 0 Perforate New Pool 0 Waiver 0 Other NEcrttVÉ ð"~oo(P 181 Abandon o Alter Casing o Change Approved Program ·v., 12> .>.......... Total Depth MD (ft): 11680 Casino Structural Conductor Surface Intermediate Production Liner 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes 181 No 9. Property Designation: 110. KB Elevation (ft): ADL 028308 58' / PRESENTWELLCONDITION SUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): IEffective Depth TVD (ft): 8814 I 10690 I /' 8854 Lenath Size MD '" TVD 4. Current Well Class: / 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 197 -101 ,...-- 6. API Number: / 50-029-20153-02-00 . 8. Well Name and Number: 02-098 .,/ 11. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Plugs (measured): Junk (measured): 10690 None Burst CollaDse Liner 100' 20" 100' 100' 1530 2130' 13-3/8" 2130' 2130' 5380 9021' 9-5/8" 9021' 7915' 6870 870' 7" 8726' - 9596' 7673' - 8406' 8160 2956' 2-7/8" 8724' - 11680' 7671' - 8814' 10570 520 2670 4760 7020 11160 Perforation Depth MD (ft} I Perforation Depth TVD (ft): I 10220' - 10645' / 8857' - 8858' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'SAB' packer Tubing Size: Tubing MD (ft): 8763' /' 13. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 15. Estimated Date for Commencina ODerations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Dave Wesley Title Senior Drilling Engineer Signature /t:£re I(¿:t:..£.s 0.. Phone 564-5153 Date3/Í7!oÞ . (. Tubing Grade: ,/ 5-1/2",17# x 4-1/2",12.6# L-80 / N-80 / I Packers and SSSV MD (ft): 8627' r- 14. Well Class after proposed work: /' o Exploratory 181 Development 0 Service Janua(1 , 'J.007 D~ 16. Well Status after proposed work: o Oil 0 Gas o WAG 0 GINJ o Plugged OWINJ 181 Abandoned o WDSPL Contact Barbara Lasley, 564-5126 Prepared By Name/Number: Terrie Hubble, 564-4628 Commission Use Onlv Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance T-e~t- ~OPE to ~t;oo tO~~. Other: r () I I A,J fJ'ov(d kJY~ to - 4-0 ( I{€£b~d tcr ~QQrvttlK ~{( vz -Co¡ (. I Sundry Number: ~~ . ,.9~.~ Subsequent Form Requ;"'do 10 - ~ ~ ~ Approved By: ( U /t. '1 Form 10-403 Revised 06/2006 0 RIG 1 m L RBDMS BFL AUG 2 4 2006 Ø)z,Z¿ 06 5ubmifín Duplicate APPROVED BY COMMISSIONER THE COMMISSION Date . . Obp GLlJaIIW., To: Winton Aubert - AOGCC Date: August 9, 2006 From: Barbara M. Lasley - BPXA GPB Rotary Drilling Subject: 02-09B Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the P&A of PBU well 02-09B in preparation of a rotary sidetrack. Well 2-09B was sidetracked in August 1997. The well produced at high gas rates and began cycling immediately. The well was moved into the HP system in late 1999 resulting in lower oil and gas rates. Additional perforations were shot in April 2000 with no improvement in production. In February 200 I, a CIBP was set, resulting in a successful gas shut off. An IA x OA communication waiver was granted in November 2002. Additional adperfs in May 2004 and January 2006 resulted in a GOR of 60,000 scflbbl, thus making the well uncompetitive. A March 2006 caliper indicated high tubing corrosion between the POGLM's at 3944' and 7080' md. The well has passed a CMIT IA x OA to 3000 psi indicating good surface casing and tubing integrity. Pre rig operations for well 02-09C include pulling the upper POGLM, cementing the existing perforations, and cutting the tubing above the bottom POGLM. Once the rig moves on, the tubing will be pulled to the cut. The 9-5/8" casing will be cut, pulled, re-run, and cemented to restore production casing integrity. A 9-5/8" whip stock will then be set at -7000 and an 8-112" window will be milled in the 9-5/8" casing at ± 6,950' MD. An 8-112" hole will then be drilled to the top of the Sag River. A T' liner will be ran and cemented back 150' inside the 9-5/8" casing. A 6-1/8" production hole will be drilled, landing in Zone lA. The production hole will be kicked off and drilled with MWD/GR through the build section. A density/neutron tool will be picked up for drilling the lateral section. Approximate TD of the hole section will be 11,581' MD. A 4-1/2", L-80 liner will be run and cemented throughout the production section. The well will be perforated using drill pipe. The completion tubing will be 4-112", 12.6#, L-80. The 02-09C sidetrack is currently scheduled for Nabors 2ES in the first quarter of 2007. The pre-rig work for this sidetrack will be priority scheduled once Sundry approval has been obtained. Estimated Pre-Rig Start: Estimated Spud Date: January 2007 February 2007 Barbara M. Lasley GPB Rotary Drilling Engineer Office: 564-5126 Cell: 240-8044 CC: Well file Terrie Hubble / Sondra Stewman 02-098 Application for Sundry . . 02-09C Operations Summary Current Status: ~ Inner annulus x outer annulus communication. Pre Rie Operations 1. Test tubing to 3500 psi. Test IA and OA to 2000 psi. a. Pressure tests are required for competent barrier for rig operations. 2. COIL: Pull POGLM at 3944' MD. 3. COIL: Drift tU~'g through POGLM at 7080' MD to CIBP at 10,690', if possible. 4. COIL: Lay in3þbls of cement from CIBP at 10,690' to the 4-1/2" x 5-1/2" cros~,ver at 8639'. a. Volue of 2-7/8" from 10,690' to 8724': 0.0058 bpf, 1966' = 11.4 bbls ) f b. Volume of 4-1/2" from 8724' to 8639': 0.0152 bpf, 85' = 1.3 bbls f c. If unable to tag 10,690' due to fill, adjust cement to adjust for tagged bottom. d. Squeeze pressure is not required. This plug is for zonal isolation. e. Wash down cement top to crossover at 8639'. 5. E-LINE: Drift tubing to top ofPOGLM at 7080' for upcoming jet cut. /' 6. E-LINE: Jet cut 5-1/2" tubing in the middle ofthe first full joint above the POGLM at 7080'. 7. Circulate well to seawater through the cut until returns are clean. 8. Bleed casing and annulus pressures to zero. Freeze protect with Diesel to 2200' TVD. 9. Function tubing and casing LDS. Repair/replace as required. 10. Test 9-5/8" casing packoff to 500 psi. 11. Set a BPV. Remove well house and flow line. Level pad as necessary. / / Rie Operations 1. Move in. Rig up Nabors rig 2ES. 2. Pull BPV. Circulate out freeze protection and displace with seawater. 3. Run TWC and test to 1000 psi from above and below. 4. Nipple down ~~~Nipple up BOPE. 5. Test BOPE t~i~Si high, 250 psi low. Pull TWC. / 6. Screw in landing Joint. Unseat and pull 5-1/2" tubing hanger to floor. 7. Circulate the well, surface to surface. Lay down landing joint and hanger. 8. Pull 5-1/2" tbg to cut at -7050' MD. Spool up control line. Count bands and clamps. 9. Pick up and RIH with RTTS to 2100' MD. Find leak point in 9-5/8" casing. POOH, LD RTTS. 10. RU E-line. Run USIT/GR/CCL from cut stub to surface. Drift 9-518" casing to 2300' MD. /' 11. Set F ASDrill 500' below anticipated cut depth. Test 9-5/8" casing to 350ÇÞpsi. RD E-line. 12. Change one set of BOP rams to accommodate 9-5/8" casing. Test. / 13. Make up casing cutter for 9-5/8" casing. RIH to -2000' MD. Cut casing. Circulate to verify cut. 14. Make up the cement line. Circulate annulus clean. POOH, LD casing cuttey 15. Make up spear assembly. Unseat 9-5/8". POOH and LD 9-5/8" casing. 16. Pick up 13-3/8" casing scraper. RIH, ensure casing is clean. POOH. LD scraper assembly. 17. PU washover pipe. RIH, wash over 9-5/8" casing stub. POOH, LD washover assembly. / a. Scraper and washover assembly may be run together. Verify prior to running. 18. PU Baker 9-5/8" 47# backoff assembly, use drill collars as required. RIH. Tag casing stub. 19. Pressure up on drill pipe to break connection. Back off casing. 20. Drop ball and pressure up to open pump out sub. POH and LD backoff assy. 02-098 Application for Sundry . . 21. PU and RIH with Spear assembly. Recover stub. Note if pin or collar is recovered. LD spear assembly. 22. Rig up casing equipment. Run 9-5/8" BTCM casing. Screw in to stub. Test 9-5/8" to 3500 psi. Rig down casing equipment. 23. Split the BOP stack. Install emergency slips. Cut 9-5/8" casing. Im¡tall and test packoff. / 24. Nipple up BOP. Test. Ensure both sets of variables are installed. .I 25. PU and RIH TAM tool. Open port collar and establish circulation. 26. Pump cement sufficient to cover ~P9rt collar to surface. Close and test port collar. POH. a. Cement volume will be~ls, assuming port collar at 2000'. 27. PU 8-1/2" tri-cone bit. Clean out to FASDrill. N) U28. Drill up F ASDrill and push it to tubing stub, picking up singles. POOH. LD BHA/ ~ 29. RU Eline. RIH with EZSV. Set above stub at -7000' MD. POOH. RD Eline. \ 30. Test 9-5/8" casing to 3500 psi for 30 minutes. Chart test. () -31. PU and RIH with whipstock. Orient and set WS at -7000' MD. -- 32. Displace to 9.2 ppg LSND milling fluid. \/> 33. Mill window. Pump a sweep. POOH, LD window milling assembly. 34. PU 8-1/2" drilling BHA. RIH. Drill 20' of formation. Perform an FIT to 12.0 ppg EMW. 35. Drill to TD, increasing mud weight to 10.5 ppg prior to entering the HRZ. 36. At TD, Circulate sweep. Short trip to the window. Circulate sweep. POH and LD BHA. 37. Rig up liner running equipment. Run 7" 26# liner. 38. Circulate bottoms up at the window. Continue in to TD. Circulate hole clean. 39. Cement liner in place. Set liner hanger/packer. Circulate out contaminated mud and cement. POR. LD running tool. 40. MU and RIH with 6-1/8" build BHA to top of liner. Circulate bottoms up. 41. Test 7" liner to 3500 psi for 30 minutes. Chart same. 42. Drill cement and float equipment. Displace well to Flo Pro drilling fluid. Drill 20'. FIT to 10.0 ppg EMW. 43. Drill the build section to soft landing above BSAD. POOH. LD BHA. 44. PU lateral BHA. RIH. MAD Pass in the up direction, capturing 200' of the parent wellbore. 45. Locate the BSAD, drill horizontal section to TD. Circulate sweep. Short trip. Circulate sweep. POOH, LD BHA. 46. PU and MU 4-1/2" liner. RIH with 4-1/2" liner on DP. 47. Circulate liner at TD. Cement liner in place. Set liner hanger/packer. POH, LD excess DP. 48. MU and RIH with perf guns on 2-7/8" PAC and 4" DP. Perforate overbalance. Pull up to top of liner. Monitor well. Continue to POOH. LD 2-7/8" PAC and 4" DP. 49. RU to run tubing. Make dummy run with the tubing hanger. Run 4-1/2" L-80 completion. Space out and land tubing. Reverse in corrosion inhibited brine. 50. Set packer. Individually test the tubing and annulus to 3500 psi for 30 minutes. 51. Nipple down the BOPE. Nipple up the tree. 52. Freeze protect the well to 2200' TVD. Install BPV. 53. RDMO. Release rig . ~ ~ ~ -l \- Post Ril! Operations 1. Pull the ball and rod 1 RHC plug. 2. Install gas lift valves 3. Install well house and instrumentation. 4. No "S" riser modifications will be required. 02-098 Application for Sundry TREE = WELLHEAD = ACTUA TOR = KB. EL:EV =' BF. EL KOP Max Datu Datu FMC FMC AXELSON 58' . 02-098 S TES: TWO 5-1/2" POGLM's. 2-7/8" CIBP SET @ 10690' CTMD ON 2/25/01. BTM 3 PERF INTERVALS ISOLATED. ***IAxOA COMM. OPERATING PRESSUREOFTHE9 5/8" ANNULUS AND 13 3/8" 3 EV= ? - - = ? ANNULUS MUST NOT EXCEED 1000 PSI (12/10105 Angle = 100 @ 10853' W AlVER)*** mMD= 10227' mlVD= 8800' SS 113-3/8" CSG, 72#, MN-80, ID = 12.347" 2130' I ~ . II.. 2220' H 5-1/2" OTIS RQM SSSV NIP, ID = 4.562" I GAS LIFT MANDRELS U ST MD lVD DEV TYÆ VLV LATCH PORT DATE imum ID = 2.340" @ 3944' & 7080' 1 3944 3902 27 POGLM DMY BK 0 12/06/03 /2" POGLM 2 7080 6490 35 POGLM DMY BK 0 11/07/02 I I 8507' H 5-1/2" OTIS SLIDING SLV, ID =4.562" I f ~ 8607' H 5-1/2" BOT PBR ASSY I I 8: ~ 8627' H 9-5/8" X 5-1/2" BAKER SAB PKR I - /2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" H 8639' I H 5-1/2" X 4-1/2" XO, ID = 3.958" I TOPOF4-1/2"TBG-PC H I 8639' 8639' I . 8702' H 4-1/2" OTIS XN NIP, ID = 3.725" . TOPOF 3-1/2" LNR I 8724' 8724' 1-1 3-1/2" G SEAL SUB, ID - 2.917" I 1 TOP OF 7" LNR H 8726' r-. . -1/2" LNR, 9.3#, L-80, ? bpf, ID = 2.992" H 8728' I H 3-1/2" X2-7/8" XO, ID - 2.377" I 8728' 1 TOP OF 2-7/8" LNR H 8728' I 8762' 4-1/2" BAKER SHEA ROUT SUB (BEHIND LNR) "TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" I 8763' 8763' 4-1/2" TUBING TAIL (BEHIND LNR) I I 8777' H ELMD LOGGED 02/10/80 I I 9-5/8" CSG, 47#, N-80, ID = 8.681" I 9021' -µ ~ I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 9596' ~ .. 9596' H 7" MILLED WINDOW TOP I ~ ÆRFORA TION SUMMARY REF LOG: BHCS ON 06/06/75 ANGLE AT TOP ÆRF: 77 @ 10220' ~ Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE J 1-11/16" 4 10220 - 10240 0 04/19/00 2" 6 10254 - 10294 0 05/17/04 I 10690 CTMD H 2-7/8" HES MODEL M CIBP I E::::! 2-1/8" 4 10297 - 10499 0 08/16/97 0 1-11/16" 4 10453 - 10499 0 08/17/97 1-11/16" 4 10620 - 10645 0 08/17/97 ~ 1-11/16" 4 10782 - 10995 C 08/18/97 2-1/8" 4 11075 - 11254 C 08/16/97 2-1/8" 4 11322 - 11615 C 08/16/97 : 11616' H 2-7/8" LANDING COLLAR I -7/8" LNR, 6.5#, L-80, .0058 bpf, ID 2.441" 1- 11678' ...111I ... 11678' 2-7/8" DAVIS LYNCH BULLEr ~- 11680' 5ðð NOSE FLOA T SHOE Min 5-1 15-1 14-1/2 2 DATE 1997 08/19/99 04/02/01 11/16/02 01/01/03 08/18/03 REV BY COMMENTS ORIGINAL COM PLETION WORKOVER CHlKAK CORRECTIONS JRC/KK WArvER SAFETY NOTE JM'KAK GLV C/O CMOITLP DATUM MD CORRECTION DATE 12/06/03 05/17/04 12/21/05 REV BY COMMENTS DTRlTLP GL V C/O KEY /KAK ADPERFS COM'PAG WArvERSAFETY NOTE PRUDHOE BAY UNrr WELL: 02-09B PERMrr No: "1971010 API No: 50-029-20153-02 SEC 36, T11N, R14E, 1216' FNL & 971' FWL BP Exploration (Alaska) TREE = WELLHËArJ - ACTUATOR = KB. El:EV = BF. ELEV = KOP= Max Angle = Datum MO = Datum lVO = . FMC FMC AXELSON 58' ? ? 100 @ 10853' 10227' 8800' SS 13-3/8" CSG. 7 , 7" LNR, 26#, L-80, .0382 bpf, 10 = 6.276" H 6800' I Whipstock EZSV I A'e Rig Jet Cut I 5-1/2" Otis Sliding Sleeve, 10 = 4.562"1 8507' I 5-1/2" BOT PBR AsserrblyH 8607' I 9-5/8" x 5-1/2" Baker SAB Packerl 8627' I 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892" H TOPOF 4-1/2" TBG-PC 1 4-112" Otis XN Nipple, 10 = 3.725"1-1 3-112.' Lf\R 9.3#, L -m, D=2~' ~ 9-518" CSG, 47#, N-80, 10 = 8.681" H 9021' 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" I 2-7/8" LNR, 6.5#, L-80, .0058 bpf, 10 = 2.441" I ~ DATE 1997 08119199 04/02/01 11/16/02 01/01/03 08/18/03 REV BY COMMENTS ORIGINAL COM PLETION WORKOVER CHlKAK CORRECTIONS JRClKK WAr'¡ER SAFETY NOTE JMlKAK GLV C/O CMOITLP DATUM MD CORRECTION DATE 12/06/03 05/17/04 12/21/05 07/31/06 . 02-09C Proposed 2000' -i X' Nipple I Min" ID = 3"275" @ 8985' XN nipple 4-1!2'm 12EW, L-ID, .0152tµ, D=3g:ß' XN¡:pe 7' x 4-1/2" S3 R:cIa' û x N¡:pe m N¡:pe 4-1/2" Uner tq:> 7' L -00, 26#. 0=6.276' 4-1/2" L-BO, 12.6#, 0=3.958" 110690 CTMD H 2-7/8" HES MODEL M CIBP I 11616' -i 2-7/8" LANDING COLLAR I 11678' 11680' 11678' 2-7/8" DAVIS LYNCH BULLET NOSE FLOA T SHOE REV BY COMMENTS DTRlTLP GL V C/O KEY /KAK ADÆRFS COMlPAG WAr'¡ER SAFETY NOTE BML Proposed Schematic PRUDHOE BAY UNIT WELL: 02-09C Proposed PERMIT No: 11'1971010 API No: 50-029-20153-03 SEC 36, T11 N, R14E, 1216' FNL & 971' FWL BP Exploration (Alaska) FRLIJI-Œ ßll,Y, PR!JIJ!-Œ OL PEUJ)S2 5 10 10' 105 10' 10' 10' \ 10 02-098 -- 01 Rate (a:J) (bb!/d) - WIler Rate (a:J) ( bb!/d ) GasRate (a:J) (Wid) CJm 01 Prod (M:¡b ) Gasl 01 Rimo ( cribb! ) WJterCJt ( %) \ 10' 98 99 ~e > < 02..o9B 1ŒJ:J u "" .0 .0 Õ 2- '" ro 0:: õ 01 Cæe1 o O.32ß553 A e. 5i'\14æ ttIId 12'311:n12 C12!'