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Home My WebLink About196-159 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 11, 2012 Mr. Jim Regg 5064114ED. AUG 2 i 2012 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 15c1 Anchorage, Alaska 99501 I� Subject: Corrosion Inhibitor Treatments of GPB DS -05 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 05 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -05 Date: 01/10/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD 4 API 4 cement pumped cement date inhibitor sealant date ft _ bbls _ ft gal 05 -01C 1990280 50029201360000 Sealed conductor NA NA N/A N/A NA 05 -02A 2012410 50029201440100 Sealed conductor NA NA N/A N/A NA 05 -03C 2000940 50029201470300 Sealed conductor NA NA N/A N/A NA 05 -04A 1960890 50029201520100 Sealed conductor NA NA N/A N/A NA 05 -058 1961800 50029201700200 Sealed conductor NA NA N/A N/A NA 05 -06A 1950840 50029201730100 0 NA 0 N/A N/A NA 05 -07 1770130 50029202430000 Sealed conductor NA NA N/A N/A NA 05 -08A 2100550 50029202480100 Sealed conductor _ NA NA N/A N/A NA 05 -09A 1990140 50029202540100 Sealed conductor NA NA N/A N/A NA 05 -10C 2070980 50029202630300 Sealed conductor NA NA N/A N/A NA 05-11A 1960970 50029202520100 Sealed conductor NA _ NA N/A N/A NA 05 -12B 2011800 50029202440200 Sealed conductor NA NA N/A N/A NA 05 -13B 2071460 50029202500200 Sealed conductor NA NA N/A N/A NA 05 -14A 1930820 50029202530100 Sealed conductor NA NA N/A N/A NA 05 -15B 1960230 50029202550200 Sealed conductor NA _ NA N/A N/A NA 05 -16B 1991000 50029202620200 Sealed conductor NA NA N/A N/A NA 05 -17B 1981040 50029202710200 Sealed conductor NA NA N/A N/A NA 05 -18A 1981740 50029219600100 Split conductor NA NA N/A N/A N/A 05 -19 1890780 50029219620000 1.4 NA 1.4 N/A 8.5 4/11/2011 05 -20B 2042340 50029221370200 1.2 NA 1.2 N/A 5.1 4/18/2011 05 -21A 1981180 50029219690100 Dust Cover NA NA N/A N/A N/A 05 -228 2071260 50029219760200 3.1 NA 3.1 N/A 18.7 4/17/2011 05 -23B 2080610 50029219630200 1.2 NA 1.2 N/A 5.1 4/11/2011 05 -24A 2042180 50029222040100 1.5 NA 1.5 N/A 10.2 4/11/2011 05 -25C 2091240 50029219880300 6.0 NA 6.0 N/A 44.2 4/18/2011 05 -26A 2012210 50029219840100_ 0.5 NA 0.5 N/A 3.4 4/12/2011 05 -27B 2081910 50029219790200 Sealed conductor NA NA N/A N/A N/A 05 -28B 2060890 50029222080200 0.6 NA 0.6 N/A 1.7 4/10/2011 05 -30 1911150 50029222130000 i 1.2 NA 1.2 N/A 10.2 4/11/2011 05-31B 2100850 50029221590200 1.3 NA 1.3 N/A 6.8 4/12/2011 05 -32A 2020010 50029221900100 20.0 6.0 0.5 7/13/2011 3.4 7/23/2011 05 -33B 2100810 50029221680200 4.8 NA 4.8 N/A 37.4 4/27/2011 05 -34A 2080370 50029222170100 3.9 NA 3.9 N/A 18.7 1/4/2012 05 -35A 2081340 50029221720100 2.7 NA 2.7 N/A 18.7 4/18/2011 05 -36A 2050700 50029221820100 2.3 NA 2.3 N/A 13.6 4/12/2011 05 -38 1961850 50029227220000 1.8 NA 1.8 N/A 15.3 4/10/2011 05 -39 1961730 50029227150000 1.3 NA 1.3 N/A 10.2 4/10/2011 ---) 05-40 1961590 50029227070000 1.6 N/A 1.6 N/A 16.2 1/10/2012 05-41A 2031700 50029226960100 , 5.0 NA 5.0 N/A 58.7 1/8/2012 -.~~ STATE OF ALASKA ~~~ ~6'+~~ ALASKA OIL AND GAS CONSERVATION COM SION ~~T Z ~ 2007 REPORT OF SUNDRY WELL OPERATIONS gl~ska Oil & Gas Conjs. Ctlnxnissian Ancheraaa 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 196-159 ` 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22707-00-00 7. KB Elevation (ft): 71 1' ~ 9. Well Name and Number: PBU 05-40 - 8. Property Designation: 10. Field /Pool(s): ADL 028328 ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 10987 ~ feet true vertical 9058 ~ feet Plugs (measured) 9388' &9495 Effective depth: measured 10915 feet Junk (measured) None true vertical 9051 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3855' 9-5/8" x 7-5/8" 3890' 3646' 5750 3090 Intermediate 9589' 7" x 5-1/2" 9622' 8704' 7740 6280 Production Liner 1536' 3-1/2" 9451' - 10987' 8551' - 9058' 10160 10530 Scab Liner 5371' 3-1/2" 4074' - 9445' 3809' - 8546' 10160 10530 Perforation Depth MD (ft): 10350' - 10830' ~~ NCB ~ 9 2~D~ ~~~ Perforation Depth TVD (ft): 8995' - 9043' 3-1/2", 9.2# 13Cr80 4080' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 5-1/2" x 3-1/2" Baker'SABL-3' packer y 4035' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Pull existing tubing. Set 3-1/2" HES Fasdrill Plug at 949 5'. Run 3-1/2" Scab Liner, cemented with 82 Bbls Class'G' (460 cu ft / 397 sx . Run new Chrome Com letion . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or wA it C.O. Exempt: Contact Paul Chan, 564-5254 307-225 Printed Name Terrie Hubble Title Drilling Technologist ~ Prepared By Name/Number: I a~6~` ` Signature Phone 564-4628 . Date 7 Terrie Hubble, 564-4628 o Form 10-404 Revised 04/2006 ~ ~ ~ ^ ~ A ' A L ~a~'~ J ~~, i ~ ~ ~ `,O~\~ Submit Original Only Dibital Well File ~ ~ Page 1 of 2 Well: 05-40 Well History Well Date Summary 05-40 7/16/2007 '**WELL S/I ON ARRIVAL*** (pre rwo) DRIFT TO PXN PLUG BODY ~ 9298' SLM W/ 2.70" CENT & S-BAILER. RECOVER SAMPLE OF WHAT APPEARS TO BE MUD. CALIPER FROM 9279' SLM TO SURFACE IN PROGRESS ***CONTINUED ON 7/17!07*** 05-40 7/17/2007 ***CONTIUNED FROM 7/16/07*** LOGGED FROM 9,279' SLM TO SURFACE W/ 24 ARM CALIPER. RELIEVED GOOD DATA. ***WELL LEFT S/I. DSO NOTIFIED.*** 05-40 7/23/2007 WELL SHUT IN ON ARRIVAL T/IA/OA = 800/650/300 RIH WITH 2.5" SCP TO 9278', POOH RECONFIGURED TOOLSTRING -RIH WITH 2.5" SCP TO 9302' ,CUT 3.5" TUBING AT 9289', 3' ABOVE PKR ELL LE HU FINAL WHP = T/IA/OA = 700!650/300 ***JOB COMPLETE*** 05-40 7/25/2007 T/IA/OA= 640/640/340 Temp SI PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU HP bleed tool onto THA test void, 0 psi on void, RU 2nd HP bleed tool onto off side Alemite flush void until clean returns achieved. Cycled LDS "ET style" all moved free with no bent pins. Pressured THA void to 5000 psi for 30 minutes. RD 2nd HP bleed tool, reinstalled Alemite cap. 4950/ 15 minutes, 4950/ 30 minutes. Bleed THA void to 0 psi, RD test equipment reinstalled Alemite cap. PPPOT-IC RU HP bleed tool onto IC test void, 0 psi on void, RU 2nd HP bleed tool onto off side Atemite, flushed void until clean returns achieved. Cycled LDS "ET style" all moved free with no bent pins. Pressured IC void to 3000 psi for 30 minutes. RD 2nd HP bleed tool, reinstalled Alemite cap. 3000/ 15 minutes, 3000/ 30 minutes. Bleed IC void to 0 psi, RD test equipment reinstalled Alemite cap. 05-40 7/25/2007 T/I/0=640/640/320 Temp=Sl Bleed WHPs to 0 psi (Pre-RWO). TBG, IA, OA FLs @ surface. Unable to bleed because of PC leak issues and PX prong has been pulled out of PXN plug body. **Plug still in TBG. TBG has been cut** 05-40 8/6/2007 T/I/0=600/650/320 temp=Sl Circ-out (RWO Prep) Pumped 5 bbls methanol spear,290 bbls 9.8# brine and 45 bbls diesel down TBG taking returns up IA to jumper line and down Flow Line. Let U-tube for 1 hr. Freeze Protected Flow Line with 26 bbls diesel. Bled TBG and IA to 0 psi. OA pressure would not fall below 300 psi. Tagged and closed Wing valve, Master, IA and OA valves in open position ~ departure. Notified DSO of results. FW H P's=0/0/300 05-40 8/8/2007 T/I/0= 120/ 80/300. Temp= SI. Bleed WHP's to 0 psi (RWO prep). TBG, IA & OA FL ~ surface. Bled IAP from 80 psi to 55 psi in 1 hr, bled OAP from 300 psi to 290 psi in 1 hr. Bleed Trailer reach max volume, trailer will be vac out overnight. After 30 mins IAP unchanged, OAP increased 10 psi. Hardline rigged up from IA to Flowline for circ-out. Final WHPs= 120/55/300. 05-40 8/10/2007 T/I/O = 120/55/300. Temp = SI. Bleed WHPs to 0 psi (RWO prep). Hardline rigged up from IA to flowline for cir-out. TBG, IA & OA FL ~ surface. Bled IA from 55 psi to 0 psi in 1.5 hr (8 bbl). Bled OA from 300 to 40 psi in 2 hrs (18 bbl). Monitored for 30 min. IA gained 7 psi & OA unchaged. Final WHPs 120/7/40. 05-40 8/12/2007 T/I/0=200/0/160. Bullhead tubing and IA with 9.8# brine thru PC leak (RWO prep) Pumped 5 bbls neat methanol, 150 bbls 9.8# brine, and 5 bbls diesel down tubing. Pumped 5 bbls neat methanol, 115 bbls 9.8# brine and 5 bbls diesel down IA. FWHP's=vac/vac/160. Annulus valves open to gauges. 05-40 8/13/2007 T/I/O=SSVNAC/160. Temp SI. Monitor (RWO prep). Flow lines and WH removed. OA FL @ surface. 05-40 8!14/2007 TIO= vac/vac/190. SI. Monitor WHPs (RWO prep). 05-40 8/15/2007 T/I/O=VACNAC/190. Temp SI. Bleed OAP to 0 (RWO prep). OA FL ~ surface. Bled OAP from 190 psi to 0 psi in 30 min to a bleed trailer. Final WHP's T/I/O=VACNAC/0. 05-40 8/16/2007 T/I/O =VACNAC/170. Temp = SI. Monitor WHP (RWO prep). OAP increased 170 psi ovemight. *Note: WH, FL, & AL line removed, Drilling scaffolding on well.* 05-40 8/25/2007 T/I/O=VACNAC/220. SI. Bleed OAP to 0 psi (Pre-RWO). OA FL near surface. Bled OAP from 220 psi to 0 psi in 5 minutes. All fluid. Monitored 30 minutes. OAP increased 150 psi. Bled back to 0 psi. Monitored 15 minutes. OAP increased 30 psi. Bled back to 0 psi. Monitored 30 minutes. OAP increased 100 psi. Bled back to 0 psi. Monitored 30 minutes. OAP increased 100 psi. Bled back to 0 psi several more times with the OAP increasing to 100 psi each time. Final WHPs=VACNAC/100 05-40 8/25/2007 Set BPV, Set Good http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 10/16/2007 Digital Well File ~ ~ Page 2 of 2 05-40 8/25/2007 T/I/O=VACNAC/130. Temp=Sl. WHPs (post-bleed, pre-RIG). TBGP & IAP unchanged, OAP increased 30 psi overnight. ***Note*** BPV in hole. 05-40 8/26/2007 T/I/0= BPV/vac/160. (RWO Prep) Load to secure OA. Pumped 0.8 bbls neat. Pressure up to 2000 psi. Held for 10 min. Bled back 0.9 bbls to 0 psi. Pump 0.9 bbls to achieve 2000 psi. Lost 1400 psi / 3 min. Pump anothe 6 bbls of neat until reaching 2000 psi. Lost 320 psi / 30 min. Bled back 0.8 bbls to 0 psi. Gained 160 psi / 30 min. ***WSR continues on 8/27/07*** 05-40 8/27/2007 ***WSR continued from 8/26/07*** (RWO Prep) OA Load & Kill. Bled OA from 160 psi to 0 psi (0.1 bbls). Pumped it back to 2000 psi with 0.9 bbls of neat. Lost 60 psi / 1st 15 min and 80 psi / 2nd 15 min. Bled to 0 psi and pumped it back to 2000 psi two more times using 0.9 bbls each time. Bled to 0 psi. Gained 60 psi in 15 min. Bled to 0 psi. Gained 20 psi in 15 min. Bled to 0 psi. Stayed at 0 psi for 45 min. Final WHP=BPV/0/0. Annulus casing valves tagged and left open. 05-40 8/28/2007 T/1/O=BPV/vac/200. Temp=Sl. Monitor WHPs. No pressure on TBG. Flowline & wellhouse have been removed. No A/L. 05-40 8/29/2007 T/I/O = BPVNAC/210. Temp SI. Monitor WHP's (post- L&K, pre - RWO) No pressure above BPV. NO Flowline or A/L Print Date: 10/16/2007 Page 1 of 1 http://digitalwellfile.bpweb.bp.corn/WIInfo/Reports/ReportViewer.aspx 10/16/2007 DECOMP BP EXPLORATION Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Operations Summary Report 05-40 05-40 WORKOVER DOYON DRILLING INC DOYON 16 Date ;From - To Hours ~ Task 8/30/2007 06:00 - 08:00 ~ 2.00 MOB 08:00 - 13:00 5.00 MOB i I 13:00 - 14:00 ~ 1.00 MOB 14:00 - 15:00 1.00 MOB i 15:00 - 16:00 1.00 MOB 16:00 - 17:00 1.00 MOB 17:00 - 19:00 2.00 MOB 19:00 - 00:00 ~ 5.00 MOB Start: i' 8/30/2007 Rig Fj~elease: 9/13/2007 Rig f~umber: Code I NPT Phase _~_ PRE PRE PRE PRE PRE' PRE PRE PRE 8/31/2007 100:00 - 02:00 2.00 MOB P PRE '.02:00 - 04:30 2.50 MOB P PRE 04:30 - 07:30 j 3.00 MOB P I 07:30 - 09:00 1.50 KILL P 09:00 - 10:30 1.50 KILL P 10:30 - 11:30 1.00 WHSUR P 11:30 - 13:30 2.00 WHSUR P 13:30 - 14:00 0.50' WHSUR P 14:00 - 16:00 2.00 WHSUR P 16:00 - 20:30 ~ 4.50 BOPSUF~ P 20:30 - 00:00 i 3.50 BOPSUR P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP u Page 1 of 11 Spud Date: End: 9/13/2007 Description of Operations Continue Rig move from Point Mac1 to DS-05. Move Rig Mats from DS-5 Access Road to DS-5 Reserve Pit Road. Service Rig. Set Herculite and Mats over Well Slot #40. DSM set VR Plug in TBG Spool. Continue Rig Move around Reserve Pit Road to middle of DS-5. R/D Booster Wheels and Equipment. Set Herculite and Rig Mats for Camp. Install BOPE on Stand in Cellar. arse Derrick and secure. B 'dle down . R/U Floor and Top Drive. PJi,SM. Start moving rig over Well Slot #40. Rig sunk into pad. Fjemove BOP Stack from Cellar. Shim up under Tires and p II out of holes in pad. Clean up wood debris. ~et Rig Mats on pad to support Rig. fvlove Rig onto Rig Mats. Place BOPE, new Tree and Adapter Flange in Cellar. Move and spot Rig over Well. Shim into place. Spot and R/U #2 Mud Pump and Slop Tank. Take on 9.8-ppg NaCI brine to Mud Pits. R/U Circulating manifold. Accept rig at 0600-hours. P!U and install Lubricator to pelt BPV. Test to 500-psi. Tubing and IA pressures 0-psi. OA pressure 200-psi. Pull BPV and tubing is on a vacuum. UD Lubricator. H/U Circulating line to tubing and test lines to 3,500-psi. PJSM with truck drivers, MI Engineer, Rig Crew, WSL and Toolpusher for Well Kill circulation. Line up to take circulation from IA through gas buster to Slop Tank. H/U Bleed Trailer to OA and bleed off the 200-psi in seconds. S/I OA. Start circulating 120-F, 9.8-ppg NaCI brine at 1-BPM @ 200-psi, slowly build to 4-BPM @ 750-psi, IA 10-psi, and OA pressure starts increasing to 200-psi. Get returns after 7-Bbls are pumped away (FL at -800' in tubing). Bring rate to 5-BPM @ 1260-psi, IA 20-psi. Pressure climbs to 800-psi in OA. Bleed OA into Bleed Trailer and see a steady stream of fluid into the tank. Fluid weight is that of diesel/crude oil. Continue to bleed off OA pressure and it dies within 2-3-minutes. S/I OA while maintaining pump rate of 5-BPM and OA stays dead. Stop pumping at 254-Bbls with clean returns. Tubing and IA on vacuum, OA dead. Lost 62-Bbls during the circulation. FMC Technician P/U TWC and install in hanger. Test TW C from above to 3,500-psi and held rock-solid for 10-minute; below to 1,000-psi, but formation and/or Cretaceous leak(s) took 6-Bbls in 10-minutes at 1,000-psi (48-BPH at 1,000-psi). Once the Tree is removed, will use a crossover screwed into the 4-1/2" NSCT threads to check the integrity of the threads. Bleed and R/D down test lines. N/D Tree. Giving well a 20-Bbl drink every hour. N/U Adapter Flange and BOPE. Filling hole each hour. R/U to test BOPE. DECOMP ~ Experience trouble getting a BOP Body test. Trouble shoot BOP Stack and Valves. Suspect TWC leaking. CaN DSM to Printed: 10/3/2007 2:21:27 PM • • BP EXPLORATION Operations Summary Report Legal Well Name: 05-40 Common Well Name: 05-40 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours i Task Code 8/31/2007 ! 20:30 - 00:00 ' 3.501 BOPSUF# P 9/1/2007 00:00 - 01:00 01:00 - 02:00 02:00 - 08:30 1.001 BOPSU P 1.001 BOPSU N 6.50! BOPSU P 08:30 - 13:00 4.50 13:00 - 16:00 3.00 BOPSUFIP BOPSUp P 16:00 - 18:30 2.50 i BOPSUFI P 18:30 - 19:00 0.50 BOPSU P 19:00 - 19:30 , 0.50 ~ DHB P 19:30 - 20:00 0.50 ~ PULL P I ~ 20:00 - 20:30 0.50 i PULL ~ P Start: 8/30/2007 Rig Release: 9/13/2007 Rig Number: Page 2 of 1 1 Spud Date: End: 9/13/2007 NPT Phase Description of Operations DECOMP bring out a new TWC and equipment to change out TWC. Test Choke Valves and Floor Valves while waiting on DSM. Test BOPE to 250 psi low pressure and 3500 psi high pressure. Each test was held for 5 minutes. Test was witnessed by Lou Grimaldi with AOGCC, Doyon Toolpusher, and BPX WSL. Test 1-Choke Valves 3, 4, 6, and 4" TIW Valve Test 2- Choke Valves 2, 8, 5, and 4" Dart Valve Test 3- Choke Valves 7 and 9 Test 4- Choke Valves 10 and 12 Test 5- Choke Valves 11, 13 Test 6- Choke Valve 14 DECOMP Continue testing Choke Manifold to 250 psi low pressure and 3500 psi high pressure while waiting on DSM and new TWC. DECOMP P/U DSM Lubricator and Extension. R/U and test Lubricator to 500 psi. Change out TWC. R/D and UD DSM Lubricator and Equipment. DECOMP Continue BOP test. BOP Body still not testing. Continue trouble shooting BOP Stack to find leak. Isolate HCR Valves and Manual Kill and Choke Valves. Not seeing any visual leaks. Change out Test Joint. Get good tests on all Choke and Kill Manifold valves, on the VBRs with 2-7/8" and 3-1 /2" test joints, but cannot get a test on the Blind Rams. Good Koomey test. Give the well a 4-8 Bbl drink via the Charge Pump every hour. It appears that the well is only losing about 4-5 BPH. Find a hydraulic oil leak in the Bonnet gasket on top of the Hydril. Test TWC from below to ensure integrity. Inject at 1.5-BPM at 1,000-psi. Record PR on chart. DECOMP PJSM. Pump out the BOP stack and riser. Unbolt the riser flange. P/U the Potato Masher on a joint of Heavy Wall Drill Pipe, RIH and pull Hydril bonnet to replace gasket. Replace wiper seals and bonnet gasket. M/U Bonnet to Hydril body and tighten bolts. Install test joint and function-test the bag. Okay. DECOMP Install air boots and riser. Open Blind Rams and replace wear ring seals. Close Blind Rams doors and M/U bolts. Start hydraulic pump and fluid hinge on door hinge leaked. Remove and repair fluid hinge. Test the TIW and dart valves for the 2-7/8" HT PAC drill string. DECOMP Resume testin BOPE and all remaining tests are successful to 250-psi low and 3,500-psi high. Hydril had to be retested due to repairs to the bonnet seal. DECOMP R/D BOP Testing Equipment and Lines. DECOMP P/U DSM Lubricator and Extension. M/U same and pull TWC. R/D DSM Lubricator and Equipment. DECOMP PJSM. P/U Landing Joint and M/U Crossovers to 4-1/2" NSCT. M/U to HGR with 7-1/2 turns. BOLDS. PuII HGR to-Rig Floor. HGR broke free @ 112,000 Ibs up weight, TBG String pulled free @ 117,000 Ibs. Up weight while pulling TBG String to Floor- 114,000 Ibs. DECOMP Line up Circulating Lines and CBU. Pump 15 bbls to get return:>. Establish SPR @ 3.3 BPM with 740 psi. Increase Pump Rate to 6.7 8PM with 2100 psi and 180 BPH Loss Rate. Slow F'ump Rate to 5.2 BPM with 1500 psi and Loss Rate at 'i 101 BPH. Bottoms up was clean with no gas. Printed: 10/3/2007 2:21:27 PM • • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date .From - To 9/1/2007 ~ 20:30 - 21:00 21:00 - 21:30 Page 3 of 1 1 05-40 05-40 Spud Date: WORKOVER Start: 8/30/2007 End: 9/13/2007 DOYON DRILLING INC. Rig Release: 9/13/2007 DOYON 16 Rig Number: Hours ! Task ~ Code ! NPT 0.50 PULL~~~, P 0.50! PULL ! P 21:30 - 00:00 2.50 PULL 9/2/2007 00:00 - 07:00 7.00, PULL P P 07:00 - 07:30 0.50 PULL j P 07:30 - 09:00 1.50 CLEAN !. P 09:00 - 10:30 1.50 i CLEAN I P 10:30 - 21:00 10.501 CLEAN ! P f 21:00 - 00:00 ! 3.00 {CLEAN '; P .9/3/2007 100:00 - 16:00 l 16.001 CLEAN N 16:00 - 16:30 I 0.501 CLEAN I N 16:30 - 00:00 9/4/2007 00:00 - 01:00 7.50 I CLEAN I N 1.001 CLEAN I P Phase '' Description of Operations DECOMP PJSM with Rig Crew on POOH and VD TBG. Monitor well. Lost 5 bbls in 20 minutes (15 BPH). DECOMP Break out Landing Joint and UD TBG HGR. R/U Floor to pull 3-1/2", 9.2#, EUE 8rd TBG. DECOMP POOH and UD 3-1/2" EUE 8rd TBG. DECOMP POOH and UD 3-1/2" EUE 8rd TBG. Recover 296 full joints (14-jts 3-1 /2" NSCT + 282-jts 3-1/2" EUE 8-rd), a 4.53' cutoff pup joint, 3-GLMs, 1-SSSV, --485' of single 1/4" SS control line (vs "dual" 1/4" lines as reported in the original completion summary), and 11 SS bands (not reported in the original completion summary). Lost 91.6-Bbls during the POH operation using constant hole fill, -13-BPH. DECOMP RID 3-1/2" tubing handling equipment, clear and clean rig floor. DECOMP R/U 2-7/8" tubing handling equipment: power tongs, floor safety valves. Haul Baker BHA to rig floor. DECOMP P/U M/U the Baker Packer Milling BHA: 4-3/4" x 2-1!4" Packer Mill, 3-ea 3-3/4" Boot Baskets, Bowen Bumper Jar, Bowen Oil Jar, Pump Out sub, and 15-ea 2-7/8" HT PAC DCs. Total Length of BHA #1- 490.32' DECOMP RIH with Packer Milling BHA on 2-7/8" HT PAC from Pipe Shed. Joint #150 RIH at 1630-hours. Fluid foss rate to the well is 6-BPH of 9.8-ppg brine weighed at 1715-hours. Tag TBG Stump C 9286'. Establish parameters of 161,000 Ibs Up Weight; 100,000 Ibs Down Weight. DECOMP Stab TIW Valve and prep to R/U Belly Board. PJSM with Rig Crew and Crane Operator. R/U Equipment and bring Belly Board over Wind Walls. Bring down to Rig Floor and pin Bracing Arms to Belly Board. P/U and attempt to pin into place. Realize Belly Board and Wind Walls were not compatible. Access the situation and alternatives with Town and Rig Team. Decision made to make necessary modification to Belly Board. DECOMP Continue making modifications to Belly Board. Losses continue to be 5-6 BPH with 9.8 ppg NaCI Brine. All welds were inspected and passed by Tuboscope. DECOMP PJSM with Veco crane operator, rig crew, Toolpusher and WSL to discuss the installation of the Belly Board over the windwalls. Each person's part was discussed as well as issues such as taglines, safety wires in all shackle pins, Driller's responsibility for radio communications with the crane operator, and proper terminology for communicating with the operator. Everyone with a radio understood that "Stop" meant that all activity stops instantly when anyone says "Stop". DECOMP R/U slings on the Belly Board and P/U with crane to install over windwall. Attempt to put into place. Make alterations to Belly Board. Lift Belly Board and pin into place. Make sure Belly Board is secured properly. All weld inspected using Tuboscope Magnetic Particle Inspection. All welds passed inspection. R/D Tools and Equipment for making Rig Mods. DECOMP P/U 1 jt of 4" HT-38 Drill Pipe. M/U into Work String and into Top Drive. Establish Milling Parameters of 161,000 Ibs Up Weight; 100,000 Down Weight; 122,000 Ibs Rotating Weight at 40 RPM with 4,500 ft-Ibs; Pump Rate- 3 BPM with 1950 psi. Printed: 10/3/2007 2:21:27 PM • • BP EXPLORATION Operations Summary Report Legal Well Name: 05-40 Common Well Name: 05-40 Event Name: WORKOVER Start: 8/30/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 9/13/2007 Rig Name: DOYON 16 Rig Number: Date From - To 'Hours Task ,Code', NPT I Phase 9/4/2007 00:00 - 01:00 1.00 CLEAN P 101:00 - 09:00 8.00 CLEAN P 09:00 - 09:30 09:30 - 10:00 0.501 CLEAN I P 0.50 I CLEAN 1 P 10:00 - 12:30 2.50 CLEAN P 12:30 - 14:30 2.00 CLEAN P 14:30 - 16:30 2.00 CLEAN P 16:30 - 22:00 22:00 - 23:30 23:30 - 00:00 9/5/2007 00:00 - 01:00 01:00 - 06:30 5.50 CLEAN ~ P 1.50 CLEAN ~ P 0.50 I CLEAN I P 1.001 CLEAN i P 5.501 CLEAN j P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Page 4 of 1 1 Spud Date: End: 9/13/2007 Description of Operations Establish SPR. RIH and tag Tubing Stump at 9286'. Mill on Tubing at 40 RPM with 1,000 Ib WOB and 5000 ft-Ibs Torque. Losses at 10 BPM while Milling. Continue Milling lightly on Tubing while mixing Lubricity Pill. Pump Lubricity Pill. Torque decreased to 5000 ft-Ibs with 5000-8000 Ibs WOB at 40 RPM. Continue milling through Tubing Stub and through Packer to 9293'. At 9293', Top Drive stalled out due to torque increase and lossed 100% returns. Pulled up to monitor well. Increased Pump Rate to 6 BPM with 3100 psi. No Returns. Turned on hole fill and was able to fill hole. Slow Pump Rate down to 2 BPM with 1175 psi. Attempt to continue milling. Could not pull free from Packer. Attempt to work free from Packer with several attempts at Jarring and up to 115,000 Ibs overpull. Work torque down to Packer where Mill came free. Continue milling on Packer. Losses at 215 BPH with 9.8 ppg Brine. Waiting on new 8.5 ppg Seawater to decrease fluid losses to the Ivishak. Came free of the packer at 0630-hours. Fluid losses decrease to 30-40-BPH with 8.5-ppg seawater. Continue to mill and packer drops free at 0900-hours. Circulate bottoms up, 5-BPM at 3,750-psi, to release any trapped gas. Do not see any gas in returns. P/U 4-joints 2-7/8" HT PAC and push packer remains to TOL. Packer stacks out at 9,392' with tailpipe at 9,440'. TOL on wellbore schematic is 9,45i'. Well appears to be flowing a slight amount with 8.7-ppg all the way around. Call engineer and discuss and decide to go back to 9.8-ppg brine to keep the Cretaceous held back. Verified the TOL 2 more times and packer stays in that spot. Ordered two truckloads of 9.8-ppg brine. Pump 20-Bbls 9.8-ppg Hi-Vis sweep, 4-BPM 2,960-psi, saw some gas and oil across the shakers, but as long as we keep pumping the gain is less than a few gallons per 10-minutes. S/D pump and well still wants to give up 2-3 gallons per minute. Called engineer and receiviced go-ahead to pump 9.8-ppg brine. PJSM to circulate 9.8-ppg brine. Displace well back to 9.8-ppg NaCI Brine at 4 BPM with 2800 to 3000 psi. R/D circulating equipment and monitor well. POOH standing back 2-7/8" HT PAC drill pipe in derrick. POOH with BHA #1. UD (15) 2-7/8" HT PAC drill collars, jars, subs, boot baskets, and packer mill. Packer mill showed signs of wear, but in good condition. Boot baskets recovered 1.5 gallons of metal shavings. P/U BHA #2 consisting of Itco spear and extension, bumper sub, oil jars, x/o, (9) 2-7/8" HT PAC drill collars, x/o, jar intensifier, pump out sub, and x/o to HT PAC drill pipe. Total length of BHA #2- 305.20' P/U BHA #2 consisting of Itco spear