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Home My WebLink About195-129XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~.~--/~-~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Diann~athan Lowell Isl [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl STATE OF ALASKA .~ R49 ALASK~L AND GAS CONSERVATION COM~SION MAR ~ $ 2009 WELL COMPLETION OR RECOMPLETION REPORT AND L~~aska nil & Gas Cons. Cor>mtissi0n A..,.~.r 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended 2oAAC 25.,05 zoAac 2s.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 2118!2009 - 12. Permit to Drill Number 195-129 ' 309-023 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 09/12/1995 - 13. API Number 50-029-20902-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 09/20/1995 - 14. Well Name and Number: PBU 07-20A' 1596 FNL, 633 FWL, SEC. 34, T11N, R14E, UM Top of Productive Horizon: 4866' FNL, 2507' FWL, SEC. 34, T11 N, R14E, UM 8. KB (ft above MSL): 60' Ground (ft MSL): 27.3' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 680' FNL, 2847' FWL, SEC. 03, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 11077' 9055' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 676844 y- 5949344 Zone- ASP4 10. Total Depth (MD+TVD) 11123' - 9058' - 16. Property Designation: ADL 028309 & 028312 TPI: x- 678801 y_ 5946119 Zone- ASP4 Total Depth: x- 679169 y- 5945035 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No u mit le r ni n rin inf rm i n r 20 AA 25. 50 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 0" 1. H rf 0' rf 1 P I se 1- rf 1 -1/2" F n F' ' - / " 47# L-80 urfa 7' dace 4 1 -1/4" sx CI s 0 PF' ' 7" 9314' 101 9 ' -1/2" 7 x Clas ' -7/ ' 111 7' - / ' ' 23. Open to production or inject ion? ^ Yes ®No 24. TualroG RECORD If Yes, IISt 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# x 4-1/2" 12.6#, L-80 9358' 9272' MD TVD MD TVD { ^,y ~ r; ; s $[, ~~~ ~~ 25. ACID, FRACTURE,.CEMENT.SDUEEZE, ETC. ~ ~~~ ~~ 49~~i/ ~~ F ei<' DEPTH INTERVAL MD AMOUNT St KIND OF MATERIAL USED 9866' Set CIBP 9825' 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 per 20 AAC 250.071. :~,a None ~~~~ ~'~~~ "~ ~ BAR s 2~J~9 _... ___ - Form 10-407 ReVISed 02/2007, CONTINUED CN REVERSE SIDE ~~\ ~ 2S. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sadlerochit 9773' 85~' None 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 a d correct to the best of my knowledge. ~~/ Si d ~ '~ gne V itle Drilling Technologist Date Terrie Hubble PBU 07-20A 195-129 309-023 Prepared By Name/Number Terrie Hubble, 564-4628 Well Number Permit No. / A rOV81 NO. Drilling Engineer: Charles Reynolds, 564-5480 INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the 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 u 07-20A, Well History (Pre Rig Sidetrack) Date Summary 12/11/08 WELL S/I ON ARRIVAL. TAGGED CA. DSSSV @ 2,138' SLM W/ 4.625" G-RING (No problems)., PULLED 5-1/2" CA. DSSSV (intact) FROM SVLN @ 2,158' MD. DRIFT TO 10,423' SLM W/ 2.25" CENT/ SAMPLE BAILER (empty) STOPPED DUF Tn nFVieTipN_ WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 12/13/08 WELL S/I ON ARRIVAL. RAN PDS 24 ARM CALIPER FROM 10,410' TO 9,200' SLM (Good Data). PDS PROGRAMMING 40 ARM CALIPER TO RUN FROM 9,283' MD TO SURFACE. 12/14/08 RAN PDS 40 ARM CALIPER FROM 9,300' SLM TO SURFACE (Good Data~,_ SET 5 1/2" CA. -DSSSV (2 - sets std pkg, Min ID = 2.62") @ 2158' MD. WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 12/17/08 T/I/O = 2400/40/240 Temp = SI. MIT-IA PASSED to 3000 psi, MIT-OA PASSED to 2000 psi (CTD Screen). Pressured IA to 3000 psi with 2 bbls meth followed by 14.4 bbls of 50" crude. MIT-IA lost 40 psi 1st 15 minutes and 20 psi in 2nd 15 minutes for a total of 60 psi during 30 minute test. Bled IA to 100 psi (approx 6 bbls). MIT-OA =Pressured OA to 2000 psi with 8.6 bbls of 50" crude. MIT-OA lost 50 psi in 1st 15 min and 10 psi in 2nd 15 min for a total of 60 psi during 30 minute test. Bled OA to 250 psi (approx 4 bbls). FW HP's = 2400/40/250 Notified DSO of valve positions upon departure. Swab shut, Wing shut, SSV shut, Master open, Annulus valves open to guages. 12/28/08 T/I/0= 2400/40/250, Temp=Sl. PPPOT-T (PASS), CTD screen. PPPOT-T: Stung into test void (300 psi), bled to 0 psi. Functioned LDS, all moved freely. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 12/29/08 T/I/O = SSV/150/250. Temp = SI. OA FL (OA FL campaign). OA FL near surface. SV, WV &SSV = C. MV=O. IA & OA = OTG. NOVP. 01/13/09 T/I/O = 2450/700/360. Temp =Warm. Monitor WHPs, eval cellar glaciation (OPER). No AL. Well has 25" conductor w/ 2" x 3" flutes. Conductor is full of water. Water appears to be runnina out of conductor @ 5 o'clock position. Conductor is 25" deep. Minimal ice in cellar. Sample collected. SV = C. W V, SSV, MV = O. IA, OA = OTG. NOVP. 01/22/09 T/I/O = 1750/1840/1000. Temp =Hot. TIFL to eval high IAP (OPER). AL spool has been dropped. IA FL @ 648' (29 bbls). OA FL near surface. Unable to bleed, rig down wind, no LP lines to bleed to. DSO to bleed OA. SV = C. WV, SSV, MV = O. IA, OA = OTG. NOVP. 01/26/09 T/I/O =1220/1520/740. Temp=Hot. TIFL to eval high IAP. A/L disconnected. OA FL @ 30'. Bled OAP from 740 to 250 psi (all gas) fluid to surface. Monitor for 1 hr, no change in OAP. IA FL @ surface. Bled IAP from 1520 psi to 500 psi (1.5 bbls returns) Monitor for 1 hr IAP increased 20 psi. Final WHPs 1220/520/250. SV =Closed WV, SSV, MV =Open IA, OA = OTG NOVP. 01/28/09 T/I/O = 1120/540/290. Temp= Hot. IA FL post bleed (eval TxIA comm. IA FL @ surface. TP decreased 100 psi, IAP increased 20 psi, OAP increased 40 psi in two days. SV =Closed. WV, SSV, MV =Open. IA, OA = OTG. NOVP. 01/29/09 T/I/O = SSV/350/340. Temp = SI. Monitor WHPs post bleed (eval TxIA comm. S/L on location. IAP decreased 190 psi, OAP increased 50 psi overnight. SV, WV &SSV = C. MV = O. IA & OA = OTG. NOVP. 01/29/09 WELL FLOWING ON ARRIVAL. TAGGED 5 1/2" DSSSV @ 2158' MD W/ 4.565" GAUGE RING. PULL 5 1/2" DSSSV FROM 2158' MD. 01/29/09 Freeze protect Flowline for Slickline work. Pumped 2 bbls neat, 73 bbls crude down flowline to freeze protect. Pump 2 bbls neat down flowline to pressure up. Well left SI at wing. 01/30/09 DRIFT TUBING W/ 2.25" CENT S-BAILER. SLOWED TO A STOP DUE TO DEV @ 10412' SLM (BAILER EMPTY). WELL LEFT S/I, PAD OP NOTIFIED. Page 1 of 2 • 07-20A, Well History (Pre Rig Sidetrack) Date Summary 02/06/09 T/I/O = 2370/17/132. Temp=Sl. Monitor W HPs, T, IA, OA FL (E-line). AL spool dropped. TBG FL Q 10290' (223 bbl). IA & OA FL's near surface. SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. 02/06/09 T/I/O = 2500/50/150 Temp = SI. Assist E-Line Load TBG F/Protect TBG w/ 40 bbls of 120° crude (Eval high IAP (OPER), CTD Prep) Spear in to TBG w/5 bbls of meth followed by 447 bbls of 120° Seawater. 02/06/09 WELL SI ON ARRIVAL. T/I/O = 2400/0/200 PSI. RIG UP ELINE. LRS LOAD TUBING WITH 447 BBLS SEA WATER AND 40 BBLS CRUDE WITH METH SPEARS IN BETWEEN. 02/07/09 T/I/0=0/50/150 Temp=S/I Assist E-line MIT T to 3500 PSI INCONCLUSIVE (Eval high IAP (OPER), CTD prep) Pumped 31.8 bbls AMBNT diesel to test.lst test 1st 15 min lost 140 psi 2nd 15 min lost 100 psi for a total of 240 psi in 30 min RE-psi w/.2 bbl 2nd test 1st 15 min lost 80 psi 2nd 15 min lost 90 psi for a total of 170 psi in RE-psi w/.2 bbl 30 min 3rd test 1st 15 min lost 90 psi 2nd 15 min lost 110 psi. 3rd 15 min lost 60 psi 1 hr lost 80 psi for a total of 340 psi in 1 hr E-line attempt MIT TBG Final Whp's=3075/50/150 02/07/09 T/I/O AFTER LRS LOAD TUBING = 0/0/200 PSI. SET BAKER CIBP (MID-ELEMENT) AT 9866' IN 2-7/8," LINER. LRS AND SLB TEST PLUG TO 3500 P~l. CUT 2-7/8" TUBING AT 9836' WITH 2.125" POWERCUTTER. POOH.. 02/08/09 RIG DOWN ELINE. FINAL T/I/O = 0/0/150 PSI. WELL LEFT SHUT-IN, VALVES OPEN TO GAUGES, DSO NOTIFIED. JOB COMPLETE. 02/11/09 T/I/O=Vac/48/148. Temp=S1. Monitor WHPs (pre CTD). SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. 02/12/09 T/I/O =Vac/50/150. Temp = SI. Bleed W HP's to 0 psi (pre CTD). No AL. IA & OA FL near surface. Bled IAP from 50 psi to 0 psi in 5 min (all gas). Bleed OAP from 150 psi to 0 psi in 2 hour (all oas). During OA bleed IAP increased to 10 psi, bled IAP from 10 psi to 0 psi in 1 min. Monitor for 30 min. IAP unchanged. OAP increased to 0+ psi. Final WHP's Vac/0/0+. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 02/13/09 T/I/0=0/0/0. Swab valve PT'd to 5000 psi failed. Flange leak discovered @ Mstr x SSV connection. Mstr shut & flagged. Operations notified. 02/14/09 T/I/0=0/0/0. ,~eolace 5-1/8" x 7-1/16" Grav Swab valve with "B" Condition Gray valve, torque to API specs. Mstr x SSV flange connection torqued to API specs. Tree PT'd to 5000 psi. Tested Good. Page 2 of 2 i s BP EXPLORATION Page 1 ~ Operations Summary Report Legal Well Name: 07-20 Common Well Name: 07-20 Spud Date: 1/30/1983 Event Name: REENTER+COMPLETE Start: 2/14/2009 End: 3/2/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/2/2009 Rig Name: NORDIC 2 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 2/15/2009 00:00 - 06:00 6.00 MOB N HMAN PRE Move rig from 07-02. Shoulder sloughed off on the access road 06:00 - 09:00 3.00 MOB N HMAN PRE 09:00 - 12:00 3.00 MOB N HMAN PRE 12:00 - 15:30 3.50 MOB N HMAN PRE 15:30 - 17:20 1.83 MOB N HMAN PRE 17:20 - 18:30 I 1.171 MOB ~ N I HMAN I PRE 18:30 - 21:00 I 2.501 MOB I N I HMAN PRE 21:00 - 22:10 1.171 MOB I N I HMAN I PRE 22:10 - 22:45 0.581 MOB I N I HMAN I PRE 12/16/2009 ~ 00:00 - 04:100 4.17 MOB ~ P 04:10 - 08:00 3.83 MOB P 08:00 - 12:00 4.00 BOPSU P 12:00 - 12:15 0.25 BOPSUF~ P 12:15 - 17:30 5.25 BOPSU P 17:30 - 20:25 I 2.921 BOPSUp P PRE PRE PRE PRE PRE PRE PRE going from the back side to the front side of the pad, resulting in 1 fire going into the reserve pit. Jack up rig, shovel out from under the fire & place dunnage under the tire. WO Peak D8 cat assist (Peak will send Hite shift out in the early PM) Discuss plan forward w/ ADW HSE Advisor Herb Williams, DSO, CPS Determine transformer box on flare pit access is dead end for power. Confirm 7-28 and 7-29 are SI Nordic replace valve #12 on choke manifold Loader stage rig mats closer next well Nordic crew change/safety mfg Nordic fin replace valve, grease choke manifold Loader move dunnage rack and prep area for cats Peak arrive w/ two cats. Unload and stage on front side of pad WO Ken Miller and Noel Theiren to arrive to perform risk assessment Conduct risk assessment w/ Ken, Noel, Herb Conduct PJSM w/ Peak for moving cats into position Move cats into position. Attach 1 D8 cat to the rig. Conduct PJSM regarding jacking up rig & placing dunnage under the tire. Remove old dunnage & replace with new dunnage & sheets of 1-1/8" plywood. Conduct PJSM regarding hooking up other D8 cat & pulling rig. Pull rig out of the ditch. Move rig back onto the pad. Conduct PJSM regarding checking tires & warming up move system. Jack up tires & check tires /moving system. Add air to 3 tires. Moving system is ok. Spin tires & warm up moving system. Scarify S-curve access road & dump gravel on the road. Conduct PJSM regarding moving rig to front side of the pad. Move the rig from the back to the front side of the pad. Spot herculite liner around the well. Spot T-mats around the wellhead & secure around the cellar w/ plywood. Move rig mats from well 07-02 to 07-20. Spot rig mats in front of T-mats. Build wood steps for rig tires in front of rig mats. Move rig & spot rig over well to use bridge crane to RD tree cap. RU handy berm. RD tree cap flange using bridge crane. Move over well and set down Accept rig for operations at 0600 hrs 2/16/09 NU BOPE Incident review/investigation Spot mats and set cuttings box Take on fuel and water. General RU Safety mfg re: BOPE test. Fiil stack. Body test okay Test ROPE 3500/250 -PASS The right to witness was waived by the AOGCC. LD test joint. Re-seal china cap for lubricator. Blow down & FP Printed: 3/16/2009 1:47:47 PM # • BP EXPLORATION Page 2 ~ Operations Summary Report Legal Well Name: 07-20 Common Well Name: 07-20 Spud Date: 1/30/1983 Event Name: REENTER+COMPLETE Start: 2/14/2009 End: 3/2/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/2/2009 Rig Name: NORDIC 2 Rig Number: N1 Date From - To Hours i Task Code NPT Phase ~ Description of Operations 2/16/2009 17:30 - 20:25 2.92 BOPSU P PRE TT line w/ neat methanol. Open SSV & install fuseable. Open well, vac - 2bbls to fill the hole. 20:25 - 21:50 1.42 BOPSU P PRE Break circulation on coil. PU injector. Stab onto the well.. Close master. P.T. injector packoffs & inner reel valve 250psi/3500psi - PASS. 21:50 - 22:30 0.67 CLEAN P DECOMP Pop off well. MU 3-1/2" JSN BHA. Stab onto well. Set counters. 22:30 - 22:50 0.33 CLEAN P DECOMP RIH circ at min rate & take FP returns to TT. Got to 220ft & WHP rose to 220psi. Not getting returns to the tiger tank. SI TT line on the round & blow down w/ air diesel FP flash froze . 22:50 - 00:00 1.17 CLEAN N SFAL DECOMP Circ min rate to the pits while rig crew steams the line from choke room level to the ground. 2/17/2009 00:00 - 01:30 1.50 CLEAN N SFAL DECOMP Continue to steam TT line from the choke room level to the ground. 01:30 - 03:20 1.83 CLEAN P DECOMP RIH circ min rate 0.25/200psi while taking FP returns to the TT, after 4000ft increase rate to 1.55bpm/600psi. Tag TOL at 9283ft & stack 8k down while 'ettin , 40k PUW. Got slight amounts of paraffin & FCO debris over the shaker. 