Æ/2fœ æ æ Cf1 œ 04 01 2íJXJ A1æe Cæe Nmle Di te fuj REte Fm REte o.m FiOO. 1578, æ Mti Dâe 05'3iI2fœ æ.348Mti 8.JR 1898.31 Mti FC1I13CaSt Efd€d8'¡l REte FC1I13CaSt Dâe 1997 æ 99 100 _ STATE OF ALASKA _ ALA" OIL AND GAS CONSERVATION cOMrvW310N REPORT OF SUNDRY WELL OPERATIONS D D o 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 58 KB 8. Property Designation: ADL-028308 11. Present Well Condition Summary: Total Depth measured 11680 true vertical 8813.9 Effective Depth measured 11616 true vertical 8815.74 Casing Conductor Surface Production Liner Liner Liner Length 80 2109 9001 870 4 2950 Size 20" 94# H-40 13-3/8" 72# MN-80 9-5/8" 47# N-80 7" 29# L-80 3-1/2" 9.3# L-80 2-7/8" 6.5# L-80 Perforation depth: Measured depth: 10220 - 10240 True Vertical depth: 8856.64 - 8860.65 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 527 530 x RECEIVED MAR 1 4 2006 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development ;;ï Stratigraphic [J Stimulate D & Gas r.OR G .. Waiver D Time Extension D Anchor 8. Of"'""S n Re-enter Suspended Well D age 5. Permit to Drill Number: 197-1010 [J 6. API Number: 50-029-20153-02-00 9. Well Name and Number: Exploratory Service 02-09B 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool feet Plugs (measured) 10690 CTMD feet Junk (measured) None feet feet MD TVD Burst Collapse 22 - 102 22 - 102 1530 520 21 - 2130 21 - 2129.98 5380 2670 20 - 9021 20 - 7914.97 6870 4760 8726 - 9596 7672.51 - 8405.69 8160 7020 8724 - 8728 7670.91 - 7674.11 10160 10530 8728 - 11678 7674.11 - 8814.03 10570 11160 10254 - 10499 10620 - 10645 10782 -11615 Closed 8863.37 - 8864.57 8859.59 - 8858.04 8842.56 - 8815.73 5-1/2" 17# L-80 18 - 8639 4-1/2" 12.6# L-80 8639 - 8763 5-1/2" Baker SAB Packer 8627 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 31331 0 920 31377 0 350 15. Well Class after proposed work: Exploratory Development ¡;¡¡ 16. Well Status after proposed work: Oil ;;ï¡ Gas [J WAG Tubing pressure 449 562 Service WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal P,'o'ed Nam, Sh.,ma'" V"tal < / ' Signatur~ ~ Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 Date 3/13/2006 Submit Original Only e e 02-098 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDA TE I SUMMARY 1/31/2006 CTU #8, Perf with iCoil; '" Cont' from WSR 01/30/2006... Warm up unit and MU tools: iCoil head, BKR 2-1/8" MHA, 20' of 2" PJ HMX guns. RIH, correct to flag (did not use iCoil cel) and perforate interval 1 0196'- 10216'. POOH. At surface, all shots fired. RD tools / unit and head back to shop. DSO notified of well status. *** Job Complete *** FLUIDS PUMPED BBLS 50 I ~~:AL 50 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator ( STATE OF ALASKA ( "'''1~,t~''''U:,i~''\)E, r\JE.,,:r)V, ~ ,> ~,a.'" ill \¡ j/ ¡~ ALASKA OIL AND GAS CONSERVATION COMMISSION f\,~..,ò<~""li~,=.,;:1 .~= . REPORT OF SUNDRY WELL OPERATIONSJL 1 ~I 2004 Repair WellO PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate [K) 4. Current Well Class: ~ I ,~ n' ;~'l '¡-.,'~:;, t, íJ\ HI; Stimulate D :','ÜSlt3. bthêr~:r'~L WaiverD Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 197-1010 Name: BP Exploration (Alaska), Inc. Development Œ] Exploratory D ServiceD 6. API Number 50-029-20153-02-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 58.00 8. Property Designation: ADL-0028308 11. Present Well Condition Summary: Total Depth Stratigraphic D 9. Well Name and Number: 02-09B 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool measured 11680 feet None Effective Depth true vertical 8813.9 feet None measured 10708 feet true vertical 8852.8 feet Casing Conductor Liner Liner Liner Production Surface Length 80 4 870 2950 9001 2109 Perforation deDth: Plugs (measured) Junk (measured) Size 20" 94# H-40 3.1/2" 9.3# L-80 7" 29# L-80 2-718" 6.5# L-80 9-5/8" 47# N-80 13-3/8" 72# M N.80 MD TVD Burst Collapse 22 - 102 22.0 - 102.0 1530 520 8724 - 8728 7670.9 - 7674.1 10160 10530 8726 - 9596 7672.5 - 8405.7 8160 7020 8728 - 11678 7674.1 - 8814.0 10570 11160 20 - 9021 20.0 - 7915.0 6870 4760 21 - 2130 21.0 - 2130.0 5380 2670 Measured depth: 10254 -10294,10297 -10453,10453 -10499,10620 -10645 True vertical depth: 8863.37 - 8869.58, 8869.82 - 8865.5, 8865.5 - 8864.57, 8859.59 - 8858.04 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 4-1/2" 12.6# L-80 Packers & SSSV (type & measured depth): 5-1/2" Baker SAB Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 20.5 4 230 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - @ 18 @ 8639 @ 8627 8639 8763 Oil-Bbl 494 Tubing Pressure 389 323 467 20.8 4 250 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: OilŒ] GasD Development ŒJ ServiceD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: NIA Daily Report of Well Operations. X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Garry Catron Garry Catron )1~~ Contact Printed Name Signature Form 10-404 Revised 4/2004 Title Production Technical Assistant Phone 564-4657 Date 7/7/04 OR\G\NAL ,'fØ)MS BFl JUlll3 20M ( ( 02-098 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/17104 MEM LOG 1 ADPERF. CTU #5. CONTINUED FROM 5/16/04 WSR. RIH WITH PDS MEM GRICCL IN 2.2" CARRIER TO 104751 CTMD. LOG UP FROM 10450. TO 10000'. FLAG PIPE AT 102251. POOH. TIE LOG INTO SWS MCNL DATED 9/14/2000. MAKE 121 CORRECTION. MU AND RIH WITH 2 - 201 X 211 6SPF, 2006PJ TCP GUNS. CORRECT TO TOP SHOT AT FLAG. RIH SHOOT INTERVAL 10,2541 - 10,2941. ALL SHOTS FIRED. NOTIFIED DSO OF WELL STATUS. RD. «< JOB COMPLETE «< FLUIDS PUMPED' BBLS 77 77 50/50 Methanal TOTAL Page 1 ~ TREE = FWC WELLHEA 0 = FWC ACTUA. TOR = AXELSON KB. B..EV = 58' BF. B..EV = --_? KOP= .. --~? tv1ax Angle = 100 @ 10853' Datum MJ = 10ni Datum TVD = 8800' SS 113-3/8" CSG, 72#, WN-80. D = 12.347' H 2130' ~ Minimum ID = 2.340" @ 3944' & 7080' 5-1/2" POGLM 02-098 . L ( SAFETY NOTES: TWO 5-1/2" POGLM's. 2-7/8" ClSP SET@ 10690' CTMD ON 2/25/01. BTM 3 PERF INTERVALS ISOLATED. ***IA X OA COMM. OPERAT1NG PRESSUREOFTHE 9-5/8" ANNULUS AND 13-3/8" ANNULUS MUST NOT EXCEED 2000 PSI (11/16/02 WAIVER}*** ~ I 2220' H 5-1/2" 011S RQM SSSV NIP. 10 = 4.562" I GAS LIFT MANDRELS ST MD lVD DEV lYPE VLV LATŒi PORr DATE '1 3944 3902 27 POGLM D\1Y BK 12/06/03 2 7080 6490 35 POGLM D\1Y BK 11/07/02 8507 l-i 5-1/2"OTISSLlDINGSLV, 10=4.562" I r I 1 8607 1-1 5-1/2" BOT PBR ASSY 1 g :&0 1 8627 H 9-5/8" X 5-1/2" BAKER SAB PKR 1 15-1/2" TBG-FC, 17#. L-80, .0232 bpf,lD =4.892" 1-1 8639' I 1 1-1 5-1/2" X 4-1/2" XO, 10= 3.958" 1 ITOPOF 4-1/2" TBG-PC l-i 1 ~ ¡ 8639' 8639' 1 8702' 1-1 4-1/2" OTIS XN NP, 10 = 3.725" 1 ITOP OF 3-1/2" LNR l-i 8724' I bi Z, 1 8724' 1-1 3-1/2" G SEAL SLB, 10 =2.917" I 1 TOP OF 7" LNR l-i 8726' 1 :1 . 3-1/2" LNR, 9.3#, L-80, -_? bpf, 10 = 2.992" H 8728' 1 1 H 3-1/2" X 2-7/8" XO, 10 = 2.377" I "\0, ~ 8728' ITOPOF 2-7/8" LNR 1-1 8728' 1 8762' H4-1/2" BAKER SHEAROUT SUB (BEHIND LNR) 1 14-1(2" TBG-PC, 12.6#, N-80, .0152 bpf,lD =3.958" 1-1 8763' 1 ,I " 1 8763' H 4-1/2" lUBING TAIL (BEHIND LNR) 1 8777' H ELMO LOGGED 02/1 0/80 1 9-5/8" CSG, 47#, N-80, 10 = 8.681" 1-1 ~ .. ' 9021' 1 ?' LNR, 29#, L-80, .0371 bpf, 10 = 6.184" 1-1 9596' ~ ... 1 9596' 1-1 7" MLLED WINDOW TOP I rï PERFORATION SUMMA RY REF LOG: BHCS ON 06/06/75 ANGLEATTOPPERF: 77@ 10220' I'bte: Refer to A'oduction DB for historieal perf data SIZE SFF INTERVAL Opn/Sqz DA TE 1-11/16" 4 10220- 10240 0 04/19/00 2" 6 10254 - 10294 0 05/17/04 2-1/8" 4 10297 - 10499 0 08/16/97 1-11116" 4 10453- 10499 0 08/17/97 1-11/16" 4 10620 - 10645 0 08/17/97 1-11/16" 4 10782- 10995 C 08/18/97 2-1/8" 4 11075 - 11254 C 08/16/97 2-1/8" 4 11322-11615 C 08/16/97 2-7/8" LNR, 6.5#, L-80, .0058 bpf, 10 = 2.441" H 11678' 1 ITD 1-1 11680' 1 DATE 1997 08/19/99 04/02/01 11/16/02 01/01/03 08118/03 COMMENTS ORIGINAL COMPLETION WORKOVER Œi/KA K CORREC110NS JRC/KK WAIVER SAFETY NOTE JM'KAK GLV CiO CMO/1l...P DATUM MD CORRECfION REV BY 110690 CTM D 1-1 2-7/8" HES MODB.. M CIBP 1 1 11616' 1-1 2-7/8" LANDING COLLAR 1 1 11678' H2-7/8"DAVISLYNCHBLLLET I . I NOSE FLOA T Sf-OE DA TE REV BY COMMENTS 11/27/03 A TDTLP ADD C/O DATE TO ST A #2 12/06/03 DTRlTLP GL V C/O 05/17/04 KEYiKAK ADPERFS PRUDf-OEBAY UNIT WELL: 02-09B PERMT I'b: 1971010 APII'b: 50-029-20153-02 SEC 36, T11 N, R14E, 1216' FNL & 971' FWL BP Exploration (Alaska) MEMORANDUM TO: Mike Bill Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 26, 2002 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~, ~-~ ~z~,~ j BPXA Petroleum Engineer/,~) (t,~,,~--zJ DS-2 2-09 / Category B3 well FROM: Jeff Jones Prudhoe Bay Field / PBU Petroleum Inspector NON- CONFIDENTIAL Wellhead Component Type Pretest Initial 15 Min. 30 Min. WellI 2-09I Tubing Hanger Packoff 0 5200 5275 5350 P/F I P PTD~ 197-101I Type test I PPPOT Tubing 0 0 0 0 Interval. _~ IA 40 40 40 40 OA 40 40 40 40 Notes: FMC Generation I well head diagnostic PPPOT. Wellhead Component Type Pretest Initial 15 Min. 30 Min. WellI 2-09 Inner Casing Hanger Packoff 0 3220 3025 3025 P/F I P P.T.D.I 197-101 Type test I PPPOT Tubing 0 0 0 0 Interval, ~ IA 4O 4O 4O 4O OA 4O 4O 40 4O Notes: FMC Generation I well head diagnostic PPPOT. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details November 26, 2002: I traveled to BPXA's Prudhoe Bay Field DS-2 to witness a diagnostic Positive Pressure PackoffTest (PPPOT) on BPXA designated category B3 well 2-09. Jerry Cox was the BPXA representative for the tests today. I arrived at the scheduled test time to find the well shut in and a heater thawing the SSV so it could be opened to record tubing pressures during the test. Once the SSV was opened, Mr. Cox performed the tests in a safe and proficient manner according to DHD procedures, with both packoffs passing the pressure test. The increase in tubing hanger pressures recorded above may be due to expansion of the cold hydraulic test fluid (ambient 15 deg. F) in the well head packoffvoid that was heated while thawing the SSV. I monitored the tubing hanger packoffpressures an additional 15 minutes and noted stabilization at 5350 PSI. Summary: I witnessed a diagnostic PPPOT on BPXA's Pmdhoe Bay Field category B3 oil production well 2-09. M.I.T.'s performed: Attachments: Number of Failures: 0 Total Time during tests: _3 cc: MIT report form 5/12/00 L.G. PPPOT PBU 2-09 11-26-02 JJ.xls 12/16/2002 S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission THRU: Tom Maunder /~ ~,~/'~ P.I. Supervisor TO: Mike Bill ~.v~ DATE: December 27, 2002 Commissioner SUBJECT: Mechanical Integrity Tests BPX PBU DS 2-09B FROM: John Crisp Producer Class 137 B-3 Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 2-09B Type lnj.I N/A T.V.D. 7595 Tubing] 160 160 I 160 I 160 I Interval O P.T.D. 1971010 ITypetestl P ITestpsi] 3000 ICasingI 60 I 30401 29801 29501 P/F I -P Notes: Combo MIT Waivered Well Notes: Notes: Well P.T.D. Notes: P.T.D. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 1 Attachments: Number of Failures: Total Time during tests: 3 hrs. cc.' SCANNED FEB 0 4 2003 MIT report form 5/12/00 L.G. PMIT BPX PBU 2-09B 12-27-02 JC.xls 1/19/2003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner ~' T°m Maunder, P. !. Supervisor DATE: May 1, 2001 FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector SVS Tests Misc. EOA Prudhoe Bay Field Tuesday, May .1., 2001; i witnessed four misc. SVS tests on BPX in the Eastern Operating Area of the Prudhoe Bay Field. Bill Preston performed the SVS tests today. The test results (No Failures) are noted on the accompanied SVS test spreadsheets. All well houses were in "OK" condition. The pads were clean and in good condition. SUMMARY: I witnessed four misc. SVS tests in the Prudhoe Bay Field. 4 wells, 8 components, No failures. Attachmen,ts: SVS PBU DS-5 5-1-01 LG.XLS SVS PBU DS-2 5-1-01 LG.XLS SVS PBU DS-18 5-1-01 LG.XLS NON-CONFIDENTIAL SVS PBU EOA misc 5.1-01 LG1 Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Lou Grimaldi Submitted By: Lou Grimaldi Field/Unit/Pad: Prudhoe Bay, DS-2 Separator psi: LPS Date: 5/1/01 HPS 585 WeB Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE , 02-0lB 1971400 02-02A 1971680 02-03A 1951780 02-04A 1961580 02-05 1700500 02-06A 1961380 02-07A 1981070 , 02-08B 1980950 02-09B 1971010 585 600 600 P P OIL 02-10B 2000640 02-1lA 1981260 02-12A 1951650 02-13A 1941650 02-14 1800180: , 02-15A 1960420 02-16A 1931160 02-17A 1961450 02-18A 1950890 02-19 1811860 02-20 1820290 02-21 1820450 02-22A 2000590 02-23A 2000530 02-24 1820710 02-25 1820960 02-26B 2001220 02-27A 1990930 02-28 1900220 02-29A 1900210 02-30B 2001260 02-31A 1990150 ~02-33A 2001230 , 02-34A 1982380 02-35A 1970960 02-36 1980700 02-37 1961750 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GI~TJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 02-39 1961820 Wells: 1 Components: 2 Failures: 0 Failure Rate: 0.00% [3 90 Day Remarks: Cycle Well RJF 1/16/01 Page 2 of 2 SVS PBU DS-2 5-1-01 LG Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep:'B~ll'Prest~ ' ' ' AOGCC Rep: Lou Grimaldi Submitted By: Lou Gfimaldi Field/Unit~ad: Prudhoe ,Bay, DS-5 Separator psi: LPS Date: 5/1/01 HPS 585 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI T~p Code Code Code Passed GAS or CYCLE 05-01C 1990280 , 05-02 1740360 05-03B 1941000 , ,, 05-03C 2000940 05-04A 1960890 ' ' ' 05-05B 1961800 05-06A 1950840 585 600 600 P P ' ' 0IL , ~05-07 1770130 !05-08 1770240~ 05-09A 1990140 ..... 05-10B 196'i500 , , 05-1lA 1960970 , ,1 05-12A 1982600 05-13A 1940420 ' ' 05-14A 1930820 ~ ....... , 05-15B 1960230 ' , , 05-16B 1991000 , 05-17B 1981040 05-18A 1981740 , , , ,, ~05-19 1890780 ,, 05-20A 1971790: ~5-21A 1981180 05'22A 2001580 05-23 '1890790 ' " , 05-24 1911050 ,, 05-25B 2001470 ,, 05-26 1891130 05'27A 1961030 ' t, ,, ~05-28 1911100 05-30 1911150 , 05-31A 1982070 05-32 1910890 05-33A 2000920 " ' , ~ ,, 05-34 1911210 05-35 1910680 05-36 1910780 585 600 500 P P OIL , 0:5°~ ....... ~/~n/. )11961850, .oo-'==~_ _1 nq9~_ _ . .Ixlq Drill I'~Q .g q_l_nl I G Weft Pemit Separ Set L~ Test Test Test Date off, WAG, amJ, Number Number PSI PSI Trip Code Code Code Passed GASorCY~ 05-39 1961730~ 05-40' 1961590 ........ , , Wells: 2 Components: 4 Failures: 0 Failure Rate: 0.00% Fl oo oar Remarks: C, ycle wells RJF 1/16/01 Page 2 of 2 SVS PBU DS-5 5-1-01 LG Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Lou CTrimaldi Submitted By: Lou Grimaldi Field/Unit/Pad: Pmd~, o.e Bay, DS- 18 Separator psi: LPS 160_ Date: 5/1/01 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GllNJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 18-0lA 1960100 , , 18-02A 1950300 18-03A 1941020 18-04A 1980280 18'05 1860800 18'06A 19724q0 18-07A 2000140 . 18-08A 1980040 1'8-091~ "1980'~90 160 15b 150 P p OIL: 18-10A 1950600 , ,, 18-11D 1870870 18-i2A 1971230 18-13A 1972230 , 18-14A 1950070 18-15B 1970720 18_16B " 1970990 " i8_17 .... 11}71200 '' i18-18A 1950140 , 18-19 1860940 , ,, 18-20 1881410 , 18-21A 1961980 18-22A 1990500 , , , 18-23A 1931410 18-24A 1950330 , , . , , , , 18-25A 1970980 , , , , , , , ,, 18-26A 1971940 18-27C 2001540 18-28 1950740 18-29B 1980690 .... i8-30 19509i0 .... 18-31 1951090 i8-32 ' 1951240 ..... 