and extension, bumper sub, oii jars, x/o, (9) 2-718" PAC-HT drill collars, xio, jar intensifier, pump out sub, and x/o to PAC-HT drill pipe. Total Length of BHA #2- 305.20' PJSM. RIH with spear assembly (BHA #2) on 2-7/8" HT-PAC Printed: 10/3/2007 2:21:27 PM • BP EXPLORATION Page 5 of 11 Operations Summary Report Legal Well Name: 05-40 Common Well Name: 05-40 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 16 Date From - To ' Hours Task Code '' 9/5/2007 01:00 - 06:30 ~ 5.501 CLEAN P 06:30 - 07:00 I 0.501 GLEAN I P 9!6/2007 07:00 - 07:30 ~ 0.50 (GLEAN ~ P 07:30 - 08:00 I 0.501 CLEAN I P 08:00 - 09:30 1.50 CLEAN P 09:30 - 14:00 4.50 CLEAN P 14:00 - 15:00 1.00 CLEAN P 15:00 - 17:30 2.50 CLEAN N 17:30 - 19:00 I 1.501 CLEAN I N 19:00 - 00:00 5.00 CLEAN N 00:00 - 01:00 1.00 CLEAN N 01:00 - 02:00 I 1.001 CLEAN I N 02:00 - 03:00 ( 1.00 (CLEAN ( N 03:00 - 07:00 I 4.001 CLEAN N Spud Date: Start: 8/30/2007 End: 9/13/2007 Rig Release: 9/13/2007 Rig Number: NPT '' Phase Description of Operations _.. - DECOMP i drill pipe from derrick. Hold BOP drill while RIH due to new operations (Belly Board). After dri11, held safety meeting with rig crew on shut-in procedures while tripping with Belly Board. Discuss new operations and positions while tripping with Belly Board after crew had run 12 stands in hole to clear communication between floor hands and derrick personnel. ;Continue RIH w/ 94 stands of 2-7/8" PAC-HT DP from Derrick. DECOMP PfU 4 Joints of 2-718" PAC-HT DP from Pipe Shed and RIH. P/U 1 Joint of 4" HT38 DP for Kelly Joint w/ 2-7/8" PAC-HT x HT38 XO. Fluid Losses Minimal --2 bph. ~ DECOMP 'Take Initial Parameters; Up Wt = 155,000 Ibs Dw Wt = 105,000 lbs. Circulate at 1.4 BPM at 630 psi. S/O while ~ circulating and tag fish at 9392'. See pump pressure increase j to 760 psi. Shut down pumps and continue to stack off and stack weight. Stack 10,000 Ibs on fish at 9396'. P/U to 9267' w/ no over pull evident, no fluid losses observed. S/O again and tag fish at 9392'. Stack 10,000 Ibs on fish at 9396'. P/U off fish and observe slight bobble of over pull, less than 2000 lbs. No obvious fluid loss. DECOMP , Monitor W ell. Build Brine in Pits to 9.8 ppg, new load of brine i from M-I Plant at 9.6-9.7 ppg. DECOMP Circulate to ensure 9.8 ppg brine in and out. DECOMP i POOH with 2-7/8" PAC-HT and stand back in derrick. DECOMP L/D 3-1/8" PAC-HT DC's and BHA. DPRB DECOMP No Fish. Consult Town on options. Decide to do clean out ;inside 3-1/2" tbg and packer remains. Coordinate w/ Baker 'Thru Tubing Shop on Mill and Space Out Pup. Wait on Tools. DPRB DECOMP Gather BHA #3 (2.79" Junk Milling Assembly) to rig floor. M/U .Milting Assembly consisting of round nose junk mill, x/o, weight bar, x/o, (3) 3-3/4" boot baskets, bumper sub, oil jars, pump out sub, x/o, and (9) 2-7/8" HT-PAC drill collars. Total length of BHA #3- 311.32' DPRB DECOMP ~ RIH with 2-7/8" PAC-HT from derrick. DPRB DECOMP Continue RIH with 2-7/8" PAC-HT from derrick with 95 stands and one single. P/U 1 joint of 4" HT-38 drill pipe for kelly joint with 2-7/8" PAC-HT x HT-38 x/o. Fluid loss during trip @ 2 BPH. DPRB DECOMP Take Initial Parameters; Up Wt = 155,000 Ibs Dw Wt = 1105,000 Ibs Rt Wt = 120,000 Ibs at 20 RPM and 3,000 ft-Ibs torque. Establish SPM. Tag top of packer at 9392'. Circulating Pressure- 850 at 1.7 BPM. Stack 2000 Ibs on (packer then mill slipped inside. Continue milling to 9398'. Pull out of packer and run back through packer without rotation with 1000 Ibs drag while sliding through packer to 9398'. Pull out of ~ packer and run back through packer without rotation to 9398' without any indication of sliding into packer or drag while sliding through. Pull up to 9395' and start sweep. DPRB DECOMP Pump 20 BBL high viscosity sweep at 4 BPM with 3200 psi. Sweep brought back an increase of junk with fine metal cuttings. Monitor well and R/U to POOH. Fluid losses at 10 BPH while circulating. DPRB DECOMP POOH with 2-7/8" PAC-HT drill pipe and stand back in derrick. i Losses at 4 BPH while POOH. Printed: 10/3/2007 2:21:27 PM • • BP EXPLORATION Page 6 of 11 Operations Summary Report Legal Well Name: 05-40 Common Well Name: 05-40 Spud Date: Event Name: WORKOVER Start: 8/30/2007 End: 9/13/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 9/13/2007 Rig Name: DOYON 16 Rig Number: Date '~ From - To Hours Task ', Code NPT Phase Description of Operations -- -_ ' _ i__ _ - _ - - ~ __ 9/6/2007 07:00 - 08:00 j 1.00 ~ CLEAN N DPRB DECOMP i UD DC's and 2.79" Mill BHA. Small amount of wear on mill i i face and boot baskets contained about 3/4 gallon of metal I shavings mixed pipe dope and paraffin. 08:00 - 09:30 , 1.50 CLEAN N DPRB DECOMP M/U BHA #4 w/ ITCO Spear for 3-1/2" Tbg dressed with 3.001 nominal grapple, bumper sub, oil jars, x/o, (9) 3-1/8" drill collars, x/o, jar intensifier, pump out sub, x/o to 2-7/8" PAC-HT drill pipe. Total length of BHA #4- 305.20' 09:30 - 15:00 5.50 CLEAN N DPRB DECOMP RIH with BHA #4 on 2-7/8" PAC-HT DP from Derrick to 9335'. i 15:00 - 16:00 1.00. CLEAN N DPRB DECOMP PJSM, Slip and Cut 89 tt of 1-1/4" Drilling Line. ~ 16:00 - 19:30 3.50 ~ CLEAN N DPRB DECOMP P/U 1 joint of 2-7/8" PAC-HT drill pipe and RIH. P/U 1 joint 4" I HT-38 drill pipe for kelly joint. Take initial parameters; Up Wt = 155,000 Ibs, Dw Wt - 100,000 lbs. RIH and engage fish at 9392'. Pull on fish with 210,000 Ibs while jarring. Dead pull to I i 255,000 Ibs. S/O to 90,000 Ibs to cock jars and repeat I ~ ~ procedure. J_ar on fish for -57 cycles without make any ' progress. Release from fish and start POOH. 19:30 - 23:00 3.50: CLEAN N DPRB DECOMP POOH with 2-7/8 PAC-HT drill pipe and stand back in derrick. ' Losses at 2 BPH while POOH. 23:00 - 00:00 1.00 CLEAN N DPRB DECOMP POOH w/ BHA #4. UD (9) 3-1/8" drill collars, jars, bumper sub, subs, and spear. 9/7/2007 i 00:00 - 02:00 2.00 CLEAN N DPRB DECOMP P/U BHA #5 (PKR Mill Assembly). PKR mill, x/o, (3) 3-3/4" i boot baskets, bit sub, bumper sub, oil jars, pump out sub, x.o, (15) 3-118" PAC-HT drill collars. Change out jars and bumper sub. ' Total length of BHA- 491.90' 02:00 - 07:00 I 5.00 CLEAN N DPRB DECOMP RIH with junk mill assemby on 2-7/8" PAC-HT drill pipe from derrick to 9363'. Break circulation @ 3500' and 6750'. 07:00 - 07:30 0.50 CLEAN N DPRB DECOMP Take Initial Parameter - Up Wt= 157,000 Ibs; Dw Wt=102,000 Ibs; Rot Wt = 125,000 Ibs at 40 rpms and 3500 ft-Ibs free torque. Pump Rate = 1.0 bpm @ 550 psi. 07:30 - 10:00 2.50 CLEAN N DPRB DECOMP S/O and Tag Top of Packer at 9392'. Mill at 70 rpms w/ 5K torque, 5K to 10K WOB. Pumping at 1.0 bpm. Milled off - 2 ft from top of fish. Lost circulation briefly after milling off. After milling 2 ft unable make more footage, torque smoothed out and returns stayed constant. Varied paramters to try and make footage. Believe fish is spinning. Consult Town. 10:00 - 11:00 1.00 CLEAN N DPRB DECOMP Circulate 20 bbl High Visc Sweep from Surface to Surface at 4 ~ bpm and 2960 psi. Metal Shaving seen with sweep on shaker screens. Magnets in possum belly collected most of the cuttings pulled about 1.5 gallons of material from them during circulation. 11:00 - 15:00 4.00 ~ CLEAN N DPRB DECOMP Pump dry job, POOH and Stand Back 2-7/8" PAC-HT DP in Derrick. 15:00 - 16:00 1.00 CLEAN N DPRB DECOMP POOH and UD DC's and SHA. Mill Showed wear on the blades but overall in good shape. Boot Baskets full of metal shavings. Retrieved -2 gallons of shavings from Boot Baskets. 16:00 - 16:30 0.50 CLEAN N DPRB DECOMP Clear and clean rig floor. Bring up tools and equipment for BHA #6. i 16:30 - 17:30 1.00, CLEAN N DPRB DECOMP P/U BHA #6 (Spear Assembly) consisting of 3-1/2" ITCO spear, (2) spear extensions, bumper sub, oil jars, x/o, (9) 3-1/8" j drill collars, x/o, jar intensifiers, pump out sub, x/o to 2-7/8" Printed: 10/3/2007 2:21:27 PM • BP EXPLORATION ..Operations Summary Report Page 7 of 1 1 Legal Well Name: 05-40 Common Well Name: 05-40 Spud Date: Event Name: WORKOVER Start: 8/30/2007 End: 9/13/2007 Contractor Name: DOYON DRILLI NG INC. Rig Release: 9/13/2007 Rig Name: DOYON 16 Rig Number: Date ,From - To ~ Hours ! Task '' Code' NPT Phase I Description of Operations 9/7/2007 ~ 16:30 - 17:30 1.00 CLEAN N DPRB DECOMP PAC-HT drill pipe. 17:30 - 22:00 i 4.50;. CLEAN ~ N DPRB DECOMP RIH w/ BHA #6 on 2-7/8" PAC-HT drill pipe from derrick. Break ~~ circulation at 4200'. RIH w/ 95 stands and 1 joint 2-7/8" drill i, pipe to 9368'. P/U (1) joint 4" HT-38 drill pipe for kelly joint and M/U in string. 22:00 - 00:00 1 2.001 CLEAN P DECOMP Establish fishing parameters; Up Wt- 150,000 Ibs; Dn Wt- I I 102,000 Ibs; Establish SPR; Pump at 1.25 BPM with 640 psi. Engage fish at 9394' and continue to S/O to 9398', pump pressure increase to 930 psi. Shut down pumping and pull to i 210,000 Ibs. Set jars off and increase dead puN to 255,000 and ', ~ 275,000 lbs. Fish came free after 16 hits with jars. Static I losses increased from 2 to 225 BPH. Drop ball to open pump 1 out sub without success. 19/8/2007 00:00 - 00:30 ~~, 0.50 CLEAN P DECOMP POOH. Stand back 3 stands of 2-7/8" PAC-HT drill pipe. Hole fill able to keep up with loss rate as POOH. Losses 225 BPH. 00:30 - 01:00 I 0.501 CLEAN P DECOMP R/U and attempt to shear pump out sub without success. 01:00 - 05:00 I 4.00!, CLEAN P DECOMP Continue POOH standing back 2-7/8" PAC-HT drill pipe in ' derrick. Fluid losses decreased from 225 BPH to 105 BPH ' ~ ', while POOH. 05:00 - 06:30 ', 1.501 CLEAN P DECOMP POOH w/ BHA #6. L/D drill collars, subs, and jars. Recovered ', I 43.23' of fish recovered. Top 10 ft of 3-1/2" tbg recovered was filled with mud and junk, whole fish had slight bend to it. 06:30 - 07:00 ! 0.501 CLEAN P DECOMP Clean and Clear Rig Floor. Losses Stabilizing at -90 bbl / hr. 07:00 - 08:00 1.001 CLEAN P DECOMP PJSM; N/D Riser and N/U Shooting Flange 08:00 - 10:00 1 2.00!; CLEAN P DECOMP PJSM; R/U E-Line Lub Ext, Pump-In Sub, BOP's, Lubricator 1 i and Grease Head. 10:00 - 12:30 ~; 2.501 CLEAN P DECOMP M!U 2.75" Gauge Ring Junk Basket and CCL. Press Test to i 1500 psi. RIH and Gauge 3-1/2" tbg to 9580'. 12:30 - 13:30 1.00 j CLEAN P DECOMP PJSM on Firing Head. R/D Gauge Ring Junk Basket. M/U ' Secure Firing Head, Setting Tool and HES Fas Drill Piug for 3-1/2" Tbg, 2.68" OD, Plug Length -2 foot. 13:30 - 14:30 1.00! CLEAN P DECOMP RIH with Fas Drill Plug to 3-1/2" Liner Top at 9451'. 14:30 - 15:00 0.501 CLEAN P 15:00 - 15:30 ' 0.501 CLEAN P 15:30 - 17:00 1.50 ~ CLEAN P 17:00 - 18:00 1.00 CLEAN P 18:00 - 19:00 1.00 CLEAN P 19:00 - 23:00 4.00; CLEAN P DECOMP Tie into Gauge Ring run. Set top of HES Fas Drill Piug in, 3-1/2" Tbg @ 9495'. See significant weight loss upon setting. S/O on plug to confirm set. Full returns seen quickly after setting plug. Monitor Well for 10 mins while filling hole with hole fill pump w/ no losses. DECOMP POOH w/ E-Line. DECOMP B/O and L/D Setting Tools. R/D E-Line Lubricator, Grease Head, BOP's, Pump In Sub, and Lub Extension. DECOMP R/D Shooting Flange and R/U Riser. DECOMP Pull Wear Ring and install Test Plug. DECOMP Test BOPE to 250 psi low pressure and 3,500 psi high pressure. Each test was held for 5 minutes. Test was witnessed by AOGCC inspector Chuck Sheve, Doyon Toolpusher, and BPX WSL. Test 1-Annular Preventer, Manual Kill, Manual Choke, and Upper IBOP Test 2- HCR Kill, HCR Choke, and Lower IBOP Test 3- Choke Valves 1, 12, 13, and 14 Test 4- Pipe Rams w/ 3-1/2" Test Joint ;Test 5- Choke Valves 9, 11, and Blind Rams Printed: 10/3/2007 2:21:27 PM • ~ BP EXPLORATION Operations Summary Report Legal Well Name: 05-40 Common Well Name: 05-40 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - Ta I Hours Task ~ Code', NPT 9/8/2007 19:00 - 23:00 4.00 CLEAN P 9/9/2007 j 02:30 - 07:30 i 5.00 ~ CLEAN P 07:30 - 08:30 j 1.00! CLEAN P 08:30 - 09:30 I 1.00 ~ CLEAN ' P 09:30 - 14:30 5.00 CLEAN P 14:30 - 16:00 ~ 1.50, CLEAN i P 16:00 - 16:30 0.50 CLEAN P 16:30 - 20:00 ~ 3.50, CLEAN ~ P 20:00 - 20:30 0.50 i CLEAN ~ P 20:30 - 23:00 2.50 CLEAN P 23:00 - 00:00 i 1.00 CLEAN P 9/10/2007 00:00 - 01:30 1.50 CLEAN P I I 01:30 - 02:00 0.501 I I CLEAN P 02:00 - 03:00 1.00 CLEAN P 03:00 - 09:00 6.00 ~ CLEAN P ~ 23:00 - 00:00 I I 1.001, CLEAN P I 00:00 - 01:00 1.00 CLEAN P 01:00 - 02:30 1.50 i CLEAN P 09:00 - 10:30 I 1.50 CASE I P Page 8 of 1 1 Spud Date: Start: 8/30/2007 End: 9/13/2007 Rig Release: 9/13/2007 Rig Number: Phase Description of Operations DECOMP Test 6- Choke Valves 5, 8, 10, and TIW Valve Test 7- Choke Valves 4, 6, 7, and Dart Valve Test 8- Choke Valve 2 Test 9- Choke Valve 3 Test 10- Pipe Rams w/ 2-7/8" Tesi Joint Accumulater test- 3,000 psi Starting Pressure. 1,800 psi after actuation. First 200 psi recovery in 16 seconds. Full recovery in 1 minute and 16 seconds. 5 Nitorgen Bottles at 2,100 psi. DECOMP R1D floor and test equipment. Puil test joint and set W ear Ring. DECOMP R/U rig floor to RIH. Gather up Baker polish mill assembly. DECOMP P/U BHA #7 consisting of polish mill, bit sub, liner dress mill, x/o, 5-1/2" scraper, x/o, (3) 3-3/4" boot baskets, bit sub, bumper sub, oil jars, pump out sub, x/o, (9) 3-1/8" dritl collars. Total length of BHA #7- 319.58' DECOMP RIH wi BHA #7 on 2-7/8" PAC-HT dritl pipe from derrick. DECOMP M/U 4" HT38 Kelly Joint and Take Initial Paramters. Up Wt = 155,000 Ibs; Dw Wt = 100,000 Ibs; Rot Wt = 125,000 lbs. Rotate at 40 rpm's and 4500 ft-Ibs of torque. Pump Rate 2.5 bpm at 1450 psi. Tag Top of Liner at 9440' and Dress Top of Liner. DECOMP Circ 20 bbl High Visc Sweep at 4 bpm and 3100 psi. DECOMP VD Kelly Joint and POOH -Stand Back 2-7/8 PAC-HT DP. DECOMP UD Polish Mill BHA. Top of mill showed good marks on tattle tail. Junk baskets contained 2 pieces of metal that looked like slip parts from packer. DECOMP Clean and CLear Rig Floor. DECOMP P/U HES RTTS for 5-1/2" Casing and RIH w/ 47 stand of 2-7/8" DP from Derrick to 4500'. DECOMP C/O 2-7/8" elevators and P/U 4' HT38 kelly joint. Establish parameters; Up Wt- 82,000 Ibs; Dw Wt- 75,000 Ibs. Set RTTS @ 4500'. R/U to test casing. DECOMP Attempt to test casing to 3500 psi. No test. Trouble shoot for leak. C/O 4" Demco valve on mud pump #1. Test casing to 3500 si and hold for 30 charted minutes. Good test. R/D casing test equipment. DECOMP R!U and establish LLR at 2 BPM with 1100 psi. DECOMP Continue RIH w/ 2-7/8" PAC-HT drill pipe from derrick to 7000'. DECOMP C/O elevators, and P/U 4" HT38 kelly joint. Establish parameters; Up Wt- 115,000 Ibs; Dw Wt- 90,000 Ibs. Set RTTS @ 7000'. R/U to test casing and liner top. DECOMP Pressure test casing below RTTS and liner top to 3500 psi for c ante minutes. Good test. R/D testing equipment. DECOMP POOH standing back 23 stands of 2-7/8" PAC-HT drill pipe. 45 Stands total racked back in derrick for liner job. Continue POOH, L/D the rest of the string of drill pipe. TIE61 Rig up for running 3-1/2" 9.2# 13Cr80 Vam Top Tubing. M/U 3-1/2" VamTOP XO to Safety Valve, R/U Compensator, Insert dies for 3-1/2" Chrome Tbg, R/U Torque Turn, Orginize and inspect tubulars in pipe shed one last time. 10:30 - 15:00 ( 4.50 j CASE I N ~ HMAN ~ TIEB1 Float Collar Assembly and Hanger /Liner Top Packer Printed: 10!3/2007 2:21:27 PM • • BP EXPLORATION Page 9 of 11 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 9(10/2007 ~ 10:30 - 15:00 15:00 - 00:00 9/11/2007 100:00 - 00:30 00:30 - 01:30 01:30 - 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 07:30 07:30 - 08:00 08:00 - 08:30 08:30 - 09:30 05-40 05-40 WORKOVER Start: 8/30(2007 DOYON DRILLING INC. Rig Release: 9/13/2007 DOYON 16 Rig Number: Hours ' Task Code NPT Phase ---r ~ 4.50 CASE ~ N ICI HMAN ' TIEB1 I 9.00 CASE P ~ TIEB1 0.50 CASE P 1.00 CASE P 1.00 CASE P 0.50 CASE P 1.00 CASE P 3.50 CASE P 0.50 CASE P 0.50 CASE P 1.00 CASE P 09:30 - 10:00 0.50 CASE P 10:00 - 11:00 1.00 CEMT P 11:00 - 11:30 0.50 i CEMT P 11:30 - 12:00 I 0.50 CASE P 12:00 - 12:30 12:30 - 14:00 0.501 CASE I P 1.50; CASE P 'I TIE61 TIEB1 TIEB1 TIE61 TIE61 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIE61 TIEBi TIE61 TIEB1 TIEB1 Spud Date: End: 9!13!2007 Description of Operations Assembly sent back to Baker's Shop for modification. No weep hole drilled in Float Collar. PJSM with Rig Crew, Baker Completions, and Doyon Casing on running liner. RIH w! Ported Seal Stem, Float Collar Assembly, Landing Collar assembly, 168 joints of 3-1/2", 9.2 #, 13Cr80 Vam Top, Baker HMC Liner Hanger and ZXP Liner Top Packer. Continue RIH w/ 168 joints of 3-1/2" 9.2#, 13CR, Vam Top . R/D Torque Turn equipment. R/U to P/U and RIH 2-7/8 PAC-HT drill collars. Check and prep Baker HMC Liner Hanger and ZXP Liner Top Packer. RIH on 3 joints of 2-7/8 PAC-HT drill collars. RJU and circulate one liner volume at 3 BPM and 560 psi. Continue RIH, P/U another 21 JTs of PAC-HT drill collars. Continue RIH w/ 3-1/2" liner and drill collars with 34 stands of 2-7l8" PAG-HT drill pipe from derrick. M/U and Torque cmt head as per Baker and UD on Skate P/U and RIH w/ Stand #35. P/U Wt = 138,000 Ibs S/O Wt = 107,000 lbs. M/U CMT Head and Lines. S/O and Tag TOL at 9440'. No-Go at 9445'. P/U above Liner and Repeat to confirm tag, stack an additional 10,000 Ibs to confirm down. Pressure up to 500 psi and hold for 10 mins. P/U to UP Wt plus and additional 2 ft to expose cmt ports. Establish Circulation at 1 bpm - 280 psi, 1.5 bpm = 500 psi, 2 bpm = 750 psi, 2.5 bpm = 1100 psi, 3.0 bpm = 1500 psi. Circulate - 50 bbls of 9.8 ppg brine. PJSM w/ Dowell and Vac Truck Drivers. Continue to Circ at 2 bpm and 750 psi while Dowell Batch mixes cmt. Cement at 15.8 ppg at 10:35 hrs -estimated pump time 4.5 hrs. PT w/ Dowell to 5000 psi. Bleed off pressure and open up to well. Bring on 15.8 ppg Class G Cmt w/ Gas Block additive at 3 bpm . Initial rate of 3 bpm at 1580 psi. Pump 82 bbls total, final rate and pressure at 3 bpm and 1320 psi. Stop pumps and Kick Out DP Wiper Plug from Cement Head. Positive indication plug left Cmt Head. Pump 5 bbls with Dowell and then swap to rig pumps. Come on line at 3.0 bpm and 1100 psi. Able to maintain 3 bpm for first 35 bbls -limit pressure to 2100 psi due to hanger. Did not see plug latch up on liner wiper plug. Continue pumping, adjusting pump pressure to obtain max rate under 2100 psi. Bump Plug at 0.7 bpm with 2070 psi - 59 bbls of displacement. Lost -10 bbl while displacing cmt. CIP @ 1153 hrs. S/O to No-Go Mark w/ 10,000 Ibs down. Bleed Down Pressure - Floats and Seals Holding. S/O another 5,000 Ibs to confirm all the way down. P/U to Neutral Wt and Pressure Up with Dowell to 4500 psi to set hanger. Positive indication hanger set. S/O another 15,000 Ibs on hanger. Bleed Down pressure to 3500 psi and hold for 15 mins. Bleed Down Pressure and Release Dowell. Come on Line with Rig Pump and Pressure Up to 500 psi. P/U till pressure bleeds down and then come on with pumps at 2.5 Printed: 10!3/2007 2.21:27 PM • • BP EXPLORATION Page 10 of 11 Operations Summary Report Legal Well Name: 05-40 Common Well Name: 05-40 Spud Date: Event Name: WORKOVER Start: 8/30/2007 End: 9/13/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 9/13/2007 Rig Name: DOYON 16 Rig Number: Date 'From - To Task 'I Code NPT Phase Description of Operations 'Hours 9/11/2007 ~ 12:30 - 14:00 1.50 CASE P ~' TI E61 '~ bpm and 1050 psi. Circ 10 bbls to get cement up hole. Shut Down Pump and set down 30,000 Ibs to set liner top packer. PiU and Repeat 2 x. P/U and Roate down at 10 rpm's and 2000 ft-Ibs torque. P/U and Repeat 2 x. Liner Top Packer Set. ~ Bring on rig pumps again and pump 40 bbl High Visc Biozan 'sweep. Chase out of hole at 6.5 bpm. Positive indication of I ~ cement in returns. 14:00 - 14:30 0.50 CASE P j TIEB1 j B/O UD Cement Head, and Circulating Equipment, UD 3 jts of 2 7/8" Drill Pipe. 14:30 - 15:30 1.00 CASE P ~~ TIEB1 ', R!U Circulating Equipment and Pump 20 bbl Hi-Vis Sweep ' Displaced Well Bore to Clean Sea Water. 15:30 - 21:00 5.50 CASE P I TIE61 POOH and UD Drili Pipe, Drill Collars and Liner Running Tool. 21:00 - 22:00 1.00 CASE P ! TIEB1 P/U Cement Head and make remaining breaks on tool. Pull C Wear Ring. 22:00 - 00:00 2.00 CASE P TIEB1 Pull and Install new FMC 7" Pack Off, Tested to 3,500 psi for 30 minutes. 9/12/2007 00:00 - 01:00 1.00 BUNCO I RUNCMP R/U and Pressure Test Casing to 2,500 psi for 15 minutes. ' Tested OK. 01:00 - 02:00 1.00 BUNCO P ~! RUNCMP R/U Tubing Elevators, Long Bails, Compensator, Torque Turn I Equipment. 02:00 - 09:30 7.50 BUNCO P RUNCMP ~ PJSM with Baker rep, Casing rep, Rig Crews on Running Completion. Run 3.5" 9.2#, 13CR-80, Vam Top Tubing from '~, 152.39'. Use Jet Lube Seal Guard Pipe Dope. Average M/U ; Torque 2,900 fUlbs. Ran a total of 123 Jts of 3.5", 9.2#, I 13Cr80, VamTop Tbg, (1) 3.5" WLEG, (1) 3.5" X Nipple w/ RHC, Baker 5.5" x 3.5" SABL-3, 9Cr Packer, (1) X Nipple and I (1) GLM. 09:30 - 10:30 1.00 BUNCO P I RUNCMP Tag top of the Liner Top Packer 2T in on Joint #125 (4,083'). Confirm tag depth twice and set 10K down. Establish UW = 69K , DW = 66K. LD (3) Jts of Tubing. Space out 3' above tag depth with space out pups: 9.84', 9.83' and 7.85'. PU Joint j #123 and MU to the Tubing Pup Jts. 10:30 - 11:00 0.50 BUNCO P RUNCMP RD Compensator and Torque Turn Equipment with Doyon Casing Rep. 11:00 - 12:00 1.00 BUNCO P RUNCMP PU and MU Hanger Assembly with FMC rep. MU Headpin to the Hanger in preparation for reversing in with packer fluid. Check the unused ports (2) on the Hanger and they are plugged off. 12:00 - 13:30 1.50 BUNCO P RUNCMP , PJSM with WSL, Toolpusher, Doyon Crew, MI Engineer, FMC ~ rep and Vac Truck drivers. Reverse circulate 45 bbls of 140 degree seawater followed by 50 bbls of 140 degree inhibited i seawater at 3 bpm / 325 psi. 13:30 - 14:00 0.50 BUNCO P ' RUNCMP , Land the Tubing Hanger with FMC rep. Drop the Ball and Rod. ~~ RILDS with FMC rep. 14:00 - 14:30 0.50 BUNCO P ,RUNCMP ' RU Test Equipment. 14:30 - 16:00 1.50 BUNCO P RUNCMP Set the Baker SABL-3 Production Packer by pressuring up on the Tubing to 4,500 psi for 5 mins. Bleed the pressure to 3.50C si and test the Tubin for 30 charted mins - OK. Bleed the ~ Tubing to 1,550 psi. Pressure up on the IA to 3,500 psi and I ; test the IA for 30 charted mins - OK. Bleed the ubtng own ~ ~ ' and observe the DCR Shear Valve shear at 00 psi on the I Tubing (2,600 psi differential). Pump down the IA at 2 bpm / Printed: 10/3/2007 2:21:27 PM • BP EXPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: 05-40 Common Well Name: 05-40 Spud Date: Event Name: WORKOVER Start: 8/30/2007 End: 9/13/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 9!13/2007 Rig Name: DOYON 16 Rig Number: Date . From - To Hours Task ~~ Code, NPT ' Phase Description of Operations 9/12/2007 14:30 - 16:00 1.50 BUNCO P RUNCMP ~ 120 psi and down the Tubing at 2 bpm / 800 psi to confirm the j shearing of the valve. 16:00 - 17:30 1.50 WHSUR P RUNCMP ~ Set TWC with FMC rep. Test from above and below to 1,000 `psi for 10 charted mins - OK. 17:30 - 19:30 2.00 BOPSU P RUNCMP B/D Lines, Suck out BOP Stack, ND BOPE and Spacer Spool. 19:30 - 21:00 1.50 WHSUR P RUNCMP Prepare Well Head, Install Adapter Flange and test to 5,000 psi for 30 minutes. 21:00 - 23:00 2.00 WHSUR P RUNCMP ;Install Production Tree, and test same to 5,000 psi, Remove ~ I Belly Board from derrick. 23:00 - 00:00 1.00 WHSUR P RUNCMP ; R/U DSM Lubricator and test to 500 psi, Pull TWC and R/D Lubricator. 9/13/2007 00:00 - 00:30 0.50 WHSUR P RUNCMP Continue to RID DSM Lubricator. 00:30 - 01:30 1.00 WHSUR P RUNCMP R/U Little Red and Pressure Test lines to 3,200 psi, Reverse in 40 bbl Diesel at 2.5 bpm w/1700 psi. ~ 01:30 - 02:30 1.00 WHSUR P ; RUNCMP R/U Lines and U-Tube Well Bore. 1 02:30 - 03:00 0.50 WHSUR P RUNCMP Drain Lines Prepare to install BPV. 1 03:00 - 04:30 1.50 WHSUR P , RUNCMP Waiting on DSM to install BPV, R/D Rig Floor, Prepare to Move I Rig. 04:30 - 05:00 0.50 WHSUR P RUNCMP Install BPV and Pressure Test to 1,000 psi. 05:00 - 06:00 1.00 WHSUR P RUNCMP I Remove Secondary Annulus Valve, Secure Well. The Rig was released at 06:00 hrs on 9/13/2007. Printed: 10/3/2007 2:21:27 PM TREE ~ FMC GEN 5 WELLHEAD = CNV ACTUATOR = BAKER C KB. ELEV = 71.1' BF. ELEV = KOP = 1049' Max Angle = 87 @ 10314' Datum MD = 9833' Datum TVD = 8800' SS 05-40 Post RW O DRLG DRAFT 23' 76' 2119 121' 7" CSG 26#, L-80, ID = 6.276" ~ 76' 9-5/8" CSG, 40#, L-80, ID = 8.835" X12-1' 7-5/8" CSG, 29.7#. L-80, ID = 6.875" 1 sa i4-1/2" X 3-1 /2" XO 7" X 5-1/2" XO 3-1 /2" HES X NIP, ID = 9-5/8" X 7-5/8" XO GAS LIFT MANDRELS 4002' -j 3-1/2" HES X NIP, ID = 2.813" I 4035' S-1/2" x 3-1/2" BAKER SABL-3 Packer 4068' 3-1/2" HES X NIP, ID = 2.750" 5" x 5 5" Bkr ZXP Liner To 3 Packer 4074' 4078' 3-1/2" WLEG, ID = 2.920" . . p Liner Hanger (TOC) 4089' 3-1/2" CSG, 9.2#, 13Cr80, .0087 bpf, ID = 2.990 9440' ~ ^, p3,QQa ' II CJv TOC on top of Float Collar @ 9,389' TOP OF 3-1/2" LNR 9451' 13-1/2" HES FASDRILL PLUG 5-1 /2" CSG, 17#, NT-80, ID = 4.892" PERFORATION SUMMARY REF LOG: BRCS ON 11/15/96 A NGLE AT TOP PERF: 86 @ 10350' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10350 - 10430 C 11/22/96 2-7/8" 4 10446 - 10550 C 11/22/96 2-7/8" 4 10586 - 10616 C 11/22!96 2-7/8" 4 10650 - 10700 C 11/22/96 2-7/8" 4 10716 - 10754 C 11/22/96 2-7/8" 4 10770 - 10830 C 11 /22/96 DATE REV BY COMMENTS DATE REV BY COMMENTS 11/23/96 ORIGINAL COMPLETION 09!22/07 DAV/PJC GLV GO 08/14/01 RNIKAK CORRECTIONS 09/28/02 MWKAK GLV GO 06/12/03 CMO/TLP KB ELEVATION CORRECTION 09/23/05 KSB/TLH PXN TTP SET (10/14/02) 09/14/07 D16 RWO PBTD 3-1/2" LNR, 9.2#, L-80, .0087 bpf, ID = 2.992" I 10915' I PRUDHOE BAY UNfT WELL: 05-40 Permit No.: 1961730 API No: 50-029-22707-00 SEC 32, T11 N, R15E, 4968.14' FF3 8 162.79' FNL BP Exploration (Alaska) . ~1f~1fæ mJ~ ~~~~æ~ . A'I,ASBA OIL AlQ) GAS CONSBRVATlON COMMISSION SARAH PAUN, GOVERNOR 333 W 7th AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 \q/';_ ,"59 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05-40 Sundry Number: 307-225 5~ JUL 0 {; 2007 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this:2 day of July, 2007 Encl. (7'-J 7/.:1/7 ..t ~ CEIVED STATE OF ALASKA Cflt 1'.. ?..