03:20 - 05:10 1.83 CLEAN P DECOMP POH while pumping at 3bpm/1860psi. PJSM while POH regarding handling BHA. 05:10 - 06:20 1.17 CLEAN P DECOMP Pop off well. LD JSN BHA. MU fishing BHA. 06:20 - 06:30 0.17 CLEAN P DECOMP Crew change/safety mtg ~ 06:30 - 08:15 1.75 FISH P DECOMP Cut off CTC. Cut off 40' of CT and 20' of a-line to remove flat spot seen at gooseneck. MU BTT slip CTC. PT 42k, 4000 psi. WO BTT to get larger ID XO 08:15 - 09:45 1.50 FISH P DECOMP RIH w/BHA #2 (4" GS) circ KCI 0.52/100 PVT 377 09:45 - 10:00 0.25 FISH P DECOMP 9225' 40.8k was smooth to 9200' 43.1 k Repeat wf: check 24.4 et down at 9281' CTD and stack 4k. Straight pull to 49.2k and wt fell off to 47k 10:00 - 12:00 2.00 FISH P DECOMP POH w/ liner fillin from th B , Safety mtg re: LD BHA and liner 12:00 - 12:30 0.50 FISH P DECOMP LD fishing tools 12:30 - 15:30 3.00 FISH P DECOMP LD 17 jts 3-1/2" FL4S liner and 'ewel .Inspect same for NORM. Slight amounts of scale on the inside of the liner w/ most of the pins ends having corrosion. Slight cement sheath on the outside of the liner. 15:30 - 16:30 1.00 EVAL P WEXIT MU PDS memory caliper log tools on 2 jts PH6. Set timer for 3 hrs. 16:30 - 18:20 1.83 EVAL P WEXIT Run in hole. Lightly tag up at 9380ft. Attempt to pass through with no luck. 18:20 - 20:55 2.58 EVAL P WEXIT POOH. Stop at 7930ft & wait for caliper arms to open & close. Continue to POOH. PJSM while POOH regarding handling BHA. No losses while POH. 20:55 - 22:50 1.92 EVAL P WEXIT Tag up. Flow check well - no flow. Pop off well & place injector over bung hole. LD logging BHA, recovered all tools. Lower logging tools to the ground. Fill hole. Close master. PU injector & cut off CTC. Seal end of wire. 22:50 - 00:00 1.17 EVAL P WEXIT PJSM regarding pumping slack. Stab onto well. Reverse circulate a-line back into the coil. Blow back coil & recover 7bbls of fluid. Pop off well. RU coil cutter. PJSM regarding cutting/handling coil. Cut coil to find wire, cut 348ft. Test wire - good test. MU CTC. 2/18/2009 00:00 - 02:30 2.50 EVAL P WEXIT Continue to MU CTC. Pull test CTC to 40k. Head up BHI UQC. rnntea: ~iwzoua i:ai:ai rnn • $P EXPLORATION Page 3 Operations Summary Report Legal Well Name: 07-20 Common Well Name: 07-20 Spud Date: 1/30/1983 Event Name: REENTER+COMPLETE Start: 2/14/2009 End: 3/2/2009 Contractor Name: NORDIC CALISTA Rig Release: 3/2/2009 Rig Name: NORDIC 2 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 2/18/2009 00:00 - 02:30 2.50 EVAL P WEXIT Fill coil. Pressure test to 4000psi. Put injector over bung hole. Pump 1 coil volume forward & while BHI is hooking up encoder. Simultaneously MU underream BHA. 02:30 - 05:30 3.00 CLEAN P WEXIT RIH w/ underream BHA.. WT ck at 9800ft, 44k PUW & 24k RIW. Tag at 9853ft. PUH_5ft. 05:30 - 06:30 1.00 CLEAN P WEXIT Pump 50bbls of 2ppb biozan 150k LSRV pill at 2.8bpm/2500psi. Underream from 9848ft to 9400ft at 10-15ft/min, no ressure s ikes or OP's observed. 06:30 - 07:30 1.00 CLEAN P WEXIT Log GR tie in from 9600' to 9700'. Tie in to LDT/CNL/GR log dated 2/10/1983. Subtract 7' correction. Log CCL across same interval. 07:30 - 08:30 1.00 CLEAN P WEXIT Make 2nd slow UR pass from 9830 to 9800. 08:30 - 10:30 2.00 CLEAN P WEXIT Open EDC. Begin displacement to 2ppb biozan. Pull out of hole. 10:30 - 12:00 1.50 CLEAN P WEXIT Lay down undereamer. MU 7" Gen 2 Baker whi stock on Inte tools. Stab coil. Test tools. 12:00 - 14:15 2.25 STWHIP P WEXIT Run in hole at 80 fpm. 14:15 - 15:15 1.00 STWHIP P WEXIT Log GR tie in from 9700'. Subtract 13' correction, ~~~ 15:15 - 15:30 0.25 STWHIP P WEXIT o RIH. Place ws btm at 9837. PU 2' to up wt ~OQ~ Close EDC. Pressure coil to 3200 psi. WS appears to be set. 15:30 - 18:00 2.50 STWHIP P WEXIT Pull out of hole. 18:00 - 19:25 1.42 STWHIP P WEXIT Tag up. Pop off well. LD WS setting BHA. C/O w/night crew. Perform walk around & spill champion checklist. PJSM regarding handling BHA. MU window milling BHA w/ 3.80" go, 3.79" no-go window mill & string reamer. PU 2 jts of PH6 above BOT strai ht motor. :2 1 92 STWHIP P WEXIT RIH w/ window milling BHA. Circ min rate 0.25bpm/280psi C,- ~, ~r~ ` . while RIH. (~%t.~ 21:20 - 21:30 0.17 STWHIP P WEXIT Log down for tie-in from 9700ft (-11.5ft corr. 21:30 - 22:00 0.50 STWHIP P WEXIT RIH & dry tag at 9826ft. PUH, 44.5k PUW, & start pumping 2% KCL w/ 2ppb at 2.6bpm/1875psi, slowly creep in hole. First motor work at 9825ft. 22:00 - 00:00 2.00 STWHIP P WEXIT Mill window at 0.1ft every 5min using 8.4ppg 2% KCL w/ 2ppb biozan at 2.6bpm/1950psi w/ 0.3-2k WOB. PVT=400bb1s. 2/19/2009 00:00 - 04:00 4.00 STWHIP P WEXIT Continue to mill window at 0.1ft/5min using 8.4ppg 2% KCL w/ 2ppb biozan at 2.6bpm/2000psi. Begin loosing fluid at 9828ft - 6bbls/hr. ECD = 8.86ppg. PVT = 400bb1s. DHT = 128deg F. Mill to 9831.3ft & had WOB & pressure spike confirmation that the mill has exited the casing. 04:00 - 05:20 1.33 STWHIP P WEXIT Take brake off & mill at constant speed - 0.1ft/min. Mill 10ft of rate hole to 9842ft. 05:20 - 06:30 1.17 STWHIP P WEXIT Dress window using 8.4ppg 2% KCL w/ 2ppb biozan at 2.75bpm/2000psi. Ream & back ream window three times at 1fUmin. Dry drift window. Torque tree bolts from the bottom of the master valve on up. Found 3 loose studs. 06:30 - 09:00 2.50 STWHIP P WEXIT Circulate out of hole. 09:00 - 09:30 0.50 STWHIP P WEXIT LD /stand back milling BHA. String reamer and mill gauge 3.79 no-go, 3.80" go. 09:30 - 10:15 0.75 DRILL P PROD1 MU drilling build BHA with resisitivity tool. 1.9 AKO mtr with HCC re-build bi-center bit. Stab coil and test tools. Get on IRCC-~ ~~., ~~~~ ~ 07-20 B DRLG DiR~-FT WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 60.0' BF. ELEV = KOP = 2900' Max Angle = 94 @ 10701' Datum MD = ___._~_._._ Datum TV D = 10269' . m_.._._..._.._-. 8800' SS 20" CONDUCTOR, 91.5#, H-40, ID = 19.124" r 13-3/8" CSG, 72#, L-80, ID = 12.347" 2517' Minimum ID = 2.441" @ 9795' 3-1 /2" x 2-7/8" XO 5-1 /2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" H 9283' TOP OF 3-1/2" LNR 9321' TOP OF 7" LNR 9314' ~ 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 3-1 /2" LNR, 9.2#, L-80 STL, .0087 bpf, ID = 2.992" ~- 9379' 9-5/8" CSG, 47#, L-80, ID = 8.681" 962T TOP OF CEMENT ~ 9825' x 7" WHIPSTOCK 9825' ~2-718" LNR STUB ~-1 g84o, 2-718" BKR CIBP 9866' TOP OF CEMENT 10142 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~~ 10165' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 93 @ 11200' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpnlSgz DATE 2" 6 11200 - 11780 O 02/28/09 • SA~NOTES: ""`BALANCE & CONTROL LINE IN CO NICATION w/ IA*"" 2158' 5-1/2" CAMCO BAL-O SSSV NIP, ID = 4.562" w /5-1 /2" DSSSV, ID = 2.78" C,A.~, I IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2889 2886 9 MMIG DOME RK 16 03/06/09 2 5028 4748 34 MMIG SO RK 20 03/06/09 3 6559 6021 34 MMIG DMY RK 0 02/15/83 4 7625 6926 30 MMIG DMY RK 0 02/15/83 5 8240 7455 31 MMIG DMY RK 0 02/15/83 6 8317 7520 32 MMIG DMY RK 0 02/15/83 7 8704 7831 41 MMIG DMY RK 0 02!15/83 8 8777 7885 43 MMIG OMY RK 0 02/15/83 9 9107 8116 47 MMIG DMY RK 0 08/06/05 10 9184 8168 46 MMIG DMY RK 0 08/06/05 9257' ~ 5-1/2"BAKERPBRASSY 9272' 9-518" X 5-1 /2" BAKER SAB PKR 9283' 5-1/2" X 4-1/2" XO, ID = 3.958" 9321' 3.70" BTT KB LTP, ID = 2.440" 932T 3.70" BKR DEPLOY SLV, ID = 3.00" 9345' 4-1/2" CAMCO DB-6 NIP, ID = 3.813" 9357' a-1/2" BKR SHEAROUT SUB BEHIND 9358' 4-1/2" TUBING TAIL LINER 9352' ELMD TT LOGGED 09/08/86 937 3-1/2" X 3-3/16" XO, ID = 2.786" MILLOUT WINDOW (07-206) 9820' - 9831' 11013' --~ 3-3/16" X 2-7/8 XO, ID = 2.387" ° 11829' PBTD 3-3/16" LNR, 6.2#, L-80 TCII, 11013' .0076 bpf, ID = 2.80" 2-7/8" LNR, 6.16, L-80 STL~ 11869 .0058 bpf, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 02/17183 PKR176 ORIGINALCOMPLETION 09/23/95 N3ES SIDETRACK (07-20A) 03/01/09 NORDIC 2 CTD SDTRCK (07-20B) 03/04/09 PJC DRLG CORRECTIONS 03/OR'09 DAV!PJC GLV C/O PRUDHOE BAY UNIT WELL: 07-20B PERMIT No: 2090130 API No: 50-029-20902-02 SEC 34, T11 N, R14E, 1596' FNL & 633' FWL BP Exploration (Alaska) • • SARAFP PALIN, GOVERNOR ~~TT~+y~ L~isti-7~ o~ ~ ~ 333 W. 7th AVENUE. SUITE 100 C®1-S~i RQA~o1` c®~~IISS'IO~' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 - ~.~~.G~%~..1~~ ;`." `~ ~.OC Anchorage, Alaska 99519-6612 ii ~~ ,~fr ~.~ Re: Prudhoe Bay Field, Prudhoe Bay Pool, 07-20A Sundry Number: 309-023 Dear Mr. McMullen: 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 feld 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, ~. /~, ~~/~ Daniel T. Seamount, Jr. ~, Chair ~~ DATED this C~"ciay of January, 2009 Encl. p~ ~ `fir ~+"~-' - . ,y~ ~~ 1 ~~q STATE OF ALASKA ~~~ ~ ~ 2QQ~ /- ,~-D9 1 I ~ ALA OIL AND GAS CONSERVATION COM~ION i ~ APPLICATION FOR SUNDRY APPRO 20 AAC 25.280 ~,t~~ ~~~ .~°~' ~~ ~ 1. Type of Request: ®Abandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ~ ^ Exploratory 195-129 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20902-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 07-20A' Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ~` ADL 028309 & 028312 60' Prudhoe Bay Field / Prudhoe Bay Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11123" 9058' ~ 11077' 9055' 11077' Yes, See Dia ram Casin L n th Siz MD TV r olla s S ru ral n r ' rf a 517' 1 - / " 2 17' 2 17' 4 30 7 Interme is a 27' / " 27' 4 70 47 P i in r 12 1' 7" 14' - 1 1 4' 2 ' - 8898' 8160 7 2 finer 18 0' 3-1/ " x 2-7/ " 283' - 1111 2 7' - 9 7' 1016 1 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10234' - 10693' 8946' - 9038' S-1l2", 17# x 4-1/2", 12.6# L-80 9358' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SAB' packer Packers and SSSV MD (ft): 9272' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ' ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: January 28, 2009 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Charles Reynolds, 564-5480 Printed Name John McMullen Title Engineerin Team Leader Prepared By Name/Number: Signature ,~` ~ Phone 564-4711 Date ~ Zz `~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ~ _oa Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity '~OP Test ^ Mechanical Integrity Test ^ Location Clearance ~~~~ ~~` ,`~~~y~ ~~ ~~~ c~ ` Other: ~r Ps ~ \~~ ~ ~5~ Subsequent Form Required: t--{ APPROVED BY ~ A roved B : ! COMMISSIONER THE COMMISSION Date { Form 10-403 Reid b6/2~06 ~ Submit In Duplicate • • To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Charles Reynolds CTD Engineer Date: January 22, 2009 Re: 07-20B Sundry Approval CC: Well File Sondra Stewman/Terrie Hubble Sundry approval is requested to abandon perforations on well 07-20A. Well 07-20A was coil sidetracked in Sept 1995 with 600' of Z2A drilled horizontally just above the HOT with the last 100' in the HOT. 422' of initial perfs were shot, and the well came on at fairly low GOR and 50% WC (water samples showed produced water). All through 1996 they fought to keep the well online, but it did not want to flow. They hooked up gas lift, performed HOTs, thawed ice plugs, and pumped a high pressure breakdown at 12 BPM. Finally, an IBP was set at 10800'MD and the upper Zone 2A perfs were fractured in Dec 1996 with 14.5 M Ibs behind pipe and a tip screen out. Post frac rates were still low and a Z2B oil lens was added (10342'-10,352') in May 1997 boosting the oil rates. In June 1997, 10 more feet of perfs (10332'-10342') were added just above the first set without much impact. An August 1997 PNL showed an oil lens sitting on top of the shale at 10220'. 10' of this lens was shot in Oct 1997 with no effect on the oil rate yet caused the gas rate to slowly rise. In Sept 2002 the well failed a TIFL, indicating possible TxIA communication. The DSSSV was pulled and one with 2 sets of packing was run in August 2005. The TIO plots showed the tubing and IA tracking disappeared. On 4/8/08 a WRP was set at 10290' MD as a gas shut-off, allowing only the 10' of Z26 lens perfs to flow. This cut some gas production but the oil rate also died. It was pulled on 9/13/08, but the well tested at a high GOR. The well passed aMIT-IA to 3000 psi, MIT-OA to 2000 psi, and PPPOT-T to 5000 psi in Dec 2008 during CTD screening. A caliper log indicated the tubing is in good to fair condition. A SCMT log run on 12/27/02 indicated the top of cement behind the 2-7/8" liner is at ~ 9840' MD, which is below the TSGR allowing for acut-and-pull of the liner for a big coil sidetrack. REASON FOR SIDETRACK: Well 07-20A produces well above the marginal GOR. Sidetracking from this well will enable production of Zone 2A reserves from within another portion of the reservoir that would otherwise remain at risk. It will also allow for a future sidetrack from the newly drilled lateral to recover other remaining reserves. Pre-Rig Work: (Scheduled to beg January 28, 2009) • 1. Pull the DSSV from 2,158' 2. Set CIBP at 9,870' This will P&A the existing perforations. 3. Chemical Cut the 3-1/2" x 2-7/8" Liner at 9,840'. 4. Confirm 3-1/2" x 2-7/8" Liner is free 5. PT MV, SV, WV \ 6. Blind and bleed lines, remove well house, level pad ~ i `S ~~~ Rig P&A and Sidetrack Operations: (Scheduled to begin on February 20, 2009 using Nordic rig 2) 1. MIRU Nordic Rig 2 2. NU 7-1/16" CT Drilling BOPE and test. 3. Pull existing 3-1/2" x 2-7/8" Liner 4. Calliper 7" Liner from 9,840' to 9,258' 5. Undeream 7" Liner as necessary 6. Set 4-1/2" x 7" Gen II Baker thru tubing whipstock ~ ~~®, C 7. Mill 3.8"" window through 7" l,~-Cj 8. Drill turn and lateral section to 11,865'. 9. Run and cement a 3-3/16" x 2-7/8" L-80 liner string to 9,320'. 10. Make a cleanout run with mill, motor and SWS GR-CNL logging tool. 11. Perforate well. 12. Set LTP 13. FP well to 2000' with McOH. 14. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 15. RDMO Nordic 2. Post-Rig Work; 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run gas lift design. 