18-33 1951430 " , , 18-34 1951640 L2-03A 1980620! ' , , L2-07 1981650 ~ , L2o0a~4/~ n/~ 1981400 ~ ill, SE. SSS.V-- .;!i~ Retest. i~ "Well T,ype~i Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE L2-11 1980960 L2-13A 1980780i L2-18A 1981060i Wells: 1 Components: 2 Failures: 0 Failure Rate: 0.00% Fi 9o var Remarks: Cycle well RJF 1/16/01 Page 2 of 2 SVS PBU DS-18 5-1-01 LG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPOFIT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing_ Repair well _ Other_X (ClBP) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1213' FNL, 4308' FEL, Sec. 36, T11N, R14E, UM At top of productive interval 3762' FNL, 1495' FEL, Sec.25, T11N, R14E, UM At effective depth At total depth 2453' FNL, 747' FEL, Sec. 25, T11N, R14E, UM 5. Type of Well: Development __X Exploratow__ Stratigraphic~ Service__ (asp's 687729, 5949988) (asp's 690472, 690472) (asp's 691186, 5954118) 6. Datum elevation (DF or KB feet) RKB 58 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 02o09B 9. Permit number / approval number 197-101 10. APl number 50-029-20153-02 11. Field/-Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 100' Surface 2072' Production 8963' Liner 880' Liner 2956' 11680 feet Plugs (measured) 8814 feet 10690 feet Junk (measured) 8854 feet ClBP set @ 10690' MD on 2/24/2001. Size Cemented Measured Depth True vertical Depth 20" 300 Sx PF II 100' 100' 13-3/8" 5700 sx PF II 2130' 2130' 9-5/8" 750 Sx Class G 9021' 7915' 7" 109o sx Class G 9606' 8414' 2-7/8" 23 bbls I_ARC 11680' 8814' Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) measured 10220' - 10240'; 10297' - 10500'; 10620' - 10644'; (Isolated below ClBP include 10782'-10995'; 11075'-11255';[6 [ I¥[ D true vertical 8857' - 8861'; 8870' - 8864'; 8860' - 8858'; (Isolated below CIBP include 8842' - 8815'; 8815'-8815'; 8817'-8816'). MAR 2.001 5-1/2", 17#, L-80 PCT @ 8639' MD; 4-1/2", 12.6#, N-80 PCT @ 8763' MD. Alaska 0il & Gas ,.,~ns. O0rllnlissJor~ 9-5/8" X 5-1/2" BAKER SAB PACKER @ 8627' MD. Arlctierage 5-1/2" OTIS RQM SSSV @ 2220' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 2/16/2001 Subsequent to operation 3/26/2001 OiI-Bbl 962 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 23786 0 701 818 0 Casing Pressure Tubing Pressure - 2011 204 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedBrian Carlson ~~'~' ~~ ~ Title BP DS 2 Surveillance Engineer Date March 28 2001 Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 02-09B DESCRIPTION OF WORK COMPLETED SET CAST IRON BRIDGE PLUG FOR GAS SHUT OFF Date Event Summary 2/18/2001' 2/24/2001' 2/25/2001- 3/02/2001. 3/03/2001. 3/22/2001' RIH & drifted to 11250' SLM (HAW). A CIBP placement for GSO was performed as follows: MIRU CTU. PT'd equip. Liquid packed well w/1% KCL Water, followed by Crude. RIH w/CT & tagged PBTD @ 11610' CTM. POOH w/CT. RIH w/2-7/8" Model M (::;IBP & set it in the horzontal liner @ 10690' CTM to isolate the following open perforations: 10782'- 10995' MD (Zone 1) Reference Log: BPNL 1/22/1998. 11075' - 11255' MD (Zone 1) 11332' - 11615' MD (Zone 1) PUH & retagged CIBP. POOH w/setting tool. RD CTU. Set GLV's. Set GLV's. Performed N2 lift to initiate flow. Placed well BOL @ 1104 hrs. Performed a valid welltest. Note: Oil rate decreased by 261 BOPD but the decrease in gas rate provided an incremental rate benefit of 784 BOPD, resulting in a NOB of 523 BOPD. Page 1 TI-~, MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2'001 M PL ATE IA L U N D TH IS M ARK ER W E R C:LOKI~IFILM.DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1213' FNL, 4308' FEL, Sec. 36, T11N, R14E, UM At top of productive interval 3762' FNL, 1495' FEL, Sec.25, T11N, R14E, UM At effective depth At total depth 2453' FNL, 747' FEL, Sec. 25, T11 N, R14E, UM Perforate _X Other_ 5. Type of Well: Development __X Explorato~.__ Stratigraphic_ Service__ (asp's 687729, 5949988) (asp's 690472, 690472) (asp's 691186, 5954118) 6. Datum elevation (DF or KB feet) RKB 58 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 02-09B 9. Permit number / approval number 197-101 10. APl number 50-029-20153-02 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 100' Surface 2072' Production 8963' Liner 880' Liner 2956' 11680 feet Plugs(measured) PBTD Tagged @ 11615' MD on 8/19/1997. 8814 feet 11615 feet Junk(measured) ORI¢II !/ L 8860 feet Size Cemented Measured Depth True vertical Depth 20" 300 sx PF II 100' 100' 13-3/8" 57oo sx PF II 2130' 2130' 9-5/8" 750 Sx C~ass G 9021' 7915' 7" 109o sx Class G 9606' 8414' 2-7/8" 23 bbls LARC 11680' 8814' Perforation depth: measured 10220'-10240'; 10297'-10500'; 10620'-10644'; 10782'-10995'; 11075'-11255'; 11322'-11615'. true vertical 8857' - 8861'; 8870' - 8864'; 8860' - 8858'; 8842' - 8815'; 8815' - 8815'; 8817' - 8816'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 8639' MD; 4-1/2", 12.6#, N-80 PCT @ 8763' MD. Packers & SSSV (type & measured depth) 9-5/8" x 5.1/2" BAKER SAD PACKER @ 8627' MD. 5-1/2" OTIS RQM SSSV @ 2220' MD. 05 200 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiFBbl 973 898 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 24629 0 24674 0 Casing Pressure Tubing Pmssum 2034 2O53 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedErin Oba ,y~,_~~_ . ,' ~ Title ARCO EngineeringSupervisor Date Z/I' .. ~ '7- 2 00(~ Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 02-09B DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 4/19/2000: 4/20/2000: MIRU CTU#5. PT'd equip to 4000 psi. RIH w/PDS Memory logging tools & logged well for tie-in f/10800' - 10242' MD. POOH. RIH w/ Coiled Tubing conveyed perf guns & shot 20' of Add Perforations as follows: 10220' - 10240' MD (Zone lB) Reference Log: BPNL 1/22/1998. All shots @ 4 SPF, underbalanced press, & random orientation. POOH w/TCP guns. ASF. RD CTU. Placed well on production. Performed a valid welltest. AOGCC Geological Materials Inventory ¢J3 flexo ......... PERMIT 97-101 Dat~ 8121 ~P~¥ ~R 8122 , ~S-PERRY GR PB 1 8395 ~HLUM TDTP MWD SRVY ¢~PE~Y 9500-10342 PB1 MWD SR~ ~E~Y 10050.40-11680 NGP-MD ~3-10342 PB1 NGP-*VD ~}1-8822 PB1 NGP-TVD ~}1-8755 TDTP ~0-11600 ti ZZ/q'~ Are d~ ditch samples required? yes ~no Was the well cored? yes~ no Are tests required? yes ~no Well is in compliance ~ Initial Comments ARCO Sent Recieved Box 9/26/97 9/26/97 9/26/97 9/26/97 5/27/98 6/11/98 9/10/97 9/17/97 9/10/97 9/17/97 10/1/97 10/1/97 l 0/1/97 10/1/97 10/1/97 10/1/97 10/1/97 10/1/97 5/27/98 6/11/98 T C)b~t7 And r eceh,e4~-__y.~s- ........... no Analysis description recieved? ........ ~rt's~~'-no Received? ~ ...... ~ Tuesday, August 31, 1999 Page 1 of I GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11203 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 5/27/98 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL RF Sepia Disk Tape D.S. 2-09B 98236 TDTP -~-- ~,~-- 980122 I I 1 D.S. 7-11A 98231 TDTPBORAX-t~ ~ ~'~'~,~"~ 980106 1 I 1 ,i __ SIGNED DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 't' Status of Well Classification of Service Well OiI_X Gas._. Suspended__ AbandonS.._ Service___ 2 Name of Ol~erator 7 Permit Number ARCO Alaska, Inc. 97-101 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20153-02 4 ~-ocation o'f well at surface ~ i!'il,: ~!::! ",~ '~ ' 9 Unit or Lease Name 1216' FNL, 971' FWL, Sec 36, T11 N, R14E, UM. ~ ~, . ...., PRUDHOE BAY UNIT At Total Depth - .-~ -7 ~ '11 Field and Pool 2453' FNL, 747' FEL, Sec 25, T11 N, R14E, UM. ~ ................. ~ ........ PRUDHOE BAY FIELD ..... 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 58' RKB ADL 28308 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date ~-.D. Reached ' 14 Date Comp. i Susp., or Aband. 115 Water Depth, if offshore 1~ No. of Completions 8/5/97 8/13/97 8/19/97 N/A 1 17 Total Depth (MD+-i-VD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 11680' MD / 8814' TVD 11615' MD / 8860' TVD YES_X NO.__ 2220' feet MD 1900' feet (approx) 22 Type Electric or Other Logs Run MWD, GR. 23 CASING, LINER AND CEMENTING RECORD , SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 94# H-40 Surf 100' 32" 300 Sx PF II - 13-3/8" 72~ MN-80 Surf 2130' 17.5" 5300 Sx PF II - 9-5/8" 47# SOO-95/N-80 Surf 9021' 12.25" 750 Sx Class G - 7" 29# L-80 8726' 9606' 8.5" 1090 Sx Class G - 2-7/8" 6.4~ L-80 8724' 11680' 3.75 23 Bbls LARC - , , 24 Perforations open to Production (MD+TVD of TOp and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 5-1/2;' Tbg 8639' 8627' 10297 - 10500' MD; 8870 - 8864' TVD; at 4 spf. 4-1/2'' Tbg 8763' 10620 - 10644' MD; 8860 - 8858, TVD; at 4 spf. J 10782 - 10995' MD; 8842 - 8815' TVD; at 4 spf. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11075 - 11255' MD; 8815 - 8815' TVD; at 4 spf. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 11322 - 11615' MD; 8817 - 8816' TVD; at 4 spf. 127 PRODUCTION TEST Dat~ First Production Method of Operation (FIc~ing, gas lift, etc.) 10/7/97 Flowing Date of Test Hours Tested PRODUCTION FOR OIL - BBL !GA~ - MCF WATER - BBL CHOKE SIZE I GOR 10/8/97 6 TEST PERIOD --I 1046 ., Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAs - MCF WATER - BBL OIL GRAVITY - APl (corr) 379 - 24 HOUR RATE X 6763 7074 0 -- 28 CORE DATA ~ ~=~ ~ A · & J A I Brief descdptic;n of I~thology, porosity, fractures, apparent dips ~and presence of oil, gas, or water. Submit core chips.U It ]NAL * This 10-407 submitted as directed per the 10-401 form approved 6/27/97 (issued Permit # 97-101 ). }.~}~,~'~:'~~7~....~:~ ~ ~'~.~ ~ ~I '~!L.?,~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Sag River Shub!ik Sadlerochit GEOLOGIC MARKERS MEAS DEPTH 9479' 9524' 9582' TRUE VERT DEPTH 8307' 83.z~ 8397' FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase. N/A 31 LIST OF A'Fi'ACHMENTS Summary of 2-09B Coil Tubing Sidetrack Ddlling Operations. 321 hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~~ ~"Yl · ~ Engineering Supervisor INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Gasltem Injection,27: MethOdshut_ln,Of operatiOn:Other_explain.Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water I nje. cti_q, n~\¢.~ !_~,~;; ¢~i' ;'.-~.., ~,,~ ~''~'~i¢, ~ ~*-¢..;? ~-~.~ ..,.~. Item 28: If no cores taken, indicate "none". 2-09B DESCRIPTION OF WORK COMPLETED COIL TUBING SIDETRACK DRILLING OPERATIONS 8/3/97: Milled a pilot hole through cement plug from 9106' to 9475' MD. 8/4/97: Milled cement from 9475' to 9630'. POOH. RIH w/UR & reamed cement from 9130' to 9641' MD. POOH. 8/5/97: RIH & set whipstock at 9603' MD (top). POOH. from 9606' to 9611.5' MD. POOH w/milling BHA. RIH w/window mill & milled a window through the 7" casing RIH w/dressing BHA & dressed window smooth. POOH. 8/6/97: RIH w/drilling BHA. Swapped the well to FIo Pro & drilled a 3.75" sidetrack hole to 9792' MD. POOH w/BHA. 8/7/97: RIH w/drilling BHA. Continued drilling build section to 9830' MD. Drilled build to 10070' MD. POOH w/BHA. POOH w/BHA. RIH w/drilling BHA. 8/8/97: RIH w/drilling BHA & finished drilling build section to 10342' MD. POOH w/BHA. PT BOPS. 8/9/97: RIH w/drilling BHA. Reamed sticky shale at 10290 - 10325' MD. POOH w/BHA. RIH w/nozzle to 10345' & circulated FIo Pro, then pumped 12 bbls of Class G cement to plug back hole to 10030' MD. POOH & WOC. 8/10/97: RIH w/drilling BHA. Tagged TOC at 10032' MD. CBU, then reamed cement to 10060' MD. Oriented & drilled new build hole to 10320' MD w/periodic sweeps to window. POOH w/BHA. RIH w/drilling BHA. 8/11/97: Swapped to new FIo Pro & drilled horizontally to 10613' MD. POOH w/BHA. 8/12/97: RIH w/drilling BHA. Drilled horizontally to 11250' MD w/periodic sweeps to window. 8/13/97: Drilled to TD at 11680' MD. 8/14/97: Swept clean to window, then RIH to spot a Hi Vis pill in the openhole. POOH w/BHA. RIH w/2-7/8" liner & landed liner at 11680' MD. Released liner. Pumped 23 bbls of Latex Acid Resistive Cement to set the liner at 8724 - 11680' MD. Bumped plug & unstung from PBR. POOH displacing mud w/1% KCI Water. 8/15/97: RIH & washed out liner to landing collar at 11615' MD. 2000 psi; OK. POOH displacing well w/1% KCI Water. Circulated clean FIo Pro into liner. RIH w/perforating guns. PT liner top to 8/16/97 - 8/19/97: Shot initial perforation intervals in 4 gun runs using 2-1/8" & 1-11/16" carriers at 4 spf at zero degree phasing at: 10297- 10500' MD (Z1) 10620 - 10644' MD (Z1) 10782 - 10995' MD (Z1) 11075 - 11255' MD (Z1) 113£;;'- 11615' MD (Z1) POOH w/perf guns. ND stack. NU tree. RDMOL. 2-09B DESCRIPTION OF WORK COMPLETED COIL TUBING SIDETRACK DRILLING OPERATIONS 8/22J97: Set AVA DWP Retrievable POGLM's at 7080' & 3944' MD (at top elements). 9/1/97: RIH & retrieved failed upper POGLM. 9/26/97: RIH & reset a AVA DWP Retrievable POGLM at 3944' MD (at top element). tested steady. PT IA to 2700 psi; tubing pressure Placed the well on initial production & obtained a valid well test. ,RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PBU / 2-9B 500292015302 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 6/97 DATE OF SURVEY: 081397 MWD SURVEY JOB NUMBER: AK-MW-70232 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10050.40 8770.52 8712.52 42 30 10060.00 8777.54 8719.54 43 31 10068.02 8783.28 8725.28 45 0 10079.30 8791.10 8733.10 47 12 10092.37 8799.75 8741.75 49 55 N 45.20 E .00 2686.20N 2763.99E N 45.10 E 10.76 2690.82N 2768.63E N 44.65 E 18.74 2694.78N 2772.58E N 45.71 E 20.64 2700.51N 2778.35E N 45.71 E 20.81 2707.35N 2785.36E 3755.66 3762.06 3767.53 3775.47 3785.02 10117.90 8815.25 8757.25 55 16 10139.25 8826.75 8768.75 59 30 10157.32 8835.47 8777.47 62 50 10172.87 8842.12 8784.12 66 31 10186.87 8847.34 8789.34 69 36 N 46.06 E 21.02 2721.46N 2799.92E N 46.41 E 19.81 2733.90N 2812.90E N 49.05 E 22.48 2744.54N 2824.62E N 48.69 E 23.82 2753.79N 2835.20E N 49.75 E 23.09 2762.27N 2845.04E 3804.77 3822.26 3837.55 3851.06 3863.52 10196.10 8850.41 8792.41 71 10210.65 8854.59 8796.59 74 10220.32 8856.93 8798.93 76 10231.40 8859.23 8801.23 79 10239.60 8860.80 8802.80 79 37 58 59 0 0 N 51.33 E 27.20 2767.80N 2851.76E N 52.03 E 23,41 2776.44N 2862.69E N 52.56 E 21.56 2782.17N 2870.11E N 53.26 E 19,25 2788.71N 2878.76E N 51.51 E 20.95 2793.62N 2885.13E 3871.81 3885.00 3893.84 3904.02 3911,60 10253.70 8863.54 8805.54 78 34 10266.07 8865.92 8807.92 79 16 10278.45 8867.98 8809.98 81 33 10286.82 8869.08 8811.08 83 19 10300.62 8870.29 8812.29 86 34 N 48.34 E 22.27 2802.52N 2895.71E N 45.71 E 21.64 2810.80N 2904.59E N 44.12 E 22.35 2819.44N 2913.21E N 44.65 E 21.94 2825.37N 2919.02E N 46.26 E 26.33 2835.01N 2928.81E 3924.82 3936,59 3948.52 3956.65 3970.06 10320.89 8870,90 8812,90 90 0 10340.67 8870.70 8812,70 91 8 10356.57 8870.25 8812.25 92 6 10377.32 8869.23 8811.23 93 31 10393.69 8868.19 8810.19 93 46 10409.54 8867.16 8809.16 10439.79 8865,94 8807.94 10451.69 8865,76 8807.76 10474.02 8865,42 8807.42 10493.84 8864.96 8806.96 N 42.89 E 23.68 2849.44N 2943.03E N 40.61 E 12.89 2864.19N 2956.19E N 38.15 E 16.62, 2876.48N 2966.28E N 35.34 E 15.14 2893.08N 2978.67E N 33.05 E 14.05 2906.59N 2987.85E 93 41 N 30.94 E 13.30 2920.00N 2996.23E 90 55 N 33.14 E 11.69 2945.62N 3012.27E 90 47 N 29.53 E 30.35 2955.78N 3018.45E 90 58 N 29.71 E 1.14 2975,19N 3029.49E 91 40 N 28.13 E 8.72 2992.53N 3039.07E 3989.89 4009.43 4025.22 4045.89 4062.22 4078.03 4108.25 4120.14 4142.44 4162.20 10514.07 8864.43 8806.43 91 19 10552'.12 8863.26 8805.26 92 11 10567.24 8862.59 8804.59 92 54 10586.59 8861.60 8803.60 92 59 10622.59 8859.69 8801.69 93 4 N 27.07 E 5.52 3010.46N 3048.44E N 27.25 E 2.36 3044.29N 3065.80E N 23.56 E 24.82 3057.94N 3072.28E N 24.61 E 5.44 3075.58N 3080.16E N 24.26 E 1.00 3108.31N 3095.03E 4182.34 4220.19 4235.16 4254.26 4289.82 OR! tNAL S, .RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PBU / 2-9B 500292015302 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 6/97 DATE OF SURVEY: 081397 MWD SURVEY JOB NUMBER: AK-MW-70232 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10654.24 8857.58 8799.58 10676.41 8855.83 8797.83 10694.99 8854.29 8796.29 10723.04 8851.31 8793.31 10741.91 8848.80 8790.80 94 94 95 97 98 34 28 0 12 4 N 25.14 E 5.46 3136.99N 3108.23E N 23.03 E 