~¡1 RE·· . ALA Oil AND GAS CONSERVATION COMMISSION t'JUN 2 8 Z007 APPLICATION FOR SUNDRY APPROVAL ý.t~I"3>· . 20 MC 25.280 Alaska Oil & Gas Cons. Commission 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time ExtensionAnchorage o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 196-159 r 3. Address: D Service D Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22707-00-00 ' 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 05-40 ~ Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028328 71.1' -' Prudhoe Bay Field / Prudhoe Bay Pool . 12'<>/ / . « / I ....... ... ..... i/i' ....... . ·····,>iiy>..i·y. ... i ..... .... Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10987 (' 9058 f 10915 9051 9318 None Casino Lenoth Size MD TVD Burst CollaDse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3855' 9-518" x 7-5/8" 3890' 3646' 5750 3090 Intermediate 9589' 7" x 5-1/2" 9622' 8704' 7740 6280 Productinn Liner 1536' 3-1/2" 9451' - 10987' 8551' - 9058' 10160 10530 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 10350' - 10830' 8995' - 9043' 4-1/2", 12.6# x 3-1/2",9.3# L-80 9340' Packers and SSSV Type: 5-1/2" x 3-1/2" TIW 'HBBP-T' packer I Packers and SSSV MD (ft): 9294' 13. Attachments: 14. Well Class after proposed work: 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencina ODerations: August 1, 2007 181 Oil DGas D Plugged D Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan, 564-5254 Printed NamÇ)7d Reem Title Engineering Team Leader I Prepared By Name/Number: Signature ~ ¿'.AA.A Phone 564-5743 Date 6 _ ?tl.. ,,-, Terrie Hubble, 564-4628 Commission Use Onlv I Sundry Number: ~?- a.as Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance Other: 3SC(J ~..\ \šD '? ~ -\- Subsequent Form Required: 110 y APPROVED BY !/,..3,ð; Approved Bv: THE COMMISSION Date Form 10-403 Revised 06/2006 V ...// \.. -" Submit In Duplicate - 0DIGJNAt RSDMS 8Ft JUL 0 5 2007 L?M? . . G 5-40 Rig Workover Scope of Work: Pull 3-%" completion, mill and retrieve TIW HBBP-T packer, run and fully cement 3-%" scab liner from 4100' to 9451' MD, run 3-%" 13Cr80 monobore completion. MASP: 2400 psi Well Type: Producer Estimated Start Date: August 1, 2007 Pre-riCl prep work: Pre-ri re work: S 1 Drift thru 3-%" tub in for tubin cut. Run cali er 10 from -9300' to surface. E 2 Jet cut 3-%" L-80 tubing at 9292' MD, 2' above the TIW HBBP-T packer. Cut tubing as close to acker as ossible. Reference tubin tall dated 11-22-96. F 3 Circulate well with kill weight fluid for the cretaceous leak and diesel thru the cut. No pressure testin re uired on SC or PC. o 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka e check one at a time. PPPOT-T & IC. o 5 Set a BPV in the tubin han er. o 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE with 2-ya" x 5" VBR pipe rams. Pressure test to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 3- %" tubing string to the cut. 3. Mill and retrieve 5-%" TIW HBBP-T packer at 9294' MD. 4. Run and fully cement new 3-W' 9.2#/ft 13Cr80 scab liner from 4100' to 9451' MD. 5. Run 3-%" 13Cr-80 completion with Baker SABL-3 packer. Position packer at -4000' MD. 6. Displace the IA to packer fluid and set the packer. 7. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 8. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = FMC GEN 5 CrN BAKER C 71.1' 1049' S7 @ 10314' 9S33' SSOO' SS 4-1/2" TBG. 12.6#. L-SO, .0152 bpf, ID = 3.95S" I 7" CSG 26#, L-SO, ID = 6.276" I I 9-S/S" CSG, 40#, L-80, ID = S.835" I I 7-5/S" CSG. 29.7#, L-SO. ID = 6.S7S" I 3890' Minimum ID = 2.75" @ 9318' HES XN NIPPLE I 3-1/2" TBG, 9.3#, L-SO, .00S7 bpf, ID = 2.992" H 9340' DATE 11/23/96 OS/14/0 1 09/2S/02 06/12/03 09/23/05 TOPOF 3-1/2" LNR I I 5-1/2" CSG, 17#, NT-SO, 10 = 4.S92" I ÆRFORATION SUMMARY REF LOG: BHCSON 11/1S/96 ANGLEATTOPÆRF: S6 @ 103S0' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-7/S" 4 10350 -10430 C 11/22/96 2-7/S" 4 10446 - 10S50 C 11/22/96 2-7/S" 4 10586 -10616 C 11/22/96 2-7/S" 4 10650-10700 C 11/22/96 2-7/S" 4 10716 -10754 C 11/22/96 2-7/8" 4 10770-10S30 C 11/22/96 PSTD I 13-1/2" LNR, 9.2#, L-80, .0087 bpf, 10 = 2.992" I REV BY COMMENTS ORIGINAL COMPLETION RNlKAK CORRECTIONS MHlKAK GLV C/O CMOfTLP KB ELEVATION CORRECTION KSB/TLH PXN TIP SET (10/14/02) DATE 05-40 SAÆTY NOTES: HORIZONTAL WELL. -14-1/2" X 3-1/2" XO I -17" X S-1/2" XOI -i 3-1/2" CAMCO BP61 SSSV NIP, 10 = 2.S12" TVO 3714 6309 8297 GAS LIFT MANDRELS OEV TYÆ VLV LATCH 27 BST-TRIM-V4 DMY T1-V3 32 BST-TRIM-V4 oMY T1-V3 21 BST-TRlM-V4 oMY T1-V3 PORT DATE o 09/2S/02 o 09/2S/02 o 09/28/02 9294' -i 5-1/2" x 3-1/2" TIW HBBP- T A<R, 10 = 2.94" -13-112" HES XN NIP, 10 = 2.75" I -13-1/2" PXN TIP (10/14/02) I -i 3-1/2" TUBING TAIL WLEG, 10 = 2.992"1 REV BY COMMENTS PRUDHOE BA Y UNIT WELL: "05-40 Permit No.: "1961730 API No: 50-029-22707-00 SEC 32, T11 N, R15E, 496S.14' FEL & 162.79' FNL BP Exploration (Alaska) FMC GEN 5 CrN BAKER C 71.1' 5-4fproposed Compltlon TREE = " WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 1049' 87 @ 10314' 9833' 8800' SS 4-1/2" TBG. 12.6#, L-80, .0152 bpf, 10 = 3.958" 1 7" CSG 26#, L-80, 10 = 6.276" I 9-5/8" CSG, 40#, L-80, 10 = 8.835" I 17-5/8" CSG, 29.7#. L-80. 10 = 6.875" ITOP OF 3-1/2" LNR I TOP OF CEMENT 13-1/2" CSG. 9.3#, 13Cr80, .0087 bpf, 1D=2.992~ 9451' TOPOF 3-1/2" LNR I 9451' 15-1/2" CSG, 17#. NT-80. 10 = 4.892" I 9622' ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/15/96 ANGLEATTOPÆRF: 86 @ 10350' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10350 - 10430 C 11/22/96 2-7/8" 4 10446 - 10550 C 11/22/96 2-7/8" 4 10586 -10616 C 11/22/96 2- 7/8" 4 10650 - 10700 C 11/22/96 2-7/8" 4 10716 -10754 C 11/22/96 2-7/8" 4 10770 - 10830 C 11/22/96 IPBTD I 13-1/2" LNR, 9.2#. L-80, .0087 bpf, 10 = 2.992" I DATE 11/23/96 08/14/01 09/28/02 06/12/03 09/23/05 REV BY COMMENTS ORIGINAL COM PLETION RNIKAK CORRECTIONS MH/KAK GLV CJO CMOITLP KB ELEVATION CORRECTION KSBITLH PXNTTPSET(10/14/02) DATE ., 9-5/8" X 7-5/8" XO GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 2 -i 3-1/2" HES X NIP I 4000' -15-1/2" x 3-1/2" BAKER SABL-3 PKR -13-1/2" HES X NIP I .,3-1/2" WLEG, 10 = 2.992" REV BY PRUDHOE BA Y UNrr WELL: "b5-40 Permit No.: 11"1961730 API No: 50-029-22707-00 SEC32, T11N, R15E, 4968.14' FEL & 162.79' FNL COMMENTS BP Exploration (Alaska) Alaska Department ofNatur.sources Land Administration system. Page I of2 State Cabins Natun L'CLJH6 -5#IAI~ ~/)¿ é)~ j'~~ Alaska DNR Case Summary f/d3/'fI/:::-O,;?7~b 51-1/1/ ~.tj: (/¿;¡7.Pð File Type: 1~'?~..w.wwJ File Number: Iw~~w~~~_w_J ~ Printable Case File ~ See Township, Range, Section and Acreage? {!; Yes No _..·.·....'"""1IIt·····.. ~w. End of Case Summary Last updated on 07/02/2007. http://www.dnr.state.ak.us/las/Case _Summary .cfm?FileType= ADL&FileNumber=28329&... 7/2/2007 Alaska Department of Natural Resources. Land Administration system. -5cc...3r;;2 eN £ /5 ~ Page 1 of2 State Cabins Natural Resources L..~.m.m..m.m Alaska DNR Case Summary File Type: ~ml:)~~j File Number: I..._~~~.~~...... .1 ~...PJintªÞIE!.çª$E!...Fi.IE!...$.IJ.mmªry See Township, Range, Section and Acreage? (!') Yes No _I!!III!!!, '" .:.....'.,_.,^. ::.....::.:,.'. '''''''''·':¡¡f-';-''':''~;'.·.:'.~ <c·o", , "m ;'Ù_y._' .. http://www.dnr.state.ak.us/las/Case_ Summary .cfm?FileType=ADL&FileNumber=28328&... 7/2/2007 07/19/06 --. f."" ;~: ./ SI:~IonI~erger NO. 3880 /CìCo-15~ Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Field: Prudhoe Bay Well Job# Loa DescriDtion Date BL Color CD 15-12A 11211420 I"~I ACK 06/25/06 1 17-08 11211509 INJECTION PROFILE 06/24/06 1 P2-11A 11221564 JEWELRY/STATIC SURVEY 04/27/06 1 13.-06A 11217266 INJECTION PROFILE 07/12/06 1 P2-01 11223106 STATIC PRESSURE/JEWELRY 03/25/06 1 L5-08 11217256 PROD PROFILE W/GHOST & DEFT 06/06/06 1 16-04A 11217245 PROD PROFILE W/DEFT 05/08/06 1 05-40 11223123 LDL 07/07/06 1 17-09 11211412 PROD PROFILE W/DEFT & GHOST 06/26/06 1 MPC-07 N/A SENSA/MEMORY GLS 04/22/06 1 04-18 1121584 USIT 06/27/06 1 (¡-51 11212873 USIT 06/28/06 1 04-31 11217264 US IT 07/07/06 1 D-14A 11217265 USIT 07/09/06 1 PSI-07 10703937 MDT 10/13/03 1 02-16B 11209601 MCNL 04/25/06 1 1 L2-18A 11217234 MCNL 04/06/06 1 1 L5-09 11212847 MCNL 04/25/06 1 1 Z-26A 11216205 MCNL 07/05/06 1 1 12-01 11072866 RST 07/06/05 1 1 E-17A 10928602 MCNL (Prints sent 1/24/05) 10/30/04 1 e ;:V e Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ;>-.., l1. , ~~ THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE , JANUARY 03,2001 ..., ". r 411 ': ~ ~ " ø' . . - .. - ' ,~~ .', .. " , ' , . .. .... ...¡ . ' . p w - - M IAL UNDER - - - - - - MAR K E R C:LORflMFILM.DOC PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 11/05/98 RUN RECVD 96-159 GCT-GPIT 96-159 BHP 96-159 PIL/SFL 96-159 CN/HEL/LDT 96-159 ~c/SL 96-159 CN 96-159 SST~-D 96-159 7561 96-159 MWD SRVY 96-159 7606 96-159 NGP-MD 96-159 NGP-TVD 96-159 7925 9621-10988 23-10940 ~9623-10980 9623-10940 ~9623-1o888 ~j~879O-lO91O ~/9623-10980 FIN~LL 01/10/97 FINAL 01/10/97 FINAL 01/10/97 FINAL 01/10/97 FINAL 01/10/97 FINAL 01/10/97 FINAL 01/10/97 ~CHLuM CNTG/GPIT/DITE/BHC/LDT 1 -~'SCHLUM DITE/BHC/LDT/CNTG/GPIT 1 ,~5904-10987 ,~425-9o2o ~SPERRY GR 01/10/97 02/05/97 01/24/97 FINAL 03/12/97 FINAL 03/12/97 4-12 04/02/97 10-407 . .~COMPLETZO~ DATE !//~/¢~/ DAILY WELL OPS R /0/1~/?~/ TO ]]/~/~/ Are dry ditch samples required? yes ~And received? Was the well cored? yes ~_. Analysis & description received? Are well tests required? yes ~..~Received? .,ye~s--~-----~ Well is in compliance /~ In~iti'al COMMENTS STATE OF ALASKA "- ALASK~ OIL AND GAS CONSERVATION CO~viMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-159 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519z6612 50-029-22707 4. Location of well at surface ~ ' ...... ='~:"'-:~'-'" ~ ~1~ 9. Unit or Lease Name 2321' NSL, 4109' WEL, SEC. 32, T11N, R15E ~7~_~¢i ~~ Prudhoe Bay Unit A t top of productive interval ~' ~~-~ !~ 10. Well Number 528' NSL, 838' WEL, SEC. 32, T11N, R15E i ~J~i-:~! !:.;; ~ 05-40 At total depth ........ ;;~ ~ 11. Field and Pool 162' SNL, 320' EWL, SEC. 4, T10N, R15E Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 71.10'I ADL 028328 12. Date Spudded10/15/96 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fish°re I 16' N°' °f C°mpleti°nsl 1/14/96 11/23/96 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 19. Directional Surveyl20. Depth where SSSV set,.1. Thickness of Permafrost 10987 9058 FTI 10915 9051 FT []Yes [] No I (Nipple) 484' MD! 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, USIT/CBL, GR, RES, LWD (DIP/FL), DITE, HLDT, CNL, Sonic, 23. CASING, LINER AND CEMENTING RECORD CASING SE'FI'lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTT'OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) 9-5/8"x7-5/8" 40# / 29.7# L-80 / S-95 35' 3890' 9-7/8" 2034 sx PF 'E', 229 sx'G', 732 sx PF 'E' Top Job 7"x5-1/2" 29#/17# L-80 33' 9622' 6-3/4' 1142 sx Class 'G' 3-1/2" 9.2# L-80 9451' 10987' 4-3/4" 1116 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom i25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4 spf 3-1/2", 9.3#, L-80 9340' 9294' MD TVD MD TVD 10350' - 10430' 10446' - 10550' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10586' - 10610' 10650' - 10700' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10716'- 10754' Freeze Protect with 50 Bbls of Diesel 10770' - 10830'u :iL iNAL 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) December 5, 1996 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing PressureCALCULATED I~ OIL-DEL GAS-MCF WATER-BBL O~L GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED FEB 1 1 1997 Alaska Oil & Gas Cons. Commicsior~ Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Marke:_ 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 9285' 8401' Shublik 9328' 8440' Top of Sadlerochit 9405' 8509' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that tbe"fore~going js,;,true and correct to the best of my knowledge Signed '/' / --~-~'~'?/'/' 7'/,///~/' DanStoltz /X_.~-~cE~,.___~-7~_.~'~-'~__ ~.~--'-~ -- Title Senior Drilling Engineer Date /~ ~ Prepared By Name/Number: Terrie Hu/~ble, ~64-4628 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: 05-40 Rig Name: Doyon 9 AFE: 4J0334 Accept Date: I 0/15/96 Spud Date: I 0/15/96 Release Date: I 1/23/96 Oct 16 1996 (1) Made up BHA no. 1 . Tested Divertor. Held safety meeting. Made up BHA no. 1 . Held safety meeting. Drilled to 150 ft. Pulled BHA. Made up BHA no. 2. Drilled to 550 ft. Held drill (Fire). Held safety meeting. Drilled to 917 ft. Oct 17 1996 (2) Drilled to 1290 ft. Held safety meeting. Drilled to 1883 ft. Held safety meeting. Drilled to 1914 ft. Circulated at 1914 ft. Jarred stuck pipe at 1464 ft. Pulled out of hole to 400 ft. Pulled BHA. Oct 18 1996 (3) Pulled BHA. Made up BHA no. 3. R.I.H. to 416 ft. Reamed to 520 ft. Held safety meeting. Singled in drill pipe to 1914 ft. Drilled to 2319 ft. Held safety meeting. Drilled to 2800 ft. Oct 19 1996 (4) Drilled to 2975 ft. Circulated at 2975 ft. Pulled out of hole to 2850 ft. Drilled to 3226 ft. Held safety meeting. Drilled to 3439 ft. Circulated at 3444 ft. Took MWD survey at 3444 ft. Drilled to 3910 ft. Circulated at 3910 ft. Held safety meeting. Pulled out of hole to 3300 ft. Pumped out of hole to 2300 ft. Oct 20 1996 (5) Pumped out of hole to 1931 ft. Pulled out of hole to 200 ft. Pulled BHA. Made up BHA no. 4. Held safety meeting. Reamed to 597 ft. R.I.H. to 1851 ft. Reamed to 2614 ft. Held safety meeting. Reamed to 3455 ft. Circulated at 3910 ft. Oct 21 1996 (6) Pulled out of hole to 3756 ft. Pumped out of hole to 1975 ft. Held safety meeting. Pumped out of hole to 1882 ft. Washed to 3487 ft. Held safety meeting. Reamed to 3910 ft. Circulated at 3910 ft. Pulled out of hole to 3760 ft. Pumped out of hole to 3700 ft. Operations Summary for: Oct 22 1996 (7) Pumped out of hole to 2300 ft. Pulled out of hole to 0 ft. Pulled BHA. Rigged up Casing handling equipment. Held safety meeting. Ran Casing to 3495 ft (7.625 in OD). Washed to 3567 ft. Held safety meeting. Washed to 3650 ft. Oct 23 1996 (8) Washed to 3889 ft. Circulated at 3889 ft. Held safety meeting. Circulated at 3889 ft. Mixed and pumped slurry - 472 bbl. Displaced slurry - 178 bbl. Cleared Circulating head. Laid down 900 ft of HWDP. Rigged down Divertor. Rigged up High pressure lines. Held safety meeting. Ran Tubing to 380 ft (1 in OD). Circulated at 380 ft. Ran Tubing to 760 ft (1 in OD). Oct 24 1996 (9) Ran Tubing to 800 ft (1 in OD). Circulated at 800 ft. Laid down 800 ft of Tubing. Ran electric logs. Held safety meeting. Ran electric logs. Rigged down Logging/braided cable equipment. Ran Tubing to 230 ft (1.25 in OD). Circulated at 230 ft. Circulated at 260 ft. Held safety meeting. Rig waited: Engineering facilities. Rig waited: Orders. Oct 25 1996 (10) Rig waited: Orders. Rigged up High pressure lines. Held safety meeting. Mixed and pumped slurry - 283 bbl. Rigged down High pressure lines. Laid down 260 ft of Tubing. Rigged up Well control. Rigged up Kelly. Held safety meeting. Rigged up Kelly. Tested Well control. Oct 26 1996 (11) Tested Well control. Repaired Well control. Held safety meeting. Repaired Well control. Tested Well control. Made up BHA no. 5. R.I.H. to 3779 ft. Circulated at 3801 ft. Tested Casing - Via annulus and string. Drilled installed equipment- Float collar. Circulated at 3930 ft. Performed formation integrity test. Drilled to 4000 ft. Oct 27 1996 (12) Drilled to 4380 ft. Held safety meeting. Drilled to 4910 ft. Circulated at 4910 ft. Pulled out of hole to 3850 ft. R.I.H. to 4910 ft. Drilled to 5003 ft. Held safety meeting. Drilled to 5350 ft. Oct 28 1996 (13) Drilled to 5717 ft. Held safety meeting. Drilled to 5905 ft. Circulated at 5905 ft. Pulled out of hole to 215 ft. Pulled BHA. Made up BHA no. 6 . R.I.H. to 3905 ft. Held drill (Spill). Held safety meeting. Serviced Brake. Pulled out of hole to 215 ft. Pulled BHA. Made up BHA no. 6. R.I.H. to 5905 ft. Drilled to 5976 ft. RECEIVED Page 2 FE,_, l ! 199/ Ai~ch0~a. ge Operations Summary for: 0,_ ,0 Oct 29 1996 (14) Drilled to 6265 ft. Held safety meeting. Drilled to 6633 ft. Functioned downhole tools at 6633 ft. Pulled out of hole to 1500 ft. Held safety meeting. Pulled out of hole to 1097 ft. Pulled BHA. Made up BHA no. 7 . R.I.H. to 3900 ft. Functioned downhole tools at 3900 ft. R.I.H. to 5906 ft. Functioned downhole tools at 5906 ft. R.I.H. to 6247 ft. Oct 30 1996 (15) R.I.H. to 6633 ft. Drilled to 6818 ft. Held safety meeting. Drilled to 7220 ft. Held safety meeting. Drilled to 7470 ft. Oct 31 1996 (16) Drilled to 7693 ft. Held safety meeting. Drilled to 8068 ft. Circulated at 8068 ft. Pulled out of hole to 5820 ft. R.I.H. to 8068 ft. Held safety meeting. Drilled to 8174 ft. Nov I 1996 (17) Drilled to 8295 ft. Circulated at 8295 ft. Pulled out of hole to 6178 ft. Held safety meeting. Pulled out of hole to 1097 ft. Pulled BHA. Made up BHA no. 8. R.I.H. to 8295 ft. Drilled to 8320 ft. Held safety meeting. Drilled to 8336 ft. Pulled out of hole to 4896 ft. R.I.H. to 8336 ft. Drilled to 8350 ft. Nov 2 1996 (18) Drilled to 8467 ft. Held safety meeting. Drilled to 8552 ft. Circulated at 8552 ft. Pulled out of hole to 1088 ft. Pulled BHA. Made up BHA no. 9. R.I.H. to 3905 ft. Held safety meeting. R.I.H. to 8552 ft. Drilled to 8692 ft. Nov 3 1996 (19) Drilled to 8756 ft. Pulled out of hole to 4531 ft. Held drill (H2S). Held safety meeting. R.I.H. to 8756 ft. Drilled to 8976 ft. Held safety meeting. Drilled to 9175 ft. Nov 4 1996 (20) Drilled to 9244 ft. Held safety meeting. Held drill (Spill). Drilled to 9575 ft. Held safety meeting. Drilled to 9640 ft. Circulated at 9640 ft. Pulled out of hole to 8000 ft. R.I.H. to 9640 ft. Circulated at 9640 ft. Nov 5 1996 (21) Circulated at 9640 ft. Pulled out of hole to 8600 ft. R.I.H. to 9526 ft. Pulled out of hole to 9121 ft. R.I.H. to 9444 ft. Held safety meeting. Held drill (Fire). Reamed to 9640 ft. Circulated at 9640 ft. Pulled out of hole to 1097 ft. Pulled BHA. Tested BOP stack. Rigged up Casing handling equipment. Held safety meeting. Ran Casing to 3930 ft (5.5 in OD). Page 3 Operations Summary for: (,. ,0 Nov 6 1996 (22) Ran Casing to 9621 ft (5.5 in OD). Circulated at 9621 ft. Mixed and pumped slurry - 29 bbl. Displaced slurry- 222 bbl. Tested Casing hanger. Tested BOP stack. Held safety meeting. Tested BOP stack. Serviced Block line. Laid down 4650 ft of Drillpipe. Nov 7 1996 (23) Laid down 4747 ft of Drillpipe. Made up BHA no. 10. Held safety meeting. Made up BHA no. 10. R.I.H. to 1000 ft. Rigged up Drillfloor / Derrick. R.I.H. to 6529 ft. Held safety meeting. R.I.H. to 9536 ft. Tested Casing - Via string. Drilled cement to 9550 ft. Nov 8 1996 (24) Drilled cement to 9640 ft. Drilled to 9660 ft. Circulated at 9660 ft. Pulled out of hole to 9660 ft. Held safety meeting. Pulled out of hole to 184 ft. Pulled BHA. Made up BHA no. 11 . R.I.H. to 1000 ft. Pulled out of hole to 184 ft. Pulled BHA. Made up BHA no. 11 . Made up BHA no. 12. R.I.H. to 2215 ft. Held safety meeting. R.I.H. to 9600 ft. Circulated at 9600 ft. Nov 9 1996 (25) Circulated at 9600 ft. Pulled out of hole to 32 ft. Held safety meeting. Pulled BHA. Made up BHA no. 13. R.I.H. to 9615 ft. Logged hole with LWD: DIR/FE from 9615 ft to 9660 ft. Drilled to 9676 ft. Held safety meeting. Drilled to 9762 ft. Nov 10 1996 (26) Drilled to 9794 ft. Held safety meeting. Drilled to 9818 ft. Circulated at 9818 ft. Pulled out of hole to 186 ft. Pulled BHA. Made up BHA no. 14. R.I.H. to 3840 ft. Held safety meeting. R.I.H. to 9818 ft. Drilled to 9825 ft. Nov 11 1996 (27) Drilled to 9917 ft. Held safety meeting. Held drill (H2S). Drilled to 10170 ft. Held safety meeting. Drilled to 10315 ft. Nov 12 1996 (28) Circulated at 10315 ft. Pulled out of hole to 2027 ft. Held safety meeting. Pulled out of hole to 183 ft. Pulled BHA. Made up BHA no. 15. R.I.H. to 10252 ft. Reamed to 10315 ft. Drilled to 10328 ft. Held safety meeting. Drilled¢~)~ ~4~-~ ~/~. ~ FEB i I i997 Alaska 0il & Gas Cons. commission Anchorage Page 4 Operations Summary for: Nov 13 1996 (29) Drilled Drilled hole to to 10580 ft. Held safety meeting. Drilled to 10651 ft. Circulated at 10651 ft. to 10666 ft. Pulled out of hole to 3200 ft. Held safety meeting. Pulled out of 183 ft. Pulled BHA. Tested BOP stack. Nov 14 1996 (30) Tested Well control. Installed Bore protector. Downloaded MWD tool. Made up BHA no. 16. Serviced Block line. Held safety meeting. R.I.H. to 4800 ft. Pulled out of hole to 4000 ft. R.I.H. to 9960 ft. Reamed to 10067 ft. Held safety meeting. R.I.H. to 10622 ft. Reamed to 10666 ft. Drilled to 10886 ft. Nov 15 1996 (31) Drilled to 10987 ft. Circulated at 10987 ft. Pulled out of hole to 10023 ft. R.I.H. to 10987 ft. Held safety meeting. Circulated at 10987 ft. Pulled out of hole to 9620 ft. Circulated at 9620 ft. Pulled out of hole to 553 ft. Pulled BHA. Rigged up Logging/braided cable equipment. Ran Drillpipe in stands to 2000 ft. Held safety meeting. Ran Drillpipe in stands to 8863 ft. Rigged up sub-surface equipment - Formation logs. Nov 16 1996 (32) Rigged up sub-surface equipment- Formation logs. Ran electric logs. Ran electric logs. Rigged down sub-surface equipment - Formation logs. Held safety meeting. Pulled Drillpipe in stands to 200 ft. Rigged down sub-surface equipment - Formation logs. Held safety meeting. Rigged up Casing handling equipment. Ran Casing to 1518 ft (3.5 in OD). Rigged up Tubing handling equipment. Held safety meeting. Ran Tubing to 1465 ft (2.0625 in OD). Rigged down Tubing handling equipment. Ran Drillpipe in stands to 2500 ft. Nov 17 1996 (33) Ran Drillpipe in stands to 9621 ft. Circulated at 9621 ft. Rigged up High pressure lines. Held safety meeting. Ran Drillpipe in stands to 9810 ft. Rigged down Circulating head. Pulled Drillpipe in stands to 1541 ft. Laid down 1465 ft of Tubing. Pulled Casing in stands to 0 ft. Rigged up Drillstring handling equipment. Made up BHA no. 17. Held safety meeting. R.I.H. to 9600 ft. Nov 18 1996 (34) Reamed to 9898 ft. Held safety meeting. Reamed to 10087 ft. Circulated at 10087 ft. Pulled out of hole to 500 ft. Held safety meeting. Pulled out of hole to 170 ft. Pulled BHA. Made up BHA no. 18. R.I.H. to 3200 ft. Serviced Block line. R.I.H. to 6000 ft. Page Operations Summary for: 0,. +0 Nov 19 1996 (35) R.I.H. to 10070ft. Washed to 10087 ft. Reamed to 10210 ft. Held safety meeting. Reamed to 10337 ft. Laid down 180 ft of 2.875 in OD drill pipe. Reamed to 10526 ft. Laid down 180 ft of 2.875 in OD drill pipe. Reamed to 10589 ft. Held safety meeting. Reamed to 10715 ft. Laid down 280 ft of 2.875 in OD drill pipe. Reamed to 10749 ft. Nov 20 1996 (36) Reamed to 10987 ft. Circulated at 10987 ft. Held safety meeting. Pulled out of hole to 160 ft. Pulled BHA. Rigged up Casing handling equipment. Held safety meeting. Ran Casing in stands to 1300 ft. Held safety meeting. Ran Casing in stands to 1517 ft. Ran Tubing to 1465 ft (2.0625 in OD). Nov 21 1996 (37) Ran Drillpipe in stands to 9621 ft. Circulated at 9621 ft. Held safety meeting. Ran Drillpipe in stands to 10987 ft. Circulated at 10987 ft. Batch mixed slurry - 27 bbl. Displaced slurry- 47 bbl. Worked toolstring at 9469 ft. Circulated at 10915 ft. Rigged down Circulating head. Pulled Drillpipe in stands to 9469 ft. Circulated at 9469 ft. Pulled Drillpipe in stands to 2000 ft. Held safety meeting. Pulled Drillpipe in stands to 0 ft. Laid down 1500 ft of Tubing. Installed BOP test plug assembly. Tested Well control. Nov 22 1996 (38) Tested Well control. Installed Bore protector. Tested Casing. Ran Drillpipe to 1110 ft (2 in OD). Held safety meeting. Ran Tubing to 1066 ft (2.0625 in OD). Ran Drillpipe in stands to 7360 ft. Rigged up Choke manifold. Ran Drillpipe in stands to 10915 ft. Rigged up High pressure lines. Perforated from 10350 ft to 10830 ft. Held safety meeting. Rigged down High pressure lines. Laid down 5800 ft of Drillpipe. Nov 23 1996 (39) Laid down 1066 ft of Drillpipe. Rigged up Tubing handling equipment. Held safety meeting. Laid down 1100 ft of Tubing. Rigged down Kelly. Rigged up Top ram. Rigged up Tubing handling equipment. Ran Tubing to 1000 ft (3.5 in OD). Held safety meeting. Ran Tubing to 5000 ft (3.5 in OD). Nov 24 1996 (40) Ran Tubing to 8855 ft (3.5 in OD). Rigged up sub-surface equipment - SCSSSV control line. Ran Tubing to 9309 ft (3.5 in OD). Installed Tubing hanger. Held safety meeting. Ran Tubing on landing string to 9339 ft. Reverse circulated at 9339 ft. Set packer at 9294 ft with 4300 psi. Installed Hanger plug. Rigged down BOP stack. Rigged up Surface tree. Freeze protect well-50 bbl of Diesl~lE ~si~l~/::l~ger plug. ~ I... I vi.