4. POP Well E = 3RA Y GEN 3 .LHEAD=. GRAY UATOR = AXELSON ELE1/ = 60.0' ELEV = ' = 2900' Angle = 34 ~ 10701' ImMD= 10115' Im TVD = 8800' SS • 07-20A 13-3/8" CSG, 72#, L-80, ID = 12.34T' H 2517' Minimum ID = 2.441" ~ 9795' 3-1f2" x 2-7/8" XO I 9283' I 5-1/2" BAKER PBR ASSY 9-5/8" X 5-112" BAKER SAB PKR 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" TOP OF 4-1 /2" TBGPC TOP OF3-1/2" LNR-CT TOP OF T' LNR 4-1/2" TBG-PC, 12.6#, L-$0, .0152 bpf, ID = 3.958" f- 9-5/8" CSG, 47#, L-80, ID = 8.681" 3-1/2" LNR-CT, 9.3#, L-80, .0087 bpf, ID = 2.992" TOP OF 2-7/8" LNR-CT TOP OF CENiEM~- 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" PERFORATION SUMMARY REF LOG: BRCS ON 02/10/83 A NGLE A T TOP PERF: 54 ~ 10234' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL OpNSgz DATE 2" 4 10234 - 10249 O 04/10/99 I -11!15' 4 10240 - 10250 O 10/13/97 I -11116" 4 10332 - 10342 O 06!21 /97 I -11 /16" 4 10342 - 10352 O 05/07/97 2-1/8" 4 10410 -10430 O 09/23/95 2-1 /8" 4 10450 - 10693 O 09/23/95 2-1 /8" 4 10878 - 10918 C 09/23/95 2-1/8" 4 10961 -11080 C 09/23/95 8283' -1 5-1/2" X4-1/2" XO (BB~NE~ 9283' 3-1/2~ FLUTEDSUB 8314' I 9358' I 9796' 10142' CO~NK:ATION wBA~ NCE b CONTROL LINE IN () 2158' 5-1/2" CAMCO BAL-O SSSV N~, ID = 4.562" w/5-1/2" DSSSV 08/06/05) ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2889 2887 9 MMG RK 2 5028 4748 34 MMG RK 3 6559 6020 34 MMG RK 4 7625 6925 30 MMG RK 8240 7454 31 MMG RK 6 8317 7520 33 MMG RK 7 8704 7831 41 MMG RK 8 8777 7885 44 MIVIG RK 9 9107 8115 47 MMG RK 10 9184 8168 47 MMG RK 9345' 4-112" CAMCO DB-6 LAND NIP ID = 3.813" (BEeFNND CT) 9367' 4-112"BAKERSHEAROUTSUB(E 9388' 4-112" TUBgVG TAIL (BBiINO CT) 9352' ELMD TT LOGGED 09/08/86 9795' H 3-1/2" X 2-7/8" XO, ID = 2.441" 9840' TOC LINER (SCMT) MLLOUT WINDOW 10165 PBTD 11077' 2-7/8" LNR-CT, 6.5#, L-80, .00579 bpf, ID = 2.441" H 11113' }--~~ DWTE REV BY CON1VBdTS DATE REV BY COMMENTS 04/23/83 ORIGINAL COMPLETION 04/08/08 TFA/TLH WRP SET 08/23/95 SIDETRACK (07-20A) 08/05/08 AK/PJC SSSV/SFTY NOTE CORR 09/26/01 RN~TP CORRECTIONS 09/21/08 CJWSV WRP PULL (09/15/08) 02/17!03 DAV/TLH CORRECTIONS 01/12/09 MSE DRLG INFO 03/13/03 ~1V/TLH MILL CIBP 12/20!06 006/PAG CORRECTADPERF (04/10/99) PRUDHOE BAY UNIT WELL: 07-ZOA PERMfT No: 1951290 API No: 50-029-20902-01 SEC 34, T11 N, R14E, 2432.72' FEL & 677.96' FNL E3P Exploration Alaska) E_ _LHEAD =. UATOR = EL`EV = ELEV = ~_ Angle = im MD = ~mTVn= O ~ ~~ O ~ CO~1N CAT ON w/AAANCE 8 CONTROL LINE IN F P mposed C TD S ilet?ack 5-1/2" CAMCO BAL-O SSSV NIP, ID = 4.562" w/5-1/2" DSSSV (08/06/05) to be pulled 10115' 13-3/8" CSG, 72#, L-80, ID = 12.34T' H 2517' Minimum ID = 2.441" ~ 9795' 3-1 /2" x 2-7/8" XO 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" f-j 9283' f TOP OF4-1/2"TBGPC 9283' TOP OF3-1 2" LNR-CT 9320' TOP OF T' LNR 9314' ST MD TVD DEV TYPE VLV LATCH PO 1 2889 2887 9 MMG RK 2 5028 4748 34 MMG RK 3 6559 6020 34 MMG RK 4 7625 6925 30 MMG RK 3 8240 7454 31 MMG RK 6 8317 7520 33 MMG RK 7 8704 7831 41 MMG RK 8 8777 7885 44 MMG RK 9 9107 8115 47 MMG RK 10 9184 8168 47 MMG RK 9257' -i 5-1/2" BAKER PBR ASSY 9272' 9-5/8" X 5-112" BAKER SAB PM 9283' 5-1/2" X4-1/2" XO 9345' 4-1/2" CAMCO DB-6 LAND NIP ID = 3.813" (BEHIND CT) 9367' 4-1/2" BAKER SHEAROUTSUE 4-1/2" TBGPC, 12.6#, L-80, .0152 bpf, ID = 3.958" 9358' 9368' 4-1/2" TUBING TAIL (BEii1ND C 9352' ELMD TT LOGGED 09/08/86 9-5/8" CSG, 47#, L-80, ID = 8.681 " 4-1/2" x 7"whipstock ITOP OF 2-7/8" LNR-CUT r- TOP OFCEMENT T' LNR, 29#, L-80, .0371 bpf, ID = 6.184" PERFORATION SUMMA RY REF LOG: BRCS ON 02/10/83 ANGLE AT TOP PERF: 54 @ 10234' Note: Refer to Productan DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2" 4 10234 - 10249 O 04/10/99 -11/16" 4 10240-10250 O 10/13/97 -11/16" 4 10332-10342 O 06/21/97 -11/15' 4 10342 - 10352 O 05/07/97 2-1/8" 4 10410 - 10430 O 09/23/95 2-1 /8" 4 10450 - 10693 O 09/23/95 2-118" 4 t 0878 - t o9t 8 C 09/23/95 2-1 /8" 4 10961 - 11080 C 09/23/95 9820' 9840' I 10165' I at window 9840' I~ TOC LINER MILLOUT WINDOW 10165' 13-3/16" X 2-7/8" cmt'ed and perfed I PBTD 11077' 2-7/8" LNR-CT, 6.5#, L-80, .00579 bpf, ID = 2.441" ~ 11113' DATE REV BY COMMENTS DATE REV BY CONN1tN15 04/23!83 ORIGINAL COMPLETION 04/08/08 TFA/TLH WRPSET 09/23/95 SIDETRACK (07-20A) 08/05/08 AK/PJC SSSV/SFTY NOTE CORR 09/26/01 RN/TP CORRECTIONS 09/21/08 CJN/SV WRPPULL(09/15/08) 02/17/03 DAVITCH CORRECTIONS 01/20/09 MSE PROPOSED CTD SIDETRACK 03/13/03 DAVITCH MILL CIBP 12/20/06 OOB/PAG CORRECTADPERF(04l10/99) TSG R 9628` 11000' 3-3/16 x 2-7/8 X-over PRUDFIOEBAY UNfT WELL: 07-ZOB PERMIT No: API No: 50-029-20902-02 SEC 34, T11 N, R14E, 2432.72' FEL & 677.96' FNL BP Exploration (Alaska) Date: January 23, 2009 To: File From: Jane Williamson. Subject: PBU 7-20A BP has requested approval to plug-back Prudhoe well 7-02A in preparation for a sidetrack targeting the Zone 2A (same as current completion). Production history is provided below. When on production, the well produces at 70 Mscf/STB and climbing. No reserves remain. S/T will target other projected unswept zones in Sadlerochit, with possibility for future S/T. Passed MIT, I recommend approval of this sundry request. Peu o~-o2a ~aoo Sao iao r ;r ..~ T a~ 1 ~~ _~ 0.5 m-ova, - ~ I~te (Qlj (bbUd ) Ges Fate (Q7j (MtvEf/d ) f~ (~s / Ql f~tio (Nti/bbl ) ~ V~kter Q1(% ) i _._ ., 02 -----------~------...__. .. _..... ._._. ...------ ~s$ w ea w saoo m oz os a os as m ae DATE `~ i ~ ~ o~-0~ Pb Remaining Reserves for Limit 80 MSCFSTB NtrNrg FQecmt Paarelas Rye Oil C~eNare :Cae1 b 0 Di 0.112619Ae 5000 _ qi 4671 bDUtl p :17/31Yd]'OB ~ :01/31/A10 Flrel Rae :43&978 btl/tl Cun Ratl 217871 MK/ Cun Dae 0?/29'27(7B R~a~m 194981 Mbtl R®aws DaOe 01!31!X710 EUR 236391 Mttl Faerast EfdBtl 9y Rae ~ ~~ DB FQec~l Dae N~ S3.etl ~. RBBa~eTlpe Nme g,~ ti ~ '~! ~ . ~~ 1989 w 9e --. 9e 2aoo ~--m - a¢ at a ~ as -- ae m ae - ae ,0 ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging_ Perforate_ M ILL ClaP Pull tubing _ Alter casing _ Repair well _ Other_X MILL Clap 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development __X Exploratory__ Stratigraphic._ Sen/ice__ 4. Location of well at surface 1596' FNL, 4647' FEL, Sec. 34, T11N, R14E, UM At top of productive interval 4864' FNL, 2514' FEL, Sec. 34, T11N, R14E, UM At effective depth 424' FNL, 2574' FEL, Sec. 03, T10N, R14E, UM At total depth 679' FNL, 2433' FEL, Sec. 03, T10N, R14E, UM (asp's 676844, 594934~1~ ) (asp's 679060, 5946127J'~ (asp's 679021, 5945287) (asp's 679169, 5945035) 12. Present well condition summary Total depth: measured true vertical 11123 feet Plugs (measured) 9058 feet 6. Datum elevation (DF or KB feet) RKB 58 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 07-20A 9. Permitnumber/approvalnumber- ~,J 195-129 10. APInumber 50-029-20902-01 11. Field / Pool Prudhoe Ba~t Field / Prudhoe Bay Pool Tagged TD, CTMD @ 10830' (03/13/2003). Effective depth: measured true vertical 10830 feet Junk (measured) 9038 feet Casing Length Conductor 80' Surface 2482' Production 9595' Liner 851' Side Track Liner 512' Side Track Liner 1318' Size Cemented 20" 1900# Poleset 1640 sx Fondu, 400 sx 13-3/8" PF 'C' 500 sx Class 'G', 300 sx 9-5/8" PF 'C' 7" 325 sx Class 'G' 3-1/2" 2-7/8" Measured Depth True Ve~icalDe~h 115' 115' 2517' 2517' 9627' '8486' 9314'-10165' 8259'-8899' 9283'-9795' 8237'-8613' 9795'-11113' 8613'-9057' Perforation depth: measured Open Perfs 10240'-10250', 10332'-10352', 10410'-10430', 10450'-10693', Open Perfs Below IBP 10878'-10918', 10961'-11080'. true vertical Open Perfs 8949'-8955', 8995'-9003', 9023'-9028', 9032'-9038', Open Perle Below IBP 9042'-9044', 9047'-9055'. 5-1/2", 17#, L-80, TaG-PC @ 9283' MD. 5-1/2" X 4-1/2" XO @ 9283'. ~" ',- ,- ~ ~'.,.~-? i" ' "~;, ..:/.. ~ .-- . .. ,: Tubing (size, grade, and measured depth) 4-1/2", 12.6# L-80 TaG-PC @ 9358'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker 'SAB' Packer @ 9272'. 5-1/2" Camco BAL-O SSSV Nipple @ 2158' MD. 13. Stimulation or cement squeeze summary ~'~ [~ '~ ~'~ ~ U~.~ Intervals treated (measured) (see attached) '~ r', .. Treatment description including volumes used and final pressure , .,,:~_...;~: ,.;-:..-=-~: .... ~ ,~ ;c~.~ ,..~.~_,, , ........ · ~-,~=';~i;~O~ 14. Prior to Well operation 02/20/2003 Subsequent to operation 03/16/2003 OiI-Bbl 724 Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 35387 136 992 36042 167 Casin.q Pressure Tubing Pressure 1154 I O8O 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. ,~~f~ ~~ Title: Technical Assistant DeWayne R. Schnorr .~ H I J I ! '1 I%! I% / Form 10-4~ Rev 06/15/88 * Date March 18, 2003 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLIC^TE~ 07-20A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/27/2002 12/28/20O2 12/28/20O2 O3/12/2003 03/13/2003 03/16/2003 ANN-COMM (AC-EVAL AND REPAIR): DRIFT/TAG PACKERS/BRIDGE PLUGS/POGLMS: CEMENT BOND LOG--SCMT/USIT PACKERS/BRIDGE PLUGS/POGLMS: CHANNEL DETECTION LOG--BORAX LOG PACKERS/BRIDGE PLUGS/POGLMS: MILL PACKERS/BRIDGE PLUGS/POGLMS: MILL TESTEVENT --- BOPD: 797, BWPD: 545, MCFPD: 22,996, AL Rate: 0 EVENT SUMMARY 12/27/02 DRIFT & TAG W/2.25" GAUGE RING TO 10,428' SLM (CIBP SUPPOSED TO BE SET @ 10,300') <<< GAUGE RING HAD A PIECE OF METAL RING STUCK INSIDE <<<< SET DOWN WHILE RUNNING IN HOLE @ 9271' SLM, POSSIBLY 5-1/2" X 4- 1/2" XOVER >>>> ****RETURNED WELL TO OPERATOR**** 12/28/02 SLIM CEMENT MAPPING TOOL. LOG REFERENCED TO SWS TDT DATED 18- AUG-1997. DID NOT TAG. TOP OF CEMENT 9860'. TOOL STUCK IN GLM #5 WHILE POOH, ABLE TO WORK FREE. PAD OPERATOR NOTIFIED TO POP. 12/28/02 PUMPED 759 BBLS OF KCL WATER DOWN THE TUBING FOR E-LINE. 03/12/03 SWAP CTU # 8 OUT FOR CTU # 5. TRAVEL TO LOCATION. MIRU. SHUT IN & LOAD WELL. RIH W/1-11/16" MHA / 1-13/16" DAILEY JARS / 1-11/16" MOTOR / 2.250" SIX BLADE FLAT FACE MILL. TAG CIBP @ 10432' (UP). MILL W/ NUMEROUS STALLS. MILL/PUSH FROM 10432' TO 10496'. 03/13/03 WSR. MILL/PUSH CIBP FROM 10497' TO 10830' (CTM), WITH MULTIPLE STALLS. GOT HARD TAG @ IBP DEPTH. PUMP FINAL BIO SWEEP @ 10830'. DROP BALL TO OPEN CIRC SUB. CHASE OUT OF HOLE AT 80% W/WATER. FP WELLBORE TO 2500' W/CRUDE. FP FLOWLINE W/CRUDE & METH/WTR. RDMO. 03/16/03 TESTEVENT--- BOPD: 797, BWPD: 545, MCFPD: 22,996, AL Rate: 0 Fluids Pumped BBLS 0.5 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( I TEST) 31 METHANOL 20 60/40 METHANOL WATER 55 CRUDE 759 KCL WATER 480 2% EXTRA SLICK KCL WATER 1345.5 TOTAL Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _X (CIBP) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1593' FNL, 4646' FEL, Sec. 34, T11N, R14E, UM At top of productive interval 415' FSL, 2514' FEL, Sec. 34, T11 N, R14E, UM At effective depth At total depth 678' FNL, 2433' FEL, Sec. 3, T10N, R14E, UM 5. Type of Well: Development__X Explorato~__ Stratigraph lc_ Service__ 6. Datum elevation (DF or KB feet) RKB 58 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 07-20A 9. Permit number / approval number 95-129 10. APl number 50-029-20902-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2459' Production 9569' liner 856' 11123 feet Plugs (measured) 9058 feet 10300 feet Junk (measured) 8981 feet CIBP @ 10300' MD (4/28/1998) ORIGINAL Size Cemented Measured Depth True vertical Depth 20" 19oo# Poleset 80' 80' 13-3/8" 164o sx Fondu &40o Sx PFC 2517' 2517' 9-5/8" 500 Sx Class G & 300 Sx PFC 9627' 8486' 7" 325 Sx C~ass G 101 70' 8903' Perforation depth: measured 10234'- 10250'; 10332'- 10352'; 10410'- 10430'; 10450'- 10693'; 10878'- 10918'; 10961'- 11080'. true vertical 8946' - 8955'; 8995' - 9003'; 9023' - 9028'; 9032' - 9038'; 9042' - 9044'; 9047' - 9055'. Tubing (size, grade, and measured depth) 5-1/2" 17#, L-80 POT @ 9283' MD; 4-1/2", 12.6#, L-80, PCT @ 9358' MD. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker SAB Packer @ 9272' MD; 5-1/2" Camco Bal-0 SSSV @ 2158' 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 Subsequent to operation OiI-Bbl 345 Representative Daily Average Production or Iniection Data Gas-Md Water-Bbl 7109 0 712 4219 7 Casing Pressure Tubing Pressure - 301 268 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~~ ~j ~ Title Arco Engineering Supervisor Erin Oba ' Date Prepared by Paul Ra uf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 07-20A DESCRIPTION OF WORK COMPLETED ClBP ADD PERFORATION Date Event Summary 4/28/1998: 4/10/1999: RIH & set CIBP @ 10300' MD. Isolated the following perforations: 10332' - 10352' (Zone 2) 10410' - 10430' (Zone 2) 10693' - 10352' (Zone 2) 10878' - 10918' (Zone 2) 10961' - 11080' (Zone 2) RU ELU. PT'd BOPE. RIH w/perf guns & Add Perforated: 10234' - 10249' (Zone 2) POOH w/guns. ASF. Used 2-1/8" carriers. All shots @ 4 SPF, 0° phasing, random orientation, & balanced press. RD. Returned well to production & obtained a valid well test. STATE OF ALASKA ~L~SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate~ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_X 58' RKB 3. Address: Exploratory_ 7. Unit or Properly: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1596' FNL, 633' FWL, Sec 34, T11N, R14E, UM. 7-20A At top of productive interval: 9. Permit number/approval number: 415' FSL, 2514' FWL, Sec 34, T11N, R14E, UM. 95-129 At effective depth: 10. APl number: 50-029-20902-01 At total depth: 11. Field/Pool: 678' FNL, 2432' FEL, Sec 3, T11N, R14E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 11123 feet Plugs (measured) Bridge Plug @ 10800' MD. true vertical 9057 feet Effective Depth: measured 10800 feet Junk (measured) true vertical 9036 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1900# Poleset 80' 80' Surface 2459' 13-3/8" 1640 Sx Fondu & 2517' 2517' 400 Sx PFC Production 9569' 9-5/8" 500 Sx Class G & 9627' 8486' 300 Sx PFC Liner 856' 7" 325 Sx Class G 10170' 8903' Perforation Depth measured 10332 - 10352'; 10410 - 10430'; 10450 - 10693'; (Isolated below Bridge Plug: 10878 - 10918'; 10961-11080') true vertical 8995- 9003'; 9023- 9027'; 9031 - 9038'; (Isolated by Bridge Plug: 9042- 9044'; 9048- 9056') Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9283' MD; 4-1/2", 12.6#, L-80, PCT @ 9358' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 9272' MD; 5-1/2" Camco BaI-O SSSV @ 2158' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached:r' Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 842 10254 0 280 Subsequent to operation 1177 12747 120 323 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ X Oil _X Gas _ Suspended _ Service _ 17. I hereby cedify that the loregoing is true and correct to the best of my knowledge. iSigned ~'~.,~ "~ · ~ Title: Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 7-20A CTE PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 6/21/97: MIRU & PT equipment. RIH w/perforating gun & shot 10' of add perforations as follows: Added perforations: 10332- 10342' MD (Z2B) Used a 1-11/16" carrier & shot 4 spf at 0 degree phasing at overbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production & obtained a valid welltest. A O,3 C C Z n d '¥ v '¥ d u ,:.