9.50 3157.17N 3117.25E N 23.56 E 4.03 3174.17N 3124.57E N 24.08 E 8.06 3199.68N 3135.83E N 23.21 E 6.49 3216.81N 3143.33E 4321.08 4342.92 4361.18 4388.72 4407.19 10794.21 8840.85 8782.85 10815.06 8837.29 8779.29 10852.56 8830.79 8772.79 10902.59 8823.53 8765.53 10931.96 8820.22 8762.22 99 24 ** 16 99 40 97 1 95 53 N 20.04 E 6.50 3264.86N 3162.38E N 18.64 E 7.85 3284.24N 3169.18E N 16.35 E 6.23 3319.46N 3180.28E N 16.00 E 5.32 3366.99N 3194.07E N 15.65 E 4.06 3395.07N 3202.03E 4457.88 4477.86 4513.47 4560.89 4588.79 10966.51 8816.99 8758.99 10992.01 8815.25 8757.25 11023.04 8814.18 8756,18 11043.74 8814.04 8756,04 11067.89 8814,38 8756,38 94 49 92 59 90 58 89 49 88 35 N 16.18 E 3.43 3428,15N 3211.46E N 16.53 E 7.34 3452.56N 3218.62E N 17.05 E 6.72 3482.24N 3227.58E N 17.05 E 5.56 3502,03N 3233.65E N 17.40 E 5.29 3525.09N 3240.80E 4621.70 4646.10 4675.90 4695.81 4719.07 11086.96 8814,96 8756.96 11104.69 8815.52 8757.52 11130.21 8815.99 8757.99 11153.34 8816.12 8758.12 11187.09 8815.91 8757.91 87'53 88 30 89 22 90 0 90 41 N 17.23 E 3.78 3543.29N 3246.47E N 17.40 E 3.57 3560.21N 3251.75E N 20.04 E 10.90 3584.37N 3259.94E N 20.74 E 4.04 3606.05N 3267.99E N 23,56 E 8.61 3637.31N 3280.72E 4737.44 4754.51 4779.25 4801.84 4835.00 11217,09 8815.47 8757,47 11230.61 8815.36 8757.36 11270.04 8815.45 8757.45 11295.62 8815.98 8757,98 11315.14 8816.82 8758.82 11336.97 8817.72 8759.72 11368.07 8818.49 8760.49 11391.52 8818.68 8760.68 11428.92 8818.16 8760.16 11465.14 8817.24 8759.24 9O 58 9O 0 89 44 87 53 87 11 88 3 89 7 89 56 91 40 91 13 N 25.32 E 5.93 N 25.32 E 7.18 N 29.36 E 10.27 N 30.59 E 8.68 N 31.10 E 4.44 N 31,60 E 4.56 N 32.30 E 4.11 N 32.90 E 4.33 N 33.75 E 5.15 N 35.69 E 5.49 3664.61N 3293.13E 4864.67 3676.83N 3298.91E 4878.08 3711.85N 3317.01E 4917.32 3734.00N 3329.79E 4942.86 3750.74N 3339.79E 4962.35 3769.37N 3351.13E 4984.15 3795.75N 3367.59E 5015.23 3815.50N 3380.22E 5038.68 3846.75N 3400.76E 5076.07 3876.50N 3421.38E 5112.25 11510.59 8816.48 8758.48 11555.94 8815.69 8757.69 11575.12 8815.43 8757.43 11604.09 8815.49 8757.49 11617.54 8815.58 8757.58 90 40 91 19 90 15 89 28 89 49 N 37.78 E 4.75 N 40.61 E 6.40 N 40.96 E 5,82 N 41.84 E 4,08 N 42.02 E 2,92 3912.92N 3448.56E 5157.58 3948.05N 3477.21E 5202.64 3962.57N 3489.74E 5221.64 3984.30N 3508.89E 5250.28 3994.31N 3517.88E 5263.56 ~{RY-SI/N DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC. PBU / 2- 9B 500292015302 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 6/97 DATE OF SURVEY: 081397 MWD SURVEY JOB NI/MBER: AK-MW-70232 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11639.69 8815.39 8757.39 91 8 N 41.84 E 6.01 11680.00 8813.75 8755.75 93 32 N 41.30 E 6.10 4010.79N 3532.68E 5285.43 4040.91N 3559.40E 5325.23 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5385.00 FEET AT NORTH 41 DEG. 22 MIN. EAST AT MD = 11680 VERTICAL SECTION RELATIVE TO WELL HEAD· VERTICAL SECTION COMPUTED ALONG 32.83 DEG. TIE-IN SURVEY AT 10,050.40' MD WINDOW POINT AT 10,060.00' MD PROJECTED SURVEY AT 11,680.00' MD RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA INC. PBU / 2-9B 500292015302 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 6/97 DATE OF SURVEY: 081397 JOB NUMBER: AK-MW-70232 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10050.40 8770.52 11050.40 8814.06 11680.00 8813.75 8712.52 2686.20 N 2763.99 E 1279.88 8756.06 3508.40 N 3235.60 E 2236.34 956.46 8755.75 4040.91 N 3559.40 E 2866.25 629.91 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. .CRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 ARCO ALJtSKA INC. PBU / 2-9B 500292015302 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 6/97 DATE OF SURVEY: 081397 JOB NUMBER: AK-MW-70232 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10050.40 8770.52 10225.79 8858.00 10250.40 8862.89 8712.52 2686.20 N 2763.99 E 1279.88 8800.00 2785.40 N 2874.41 E 1367.79 87.91 8804.89 2800.39 N 2893.28 E 1387.51 19.72 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Si .RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PBU / 2-9B PB1 500292015372 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 4/97 DATE OF SURVEY: 080897 MWD SURVEY JOB NUMBER: AK-MW-70232 KELLY BUSHING ELEV. = 58.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9500.00 8322.50 8264.50 9606.00 8414.38 8356.38 9635.90 8440.18 8382.18 9665.70 8465.55 8407.55 9691.37 8486.76 8428.76 30 0 29 49 30 53 32 24 36 7 N 57.50 E .00 N 56.73 E .40 N 51.40 E 9.69 N 45.90 E 10.91 N 43.95 E 15.11 2454.40N 2553.60E 3446.82 2483.10N 2597.99E 3495.00 2491.97N 2610.21E 3509.08 2502.30N 2621.93E 3524.12 2512.54N 2632.12E 3538.25 9723.42 8512.15 8454.15 9752.92 8534.68 8476.68 9780.97 8555.94 8497.94 9795.72 8567.33 8509.33 9809.12 8577.88 8519.88 39 12 41 13 40 17 38 34 37 37 N 35.16 E 19.30 N 33.23 E 8.04 N 24.70 E 20.11 N 29.53 E 23.84 N 29.89 E 7.35 2527.64N 2644.52E 3557.65 2543.39N 2655.22E 3576.69 2559.37N 2664,08E 3594.92 2567..71N 2668.34E 3604.24 2574.89N 2672.44E 3612.50 9838.27 8601.24 8543.24 9871.39 8628.19 8570.19 9904.22 8654.94 8596.94 9931.74 8677.21 86'19.21 9960.29 8700.11 8642.11 35 51 35 14 35 35 36 23 36 54 N 29.53 E 6.08 N 35.34 E 10.37 N 37.09 E 3.28 N 39.90 E 6.65 N 42.37 E 5.48 2590.04N 2681.08E 3629.91 2606.28N 2691.39E 3649.14 2621.62N 2702.63E 3668.13 2634.28N 2712.70E 3684.22 2647.11N 2723.91E 3701.08 9980.17 8716.00 8658.00 10001.59 8733.00 8675.00 10019.87 8747.28 8689.28 10032.49 8756.94 8698.94 10050.44 8770.35 8712.35 37 0 37 58 39 17 40 46 42 30 N 45.18 E 8.51 N 46.06 E 5.17 N 46.06 E 7.22 N 45.18 E 12.63 N 45.20 E 9.64 2655.73N 2732.18E 3712.81 2664.85N 2741.49E 3725.52 2672.77N 2749.71E 3736.63 2678.45N 2755.51E 3744.55 2686.85N 2763.97E 3756.20 10070.79 8785.08 8727.08 10093.47 8800.46 8742.46 10116.82 8814.75 8756.75 10130.44 8822.24 8764.24 10147.74 8830.79 8772.79 10162.69 8837.66 8779.66 10189.72 8849.10 8791.10 10209.02 8856.17 8798.17 10221.72 8860.15 8802.15 10239.04 8864.84 8806.84 44 44 49 49 54 40 58 37 62 8 63 11 66 43 70 18 73 12 75 19 N 45.00 E 10.98 N 46.41 E 22.90 N 42.37 E 24.83, N 42.89 E 29.18 N 41.66 E 21.26 N 37.80 E 23.99 N 32.16 E 22.97 N 28.83 E 24.57 N 27.07 E 26.36 N 24.44 E 19.03 2696.76N 2773.92E 3769.92 2708.39N 2785.84E 3786.15 2721.59N 2798.74E 3804.23 2729.95N 2806.44E 3815.44 2741.08N 2816.55E 3830.27 2751.29N 2825.04E 3843.46 2771.35N 2839.05E 3867.91 2786.83N 2848.16E 3885.85 2797.48N 2853.81E 3897.86 2812.50N 2861.05E 3914.41 10261.04 8870.00 8812.00 10284.27 8874.30 8816.30 10300.27 8876.50 8818.50 10319.69 8878.51 8820.51 10322.19 8878.73 8820.73 77 36 N 19.16 E 25.55 81 2 N 16.53 E 18.49 83 8 N 18.11 E 16.37 84 59 N 23.03 E 26.94 85 10 N 23.73 E 28.81 2832.35N 2868.99E 3935.39 2854.07N 2875.98E 3957.43 2869.20N 2880.69E 3972.70 2887.28N 2887.48E 3991.57 2889.56N 2888.47E 3994.03 SEP 1 7 !997 Alaska Oil & Gas Co~m. Commission M¢ora,qe S.~ ~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC. PBU / 2-9B PB1 5oo292o15372 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 4/97 DATE OF SURVEY: 080897 MWD SURVEY JOB NUMBER: AK-MW-70232 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10342.00 8880.15 8822.15 86 36 N 29.20 E 28.48 2907.24N 2897.27E 4013.66 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4104.42 FEET AT NORTH 44 DEG. 54 MIN. EAST AT MD = 10342 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 32.83 DEG. TIE-IN SURVEY AT 9,500.00' MD WINDOW POINT AT 9,606.00' MD PROJECTED SURVEY AT 10,342.00' MD ~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC. PBU / 2-9B PB1 500292015372 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 4/97 DATE OF SURVEY: 080897 JOB NUMBER: AK-MW-70232 KELLY BUSHING ELEV. = 58.00 FT. OPEP~ATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGUL~ COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9500.00 8322.50 8264.50 2454.40 N 2553.60 E 1177.50 10342.00 8880.15 8822.15 2907.24 N 2897.27 E 1461.85 284.35 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. .~RY-SUN DRILLING SERVICES ANCHOP_AGE ALASKA PAGE ARCO ALASKA INC. PBU / 2-9B PB1 500292015372 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 4/97 DATE OF SURVEY: 080897 JOB NUMBER: AK-MW-70232 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 9500.00 8322.50 8264.50 2454.40 N 2553.60 E 1177.50 9540.99 8358.00 8300.00 2465.41 N 2570.88 E 1182.99 9656.79 8458.00 8400.00 2499.10 N 2618.46 E 1198.79 9783.62 8558.00 8500.00 2560.84 N 2664.87 E 1225.62 5.49 15.80 26.82 9907.99 8658.00 8600.00 2623.37 N 2703.98 E 1249.99 10033.93 8758.00 8700.00 2679.15 N 2756.20 E 1275.93 10215.04 8858.00 8800.00 2791.92 N 2850.81 E 1357.04 10240.00 8865.09 8807.09 2813.34 N 2861.43 E 1374.91 24.37 25.95 81.10 17.87 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS r'~ I::t I I_1_ I I~J G S E I::t~1 r' ~: S WELL LOG TRANSMITTAL To: State of Alaska October 1, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor [0~ 3001 Porcupine Dr. .~..,./q// Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs D.S. 2-09B & 2-09B PB 1, AK-MW-70232 The techniCal data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' J'n'n Galv~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 2-09B: 2" x 5" MD Gamma Ray Logs: 50-029-20153-02 2"x 5" TVD Gamma Ray Logs: 50-029-20153-02 DS 2-09B PBI: 2"x 5" MD Gamma Ray Logs: 50-029-20153-72 2" x 5" TVD Gamma Ray Logs: 50-029-20153-72 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 C)~,, MWD Formation Evaluation Logs - D.S. 2-09B, AK-MW-70232 September 26, 1997 The technical data listed below is being submitted herewitk Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted Disc w/th verification listing. APl#: 50-029-20153-02. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I:! I I..I.. I I~i G S E i:IL~ I r- ~:: S WELL LOG TRANSM1TFAL To.' REz State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 (,~Y~, ' MWD Formation Evaluation Logs - D.S. 2-09B PB 1, September 26, 1997 AK-MW-70232 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.' Ytm Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. Ag)]:#: 50-029-20153-72. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company September 10, 1997 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data 2-9B Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 2-9B MWD survey tie-in point at 10,050.40', window point at 10,060.00' and a projected survey at 11,680.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company September 10, 1997 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data 2-9B PB 1 Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 2-9B PB1 MWD survey tie-in point at 9,500.00', window poim at 9,606.00' and a projected survey at 10,342.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments SEP I 7 1991 Alaska Oil 6 Gas Co,s, 6ommb~ion Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 27, 1997 Erin Oba, Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Prudhoe Bay Unit 2-09B ARCO Alaska, Inc. Permit No: 97-101 Sur. Loc. 1216'FNL, 971'FWL, Sec. 36, T11N, R14E, UM Btmnhole Loc. 2855'FNL, 925'FEL, Sec. 25, T11N, R14E, UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new' hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W~ohxnston Chairman BY ORDER OF tHE COMMISSION dlf/Enclosm es CC' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation ~v/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll _ Redrill X~ lb. Type o1' Well Exploratorym Stratigraphic Test ~ Development Oil Re-Entry__ Deepen _ Service_ Development Gas__ Single Zone ~ Multiple Zone_ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 58' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 28308 Prudhoe Bay' Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1216' FNL, 971' FWL, Sec 36, TllN, R14E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1250' FSL, 1730' FEL, Sec 25, T11N, R14E, UM. 2-09B #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 2855' FNL, 925' FEL, Sec 25, T11N, R14E, UM. August, 1997 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 11230' MD / 8833' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 9600' MD Maximum hole angle 90° Maximum surfac~ 2800 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth Size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD 'I'VD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4 L-80 FL4S 2530' 8700' 7652' 11230' 8833' 25 bbls 19'. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: true measured vertical 8905 10784 feet feet Plugs(measured) Effective depth : measured 10757 feet Junk(measured) true vertical 8905 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 100' 20" 300 Sx Permafrost II 100' 100' Surface 2072' 13-3/8" 5300 Sx Permafrost II 2130' 2130' Production 8963' 9-5/8" 750 Sx Class G 9021' 7915' Liner 1214' 7" 1090 Sx Class G 9940' 8707' CT Liner 1090' 3-1/2" 11 bbls Cl G (for 3-1/2 & 2-7/8") 9781' 8567'~"~ ~ ~ ~=. l~ . ~, CT Liner 996' 2-7/8" 10778' 891 Perforation depth: measured 10398- 10498'; 10518- 10635'; 10655- 10727' r¢.,AY 2 9 1997 true vertical 8899 - 8907'; 8907- 8910'; 8909 - 8906' 41asPa .0il .& Gas C0r so 20. Attachments Filing fee ~ Property plat _ BOP Sketch X Diverter Sketch _ Ddlling program x Ddlling fluid program __ Time vs depth pict 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 ,.~.G'~[~~ 5~'x/~ ~.-~C'¢~ ~' 2--~.~-' J- Signed ~~ ~'1. ~ Titlle Engineering Supervisor Date ,~-Z~'-c~ '-~ Commission Use Only Permit Number I APInumber I Ap~c,ov_..a,~ e.~ See cover letter for ~"~-'/'O// 50-'~',7- ~- ,~-- C:3/,.~',_~" - O "2-.- '"'~;; ~ other requirements Conditions of approval Samples required Yes ,~No Mud Icg required _ Yes ,~No Hydrogen sulfide measures ~('Yes _ No Directional survey required ~¢es _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M'X3_ 500 psi for CTU Other: V~ Original Signed By byorderof ~ '¢;~'"" ~y Approved by ~[vid w. Johnston Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate DS 2-9B CT Sidetrack and Completion Intended Procedure Objective: Cut and pull the 3-1/2" x 2-7/8" liner at - 9650'. Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 2-7/8" cemented liner. Intended Procedure: Pull packer from top of liner. Cut and pull the 3-1/2" x 2-7/8" liner at - 9650'. · Cement squeeze and plugback the existing completion to - 957(/md. Mill window in 7" casing at -9600' md. Drill 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight. Build angle to -90°. Directionally drill 3-3/4" x 1000' horizontal well to access Lower Romeo reserves. · Run and cement 2-7/8" liner to TD. · Perforate selected intervals. · Place well on production. F,~AY 2'9 1997 0il & Gas CoDsi Commi$$ Anchorago May 27, 1997 DS 2-9B Proposed CT Sidetrack Horizontal 5-1/2" Tub' 2220' 5-1/2" RQM SSSV Nipple 8507 5-1/2" Otis SS ~ Packer 8627' 7" Liner Top 8726' XN Nipple 8702' Tbg Tail 8763' Top of 2-7/8" Liner in 4-1/2" Tbg. tail. 9-5/8" Casing shoe @ 9021' 3-3/4" Open hole 2-7/8" liner TD @ - 11230' Window cut in 7" at -9600- 9605' Current perforations cement squeezed TD @ - 10784' ~m : ? 2-gBxl~ 5.~23,~7 3 23 PM 595~: ..... ~_~__a~_ i "~?i · ).;,. "-~:~s~i '-~.~ .. ~ ~-.~ ..... ~ . 1.2: --~ ~., 6~ [.. l? ......... ~'~ ~'li .... ~ ~' ~! "g~' '" ~ ............. .. ~ ~ '---~7~~ .... m~o~1 ......... ~ ...... .~ · . . ~ ........ .... ~. ~ ..... · ~ ............ ..