- ~ FEB 1 l 997 Page 6 Alaska 0ii & Gas Cons. Anch0r~.ge SP~ .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PSU/5-4o 500292270700 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/28/97 DATE OF SURVEY: 111596 MWD SURVEY JOB NUMBER: AK-MM-60140 KELLY BUSHING ELEV. = 71.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -71.10 225 . 62 225 . 62 154 . 52 318.23 318.22 247.12 407.14 407.11 336 . 01 497.92 497. 82 426.72 0 0 0 25 0 46 1 24 2 49 N .00 E .00 .00N .00E .00 N 3.53 E .19 .85N .05E -.36 N 29.54 W .51 1.73N .23W -1.04 N 54.00 E 1.72 2.90N .36E -1.08 N 73.09 E 1.73 4.20N 3.40E .96 587.58 587.36 516.26 677.41 676.99 605.89 765.91 765.19 694.09 858.26 857.15 786.05 954.55 952.91 881.81 3 15 4 18 5 7 5 19 6 38 N 70.04 E .51 5.72N 7.92E 4.19 N 75.75 E 1.23 7.42N 13.58E 8.34 N 86.30 E 1.34 8.49N 20.74E 14.10 S 81.85 E 1.19 8.15N 29.10E 21.59 S 66.84 E 2.11 5.33N 38.64E 31.32 1049.23 1046.64 975.54 1143.16 1138.93 1067.83 1237.05 1230.75 1159.65 1331.15 1322.75 1251.65 1425.20 1414.67 1343.57 9 33 11 46 12 19 11 53 12 32 S 60.44 E 3.21 .70S 50.51E 44.62 S 60.95 E 2.38 9.20S 65.67E 62.00 S 60.52 E .59 18.79S 82.78E 81.61 S 57.93 E .74 28.88S 99.74E 101.33 S 57.92 E .69 39.45S 116.60E 121.20 1517.71 1504.42 1433.32 15 28 1611.77 1594.66 1523.56 17 15 1702.60 1681.49 1610.39 16 52 1798.72 1773.18 1702.08 18 1 1890.15 1859.63 1788.53 19 56 S 54.52 E 3.30 51.95S 135.17E 143.49 S 51.43 E 2.10 67.93S 156.29E 169.70 S 55.19 E 1.28 83.86S 177.65E 196.08 S 59.01 E 1.68 99.48S 201.85E 224.82 S 60.40 E 2.16 114.46S 227.53E 254.54 1983.66 1947.40 1876.30 20 2078.14 2035.21 1964.11 22 2172.28 2121.15 2050.05 25 -2266.74 2206.01 2134.91 26 2360.98 2290.63 2219.53 25 25 48 19 45 27 S 60.42 E .52 130.39S 255.59E 286.80 S 60.84 E 2.52 147.46S 285.92E 321.60 S 61.15 E 2.68 166.06S 319.49E 359.98 S 60.79 E 1.51 186.19S 355.75E 401.45 S 60.86 E 1.37 206.40S 391.95E 442.91 2455.71 2375.76 2304.66 26 34 2550.05 2459.45 2388.35 28 21 2644.39 2542.84 2471.74 27 22 2737.24 2625.40 2554.30 27 6 2829.01 2706.57 2635.47 28 30 S 61.36 E 1.20 226.47S 428.34E 484.47 S 61.31 E 1.89 247.35S 466.52E 527.98 S 58.26 E 1.83 269.52S 504.62E 572.05 S 61.30 E 1.53 290.90S 541.33E 614.52 S 61.99 E 1.57 311.22S 578.99E 657.31 2923.27 2789.55 2718.45 28 7 3016.95 2872.14 2801.04 28 12 3111.33 2955.37 2884.27 28 2 3203.41 3036.86 2965.76 27 26 3297.52 3119.92 3048.82 28 39 S 60.91 E .68 332.59S 618.26E 702.01 S 60.67 E .15 354.16S 656.85E 746.23 S 57.72 E 1.48 376.94S 695.06E 790.68 S 56.44 E .93 400.23S 731.04E 833.43 S 56.37 E 1.30 424.72S 767.90E 877.53 .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ~RCO ALASKA INC. PBU/5-40 500292270700 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/28/97 DATE OF SURVEY: 111596 MWD SURVEY JOB NUMBER: AK-MM-60140 KELLY BUSHING ELEV. = 71.10 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3391.30 3202.35 3131.25 3486.00 3285.89 3214.79 3578.81 3368.06 3296.96 3672.70 3451.41 3380.31 3767.88 3536.17 3465.07 28 16 S 56.04 E .44 449.58S 805.06E 27 55 S 55.47 E .47 474.69S 841.93E 27 28 S 54.07 E .85 499.57S 877.18E 27 19 S 55.03 E .50 524.63S 912.38E 26 47 S 53.74 E .82 549.84S 947.58E 922.06 966.47 1009.34 1052.25 1095.23 3856.15 3615.12 3544.02 3958.89 3706.90 3635.80 4052.89 3789.94 3718.84 4146.72 3871.54 3800.44 4240.82 3952.75 3881.65 26 20 S 53.63 E .52 573.22S 979.39E 27 3 S 53.42 E .71 600.67S 1016.51E 28 50 S 57.47 E 2.77 625.60S 1052.80E 30 21 S 62.61 E 3.15 648.69S 1092.94E 30 19 S 62.87 E .15 670.46S 1135.20E 1134.37 1180.11 1223.93 1270.22 1317.74 4334.52 4034.10 3963.00 4429.39 4118.14 4047.04 4520.31 4200.07 4128.97 4612.84 4283.08 4211.98 4708.41 4367.64 4296.54 29 9 S 65.83 E 2.00 690.59S 1177.07E 26 6 S 64.67 E 3.26 708.99S 1217.04E 25 17 S 61.26 E 1.86 726.89S 1252.15E 27 6 S 62.13 E 2.01 746.25S 1288.11E 28 25 S 63.67 E 1.57 766.52S 1327.75E 1364.14 1408.02 1447.42 1488.26 1532.76 4803.24 4450.80 4379.70 4896.23 4532.55 4461.45 4988.31 4614.23 4543.13 5083.16 4698.29 4627.19 5176.89 4780.66 4709.56 29 0 S 62.39 E .89 787.19S 1368.36E 27 53 S 62.25 E 1.20 807.77S 1407.60E 27 6 S 62.73 E .90 827.41S 1445.30E 28 3 S 60.17 E 1.61 848.40S 1483.86E 28 57 S 58.33 E 1.33 871.28S 1522.29E 1578.31 1622.60 1665.11 1709.01 1753.71 5269.34 4862.31 4791.21 5364.19 4947.34 4876.24 5445.78 5020.55 4949.45 5548.64 5112.04 5040.94 5640.41 5193.12 5122.02 26 57 S 59.91 E 2.31 893.53S 1559.46E 25 38 S 63.43 E 2.15 913.48S 1596.41E 26 45 S 62.76 E 1.42 929.79S 1628.53E 27 37 S 62.30 E .86 951.47S 1670.23E 28 14 S 60.04 E 1.34 972.20S 1707.88E 1797.00 1838.99 1874.99 1921.98 1964.96 5729.02 5271.12 5200.02 5829.17 5359.24 5288.14 5932.49 5450.46 5379.36 6024.98 5532.30 5461.20 6111.43 5608.60 5537.50 28 23 S 58.10 E 1.05 993.81S 1743.93E 28 21 S 55.18 E 1.39 1019.97S 1783.67E 27 38 S 53.69 E .97 1048.18S 1823.13E 27 53 S 53.51 E .30 1073.75S 1857.82E 28 11 S 53.09 E .41 1098.04S 1890.41E 2006.96 2054.39 2102.55 2145.26 2185.51 6214.01 5698.64 5627.54 6305.10 5778.20 5707.10 6391.75 5853.73 5782.63 6501.72 5948.76 5877.66 6594.91 6028.49 5957.39 29 2 S 54.08 E .95 1127.20S 1929.94E 29 15 S 54.03 E .24 1153.24S 1965.86E 29 25 S 58.72 E 2.66 1176.73S 2001.19E 31 0 S 62.87 E 2.38 1203.68S 2049.50E 31 20 S 66.76 E 2.19 1224.19S 2093.14E 2234.20 2278.22 2320.50 2375.81 2423.93 SP1 Y-SLrN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC. PBU/5-40 500292270700 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/28/97 DATE OF SURVEY: 111596 MWD SURVEY JOB NUMBER: AK-MM-60140 KELLY BUSHING ELEV. = 71.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6688.06 6107.89 6036.79 6779.91 6185.76 6114.66 6873.13 6264.32 6193.22 6969.72 6346.02 6274.92 7062.61 6426.05 6354.95 31 43 32 18 32 49 31 37 29 21 S 65.76 E .70 1243.81S 2137.73E S 67.53 E 1.20 1263.11S 2182.44E S 68.07 E .64 1282.07S 2228.90E S 66.67 E 1.46 1301.88S 2276.44E S 68.50 E 2.64 1319.87S 2320.00E 2472.46 2520.94 2570.79 2622.01 2668.84 7156.43 6507.89 6436.79 29 11 7250.54 6590.15 6519.05 28 55 7344.08 6672.27 6601.17 28 17 7439.04 6755.71 6684.60 28 45 7530.65 6836.17 6765.07 28 20 S 68.31 E .21 1336.75S 2362.66E S 68.24 E .29 1353.67S 2405.11E S 64.61 E 1.98 1371.56S 2446.14E S 64.46 E .50 1391.06S 2487.09E S 63.04 E .87 1410.42S 2526.35E 2714.37 2759.73 2804.30 2849.58 2893.31 7622.86 6917.43 6846.33 28 5 7716.90 7000.45 6929.35 27 56 7812.27 7084.88 7013.78 27 29 7905.69 7168.01 7096.91 26 47 7995.15 7248.35 7177.25 25 23 S 63.88 E .51 1429.90S 2565.35E S 64.43 E .32 1449.15S 2605.10E S 64.85 E .51 1468.15S 2645.18E S 63.87 E .89 1486.58S 2683.60E S 63.85 E 1.57 1503.92S 2718.92E 2936.88 2980.99 3025.26 3067.81 3107.11 8091.98 7336.12 7265.02 24 8186.49 7422.28 7351.18 24 8218.13 7451.23 7380.13 23 8280.12 7508.29 7437.19 22 8375.41 7594.68 7523.58 27 32 0 34 23 26 S 62.91 E .96 1522.23S 2755.46E S 63.81 E .70 1539.65S 2790.19E S 62.85 E 1.81 1545.38S 2801.59E S 62.95 E 1.90 1556.41S 2823.14E S 62.30 E 5.30 1574.88S 2858.78E 3147.96 3186.79 3199.54 3223.74 3263.87 8469.87 7676.72 7605.62 31 57 8530.31 7727.46 7656.36 33 50 8623.96 7805.92 7734.82 32 19 8716.88 7885.27 7814.17 30 21 8812.39 7968.89 7897.79 27 25 S 64.37 E 4.90 1595.82S 2900.60E S 66.29 E 3.59 1609.51S 2930.43E S 64.62 E 1.90 1630.73S 2976.93E S 63.27 E 2.25 1651.93S 3020.34E S 64.50 E 3.12 1672.26S 3061.76E 3310.61 3343.34 3394.32 3442.58 3488.66 8906.72 8053.08 7981.98 26 10 9002.06 8139.79 8068.69 22 55 9095.38 8225.96 8154.86 22 13 9188.86 8312.79 8241.69 21 18 9281.71 8398.09 8326.99 25 10 S 61.65 E 1.91 1691.49S 3099.68E S 63.81 E 3.53 1709.68S 3134.85E S 62.95 E .84 1725.72S 3166.88E S 55.47 E 3.12 1743.40S 3196.62E S 56.59 E 4.19 1763.84S 3227.02E 3531.16 3570.75 3606.54 3641.12 3677.61 9374.29 8481.57 8410.47 26 1 9466.80 8564.87 8493.77 25 32 9562.63 8650.85 8579.75 26 51 9652.54 8730.98 8659.88 27 4 9684.19 8758.74 8687.64 30 22 S 57.10 E .95 1785.72S 3260.52E S 53.16 E 1.92 1808.71S 3293.53E S 57.61 E 2.46 1832.69S 3328.34E S 55.16 E 1.26 1855.26S 3362.28E S 56.14 E 10.50 1863.84S 3374.84E 3717.50 3757.49 3799.55 3840.16 3855.30 .Y-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 4 ARCO ALASKA INC. PBU/5-40 500292270700 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/28/97 DATE OF SURVEY: 111596 MWD SURVEY JOB NUMBER: AK-MM-60140 KELLY BUSHING ELEV. = 71.10 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9715.67 8785.32 8714.22 34 19 S 57.26 E 12.72 1873.07S 3388.92E 9747.28 8810.75 8739.65 38 32 S 60.10 E 14.34 1882.81S 3404.97E 9770.55 8828.44 8757.34 42 29 S 61.70 E 17.55 1890.15S 3418.18E 9809.37 8855.63 8784.53 48 33 S 64.00 E 16.20 1902.76S 3442.82E 9840.77 8875.55 8804.45 52 40 S 63.40 E 13.17 1913.51S 3464.57E 3872.09 3890.84 3905.95 3933.62 3957.86 9872.44 8893.77 8822.67 57 2 S 63.60 E 13.81 1925.06S 3487.74E 9901.52 8908.68 8837.58 61 15 S 61.40 E 15.90 1936.60S 3509.88E 9933.46 8922.93 8851.83 65 44 S 57.80 E 17.27 1951.07S 3534.51E 9965.02 8935.02 8863.92 69 13 S 56.20 E 12.01 1966.95S 3558.95E 9996.80 8945.19 8874.09 73 26 S 59.46 E 16.45 1982.96S 3584.44E 3983.73 4008.68 4037.24 4066.31 4096.35 10028.17 8953.68 8882.58 75 9 S 56.84 E 9.70 1998.90S 3610.08E 10059.72 8961.01 8889.91 77 58 S 60.19 E 13.68 2014.92S 3636.25E 10091.92 8966.99 8895.89 80 36 S 58.54 E 9.59 2031.04S 3663.47E 10122.37 8971.63 8900.53 81 52 S 61.91 E 11.71 2045.98S 3689.59E 10156.79 8976.03 8904.93 83 24 S 59.95 E 7.17 2062.57S 3719.42E 4126.51 4157.15 4188.77 4218.85 4252.98 10187.30 8979.68 8908.58 82 52 S 63.60 E 12.00 2076.89S 3746.10E 10218.41 8983.58 8912.49 82 41 S 67.07 E 11.08 2089.77S 3774.14E 10250.36 8987.09 8915.99 84 41 S 63.49 E 12.78 2103.05S 3802.98E 10281.68 8989.87 8918.77 85 6 S 60.16 E 10.67 2117.77S 3830.48E 10313.54 8992.15 8921.05 86 40 S 59.94 E 4.98 2133.64S 3858.01E 4283.27 4314.05 4345.72 4376.91 4408.68 10345.73 8994.13 8923.03 86 16 S 61.61 E 5.33 2149.32S 3886.05E 10377.36 8996.64 8925.54 84 36 S 60.27 E 6.76 2164.64S 3913.60E 10408.93 8999.83 8928.73 83 48 S 61.73 E 5.25 2179.86S 3941.07E 10441.01 9003.02 8931.92 84 46 S 60.90 E 3.95 2195.18S 3969.07E 10471.94 9005.95 8934.85 84 22 S 60.41 E 2.04 2210.27S 3995.91E 4440.80 4472.33 4503.73 4535.65 4566.44 10503.12 9009.17 8938.07 83 45 S 59.33 E 3.98 2225.84S 4022.73E 10535.72 9012.92 8941.82 83 2 S 58.26 E 3.92 2242.61S 4050.43E 10564.91 9016.29 8945.19 83 43 S 56.04 E 7.91 2258.34S 4074.78E 10598.08 9019.71 8948.61 84 25 S 57.66 E 5.30 2276.38S 4102.40E 10987.00 9057.53 8986.43 84 25 S 57.66 E .00 2483.44S 4429.44E 4597.44 4629.79 4658.71 4691.60 5077.92 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5078.13 FEET AT SOUTH 60 DEG. 43 MIN. EAST AT MD = 10987 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 118.75 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 10,987.00' MD SP5 f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PBU/5-40 500292270700 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/28/97 DATE OF SURVEY: 111596 JOB NUMBER: AK-MM-60140 KELLY BUSHING ELEV. = 71.10 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -71.10 .00 N .00 E .00 1000.00 997.99 926.89 2.86 N 43.89 E 2.01 2000.00 1962.71 1891.61 133.21 S 260.55 E 37.29 3000.00 2857.20 2786.10 350.24 S 649.87 E 142.80 4000.00 3743.39 3672.29 611.71 S 1031.90 E 256.61 2.01 35.28 105.51 113.82 5000.00 4624.63 4553.53 829.85 S 1450.04 E 375.37 6000.00 5510.22 5439.12 1066.80 S 1848.42 E 489.78 7000.00 6371.80 6300.70 1308.16 S 2291.03 E 628.20 8000.00 7252.73 7181.63 1504.83 S 2720.78 E 747.27 9000.00 8137.89 8066.79 1709.32 S 3134.13 E 862.11 118.75 114.41 138.42 119.07 114.83 10000.00 8946.09 8874.99 1984.53 S 3587.08 E 1053.91 10987.00 9057.53 8986.43 2483.44 S 4429.44 E 1929.47 191.80 875.56 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PBU/5-40 500292270700 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/28/97 DATE OF SURVEY: 111596 JOB NUMBER: AK-MM-60140 KELLY BUSHING ELEV. = 71.10 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION .00 .00 -71.10 71.10 71.10 .00 171.10 171.10 100.00 271.10 271.10 200.00 371.12 371.10 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .44 N .03 E .00 .00 1.20 N .04 E .00 .00 2.38 N .33 W .02 .01 471.16 471.10 400.00 571.30 571.10 500.00 671.51 671.10 600.00 771.85 771.10 700.00 872.27 871.10 800.00 3.82 N 2.14 E .06 .05 5.40 N 7.05 E .20 .13 7.31 N 13.15 E .41 .21 8.53 N 21.27 E .75 .34 7.96 N 30.39 E 1.17 .42 972.87 971.10 900.00 1074.03 1071.10 1000.00 1176.02 1171.10 1100.00 1278.35 1271.10 1200.00 1380.56 1371.10 1300.00 4.41 N 40.68 E 2.73 S 54.09 E 12.46 S 71.53 E 23.13 S 90.45 E 34.30 S 108.39 E 1.77 2.93 4.92 7.25 9.46 .61 1.16 1.99 2.33 2.21 1483.23 1471.10 1400.00 1587.10 1571.10 1500.00 1691.74 1671.10 1600.00 1796.53 1771.10 1700.00 1902.35 1871.10 1800.00 46.87 S 127.89 E 63.37 S 150.57 E 82.06 S 175.06 E 99.13 S 201.27 E 116.52 S 231.15 E 12 16 20 25 31 .13 .00 .64 .43 .25 2.66 3.87 4.64 4.79 5.82 2008.95 1971.10 1900.00 2117.07 2071.10 2000.00 2227.65 2171.10 2100.00 2339.35 2271.10 2200.00 2450.50 2371.10 2300.00 134.75 S 263.27 E 154.81 S 299.10 E 177.60 S 340.39 E 201.87 S 383.83 E 225.36 S 426.29 E 37 45 56 68 79 .85 .97 .55 .25 .40 6.60 8.12 10.57 11.70 11.16 2563.29 2471.10 2400.00 2676.21 2571.10 2500.00 2788.67 2671.10 2600.00 2902.35 2771.10 2700.00 3015.77 2871.10 2800.00 250.37 S 472.03 E 92 277.21 S 517.07 E 105 302.19 S 562.04 E 117 327.79 S 609.64 E 131 353.89 S 656.37 E 144 .19 .11 .57 .25 .67 12.79 12.92 12.46 13.67 13.42 3129.15 2971.10 2900.00 3242.00 3071.10 3000.00 3355.81 3171.10 3100.00 3469.26 3271.10 3200.00 3582.24 3371.10 3300.00 381.42 S 702.15 E 158.05 410.07 S 745.88 E 170.90 440.19 S 791.10 E 184.71 470.24 S 835.48 E 198.16 500.50 S 878.46 E 211.14 13.38 12.84 13.81 13.46 12.98 SP~ f-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE ARCO ALASKA INC. PBU/5-40 500292270700 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/28/97 DATE OF SURVEY: 111596 JOB NUMBER: AK-MM-60140 KELLY BUSHING ELEV. = 71.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3694.86 3471.10 3400.0 3807.00 3571.10 3500.0 3918.69 3671.10 3600.0 4031.43 3771.10 3700.0 4146.22 3871.10 3800.0 530.46 S 920.71 E 560.26 S 961.78 E 589.77 S 1001.83 E 620.00 S 1044.19 E 648.57 S 1092.72 E 223.76 12.62 235.90 12.14 247.59 11.69 260.33 12.74 275.12 14.78 4262.08 3971.10 3900.0 4376.60 4071.10 4000.0 4488.27 4171.10 4100.0 4599.38 4271.10 4200.0 4712.35 4371.10 4300.0 675.35 S 1144.75 E 698.88 S 1195.33 E 720.31 S 1240.15 E 743.38 S 1282.69 E 767.35 S 1329.43 E 290.98 15.86 305.50 14.53 317.17 11.67 328.28 11.11 341.25 12.97 4826.45 4471.10 4400.0 4939.85 4571.10 4500.0 5052.34 4671.10 4600.0 5165.97 4771.10 4700.0 5279.20 4871.10 4800.0 792.40 S 1378.34 E 817.27 S 1425.66 E 841.19 S 1471.28 E 868.50 S 1517.79 E 895.77 S 1563.33 E 355.35 14.10 368.75 13.40 381.24 12.50 394.87 13.62 408.10 13.23 5390.54 4971.10 4900.0 5502.44 5071.10 5000.0 5615.42 5171.10 5100.0 5728.99 5271.10 5200.0 5842.65 5371.10 5300.0 918.58 S 1606.61 E 941.51 S 1651.27 E 966.30 S 1697.63 E 993.80 S 1743.92 E 1023.63 S 1788.93 E 419.44 11.34 431.34 11.90 444.32 12.98 457.89 13.58 471.55 13.66 5955.79 5471.10 5400.0 6068.90 5571.10 5500.0 6182.51 5671.10 5600.0 6296.97 5771.10 5700.0 6411.73 5871.10 5800.0 1054.58 S 1831.84 E 1086.00 S 1874.35 E 1118.23 S 1917.56 E 1150.91 S 1962.64 E 1181.79 S 2009.67 E 484.69 13.14 497.80 13.11 511.41 13.61 525.86 14.46 540.63 14.77 6527.78 5971.10 5900.0 6644.81 6071.10 6000.0 6762.56 6171.10 6100.0 6881.20 6271.10 6200.0 6999.17 6371.10 6300.0 1209.81 S 2061.45 E 1234.48 S 2116.99 E 1259.56 S 2173.87 E 1283.70 S 2232.96 E 1307.99 S 2290.63 E 556.68 16.05 573.71 17.03 591.46 17.75 610.10 18.64 628.07 17.97 7114.29 6471.10 6400.0 7228.77 6571.10 6500.0 7342.75 6671.10 6600.0 7456.60 6771.10 6700.0 7570.33 6871.10 6800.0 1329.16 S 2343.55 E 1349.77 S 2395.34 E 1371.29 S 2445.57 E 1394.70 S 2494.71 E 1418.94 S 2543.14 E 643.19 15.12 657.67 14.48 671.65 13.97 685.50 13.85 699.23 13.73 SPE. f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 8 ARCO ALASKA INC. PBU/5-40 500292270700 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/28/97 DATE OF SURVEY: 111596 JOB NUMBER: AK-MM-60140 KELLY BUSHING ELEV. = 71.10 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7683.68 6971.10 6900.00 1442.43 S 2591.06 E 712.58 13.35 7796.74 7071.10 7000.00 1465.10 S 2638.69 E 725.64 13.06 7909.15 7171.10 7100.00 1487.27 S 2685.00 E 738.05 12.41 8020.34 7271.10 7200.00 1508.68 S 2728.61 E 749.24 11.18 8130.43 7371.10 7300.00 1529.50 S 2769.68 E 759.33 10.09 8239.81 7471.10 7400.00 1549.34 S 2809.31 E 768.71 9.38 8349.03 7571.10 7500.00 1569.40 S 2848.29 E 777.93 9.21 8463.27 7671.10 7600.00 1594.32 S 2897.48 E 792.17 14.25 8582.76 7771.10 7700.00 1621.28 S 2957.03 E 811.66 19.49 8700.46 7871.10 7800.00 1648.20 S 3012.93 E 829.36 17.70 8814.88 7971.10 7900.00 1672.75 S 3062.79 E 843.78 14.42 8926.73 8071.10 8000.00 1695.59 S 3107.34 E 855.63 11.85 9036.06 8171.10 8100.00 1715.52 S 3146.74 E 864.96 9.33 9144.05 8271.10 8200.00 1734.54 S 3182.79 E 872.95 7.99 9252.05 8371.10 8300.00 1757.04 S 3216.78 E 880.95 8.00 9362.63 8471.10 8400.00 1782.94 S 3256.22 E 891.53 10.58 9473.71 8571.10 8500.00 1810.49 S 3295.91 E 902.61 11.07 9585.33 8671.10 8600.00 1838.18 S 3337.00 E 914.23 11.62 9698.68 8771.10 8700.00 1868.00 S 3381.13 E 927.58 13.35 9833.64 8871.10 8800.00 1911.03 S 3459.58 E 962.54 34.97 10118.75 8971.10 8900.00 2044.26 S 3686.44 E 1147.65 185.10 10987.00 9057.53 8986.43 2483.44 S 4429.44 E 1929.47 781.82 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Ci I::i ! I--I-- I ~ G S ~::: I~! ~d I 1-- E S WELL LOG TRANSMITTAL To: State of Alaska April 2, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. ~ ~5 Q~ ~ Anchorage, Alaska 99501 ~(0 f [ ~ ~ '~ MWD Formation Evaluation Logs - D.S. 05-40, AK-MM-60140 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-22707-00. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company CI Ft ICI-- I I~1 G S E FI ~J I i-- 1:: S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 05-40, AK-MM-60140 March 12, 1997 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ Jim Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 o54o: i -q 2"x 5" MD Gamma Ray Logs: 50-029-22707-00 2" x 5" TVD Gamma Ray Logs: 50-029-22707-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 , Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10678 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1/8/97 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape D.S. 11-05A 96328 PEX-(AIT,LDTICNL, MCR),BHC 'J~ '"'J,~(~ 961017 1 D.S. 05-40 96351 DITE/BHC/LDT/CNTG/GPIT -~ 7~' (_~ ! 9611 15 1 D.S. 05-40 96353. PHASOR INDUCTION-SFL 96111 5 I 1 D.S. 05-40 96353. COMPENSATED NEUTRON 9611 15 I 1 D.S. 05-40 96351 COMP NEUTRON*HEL*LITHO-DENSlTY 961 I 1 5 I 1 D.S. 05-40 96351 BHC 961115 I 1 D.S. O5-4O 96351 CONTINUOUS DIRECTIONAL (GPIT) 961 115 1 1 D.S. O5-4O 96351 BORENOLEPROFILE 961115 I 1 D.S. O5-4O 96351 SSTVD 961115 I 1 ., , .... .- . ! Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. JAN 1 0 DATE: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnst. p~, DATE: Chairman~ THRU: Blair Wondzell, .~~ FILE NO: P. I. Supervisor FROM: Chuck Scheve, ~ ~ SUBJECT: Petroleum Inspector October 25, 1996 aefkjydd.doc BOPE Test Doyon 9 PBU DS 5-40 PTD # 96-159 Friday October 25,1996: I traveled to Doyon Rig 9 and witnessed the initial BOPE test on the DS 5-40 Well. As the attached AOGCC BOPE Test Report shows,,there were 3 failures. The Blind Shear Rams, the Kill line HCR Valve,and one valve on the choke manifold failed the initial test. The valve on the choke manifold was replaced. The kill line HCR valve was repaired and the Blind Shear Ram Blocks were replaced with a set of Blind Ram Blocks, These 3 components were then r~tested and passed. This is Doyon 9's first well after a shut down period for maintenance and modifications to the mud system. The rig was clean and all equipment seemed to be in good working order. The location was well organized and all excess equipment was properly stored. Summa_w: I witnessed the BOPE test on Doyon Rig 9 drilling ARCO's DS 5-40 Well test time 9 hours - 3 failures. Attachment: aefkjydd.XLS X Unclassified STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Doyon Rig No. Operator: ARCO Well Name: DS 5-40 Casing Size: 7 5/8 Set @ 3,889 Test: Initial X Weekly Other PTD# 96-159 Rep.: Rig Rep.: Location: Sec. 32 T. DATE: Rig Ph.# Jerry Haberthur 10/25/96 659-4631 Tim Krupa 11N R. 15E Meddian Umiat MISC. INSPECTIONS: Location Gen.: OK Well Sign Yes Housekeeping: OK (Gen) Dri. Rig OK PTD On Location Yes ~' Hazard Sec. YES ~' Standing Order Posted Yes ~ BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HeR Valves Kill Line Valves Check Valve N/A 250/5,000 P 250/5,000 P 250/5,000 F/P 250/5,000 P 250/5,000 F/P 250/5,000 P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/5,000 P 250/5,000 P 250/5,000 P 250/5,000 P Test Press. P/F Test 250/2500 P Pressure P/F 250/5,000 F/P 250/5,000 N/A CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 38 250/5,000 P 1 P Functioned Func§oned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 40 sec. Trip Tank OK OK System Pressure Attained 3 minutes 15 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: Yes Remote: Yes Flow Indicator OK OK Nitgn. Btl's: 5 bottels at Meth Gas Detector OK OK 2000 Psig. H2S Gas Detector OK OK 3000I 1300 Number of Failures: 3 ,Test Time: 9.0 '~Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 days. 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 retumed by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The Blind Rams the kill line HCR and one valve on the choke manifold failed to pressure test ? Distribution: odg-Well File c - Oper.lRig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO waived By: Wrtnessed By: Chuck Scheve F1-021L (Rev.12/94) AEFKJYDD.XLS MEMORANDUM TO: David John, Chairman..