~ I W ~s.... i 'i i-.'')ERjvj[[T [}'~,TA T DAT,'& .... PLlJS 9~ '~ i29 95-~ 'i 29 S U RVE V G R '-~- H D 9S~- 1''~° ,SR '- TVD ~EF'..T.A '~ d~~'/ ~ ~'"¢ ~ 4'.~ ~ '- JO .... ~,07 ~OHPLETZON DATE ~/,,'z.T/~ ,-,' ,~,"o~,,"~; ," y ..... c samp s r"equ r"e yes ~ n r"ece ye ,, ',~:.) W a s -~ h e w e i I o o r' e d ? y e s i~____ A r'~ ,si t y s 'i s & d e s c r' 'i p 'L 'i ,. ) r~ r" e c x!.~ 'i v e d '? ~-.-~--- prc~.., Rece'i ved? STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !1. Operations performed: Operation Shutdown_ Stimulate._ Plugging _ Perforate _X Pull tubing_ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of 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: 1596' FNL, 633' FWL, Sec 34, T11N, R14E, UM. 7-20A At top of productive interval: 9. Permit number/approval number: 415' FSL, 2514' FWL, Sec 34, T11N, R14E, UM. 95-129 At effective depth: 10. APl number: 50-029-20902-01 At total depth: 11. Field/Pool: 678' FNL, 2432' FEL, Sec 3, T11N, R14E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 11123 feet Plugs (measured) Bridge Plug @ 10800' MD. true vertical 9057 feet Effective Depth: measured 10800 feet Junk (measured) true vertical 9036 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1900# Poleset 80' 80' Surface 2459' 13-3/8" 1640 Sx Fondu & 2517' 2517' 400 Sx PFC Production 9569' 9-5/8" 500 Sx Class G & 9627' 8486' 300 Sx PFC Liner 856' 7" 325 Sx Class G 10170' 8903' Perforation Depth measured 10342- 10352'; 10410 - 10430'; 10450 - 10693'; (Isolated below Bridge Plug: 10878- 10918'; 10961 - 11080') true vedical 8999- 9003'; 9023 - 9027'; 9031 - 9038'; (Isolated by Bridge Plug: 9042- 9044'; 9048 - 9056') Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9283' MD; 4-1/2", 12.6#, L-80, PCT @ 9358' MD. Packers and SSSV (type and measured depth) Baker SAD Packer @ 9272' MD; 5-1/2" Camco BaI-O SSSV @ 2158' MD. ~- .-. ,; './ ,'-; ._ . 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Dally Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 444 8523 399 272 Subsequent to operation 1424 10068 859 290 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢=,.,~,..... % . ~ Title: Engineering Supervisor Date ~- :2 ¢- '~ '7 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 7-20A CTE PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 5/7/97: MIRU & PT equipment. RIH w/perforating gun & shot 10' of perforations as follows: Added perforations: 10342- 10352' MD (Z2B) Used a 1-11/16" carrier & shot4 spf at 0 degree phasing at overbalanced pressure. POOH w/peK gun. Noted all shots fired. Rigged down. Returned the well to production & obtained a valid welltest. .... STATE OF ALASKA ALASKA O,,_ AND GAS CONSERVATION CON,,¢,ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1596' FNL, 633' FWL, Sec 34, T11N, R14E, UM. At top of productive interval 415' FSL, 2514' FWL, Sec 34, T11N, R14E, UM. At effective depth At total depth 678' FNL, 2432' FEL, Sec 3, T10N, R14E, UM. 5. Type of Well Development X Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 58 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 7-20A 9. Permit number/approval number 95-129 10. APl number 50 - 029-20902-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2459' Production 9569' Liner 856' 11123 feet 9057 feet Plugs(measured) Bridge Plug @ 10800' MD. 10800 feet 9036 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 1900# Poleset 80' 80' 13-3/8" 1640 Sx Fondu & 400 Sx PFC 2517' 2517' 9-5/8" 500 Sx CIG & 300 Sx PFC 9627' 8486' 7" 325 Sx Cl G 10170' 8903' Perforation depth: measured 10410 - 10430'; 10450 - 10693'; [Isolated below Bridge Plug: 10878 - 10918'; 10961 - 11080'] true vertical 9023 - 9027'; 9031 - 9038'; [Isolated below Bridge Plug' 9042 - 9044'; 9048 - 9056'] Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9283' MD; 4-1/2", 12.6#, L-80, PCT @ 9358' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 9272' MD; 5-1/2" Camco BaI-O SSSV @ 2158' MD. 13. Stimulation or cement squeeze summary ~ %~,.~.'~¢~I ¥ ~ 14. Intervals treated(measured) see Attached Treatment description including volumes used and final pressure ORI6i Representative Daily Average Production or Injection Data JAN 21 1997 Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl 0 640 0 214 918 286 Casing Pressure Tubing Pressure 27O 276 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. Signed ~"'~,X~ '~,q. ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 Date /"-/~-'¢ 7 SUBMIT IN DUPLICATE..~ 7-20A DESCRIPTION OF WORK COMPLETED HIGH PRESSURE BREAKDOWN & FRACTURE TREATMENT OF ZONE 2 7/30/96: MIRU & PT equipment. Pumped a Fullbore High Pressure Perforation Breakdown Treatment through the perforation intervals located at: 10410 - 10430' MD (Z2) 10450 - 10693' MD (Z2) 10878 - 10918' MD (Z2) 10961 - 11080' MD (Z2) 'Pumped 230 bbls Slick Seawater @ 15 bpm, followed by Shutdown. ISIP @ 1557 psi. Resumed pumping 50 bbls 40# Crosslinked Gel @ 10 bpm, followed by, 50 bbls 40# Crosslinked Gel w/3300 lbs of 20/40 mesh proppant, followed by 120 bbls Crude Displacement @ 6 bpm, followed by 120 bbls Slick Seawater, followed by Shutdown. ISlP @ 2045. Rigged down. I 2/6~96: RIH w/an Inflatable Bridge Plug & inflated to set in the 2-7/8" liner at 10800' MD. POOH. RD. 1 2/1 3/96: MIRU & PT equipment to 9800 psi. Pumped a Hydraulic Fracture Treatment through the upper two perforation intervals located above the Bridge Plug (listed above). Pumped: a) 300 bbls 20# Pre Pad Gel @ 20 bpm, followed by b) Shutdown. ISIP @ 1620. Resumed pumping Datafrac: c) 75 bbls 40# Crosslinked Pad @ 20 bpm, followed by d) 148 bbls DF Flush @ 3 - 20 bpm, followed by e) 70 bbls DF Flush @ 20 bpm, followed by f) Shutdown. ISlP @ 1980. Resumed pumping Frac: g) 15 bbls 40# Crosslinked Pad @ 15 bpm, followed by h) 97 bbls Crosslinked Slurry @ 2 - 8 ppg of proppant, followed by i) 218 bbls Flush, followed by j) Shutdown. Placed a total of 14,932 lbs of proppant into the formation. Rigged down. 12/14/96: RIH w/CT & jetted a proppant fill cleanout w/biozan to 10445' MD to uncover open perfs (above). Returned well to production w/gas lift & obtained a valid welltest. 0 F:t I I_I_ I I~1G WELL LOG TRANS~AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Howard Okland 3001 Porcupine Dr. C~J'-- 12. q Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 07-20A AK-MW-50082 May 31, 1996 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted magnetic tape with LIS listing. 5631 Silverado Way, Suite G · Anchorage, ,,Naska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I::! I /1__ I I~1G S E I~l~JI r' E S WELL LOG TRANSMITTAL To: State of Alaska April 15, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Larry Grant 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 07-20A, AK-MW-50082 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Yah Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 07-20A: 2" x 5" MD Gamma Ray Logs: 50-029-20902-01 2" x 5" TVD Gamma Ray Logs: 50-029-20902-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALA~,~A OIL AND GAS CONSERVATION COMM,,.,,¢ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL F~ GAS Eli SUSPENDED [~ ABANDONED [~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-129 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 i- ..:.~.':-.~-.~,;~ ~ ~_~ m,,~,¢~,,~¢,,~ ~ 50-029-20902-01 4 Location of well at surface ','-.'~';,'i !-:~i~i~ l~ ~ ;~,,,,,~-r~ .~ 9 Unit or Lease Name 633' FWL, Sec 34, T11N, R14E, UM. ' ,-~:~"!-'~ ~'Q~ .~ PRUDHOE BAY UNIT 1596' FNL, AtTop Producing Interval ~, ',./~:;~r~,~:-~ "· ~., ~. 10 Well Number 415' FSL, 2514' FWL, Sec 34, T11N, R14E, UM. .i ~i i 7-20A At Total Depth . . "~ :~¢-~'~', -'! '~ 11 Field and Pool 678' FNL, 2432' FEL, Sec 3, T10N, R14E, UM. (revised) PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL 58' RKBI ADL 28312 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 9/12/95. 9/20/95. 9/23/95. N/A feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 11123' MD/9057'TVD 11077' MD/9055'TVD YES ~ NO [--'1I 2158' feetMD[ 1900' (approx) 22 Type Electric or Other Logs Run MWD Survey; GR. 23 CASING, LINER AND CEMENTING RECORD SE-I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SiZE CEMENTING RECORD AMOUNT PULLED 20" 91.5 # H-40 Surf 80' 30" 1900~ Poleset 13-3/8" 72 # L-80 Surf 2517' 17-1/2" 1640 Sx Fondu & 400 Sx PFC 9-5/8" 47 # L-80 Surf 9627' 12-1/4" 500 Sx Cl G & 300 Sx PFC 7" 29 # L-80 9314' 10170' 8-1/2" 375 Sx Cl G 24 Pedorations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5.5" Tbg 9283' 9272' 10410 - 10430' MD; 9023 - 9027' TVD; at 4 spf. 4.5" Tbg 9358' 10450 - 10693' MD; 9031 - 9038' TV'D; .... 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 10878- 10918' MD; 9042- 9044' TVD; .... DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED 10961 - 11080' MD; 9048 - 9056' TVD; .... N/A 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 9/30/95. Gas ft. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10/7/95. 6.6 TEST PERIOD ¢' - - 7037 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 233 24~HOU R RATE ¢ 71 5 5032 414 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · Note: 7-20A Coil Tubing Drilling operations summary attached. · This 10-407 submitted as directed per 10-401 approved on 8/29/95 (Permit # 95-129). F E B 0 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ ~ FORNIA~ TESTS NAME Include intervaJ tested, pressure data, all fluids recoverd and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9773' 8596' N/A GOC 9902' 8695' UST OF A'I-I'ACHMENTS Summary of 7-20A Coil Tubin~ Sidetrack Drilling Operations. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed "~~ ~'~' ~ Title Engineering Supervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 7-20A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING 9/11/95: Milled pilot hole through cement plug from 10140' to 10155' MD. 9/12/95: Milled pilot hole to 10165' MD. Circulated hi-vis biozan sweep & POOH w/milling BHA. MU & RIH w/window milling BHA, and started mill'ng window through the 7' liner at 10163.5' MD. POOH w/BHA. MU & RIH w/milling BHA & resumed milling window. 9/13/95: Milled window to 10167.3' MD. Broke chain on reel motor. Cut pipe at surface & RD CTU for repairs. 9/14/95: Spooled CT OOH. RD CTU & MIRU WLU. RIH to fish motor shaft & bit from well. POOH w/fish & RDWL. 9/15/95: RU CTU. MU & RIH w/milling BHA. Resumed milling window at 10165.5' MD. 9/16/95; Completed milling window to 10170' MD. Drilled formation to 10174' MD. sweep, backreamed window, & jetted OOH w/BHA. MU & RIH w/drilling BHA. Circulated 30 bbl biozan 9/17/95: Drilled 3.75" hole 10182' MD, and swapped hole to 9# FIo-Pro. Drilled curve to 10219' MD. w/BH^. MU & RIH w/drilling BHA & continued drilling build section to 10372' MD. POOH 9/18/95: Drilled to 10394' MD. POOH w/BHA. MU & RIH w/drilling BHA & drilled to 10475' MD. 9/19195: Continued ddlling curve to horizontal at 10538' MD. Made two OH wiper passes & POOH w/BHA. RIH w/drilling BHA. Circulated in new 9# FIo-Pro, then drilled to 10712' MD. POOH w/BHA. RIH w/drilling BHA. Drilled to 10735' MD. MU & MU & 9/20/95: Drilled to 11000' MD. Short tripped to 9360' MD. Drilled to TD at 11123' MD. POOH w/BHA. Drilled to 11096' MD. Short tripped to 10200' 'MD. 9/21/95: MU & RIH with 2-7/8 x 3-1/2" liner assembly. Sat down BOL at 11113' MD, putting TOL at 9274' MD. Circulated to condition hole. Pumped 14 bbls Class 'G' cement, followed by biozan to set liner. Displaced cement, unstung from liner, and POOH displacing well to Seawater. RIH w/nozzle & jetted cement from liner to 11077 MD. POOH w/nozzle. WOC. 9/22/95: WOC. RIH w/pedorating guns. Could not work perf guns past 10274' MD. POOH w/perf guns. RIH w/milling BHA. Milled & washed liner to 11077' MD. POOH & PT liner to 2500 psi. MU & g/23/95: MU & RIH wiped guns. Shot initial perforations in the 2-7/8' liner at: 10410 - 10430' MD (Z2) 10450 - 10693' MD (Z2) 10878 - 10918' MD (Z2) 10961 11080' MD (Z2) POOH w/perf guns. Noted all shots fired. RIH w/nozzle to 10000' MD & circulated well to Crude. RD. Placed well on production. Initial welltest rates are 700 - 800 BOPD, 400 - 420 BWPD, & 4800 - 5800 MscfD, at 233 - 256 flowing tubing pressures. SP~..RY-SUN DRILLING SERVICES .ANCHORAGE ALASKA PAGE .ARCC ALASKA INC. PBU/7-20A 500292090201 NORTH SLOPE BOROUGH COMPUTATION DATE: 1©/ -_/95 DATE OF SURVEY: 092195 MWD SURVEY JOB NUMBER: AK-MW-50082 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB - SEA MEASD VERTICAL VERTICAL ---DEPTH DEPTH DEPTH COURS INCLN DG COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. !0100 8848.43 8790.43 10170 8903.06 8845.06 10184 8914.14 8856.14 10201 8925.61 8867.61 10231 8944.59 8886.59 39 0 38 24 44 35 48 7 53 41 S 19.00 E .00 3464.84S 1950.73E S 20.40 E 1.52 3506.04S 1965.48E S 20.00 E 41.90 3515.25S 1968.86E S 19.57 E 21.27 3526.56S 1972.93E S 17.92 E 18.98 3548.68S 1980.42E 3910.54 3954.30 3964.10 3976.12 3999.48 10261 8961.39 8903.39 10292 8977.08 8919.08 10322 8990.77 8932.77 10353 9003.27 8945.27 10380 9013.50 8955.50 57 55 61 4 64 51 66 58 69 54 S 13.83 E 18.11 3572.46S 1987.16E S 8.03 E 19.13 3598.59S 1992.19E S .47 E 25.66 3625.28S 1994.14E S 4.98 W 17.65 3653.19S 1993.03E S 9.40 W 18.16 3678.86S 1989.78E 4024.16 4050.50 