~ ASP X [Ccm~ments ... Drilling Wellhead Detail ~ CT Injector Head Methanol Injection ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure 7" Riser ConnectOtis 7" WLA Quick~ Alignment Guide Flange 7-1/16", 5M Ram Type Dual ~ ~ Gate BOPE . Flanged Fire Resistant Man~ Kelly Hose to Dual HCR Choke Manifold Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure (3.5") Cutters or Combination Cutter/Blinds ~]~ Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manualover Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In 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 AIaska Oil & Gas Cons, Anunorage Shop Fuel Boilers Mu~ Tanks Water Pump Fir~e Ext. Preferred Major 60/4O I TrplxI Fire Ext. Equipment ,~Pipe rack Layout for r-cf) CT Ext. EDOWell Drilling I quipment Trailer Drilling -' STATE OF ALASKA ALASI' ,L AND GAS CONSERVATION COMMISSION APPLICA¥1ON FOR SUNDRY APPROVALS 1. Type of request: Abandon_X Suspend_ OperatJon Shutdown_ Reenter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Puli tubing_ Vadance_ Per/orate _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum el elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 58' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1216' FNL, 971' FWL, Sec 36, T11N, R14E, UM 2-09A At top of productive interval: 9. Permit number: 1250' FSL, 1730' FEL, Sec 25, T11N, R14E, UM 96-58 At effective depth: 10. APl number: 50-029-20153-01 At total depth: 11. Field/Pool: 4464' FNL, 1477' FEL, Sec 25, T11N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 10784 feet Plugs (measured) true vertical 8905 feet Effective Depth: measured 10757 feet Junk (measured) true vertical 8905 feet ¢3i~,~.~ ~:~ Casing Length Size Cemented Measured depth True vertical depth Conductor 100' 20" 300 Sx Permafrost II 100' 100' Surface 2072' 13-3/8" 5300 Sx PF II 2130' 2130' Production 8963' 9-5/8" 750 Sx Class G 9021' 7915' Liner 1214' 7" 1090 Sx Class G 9940' 8695' CT Liner 1092' 3-1/2" 11 Bbls Class G 9781' 8567' CT Liner 996' 2-7/8 ........ 10778' 8910' Perloration Depth measured 10398- 10498'; 10518- 10635'; 10655- 10727' true vertical 8899 - 8907'; 8907 - 8910'; 8909 - 8906' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8639' MD; 4-1/2", 12.6#, N-80, PCT @ 8763' MD. Packers and SSSV (type and measured depth) Baker SAD Packer @ 8627' MD; Otis RQM SSSV @ 2220' MD. 13. Attachments Description summary of proposal _ X Detailed operations program _ BOP sketch _ X 14. Estimated date for commencing operation 15. Status of well classification as: June, 1997 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 el my knowledge. Signed ~.,,f,,,~ '~. ~--~ Title: Engineering Supervisor Date FOR CO~MlSSlON USE ONLY Conditions of approval: Notify Comisslon so representitive may witness ~ ~ ~.7.,or:'''' IApproval No."~ Plug integrety BOP test Location clearance ~'O~--,-,~.O Mechanical integrety test Subsequent form required lO- Original Si¢~,~-., _~~ / Approved by order of the Commissioner David W. ~Joh,rtsloi', Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PERMIT CHECKLISTco Y ~__~ INIT CLASS GEOL AREA PROGRAM: expD dev~redrl~ servO wellbore seg~ ann disp para reqfq ON,O HO ADMINISTRATION ENGINEERING 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary. . N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ...... N 8. If deviated, is wellbore plat included ......... N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order ..... N 12. Permit can be issued without administrative approval. . N 13. Can permit be approved before 15-day wait ........ N REMARKS 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg. . Y N 17. CMT vol adequate to tie-in long string to surf csg . . . Y N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... 23. If diverter required, is it adequate ......... ~ 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate .............. .__ ..... 26. BOPE press rating adequate; test to ~~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... N 28. Work will occur without operation shutdown ....... .y~~ ~ 29. Is presence of H2S gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... Y/N 33. Seabed condition survey (if off-shore) ........ 34. Contact name/phone for weekly progress reports . . . .//. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMI SS ION: JDH~ mcm Comments/Instructions: © ..q HOWldlf- A:\FORMS\cheklist rev 01/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : DS 02-09B FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292015302 REFERENCE NO : 98236 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/05/21 ORIGIN : FLIC REEL NAME : 98236 CONTINUATION # : PREVIOUS REEL : CO~4MENT : ARCO ALASKA INC, D.S. 02-09B, PRUDHOE BAY, 50-029-20153-02 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 98/05/21 ORIGIN .. FLIC TAPE NAME : 98236 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, D.S. 02-09B, PRUDHOE BAY, 50-029-20153-02 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: DS 02-09B API NUMBER: 500292015302 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 20-MAY-98 JOB NUMBER: 98236 LOGGING ENGINEER: C Yon OPERATOR WITNESS: G Sarber SURFACE LOCATION SECTION: 36 TOWNSHIP: liN RANGE: 14E FNL: 1216 FSL: FEL: FWL: 971 ELEVATION(FT FROM MSL O) KELLY BUSHING: 58.00 DERRICK FLOOR: 57.00 GROUND LEVEL: 30.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 3. 750 2. 875 11678.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 13-AUG-97 LOGGING COMPANY: SPERRY-SUN BASELINE DEPTH 88888.0 11530.0 11520.0 11514.0 11491.0 11470.0 11469.0 11421.5 11416.0 11385.0 11382.5 11367.5 11352.0 11341.5 11331.5 11327.5 11316.5 11311.5 11298.5 11290.0 11282.5 11277.5 11274.0 11272.5 11270.5 11256.5 11255 0 11247 0 11230 5 11228 5 11225 5 11224 5 11216.5 11214.0 11213.5 11200.0 11192.5 11187.0 11186.0 11173 0 11166 5 11165 0 11164 0 11156 0 11138 0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88890.0 88890.5 11532.5 11522.0 11492.0 11471.0 11420.0 11383.0 11364.5 11349.0 11326.5 11324.0 11316.5 11293.5 11287.5 11281.5 11278.5 11272.5 11271.0 11254.5 11253.5 11247.0 11230.5 11225.5 11219.0 11215.0 11202.0 11195.0 11188.0 11175.0 11165.0 11158.0 11138.0 11515.0 11472.0 11420.0 11383.5 11343.5 11316.5 11274.5 11271.0 11231.5 11225.5 11214.5 11195.0 11177.0 11174.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11137 5 11125 5 11121 0 11110 0 11100 5 11096 0 11092.0 11087.0 11082.0 11080.0 11074.5 11072.0 11070.0 11069.0 11062.5 11059.5 11056.5 11052.5 11051.0 11044.0 11040.5 11034.5 11031.0 11028.0 11026.0 11023.0 11016.0 11008.5 11006.5 11004.5 10999.0 10993.5 10991.5 10990.0 10978.0 10965.0 10956.0 10944.5 10935 5 10935 0 10930 5 10928 5 10928 0 10923 0 10914 0 10908 5 10906 5 10901 0 10894 5 10892 5 10891 0 10885 5 10880 5 10873 0 10868 5 10864 0 11127 5 11126 0 11108 5 11103 5 11097 5 11091 5 11086 5 11082 5 11080 0 11071.5 11069.0 11064.0 11060.5 11054.0 11052.5 11045.5 11042.5 11036.5 11033.0 11027.5 11025.0 11017.5 11014.5 11008.0 11002.5 10996.0 10993.0 10980.5 10966.5 10957.0 10943.5 10936.5 10933.0 10929.5 10925.0 10915.5 10911.0 10907.5 10902.5 10895.0 10893.5 10885.0 10882.5 10874.0 10871.0 10866.0 11145.0 11078.0 11071.0 11060.5 11033.0 11028.0 11008.5 10988.0 10938.5 10929.0 10894.0 10874.0 21-MAY-1998 13:38 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10858.5 10855.5 10842.0 10841.5 10828.0 10820.5 10809.5 10801.0 10799.0 10798.0 10791.0 10786.5 10782.0 10779.5 10776.5 10775.0 10766.5 10764.5 10764.0 10762.5 10759.0 10755.0 10750.0 10735.0 10728.0 10707.5 10705.5 10702.0 10699.5 10696.0 10692.5 10676.0 10670.5 10662 0 10651 5 10645 5 10642 5 10640 0 10636 0 10633 0 10619 5 10615 5 10614 5 10610 0 10601.5 10596.5 10591.0 10589.0 10584.5 10578.0 10575.5 10573.5 10572.5 10571.0 10568.0 10561.5 10861.0 10857.5 10845.0 10831.0 10821.0 10811.0 10804.0 10798.5 10795.0 10790.0 10781.0 10777.5 10770.0 10767.0 10765.0 10760.5 10759.0 10738.5 10733.0 10711.5 10708.5 10700.5 10681.5 10666.5 10651.0 10649.0 10646.0 10639.5 10625.0 10620.0 10615.5 10606.0 10601.0 10591.0 10588.5 10580.0 10576.0 10573.5 10568.5 10840.0 10798.5 10781.5 10776.5 10765.0 10753.0 10739.0 10712.0 10704.5 10700.5 10676.5 10658.0 10640.0 10620.5 10601.0 10580. 0 10568.0 10565.0 10554.0 21-MAY-1998 13:38 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10552.0 10547.5 10543.0 10530.5 10518.5 10515.5 10512.0 10507.0 10499.5 10490.5 10458.0 10429.0 10422.5 10421.0 10419.5 10414.5 10406.0 10402.5 10399.0 10392.5 10388.0 10387.5 10382.5 10378.0 10377.0 10374.0 10373.0 10359.0 10353.0 10351.0 10339 0 10337 0 10331 0 10306 0 10301 0 10298 0 10297.0 10295.0 10294.5 10291.0 10280.5 10276.0 10273.0 10265.5 10263.5 10259.0 10254.5 10252.5 10248.0 10243.5 10243 0 10241 0 10240 5 10236 5 10236 0 10231 0 10546.5 10506.5 10502.0 10496.5 10486.5 10452.5 10419.0 10417.5 10412.0 10405.5 10399.0 10391.0 10385.5 10380.0 10374.5 10371.0 10357.0 10350.0 10335.5 10328.5 10299.0 10293.0 10291.0 10277.0 10272.0 10268.5 10261.5 10254.5 10248.5 10240.0 10237.5 10233.0 10228.5 10547.0 10541.5 10536.5 10526.0 10512.0 10510.5 10425.0 10419.0 10395.5 10385.5 10375.5 10370.5 10351.5 10337.0 10328.5 10302.5 10293.5 10291.0 10286.0 10277.0 10266.0 10254. 0 10247.5 10239.5 10237.5 10232.5 21-MAY-1998 13:38 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 10229.0 10220.5 10219.0 10213.5 10204.5 10201.0 10197.5 10189.5 10186.5 10186.0 10184.0 10179.5 10178.5 10175.5 10174.5 10170.5 10170.0 10167.0 10164.5 10148.0 10142.0 10138.5 10134.0 10131.0 10119.0 10113.5 10109.0 10106.0 10105.5 10103.5 10102.5 10097.0 10090.5 10087.5 10086.5 10080.0 10079 0 10073 5 10071 0 10069 0 10062 5 10060 5 10056.0 10052.0 100.0 $ REMARKS: 1 022 6.0 10218.5 10211.0 10203.5 10198.0 10189.0 10184.0 10181.5 10176.0 10173.0 10167.5 10164.5 10162.0 10146.5 10139.0 10129.0 10116.5 10110.5 10106.0 10103.0 10100.5 10095.0 10088.0 10084.0 10077.5 10071.0 10066.0 10058.5 10057.0 10052.0 96.0 10217.5 10197.0 10184.5 10176.0 10172.5 10167.5 10164.5 10138.5 10135.0 10103.0 10100.0 10084.0 10077.5 10071.0 10052.0 100.0 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON ARCO'S DS 02-09B WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE MWD GAIV~IARAY, ALSO BASE PASS #1 SIGMA AND THE MWD GAR~ARAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ PAGE LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/21 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: O. 5000 FILE SUN~L~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11526.0 10036.0 TDTP 11547.5 10040.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS 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 88 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 8 TYPE REPR CODE VALUE 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 0 ** 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 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 SBHNTDTP CU 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 1022565 O0 000 O0 0 1 i 1 4 68 0000000000 CCL TDTP V 1022565 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11545. 000 SIGM. TDTP 15. 353 TPHI. TDTP 32. 558 SBHF. TDTP 25. 854 SBHN. TDTP 39.351 SIGC. TDTP 1.917 SIBH. TDTP 66.526 TRAT. TDTP 2.120 SDSI. TDTP O. 260 BACK. TDTP 156. 739 FBAC. TDTP 51 . 300 TCAN. TDTP 65357. 594 TCAF. TDTP 24030. 668 TCND. TDTP 30967. 395 TCFD. TDTP 9938. 264 TSCN. TDTP 12329. 264 TSCF. TDTP 4533.222 INND. TDTP 828.337 INFD. TDTP 321.033 GRCH. TDTP -999.250 TENS. TDTP 85. 000 CCL. TDTP O. 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: DEPT. 10036.000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 25.311 TENS. TDTP -999.250 CCL.TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE : 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE : 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AUUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11530.5 10061.5 TDTP 11549.5 10063.0 $ CURVE SHIFT DATA ~ PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 10 BASELINE DEPTH .............. 88888 0 11534 0 11502 5 11497 5 11493 5 11490 5 11488 5 11483 5 11470 5 11457 5 11447 5 11438 5 11424 5 11408 5 11403 0 11367.0 11365.5 11351.5 11347.0 11343.5 11328.5 11311.0 11308.5 11295.0 11286.0 11282.5 11274.5 11273.0 11271.0 11267.5 11259.0 11250.5 11245.0 11234.0 11233.0 11230.5 11224.5 11222.0 11221.0 11212.0 11204.5 11201.0 11193.0 11177.0 11170.5 11158.0 11124.0 11122.5 11118.5 11109.0 11101.0 11097.0 11093.5 GRCH 88888.5 11503.0 11492.0 11489.0 11486.0 11480.5 11453.5 11445.5 11436.5 11422.0 11404.5 11365.0 11349.0 11340.5 11327.0 11305.5 11293.0 11284.0 11281.5 11274.5 11272.5 11266.0 11257.0 11248.0 11245.0 11234.0 11232.0 11225.5 11220.5 11215.5 11206.0 11202.0 11195.0 11170.5 11158.0 11126.0 11125.0 11119.0 11109.0 11103.5 11096.5 11093.5 TDTP 88886.5 11532.5 11497.0 11471.5 11406.0 11370.0 11344.0 11312.0 11270.5 11241.5 11232.0 11219.0 11174.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 11 11085 0 11082 5 11080 0 11069 5 11066 5 11063 0 11057 0 11053 5 11051 5 11049 5 11044 0 11038 0 11036 5 11031 5 11027 5 11022 5 11017 0 11016.5 11011.0 11006.5 11002.5 10999.5 10994.5 10990.0 10979.0 10970.5 10955.0 10942.0 10938.0 10932.0 10922.0 10913.5 10910.0 10904.5 10898.0 10893.0 10889.0 10880.5 10879.5 10869.0 10866.0 10859.5 10852.5 10849.0 10848.0 10845.0 10831.5 10828.0 10823.5 10812.5 10809.0 10803.0 10802.5 10792.5 10780.5 11086.5 11082.5 11080.0 11070.0 11064.0 11060.5 11054.0 11052.5 11050.0 11046.0 11039.0 11038.0 11033.0 11028.0 11024.0 11017 5 11014 5 11008 5 11005 0 11002 5 10996 0 10981.0 10974.0 10957.0 10942.0 10937.0 10933.5 10925.0 10914.0 10911.0 10904.5 10900.0 10893.5 10888.5 10882.0 10871.0 10866.5 10861.0 10853.0 10849.0 10845.0 10825.0 10811.5 10803.0 10795.5 10781.0 11065.5 11017.0 11007.5 10987.0 10877.5 10846.0 10828.0 10823.0 10809.5 10798.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 12 10780 0 10768 0 10767 0 10765 0 10763 5 10760 5 10751 0 10750 0 10740 5 10735 5 10734 5 10728.5 10725.0 10715.0 10703.5 10701.0 10699.0 10697.0 10696.0 10685.0 10683.0 10677.0 10669.0 10665.0 10652.0 10645.5 10645.0 10643.0 10638.0 10633.5 10622.5 10615.5 10614.5 10604.0 10593.5 10590.0 10584.0 10578.5 10576.0 10575.5 10573.0 10571.0 10567.5 10561.5 10553.0 10551.5 10548.5 10537.0 10536.0 10530.5 10523.5 10521.0 10513.5 10511.0 10509.0 10770.0 10767.0 10765.0 10760.5 10753.0 10743.5 10739.0 10733.0 10717.0 10708.5 10700.0 10686.0 10681.5 10674.0 10656.0 10651.0 10649.0 10639.5 10626.5 10620.0 10588.5 10580.5 10576.0 10573.5 10568.5 10554.5 10536.5 10530.0 10520.0 10517.0 10506.5 10502.5 10776.0 10765.5 10753.5 10738.0 10731.0 10708.0 10704.5 10700.5 10688.5 10669.5 10657.5 10647.0 10640.0 10620.0 10602.5 10590.0 10577.0 10569.0 10564.0 10561.5 10554.5 10545.0 10541.5 10531.5 10526.0 10508.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 13 10501.0 10488.5 10476.0 10460.5 10427.5 10423.5 10418 5 10405 5 10399 5 10392 5 10391 0 10389 5 10381 0 10380 5 10375 5 10371 5 10367 5 10363 5 10353 5 10345 5 10339 0 10331 5 10326 0 10316 0 10314 5 10305 5 10302 0 10295.5 10293.5 10281.0 10277.5 10276.5 10272.0 10262.5 10260.0 10253.5 10249.5 10243.5 10242.0 10241.0 10232.0 10220.5 10198.5 10196.0 10194.0 10186.5 10185.5 10178.0 10176.5 10175.0 10170.5 10165.5 10150.0 10142.5 10136.0 10497.0 10483.5 10472.5 10423.0 10419.5 10415.0 10396.0 10391.0 10385.5 10378.0 10371.5 10367.5 10365.0 10360.0 10350.5 10340.5 10336.5 10328 5 10323 0 10310 0 10308 0 10303 0 10299 0 10290 5 10276.5 10272.5 10271.0 10268.5 10255.0 10248.5 10240.0 10237.5 10228.0 10193.5 10192.5 10184.0 10173.0 10162.5 10139.5 10455.0 10401.0 10385.5 10370.5 10293.5 10262.5 10247.5 10238.0 10217.0 10197.5 10181.5 10175.0 10172.5 10167.5 10148.5 10134.