-' THRU: Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 23, 1996 FILE NO: gefkjxdd. DOC FROM: Chuck Scheve, <~J SUBJECT: Petroleum Inspector Surface Cement Job PBU-DS 5-4O PTD# 96-0159 Wednesday October 23,1996: i was contacted by Jerry Haberthur, Shared Services Drilling Foreman, at 7 PM informing me that the USIT Log had indicated cement at 230' and it was their intention to run 1.25" pipe to 260' and circulate watching returns for signs of cement. I arrived on location at 7:30 PM and the crew had already run 230'of 1.25" pipe into the annulus. After talking to Jerry and Morris Redford the mud man another 30' of pipe was run with no sign of setting down. At this point circulation was established at two barrels a minute with pH readings taken at 10 barrel intervals. The pH at the 30 barrel point reached 8.7 with another reading immediately following reading 8.4 and all subsequent readings were 8.4 or 8.5. In all 290 barrels of mud were circulated at a depth of 260' with no sign of cement or contaminated mud at surface. Based on these facts, and those in Bobby Fosters report File # nefijwdd, I did not feel I could approve a top job regardless of Shared Services interpretation of the USlT Log. Thursday October 24,1996: After reviewing the USIT log a top job was approved by Blair Wondzell. With the 1.25" pipe at a depth of 260'RKB 283 barrels of cement was pumped before cement returns were observed at surface. The calculated volume of gauge hole at this depth was 32 barrels. ,. o¢'¢-'r Attachments: Unclassified Classified MEMORANDUM TO: THRU: David johnson,/'/' Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 23, 1996 Blair Wondzell, P. i. Supervisor ~ol~ Petroleum Inspector FILE NO: NEFIJWDD.doc Surface Cement Job PBU - DS 5-40 PTD # 96-0159 Wednesday, October 23, 1996: ! was contacted by Dan Stoltz, SDS drilling engineer, on 10/22/96, informing me that they did not get cement to surface on well DS 5-40. Dan gave me some of the information I needed, but began to tell me how much excess cement that they pumped and I told him I didn't need to know that. The only thing that I needed to know was where the top of the cement was located. He said he would have Jerry Haberthur, SDS drilling foreman, call me. ! received a call from Jerry at 7:30 PM and he said he pumped 400 bbls. of lead cement and lost returns. He continued to pump another 42 bbls. of lead cement in an attempt to re-establish circulation. He then pumped 47 bbls. of tail cement and bumped the plug with 178 bbls. of mud. I ask Jerry if he had an idea were the TOC might be and he said no. He said he had ordered 1200' of 1' pipe and was going to try to find the cement. ! arrived at the rig at 00:30 AM and the crew was rigging up to run the 40' joints of 1' pipe. The crew ran 420' (RKB) of the pipe in the hole and then circulated 48 bbls. of 9.7# / gal. mud down the hole at a rate of .8 bbl/min with no sign of cement. The crew began to run pipe on in the hole. i met with Jerry and told him that I was going to leave the location since I was going to Anchorage. I told Jerry that for me to know that there was cement coming out of the hole I would have to have 11.5#/gal. mud weight and at least a 11.5 pH. Jerry said he would call me if he found anything. I departed the location. Jerry and the mud engineer told me that the hole had been drilled with 10+#/gal. mud and a viscosity of 300+ and that they had hole problems this whole job. The 7" casing was washed down for 600' to 1000' to get it to bottom but they could circulate OK. Jerry said that they had cut the mud weight back to 9.7# and lowered the viscosity to 71+ prior to running pipe. i contacted Jerry at 10:00 AM and he said that they ran the 1" to 800' and it when they tried to circulate it was plugged. They pulled it out of the hole and were rigging up to run USlT log and a bond log. Summary: Attachment: Unclassified Confidential (Unclassified if doc. removed ) Confidential 55o Z~43z.. ~ T'~ c Ir-."/'~ 'L.,9 ~/D e'o ~o~- Rce. ip. ,t.. r2 / MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 23, 1996 To: Blair Wondzell, ~o~ FILE NO: P. I. Supervisor (of~ FROM: Chuck Scheve, c&~ SUBJECT: Petroleum Inspector gefl<jxdd. DOC Surface Cement Job PBU-DS 5-40 PTD# 96-0159 Wednesda.¥ October 23,!996-' l was contacted by Jerry Haberthur, SSD Drilling Foreman, at 7-~M informing me that the USiT Log had indicated cement at 230' and it was their intention to run 1.25" pipe to 260' and circulate watching returns for signs of cement. I arrived on location at 7:30 PM and the crew had already run 230'of 1.25~ pipe into the annulus. After talking to Jerry and Morris Redford the mud man another 30' of pipe was run with no sign of setting down. At this point circulation was established at two barrels a minute with pH readings taken at t0 barrel intervals. The pH at the 30 barrel point reached 847 with another reading immediately following reading 8,4 and all subsequent readings were 8.4 or 8.5_ in all 290 barrels of mud were circulated at a depth of 260' with no sign of cement or contaminated mud at surfaco. Based on these facts I did not feel I could approve a top job regardless of SSDs 07" interpretation of the USIT Log. I ~t~.~ Attachm, ents: Unclassified Classified Unclassified with Document Removed RECEIVED OCT 2 ~ Alaska Oil & 6'.~s Cons, Commission Ar]~.hor2¢9 '1:8 39t~cl 3OI_~_~O 3a095 3090t~ ilL~6qgLoG G;5:9I 966]:/EC/0'C MEMORANDUM State of Alaska Alaska Oil and Gas Conservation 'Commission TO: David Johnston, DATE: Chairman THRU: Blair Wondzell, P. I. Supervisor FILE NO: FROM: Bobby Foster, SUBJECT: Petroleum Inspector October 23, 1996 NEFIJWDD.doc Surface Cement Job PBU - DS 5-40 PTD # 96-0159 Wednesday, Octobe. r 23,.,..!...9._96: I was contacted by Dan Stoltz, SDS drilling engineer, on 10/22/96, informing me that they did not get cement to surface on well DS 5-40. Dan gave me some of the information I needed, but began to tell me how much excess cement that they pumped and i told him I didn't need to know that. The only thing that I needed to know was where the top of the cement was located. He said he would have Jerry Haberthur, SDS drilling foreman, call me_ I received a call from Jerry at 7:30 PM and he said he pumped 400 bbls. of lead cement and lost returns. He continued to pump another 42 bbls. of lead cement in an attempt to re-establish circulation. He then pumped 47 bbls. of tail cement and bumped the plug with 178 .bbls. of mud. I ask Jerry if he had an idea were the TOC might be and he said no. He said he had ordered 1200' of 1" pipe and was going to try to find the cement. I arrived at the rig at 00:30 AM and the crew was rigging up to run the 40' joints of 1" pipe. The crew ran 420' (RKB) of the pipe in the hole and then circulated 48 bbls. of 9.7# / gal. mud down the hole at a rate of .8 bbl/min with no sign of cement. The crew began to run pipe on in the hole. ! met with Jerry and told him that I was going to leave the location since I was going to Anchorage. I told Jerry that for me to know that there was cement coming out of the hole I would have to have 11_SA/gal_ mud weight and at least a 11.5 pH. Jerry said he would call me if he found anything. I departed the location. Jerry and the mud engineer told me that the hole had been drilled with lO+-/f/gal. mud and a viscosity of 300+ and that they had hole problems this whole job. The 7" casing was washed down for 800' to 1000' to get it to bottom but they could circulate OK. Jerry said that they had cut the mud weight back to 9.7# and lowered the viscosity to 71 + prior to running pipe. 2;8 3E)t~cl 3OI_-I_-I0 3cl09S OOBQ~ Z~2;6§9~06 §2; :9~ I contacted Jerry at 10:00 AM and he said that they ran the 1" to 800' and it when they tried to circulate it was plugged. They pulled it out of the hole and were rigging up to run USIT log and a bond tog. Sumrn~,,~: Attachment: Unclassified Confidential Confidential (Unclassified if doc. removed ) RECEIVED OCT2 Alaska Oil & (]as Cons. Commission ..ri £0 39'~'d :lOI_J,_=lO 3d09S OOgO'~' /_1] /__ 2; E, cig/__.OE, G2;'91~ TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Septe. mber 26, 1996 Dan Stoltz Senior Dr/lling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re~ Prudhoe Bay Unit 05-40 ARCO Alaska, Inc. Permit No: 96-159 Sur. Loc. 2321'NSL, 4109'WEL, Sec. 32, T1 iN, R15E, UM Btmhole Loc. 68'SNL, 147'WEL, Sec. 05, T10N, R15E, UM Dear Mr. Stoltz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout preventiOn equipment (BOPE) must be tested in accordance with 20 AAC '25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-36C. J~--~.~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type°fw°rk []Re-Entry []Deepen~ []Service []Development Gas []Single Zone []Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE = 69' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designatio, p E./~ Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028329/.2.~25'.2.¢ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2321' NSL, 4109' WEL, SEC. 32, T11N, R15E Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 309' NSL, 459' WEL, SEC. 32, T11 N, R15E 05-40 Attotal depth 9. Approximate spud date Amount $200,000.00 68' SNL, 147' WEL, SEC. 5, T10N, R15E 09/27/96 12. Distance to nearest property line113. Distance to nearest well 114. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028326 68'I No Close Approach 2560 10779' MD / 9049' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 400' Maximum Hole Angle 83.05° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig ,18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing i Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 30' 30' 110' 110' 260 sx Arctic Set (Approx.) 9-7/8" 7-5/8" 29.7# L-80 BTC-Mod 3864' 29' 29' 3893' 3639' PF 'E' to Surface, 229' sx 'G' Tail 6-3/4' 5-1/2" 17# L-80 IBT-Mod 9386' 28' 28' 9414' 8524' 1117 sx Class 'G' 4-3/4" 3-1/2" 9.3# L-80 IBT-Mod 1515' 9264' 8392' 10779' 9049' :111 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs(measured) ORIGINAL true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production RECEIVED Liner SEP 12 1996 Perforation depth: measured Alasl{a 0il & Gas Cons. Commission true vertical Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Johnson, 564-5480 Prepared By Name/Number: Terrie Hubb/e, 564-4628 21. I hereby certify that t~6~orrect to the best of my knowledge Signed/ ~===~f~~/~/~/,/47 ¢~'/. ~/~ Da, Storz ~.,~__~_ Title Senior Drilling Engineer Date ///" Commission Use Only '/ / ' ~'~'"-,,,,/~? 50- O 2_ 7 ~ 2_- ~ ~d::~ 7 ~ _-~ ~ _ .~ ~.-~ for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures ~s ~ [] No Directional Survey Required ~ Yes [] No Required Working Pressure for BOP, E,.. [] 2M; [] 3M; I~i 5M; [] 10M; [] 15M Other: ;: 1~nal Signed i~y by order of Approved By -~SV{Q W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: I PBU 05-40 I Type of Well (producer or injector): I Producer Surface Location: 2321' NSL, 4109' WEL, SEC 32, TllN, R15E Target Location: 309' NSL, 459' WEL, SEC 32, TI IN, R15E Bottom Hole Location: 68' SNL, 147' WEL, SEC 5, T10N, R15E ]AFE Number: 14J0334 I I Estimated Start Date: I 9/27/96, 1996 I Rig: I DOYON 9 I Days to complete [25 IMD: I10779, I I TVD: 19049' brt I IRTE: I69, Well Design (conventional, slimhole, etc.): ] Micro-Slimhole High Angle Well (83°) Formation Markers: Formation Tops MD TVD Base of Permafrost 1960 1919 SV3 3882 3629 7 5/8" Casing Point 3893 3639 7 5/8" shoe, 10' TVD below SV3 Ugnu 6159 5644 LCU 9267 8394 Sag 9282 8407 Shublik 9326 8446 TSAD 9403 8514 5 1/2" Casing Point 9414 8524 5 1/2" shoe, 10' TVD below TSAD Zone 1 9950 8934 Begin target 10060 8962 End target 10779 9049 3 1/2" Casing Point 10779 9049 3-1/2" liner Shoe Casing/Tubing Program: Hole Csg/Tbg Wt/Ft Grade Conn Length Top Btm Size O.D. MD/TVD MD/TVD 30" 20" 91.5# H40 WELD 80' 30/30' 110/110' 9 7/8" 7 5/8" 29.7# L80 BTC-Mod 3864' 29/29' 3893/3639' 6 3/4" 5 1/2" 17# L-80 IBT-Mod 9386' 28/28' 9414/8524' 4 3/4" 3 1/2" 9.3# L-80 IBT-MOd 1515' 9264/8392' 10779/9049' Tubing 3 1/2" 9.3# L-80 [BT-Mod 9235 26/26 9261/8391' Mud Program: Surface Mud Properties: Spud [ 9 7/8" hole section Density (5ppg)~unnel VislYield Point I a0 sec g~lll0 min gel[ 8.6-9. ! 100-300 30-70 20-30 30-40 pH ]Fluid Loss[ 8.5-9.5 8-12cc Intermediate Mud Properties: LSND ] 6 3/4" hole section Density (ppg)lFunnel Vil Yield PointI a0 sec gelI a0 mia gelI 8.8-10.2 ] 40-55 5-17 4-10 15-20 I I pH inuid , oss i 8.5-9.5 6-10cc Production Mud Properties: ShearDriln1 4 3/4" hole section Density (ppg) Funnel visI LSR YP 10 sec 10 rain I gel gel 8.8-9.0 40-50 6-10 10-15 15-20 I pH Fluid Loss 8.5-9.0 <6cc Cement Data: Casing/Liner Lead:Sxs/Wt/Yield Tail: Sxs/Wt/Yield Comments 7-5/8" Pump to surface. 229/15.8/1.15 Screw in job. Type E Suggested mix on the Permafrost lead & Class "G" fly cement available on tail. Lead will be circulated to location is: surface prior to tail being 1350/12.0/2.17 pumped. Tail is 750' of fill (assumes 500% excess +50% excess + shoe (47 Bbl). in permafrost, 50% below) 5 1/2" none 117/15.8/1.15 Class "G". Volume based on cement to 1000' above the Sag River with 30% excess 3-1/2" none 111/15.6/1.2 Class "G". Volume based on open hole with 30% excess, 150' lap, 200' DP, 80' shoe Logging Program: I Open Hole Logs: I Cased Hole Logs: 9 7/8" MWD 6 3/4" MWX)/GR 4 3/4" MWD/GR & SWS DPC GR/sonic/neutron/resistivity None Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP: 400' MD Maximum Hole Angle: 83.05 degrees Close Approach Well: None Drilling and Completion Scope . 2. 3 4 5 6 7 8 9 10. 11. Move rig to 5-40 Drill 9 7/8" surface hole to -3893' MD. Run and cement 7 5/8" casing Drill 6 3/4" intermediate hole to -9414' MD. Run and cement 5 1/2" casing. Drill 4 3/4" high angle to TD at -10779' MD Run and cement 3 1/2" production liner Cleanout 3 1/2" liner Perforate with drillpipe conveyed guns. Run 3-1/2" L-80 production tubing with 5 1/2"x3-1/2" packer, 3-1/2" SSSV, and 3-1/2"x 1" GLMs. Secure well, RDMO Drilling Hazards · Pore pressure may be as high as 9.8 ppg EMW in the Cretaceous interval due to water disposal at FS-1. Will ensure appropriate mud weight. · No potential hydrocarbon-bearing zones expected above the Sag River. · Drillsite 5 is not an H2S pad. The highest H2S level on the pad is from 5-19 at 14 ppm in 3/96. Losses have been encountered drilling the Sag River, Shublik and Sadleroci,., formations on other DS-5 wells. Pump LCM as necessary to control losses. Disposal · Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC- 2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. MOJ 9/10/96 BPX - Shared Servi, s Drilling Alaska State Plane: Zone4 PBU' EOA' DS05 Slot · 05-40 As-Built We ll~2~A~hv,E:w 0~~-- 4 0 Wp4_~ SCALE 200 ft. / DIVISION TVD REP: WELLHEAD VERTICAL SECTION REF: WELLHEAD 200 400-~.~ BOO ~ 1200 { 63 291 389 471 0.00' @ 0 ND TIE IN 00' @400MD KOP/START OF BUILD @ 1.00'/100 1.00' @500MD 2,00' @GO0MD 3.00' @700HD 4.00' @BOO MBSTART OFBUILD @1.50'/100 Ft 5.50' @ 900 HD 7.00' @ I000 MD .50' @ I100 MD 0.00' @ 1200 MD START OF BUILD @ 2.00'/100 2,00' @ 1300 MD 4.00' @ 1400 MD 6.00' @ 1500.HD @ 1600 ND @ 1700 ND @ 1800 HD B1900 MD END OF BUILD @1960 MD Bose Pern' @ 2200 MD START OF CURVE @ 2.00'/100 @ 2300 MD 77' @ 2389 MD END OF CURVE CASING POINT DATA OD MD lac Azl 5/8 In3893 27.77'118.62' 1/2 In9414 27.77'I18.62' I/2 ~n10779 83.05' 121.84' 1167 HORIZONTAL VIEW (TRUE NORTH) SCALE 400 fl:. / DIVISION SURVEY REF: WELLHEAD HALLIBURTON 1600 - 2000- 119,00' , aaco - Iie, 64- ~~o ol I-~- ~. 6e· 4/~ -IIB, 62' ~ - 118.6~' .6aoo - 6~ -lIB. 62' GS~- He. Ga' 71~ - IIB.~' ?400 - 11B. 62' 8~ -IIB. 62' ~ ~/2 ~ o~, o ~a~ u~~[X~' 9~0 - 121.84' ~ I/~ in OD ~ 10779 ~0 9049 ~0 400 0 800 -120( -I G0( 200( 2401 2801 -3201 360( 0 400 4000 4400 4800 5200 5600 G000 TVD N/S E/W 3639 564 S 1088 E J 32@G E 85241796 S 4263 E 90492389S SEPt t 199~ 0ii & Gas Cons. ruomm~Ssion Anchorage 5193 MD K-IS ~t! 2228 58[ 6O0 64( 2620 66£ 7OO 712 3007 720 740 76O 772 3328 78O 300, 32O 3676 0400 -500 -3bo -160 ldo 3do 5do 7do 9do lidO 1360 1560 ITbO 1900 2100 2300 2500 VERTICAL SECTION PLANE: I 19.27' vERTICAL VIEW SCALE 100 fL. / DIVISION 'CVD REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD 27.77' @ 6159 MD Top Ugnu 27,77' 7001 MD Top Vest 2900 3100 3300 ITor~et NameTVD NS EV Grid X Grid Y Target ESL 8962 2013 S 3657 E 701964 5946600 Torget ESL 9049 2389 S 4263 E 702580 5946240 Poty I 8962 1914 S 3710 E 702014 5946700 Poly 2 8962 2111 S 3604 E 701914 5946500 Poly 3 9062 2290 S 4316 £ 702630 5946340 Poiy 4 8962 2488 S 4211E 702530 5946140 Polygon 8962 0 N 0 E 698255 5948515 CRITICAL POINT DATA Hf lac Az,. T? N~SN E~ TIE IN 0.00'119.00' KUP / START 400 0.00'119.00' 400 0 N 0 OF BUILD I,O0'/lO0 ?~ START or BUILD B00 4.00'119.00' B00 7S 12 @ 1.50'/100 START OF BUILD 1200 lO. O0' 119.00' 1197 30 S 55 @ 2.00'/100 F~ END 0~ BU,LD ,900 24.00. ,,9.00. ,864 l~? ~ 233 Bose Perm' 1960 24.00' 119.00' 1919 255 START OF 2200 24.00'119.00' 2138 189S340 CURVE @ 2.00'/100 Ft END OF CURVE2389 27.77'J18.62' 2308 228~412 SV3 / T-5 3082 27.77'18.62' 3629 561 I023 K-15 5193 27.77'118.62' 4789 854S1559 Top Ugnu 6159 27.77'118.62' 5644 1070 S 1954 Top Vest Sa~7001 27.77'118.62' 6389 1258S2299 K-lO 7832 27.77'! 18.62' 7124 1443 S 2639 K-5 8521 27.77'118.62' 7734 1597 S 2921 Ju~osslc A 9205 27.77'118.62' 8339 1750S3200 LCU 9267 27.77'11262. 8394 1764 ~ 3226 So9 River Send 9282 27.77'I8.62' 8407 1767 3232 ShubUN 9326 27.77'II8.62' 8446 1777 S 3250 TSAD / TZ4B 9403 87.77'I18.62' 8514 1794S3281 TZ3 9606 27.77'118.62' 8694 1839 S 3364 TZ2C 9657 27.77'118.62' 8739 185IS3385 START BF 9665 27.77'I18.62' 8746 1852 S3388 CURVE @ 14.00'/100 Ft Zone 28 9715 34.77'119.45' 8789 1865 S 3411 Zone 2A / 9848 53.34'120.71' 8884 19}1S 3491 Romeo CGOC 9925 64.14'121.18' 8924 1945 S 3547 Zone I 9950 67.56'121.31' 8934 1957S 3566 END DF CURVE10060 83.05'121.84' 8962 2013 S 3657 BSAD / Top 10490 83.05'121.84' 9014 2238S 4019 Kovik Torget ESL /]0779 83.05'121.84' 9049 2389 S 4263 HOT 27. 77' 8521 K-5 WELL PLAN PRO~E SUMMAJ~.Y ~l'lU ~B {~'D ),{I) 0 400 80O 1200 22O0 2389 3893 9413 9665 il2o0 2389 3893 9413 9665 27.77' @ 9205 ND Jurassic A 27.77' @ 9267 MD LCU 3700 PLOT INFORMATION DRAWING NAME / FILl: NAME O5-~Oc. skd i 0S-40 Comp SURFACE LOCATION PROPOSED BIlL Alaska State Plane J O As-Bu,'lt TVD g04g. O0 I ~D 10779.0D No .rth~: S~4~5t 4.~ J 0 ~-$l~kad VS 4887.01 Em*?mg: ~8254.e3 2389.07 E~ 4263.23 ~ RTE FL: ~9.0 O E~mated N/S Designed By: ,~¢~, ,~ 0300 1 \ 1339 m 3647 \ 27.77' @ 9205 HD Jurossic A ]400 / 3676 \ 27.77' @ 9267 MD LCU 1407 ] 3683 ~ 27.77' @ 9282 MD Sag River Sand 1446 [ 3703 ~27.77' @ 9326 HD Shublik :5.00, ~ , 3739 ~ 27.77' e 9403 MD TSAD / TZ4B 1694 l ~700 ~ 3834 ~ ~7.77' e 9606 MD TZ3 1739 / 3858~~7.77' ~ 9657 MD TZ~C ~746 [ 1789 J 3887~34.77' 1800 J X41'75' ~ 9765 H~ lBO4 o~0 J 3979 ~ 53.34' ~ 9848 HD Zone ~A / Romeo j454 J ~04~~ 64.~4' ~ 99~5 ND CGGC '~4/ 4068 = ~ ~ 67.56' e 9950 Hg Zone 1 ~9~J 4174 ~ 83.05' ~ 10060 MD END DF CURVE q00~ ~ 83.05' ~ 10779 HD T~get ESL / HaT J Jill VERTICAL SECTION PLANE: 1 19.27' Halliburton Energy Services - Drilling Systems PSL Proposal Report Proposal No: 96-0_ Date: 9/9/96 Time: 2:48 pm Wellpath ID: 0540 Wp4 Last Revision: 9/5/96 Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.15.48 N - Long. 148.23.49 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (it): 5948514.64 N 698254.93 E North Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD TVD Reference: WELLHEAD Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2.2.2 Vertical Section Plane: 119.27 deg. BPX - Shared Services Drilling Alaska State Plane: Zone4 PBU: EOA: DS05 Slot: 0540 As-Built Wellpath: 05-40 Wp4 WPFS Measured Inci Drift Subsea TVD Course T O TA L Depth Dir. Depth Length Rectangular Offsets (it) (deg.) (deg.) (it) (fi) (it) (it) (it) GRID Coordinates Northing Easting (it) (it) Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (it) (dg/100it) (dg/100it) (dg/100ft) (deg) (it) (it) (it) (it) (deg.) (it) Survey Tool TIE IN 0.00 0.00 0.00 -69.00 0.00 0.00 0.00N 200.00 0.00 0.00 131.00 200.00 200.00 0.00N KOP / START OF BUILD ~ 1.00 deg/100 ft 400.00 0.00 0.00 331.00 400.00 200.00 0.00N 0.00E 5948514.64 698254.93 0.00E 5948514.64 698254.93 0.00E 5948514.64 698254.93 0.0~ 0.00 0.00 0.00 0.00 0.00~ 0.00 0.00 0.00 0.00 0.00~ 0.00 0.00 0.00 0.00 500.00 1.00 119.00 430.99 499.99 100.00 0.42 S 600.00 2.00 119.00 530.96 599.96 100.00 1.69 S 700.00 3.00 119.00 630.86 699.86 100.00 3.81S 0.76E 5948514.24 698255.70 3.05 E 5948513.03 698258.03 6.87E 5948511.02 698261.89 0.87@119.00 0.87 1.00 0.00 3.4~ 119.00 3.49 1.00 0.00 7.85~ 119.00 7.85 1.00 0.00 START OF BU1LD~I.50 deg/100 it 800.00 4.00 119.00 730.68 799.68 100.00 6.77 S 12.21E 5948508.20 698267.31 13.96~119.00 13.96 900.00 5.50 119.00 830.33 899.33 100.00 10.78 S 19.45 E 5948504.38 698274.66 22.24~119.00 22.24 1000.00 7.00 119.00 929.73 998.73 100.00 16.06 S 28.97 E 5948499.36 698284.31 33.12~119.00 33.12 1100.00 8.50 119.00 1028.82 1097.82 100.00 22.60 S 40.76E 5948493.13 698296.27 46.61~119.00 46.61 START OF BUILD~2.00 deg/100 it 1200.00 10.00 119.00 1127.51 1196.51 I00.00 30.39 S 54.82 E 5948485.71 698310.53 62.68~I19.00 62.68 1300.00 12.00 119.00 1225.67 1294.67 100.00 39.64 S 71.51E 5948476.90 698327.46 81.76~119.00 81.76 1400.00 14.00 119.00 1323.10 1392.10 I00.00 50.54 S 91.18 E 5948466.52 698347.41 104.26~119.00 104.26 1500.00 16.00 119.00 1419.69 1488.69 100.00 63.09 S 113.82 E 5948454.58 698370.37 130.14~I19.00 130.14 1600.00 18.00 119.00 1515.32 1584.32 100.00 77.27 S 139.39E 5948441.08 698396.30 159.37~119.00 159.37 1700.00 20.00 119.00 1609.86 1678.86 I00.00 93.05 S 167.86E 5948426.06 698425.18 191.93~119.00 191.93 1800.00 22.00 119.00 1703.22 1772.22 100.00 110.42 S 199.21E 5948409.52 698456.96 227.76~119.00 227.76 END OF BUILD 1900.00 24.00 119.00 1795.26 1864.26 100.00 129.36 S 233.38E 5948391.48 698491.62 266.83~119.00 266.83 Base Perm' 1959.92 24.00 119.00 1850.00 1919.00 59.92 141.18S 254.69E 5948380.23 698513.24 291.216119.00 291.20 START OF CURVE ~ 2.00 deg/100 ft 1.00 0.00 1.50 0.00 1.50 0.00 1.50 1.50 2.00 2.00 2.00 2.00 2.00 2.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.0 0.00N 0.00 0.0 0.00N 0.00 0.0 0.00N 1.00 1.0 0.42 S 1.00 2.0 1.70 S 1.00 3.0 3.83 S 0.00 E 0.00 0.00 0.00 0.00 MWD 0.00 E 0.03 0.03 0.00 0.20 BPHM-PBD 0.00 E 0.09 0.09 0.00 0.50 BPHM-PBD 0.76E 0.13 0.11 29.00 0.65 BPHM-PBD 3.05 E 0.23 0.15 29.00 0.80 BPHM-PBD 6.86E 0.40 0.20 29.00 0.95 BPHM-PBD 1.00 4.0 6.81 S 12.18E 0.64 0.27 29.00 1.10 BPHM-PBD 1.50 5.5 10.87 S 19.40E 0.97 0.36 29.00 1.25 BPHM-?BD 1.50 7.0 16.21 S 28.88 E 1.40 0.48 29.00 1.39 BPHM-PBD 1.50 8.5 22.85 S 40.62 E 1.93 0.63 29.00 1.54 BPHM-PBD 1.50 10.0 30.79 S 54.60E 2.55 0.80 29.00 1.69 BPHM-PBD 2.00 12.0 40.24 S 71.18E 3.30 1.01 29.00 1.84 BPHM-PBD 2.00 14.0 51.42 S 90.70E 4.20 1.26 29.00 1.99 BPHM-PBD 2.00 16.0 64.32 S 113.14E 5.23 1.54 29.00 2.15 BPHM-?BD 2.00 18.0 78.94 S 138.46E 6.41 1.84 29.00 2.30 BPHM-PBD 2.00 20.0 95.27 S 166.63 E 7.74 2.18 29.00 2.47 BPHM-PBD 2.00 22.0 113.30 S 197.61 E 9.22 2.55 29.00 2.63 BPHM-PBD 2.00 24.0 133.01 S 231.35 E 10.87 2.94 29.00 2.81 BPHM-PBD 0.00 24.0 145.29 S 252.41 E 11.86 3.18 29.00 2.92 BPHM-PBD Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (ft) (&g.) (deg.) (ft) (ft) (ft) (ft) (ft) Halliburton Energy Services - Drilling Systems PSL GRID Coordinates Northing Easting (ft) (ft) Proposal Report Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (a) (f~) (f~) (deg.) (f~) 2200.00 24.00 119.00 2069.32 2138.32 240.08 188.52S 340.10E 5948335.16 698599.86 388.85~119.00 388.85 2300.00 26.00 118.79 2159.95 2228.95 100.00 208.94S 377.10E 5948315.73 698637.38 431.11~118.99 431.11 END OF CURVE 2388.80 27.77 118.62 2239.15 2308.15 88.80 228.22S 412.32E 5948297.38 698673.10 471.27~118.96 471.26 SV3 / T-5 3881.61 27.77 118.62 3560.00 3629.00 1492.81 561.44 S 1022.91E 5947980.43 699292.24 1166.86~118.76 1166.81 CASING POINT OD = 7 5/8 in, ID = 6 7/8 in, Weight = 29.70 lb/ft. 3892.92 27.77 118.62 3570.00 3639.00 11.30 563.97S 1027.53E 5947978.03 699296.93 1172.12~118.76 1172.08 K-15 5192.64 27.77 118.62 4720.00 4789.00 1299.72 854.09 S 1559.14E 5947702.12 699836.01 1777.74~118.71 1777.66 0.00 0.00 2.00 -0.21 2.00 -0.19 Top Ugnu 6158.95 27.77 118.62 5575.00 5644.00 966.31 1069.78 S 1954.37E 5947497.01 700236.82 2228.01~118.70 2227.90 Top West Sak 7000.95 27.77 118.62 6320.00 6389.00 841.99 1257.73S 2298.76E 5947318.30 700586.07 2620.34~118.68 2620.21 K-10 7831.64 27.77 118.62 7055.00 7124.00 830.69 1443.15 S 2638.53 E 5947142.01 700930.64 3007.41~118.68 3007.25 K-5 8521.06 27.77 118.62 7665.00 7734.00 689.42 1597.04 S 2920.51E 5946995.71 701216.61 3328.66(~118.67 3328.48 Date: 9/9/~, Wellpath ID: 05-40 Wp4 Survey Tool 0.00 0.00 0.00 0.00 0.00 0.00 0.00 24.0 194.49 S 336.79E 15.84 4.12 29.00 3.38 BPHM-PBD 2.00 26.0 215.81 S 373.29E 17.67 4.54 28.98 3.59 BPHM-PBD 0.00 0.00 0.00 0.00 0.00 0.00 2.00 27.8 236.00 S 408.02E 19.42 4.92 28.95 3.79 BPHM-PBD 0.00 27.8 584.48 S 1010.28E 49.16 11.46 28.75 7.42 BPHM-PBD 0.00 27.8 563.97 S 1027.53 E 0.00 0.00 0.00 0.00 BPHM-PBD 0.00 27.8 890.52 S 1539.20E 75.35 17.20 28.70 10.78 BPHM-PBD 0.00 27.8 1116.09 S 1929.05 E 94.67 21.43 28.69 13.29 BPHM-PBD 0.00 27.8 1312.64 S 2268.74E Ill.51 25.12 28.68 15.49 BPHM-PBD 0.00 27.8 1506.56 S 2603.88 E 128.12 28.76 28.67 17.66 BPHM-PBD 0.00 0.00 0.00 27.8 1667.49 S 2882.01E 141.91 31.77 28.67 19.47 BPHM-PBD LCU 9266.98 27.77 118.62 8325.00 8394.00 62.16 1763.55 S 3225.61E 5946837.43 701526.04 3676.23~118.67 3676.03 0.00 Sag River Sand 9281.67 27.77 118.62 8338.00 8407.00 14.69 1766.83S 3231.62E 5946834.32 701532.13 3683.07~I18.67 3682.87 0.00 Shublik 9325.75 27.77 118.62 8377.00 8446.00 44.08 1776.67 S 3249.65 E 5946824.96 701550.42 3703.61~118.67 3703.41 0.00 TSAD / TZ4B 9402.60 27.77 118.62 8445.00 8514.00 76.85 1793.82 S 3281.08 E 5946808.66 701582.30 3739.42~118.67 3739.22 0.00 CASING POINT OD = 5 1/2 in, ID = 4.89 in, Weight = 17.00 lb/ft. 9413.91 27.77 118.62 8455.00 8524.00 11.30 1796.34 S 3285.70E 5946806.26 701586.98 3744.69(~118.67 3744.49 0.00 TZ3 ' 9606.04 27.77 118.62 8625.00 8694.00 192.13 1839.23 S 3364.29E 5946765.49 701666.69 3834.22~118.67 3834.01 0.00 TZ2C 9656.90 27.77 118.62 8670.00 8739.00 50.86 1850.58S 3385.09E 5946754.70 701687.78 3857.91~118.66 3857.70 0.00 START OF CURVE ~ 14.00 deg/100 fl 9665.06 27.77 118.62 8677.22 8746.22 8.16 1852.40 S 3388.43 E 5946752.97 701691.17 3861.72~118.66 3861.50 0.00 Zone 2B 9715.14 34.77 119.45 8720.00 8789.00 50.08 1865.03 S 3411.14E 5946740.96 701714.20 3887.70~118.67 3887.49 13.97 9765.06 41.75 120.03 8759.17 8828.17 49.92 1880.37S 3437.95E 5946726.34 701741.42 3918.58~118.68 3918.38 13.98 Zone 2A / Romeo 9847.91 53.34 120.71 8815.00 8884.00 82.85 1911.25 S 3490.58 E 5946696.88 701794.85 3979.58~118.70 3979.39 13.99 9865.06 55.74 120.83 8824.95 8893.95 17.15 1918.40S 3502.58E 5946690.06 701807.04 3993.54~118.71 3993.35 13.99 CGOC 9925.10 64.14 121.18 8855.00 8924.00 60.04 1945.15 S 3547.08 E 5946664.51 701852.24 4045.42~118.74 4045.25 13.99 Zone I 0.00 0.00 27.8 1841.62 S 3182.95 E 156.83 35.04 28.66 21.42 BPHM-PBD 0.00 0.00 0.00 0.00 27.8 1845.05 S 3188.88 E 157.12 35.11 28.66 21.46 BPHM-PBD 0.00 27.8 1855.34 S 3206.66E 158.00 35.30 28.66 21.58 BPHM-PBD 0.00 27.8 1873.28 S 3237.67E 159.54 35.64 28.66 21.78 BPHM-PBD 0.00 0.00 0.00 0.00 27.8 1796.34 S 3285.70E 0.00 0.00 0.00 0.00 BPHM-PBD 0.00 27.8 1920.76 S 3319.74 E 163.61 36.53 28.66 22.31 BPHM-PBD 0.00 27.8 1932.64 S 3340.26E 164.63 36.75 28.66 22.45 BPHM-PBD 0.00 0.00 27.8 1934.54 S 3343.55 E 164.79 36.79 28.66 22.47 BPHM-PBD 1.66 14.00 34.8 1947.92 S 3365.83 E 166.10 37.03 28.67 22.66 BPHM-PBD 1.16 14.00 41.8 1964.27 S 3392.06 E 167.72 37.28 28.68 22.90 BPHM-PBD 0.82 14.00 53.4 1997.57 S 3443.26E 171.23 37.69 28.72 23.43 BPHM-PBD 0.67 14.00 55.8 2005.24 S 3454.94 E 171.98 37.77 28.73 23.54 BPHM-PBD 0.59 14.00 64.2 2034.17 S 3498.13 E 174.99 38.02 28.78 24.00 BPHM-PBD Measured Incl Drift Subsea TVD Course T 0 T A L Depth Dir. Depth Length Rectangular Offsets (f) (deg.) (deg.) (fl) (f) (f) (f) (fl) Halliburton Energy Services - Drilling Systems PSL Proposal Report GRID Coordinates Closure Vertical Build Walk DLS Cum. Expected Total Max Hot Min Hot Dir. Vert Northing Easting Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (fl) (fl) (f) (deg.) (f) (dg/lOOfl) (dg/lOOf) (rig/IOOf) (deg) (It) (f) (f) (f) (deg.) (f) 9949.55 67.56 121.31 8865.00 8934.00 24.44 1956.72 S 3566.15E 5946653.46 701871.60 4067.76~118.75 4067.53 13.99 9965.06 69.73 121.39 8870.65 8939.65 15.51 1964.24 S 3578.48E 5946646.28 701884.14 4082.13~118.76 4081.97 13.99 END OF CURVE 10060.25 83.05 121.84 8893.00 8962.00 95.19 2012.64 S 3657.08E 5946600.00 701964.00 4174.32~118.83 4174.20 13.99 Pag~ Date: 9/9/96 Wellpath ID: 05-40 Wp4 Survey Tool 0.53 14.00 67.6 2046.67 S 3516.63E 176.26 38.11 28.80 24.20 BPHM-PBD 0.51 14.00 69.8 2054.79 S 3528.59E 177.09 38.16 28.81 24.33 BPHM-PBD 0.47 14.00 83.1 2107.33 S 3604.62E 182.61 38.29 28.90 25.17 BPHM-PBD BSAD / Top Kavik 10489.88 83.05 121.84 8945.00 9014.00 429.64 2237.63S 4019.38E 5946384.82 702332.18 4600.26~119.11 4600.25 0.00 0.00 Target ESL / HOT / CASING POINT OD = 3 1/2 in, ID --- 2.97 in, Weight = 9.30 lb/f. 10779.06 83.05 121.84 8980.00 9049.00 289.18 2389.07 S 4263.23E 5946240.00 702580.00 4887.01~119.27 4887.01 -0.00 -0.00 0.00 83.1 2350.98 S 3955.33 E 207.79 38.94 29.28 29.06 BPHM-PBD 0.00 83.1 2514.98 S 4191.39E 224.90 39.38 29.48 31.75 BPHM-PBD · . · WELL PERMIT CHECKLIST COMPANY/~r,,--~, WELL NAME/~z~'~f/ .