4076.38 4102.42 4125.64 10410 9022.70 8964.70 10424 9026.43 8968.43 10437 9029.13 897i.13 10455 9032.66 8974.66 10479 9037.23 8979.23 73 28 76 54 78 39 78 31 79 53 S 8.49 W 12.54 3706.32S 1985.46E S 8.84 W 23.49 3720.308 1983.33E S 7.08 W 19.30 3732.64S 1981.61E S 2.17 W 27.02 3750.048 1980.20E S 2.94 E 21.32 3774.00S 1980.36E 4150.21 4162.74 4173.85 4189.85 4212.57 10493 9039.50 8981.50 81 33 10512 9041.68 8983.68 84 54 10525 9042.55 8984.55 87 21 10555 9043.14 8985.14 90 26 10574 9042.93 8984.93 90 52 S 5.22 E 19.97 3787.81S 1981.35E S 7.33 E 21.25 3806.12S 1983.36E S 8.56 E 21.31 3818.868 1985.14E S 9.62 E 10.59 3849.24S 1990.00E S 13.31 E 20.25 3867.22S 1993.65E 4225.95 4243.92 4256.55 4286.86 4305.04 10612 9041.91 8983.91 10631 9041.31 8983.31 10662 9040.25 8982.25 10674 9039.62 8981.62 10701 9037.81 8979.81 92 i1 91 19 92 38 93 35 94 2 S 15.59 E 6.93 3904.03S 2003.13E S 16.12 E 5.24 3922.89S 2008.49E S 19.46 E 11.81 395!.81S 2017.77E S 19.63 E 8.30 3962.87S 2021.70E S 21.74 E 7.95 3988.12S 2031.23E 4342.94 4362.52 4392.89 4404.62 4431.60 10726 9036.49 8978.49 10771 9035.64 8977.64 10790 9035.91 8977.91 10819 9037.16 8979.16 10844 9038.88 8980.88 92 1 9O 9 88 13 86 48 85 29 S 22.62 E 8.82 4011.22S 2040.65E S 22.95 E 4.22 4052.69S 2058.07E S 23.80 E 11.05 4070.20S 2065.64E S 24.47 E 5.43 4096.41S 2077.38E S 25.45 E 6.41 4119.60S 2088.17E 4456.51 4501.38 4520.41 4549.01 4574.44 10873 9041.15 8983.i5 10890 9042.42 8984.42 10922 9044.65 8986.65 10938 9045.78 8987.78 11023 9051.55 8993.55 85 31 86 3 85 51 85 50 86 24 S 28.40 E 10.17 4145.31S 2101.23E S 27.96 E 3.91 4160.598 2109.41E S 27.83 E .73 4188.37S 2124.12E S 28.18 E 2.22 4202.24S 2131.50E S 29.83 E 2.04 4276.65S 2172.75E 4603.00 4620.11 4651.17 4666.68 4750.45 M C OF LM D J' """ff --~ SP~_.RY-SUN DRILLING SERVICES ANCHORAGE }J_JLS KA PAGE 2 .ARCO ALASKA iNC. PBU/7-20A 500292090201 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/95 DATE OF SURVEY: 092195 MWD SURVEY JOB NUMBER: AK-MW-50082 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 PEPS4 DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11045 9052.88 8994.88 86 34 S 29.48 E 1.79 i1100 9056.20 8998.20 86 30 S 31.95 E 4.49 11123 9057.60 8999.60 86 26 S 33.90 E 8.51 4295.44S 2183.45E 4771.69 4342.58S 2211.46E 4825.38 4361.75S 2223.87E 4847.54 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4895.97 FEET AT SOUTH 27 DEG. 0 MIN. EAST AT MD = 11123 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 161.05 DEG. TIE IN AT 10100' TO EASTMAN SURVEY DATED 3/21/83 SP~ .RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC. PBU/7-20A 500292090201 NORTH SLOPE BOROUGH COMPUTATION DATE: !0/ 4/95 DATE OF SURVEY: 092195 JOB NUMBER: AK-MW-50082 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 RECTikNGU~ COORDINATES MD-TV]D VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10100 8848.43 8790.43 11100 9056.19 8998.19 11123 9057.60 8999.60 3464.84 S 1950.73 E 1251.57 4342.49 S 2211.40 E 2043.81 792.24 4361.75 S 2223.87 E 2065.40 21.59 THE CAL~TION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ~PE .Y-SUN DRILLING SERVICES ANCHOP, AGE ALASKA PAGE 4 .ARCO ALASKA INC. PBU/7-20A 500292090201 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/95 DATE OF SURVEY: 092195 JOB NIIMBER: AK-MW-50082 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALJISKA INC INTERPOLATED VALU?~S FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANG~ COORDINATES MD-TVID VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10100 8848.43 8790.43 3464.84 S 1950.73 E 1251.57 10112 8858.00 8800.00 3472.20 S 1953.23 E 1254.33 2.76 10255 8958.00 8900.00 3567.48 S 1985.83 E 1297.26 42.93 11123 9057.60 8999.60 4361.75 S 2223.88 E 2065.40 768.14 THE CALCULJITION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPL. 4~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA ARCO ALASKA INC. DBU/7-20A 500292090201 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/9 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 10100 8848.43 8790.43 10170 8903.06 8845.06 10184 8914.14 8856.14 10201 8925.61 8867.61 10231 8944.59 8886.59 39 0 38 24 44 35 48 7 53 41 DATE OF SURVEY: MWD SURVEY JOBNU~B~'.~,M~W~B : - -50082 8.oo OPERATOR: ARCO ALASKA INC CO RS DLS OCr 0 DIRECTION RECTANGULAR ,COORDINATES VERT. S 19.00 E .00 3464.84S 1950.73E S 20.40 E 2.52 3506.04S 1965.48E S 20.00 E 41.90 3515.25S 1968.86E S 19.57 E 21.27 3526.56S 1972.93E S 17.92 E 18.98 3548.68S 1980.42E 0 R ~ ,, PAGE 1 092195 3910.54 3954.30 3964.10 3976.12 3999.48 10261 8961.39 8903.39 10292 8977.08 8919.08 10322 8990.77 8932.77 10353 9003.27 8945.27 10380 9013.50 8955.50 57 55 61 4 64 51 66 58 69 54 S 13.83 E 18.11 3572.46S 1987.16E 4024.16 S 8.03 E 19.13 3598.59S 1992.19E 4050.50 S .47 E 25.66 3625.28S 1994.14E 4076.38 S 4.98 W 17.65 3653.19S 1993.03E 4102.42 S 9.40 W 18.16 3678.86S 1989.78E 4125.64 10410 9022.70 8964.70 10424 9026.43 8968.43 10437 9029.13 8971.13 10455 9032.66 8974.66 10479 9037.23 8979.23 73 28 76 54 78 39 78 31 79 53 S 8.49 W 12.54 3706.32S 1985.46E 4150.21 S 8.84 W 23.49 3720.30S 1983.33E 4162.74 S 7.08 W 19.30 3732.64S 1981.61E 4173.85 S 2.17 W 27.02 3750.04S 1980.20E 4189.85 S 2.94 E 21.32 3774.00S 1980.36E 4212.57 10493 9039.50 8981.50 10512 9041.68 8983.68 10525 9042.55 8984.55 10555 9043.14 8985.14 10574 9042.93 8984.93 81 33 84 54 87 21 90 26 90 52 S 5.22 E 19.97 S 7.33 E 21.25 S 8.56 E 21.31 S 9.62 E 10.59 S 13.31 E 20.25 3787.81S 1981.35E 4225.95 3806.12S 1983.36E 4243.92 3818.86S 1985.14E 4256.55 3849.24S 1990.00E 4286.86 3867.22S 1993.65E 4305.04 10612 9041.91 8983.91 10631 9041.31 8983.31 10662 9040.25 8982.25 10674 9039.62 8981.62 10701 9037.81 8979.81 92 11 91 19 92 38 93 35 94 2 S 15.59 E 6.93 3904.03S 2003.13E 4342.94 S 16.12 E 5.24 3922.89S 2008.49E 4362.52 S 19.46 E 11.81 3951.81S 2017.77E 4392.89 S 19.63 E 8.30 3962.87S 2021.70E 4404.62 S 21.74 E 7.95 3988.12S 2031.23E 4431.60 10726 9036.49 8978.49 10771 9035.64 8977.64 10790 9035.91 8977.91 10819 9037.16 8979.16 10844 9038.88 8980.88 92 1 90 9 88 13 86 48 85 29 S 22.62 E 8.82 4011.22S 2040.65E 4456.51 S 22.95 E 4.22 4052.69S 2058.07E 4501.38 S 23.80 E 11.05 4070.20S 2065.64E 4520.41 S 24.47 E 5.43 4096.41S 2077.38E 4549.01 S 25.45 E 6.41 4119.60S 2088.17E 4574.44 10873 9041.15 8983.15 10890 9042.42 8984.42 10922 9044.65 8986.65 10938 9045.78 8987.78 11023 9051.55 8993.55 85 31 86 3 85 51 85 50 86 24 S 28.40 E 10.17 4145.31S 2101.23E 4603.00 S 27.96 E 3.91 4160.59S 2109.41E 4620.11 S 27.83 E .73 4188.37S 2124.12E 4651.17 S 28.18 E 2.22 4202.24S 2131.50E 4666.68 S 29.83 E 2.04 4276.65S 2172.75E 4750.45 Date~ ----'--' AOGCC Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Dear Mr. Grant, Re: MWD Survey Data- 7-20A Enclosed are two hard copies of the above mentioned survey(s). Well 7-20A Tied in at 10100' to Eastman survey dated 3/21/83 Please call me at 563-3256 if you have any questions. Sincerely, I Depa~me~ Speciahst Enclosures. October 4, 1995 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company SPE .... Y-SUN DRILLING SERVICES A/~CHORAGE ALASKA PAGE 2 ARCO ALASKA INC. PBU/7-20A 500292090201 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/95 DATE OF SURVEY: 092195 MWD SURVEY JOB NUMBER: AK-MW-50082 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASRA 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. 11045 9052.88 8994.88 86 34 S 29.48 E 1.79 11100 9056.20 8998.20 86 30 S 31.95 E 4.49 11123 9057.60 8999.60 86 26 S 33.90 E 8.51 4295.44S 2183.45E 4771.69 4342.58S 2211.46E 4825.38 4361.75S 2223.87E 4847.54 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4895.97 FEET AT SOUTH 27 DEG. 0 MIN. EAST AT MD = 11123 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 161.05 DEG. TIE IN AT 10100' TO EASTMAN SURVEY DATED 3/21/83 SPE. ~.Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC. PBU/V-20A 500292090201 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/95 DATE OF SURVEY: 092195 JOB NUMBER: AK-MW-50082 KELLY BUSHING ELEV. = 58.00 FT. OPER~ATOR: ARCO A/_J~S~ INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOT~_L RECTANG~ COORDINATES MD-TVI) VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10100 8848.43 8790.43 11100 9056.19 8998.19 11123 9057.60 8999.60 3464.84 S 1950.73 E 1251.57 4342.49 S 2211.40 E 2043.81 792.24 4361.75 S 2223.87 E 2065.40 21.59 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE .f-SUN DRILLING SERVICES ANCHOR.AGE ALASKA PAGE 4 ARCO ALASKA INC. DBU/7-20A 500292090201 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/95 DATE OF SURVEY: 092195 JOB NUMBER: AK-MW-50082 KELLY BUSHING ELEV. ~= 58.00 FT. OPER3tTOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTIC~J.~ DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10100 8848.43 8790.43 10112 8858.00 8800.00 10255 8958.00 8900.00 11123 9057.60 8999.60 3464.84 S 1950.73 E 1251.57 3472.20 S 1953.23 E 1254.33 2.76 3567.48 S 1985.83 E 1297.26 42.93 4361.75 S 2223.88 E 2065.40 768.14 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo~, DATE: Chairman--"'"" September 11, 1995 THRU: Blair Wondzell, ~I~'~ FILE NO: P. !. Supervisor FROM: John Spauldingg;~ SUBJECT: Petroleum Insp¢ AG9LIKCD.doc BOPE Test- Dowell CTU ARCO PBU DS 7-02 Prudhoe Oil Pool PTD # 95-129 Monday September 11, 1995:! witnessed the BOPE test on Dowell / Nabors Coiled Tubing Unit in preparation for drilling. The AOGCC BOPE test report is attached for reference. All testing went well with no failures observed Summary: ! witnessed the successful BOPE test on Dowell/Nabors CTU with no failures. Attachments' AG9LIKCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Dowell / Nabors Operator: ARCO Well Name: DS. 7-02 Casing Size: 5.5"tubing Set @ Test: Initial X Weekly Rig No. CTU#4 PTD# Rep.: Rig Rep.: 9232' Location: Sec. Other DATE: Sept. 11, 1995 95-129 Rig Ph.# 659-3799 Arvell Bass Roger Smith 34 T. 1 1N R. 11N Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gert) PTD On Location ok Standing Order Posted ok BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. 1 Well Sign Drl. Rig Hazard Sec. Test Pressure 4OO/3,5OO ok ok ok P/F P 1 4OO/3,50O P 1 400/3,500 P 1 40O/3,50O P 1 400/3,500 P 1 400/3,500 P 2 400/3,500 P na MUD SYSTEM: Visual Alarm Trip Tank na na Pit Level Indicators ok ok Flow Indicator na na Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F na na 1 400/3,500 P na CHOKE MANIFOLD: No. Valves 13 J 1 No. Flanges 36 Manual Chokes 1 Hydraulic Chokes 1 Test Pressure P/F 400/3,500 P 400/3,500 P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2,900 I P 2,150 P minutes 13 minutes 52 X Remote: 2150 / 2450 / 2100 / 2050 Psig. sec. sec. na F'~'-"'~ TEST RESULTS Number of Failures: 0 ,Test Hrs.: ~ ~ours. Number of valves tested '18 Repair or Replacement of Failed Equipment will be made within sc~Ly.2~ Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within '12 hours please contact the P. I. Supervisor at: I 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding FI-021L (Rev. 12/94) AG9LIKCD.XLS TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 29, 1995 James Cawvey, Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit 7-20A ARCO Alaska, Inc. Permit No. 95-129 Surf Loc 1596'FNL, 633'FWL, Sec 34, T11N, R14E. UM Btmhole Loc ' 518'FNL, 2347'FEL, Sec 3, T10N, R14E, UM Dear Mr Cawvey: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until ali 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 pdor to ddlling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. Yours very truly, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,.,,,.)N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill _ Redrill X lb. Type of Well Exploratory__ Stratigraphic Test _ Development Oil _~. Re-EntryI Deepen _ Service _ Development Gas __ Single Zone _.X_ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 60' 3. Address 6. Property Designation P. O. Box 100360, Anchora~le, AK 99510-0360 ADL...2.890g ..~ ~-_~'/.:7__. Prudhoe Ba¥/Prudhoe Bay Oil 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1596' FNL, 633' FWL, Sec 34, TllN, R14E, UM. Prudhoe Bay Unit Statewide . At top of productive interval 8. Well number Number 415' FSL, 2514' FWL, Sec 34, T11N, R14E, UM. 7-20A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 518' FNL, 2347' FEL, Sec 3, T10N, R14E, UM. Au~]ust, 1995 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 10995' MD / 9040' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 10165' MD Maximum hole angle 90° Maximum sudace 3000 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) 4-1/2" 3-1/2" 9.3 L-80 FL4S 1715' 9280' 8235' 10995' 9040' 15 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10545 feet Plugs(measured) true vertical 9202 feet Effective depth: measured 10415 feet Junk (measured) · true vertical 9097 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 20" 1900# Poleset 80 80i~ , ~.~, ~ · ~ ~.,~- Surface 2459' 1 3-3/8" 1640 Sx Fondu & 400 Sx PFC 251 7' 2517' · Production 9569' 9-5/8" 500 Sx CIG & 300 Sx PFC 9627' 8486' AUG 2 Liner 1231' 7" 375 Sx C, G 10545' 9202' Perforation depth: measured 10224 - 10231'; 10330 - 10347' ~.I~[/~ 0ii & 6aS C0~SlC0mmissi0' . . true vertical 8928 - 8933'; 9030 - 9044'Anchorage 20. Attachments Filing fee ~ Property plat ~ BOP Sketch x Diverter Sketch _ Drilling program Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed report _20 AAC 25.050 requirements _ 21. I here~he~~,z ~-' ~f°reg°ing is true and correct to the best of my knowledge ~::~/~,..,~t~//'~ Signed ~/ ) T'rtlle Engineering Supervisor Date , Commission Use Only ! Permit Number APl number Appro See cover letter for ~'o~-'- /~___ ~' 50- ,0..?.- ~'- ~ 4D ~(:~.~_-'O~/ other requirements Conditions of'approval Samples required iY e s ~ N o Mud Iog.Cequired'"I Y e s ~ N o Hydrogen sulfide measures .