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 14 10126. 10122. 10114. 10110. 10106. 10103 10098 10097 10094 10091 10O88 10O88 10080 10079 10078 10074 100 $ 5 10121.5 0 10118.5 5 10110.5 0 10108.0 5 10103.0 5 10100.5 5 10095.0 0 10095.5 5 10092.5 5 10088.0 5 10085.0 0 10084.5 5 10077.5 5 10077.5 0 10075.0 5 10071.0 0 96.5 98.0 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #1 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 15 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NI]FZB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 SBHNTDTP CU 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1022565 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11545. 000 SIGM. TDTP 26. 201 TPHI. TDTP 44. 563 SBHF. TDTP SBHN. TDTP 18.374 SIGC. TDTP 0.000 SIBH. TDTP 18.374 TRAT. TDTP SDSI. TDTP O. 812 BACK. TDTP 152. 552 FBAC. TDTP 55. 811 TCAN. TDTP TCAF. TDTP 8286.881 TCND. TDTP 14716.057 TCFD. TDTP 4544.315 TSCN. TDTP TSCF. TDTP 1304.441 INND.TDTP 719.625 INFD. TDTP 301.823 GRCH. TDTP TENS. TDTP 86. 000 CCL. TDTP O . 000 DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 10061 500 -999 250 -999 250 -999 250 -999 250 -999 250 39. 628 2. 029 25039. 906 3924. 400 -999.250 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP -999. 250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCND.TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 INND.TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 26.216 CCL. TDTP -999. 250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13 '.38 PAGE: 16 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE . 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~ff4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11522.0 9600.5 TDTP 11547.0 9600.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88886.0 88890.0 11541.5 11543.5 11531.5 11532.5 11496.5 11497.5 11486.0 11488.5 11473.0 11471.0 11456.0 11453.5 11446.0 11448.5 11445.0 11442.0 11434.5 11438.0 11423.5 11422.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 17 11422.0 11420.0 11417.5 11416.0 11400.5 11400.5 11389.5 11390.5 11389.0 11388.5 11377.5 11375.5 11367.0 11370.5 11361.5 11358.5 11360.0 11361.5 11357.5 11358.0 11351.0 11348.5 11345.5 11340.5 11343.0 11344.0 11315.5 11316.0 11311.5 11317.0 11294.5 11300.0 11294.0 11293.5 11290.5 11295.5 11284.0 11285.5 11283.0 11283.0 11275.0 11274.5 11277.5 11260.0 11261.5 11256.0 11256.5 11247.5 11248.5 11244.5 11245.0 11232.0 11232.0 11230.5 11231.5 11225.0 11225.0 11215.5 11214.5 11209.0 11208.5 11196.5 11195.0 11189.0 11189.0 11160.5 11159.5 11159.0 11158.0 11152.0 11150.0 11141.0 11142.5 11138.0 11136.0 11118.0 11118.5 11117.5 11117.0 11106.0 11106.0 11104.0 11103.5 11080.5 11080.0 11077.0 11078.5 11072.0 11071.5 11069.5 11069.0 11065.0 11065.5 11063.5 11064.0 11049.5 11050.5 11048.5 11048.0 11045.5 11047.0 11031.5 11033.0 11033.0 11026.5 11028.0 11023.0 11024.5 11009.5 11014.5 11006.5 11007.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 18 11003 0 10995 0 10991 5 10990 5 10979 5 10965 5 10952 0 10951 5 10942 0 10936 5 10936 0 10923 0 10916 0 10914 0 10908 0 10902 0 10889.0 10885.0 10876.5 10874.5 10868.5 10855.0 10847.0 10844.0 10830.0 10824.5 10820.0 10815.5 10806.5 10803.5 10797.0 10795.5 10790.0 10780.0 10775.0 10767.5 10758.5 10754.5 10751.5 10745.0 10743.5 10734.0 10729.0 10713.5 10707.5 10700.5 10700.0 10698.5 10690.5 10689.0 10678.5 10675.5 10673.0 10671.0 10670.0 11005.0 10996.5 10993.0 10981.0 10950.5 10942.0 10936.5 10924.5 10915.5 10910.5 10888.5 10847.5 10821.0 10790.0 10769.5 10767.0 10753.5 10749.0 10739.0 10708.5 10696.5 10695.0 10686.5 10673.5 10666.0 10662.0 10991.0 10968.5 10952.5 10938.0 10915.5 10904.0 10885.5 10875.0 10874.0 10867.5 10854.0 10841.0 10827.5 10823.0 10812.5 10806.0 10802.0 10796.5 10789.5 10776.5 10770.0 10753.5 10746.5 10737.5 10734.0 10712.0 10704.5 10700.0 10695.5 10680.5 10676.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 19 10661 0 10660 0 10659 0 10652 0 10649 0 10644 5 10643 0 10636 5 10634 0 10625 5 10620 0 10616 0 10604 5 10599 0 10594 0 10593 5 10585 5 10582 5 10582 0 10578 5 10571 0 10558.0 10557.5 10551.5 10546.0 10544.0 10534.5 10529.5 10522.5 10518.0 10501.0 10500.0 10495.5 10488.5 10485.5 10481.5 10471.0 10470.0 10458.0 10454.0 10452.5 10449.0 10442.0 10428.5 10423.5 10421.0 10419.5 10417.5 10402.0 10396.5 10395.5 10387.5 10378.0 10372.0 10351.0 10656.0 10627.0 10615.5 10588.5 10576. 0 10573.5 10554.5 10530.0 10519.5 10496.5 10491.5 10482.5 10477.0 10466.5 10447.5 10437. 0 10419.5 10417.5 10415. 0 10399.5 10392.5 10668.5 10666.0 10658.0 10654.5 10650.0 10647.5 10640.0 10630.5 10619.5 10602.5 10597.0 10589.5 10581.5 10577.0 10565.0 10554.0 10547.0 10541.5 10538. 0 10530. 0 10526. 0 10512.5 10496.0 10481.5 10466.5 10454.5 10450.0 10444. 0 10425. 0 10419.5 10395.0 10386.0 10375.0 10370.5 10351.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 2O 10335.5 10330.0 10307.5 10297.5 10294.0 10291.5 10279.5 10278.0 10277.5 10268.5 10263.5 10253.5 10253.0 10247.5 10241.5 10241.0 10233.5 10220.5 10205.0 10201.5 10198.5 10194.0 10186.0 10185 0 10177 5 10175 0 10174 0 10169 5 10167 0 10166 0 10149 5 10143.5 10141.5 10138.0 10136.0 10130.5 10126.0 10120.0 10119.0 10113.0 10112.5 10104.5 10103.5 10102.0 10099.0 10098.0 10092.5 10091.0 10090.0 10087.5 10085.5 10082.0 10080.0 10078.5 10078.0 10291.0 10272.5 10245.0 10233.0 10197.5 10172.5 10164.5 10147.0 10139.5 10134.5 10118.5 10110.5 10103.0 10101.0 10094.5 10091.0 10088.5 10084.0 10077.5 10076.0 10334.5 10328.5 10302.0 10293.5 10286.5 10277.0 10275.0 10265.5 10261.5 10254.0 10247.5 10237.5 10231.0 10217.0 10205.0 10201.0 10198.5 10192.5 10184.5 10182.0 10176.0 10172.5 10167.5 10164.5 10148.5 10144.0 10138.5 10135.0 10125.5 10119.5 10111.5 10100.0 10095.5 10087.5 10084.5 10080.5 10078.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 21 10072 10071 10064 10061 10052 10049 10048 10045 10042 10036 100 $ · 0 10068.5 0 10071.0 0 10059.0 5 10062.0 0 10052.0 5 10048.5 5 10048.5 5 10045.5 0 10042.0 5 10037.0 0 100.5 100.0 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE DOWN PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE DOWN PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA BASE DOWN PASS #1 AND SIGMA BASE PASS #1, TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * .............................. TYPE REPR CODE VALUE 1 2 3 4 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 88 66 1 0.5 FT 11 0 FT 68 1 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 22 ** 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 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1022565 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11545. 000 SIGM. TDTP 15. 682 TPHI. TDTP 29. 440 SBHF. TDTP 25. 431 SBHN. TDTP 42. 878 SIGC. TDTP 1 . 222 SIBH. TDTP 78. 951 TRAT. TDTP 1 . 993 SDSI. TDTP 0.464 BACK. TDTP 311.778 FBAC. TDTP 300.621 TCAN. TDTP 41914.906 TCAF. TDTP 16237.543 TCND. TDTP 28779. 648 TCFD. TDTP 9932. 762 TSCN. TDTP 11494.104 TSCF. TDTP 4452.735 INND. TDTP 810.320 INFD. TDTP 323.165 GRCH. TDTP -999.250 TENS. TDTP 86. 000 CCL. TDTP O. 000 DEPT. 9600. 000 SIGM. TDTP 20. 850 TPHI. TDTP 34.174 SBHF. TDTP 23 . 563 SBHN. TDTP 64 . 807 SIGC. TDTP O. 000 SIBH. TDTP 193 . 605 TRAT. TDTP 1 . 856 SDSI. TDTP 0.958 BACK. TDTP 90.546 FBAC. TDTP 160.782 TCAN. TDTP 8372.631 TCAF. TDTP 3197.794 TCND. TDTP 17203.902 TCFD. TDTP 5682.218 TSCN. TDTP 4824.130 TSCF. TDTP 1842. 500 INND. TDTP 545. 193 INFD. TDTP 266. 551 GRCH. TDTP -999. 250 TENS. TDTP 85. 000 CCL. TDTP -2. 406 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 23 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE · 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11532.0 9998.5 TDTP 11544.5 10000.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 11538.0 11536.5 11525 0 11518 5 11507 5 11500 0 11484 0 11480 5 11460 0 11458 5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88896.0 88887.5 11537.5 11533.5 11523.5 11515.5 11507.5 11498.0 11484.0 11481.0 11468.0 11460.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 24 11436.0 11432.5 11431.0 11420.5 11414.5 11413.5 11403.5 11397.0 11391.0 11384.0 11382.0 11378.5 11367.5 11363.5 11363.0 11358.5 11352.5 11349.0 11342.5 11339.0 11330.5 11325.0 11324.5 11321.5 11317 5 11311 0 11302 5 11298 0 11291 5 11289 0 11273 0 11268 0 11267 5 11244 0 11234 0 11232 0 11228.5 11227.0 11225.5 11221.0 11220.5 11211.5 11200.5 11193.0 11190.0 11176.0 11163.5 11160.0 11159.0 11144.5 11140.0 11134.5 11130.0 11126.0 11125.5 11439.0 11426.5 11422.0 11365.0 11349.0 11327.0 11314.5 11292.5 11273.0 11234.0 11232.5 11225.5 11202.0 11195.0 11192.0 11158.0 11138.0 11125.0 11438.5 11435.0 11416.0 11406.0 11399.5 11393.5 11387.5 11384.5 11382.5 11370.5 11367.5 11360.5 11353.0 11344.0 11338.5 11331.0 11326.0 11321.5 11317.5 11302.5 11297.5 11292.5 11273.5 11266.0 11239.5 11232.0 11229.5 11224.5 11219.0 11209.5 11197.0 11186.0 11174.5 11161.0 11157.5 11143.0 11138.0 11135.0 11127.0 11123.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 25 11121 0 11120 5 11117 5 llllO 5 11102 5 11101 5 11097 5 11093 0 11092 5 11083.0 11082.0 11075.0 11072.0 11071.0 11070.5 11062.5 11059.0 11044.0 11039.0 11024.5 11009.5 11007.5 11006.0 11004.0 10994.0 10987.0 10984.0 10981.5 10980.0 10977.5 10969.5 10967.5 10955.5 10953.5 10941 0 10928 5 10928 0 10923 0 10920 0 10911 0 10908 5 10900 0 10897 0 10886 5 10883 0 10881 5 10879 5 10877 5 10869 5 10862.5 10860.0 10848.5 10839.5 10831.5 10827.5 11121.5 11092.0 11082.0 11071.5 11069.5 11064.0 11060.5 11046.5 11024.5 11008.5 11005.0 11002.5 10980.5 10957.0 10941.5 10929.5 10925.0 10910.5 10880.5 11119.5 11115.5 11109.0 11101.5 11099.0 11097.0 11091.0 11084.0 11074.5 11069.5 11036.0 11008.0 10993.5 10984.0 10981.0 10976.5 10974.0 10968.0 10965.0 10951.5 10927.0 10920.0 10919.0 10909.0 10898.0 10894.5 10884.5 10877.5 10875.0 10873.0 10867.5 10860.5 10858.0 10846.0 10836.0 10828.0 10823.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 26 10822 0 10820 0 10808 0 10804 5 10803 0 10798 5 10793 5 10788.5 10786.0 10783.0 10782.0 10778.5 10775.0 10769.0 10760.0 10758.5 10752.0 10743.0 10735.0 10731.5 10716.0 10712.0 10700 0 10695 5 10691 0 10688 0 10686 0 10682 5 10676.0 10662.5 10658.5 10653.5 10651.5 10634.5 10633.0 10621.0 10619.0 10615.5 10609.5 10595.0 10574.0 10568.0 10566.5 10565.0 10563.0 10562.5 10556.5 10551.5 10547.5 10546.5 10536.0 10530.5 10522.5 10520. 5 10518.5 10820.5 10798.5 10793.0 10777.0 10767.0 10764.5 10753.0 10708.5 10681.0 10673.5 10651.0 10646.0 10611.5 10558.0 10556.5 10554.5 10546.5 10536.0 10529.5 10512.5 10816.5 10805.5 10798.5 10788.0 10784.0 10782.5 10777.5 10774.0 10759.5 10753.0 10746.0 10738.5 10734.0 10715.5 10704.0 10700.5 10692.5 10688.5 10680.5 10668.5 10657.0 10640.0 10635.0 10625.0 10621.0 10617.5 10589.0 10569.0 10561.0 10555.0 10545.0 10541.5 10526.0 10517.5 10514.5 10513.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 27 10513 5 10509 5 10507 5 10501 5 10488 5 10482 0 10475 5 10463 0 10455 0 10450 5 10447 0 10433 5 10423 5 10420 5 10419 5 10414 5 10414 0 10405 5 10395 5 10391 0 10389 0 10385 5 10383 0 10376 5 10368 5 10366 5 10356 0 10348.0 10335.5 10333.0 10332.0 10317.0 10307.5 10297.0 10295.0 10290.0 10285.5 10276.5 10267.5 10266.5 10263.5 10259.5 10254.0 10248.0 10241.0 10224.5 10218.0 10213.0 10206.0 10201.5 10198.5 10192.0 10180.0 10178.5 10174.0 10502.5 10483.0 10449.0 10419.0 10417.5 10412.5 10391.0 10385.0 10380.0 10375.0 10365.0 10328.5 10290.5 10272.5 10264.5 10248.5 10197.5 10176.0 10507.5 10505.0 10496.0 10479.5 10470.5 10457.5 10445.5 10442.0 10430.0 10416.0 10409.0 10401.5 10377.5 10368.0 10359.0 10351.0 10342.0 10331.0 10326.0 10314.5 10305.0 10298.5 10291.0 10286.5 10267.5 10266.0 10260.5 10246 5 10238 0 10222 5 10218 5 10212 5 10205 5 10197.5 10191.0 10175.5 10172.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 28 10173.0 10168.0 10169.5 10167.5 10164 . 0 10162.5 10154.5 10154.5 10149.0 10148.5 10148.5 10146.5 10141.5 10139.0 10136.0 10133.0 10113.0 10112.0 10101.5 10102.5 10095.0 10096.0 10092.5 10092.5 10090.5 10089.5 10090.0 10088.5 10086.5 10085.5 10082.5 10080.5 10078.5 10077.5 10071.0 10070.5 10065.5 10066.0 100.0 98.5 100.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX DOWN PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX DOWN PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA BORAX DOWN PASS #1 AND SIGMA BASE PASS #1, TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 29 TYPE REPR CODE VALUE 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 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN TDTP CU 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 1022565 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11544. 500 SIGM. TDTP 25. 904 TPHI. TDTP 33 . 420 SBHF. TDTP 34. 291 SBHN. TDTP 17. 940 SIGC. TDTP O. 000 SIBH. TDTP 17. 940 TRAT. TDTP 1. 748 SDSI. TDTP 1 . 019 BACK. TDTP 299. 311 FBAC. TDTP 425. 175 TCAN. TDTP 20835. 570 TCAF. TDTP 7720.825 TCND. TDTP 13918.146 TCFD. TDTP 4588.901 TSCN. TDTP 3396.052 TSCF. TDTP 1313.805 INND. TDTP 697.603 INFD. TDTP 292.731 GRCH. TDTP -999.250 TENS. TDTP 85. 000 CCL. TDTP O. 000 DEPT. 9998.500 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND.TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 413.054 TENS.TDTP -999.250 CCL.TDTP -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 2i-MAY-1998 13:38 PAGE: 30 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 mATE · 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 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 .......................... TDTP $ REMARKS: THIS FILE CONTAINS EDITED BASE PASS #1. NO AVERAGE WAS CALCULATED BECAUSE ONLY ONE UP BASE PASS WAS LOGGED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 31 TYPE REPR CODE VALUE 7 65 8 68 O. 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 NUMB SAMP ELEM CODE (HEX) DEPT FT 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PNAV CU 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PNAV PU-S 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PNAV CU 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN PNAV CU 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PNAV CU 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PNAV CU 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PNAV 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PNAV CU 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN PNAV CPS 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF PNAV CPS 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 TCND PNAV CPS 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD PNAV CPS 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PNAV CPS 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PNAV CPS 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 INND PNAV CPS 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 INFD PNAV CPS 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 1022565 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11545.000 SIGM. PNAV 15.353 TPHI.PNAV 32.558 SBHF. PNAV 25.854 SBHN. PNAV 39.351 SIGC. PNAV 1.917 SIBH. PNAV 66.526 TRAT. PNAV 2.120 SDSI.PNAV 0.260 BACK. TDTP 156. 739 FBAC. TDTP 51.300 TCAN. PNAV 65357.594 TCAF. PNAV 24030. 