~""-' FIELD & POOL ~ .c_/z~)//...~'cD INIT CLASS//~ / -0// GEOL AREA ADMINISTRATION . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. -'ENGiNEERiNG APPR D/~TE ! 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. PROGRAM: exp [] dev~reddl [] serv [3 wellbore seg [] ann. disposal para req I'-1 UNIT# ' //~"~::3 ON/OFFSHORE__ ~,,,'~ Permit fee attached ....................... .~ N Lease number appropriate ................... t~ ,N Unique well name and number ................. I~ N Well located in a defined pool .................. I~ N Well located proper distance from dflg unit boundary ..... ~.'~ N Well located proper distance from other wells ......... ~.~ N Sufficient acreage available in ddiling unit. .......... J'~ N If deviated, is wellbore plat included .............. ~? N Operator only affected party ................... I~ N Operator has appropriate bond in force ............ t'~ N Permit can be issued without conservation order ...... t'~ N Permit can be issued wi~out administrate approval .... ~.~ N Can permit be approved before 15-day wait. ........ t~ N REMARKS 'GEOLOGY APPR Conductor string provided .................. _~ N Surface casing protects ail known USDWs ......... CMT vol adequate to circulate on conductor & surf csg..~. '(~ N CMT vol adequate to tie-in long s~ng to surf csg ....... CMT will cover ail known productive horizons ......... ~-~N casing designs adequate for C, T, B & pe~t. ..... ~Y~'.N, Adequate tankage or reserve pit. ............... (,._Y.J N If a re-drill, has a 10-403 for abndnmnt been approved .... j~ N Adequate wellbore separation proposed ............ If diverter required, is it adequate ................ L..~N Ddlling fluid program schematic & equip list adequate .... ~L,~N BOP Es adequate ........................ -~J~, N BOPE press rating adequate; test to ~'-~> ~ psig. ~(~.,.~ Choke manifold complies w/AP! RP-53 (May 84) ....... Work will occur without operation shutdown .......... Is presence of H2S gas probable ............... (._Y~N vx/ 30. Permit can be issued w/o hydrogen sulfide measures ..... Y 1~~ //~ _,,,'? 31. Data presented on potential overpressure zones ....... Y/a<~ /.x/~_j,~7~', 32. Seismic anaiysis of shailow gas zones ............. /Y N 33. Seabed condition survey (if off-shore) ........... //. Y N 34. Contact name/phone for weekly progresg, mpo~ ,....~... Y N /exp/oramry ono~J GEOLOGY: ENGINEERING: COMMISSION: JDH ~,-3~:~ JDN TAB ~].~, Comments/Instructions: HOW/lib - A.'~FOR~ rev 4¢:36 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * . . ****************************** . ............................ . * SCHLUMBERGER ....... * . ............................ . ****************************** COMPANY NAME : ARCO ALASKA INC. WELL NAME : P2 - 20 FIELD NAME : POINT MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API NURIBER : 500292266400 REFERENCE NO : 98563 NOV 13 1998 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 5 ORIGIN : FLIC REEL NAME : 98563 CONTINUATION # : PREVIOUS REEL : COf4M~2~T : ARCO ALASKA, P2-20, POINT MCI TYR , API #50-029-22664-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 5 ORIGIN : FLIC TAPE NAi~E : 98563 CONTINUATION # : 1 PREVIOUS TAPE : COMPiENT : ARCO ALASKA, P2-20, POINT MCINTYRE, API #50-029-22664-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: P2-20 API NUFiBER: 500292266400 OPERATOR: Arco Alaska Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 5-NOV-98 JOB NUMBER: 98563 LOGGING ENGINEER: G. Johnson OPERATOR WITNESS: RON WHITE SURFACE LOCATION SECTION: 14 TOWNSHIP: 12N RANGE: 14E FNL : 50 FSL: FEL: FWL: 1239 ELEVATION(FT FROM MSL O) KELLY BUSHING: 52. O0 DERRICK FLOOR: 52. O0 GROUND LEVEL: 11.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 8. 500 4. 500 9587.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(M~ASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 26-MAR-96 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88888.0 88889.0 9451.5 9451.5 9450.5 9451.5 9444.0 9445.0 9445.0 9437.5 9438.5 9437.0 9438.5 9427.5 9427.5 9427.5 9391.5 9393.5 9393.5 9381.0 9381.0 9380.5 9381.0 9378.5 9378.5 9378.5 9377.0 9377.0 9376.5 9377.0 9375.5 9374.5 9375.0 9374.5 9367.5 9367.0 9367.5 9356.5 9357.0 9357.0 9350.0 9350.5 9350.5 9336.0 9338.0 9338.0 9330.5 9329.5 9329.5 9306.5 9307.5 9307.5 9302.5 9302 . 5 9301 . 0 9302.5 9261.5 9262.5 9261.0 9262.5 9197.5 9196.0 9197.0 9196.0 9191.5 9190.5 9190.5 9185.5 9184.5 9184.5 9165 . 5 9164.0 9165.0 9164.0 9162.5 9162.0 9162.0 9157.5 9156.5 9157.0 9156.5 9153.5 9151.5 9152.0 9151.5 9147.5 9146.5 9146.5 9145.5 9145.0 9145.0 9142.5 9142.0 9142.0 9139.5 9138.5 9138.5 9131.5 9130.0 9130.0 9125.0 9124.5 9124.5 9117.5 9117.5 9117.5 9112.0 9111.5 9111.5 9109.5 9108.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 9109.0 9108.5 9107.0 9106.5 9106.5 9103.0 9103.0 9102.5 9103.0 9098.5 9098.5 9098.5 9095.0 9094.5 9094.5 9093.0 9092.0 9092.5 9092.0 100.0 99.5 99.0 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON ARCO ALASKA'S P2-20 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE MWD GA~4~A RAY, ALSO BASE PASS #1 SIGMA AND THE MWD GAM~zA RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAM~ : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFiBER: 1 DEPTH INCREPiENT: 0.5000 FILE SUM~A2~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9479.0 9085.5 RST 9498.0 9085.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 8 9 i1 12 13 14 15 16 0 0.5 FT 10 65 68 65 66 68 66 0 65 FT 66 68 66 1 66 0 ** SET TYPE - CHAN ** NAMiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI..~SS MOD NUMB S~2~IP ELE3/I CODE (HEX) DEPT FT 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 CIRNFIL 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 BSALRST PPK 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM RST CU 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PA GE: NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DSIG RST CU 1274717 GRCH RST GAPI 1274717 TENS RST LB 1274717 CCL RST V 1274717 FBEF RST UA 1274717 CRRA RST 1274717 GR MWD GAPI 1274717 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9498.000 SFNA.FIL 19.622 IRAT.FIL 0.487 SIBF.RST 41.806 SIGM. RST 15.922 CCL.RST 0.000 DEPT. 9050.000 SFNA.FIL -999.250 IRAT.FIL -999.250 SIBF. RST -999.250 SIGM. RST -999.250 CCL.RST -999.250 NBAC. RST 2526.443 FBAC.RST 3173.837 SBNA.FIL SBFA.FIL 42.629 SFFA.FIL 17.341 TRAT. FIL CIRN. FIL 1.190 CIRF. FIL 2.473 BSAL.RST TPHI.RST 28.259 SFFC.RST 15.872 SFNC.RST DSIG.RST 0.698 GRCH.RST -999.250 TENS.RST FBEF. RST 34.216 CRRA.RST 2.050 GR.MWD NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL SBFA. FIL -999.250 SFFA.FIL -999.250 TRAT. FIL CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST DSIG.RST -999.250 GRCH. RST -999.250 TENS.RST FBEF.RST -999.250 CRJ~.RST -999.250 GR.MWD 46.860 0.985 55.586 16.773 1195.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 162.686 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: FILE HEADER FILE~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 2 DEPTH INCREMFaVT: 0.5000 FILE SUF~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9475.0 9079.0 RST 9497.0 9078.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: 1 BASELINE DEPTH .............. 88888.0 9491.0 9485.0 9476.0 9456.5 9456.0 9453.5 9446.0 9439.0 9437.0 9431.5 9426.0 9421.0 9415.0 9402.5 9401.5 9400.0 9396.5 9393.5 9385.5 9382.0 9377.5 9376.0 9375.0 9371.5 9368.0 9365.0 9362.0 9360.5 9358.0 9357.0 9355.0 9353.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88886.0 88890.0 9454.5 9451.0 9438.5 9423.0 9405.5 9403.0 9398.0 9394.0 9386.5 9377.0 9374.5 9370.0 9367.0 9361.5 9359.0 9357.0 9493.0 9485.5 9477.0 9456.5 9446.5 9438.5 9431.5 9425.5 9416.0 9401.5 9382.0 9377.0 9374.5 9367.5 9364.5 9359.0 9355.0 9354.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 9350.5 9350.5 9348.5 9349.0 9347.0 9348.5 9343.0 9344.5 9341.5 9343.0 9338.5 9339.5 9338.0 9340.0 9332.5 9335.0 9332.0 9330.5 9329.0 9328.0 9326.0 9329.5 9321.5 9321.0 9318.5 9318.5 9314.5 9317.5 9311.5 9312.0 9307.5 9307.5 9304.0 9304.5 9303.5 9302.5 9301.0 9302.0 9293.5 9293.5 9290.5 9290.5 9288.0 9289.0 9286.0 9286.0 9284.0 9284.5 9276.5 9277 . 0 9277.5 9274.5 9275.0 9275.5 9269.5 9270.0 9267.0 9268.0 9257.0 9258.0 9257.5 9254.5 9255.5 9253.0 9253.5 9252.0 9252.0 9249.0 9249.5 9244.0 9244.5 9243.0 9243.5 9241.5 9241.0 9239.5 9240.0 9238.0 9238.0 9236.5 9236.0 9236.0 9236.0 9229.0 9229.0 9228.0 9227.5 9227.0 9227.0 9225.5 9225.0 9224.0 9224.0 9220.5 9219.0 9217.0 9216.0 9216.0 9215.0 9213.5 9212.0 9210.5 9210.0 9209.5 9208.5 9207.0 9205.5 9204.5 9203.0 9204.0 9202.5 9197.5 9196.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 9197.0 9196.0 9194.5 9193 . 0 9185.5 9184.5 9185.0 9184.0 9180.0 9178.5 9177.5 9177.0 9173 . 0 9171 . 5 9170.5 9169 . 5 9170.0 9168.0 9165.0 9163.5 9163 . 0 9162.0 9161 . 0 9160.5 9156.5 9156.0 9153.5 9151.5 9152.5 9151.5 9145.5 9145.0 9143.0 9142.5 9139.5 9138.0 9138.5 9135.5 9135.0 9131 . 5 913 O. 0 9125.5 9124.5 9124.0 9124.0 9123 . 0 9122.5 9121.5 9120.0 9118.5 9118.0 9115.0 9114.5 9112.0 9111.5 9109.5 9108.0 9109.0 9108.5 9107.0 9106.5 9103.0 9103.0 9099.5 9099.0 9098.0 9097.0 9096.0 9094.0 9095 . 5 9094.5 9093.5 9092.0 9093.0 9092.0 9089.5 9087.5 100.0 99.0 98.0 REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 2 3 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 92 1 0.5 FT 11 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 BSALRST PPK 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1274717 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 10 ** DATA ** DEPT. 9497.000 NBAC.RST SFNA.FIL 19.561 SBFA.FIL IRAT.FIL 0.481 CIRN. FIL SIBF.RST 42.601 TPHI.RST SIGM. RST 16.162 DSIG.RST CCL.RST 0.005 CRRA.RST DEPT. 9078.000 NBAC.RST SFNA.FIL 37.117 SBFA.FIL IRAT. FIL 0.478 CIRN. FIL SIBF. RST 36.365 TPHI.RST SIGM. RST 37.718 DSIG.RST CCL.RST -0.034 CRRA.RST 2652.732 FBAC.RST 41.812 SFFA.FIL 1.180 CIRF. FIL 28.707 SFFC.RST 0.787 GRCH. RST 2.049 FBEF. RST 2749.198 FBAC. RST 38.578 SFFA.FIL 0.691 CIRF. FIL 49.360 SFFC.RST 1.250 GRCH.RST 2.090 FBEF. RST 3347.318 SBNA.FIL 17.563 TRAT.FIL 2.481 BSAL.RST 16.118 SFNC.RST -999.250 TENS.RST 38.663 3415.829 SBNA.FIL 36.256 TRAT. FIL 1.029 BSAL.RST 37.580 SFNC.RST -999.250 TENS.RST 37.476 48.478 0.990 57.759 16.784 1184.000 45.332 1.411 40.569 41.349 1161.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAMiE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS--ER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH GRCH 9478.0 RST 9497.5 STOP DEPTH .......... 9055.0 9055.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 11 $ CURVE SHIFT DATA - PASS TO PASS (FL~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFi~ER : 1 BASELINE DEPTH 88888.0 9492.0 9485.0 9482.0 9470.0 9455.0 9445.5 9438.5 9437.0 9433.0 9431.5 9400.0 9382.0 9380.5 9379.0 9377.0 9376.0 9375.0 93 68.0 9358.5 9354.0 9350.0 9339.5 9337.0 9336.0 9331.5 9325.5 9321.5 9319.5 9302.5 9300.5 9296.5 9290.5 9284.5 9276.5 9267.0 9266.5 92 64.0 9263.5 92 62.0 9257.5 9252.0 9249.5 9248.5 9243.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88887.0 88888.5 9469.0 9454.5 9438.5 9432.5 9381.5 9378.5 9377.0 9374.5 9367.0 9354.5 9338.0 9319.5 9302.5 9296.0 9290.5 9284.5 9277.0 9268.5 9264.5 9262.0 9258.5 9249.5 9243.5 9492.5 9485.0 9482.5 9446.5 9438.5 9431.5 9401.5 9382.0 9375.0 9367.5 9359.0 9350.5 9341.0 9337.5 9331.0 9324.5 9321.0 9302.0 9292.0 9265.5 9263.5 9258.5 9252.0 9249.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 12 9241.5 9241.0 9239.5 9240.0 9237.5 9237.5 9236.0 9236.0 9229.0 9229.0 9228.0 9227.0 9227.0 9227.0 9225.5 9223.0 9225.0 9225.0 9216.5 9216.0 9214.5 9212.5 9212.0 9211.5 9208.5 9207.5 9204.5 9202.5 9198.0 9196.0 9197.5 9196.0 9194.0 9193.0 9193.0 9190.5 9185.5 9184.5 9181.0 9179.0 9177.0 9175.5 9169.5 9168.0 9165.5 9164.0 9164.0 9163.5 9160.5 9160.5 9160.5 9159.5 9159.5 9157.0 9156.0 9153.5 9151.5 9152.5 9151.5 9147.0 9146.0 9145.5 9145.0 9143.5 9143.0 9143.0 9142.0 9139.5 9138.5 9138.0 9135.5 9133.0 9131.5 9130.0 9125.0 9124.0 9124.5 9124.0 9121.0 9120.0 9118.5 9117.0 9118.0 9117.5 9112.5 9111.5 9110.5 9110.5 9110.0 9108.5 9107.0 9106.5 9097.5 9097.5 9093.0 9092.5 9092.5 9091.5 9090.5 100.0 99.0 99.5 THIS FILE CONTAINS CASED HOLE RST BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #1 AND SIGMA BASE PASS #1, CARRYING ALL LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 13 RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 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 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 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNFIL 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF FIL 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 BSAL RST PPK 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RST PU-S 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST CU 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 14 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) GRCH RST GAPI 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 CCL RST V 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 CRRARST 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RST UA 1274717 O0 000 O0 0 3 1 1 4 68 0000000000 * * DA TA * * DEPT. 9497.500 NBAC.RST 2673.797 FBAC. RST 3394.742 SBNA.FIL SFNA.FIL 19.758 SBFA.FIL 44.929 SFFA.FIL 18.113 TRAT. FIL IRAT. FIL 0.486 CIRN. FIL 1.169 CIRF. FIL 2.436 BSAL.RST SIBF.RST 42.355 TPHI.RST 28.069 SFFC.RST 16.686 SFNC.RST SIGM. RST 16.709 DSIG.RST 0.638 GRCH.RST -999.250 TENS.RST CCL.RST 0.000 CRRA.RST 2.068 FBEF. RST 39.425 DEPT. 9055.000 NBAC.RST -999.250 FBAC. RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 GRCH.RST 205.475 TENS.RST CCL.RST -999.250 CRRA.RST -999.250 FBEF.RST -999.250 50.366 O. 985 57. 088 16. 927 1273. 000 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 15 FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS ~ER : 4 DEPTH INCREMENT: 0.5000 FILE SU~FLAR Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9478.5 9081.5 RST 9497.5 9081 . 0 $ CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9492.0 9485.0 9481.5 9469.0 9468.5 9456.0 9452.5 9450.5 9436.5 9431.5 9424.0 9403.0 9400.0 9387.5 9381.5 9377.0 9376.0 9369.0 9368.0 9367.0 9362.0 9358.5 9356.5 9355.0 9349.5 9348.0 9338.0 9336.0 9331.5 9327.5 9324.0 9321.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88887.5 88888.5 9468.5 9451.0 9423.0 9403.0 9381.0 9377.0 9370.0 9367.5 9361.5 9357.0 9349.0 9338.0 9329.5 9322.0 9492.5 9485.0 9483.0 9469.5 9457.0 9451.0 9438.5 9431.5 9401.5 9388.0 9381.5 9375.0 9367.5 9359.0 9355.0 9350.5 9340.0 9330. 5 9324.5 9321.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 16 9303.5 9303.0 9300.5 9292.5 9290.5 9287.0 9284.0 9276.5 9269.0 9266.5 9263.5 9257.0 9255.0 9252.5 9252.0 9243.0 9241.5 9229.0 9228.0 9225.0 9222.0 9220 0 9217 0 9213 5 9211 0 9204 5 9203 5 9199.5 9192.0 9191.5 9185.5 9180.0 9177.5 9176.5 9171.0 9169.5 9165.0 9164.0 9160.5 9158.0 9156.5 9153.5 9152.5 9148.5 9147.5 9145.0 9143.0 9139.5 9139.0 9134.0 9128.5 9124.0 9123.0 9117.5 9117.0 9302.5 9290.5 9284.5 92 77.5 9268.0 92 64.5 9253.5 9243.5 9229.0 9225.0 9222.5 9221.5 9213.0 9211.5 9202.5 9198.5 9190.5 9184.5 9177.0 9169.0 9164.0 9157.5 9151.5 9146.5 9144.5 9142.5 9138.5 9127.5 9122.5 9117.5 9305.5 9302.5 9294.0 9288.0 9268.5 9258.5 9255.0 9252.5 9241.0 9227.5 9216.0 9202.5 9190.5 9179.0 9175.5 9168.0 9163.5 9160.5 9156.0 9152.0 9146.5 9138.0 9133.0 9123.5 9117.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 17 9112.0 9111.5 9109.0 9108.5 9108.5 9108.5 9099.5 9099.0 9097.0 9097.0 9093.0 9092.5 9090.5 9089.5 100.0 99.5 99.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 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 ** NAMiE SERV UNIT SERVICE API API API API FILE NOW~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 18 NA~IE SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SFNA FIL CU 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 CIRFFIL 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 BSALRST PPK 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RST CU 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RST PU-S 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RST CU 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RST CU 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RST CU 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RST CU 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 TENS RST LB 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 CCL RST V . 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 CRRARST 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RST UA 1274717 O0 000 O0 0 4 1 1 4 68 0000000000 * * DA TA * * DEPT. SFNA. FIL IRAT. FIL SIBF. RST SIGM. RST CCL . RST DEPT. SFNA.FIL IRAT. FIL SIBF. RST SIGM. RST CCL.RST 9497.500 NBAC.RST 2753.976 FBAC.RST 3487.653 SBNA.FIL 47.547 19.623 SBFA.FIL 41.939 SFFA.FIL 17.972 TRAT. FIL 1.001 0.490 CIRN. FIL 1.199 CIRF. FIL 2.431 BSAL.RST 52.331 40.618 TPHI.RST 29.323 SFFC.RST 16.511 SFNC.RST 16.803 16.542 DSIG.RST 0.316 GRCH.RST -999.250 TENS.RST 1231.000 0.003 CRRA.RST 2.042 FBEF.RST 39.008 9081 000 NBAC. RST 2794.652 FBAC.RST 3608.523 SBNA.FIL 60.776 35 608 SBFA.FIL 46.969 SFFA.FIL 35.944 TRAT. FIL 1.227 0 467 CIRN. FIL 0.511 CIRF. FIL 0.872 BSAL.RST 163.704 83 980 TPHI.RST 45.353 SFFC.RST 36.433 SFNC. RST 37.358 36 865 DSIG.RST 0.074 GRCH.RST -999.250 TENS.RST 1161.000 -0 027 CRRA.RST 2.083 FBEF. RST 39.574 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 19 **** FILE TRAILER **** FILE NA~E : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE . 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFiBER: 5 DEPTH INCREmENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9477.5 9087.5 RST 9497.5 9088.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88886.5 88888.5 9484.5 9485.0 9475.5 9477.0 9456.0 9454.5 9447.0 9447.5 9438.5 9438.0 9437.0 9438.5 9431.5 9431.5 9413.5 9414.5 9412.5 9413.5 9401.0 9402.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PA GE: 2O 9393.0 9394.0 9392.0 9394.0 9385.5 9385.5 9382.0 9382.5 9379.0 9378.5 9376.0 9374.5 9374.5 9374.5 9368.0 9367.5 9367.0 9367.0 9358.0 9358.0 9355.0 9355.5 9354.5 9355.5 9350.0 9350.5 9331 . 5 9331 . 0 9322.0 9321 . 5 9320.5 9319.0 9304.5 9306.0 9302.5 9302.5 9300.5 9302.0 9296.5 9296.0 9294.5 9296.5 9293.5 9293.5 9289.5 9291 . 5 9284.5 9284.5 9281.5 9282.0 9271 . 5 9272.0 9269.5 9269.0 9267.0 9268.0 9255.5 9255.5 9252.5 9253 . 5 9251.5 9252.0 9249.0 9249.5 9241 . 5 9241 . 0 9239.5 9240.0 9236.0 9236.0 9229.0 9229.0 9225.0 9223.5 9217.0 9216.0 9213 . 5 9213.0 9204.5 9203.0 9204.0 9202.5 9202.5 9200.0 9190.0 9188.5 9183 . 0 9183.0 9177.0 9175.5 9170.5 9169.0 9169.0 9167.5 9165.0 9164.0 9164 . 5 9164 . 0 9157.0 9156.0 9152.5 9151.5 9148.0 9146.5 9145.5 9145.0 9143 . 0 9142.5 9140.0 9138.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 21 9139.0 9130.5 9128.5 9127.5 9124.5 9124.5 9123.0 9122.5 9121.0 9118.0 9117.5 9114.0 9113.0 9111.5 9109.5 9108.5 9106.5 9106.5 9099.0 9099.0 9095.0 9094.5 9093.0 9092.5 100.0 99.5 9138.0 9128.0 9120.0 9114.0 9106.5 100.0 REMARKS.. THIS FILE CONTAINS CASED HOLE RST BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 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 5-NOV-1998 15:24 PAGE: 22 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1274717 00 000 O0 0 5 I 1 4 68 0000000000 NBAC RST CPS 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC RST CPS 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT FIL 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL RST PPK 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF RST CU 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI RST PU-S 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC RST CU 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC RST CU 1274717 O0 000 O0 0 5 i 1 4 68 0000000000 SIGM RST CU 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG RST CU 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH RST GAPI 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 TENS RST LB 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 CCL RST V 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 CRRARST 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF RST UA 1274717 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9497.500 NBAC.RST 2813.748 FBAC.RST 3426.309 SBNA.FIL SFNA.FIL 19.369 SBFA.FIL 36.507 SFFA.FIL 17.817 TRAT. FIL IRAT. FIL 0.487 CIRN. FIL 1.172 CIRF.FIL 2.463 BSAL.RST SIBF. RST 43.022 TPHI.RST 28.887 SFFC.RST 16.390 SFNC.RST SIGM.RST 16.422 DSIG.RST 0.716 GRCH.RST -999.250 TENS.RST CCL.RST 0.000 CRRA.RST 2.074 FBEF.RST 39.464 DEPT. 9087.500 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 GRCH.RST 229.326 TENS.RST CCL.RST -999.250 CRRA.RST -999.250 FBEF. RST -999.250 49.940 0.992 58.908 16.622 1230.000 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 23 **** FILE TRAILER **** FILE NAM~ : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iV-UMBER: 6 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, RST $ REWORKS: THIS FILE CONTAINS THE ARITHIZiETIC AVERAGE OF BASE PASSES 1 & 2. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 24 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 NBAC RST CPS 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC RST CPS 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA RSAV CU 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA RSAV CU 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA RSAV CU 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA RSAV CU 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT RSAV 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT RSAV 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 CIRN RSAV 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF RSAV 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL RSAV PPK 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF RSAV CU 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI RSAV PU-S 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC RSAV CU 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC RSAV CU 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM RSAV CU 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG RSAV CU 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF RSAV UA 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA RSAV 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH RST GAPI 1274717 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9498.000 NBAC.RST 2526.443 FBAC.RST 3173.837 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV -999.250 IRAT.RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 SIBF.RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF. RSAV -999.250 CRRA.RSAV -999.250 GRCH. RST -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 25 DEPT. 9085. 000 NBAC. RST 2697. 251 FBAC. RST SFNA. RSAV 37. 541 SBFA. RSAV 42. 721 SFFA. RSAV IRAT. RSAV O. 457 CIRN. RSAV O. 632 CIRF. RSAV SIBF. RSAV 35. 698 TPHI. RSAV 48. 264 SFFC. RSAV SIGM. RSAV 40. 471 DSIG. RSAV 1 . 102 FBEF. RSAV GRCH. RST -999. 250 3469.348 SBNA.RSAV 38. 467 TRAT. RSAV O. 999 BSAL. RSAV 40. 340 SFNC. RSAV 37. 236 CRRA. RSAV 49. 040 1.389 38. 703 41. 801 2.161 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENOI~BER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFiBER : 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RST 9528.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : STOP DEPTH 9027.5 13 -AUG-98 8CI -205 1506 13-AUG-98 9507.0 9498.0 9056.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 26 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~LA RAY RST RESERVOIR SATURATION $ 9497.0 TOOL NUMBER CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 9587.0 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/BORAX WATER 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): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): CORRELATED TO PERF RECORD DATED 4/21/96 MADE UP/DOWN TEMP PASS PRIOR TO PUMPING (WELL SHUT IN) MADE A TEMP PASS WHILE AFTER PUMPING 180 BBLS INITIAL CRUDE AFTER PUMPING 225 BBLS CRUDE AT 5-6 BPM MADE 2 RST BASE PASSES. PUMPED & DISPLACED BORAX WATER AND MADE 3 RST BORAX PASSES MADE A UP/DOWN TEMP PASS AFTER ALL PUMPING MADE A TEMP PASS DOWN AFTER PUMPING HAD STOPPPED FOR 1.25 HR. CHANNEL FROM THE UB3 TO UB4/UCl PERFS LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 27 CHANNEL FROM THE UB3 TO UB2 PERFS THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 376 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME 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 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS1F/HR 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS1 LB 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 NPHVPS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 NPDE PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CRRA PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 AQTMPS1 S 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CHV PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CPSV PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CP2V PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 C~I2V PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PSl 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 RCAKPS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center S-NOV-1998 15..24 PAGE: 28 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NU~ SAMP ELEM CODE (HEX) RTDF PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 FPHVPS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 FPDE PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 FSCE PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 FSCR PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 AQTF PS1 S 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SF6P PSl PSIG 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 HVPV PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 BMCU PS1 UA 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 GDCU PS1 MA 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 EXCUPS1 UA 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS1 UA 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF PS1 UA 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 BSPR PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 MARC PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 XHV PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 XPSV PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 ~2V PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 RXFR PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 RXLC PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 RXRC PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 RXAKPS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SHCU PS1 MA 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL PS1 PPK 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL SIG PPK 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CIRFPS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG PS1 CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS1 CPS 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS1 CPS 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS1 CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS1 CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS1 CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS1 CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA FIL CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA FIL CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS1 CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 29 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) SFNC PS1 CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC PS1 CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS1 CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS1 GAPI 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 RDIX PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CRNI PS1 K~Z 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS1 K~Z 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 RSCS PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CTM PS1 DEGC 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 XTM PS1 DEGC 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 TAV PS1 KV 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS1 AMP 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS1 AMP 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 BUST PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 RSXS PS1 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS1 PU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS1 V 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 WTEP PS1 DEGC 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 WPRE PS1 PSI 1274717 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS1 AQTM. PS1 CM2V. PS1 RCAK. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR . PS1 XP5 V. PSi R3LLC. PS1 BSAL. PSi CIRN. FIL IRAT. PSl SFFA. PS1 SFFA. SIG SFFA. FIL SFNC. PS1 SIGM. SIG GR.PSl 9528.000 1452.562 0.441 -12 211 2 000 1 885 160 889 17 231 4O O88 5 069 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 6.679 CS.PS1 1985.659 TENS.PSi 701.000 NPHV. PS1 NSCE. PS1 2.738 CRRA.PS1 2.053 NSCR.PS1 CHV. PS1 201.096 CPSV. PS1 5.060 CP2V. PS1 RCFR.PS1 0.000 RCLC. PS1 0.000 RCRC. PS1 RTDF. PS1 0.000 FPHV. PS1 1403.810 FPDE. PS1 FSCR.PS1 -0.114 AQTF. PS1 0.441 SF6P. PS1 BMCU. PS1 36.328 GDCU. PS1 58.700 EXCU. PS1 FBEF. PS1 35.367 NPGF. PS1 0.998 FPGF. PS1 BSPR.PS1 1.081 MARC. PSI 0.000 XHV. PS1 XP2V. PS1 12.100 XI~2V. PS1 -12.348 RXFR.PS1 RXRC. PS1 0.000 RXAK. PS1 0.000 SHCU. PS1 BSAL.SIG -999.250 CIRN. PS1 -999.250 CIRF. PS1 CIRF. FIL -999.250 DSIG.PSl -999.250 FBAC. PS1 IRAT. FIL -999.250 NBAC. PS1 -999.250 SFNA.PS1 SBNA. PS1 -999.250 SBFA.PS1 -999.250 SFNA.SIG SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PSl SFFC. PS1 -999.250 SIGM. PS1 -999.250 SIBF. SIG TRAT. PS1 -999.250 TRAT. SIG -999.250 TRAT. FIL RDIX. PS1 53708.000 CRNI.PS1 446.307 CRFI.PS1 1481.935 0.583 12.129 0.000 1379.014 161.331 20.121 0.999 200.612 0.000 50.080 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 217 444 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 3O RSCS. PS1 8192.000 CTM. PS1 FICU. PS1 2.319 CACU. PS1 RSXS. PS1 8878.000 TPHI.PS1 WTEP. PS1 84.838 WPRE. PS1 DEPT. 9027.500 CS.PS1 NPDE. PS1 1455.537 NSCE.PS1 AQTM. PS1 1 . 102 CHV. PS1 CM2V. PSI -12. 221 RCFR. PS1 RCAK. PS1 2. 000 RTDF. PS1 FSCE. PS1 1.870 FSCR . PSi HVPV. PS1 160.355 BMCU. PS1 NBEF. PS1 17.597 FBEF. PS1 BSTR.PS1 51.630 BSPR.PS1 XPSV. PS1 5.068 XP2V. PS1 RXLC. PS1 0.000 RXRC. PS1 BSAL.PS1 36.064 BSAL.SIG CIRN. FIL 0.696 CIRF. FIL IRAT. PS1 0.483 IRAT. FIL SFFA.PS1 38.365 SBNA.PS1 SFFA.SIG 0.947 SBNA.SIG SFFA.FIL 37.918 SBNA.FIL SFNC. PS1 41.123 SFFC. PS1 SIGM. SIG 0.673 TRAT. PS1 GR.PS1 202.393 RDIX. PS1 RSCS.PSl 8192.000 CTM. PS1 FICU. PS1 2.334 CACU. PS1 RSXS.PS1 8878.000 TPHI.PS1 WTEP. PS1 72.492 WPRE. PS1 83.496 XTM. PS1 2.500 BUST. PSi -999.250 TPHI.SIG 0.000 1667.224 TENS.PSi 2.717 CRRA. PS1 201.218 CPSV. PS1 O. 000 RCLC. PS1 0.000 FPHV. PS1 0.226 AQTF. PS1 36.163 GDCU. PS1 35.428 NPGF. PS1 1.177 MARC. PSi 12.098 XM2V. PS1 0.000 RXAK. PS1 3.162 CIRN. PS1 1.003 DSIG. PS1 0.481 NBAC. PS1 49.730 SBFA.PS1 2.996 SBFA.SIG 48.877 SBFA.FIL 39.715 SIGM. PS1 1.444 TRAT. SIG 66949.000 CRNI. PS1 79.102 XTM. PS1 2.490 BUST. PSi 49.243 TPHI. SIG 0.000 82.031 3.000 -999.250 1127.000 2.013 5.050 0.000 1402.589 1.102 60.176 1.003 0.000 -12.355 1.000 0.684 1.319 2725.911 40.124 3.991 44.873 39.604 0.031 435.133 78.125 3.000 1.493 TA V. PS1 BUSP. PS1 CCLC. PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT.FIL CRFI.PSl TAV. PS1 BUSP. PS1 CCLC. PS1 95. 031 3. 000 O. 010 1481.935 -0.185 12.151 0.000 1381.112 160.691 21.674 0.996 200.612 0.000 51.666 0.984 3607.309 36. 612 O. 719 36. 820 34.752 1.129 1.424 216.131 95.022 3.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFiE : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 31 FILE HEADER FILE NTrf4BER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS ~ER : 2 DEPTH INCREMENT: 0.5000 FILE SUP~L~RY VENDOR TOOL CODE START DEPTH RST 9529.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 9023.0 13 -AUG-98 8Cl -205 1506 13 -AUG-98 9507.0 9498.0 9056.0 9497.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY RST RESERVOIR SATURATION $ TOOL NUMBER CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 9587.0 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/BORAX WATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 32 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): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: CORRELATED TO PERF RECORD DATED 4/21/96 MADE UP/DOWN TEMP PASS PRIOR TO PUMPING (WELL SHUT IN) MADE A TE~IP PASS WHILE AFTER PUMPING 180 BBLS INITIAL CRUDE AFTER PUMPING 225 BBLS CRUDE AT 5-6 BPM MADE 2 RST BASE PASSES. PUMPED & DISPLACED BORAX WATER AND MADE 3 RST BORAX PASSES MADE A UP/DOWN TEMP PASS AFTER ALL PUMPING MADE A TEMP PASS DOWN AFTER PUMPING HAD STOPPPED FOR 1.25 HR. CHANNEL FROM THE UB3 TO UB4/UCl PERFS CHANArEL FROM THE UB3 TO UB2 PERFS THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 0 66 0 66 0 73 376 66 1 66 73 65 68 O. 5 65 FT 66 2 68 66 0 65 FT 66 68 66 1 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 33 ** SET TYPE - CHAN ** NA~iE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT ?T 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CS PS2F/HR 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS2 LB 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 NPHVPS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 NPDE PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 NSCE PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CRRA PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 NSCR PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 AQTMPS2 S 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CHV PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CPSV PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CP2V PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CM2V PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 RCFR PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 RCLC PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 RCRC PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 RCAKPS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 RTDF PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 FPHVPS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 FPDE PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 FSCE PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 FSCR PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 AQTF PS2 S 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SF6P PS2 PSIG 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 HVPV PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 BMCUPS2 UA 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 GDCU PS2 MA 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 EXCU PS2 UA 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 NBEF PS2 UA 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 FBEF PS2 UA 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 NPGF PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 FPGF PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 BSTR PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 BSPR PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 MARC PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 XHV PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 XPSV PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 XP2V PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 X~I2V PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 RXFR PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 ~C PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 RXRC PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 RXAKPS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SHCU PS2 MA 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL PS2 PPK 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL SIG PPK 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNPS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNFIL 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF FIL 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 34 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DSIG PS2 CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS2 CPS 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT FIL 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 NBAC PS2 CPS 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA PS2 CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA PS2 CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA PS2 CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA PS2 CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA SIG CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA SIG CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA SIG CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA SIG CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA FIL CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA FIL CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA FIL CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA FIL CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF PS2 CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SFNC PS2 CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SFFC PS2 CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS2 CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF SIG CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM SIG CU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT SIG 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT FIL 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS2 GAPI 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 RDIX PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CRNI PS2 K~Z 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CRFI PS2 KHZ 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 RSCS PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CTM PS2 DEGC 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 XTM PS2 DEGC 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 TAV PS2 KV 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 FICU PS2 AMP 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CACU PS2 AMP 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 BUST PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 BUSP PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 RSXS PS2 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS2 PU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI SIG PU 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 CCLC PS2 V 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 WTEP PS2 DEGC 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 WPRE PS2 PSI 1274717 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 35 DEPT. NPDE. PS2 AQTM. PS2 C~2V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 BSTR.PS2 XPSV. PS2 RXLC. PS2 BSAL. PS2 CIRN. FIL IRAT. PS2 SFFA.PS2 SFFA.SIG SFFA.FIL SFNC. PS2 SIGM. SIG GR.PS2 RSCS.PS2 FICU. PS2 RSXS.PS2 WTEP. PS2 9529.500 1456.605 0.661 -12.211 0.000 1.904 160.645 18.926 39.851 5.079 0.000 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 107.669 8463.000 2.339 8878.000 84.960 CS.PS2 NSCE.PS2 CHV. PS2 RCFR.PS2 RTDF. PS2 FSCR.PS2 BMCU. PS2 FBEF. PS2 BSPR.PS2 XP2V. PS2 RXRC.PS2 BSAL.SIG CIRF. FIL IRAT.FIL SBNA.PS2 SBNA.SIG SBNA.FIL SFFC. PS2 TRAT. PS2 RDIX.PS2 CTM. PS2 CACU. PS2 TPHI.PS2 WPRE.PS2 DEPT. 9023.000 CS.PS2 NPDE. PS2 1457.368 NSCE.PS2 AQTM. PS2 1.102 CHV. PS2 CM2V. PS2 -12.191 RCFR.PS2 RCAK. PS2 2.000 RTDF. PS2 FSCE. PS2 1.899 FSCR.PS2 HVPV. PS2 160.173 BMCU. PS2 NBEF. PS2 17.603 FBEF. PS2 BSTR.PS2 73.300 BSPR.PS2 XP5V. PS2 5.074 XP2V. PS2 RXLC. PS2 0.000 RXRC. PS2 BSAL.PS2 39.675 BSAL.SIG CIRN. FIL 0.702 CIRF.FIL IRAT. PS2 0.480 IRAT. FIL SFFA.PS2 38.574 SBNA.PS2 SFFA.SIG 0.904 SBNA.SIG SFFA.FIL 37.581 SBNA.FIL SFNC. PS2 40.104 SFFC.PS2 SIGM. SIG 0.727 TRAT.PS2 GR.PS2 200.267 RDIX. PS2 RSCS.PS2 8463.000 CTM. PS2 FICU. PS2 2.338 CACU. PS2 RSXS.PS2 8878.000 TPHI.PS2 WTEP.PS2 72.511 WPRE. PS2 2580.646 TENS.PS2 2.800 CRRA. PS2 200.612 CP5V. PS2 0.000 RCLC. PS2 0.000 FPHV. PS2 0.554 AQTF. PS2 37.500 GDCU. PS2 38.505 NPGF. PS2 1.054 MARC. PS2 12.100 XM2V. PS2 0.000 RXAK. PS2 -999.250 CIRN. PS2 -999.250 DSIG. PS2 -999.250 NBAC. PS2 -999.250 SBFA. PS2 -999.250 SBFA.SIG -999.250 SBFA.FIL -999.250 SIGM. PS2 -999.250 TRAT. SIG 69377.000 CRNI.PS2 79.590 XTM. PS2 2.480 BUST. PS2 -999.250 TPHI.SIG 0.000 1813.311 TENS. PS2 2.768 CRRA. PS2 200.854 CP5V. PS2 0.000 RCLC. PS2 0.000 FPHV. PS2 -0.082 AQTF. PS2 36.953 GDCU. PS2 35.532 NPGF. PS2 1.166 MARC. PS2 12.108 3qq2V. PS2 0.000 RXAK. PS2 3.504 CIRN. PS2 1.054 DSIG.PS2 0.478 NBAC.PS2 48.566 SBFA.PS2 3.766 SBFA.SIG 47.462 SBFA.FIL 39.245 SIGM. PS2 1.395 TRAT. SIG 83153.000 CRNI.PS2 77.637 XTM. PS2 2.489 BUST. PS2 48.487 TPHI.SIG 0.000 718.000 2.035 5.069 0.000 1398. 927 O. 661 59. 028 0.997 0.000 -12.368 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 442.553 77.148 3.000 -999.250 1150.000 2 019 5 055 0 000 1400 147 1 102 59 837 1. 001 0.000 -12.364 0.000 0.697 2.180 2737.968 43.777 3.920 42.273 38.971 0.031 442.704 77.148 3.000 1.522 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 TAV. PS2 BUSP.PS2 CCLC. PS2 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 TAV. PS2 BUSP. PS2 CCLC. PS2 1486. 817 0 140 12 143 0 000 1380 959 161 587 20 910 0 999 200 612 0 000 49.105 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 217.523 95.031 3.000 0.010 1484.376 0.138 12 143 0 000 1380 769 160 990 21 515 0 998 200 483 0 000 50.471 1.065 3379.289 35.675 0.927 36.246 36.044 1.257 1. 391 219.318 95.012 3.000 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 36 **** FILE TRAILER **** FILE NA~E : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SO?~4ARY VENDOR TOOL CODE START DEPTH RST 9528.0 $ LOG HEADER DATA STOP DEPTH .......... 8996.5 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): TOOL STRING (TOP TO BOTTOM) VE1VDOR TOOL CODE TOOL TYPE GR GA~4A RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 13 -AUG-98 8Cl -205 1506 13-AUG-98 9507.0 9498.0 9056.0 9497.0 TOOL NUMBER ........... CGRS-A RST-A 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 37 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CO~rDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 9587.0 CRUDE/BORAX WATER 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): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 3 TOOL STANDOFF (IN): RE~LCRKS: CORRELATED TO PERF RECORD DATED 4/21/96 MADE UP/DOWN TEMP PASS PRIOR TO PUMPING (WELL SHUT IN) MADE A TEMP PASS WHILE AFTER PUMPING 180 BBLS INITIAL CRUDE AFTER PUMPING 225 BBLS CRUDE AT 5-6 BPM MADE 2 RST BASE PASSES. PUMPED & DISPLACED BORAX WATER AND MADE 3 RST BORAX PASSES MADE A UP/DOWN TEMP PASS AFTER ALL PUMPING MADE A TEMP PASS DOWN AFTER PUMPING HAD STOPPPED FOR 1.25 HR. CHANNEL FROM THE UB3 TO UB4/UCl PERFS CHANNEL FROM THE UB3 TO UB2 PERFS THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 38 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 376 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME 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 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CS BX1 F/HR 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 TENS BX1 LB 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 NPHVBX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 NPDE BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 NSCE BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CRRA BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 NSCR BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 AQTMBX1 S 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CHV BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CPSV BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CP2V BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CM2V BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 RCFR BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 RCLC BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 RCRC BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 RCAKBX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 RTDF BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 FPHVBX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 FPDE BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 FSCE BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 FSCR BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 AQTF BX1 S 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SF6P BX1 PSIG 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 HVPV BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 BMCU BX1 UA 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PA GE: 39 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) GDCU BX1 MA 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 EXCU BX1 UA 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 NBEF BX1 UA 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 FBEF BX1 UA 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 NPGF BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 FPGF BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 BSTR BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 BSPR BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 MARC BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 XHV BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 XPSV BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 XP2V BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 XM2V BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 RXFR BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 RXLC BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 RXRC BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 RXAKBX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SHCU BX1 MA 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL BX1 PPK 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL SIG PPK 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNBX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNFIL 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF FIL 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 DSIG BX1 CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC BX1 CPS 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT FIL 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 NBAC BX1 CPS 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA BX1 CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA BX1 CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA BX1 CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA BX1 CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA SIG CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA SIG CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA SIG CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA SIG CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA FIL CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA FIL CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA FIL CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA FIL CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF BX1 CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SFNC BX1 CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SFFC BX1 CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM BX1 CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF SIG CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM SIG CU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT SIG 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT FIL 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 GR BX1 GAPI 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 40 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) RDIX BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CRNI BX1 KHZ 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CRFI BX1 KHZ 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 RSCS BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CTM BX1 DEGC 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 XTM BX1 DEGC 1274717 O0 000 O0 0 9 1 1 4 68 . 