~ Y e s N o Directional survey required ~ Yes __ N o Required working pressure forBOPE ~2M' ~ 3 M - ~ 5 M · ~ I OM' ~ 1 5 M ]~ 3500 psi forCTU Other: OR,GJNAL SIGNED BY by order of Approved by RUSSELL A. DOt,I~ A,~ Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplica DS 7-20A CT Sidetrack and Completion Intended Procedure Objective: Directionally drill ~500' horizontal well from the existing wellbore. Complete with 3-1/2" cemented liner. Intended Procedure: P&A existing interval. Mill window in 7" casing at ~10,165' md. Build angle to horizontal at ~16°/100'. Directionally drill ~500' horizontal to access upper Romeo reserves. Run and cement 3-1/2" liner to TD. Perforate selected intervals. · Return well to production. Alaska 0it & Gas Cons. Cornmission Anchorage August 17, 1995 DS 7-20A Potential Drilling Hazards POST ON RIG · Tested as high as 10 ppm H2S production. BHP' 3415 psi @ 8800' ss (7.5 ppg EMW), BHT 205 °F (estimated values based on offset wells). No over pressured zones are anticipated. Maximum anticipated WHP w/ full column of gas' 2800 psi. · Deepest expected gas/oil contact is 8915' ss. Potential high perm intervals in upper part of build section. This section warrants consideration for lost circulation or high rate gas production during underbalanced operations to address differential sticking concerns. AUG 25 1995 hlaska.0il & Gas Cons. Commissior~ ~chorage August 17, 1995 C T ~, dling Wellhead Detail ~ CT Injector Head ~~_~~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure 7 R~ser Methanol Injection Otis 7' WLA Quick_ Connect 4-1/16" ID CT BOP Stack 10,000 psi Working Pressure 2' Pump-In Blind Rams or Combination Cutter/Blinds Cutters or Combination Cutter/Blinds Slip rams Pipe rams Flange Flanged Fire Resistant Kelly Hose To Dual ChokeManifold Optional Flanged / / Manual Valve HCR (28") 2.0' (24") Test Gauge 1.67' (20') Approxhnate top of Wellhouse Optional: Space with spool pieces or valves to top of wellhouse as shown Alignment Guide Flange Optionally Made-up During Drilling \ 6'-8' Line To Plant Annular BOP (Hydril), 5-1/8' ID 5,000 psi working pressure 3.167' (38') Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Valves 5.75' (69') 1.427' (17-1/8") 0.458' (5.5') f 5.604' (67.25') Top of Pad Level --- Mandatory SSV ~ Optional Manual Master Valve or Hydraulic SSV (24.5" for SSV) ~Tubing Hanger ~Fire Resistant Kelly Hose to Flange by Hammer Up 1/4 Turn Valve on DS Hardline 10' from Tree 9-5/8' Annulus ,,, ,,-: ,o - Anchorage, .-i Customer Location H. DEPTH ft 101'70. O0 10200.09 10230.00 10260.00 10290.00 10320. O0 10350. O0 10380. O0 10410.00 10440.00 10470.00 10495.76 10500. O0 19530. O0 10560. O0 !0590,00 10620.00 10650.00 10680.00 10710.00 10740.d0 10770.00 10800.00 10830.00 10860.00 10890.00 10920. O0 10950. O0 10980.00 10995,76 Drilex Systems, l~:c. : ARCO Alaska : DS 07-20 Side~zack : : Prudhoe Bay : Alaska Meigh% of Area Datum above Customer Datum O.CO ft Height of ~'~]eli Datum above ~--~ea Datum 0.00 ft Ail TVDs a_~e relative ~ the Well Datum Level ANGLE DiR 55 TV£) V/S ASP(;-;.'_) AS~' ('f) dog dog Et ft Et Et 38.40 S19,0O~ E 8845.0 3938.3 67888-2.0 5945893.0 43.15 $19.00°E 8867.7 3957.8 678895,4 5945564.5 47,90 $19.00°E 8888.? 3979.5 67~902.4 5945844.0 52.66 S19.00°E 8907.9 4002.3 678909,9 5945822.5 57 4~ Slq 00°E 8925 ~ 402~ i 6~8q17 q 5n.c:%7c~q n D' LES °/i00 C. 09 15.84 15.84 15.84 i5.%4 62.16 S19.00°E 8940.2 4053.0 678926.$ 5945~74.5 66.91 S19.00°E 8953.1 4080.0 678935.1 5945749.0 71.66 S19.00°E 8963.~ 4!08.U 67~944.3 5945;22.5 76.42 S19.00°E 8971.9 4136.6 6789_53.6 5945695.5 81.17 $19,00°E 8977,~ 4166,2 678965.2 5945667.5 15.8,i 15.~4 !5.~4 15.84 15.84 85.92 S19.00°E 8981.1 4!95.8 578972.9 5945639 90.00 S19.00~E 8982.0 4221.7 678981,2 5945615 90.00 S19.00°E 8982.0 422.5.9 6~9982.7 5945611 90.00 S19,00°E 8982.0 4256.1 679992.4 5945582 90.00 S19. O0°E 8982.0 4286.2 679602. ,C 5 945.%54 .5 15. '34 .O 15.94 .0 0,0 3 .5 $. :39 · C 9. ' '7 d ,. I 90,00 S19.00°E 8982.0 4315.9 679012.0 5945526 90,00 $19.00°E 8982.0 4346.0 5~9021.8 5945497 90.00 S19.00°E 8982.0 43.76,1 679631.5 5945469 90.00 S19.00°E 8982.0 4405.8 679041.2 5945441 90.00 S!9,00°E 8992.0 4435.9 6796-51.1 5945412 .0 .5 .0 .0 .5 9.39 '.ii. '.30 3.00 " 09 O. O0 90.00 S19.00°E 8982.0 4466.~ 6'~ 9(.in0.8 5945384 90.00 S19.00°E 8982,0 4496,1 679070.6 5945355 90.00 $19.00°E 8982.0 4525.8 679080.3 5945327 90.00 $19.00°E 89~2,0 4555,9 ~796.9¢. 1 9945299 90.00 Sl~,00°E 8982.0 4586,1 679099.9 5945270 ,0 .5 .5 .C .5 U. ';3. O0 O. 0 0 O,Og C,O9 90.00 S19,00°E 8982,0 4616.2 679109.6 5~-~45242 90.00 S19.00°E 8982.0 46~5.8 679119.4 5945214 90.00 S19.00°E 8982.0 4676.O 679]2?.2 5946185 90.00' SI9.00°E 8982,0 4796.1 679138.9 5945157 90.00 S19.00°E 8982,0 4721.9 679144.1 5945142 .0 O. O0 .0 3.00 .5 U. ',)', .0 3.00 .O 0. O0 All depths are Sub-Sea AUG 25 1995 .DiI & Gas Cons. Commission ~ Anchorage Customer Well Location Drilex Systems, Inc. : ARCO Alaska : DS 07-2(3 SideLrack : : Prudhoe Bay Unit : Alaska Page=" ,_~f 1 DaLe Augus~ 18, 1995 No Intezpoia~ion Height of Area DaLum above Customer Dat~n C.00 ft Mei~h~ of Well D~tum above Area Dat~%~ 0.00 ft Ail TVDs are relative to the Well Dauum Level M DEPTH AN,=~_ DIR C\= ~STVD V/S N~/S- ft dee dee ft ft f~g f~ 10170.00 38.40 S19.00°E 0.00 8845.00 3928.~6 -3460.90 10200.0n~ ~3_ .15 S19.00°E 30.00 8867.71 ~957.,_.~ -3479.42 10230.00 47.90 S19.00°E 30.00 8888.72 3979.15 -3499.66 10260.00 .52.66 Sl9.00°E 30.00 8907.89 4002.22 -3521.47 10290.00 57.41 Sl9.00°E 30.00 8925.08 4026.80 -3544.71 10320.00 62.16 Sl9.00°g 30.00 8940.17 4052.72 -:3569.21 10350.00 66.91 S19.00°E 30.00 8953.06 4079.79 -3594.81 10~80.00 71.66 S19.00°E 30.00 8963.67 4107.85 -3621.34 10410.00 7~.42 S19.00°E 30.00 8971.92 4136.68 -3~48.60 10440.00 81.17 S19.00°E 30.00 8977.75 4166.10 -3676.42 10470.00 85.92 S19.00°E 30.00 8981.12 4195.90 -3704.60 10495.76 90.00 S19.00°E 25.76 8982.04 4221.64 -3728.93 10500.00 90.00 S19.00°E 4.24 8982.04 4225.88 -3732.94 10530.00 90.00 Sl9.00°E 30.00 8982.04 4255.88 -376!.31 10560.00 90.00 S19.00°E 30.00 8982.04 42~5.88 -3789.67 10590.00 90,00 S19.00°E 30.00 8982.04 4315.88 -3818.04 10620.00 90.00 S19.00°E 30.00 8982.04 434~.88 -3846.40 10650.00 90.00 slg.00°E 30.00 8982.94 4375.88 -3874.77 10680.00 90.00 Slg.00°E 30.00 8982.04 4405.88 -3903.14 10710.00 90.00 S19.00°E 30.00 8982.04 4435.88 -3931.50 1:3740.00 90.00 S19,00°E 30.00 ~982.04 4465.88 -3969.8'! 10770.00 90.00 S19.00°E 30.00 8982.04 4495.88 -3988.23 10800.00 90.00 S19.00°E i 30.00 8982.04 4525.88 -4016.60 10830.00 90.00 Slg. 00°E 30.00 8982.04 4555.88 -4044.96 10860.00 90.00 slg, 00°E 30.00 8982.04 4585.88 -4073.33 10890.00 90.00 S19.00°E 30.00 8982.04 4615.88 -4101.69 10920.00 90.00 'Sl9.00°E 30.00 8982.04 4645.88 -4120.06 10950.00 90.00 S19.00°E 30.00 8982.04 4675.88 -4158.43 10980.00 90.00 $19.00°E 30.00 8982.04 4705,88 -4186.79 10995.76 90.00 Slg.00°E 15.76 8982.04 4721.64 -4201.69 E-,/W- D'LEG fu °/!00 2045.10 0.09 2051.48 15.84 2058.44 ~5.84 2065.96 15.84 2073.96 15.84 2082.39 15.84 2091.21 i~.84 2100.34 15.84 2109.73 15.84 2119.31 15.84 2'129.01 15.84 2137.39 15.84 2138.77 O.00 2148.54 0.120 2158.31 O.00 2168.07 2177.84 0.03 2187.61 0.00 2197,37 0.00 2207.14 0.00 2216.91 O.OU 2226.67 0.00 2236.44 O.OO 2246.21 0.00 2255.98 0.09 2265.74 0.CO 2275.51 0.00 2285.28 0.00 2295.04 0.00 2300.17 0.00 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 4790 ft 151.3': All depLhs are Sub-Sea At~S~,a Oit .& Gas Cons~ Commissio~ : Anchorage DRILEj~_ ARCO Alaska DS 07-20 $ideb-a~k Pruc~loe Bay Unit Note: .All DeFths ,Are SuNSea (;rid North Mag 1+/9.7) -2600 -3250 -3900 -4550 Departure Scale 1 inch' 650 ft I i i Planned Sidetrack PLANE OF VERT SECTn S19.00E AUG 25 199,5 Aia~k~t Oil .A Gas Cons. Commission DRILE C_ ARCO Alaska DS 07-20 Sidetrack lXrudhoe Bay Unit Grid North .Alaska Mag (+29.7) 'Vertical Section Scale 1 inch' 150 ft 8600 8750 8845.0 DO ',i' 8982.0 .. <o .~1 9050 :20'W 5.84°/1 70 3814° 70° I : , i , I ! , i ! ~-'--~ ' 77' ......... ~ ,, · Planrted Si~tetrac:k 3'~D 8982.p TVD ~ID 109~ 90.0° PLANE OF VERT SECTn S19.00E PLOT DATE 08-18-1995 IqELL PROPOSAL 3ec MD TVD VS INC DIR LA'I~ DEP TGr 1 10170.0 8846.0 3938.2 38.4 S19.00E -3460.9 2045.1 2 10495.8 8982.0 4221.6 90.0 $19.00E -3728.9 2137.4 3 10995.8 8982.0 472'1.6 90.0 SI9.00E 4201.7 2300.2 STATE OF ALASKA -. ALASKA ._,L AND GAS CONSERVATION CC .vllSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging X Time extension Stimulate Change approve~ program Pull tubing Vadance Perforate "I 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 5. Type of Well Development Exploratory Stratigraphic Service Other 6. Datum of elevation(DF or KB) 58 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1596' FNL, 633' FWS, Sec. 34, T11N, R14E, UM 7-20 At top of productive interval 9. Permit...num'b~r "~ FSL, 2514' FWS, Sec. 34, T11N, R14E, UM 83-14.~. 415' At effective depth 10~P~mber ////50 - 029-20902 i At total depth .,//11. Field/Pool mX / 37' FNL, 2609' FEL, Sec. 3, T10N, R14E, UM // P r.u d ho e ~-y~O~/~ o I / 12. Present well condition summary / ~ f/-"%~., J \ // Total depth: measured 10545 feet Plugs(measured) true vertical 9202 feet Effective depth: measured 10415 feet true vertical 9097 feet dunk(measure~) ~ / Casing Length Size Cemented ~k, Measured depth,~rue vertical depth Conductor 80' 20" 1900# Poleset ~. 80' ..../' 80' Su dace 2459' 13-3/8" 164o Sx Fondu & 400 Sx Per rost C 17' 2517' Production 9569' 9-5/8" 5o0 Sx CL G & 300 Sx Permafrost C 9627' 8486' Liner 1231' 7" 375 Sx CIG 10545' 9202' Perforation depth: measured 10224-10231 '; 10330-10347' true vertical 8928-8933'; 9030-9044' A~aSl~ 0~ & Gas Oons, Commission Tubing (size, grade, and measured depth) 5-1/2", 17#, C-80, PCT @ 9283~°;r~-~/2'', 12.c~, L-SO, PeT Tail @ 9358' MD Packers and SSSV (type and measured depth) Baker SAB Hydroset Packer @ 9272' MD; Camco BaI-O SSSV nipple @ 2158' MD 13. Attachments Description summary of proposal x 14. Estimated date for commencing operation August, 1995 16. If proposal was verbally approved Detailed operations program BOP sketch x 15. Status of well classification as' Oil x. Gas . Suspended Service Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ) Title Engineering Supervisor FOR COMMISSION LI~;E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance . Mechanical Integrity Test ~ Subsequent form required 10- ' _-'/"/__(~"/' ~up~oved Copy Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Original Signed By ~avid W, ,Johnston I Approval No. ¢~'... ~/~¢ Returned Date (~/'~/?~-'---~ SUBMIT IN TRIPLICATE Objective: DS 7-20 Intended P&A Procedure P&A existing interval in preparation for CT sidetracking operations. Intended Procedure · RU coiled tubing unit. Tag bottom Pump 30 bbls Class 'G', 17 ppg fibered cement, squeeze up to 17 bbls behind pipe. Clean cement top to ~10,130' md (KOP for CTU drilling at 10,165') · WOC, Tag top of cement, pressure test to 1500 psi August 17, 1995 6 5 4 3 2 COILED ?UBIN~ UNIT BOP EOU I PMENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAJAS 6. 5000 PS! 4 1/16" STUFFING BOX 3 J 2 Gas Guns. commiss~oD Anchorage NIRELINE BOP EQUIPMENT · 1. 5000 PSI 7" WELLHEAD CONNEC'I'OR FLANGE 2. 5000 PSI W~RELINE RAUS (VARIABLE SIZ£) J 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF WELL PERMIT CHECKLIST COMPLY ~,~(~ ,, _~ INIT CLASS ~~ ADMINISTRATION 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 ENGINEERING UNIT# PROGRAM: exp [] dev [] redr11~ serv [] //~ ON/O~ s~o~ ~C~j 15. Surface casing protects all known USDWs ......... Y ;6t . 16. CMT vol adequate to circulate on conductor & surf csg.. Y 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 .... i~ N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. N 22. Adequate wellbore separation proposed ......... N 23. If diverter required, is it adequate .......... ~~A]~ 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~--~'~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... ~f----~/~ 28. Work will occur without operation shutdown ....... Y~ N 29. Is presence of H2S.gas probable ............ Y~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N~/_ 31. Data presented on potential overpressure zones ..... Y/~~1//~/ . 32. Seismic analysis Qf shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... ...,:'. Y N 34. Contact name/phone for weekly progress reports . ..'2' . . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ RAD '~--~ Comments/Instructions: O -' 'C~cheklist rev 03/94 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 NAM~ WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO .- ~co ~u_~sKA, ~. s. 7-20A ,~as~ra Oil & Gas ~s. : NOR~ SLOPE : ~S~ : 500292090201 : 97479 Date_~~~'~ ~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 97/10/22 ORIGIN : FLIC REEL NAM~ : 97479 CONTINUATION # : PREVIOUS REEL : CO~J~LNT : ARCO ALASKA INC, D.S. 7-20A, PRUDHOE BAY, 50-029-20902-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/10/22 ORIGIN : FLIC TAPE NAME : 97479 CONTINUATION # : 1 PREVIOUS TAPE : COF~_J~f : ARCO ALASKA INC, D.S. 7-20A, PRUDHOE BAY, 50-029-20902-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINELOGS WELL NAME: D.S. 7-20A API NU~!BER: 500292090201 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 22-0CT-97 JOB AUIf4BER: 97479 LOGGING ENGINEER: G.JOH~SON OPERATOR WITNESS: D. CISMOSKI SURFACE LOCATION SECTION: 34 TOWNSHIP: lin RANGE: 14E FNL: 1596 FSL: FEL: FWL : 633 ELEVATION (FT FROM MSL O) KELLY BUSHING: 58. O0 DERRICK FLOOR: 57.00 GROUND LEVEL: 28.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 3. 725 9. 625 9627.0 47. O0 2ND STRING 7. 000 10165. 0 29. O0 3RD STRING 2. 875 11113.0 6.50 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (M~ASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUM~ER: PASS--ER: DATE LOGGED: 21-SEP-95 LOGGING COMPANY: SPERRY SUN BASELINE DEPTH 88888.0 10359.0 10335.0 10273.0 10269.0 10263.5 10251.5 10246.5 10217.5 10201.0 10200.5 10197.5 10191.0 10185.0 10179.5 10178.5 10170.0 10129.0 10110.5 10110.0 10104.0 10096.0 10073.5 10058.0 10031.5 10031.0 10028.5 10028.0 10012.0 10011.0 10009.5 10009.0 10007.5 10007.0 9999.0 9989 5 9969 5 9967 5 9965 0 9953 5 9940 5 9933 5 9922.0 9915.5 9894.