668 TCND.PNAV 30967.395 TCFD.PNAV 9938.264 TSCN. PNAV 12329.264 TSCF. PNAV 4533.222 INND.PNAV 828.337 INFD.PNAV 321.033 GRCH. TDTP -999.250 DEPT. 10036.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 32 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP 25.311 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE : 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE : 98/05/21 MA~YREC 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: 1 DEPTH INCREMENT: O. 5000 FILE SUNk4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11573 . 5 10008.0 TDTP $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 22-JAN-98 8C0-609 2113 22-JAN-98 11680.0 9600.0 11551.0 1800.0 TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 33 GR GA~A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CGRS-A TDT- P 3. 750 11678.0 Produced Fluids 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): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger This log was depth referenced to a Sperry-Sun MWD log, dated 07-Aug-1997 First pass was made with well flowing from PBTD to 10100' Temperature & Pressure. Second pass was made after a 250 bbl of crude pumped in to fluid pack (baseline) the wellbore @ 1800 ft/hr. All depth correlations witnessed by co. rep. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 34 ** 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 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 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS1 CU 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PSi PU 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PSi CU 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNPS1 CU 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS1 CU 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS1 CU 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS1 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS1 CU 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS1 CPS 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS1 CPS 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 TCAN PS1 CPS 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PS1 CPS 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 TCND PS1 CPS 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PS1 CPS 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PSI CPS 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS1 CPS 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 INND PS1 CPS 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS1 CPS 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PSi LB 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 PPRE PS1 PSI 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 PTEM PS1 DEGF 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS1 V 1022565 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 35 ** DATA ** DEPT. 11545.000 SIGM. PS1 15.877 TPHI.PS1 31.606 SBHF. PS1 SBHN. PS1 32.576 SIGC. PS1 2.226 SIBH. PS1 34.235 TRAT. PS1 SDSI.PS1 0.326 BACK. PSi 171.585 FBAC. PS1 50.030 TCAN. PS1 TCAF. PS1 24120.555 TCND.PS1 30667.730 TCFD. PS1 10068.781 TSCN. PS1 TSCF. PS1 4572.761 IN-ND.PSi 804.130 INFD.PS1 318.041 TENS.PSi PPRE. PS1 3657.017 PTEM. PS1 182.465 GR.PS1 348.056 CCL.PS1 DEPT. 10008.000 SIGM. PS1 12.782 TPHI.PS1 17.121 SBHF. PS1 SBHN. PS1 46.770 SIGC. PS1 0.712 SIBH. PS1 81.234 TRAT. PS1 SDSI.PS1 0.130 BACK. PSi 287.563 FBAC. PS1 41.359 TCAN. PS1 TCAF. PS1 42341.469 TCND. PS1 33713.055 TCFD. PS1 15605.453 TSCN. PS1 TSCF. PS1 8032.575 INND.PS1 665.933 INFD.PS1 383.629 TENS.PSi PPRE. PS1 4469.488 PTEM. PS1 154.189 GR.PS1 19.895 CCL.PS1 28. 2. 64025. 12137. 86. O. 24. 1. 83223. 15788. 84. -999. 251 063 102 842 000 000 563 598 969 369 000 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE . FLIC VERSION · O01CO1 DATE · 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION . O01CO1 DATE : 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SU~E4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 11576.5 10034.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 36 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): 22-JAN-98 8C0-609 2113 22-JAN-98 11680.0 9600.0 11551.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAlV~4A RAY TDTP THERMAL DECAY $ TOOL NTJAI~ER CGRS-A TDT-P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 3. 750 11678.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Produced Fluids 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): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger This log was depth referenced to a Sperry-Sun MWD log, LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 37 dated 07-Aug-1997 First pass was made with well flowing from PBTD to 10100~ Temperature & Pressure. Second pass was made after a 250 bbl of crude pumped in to fluid pack (baseline) the wellbore @ 1800 ft/hr. Ail depth correlations witnessed by co. rep. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #1. $ 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 O. 5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM BX1 CU 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI BX1 PU 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF BX1 CU 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 SBHN BX1 CU 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC BX1 CU 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH BX1 CU 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT BX1 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI BX1 CU 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 BACK BX1 CPS 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC BX1 CPS 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 TCANBX1 CPS 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 38 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) TCAF DX1 CPS 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 TCNDBX1 CPS 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD DX1 CPS 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN DX1 CPS 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF DX1 CPS 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 INNDBX1 CPS 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 INFD BX1 CPS 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 TENS DX1 LB 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 PPRE DX1 PSI 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 PTEMBX1 DEGF 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 GR DX1 GAPI 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 CCL DX1 V 1022565 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11545 000 SIGM. BX1 26.568 TPHI.BX1 43.707 SBHF.BX1 34.633 SBHN. BX1 15 328 SIGC.BX1 0.000 SIBH. BX1 15.328 TRAT.BX1 1.995 SDSI.BX1 0 689 BACK.DX1 169.693 FBAC.BX1 54.049 TCAN. BX1 28884.363 TCAF. BX1 9541 088 TCND.BX1 14397.152 TCFD.BX1 4420.436 TSCN. BX1 3717.099 TSCF. BX1 1256 659 INND.BX1 684.328 INFD.BX1 290.471 TENS.DX1 85.000 PPRE.BX1 5214 127 PTEM. BX1 168.958 GR.BX1 273.472 CCL.BX1 0.000 DEPT. 10034 000 SIGM. BX1 12.378 TPHI.BX1 19.208 SBHF.BX1 19.647 SBHN. BX1 31 223 SIGC.BX1 3.206 SIBH. BX1 31.223 TRAT.BX1 1.707 SDSI.BX1 0 216 BACK. DX1 209.414 FBAC.BX1 45.235 TCAN. BX1 68177.578 TCAF. BX1 32222 438 TCND.BX1 30470.258 TCFD.BX1 12657.693 TSCN. BX1 13731.791 TSCF. BX1 6489 989 INND.BX1 669.922 INFD.BX1 401.013 TENS.DX1 85.000 PPRE. BX1 5493 686 PTEM. BX1 125.649 GR.BX1 24.395 CCL.BX1 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE . FLIC VERSION · O01CO1 DATE . 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 39 **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION · O01CO1 DATE : 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~fl~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11564.0 9568.0 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~k4A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 22-JAN-98 8C0-609 2113 22-JAN-98 11680.0 9600.0 11551.0 1800.0 TOOL NUMBER ........... CGRS-A TDT-P 3.750 11678.0 Produced Fluids LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 4O FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger This log was depth referenced to a Sperry-Sun MWD log, dated 07-Aug-1997 First pass was made with well flowing from PBTD to 10100' Temperature & Pressure. Second pass was made after a 250 bbl of crude pumped in to fluid pack (baseline) the wellbore @ 1800 ft/hr. All depth correlations witnessed by co. rep. THIS FILE CONTAINS THE RAW DATA FOR BASE DOWN PASS #1. $ 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 41 TYPE REPR CODE VALUE 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 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PSD CU 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PSD PU 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF PSD CU 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 SBHN PSD CU 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PSD CU 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH PSD CU 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PSD 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI PSD CU 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 BACK PSD CPS 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PSD CPS 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 TCAN PSD CPS 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 TCAF PSD CPS 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 TCND PSD CPS 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD PSD CPS 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN PSD CPS 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF PSD CPS 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 INND PSD CPS 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 INFD PSD CPS 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PSD LB 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 PPRE PSD PSI 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 PTEM PSD DEGF 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 GR PSD GAPI 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PSD V 1022565 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 11545.000 SIGM. PSD 13.477 TPHI.PSD 27.398 SBHF. PSD SBHN. PSD 34.524 SIGC. PSD 3.327 SIBH. PSD 42.594 TRAT. PSD SDSI.PSD 0.522 BACK. PSD 303.227 FBAC.PSD 298.485 TCAN. PSD TCAF. PSD 16282.836 TCND. PSD 28503.367 TCFD. PSD 9922.672 TSCN. PSD TSCF. PSD 4465.156 INND.PSD 744.601 INFD. PSD 294.377 TENS.PSD PPRE. PSD 3716.114 PTEM. PSD 181.880 GR.PSD 457.934 CCL. PSD DEPT. 9590.000 SIGM. PSD 28.995 TPHI.PSD 39.311 SBHF. PSD SBHN. PSD 93.188 SIGC. PSD 0.000 SIBH. PSD 333.837 TRAT. PSD SDSI.PSD 1.575 BACK. PSD 100.415 FBAC. PSD 204.687 TCAN. PSD TCAF. PSD 3297.611 TCND.PSD 17957.816 TCFD.PSD 6277.345 TSCN. PSD 20 830 2 008 42078 219 11538 889 86 000 0 000 30.434 1.677 8283.430 4733.539 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 42 TSCF. PSD 1883.183 INND. PSD PPRE. PSD 3667.398 PTEM. PSD 454.014 INFD.PSD 159.818 GR.PSD 450.469 TENS.PSD 282.195 CCL.PSD 85.000 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE · FLIC VERSION · O01CO1 DATE · 98/05/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11565.5 9950.5 TDTP $ LOG HEADER DATA DATE LOGGED: 22 -JAN- 98 SOFTWARE VERSION: 8C0-609 TIME LOGGER ON BOTTOM: 2113 22-JAN-98 TD DRILLER (FT) : 11680.0 TD LOGGER (FT) : TOP LOG INTERVAL (FT) : 9600.0 BOTTOM LOG INTERVAL (FT) : 11551.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 43 VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS-A TDT-P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 3. 750 11678.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Produced Fluids 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): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS) .. 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger This log was depth referenced to a Sperry-Sun MWD log, dated 07-Aug-1997 First pass was made with well flowing from PBTD to 10100' Temperature & Pressure. Second pass was made after a 250 bbl of crude pumped in to fluid pack (baseline) the wellbore @ 1800 ft/hr. Ail depth correlations witnessed by co. rep. THIS FILE CONTAINS THE RAW DATA FOR BORAX DOWN PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 44 ** 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 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~I CODE (HEX) DEPT FT 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM BXD CU 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI BXD PU 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF BXD CU 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 SBHN BXD CU 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC BXD CU 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH BXD CU 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT BXD 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI BXD CU 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 BACK BXD CPS 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC BXD CPS 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 TCANBXD CPS 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 TCAF BXD CPS 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 TCND BXD CPS 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD BXD CPS 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN BXD CPS 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF BXD CPS 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 INND BXD CPS 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 INFD BXD CPS 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 TENS BXD LB 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 PPRE BXD PSI 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 PTEMBXD DEGF 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 GR BXD GAPI 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 CCL BXD V 1022565 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing S¢'~lumberger Alaska Computing Center 21-MAY-1998 13:38 PAGE: 45 ** DATA ** DEPT. 11545. 000 SIGM. BXD 25. 904 TPHI.BXD 33. 420 SBHF. BXD SBHN. BXD 17. 940 SIGC.BXD O. 000 SIBH. BXD 17. 940 TR~T. BXD SDSI.BXD 1.019 BACK.BXD 299.311 FBAC. BXD 425.175 TCAN. BXD TCAF. BXD 7720. 825 TCND. BXD 13918. 146 TCFD. BXD 4588. 901 TSCN. BXD TSCF. BXD 1313. 805 INND.BXD 697. 603 INFD.BXD 292. 731 TENS.BXD PPRE. BXD 5307. 969 PTEM. BXD 163. 019 GR. BXD 576. 731 CCL. BXD DEPT. 9950. 500 SIGM. BXD 17. 804 TPHI. BXD 22. 808 SBHF. BXD SBHN. BXD 84. 405 SIGC. BXD O. 000 SIBH. BXD 241. 472 TRAT.BXD SDSI.BXD 0.232 BACK.BXD 256.275 FBAC.BXD 189.082 TCAN. BXD TCAF. BXD 4013.927 TCND.BXD 17320.203 TCFD.BXD 6832.542 TSCN. BXD TSCF. BXD 2042.923 INND.BXD 3470.896 INFD.BXD 357.953 TENS.BXD PPRE.BXD 5221.901 PTEM. BXD 125.199 GR.BXD 546.944 CCL.BXD 34. 291 1. 748 20835.570 3396. 052 85. 000 O. 000 99. 268 1. 590 9014. 154 4654. 828 85. 000 -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/21 MA~REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/05/21 ORIGIN : FLIC TAPE NAME : 98236 CONTINUATION # : 1 PREVIOUS TAPE COMMENT : ARCO ALASKA INC, D.S. 02-09B, PRUDHOE BAY, 50-029-20153-02 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/05/21 ORIGIN : FLIC REEL NAME · 98236 CONTINUATION # : PREVIOUS REEL : CO~4~ENT : ARCO ALASKA INC, D.S. 02-09B, PRUDHOE BAY, 50-029-20153-02 Sperry-Sun Drilling Services LIS Scan Utility Wed Sep 24 14:27:17 1997 Reel Header Service name ............. LISTPE Date ..................... 97/09/24 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 ..................... 97/09/24 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 2-09B PB1 500292015372 ARCO ALASKA, INC. SPERRY'-SLKN DRILLING SERVICES 24-SEP-97 MWD RUN 1 AK-MW-70232 A. WORTHINGT GARY GOODRIC MWD RUN 2 AK-MW-70232 A. WORTHINGT GARY GOODRIC MWD RUN 3 AK-MW-70232 A. WORTHINGT GARY GOODRI C JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: MWD RUN 4 AK-MW-70232 A. WORTHINGT ARVELL BASS MWD RUN 5 AK-MW-70232 A. WORTHINGT ARVELL BASS 36 llN 14E 1216 FWL: 971 ELEVATION (FT FROM MSL 0) KELLY BUSHING: 58.00 DERRICK FLOOR: .00 GROUND LEVEL: .00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.375 2130.0 2ND STRING 9.625 9021.0 3RD STRING 7.000 9609.0 PRODUCTION STRING 3.750 10342.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL TRUE VERTICAL DEPTHS (TVD) ARE SUB-SEA TRUE VERTICAL DEPTHS (SSTVD). 3. MWD RUNS 1 THROUGH 5 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTOR. 4. MWD RUN 6 MADE NO FOOTAGE AND IS NOT PRESENTED. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN DOUG KNOCK OF ARCO ALASKA, INC. AND ALI TURKER OF SPERRY-SUN DRILLING SERVICES ON 08/19/97. 6. MWD RUNS 1 THROUGH 5 REPRESENT WELL 2-09B PB1 WITH API#: 50-029-20153-72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10342'MD, 8822'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 · Date of Generation ....... 97/09/24 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 9560.0 10314.5 ROP 9584.0 10341.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 9183.0 9628.0 2 9628.0 9790.0 3 9790.0 9830.0 4 9830.0 10070.0 5 10070.0 10342.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9560 10341.5 9950.75 1564 9560 GR 20.46 346.78 50.4443 1510 9560 ROP 3.94 615.5 56.2785 1516 - 9584 Last Reading 10341.5 10314.5 10341.5 First Reading For Entire File .......... 9560 Last Reading For Entire File ........... 10341.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9560.0 9603.0 ROP 9584.0 9628.0 $ LOG HEADER DATA DATE LOGGED: 03-AUG-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 9628.0 9183.0 9628.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP SPC 317 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.800' 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: BIOZAN/SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .000 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF IN): EWR FREQUENCY HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9560 9628 9594 137 9560 GR 22.88 346.78 91.2962 87 9560 ROP 30.11 69.14 53.8037 89 9584 Last Reading 9628 9603 9628 First Reading For Entire File .......... 9560 Last Reading For Entire File ........... 9628 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/24 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 9603.5 9763.0 ROP 9628 . 5 9790.0 $ LOG HEADER DATA DATE LOGGED: 05-AUG-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 29.5 MAXIMUM ANGLE: 40.3 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 9790.0 9628.0 9790.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP SPC 317 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.250 4.3 BOREHOLE CONDITIONS MUD TYPE: , FLO-PRO MUD DENSITY (LB/G): 9.i0 MUD VISCOSITY (S) : .0 MUD PH: 9.8 MUD CHLORIDES (PPM) : FLUID LOSS (C3) : 6.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 49.2 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .3 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 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 ROP MWD 2 FT/H 4 1 68 Code Offset 0 4 8 Channel 1 2 3 Name Min Max Mean Nsam DEPT 9603.5 9790 9696.75 374 GR 29.19 135.15 43.4684 320 ROP 9.57 124 47.496 324 First Reading 9603.5 9603.5 9628.5 Last Reading 9790 9763 9790 First Reading For Entire File .......... 9603.5 Last Reading For Entire File ........... 9790 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/24 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 BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 for each bit run in separate files. FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9763.5 ROP 9790.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined STOP DEPTH 9802.5 9829.0 06-AUG- 97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 9830.0 9790.0 9830.0 37.6 40.3 TOOL NUMBER NGP SPC 40 3.750 3.8 FLO- PRO 9.20 .0 9.2 5.4 .000 .000 .000 .000- 51.6 .3 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9763.5 9829 9796.25 132 9763.5 GR 26.24 129.96 49.5157 79 9763.5 ROP 3.94 38.6 14.4454 78 9790.5 Last Reading 9829 9802.5 9829 First Reading For Entire File .......... 9763.5 Last Reading For Entire File ........... 9829 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/24 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 ....... 97/09/24 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 GR ROP $ START DEPTH STOP DEPTH 9803.0 10042.5 9829.5 10069.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 07 -AU G- 97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 10070.0 9830.0 10070.0 35.2 42.5 TOOL NUMBER NGP SPC 40 3.750 3.8 FLO- PRO 9.00 .0 9.6 6.5 .000 .000 .000 .000 51.6 .3 - Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 4 AAPI 4 1 68 ROP MWD 4 FT/H 4 1 68 0 1 4 2 8 3 Name Min Max Mean Nsam DEPT 9803 10069.5 9936.25 534 GR 20.95 145.03 33.5204 480 ROP 18.16 343.6 57.6454 481 First Last Reading Reading 9803 10069.5 9803 10042.5 9829.5 10069.5 First Reading For Entire File .......... 9803 Last Reading For Entire File ........... 10069.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/24 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 ....... 97/09/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 ' RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10043.0 10314.5 ROP 10070.0 10341.5 $ LOG HEADER DATA DATE LOGGED: 08-AUG-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 10342.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 10070.0 10342.0 44.7 85.0 TOOL NUMBER NGP SPC 40 3.750 3.8 FLO- PRO 9.00 .0 9.5 6.2 .000 .000 .000 .000 56.2 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam DEPT 10043 10341.5 10192.2 598 GR 20.46 173.87 63.0823 544 ROP 18.8 615.5 66.7036 544 Reading 10043 10043 10070 Reading 10341.5 10314.5 10341.5 First Reading For Entire File .......... 10043 Last Reading For Entire File ........... 10341.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/09/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/09/24 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 · Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Tue Sep 23 11:34:01 1997 Reel Header Service name ............. LISTPE Date ..................... 97/09/23 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 ..................... 97/09/23 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 2-09B 500292015302 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 23-SEP-97 SEP 2 6 1997 A~as~a Oil & Gas Con, s. C<~mmi~Y~ MWD RUN 1 AK-MW-70232 A. WORTHINGT GARY GOODRI C MWD RUN 2 AK-MW-70232 A. WORTHINGT GARY GOODRIC MWD RUN 3 AK-MW-70232 A. WORTHINGT GARY GOODRIC JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-70232 A. WORTHINGT ARVELL BASS MWD RUN 7 AK-MW- 70232 A. WORTHINGT ARVELL BAS S MWD RUN 8 AK-MW- 70232 A. WORTHINGT ARVELL BAS S JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION MWD RUN 9 AK-MW-70232 A. WORTHINGT ARVELL BASS SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 36 liN 14E 1216 971 58.00 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2130.0 9.625 9021.0 7.000 9609.0 3.750 11680.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 THROUGH 4 AND 7 THROUGH 9 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTOR. · 3. MWD RUN 6 MADE NO FOOTAGE AND IS NOT PRESENTED. 4. THIS WELL KICKS OFF FROM 2-09B PB1 AT 10060'MD, 8719'SSTVD. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN DOUG KNOCK OF ARCO ALASKA, INC. AND ALI TURKER OF SPERRY-SUN DRILLING SERVICES ON 08/19/97. 6. MWD RUNS 1 THROUGH 4 AND 7 THROUGH 9 REPRESENT WELL 2-09B WITH API#: 50-029-20153-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF l1680'MD, 8756'SSTVD. ' SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ - File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/23 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 9560.0 ROP 9584.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 MWD 4 MWD 7 MWD 8 MWD 9 $ REMARKS: MERGED MAIN PASS . $ 11652.5 11679.0 EQUIVALENT UNSHIFTED DEPTH MERGE TOP MERGE BASE 9584.0 9628.0 9628.0 9790.0 9790.0 9830.0 9830.0 10070.0 10060.0 10320.0 10320.0 10616.0 10616.0 11680.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT GR MWD ROP MWD Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 AAPI 4 1 68 · 4 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9560 11679 10619.5 4239 9560 GR 20.95 346.78 63.3272 4186 9560 ROP 3.94 3348 88.1298 4191 9584 Last Reading 11679 11652.5 11679 First Reading For Entire File .......... 9560 Last Reading For Entire File ........... 11679 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9560.0 ROP 9584.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9603.0 9628.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : 03-AUG-97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 9628.0 9183.0 9628.0 TOOL NUMBER NGP SPC 317 3.800 3.8 BIOZAN/SEAWATER .00 .0 .0 0 .0 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 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 1 FT/H 4 1 68 4 2 GR MWD 1 AAPI 4 1 68 8 3 68.0 First Name Min Max Mean Nsam Reading DEPT 9560 9628 9594 139 ' 9560 ROP 30.11 69.14 53.8037 89 9584 GR 22.88 346.78 91.2962 87 9560 First Reading For Entire File .......... 9560 Last Reading For Entire File ........... 9628 Last Reading 9628 9628 9603 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/23 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 SUM]VLARY VENDOR TOOL CODE START DEPTH GR 9603.5 ROP 9628.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9763.0 9790.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G)-' MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL 05-AUG-97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 9790.0 9628.0 9790.0 29.5 40.3 TOOL NUMBER NGP SPC 317 4.250 4.3 FLO- PRO 9.10 .0 9.8 6.4 .000 .000 .000 .000 49.2 Dat 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 .3 Name Service Order DEPT ROP MWD 2 GR MWD 2 Units Size Nsam Rep Code Offset Channel FT 4 1, 68 0 1 FT/H 4 1 68 4 2 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9603.5 9790 9696.75 374 9603.5 ROP 9.57 124 47.496 324 9628.5 GR 29.19 135.15 43.4684 320 9603.5 Last Reading 9790 9790 9763 First Reading For Entire File .......... 9603.5 Last Reading For Entire File ........... 9790 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/23 Maximum Physical Record..65535 File Type ................ LO Pzevious File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9763.5 ROP 9790.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9802.5 9829.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MA~X CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): 06-AUG- 97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 9830.0 9790.0 9830.0 37.6 40.3 TOOL NUMBER NGP SPC 40 3.750 3.8 FLO- PRO 9.20 .0 9.2 5.4 .000 .000 .000 .000 51.6 .3 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9763.5 9829 9796.25 132 9763.5 ROP 3.94 38.6 14.4454 78 9790.5 GR 26.24 129.96 49.5157 79 9763.5 Last Reading 9829 9829 9802.5 First Reading For Entire File .......... 9763.5 Last Reading For Entire File ........... 9829 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/23 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 ....... 97/09/23 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 GR 9803.0 ROP 9829.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10042.5 10060.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (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 07-AUG-97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 10070.0 9830.0 10070.0 35.2 42.5 TOOL NUMBER NGP SPC 40 3.750 3.8 FLO- PRO 9.00 .0 9.6 6.5 .000 .000 - .000 .000 51.6 .3 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9803 10060 9931.5 515 9803 ROP 18.16 343.6 57.4289 462 9829.5 GR 20.95 145.03 33.5204 480 9803 Last Reading 10060 10060 10042.5 First Reading For Entire File .......... 9803 Last Reading For Entire File ........... 10060 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/23 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 ....... 97/09/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10043.0 ROP 10060.5 STOP DEPTH 10292.5 10319.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Recozd 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 10-AUG-97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 10320.0 10060.0 10320.0 42.5 86.5 TOOL NUMBER NGP SPC 317 3.750 3.8 FLO-PRO 9.00 .0 9.5 5.9 .000 .000 .000 .000 56.2 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10043 10319.5 10181.2 554 10043 GR 20.96 168.01 52.7047 500 10043 ROP 15.55 1614.81 95.29 519 10060.5 Last Reading 10319.5 10292.5 10319.5 First Reading For Entire File .......... 10043 Last Reading For Entire File ........... 10319.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/23 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 ....... 97/09/23 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: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10293.0 ROP 10320.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 10589.5 10616.5 il-AUG-97 MSC 1.32 NGP 5.74, DEP 2.041, 42 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE A~D CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MEMORY 10616.0 10320.0 10616.0 88.4 93.8 TOOL NUMBER NGP SPC 317 3.750 3.8 FLO- PRO 9.00 .0 9.0 6.8 .000 .000 .000 .000 58.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 10293 10616.5 10454.8 648 GR 30.7 167.5 79.3048 594 ROP 14.75 632.22 62.3911 594 First Last Reading Reading 10293 10616.5 10293 10589.5 10320 10616.5 First Reading For Entire File .......... 10293 Last Reading For Entire File ........... 10616.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/23 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 ....... 97/09/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Corament Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit ru~ in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 # FILE SUM~LARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10589.0 11652.5 ROP 10617.0 11679.0 $ LOG HEADER DATA DATE LOGGED: 13-AUG-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 87.2 MSC 1.32 NGP 5.74, DEP 2.041, MEMORY 11680.0 10616.0 11680.0 42 MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 100.3 TOOL NUMBER NGP SPC 317 3.750 3.8 FLO- PRO 9.50 .0 9.1 5.2 .000 .000 .000 .000 60.9 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 ROP MWD 9 FT/H 4 1 68 4 2 GR MWD 9 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10589 11679 11134 2181 10589 ROP 20.06 3348 110.589 2125 10617 GR 32.65 172.47 70.4414 2128 10589 Last Reading 11679 11679 11652.5 First Reading For Entire File .......... 10589 Last Reading For Entire File ........... 11679 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/09/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/09/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Physical EOF Scientific Scientific Physical EOF End Of LIS File