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88884.0 88884.0 10355.0 10355.0 10332.5 10332.5 10270.5 10270.5 10267.5 10267.5 10261.0 10261.0 10251 . 0 10251 . 0 10246.5 10246.5 10218.0 10218.0 10202.0 10202.0 10197.0 10197.0 10189.0 10189.0 10183.0 10183.0 10177.5 10177.5 10168.5 10168.5 10131.5 10131.5 10113.0 10113.0 10106.5 10098.5 10073.0 10058.0 10033.5 10030.0 10014.0 10012.0 10009.5 10002.0 9991.5 9971.5 9969.5 9967.5 9955.5 9944.0 9935.5 9924.0 9918.5 10106.5 10098.5 10073.0 10058.0 10033.5 10030.0 10014.0 10012.0 10009.5 10002.0 9992.0 9971.5 9969.5 9967.5 9955.5 9944.0 9935.5 9924.0 9918.5 9896.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 9893.0 9896.0 9886.0 9888.0 9888.0 9880.0 9882.5 9882.5 9874.5 9877.0 9877.5 9859.0 9861.0 9857.5 9861.0 9846.5 9848.5 9838.5 9841.5 9813.5 9816.5 9813.0 9816.5 9806.0 9809.0 9805.0 9809.0 9803.0 9806.0 9806.0 9801.5 9805.0 9805.0 100.0 103.5 103.5 $ THIS FILE CONTAINS THE TDTP DATA ACQUIRED ON 18-AUG-97 ON ARCO ALASKA, INC. WELL DS 7-20A. THE DEPTH SHIFTS SHOWN ABOVEREFLECT PASS #1 GRCH TO GR.MWD; AND PASS #1 SIGM TO GR.MWD. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUFmLARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10366.0 9800.0 TDTP 10390.0 9800.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT~1997 11:59 PAGE: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH GRCH TDTP REMARKS: THIS FILE CONTAINS TDTP PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAPIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 SIGMTDTP CU 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 LCO1 TDTP 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TCAN TDTP CPS 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 1065805 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10500.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP SBP~N. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP LCO1.TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP GRCH. TDTP -999.250 TENS. TDTP -999.250 CCL.TDTP -999.250 GR.MWD DEPT. 9750.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP SBP~V. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP LCO1.TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND.TDTP -999.250 TCFD. TDTP TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND.TDTP -999.250 INFD. TDTP GRCH. TDTP -999.250 TENS. TDTP -999.250 CCL. TDTP -999.250 GR.MWD -999.250 -999.250 -999.250 -999.250 -999.250 36.770 -999.250 -999.250 -999.250 -999.250 -999.250 104.688 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: **** FILE HEADER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUbt~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUbl~ER : 2 DEPTH INCREblENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10376.0 9800.0 TDTP 10400.0 9800.0 $ CURVE SHIFT DATA - PASS TO PASS (tq~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~ER : 1 BASELINE DEPTH 88888.0 10372.5 10360.0 10353.5 10352.5 10335.0 10326.0 10322.0 10321.0 10297 0 10290 5 10279 0 10277 5 10273 5 10269 5 10268.0 10266.5 10263.5 10259.0 10251.5 10248.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88883.5 88883.5 10368.0 10355.5 10349.5 10332.0 10323.5 10319.0 10295.0 10276.0 10270.5 10267.5 10265.0 10263.5 10261.0 10257.0 10250.5 10349.0 10317.5 10287.5 10274.5 10261.0 10251.0 10246.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 10247.0 10246.5 10223.5 10223.5 10206.5 10206.5 10201.0 10202.0 10200.5 10201 . 5 10196.5 10197.0 10191.5 10190.0 10188.5 10186.0 10182.0 10180.0 10180.0 10177.5 10178.5 10177.5 10170.5 10169.0 10163.5 10160.0 10160.0 10159.5 10142.0 10142.5 10133.0 10134.5 10115.5 10113.0 10110.5 10113.0 10102.5 10099.0 10065.0 10065.0 10059.0 10058.5 10035.5 10036.5 10031.0 10033.0 10033.5 10028.0 10030.0 10025.0 10025.5 10021.0 10023.5 10012.0 10014.5 10007.5 10009.5 10007.0 10009.5 9989 . 5 9991 . 5 9992.0 9982.0 9984.5 9984.0 9980.0 9982.5 9970 . 0 9971 . 5 9971 . 5 9967.5 9969 . 0 9962.5 9964.5 9956.0 9957.5 9954.0 9956.0 9953.5 9955.5 9946.0 9949.0 9945.5 9948.5 9939.5 9944 . 0 9933.5 9935.5 9935.5 993 O. 0 9931 . 5 9919.0 9922.0 9916.5 9918.5 9916.0 9918.5 9911 . 0 9913 . 5 9907.5 9910.5 9897 . 5 9900 . 0 9880.5 9882.5 9880.0 9882.0 9877.5 9880.5 9874.0 9876.5 9872.5 9875.0 9860.5 9862.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 9858.0 9853.5 9848.0 9845.0 9846.0 9840.5 9829.5 9830.0 9814.0 9816.5 9813.0 9811.5 9814.5 9809.0 9806.0 9809.5 9805.5 100.0 103.5 $ 9861.0 9856.5 9850.0 9847.0 9843.0 9816.5 9813.0 9809.0 103.5 REMARKS: THIS FILE CONTAINS TDTP PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH; AND PASS #2 SIGM TO PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: ** SET TYPE ~ CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMTDTP CU 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 SBHFTDTP CU 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 SBHNTDTP CU 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 LCO1 TDTP 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 TCANTDTP CPS 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 TCAFTDTP CPS 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 TSCNTDTP CPS 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 TSCFTDTP CPS 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1065805 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10395.500 SIGM. TDTP 34.343 TPHI.TDTP 57.877 SBHF. TDTP SBPZN. TDTP 52.313 SIGC. TDTP 0.236 SIBH. TDTP 132.588 TRAT. TDTP LCO1.TDTP 3.453 SDSI.TDTP 0.603 BACK. TDTP 211.444 FBAC. TDTP TCAN. TDTP 23952.723 TCAF. TDTP 6729.591 TCND.TDTP 17361.539 TCFD. TDTP TSCN. TDTP 2674.218 TSCF. TDTP 774.552 INND. TDTP 861.251 INFD. TDTP GRCTt. TDTP -999.250 TENS. TDTP 1470.000 CCL.TDTP 0.000 DEPT. 9803.500 SIGM. TDTP 21.318 TPHI. TDTP 24.173 SBHF. TDTP SBHN. TDTP 67.894 SIGC. TDTP 1.636 SIBH. TDTP 95.647 TRAT. TDTP LCO1.TDTP 2.074 SDSI. TDTP 1.079 BACK. TDTP 231.774 FBAC. TDTP TCAN. TDTP 10771.359 TCAF. TDTP 5194.059 TCND.TDTP 16170.381 TCFD.TDTP TSCN. TDTP 2283.528 TSCF. TDTP 1101.140 INND. TDTP 850.343 INFD. TDTP GRCH. TDTP 54.375 TENS. TDTP 1380.000 CCL. TDTP 0.000 49.395 1.950 51.434 4312.072 337.273 59.873 1.381 47.594 4938.252 332.889 END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 10 **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO ~T FILE : **** FILE HEADER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER: 3 EDITED CURVES Depth shifted amd clipped curves for each pass in separate files. PASS ~ER : 3 DEPTH INCREI4ENT: O. 5000 FILE SU~!ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10376.0 9800.0 TDTP 10400.0 9800.0 $ 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 88883.5 88883.5 10373.0 10368.5 10370.0 10365.0 10360.0 10355.5 10353.5 10350.0 10342.0 10338.5 10325.5 10323.5 10322.0 10317.5 10277.5 10274.5 10273.5 10270.5 10266.5 10263.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 11 10264.5 10262.0 10259.5 10257.0 10257.5 10252.0 10251.0 10251.0 10247.5 10246.5 10213.5 10214.0 10204.5 10205.0 10201.0 10202.0 10200.5 10201.5 10191.5 10189.0 10186.0 10183.0 10182.0 10180.0 10180.0 10177.5 10179.0 10177.5 10176.5 10174.0 10170.0 10168.5 10159.5 10159.0 10143.5 10144.5 10122.0 10123.5 10118.0 10120.5 10110.5 10112.5 10105.0 10105.0 10093 . 5 10094.5 10065.0 10064.5 10032.0 10033.5 10031.5 10033.5 10012.5 10014.0 10011.5 10014.0 10007.5 10009.5 10007.0 10009.5 9990.0 9991.5 9989.5 9991.5 9986.5 9989.0 9983.0 9984.5 9982.5 9984.0 9970.0 9971.5 9969 . 5 9971 . 5 9965.0 9967.5 9963.5 9965.0 9963.0 9965.0 9954.0 9955.5 9953.5 9955.0 9946.0 9949.0 9948.5 9942.0 9944.0 9937.5 9940.0 9934.0 9935 . 5 9935.5 9924.0 9925.5 9916.0 9918.5 9915.5 9918.5 9909.0 9911 . 0 9898.0 9900.0 9896.5 9897.5 9894 . 5 9896.0 9882.5 9885.5 9880.0 9882.5 9882.0 9874.5 9876.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 12 9872 9862 9861 9853 9845 9840 9834 9831 0 9814 0 9813 5 9809 0 9806 0 9805 5 100.0 $ .5 5 5 9862.5 5 5 5 9841.5 5 9836.0 9816.5 9811.5 9809.0 103.0 9875.0 9865.5 9856.0 9847.0 9843.0 9834.0 9816.5 9809.0 103.5 RE~ARKS: THIS FILE CONTAINS TDTP PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #3 GRCH TO PASS #1GRCH; AND PASS #3 SIGM TO PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 13 ** 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 1065805 O0 000 O0 0 3 1 1 4 68 SIGMTDTP CU 1065805 O0 000 O0 0 3 1 1 4 68 TPHI TDTP PU-S 1065805 O0 000 O0 0 3 1 1 4 68 SBHF TDTP CU 1065805 O0 000 O0 0 3 1 1 4 68 SBHNTDTP CU 1065805 O0 000 O0 0 3 1 1 4 68 SIGC TDTP CU 1065805 O0 000 O0 0 3 1 1 4 68 SIBH TDTP CU 1065805 O0 000 O0 0 3 1 1 4 68 TRAT TDTP 1065805 O0 000 O0 0 3 1 1 4 68 LCO1 TDTP 1065805 O0 000 O0 0 3 1 1 4 68 SDSI TDTP CU 1065805 O0 000 O0 0 3 1 1 4 68 BACK TDTP CPS 1065805 O0 000 O0 0 3 1 1 4 68 FBAC TDTP CPS 1065805 O0 000 O0 0 3 1 1 4 68 TCAN TDTP CPS 1065805 O0 000 O0 0 3 1 1 4 68 TCAF TDTP CPS 1065805 O0 000 O0 0 3 1 1 4 68 TCND TDTP CPS 1065805 O0 000 O0 0 3 1 1 4 68 TCFD TDTP CPS 1065805 O0 000 O0 0 3 1 1 4 68 TSCNTDTP CPS 1065805 O0 000 O0 0 3 1 1 4 68 TSCF TDTP CPS 1065805 O0 000 O0 0 3 1 1 4 68 INND TDTP CPS 1065805 O0 000 O0 0 3 1 1 4 68 INFD TDTP CPS 1065805 O0 000 O0 0 3 1 1 4 68 GRCH TDTP GAPI 1065805 O0 000 O0 0 3 1 1 4 68 TENS TDTP LB 1065805 O0 000 O0 0 3 1 1 4 68 CCL TDTP V 1065805 O0 000 O0 0 3 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 10395.500 SIGM. TDTP 31.415 TPHI.TDTP 44.565 SBHF. TDTP SBt~N. TDTP 49.918 SIGC. TDTP 0.420 SIBH. TDTP 120.693 TRAT. TDTP LCO1.TDTP 3.035 SDSI.TDTP 0.557 BACK. TDTP 263.481 FBAC. TDTP TCAN. TDTP 27733.605 TCAF. TDTP 8537.553 TCND. TDTP 19320.227 TCFD. TDTP TSCN. TDTP 3184.668 TSCF. TDTP 1049.202 INND. TDTP 822.594 INFD. TDTP GRCH. TDTP -999.250 TENS. TDTP 1445.000 CCL.TDTP 0.000 DEPT. 9803. 000 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP LCO1. TDTP -999. 250 SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP TCAN. TDTP -999. 250 TCAF. TDTP -999. 250 TCND. TDTP -999. 250 TCFD. TDTP TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999. 250 INFD. TDTP GRCH. TDTP 61. 906 TENS. TDTP -999. 250 CCL. TDTP -999. 250 46.695 1.827 60.005 5233.377 346.845 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 14 **** FILE TRAILER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION . O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION . O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, TDTP THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 15 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NglVlE SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNPNAV CU 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 TCAFPNAV CPS 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 TCND PNAV CPS 1065805 O0 000 O0 0 4 1 i 4 68 0000000000 TCFD PNAV CPS 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 INND PNAV CPS 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 LCO1 PNAV 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1065805 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10386.000 SIGM. PNAV 37.534 TPHI.PNAV 55.144 SBHF. PNAV SBP~N. PNAV 52.539 SIGC. PNAV O. 461 SIBH. PNAV 133. 722 TRAT. PNAV SDSI. PNAV 0. 733 BACK. TDTP 108. 155 FBAC. TDTP 24. 152 TCAN. PNAV TCAF. PNAV 5865.677 TCND. PNAV 17026.004 TCFD. PNAV 4274.158 TSCN. PNAV TSCF. PNAV 633.286 INND.PNAV 845. 690 INFD.PNAV 337. 400 LCO1 .PNAV GRCH. TDTP -999 . 250 44.653 1.805 20847.164 2132.781 3.369 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 16 DEPT. 9803.500 SIGM. PNAV 21. 014 TPHI.PNAV 23. 059 SBHF. PNAV 58. 706 SBPiN. PNAV 67.618 SIGC. PNAV 1. 730 SIBH. PNAV 94.259 TRAT. PNAV 1.358 SDSI.PNAV 1. 057 BACK. TDTP 167. 342 FBAC. TDTP 39. 192 TCAN. PNAV 10986. 008 TCAF.PNAV 5398.473 TCND.PNAV 15964.797 TCFD.PNAV 4926.671 TSCN. PNAV 2265.344 TSCF. PNAV 1114. 756 INND.PNAV 858. 656 INFD.PNAV 338.514 LCO1 .PNAV 2. 038 GRCH. TDTP 41. 781 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NY]M~ER : 1 DEPTH INCREM~Jfr: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 10406.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TII4~ LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : STOP DEPTH 9789.5 18-AUG-97 CP 44.2 1010 18-AUG-97 11081.0 9800.0 10406.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 17 LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAI~VZA RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CGRS-A-863 TDTP SET 230 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 3. 725 11113.0 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) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMA~ 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: TIED INTO SPERRY GR DATED 9/17/95 PUMPED 370 BBLS CRUDE INTO TUBING AT 5 BPM BEFORE LOGGING. MADE 3 PASSES FROM 10400 TO 9800 WHILE PUMPING AT 1 BPM AT 10165' (LINER BTM) CHANGED: BS= 8.5, CSIZ= 7, CWEI= 35.5. GOC AT 10190'. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 18 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E 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 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PS1 CU 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 SBH~PS1 CU 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PSl CU 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PS1 CU 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 LCO1 PS1 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PSi CU 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 BACK PS1 CPS 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 TCANPS1 CPS 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 TCAFPS1 CPS 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 TCNDPS1 CPS 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD PS1 CPS 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PS1 CPS 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PS1 CPS 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 INNDPS1 CPS 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 INFDPS1 CPS 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1065805 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 19 ** DATA ** DEPT. 10406.500 SIGM. PS1 27.650 TPHI.PS1 SBP~N. PS1 166.075 SIGC. PS1 0.000 SIBH. PS1 LCO1.PS1 3.094 SDSI.PS1 4.020 BACK. PSI TCAN. PS1 11199.113 TCAF. PS1 3619.678 TCND.PS1 TSCN. PS1 2105.281 TSCF. PS1 680.450 INND.PS1 TENS.PSi 1135.000 GR.PS1 66.688 CCL.PS1 DEPT. 9789.500 SIGM. PS1 11.026 TPHI.PS1 SBHN. PS1 64.881 SIGC. PS1 0.539 SIBH. PS1 LCO1.PS1 1.763 SDSI.PS1 0.241 BACK. PSi TCAN. PS1 36283.258 TCAF. PS1 20584.965 TCND. PS1 TSCN. PS1 7167.960 TSC?.PS1 4066.674 INND. PS1 TENS.PSi 1400.000 GR.PS1 22.766 CCL.PS1 39 657 697 514 86 982 17208 293 913 477 0 026 15 354 82 495 176 768 22559 582 884 357 0 000 SBHF. PS1 TRAT. PS1 FBAC. PS1 TCFD.PS1 INFD. PS1 SBHF. PS1 TRAT. PS1 FBAC. PS1 TCFD.PS1 INFD.PS1 105.479 1.735 16.049 4378.158 324.439 56.105 1.418 31.335 9226.982 376.909 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~BER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~LARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 2O TDTP 10406.5 $ LOG HEADER DATA 9789.5 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) : 18-AUG-97 CP 44.2 1010 18-AUG-97 11081.0 9800. 0 10406.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAb~gA RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CGRS-A-863 TDTP SET 230 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 3. 725 11113.0 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) : CRUDE 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): LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 21 REM_ARKS: TIED INTO SPERRY GR DATED 9/17/95 PUMPED 370 BBLS CRUDE INTO TUBING AT 5 BPM BEFORE LOGGING. MADE 3 PASSES FROM 10400 TO 9800 WHILE PUMPING AT 1 BPM AT 10165' (LINER BTM) CHANGED: BS= 8.5, CSIZ= 7, CWEI= 35.5. GOC AT 10190'. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 92 66 1 66 0.5 FT 11 0 FT 68 1 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~ CODE (HEX) DEPT FT 1065805 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1065805 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1065805 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 1065805 O0 000 O0 0 6 1 1 4 68 0000000000 SBP~VPS2 CU 1065805 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 1065805 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 1065805 O0 000 O0 0 6 1 1 4 68 0000000000 TROT PS2 1065805 O0 000 O0 0 6 1 1 4 68 0000000000 LCO1 PS2 1065805 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 1065805 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 22 NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BACK PS2 CPS 1065805 O0 000 O0 0 6 1 1 4 FBAC PS2 CPS 1065805 O0 000 O0 0 6 1 1 4 TCANPS2 CPS 1065805 O0 000 O0 0 6 1 1 4 TCAFPS2 CPS 1065805 O0 000 O0 0 6 1 1 4 TCND PS2 CPS 1065805 O0 000 O0 0 6 1 1 4 TCFD PS2 CPS 1065805 O0 000 O0 0 6 1 1 4 TSCN PS2 CPS 1065805 O0 000 O0 0 6 1 1 4 TSCF PS2 CPS 1065805 O0 000 O0 0 6 1 1 4 INND PS2 CPS 1065805 O0 000 O0 0 6 1 1 4 INFD PS2 CPS 1065805 O0 000 O0 0 6 1 1 4 TENS PS2 LB 1065805 O0 000 O0 0 6 1 1 4 GR PS2 GAPI 1065805 O0 000 O0 0 6 1 1 4 CCL PS2 V 1065805 O0 000 O0 0 6 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 10415 500 SIGM. PS2 SBt{N. PS2 57 769 SIGC. PS2 LCO1.PS2 3 635 SDSI. PS2 TCAN. PS2 14177 461 TCAF. PS2 TSCN. PS2 2444 805 TSCF. PS2 TENS.PS2 1130 000 GR.PS2 DEPT. 9799 000 SIGM. PS2 SBP~V. PS2 66 653 SIGC. PS2 LCO1.PS2 2 041 SDSI. PS2 TCAN. PS2 15819 092 TCAF. PS2 TSCN. PS2 3350 132 TSCF. PS2 TENS.PS2 1360 000 GR.PS2 10.220 TPHI.PS2 23.969 SBHF. PS2 0.406 SIBH. PS2 132.525 TRAT. PS2 0.145 BACK. PS2 219.594 FBAC. PS2 3900.078 TCND.PS2 16820.703 TCFD.PS2 672.541 INND.PS2 872.627 INFD. PS2 89.563 CCL.PS2 0.013 17 354 TPHI.PS2 22.061 SBHF. PS2 1 479 SIBH. PS2 88.941 TRAT. PS2 0 629 BACK. PS2 228.829 FBAC. PS2 7749 095 TCND.PS2 18099.070 TCFD. PS2 1641 086 INND.PS2 842.380 INFD. PS2 49 531 CCL.PS2 0.000 45. 065 1. 972 62. 143 4169. 190 348. 125 59.428 1.445 48.791 5773.881 351.073 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 23 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE . FLIC VERSION : O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMEJgT: 0.5000 FILE SUM~zARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10406.5 9789.5 TDTP LOG HEADER DATA DATE LOGGED: 18-AUG- 97 SOFTWARE VERSION: CP 44.2 TI~E LOGGER ON BOTTOM: 1010 18-AUG-97 TD DRILLER (FT) : 11081.0 TD LOGGER (FT) : TOP LOG INTERVAL (FT) : 9800.0 BOTTOM LOG INTERVAL (FT) : 10406.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAlVk~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) : TOOL NUMBER ........... CGRS-A-863 TDTP SET 230 3.725 11113.0 CRUDE LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PA GE: 24 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL R~TIO: 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: TIED INTO SPERRY GR DATED 9/17/95 PUMPED 370 BBLS CRUDE INTO TUBING AT 5 BPM BEFORE LOGGING. MADE 3 PASSES FROM 10400 TO 9800 WHILE PUMPING AT 1 BPM AT lO165'(LINER BTM) CHANGED: BS= 8.5, CSIZ= 7, CWEI= 35.5. GOC AT 10190'. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 O. $ 9 65 FT 11 66 11 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1997 11:59 PAGE: 25 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE ND?~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1065805 00 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPS3 CU 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS3 CU 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 LCO1 PS3 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS3 CPS 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 TCAFPS3 CPS 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 TCNDPS3 CPS 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 TCFDPS3 CPS 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS3 CPS 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 INNDPS3 CPS 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 INFDPS3 CPS 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1065805 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 10416.000 SIGM. PS3 12.616 TPHI.PS3 18.061 SBHF. PS3 SBHN. PS3 63.612 SIGC. PS3 0.522 SIBH. PS3 140.070 TRAT. PS3 LCO1.PS3 2.584 SDSI.PS3 0.198 BACK. PS3 273.347 FBAC. PS3 TCAN. PS3 20176.824 TCAF. PS3 7807.721 TCND.PS3 19221.434 TCFD.PS3 TSCN. PS3 3083.838 TSCF. PS3 1193.337 INND. PS3 831.269 INFD.PS3 TENS.PS3 1135.000 GR.PS3 96.938 CCL.PS3 0.017 44.980 1.602 38.375 5510.523 349.582 ** END OF DATA ** LIS Tape Vt cation Listing Schlumberger Alaska Computing Center 22-0CT-1997 1~ PAGE: 26 **** FILE TRAILER **** FILE NA~E : EDIT .007 SERVICE · FLIC VERSION : O01CO1 DATE : 97/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/10/22 ORIGIN : FLIC TAPE NAME : 97479 CONTINUATION # : 1 PREVIOUS TAPE : COn, lENT : ARCO ALASKA INC, D.S. 7-20A, PRUDHOE BAY, 50-029-20902-01 **** REEL TRAILER **** SERVICE NA14~ : EDIT DATE : 97/10/22 ORIGIN : FLIC REEL NA~E : 97479 CONTINUATION # : PREVIOUS REEL .. CO~ : ARCO ALASKA INC, D.S. 7-20A, PRUDHOE BAY, 50-029-20902-01 t Tape Subfile 2 is type: LIS TAPE HEADER DRUDHOE BAY UNIT MWD/Man LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 664O.00 WORTHINGTON BASS/MOORE D.S. 7-20A 500292090201 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 24-MAY-96 MWD RUN 5 WORTHINGTON BASS/MOORE MWD RUN 6 WORTHINGTON BASS/MOORE MWD RUN 7 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD WORTHINGTON BASS/MOORE MWD RUN 8 WORTHINGTON BASS/MOORE MWD RUN 9 B. JAHN BASS/MOORE OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 1ST STRING 13.375 2ND STRING 9.625 3RD STRING 7.000 PRODUCTION STRING 3.750 REMARKS: DRILLERS ^~s ~,~.~,z0i!&GasOo~o. Oommission DEPTH (FT) Anchorage 2517.0 9627.0 10170.0 11123.0 MWD - GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUNS 1 THROUGH 9 WERE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP/SGRD). NO FOOTAGE WAS MADE ON MWD RUNS 1 THROUGH 3. NO DATA IS PRESENTED. GAMMA RAY DATA IS DOWNHOLE RECORDED. A GAMMA RAY TOOL VERIFIER WAS USED PRE/POST TOOL SWAPS. LESS THAN A 2% CHANGE WAS SEEN. AS PER THE CONVERSATION BETWEEN DOUG KNOCK (ARCO ALASKA) AND ALI TURKER (SPERRY-SUN) ON 29-MAR-96, NO DEPTH SHIFTING WAS REQUIRED FOR THE MWD DATA ON THIS WELL. FILE HEADER FILE NIIMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 10146.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: STOP DEPTH 11100.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 10167.0 10178.0 10178.0 10219.0 10219.0 10394.0 10394.0 10548.0 10548.0 10715.0 10715.0 11123.0 MERGED PASS. CN WN FN COLIN STAT : ARCO ALASKA, INC. : D.S. 7-20A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Tip Tip Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 24 Tape File Start Depth = 11124.000000 Tape File End Depth = 10145.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5878 datums Tape Subfile: 2 118 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SLIMMARY VENDOR TOOL CODE START DEPTH GR 10145.0 $ 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 10156.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 4. 16-SEP-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 10178.0 10167.0 10178.0 0 37.9 38.6 TOOL NUMBER NGP 110 3.800 10170.0 BIOZAN/SEAWATER .00 .0 .0 0 .0 .000 .0 .000 167.0 .000 .0 .000 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 7-20A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 858 BYTES * Total Data Records: Tape File Start Depth = 10180.000000 Tape File End Depth = 10145.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 214 datums Tape Subfile: 3 64 records... Minimum record length: Maximum record length: 62 bytes 858 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10148.0 $ 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) MINIMI/MANGLE: MAXIMUM ANGLE: STOP DEPTH 10197.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 5. 17-SEP-95 MSC 1.32 DEP 2. 042 / NGP 5.74 MEMORY 10219.0 10178.0 10219.0 0 44.6 48.1 TOOL NUMBER NGP 110 3.750 10170.0 FLO- PRO 9.00 73.0 10.0 37000 5.2 .000 .000 .000 .000 .0 145.9 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT ARCO ALASKA, INC. D.S. 7-20A PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 2 Tape File Start Depth = 10220.000000 Tape File End Depth = 10145.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6332 datums Tape Subfile: 4 65 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NI/MBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10177.0 $ 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 10372.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 6. 18-SEP-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 10394.0 10219.0 10394.0 0 53.7 69.9 TOOL NUMBER NGP 110 3.750 10170.0 FLO-PRO 9.00 68.0 10.0 36500 5.6 .000 .000 .000 .000 .0 150.1 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 7-20A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 10400.000000 Tape File End Depth = 10175.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1568 datums Tape Subfile: 5 69 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10366.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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: MAXIM UMANGLE: STOP DEPTH 10526.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 7. 19-SEP-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 10548.0 10394.0 10548.0 0 73.5 87.4 TOOL NUMBER NGP 182 3.750 10170.0 FLO-PRO 9.00 74.0 10.0 37000 .0 .000 .000 .000 .000 .0 154.4 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 7-20A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 5 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 Tape File Start Depth = 10550.000000 Tape File End Depth = 10360.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7476 datums Tape Subfile: 6 68 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10261.0 $ 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 10693.0 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 (CB): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 8. 20-SEP-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 10715.0 10548.0 10715.0 0 90.4 94.0 TOOL NUMBER NGP 182 3.750 10170.0 FLO- PRO 9.00 64.0 9.5 54000 .0 .000 .000 .000 .000 .0 158.5 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT ARCO ALASKA, INC. D.S. 7-20A PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 11 Tape File Start Depth = 10720.000000 Tape File End Depth = 10260.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4332 datums Tape Subfile: 7 74 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10695.0 $ 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 11100.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 9. 21-SEP-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 11123.0 10715.0 11123.0 0 85.5 92.0 TOOL NUMBER NGP 182 3.750 10170.0 FLO-PRO 9.00 70.0 10.0 57000 .0 .000 .000 .000 .000 .0 158.5 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT ARCO ALASKA, INC. D.S. 7-20A PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 11 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 Tape File Start Depth = 11124.000000 Tape File End Depth = 10690.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 10084 datums Tape Subfile: 8 74 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 9 is type: LIS 96/ 5/24 01 **** REEL TRAILER **** 96/ 5/24 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 24 MAY 96 8:33p Elapsed execution time = 1.1'6 seconds. SYSTEM RETURN CODE = 0