0000000000 TAV BX1 KV 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 FICU BX1 AMP 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CACU BX1 AMP 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 BUST BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 BUSP BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 RSXS BX1 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI BX1 PU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI SIG PU 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 CCLC BX1 V 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 WTEP BX1 DEGC 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 WPREBX1 PSI 1274717 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE.BX1 1454.507 NSCE.BX1 AQTM. BX1 O. 661 CHV. BX1 CM2V. BX1 -12.172 RCFR.BX1 RCAK.BX1 O. 000 RTDF.BX1 FSCE.BX1 1.899 FSCR.BX1 HVPV. BX1 160.645 BMCU. BX1 ATBEF. BX1 19.336 FBEF. BX1 BSTR.BX1 43.800 BSPR.BX1 XPSV. BX1 5.069 XP2V. BX1 RXLC.BX1 0.000 RXRC.BX1 9528.000 CS.BX1 1842 375 TENS.BX1 832.000 NPHV. BX1 1484.376 2 728 CRRA.BX1 2.064 NSCR.BX1 0.149 201 339 CPSV. BX1 5.050 CP2V. BX1 12.143 0 000 RCLC.BX1 0.000 RCRC.BX1 0.000 0 000 FPHV. BX1 1396.485 FPDE.BX1 1382.638 0.661 SF6P.BX1 59.356 EXCU.BX1 0.990 FPGF. BX1 -0 116 AQTF.BX1 38.379 GDCU. BX1 39.911 NPGF.BX1 1.057 MARC.BX1 0.000 XHV. BX1 201 12.100 ~2V. BX1 -12.368 RXFR.BX1 0 0.000 RXAK.BX1 0.000 SHCU. BX1 52 BSAL.BX1 -999.250 BSAL.SIG -999.250 CIRN. BX1 -999.250 CIRF.BX1 -999 163 378 20 121 0 998 096 000 357 250 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.BX1 -999.250 FBAC.BX1 -999.250 IRAT.BX1 -999.250 IRAT. FIL -999.250 NBAC.BX1 -999.250 SFNA.BX1 -999.250 SFFA.BX1 -999.250 SBNA.BX1 -999.250 SBFA.BX1 -999.250 SFNA.SIG -999.250 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL -999.250 SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. BX1 -999.250 SFNC.BX1 -999.250 SFFC.BX1 -999.250 SIGM. BX1 -999.250 SIBF. SIG -999.250 SIGM. SIG -999.250 TRAT.BX1 -999.250 TRAT. SIG -999.250 TRAT. FIL -999.250 GR.BX1 40.376 RDIX. BX1 6276.000 CRNI.BX1 456.916 CRFI.BX1 221.362 RSCS.BX1 8459.000 CTM. BX1 84.473 XTM. BX1 84.473 TAV. BX1 95.031 FICU. BX1 2.295 CACU. BX1 2.500 BUST.BX1 3.000 BUSP. BX1 3.000 RSXS.BX1 8878.000 TPHI.BX1 -999.250 TPHI.SIG -999.250 CCLC.BX1 0.000 WTEP.BX1 84.791 WPRE.BX1 0.000 DEPT. 8996.500 CS.BX1 1858.359 TENS.BX1 1185.000 NPHV. BX1 1472.169 NPDE.BX1 1453.477 NSCE.BX1 2.798 CRRA.BX1 2.090 NSCR.BX1 0.208 AQTM. BX1 0.441 CHV. BX1 200.854 CP5V. BX1 5.050 CP2V. BX1 12.129 CM2V. BX1 -12.231 RCFR.BX1 0.000 RCLC.BX1 0.000 RCRC. BX1 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 41 RCAK. BX1 0.000 RTDF. BX1 FSCE.BX1 1.927 FSCR.BX1 HVPV. BX1 160.254 BMCU. BX1 ArBEF. BX1 18.059 FBEF. BX1 BSTR.BX1 52.971 BSPR.BX1 XPSV. BX1 5.076 XP2V. BX1 R2LLC.BX1 0.000 RXRC.BX1 BSAL.BX1 158.062 BSAL.SIG CIRN. FIL 0.487 CIRF. FIL IRAT. BX1 0.466 IRAT.FIL SFFA.BX1 35.042 SBNA.BX1 SFFA.SIG 0.868 SBNA.SIG SFFA.FIL 35.757 SBNA.FIL SPIVC.BX1 34.926 SFFC.BX1 SIGM. SIG 0.871 TRAT. BX1 GR.BX1 210.210 RDIX. BX1 RSCS.BX1 8459.000 CTM. BX1 FICU. BX1 2.373 CACU. BX1 RSXS.BX1 8878.000 TPHI.BX1 WTEP.BX1 61.977 WPRE.BX1 0.000 0.123 37.031 37.751 1.245 12.118 0 000 3 978 0 888 0 467 65 743 3 385 60 880 36 392 1 183 20318.000 68.848 2.494 41.174 0.000 FPHV. BX1 AQTF. BX1 GDCU. BX1 NPGF. BX1 MARC. BX1 XM2 V. BX1 RXAK. BX1 CIRN. BX1 DSIG. BX1 NBAC. BX1 SBFA . BX1 SBFA. SIG SBFA. FIL SIGM. BX1 TRAT. SIG CRNI. BX1 XTM. BX1 BUST. BX1 TPHI. SIG 1396.485 FPDE. BX1 0.441 SF6P.BX1 60.143 EXCU. BX1 1.005 FPGF. BX1 0.000 XHV. BX1 -12.366 RXFR.BX1 0.000 SHCU. BX1 0.508 CIRF. BX1 -0.634 FBAC.BX1 2767.558 SFNA.BX1 51.559 SFNA.SIG 3.990 SFNA.FIL 50.622 SIBF. BX1 36.370 SIBF. SIG 0.031 TRAT. FIL 453. 045 CRFI. BX1 68. 392 TAV. BX1 3. 000 BUSP. BX1 1.578 CCLC.BX1 1380.006 156.657 21.015 1.000 200.305 0.000 52.682 0.884 3530.125 32.563 0.813 33.838 81.633 1. 648 1. 181 216. 725 95.012 3.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE ·FLIC VERSION .O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NA~IE : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUM~ER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFiBER: 4 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 42 FILE SU2~4ARY VENDOR TOOL CODE START DEPTH RST 9535.5 $ LOG HEADER DATA STOP DEPTH 9025.5 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): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) '. FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): M-~TRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 13 -AUG- 98 8Cl -205 1506 13 -AUG-98 9507.0 9498.0 9056.0 9497.0 TOOL NUMBER CGRS-A RST-A 8.500 9587.0 CRUDE/BORAX WATER THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 43 NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: CORRELATED TO PERF RECORD DATED 4/21/96 MADE UP/DOWN TEMP PASS PRIOR TO PUMPING (WELL SHUT IN) MADE A TE~P PASS WHILE AFTER PUMPING 180 BBLS INITIAL CRUDE AFTER PUMPING 225 BBLS CRUDE AT 5-6 BPM MADE 2 RST BASE PASSES. PUMPED & DISPLACED BORAX WATER AND MADE 3 RST BORAX PASSES MADE A UP/DOWN TE~P PASS AFTER ALL PUMPING MADE A TEMP PASS DOWN AFTER PUMPING HAD STOPPPED FOR 1.25 HR. CHANNEL FROM THE UB3 TO UB4/UCl PERFS CHANNEL FROM THE UB3 TO UB2 PERFS THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 376 4 66 1 5 66 6 73 7 8 9 11 12 13 14 15 16 0 0.5 FT 2 65 68 65 66 68 66 0 65 FT 66 68 66 1 66 1 ** SET TYPE - CHAN ** NAME 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 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CS BX2 F/HR 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 TENS BX2 LB 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 NPHVBX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 44 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUN~ SAMP ELE~ CODE (HEX) NPDE BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 NSCE BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CRRABX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 NSCR BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 AQTMBX2 S 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CHV BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CPSV BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CP2V BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CM2V BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 RCFR BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 RCLC BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 RCRC BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 RCAKBX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 RTDF BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 FPHVBX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 FPDE BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 FSCE BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 FSCR BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 AQTF BX2 S 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SF6P BX2 PSIG 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 HVPV BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 BMCU BX2 UA 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 GDCU BX2 MA 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 EXCU BX2 UA 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 NBEF BX2 UA 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 FBEF BX2 UA 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 NPGF BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 FPGF BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 BSTR BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 BSPR BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 MARC BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 3fHV BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 XPSV BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 XP2V BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 XM2V BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 RXFR BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 RXLC BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 RXRC BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 RXAKBX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SHCU BX2 MA 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 BSALBX2 PPK 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 BSALSIG PPK 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CIRNBX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CIRF BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CIRNFIL 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CIRF FIL 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 DSIG BX2 CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC BX2 CPS 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 IRAT BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 IRAT FIL 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 NBAC BX2 CPS 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE 45 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) SFNA BX2 CU 1274717 O0 000 00 0 10 1 1 4 68 0000000000 SFFA BX2 CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA BX2 CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA BX2 CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SFNA SIG CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SFFA SIG CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA SIG CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA SIG CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SFNA FIL CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SFFA FIL CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA FIL CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA FIL CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SIBF BX2 CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SFNC BX2 CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SFFC BX2 CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM BX2 CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SIBF SIG CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM SIG CU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT SIG 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT FIL 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 GR BX2 GAPI 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 RDIX BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CRNI BX2 KHZ 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CRFI BX2 KHZ 1274717 O0 000 O0 0 10 I 1 4 68 0000000000 RSCS BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CTM BX2 DEGC 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 XTM BX2 DEGC 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 TAV BX2 KV 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 FICU BX2 AMP 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CACU BX2 AMP 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 BUST BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 BUSP BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 RSXS BX2 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI BX2 PU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI SIG PU 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 CCLC BX2 V 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 WTEP BX2 DEGC 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 WPREBX2 PSI 1274717 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 9535.500 CS.BX2 1908.802 TENS.BX2 826.000 NPHV. BX2 NPDE.BX2 1452.066 NSCE.BX2 2.861 CRRA.BX2 2.075 NSCR.BX2 AQTM. BX2 0.661 CHV. BX2 200.370 CPSV. BX2 5. 060 CP2V. BX2 CM2V. BX2 -12. 270 RCFR. BX2 O. 000 RCLC. BX2 O. 000 RCRC. BX2 RCAK.BX2 1 . 000 RTDF. BX2 O. 000 FPHV. BX2 1398. 927 FPDE. BX2 FSCE.BX2 2.033 FSCR.BX2 -0.093 AQTF. BX2 0.661 SF6P.BX2 HVPV. BX2 160.401 BMCU. BX2 37.500 GDCU. BX2 59.028 EXCU. BX2 1477.052 0.369 12.158 0.000 1379.586 158.005 20.515 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 46 NBEF. BX2 BSTR . BX2 XP5 V. BX2 RXL C . BX2 BSAL. BX2 CIRN. FIL IRA T. BX2 SFFA. BX2 SFFA. SIG SFFA. FIL SFNC. BX2 SIGM. SIG GR. BX2 RSCS. BX2 FICU. BX2 RSXS. BX2 WTEP. BX2 DEPT. NPDE. BX2 AQTM. BX2 CM2 V. BX2 R CAK. BX2 FSCE. BX2 HVPV. BX2 NBEF. BX2 BSTR . BX2 XPSV. BX2 RXLC. BX2 BSAL. BX2 CIRN. FIL IRA T. BX2 SFFA. BX2 SFFA. SIG SFFA. FIL SFNC. BX2 SIGM. SIG GR.BX2 RSCS. BX2 FI CU. BX2 RSXS. BX2 WTEP. BX2 18.820 45.048 5 069 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 253.806 8463.000 2.363 8878.000 84.801 9025.500 1451.913 1.102 -12.240 0.000 1.949 160.400 18 947 55 838 5 076 0 000 161 680 0 488 0 469 39. 023 1.101 37. 875 39.542 0.946 206.740 8463.000 2.348 8878.000 63.161 FBEF. BX2 BSPR.BX2 XP2V. BX2 RXRC.BX2 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.BX2 SBNA.SIG SBNA.FIL SFFC.BX2 TRAT.BX2 RDIX. BX2 CTM. BX2 CACU. BX2 TPHI.BX2 WPRE.BX2 CS.BX2 NSCE.BX2 CHV. BX2 RCFR.BX2 RTDF. BX2 FSCR . BX2 BMCU. BX2 FBEF. BX2 BSPR.BX2 XP2V. BX2 RXRC.BX2 BSAL.SIG CIRF. FIL IRAT.FIL SBNA.BX2 SBNA.SIG SBNA.FIL SFFC.BX2 TRAT. BX2 RDIX. BX2 CTM. BX2 CACU. BX2 TPHI. BX2 WPRE.BX2 39.057 1.191 12.100 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 22193 000 69 336 2 500 -999.250 0.000 1875.045 2.804 200.854 0.000 0.000 0.040 37.754 39.539 1.023 12.112 0.000 3.951 0.839 0 470 60 839 4 222 62 721 38 688 1 243 35450000 69.336 2.499 46.385 0.000 NPGF. BX2 MARC.BX2 2242V. BX2 RXAK. BX2 CIRN. BX2 DSIG.BX2 NBAC.BX2 SBFA.BX2 SBFA. SIG SBFA.FIL SIGM. BX2 TRAT. SIG CRNI.BX2 XTM. BX2 BUST. BX2 TPHI.SIG TENS.BX2 CRRA.BX2 CPSV. BX2 RCLC.BX2 FPHV. BX2 AQTF. BX2 GDCU. BX2 NPGF. BX2 MARC. BX2 X~2V. BX2 R3fAK. BX2 CIRN. BX2 DSIG.BX2 NBAC. BX2 SBFA.BX2 SBFA.SIG SBFA.FIL SIGM. BX2 TRAT. SIG CRNI.BX2 XTM. BX2 BUST. BX2 TPHI.SIG 1.001 0.000 -12.328 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 443.245 67.383 3.000 -999.250 1165.000 2.087 5.069 0.000 1402.589 1.102 59.837 1.002 0.000 -12.366 0.000 0.476 0.020 2750.089 46.512 4.282 49.448 38.795 0.037 437.003 68.913 3.000 1.837 FPGF. BX2 XHV. BX2 RXFR.BX2 SHCU. BX2 CIRF. BX2 FBAC.BX2 SFNA.BX2 SFNA.SIG SFNA.FIL SIBF. BX2 SIBF. SIG TRAT. FIL CRFI. BX2 TA V. BX2 BUSP. BX2 CCLC.BX2 NPHV. BX2 NSCR.BX2 CP2V. BX2 RCRC. BX2 FPDE.BX2 SF6P.BX2 EXCU. BX2 FPGF.BX2 XHV. BX2 RXFR.BX2 SHCU. BX2 CIRF.BX2 FBAC.BX2 SFNA.BX2 SFNA.SIG SFNA.FIL SIBF.BX2 SIBF. SIG TRAT. FIL CRFI.BX2 TAV. BX2 BUSP.BX2 CCLC.BX2 0.990 200.612 0.000 51.381 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 213.582 95.031 3.000 0.000 1475. 831 0 136 12 173 0 000 1380 426 156 248 20 989 0 994 200 370 0.000 52.075 O. 850 3630. 271 36. 465 1.178 37.280 83.135 1.645 1.250 209.406 94.974 3.000 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 47 **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9527.0 9021.0 RST $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 13 -AUG-98 8Cl -205 1506 13-AUG-98 9507.0 9498.0 9056.0 9497.0 TOOL NUMBER CGRS-A RST-A 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 48 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 9587.0 CRUDE/BORAX WATER 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): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: CORRELATED TO PERF RECORD DATED 4/21/96 MADE UP/DOWN TEMP PASS PRIOR TO PUMPING (WELL SHUT IN) MADE A TEMP PASS WHILE AFTER PUMPING 180 BBLS INITIAL CRUDE AFTER PUMPING 225 BBLS CRUDE AT 5-6 BPM MADE 2 RST BASE PASSES. PUMPED & DISPLACED BORAX WATER AND MADE 3 RST BORAX PASSES MADE A UP/DOWN TEMP PASS AFTER ALL PUMPING MADE A TE~IP PASS DOWN AFTER PUMPING HAD STOPPPED FOR 1.25 HR. CHANNEL FROM THE UB3 TO UB4/UCl PERFS CHANNEL FROM THE UB3 TO UB2 PERFS THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 49 ** 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 73 376 66 1 66 0.5 FT 2 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 CS BX3 F/HR 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 TENS BX3 LB 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 NPHVBX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 NPDE BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 NSCE BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 CRRABX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 NSCR BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 AQTMBX3 S 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 CHV BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 CPSV BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 CP2V BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 ~2V BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 RCFR BX3 1274717 O0 000 O0 0 I1 1 1 4 68 0000000000 RCLC BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 RCRC BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 RCAKBX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 RTDF BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 FPHVBX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 FPDE BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 FSCE BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 FSCR BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 AQTF BX3 S 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SF6P BX3 PSIG 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 HVPV BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 BMCU BX3 UA 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center S-NOV-1998 15:24 PAGE: $ 0 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) GDCU BX3 MA 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 EXCU BX3 UA 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 NBEF BX3 UA 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 FBEF BX3 UA 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 NPGF BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 FPGF BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 BSTR BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 BSPR BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 MARC BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 XArV BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 XPSV BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 XP2V BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 X~2V BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 RXFR BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 RXLC BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 RXRC BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 RXAKBX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SHCU BX3 MA 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 BSAL BX3 PPK 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 BSAL SIG PPK 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 CIRNBX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 CIRF BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 CIRNFIL 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 CIRF FIL 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 DSIG BX3 CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC BX3 CPS 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 IRAT BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 IRAT FIL 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 NBAC BX3 CPS 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SFNA BX3 CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SFFA BX3 CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SBNA BX3 CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SBFA BX3 CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SFNA SIG CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SFFA SIG CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SBNA SIG CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SBFA SIG CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SFNA FIL CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SFFA FIL CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SBNA FIL CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SBFA FIL CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SIBF BX3 CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SFNC BX$ CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SFFC BX3 CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM BX3 CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SIBF SIG CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM SIG CU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT BX3 1274717 O0 000 00 0 11 1 1 4 68 0000000000 TRAT SIG 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT FIL 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 GR BX3 GAPI 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1998 15:24 PAGE: 51 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) RDIX BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 CRNI BX3 KHZ 1274717 O0 000 O0 0 11 1 1 CRFI BX3 K~Z 1274717 O0 000 O0 0 11 1 1 RSCS BX3 1274717 O0 000 O0 0 11 1 1 CTM BX3 DEGC 1274717 O0 000 O0 0 11 1 1 XTM BX3 DEGC 1274717 O0 000 O0 0 11 1 1 TAV BX3 KV 1274717 O0 000 O0 0 11 1 1 FICU BX3 AMP 1274717 O0 000 O0 0 11 1 1 CACU BX3 AMP 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 BUST BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 BUSP BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 RSXS BX3 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI BX3 PU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI SIG PU 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 CCLC BX3 V 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 WTEP BX3 DEGC 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 WPREBX3 PSI 1274717 O0 000 O0 0 11 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ** DATA ** DEPT. 9527.000 NPDE.BX3 1451.379 NSCE. BX3 2.823 CRRA.BX3 2 AQTM. BX3 0.441 CHV. BX3 201.339 CPSV. BX3 5 CM2V. BX3 -12.211 RCFR.BX3 0.000 RCLC.BX3 0 RCAK.BX3 2.000 RTDF.BX3 0.000 FPHV. BX3 1401 FSCE.BX3 2.014 FSCR.BX3 0.030 AQTF.BX3 HVPV. BX3 160.401 BMCU. BX3 38.086 GDCU. BX3 NBEF.BX3 18.914 FBEF.BX3 39.879 NPGF.BX3 BSTR.BX3 42 893 BSPR.BX3 1.141 MARC. BX3 XPSV. BX3 5 RXLC.BX3 0 BSAL.BX3 -999 CIRN. FIL -999 IRAT. BX3 -999 SFFA.BX3 -999 SFFA.SIG -999 SFFA.FIL -999 SFNC.BX3 -999 SIGM. SIG -999 CS.BX3 1778.656 TENS.BX3 793 000 NPHV. BX3 1474.610 108 NSCR.BX3 0.548 030 CP2V. BX3 12.114 000 RCRC.BX3 0 000 368 FPDE.BX3 1379 167 0 441 SF6P.BX3 157 493 60 340 EXCU. BX3 20 515 0.992 FPGF. BX3 1 003 0.000 XHV. BX3 200 370 079 XP2V. BX3 12.114 X~42V. BX3 -12.368 RXFR.BX3 0 000 000 RXRC.BX3 0.000 RXAK. BX3 0.000 SHCU. BX3 50 406 250 BSAL.SIG -999.250 CIRN. BX3 -999.250 CIRF. BX3 -999.250 250 CIRF. FIL -999.250 DSIG.BX3 -999.250 FBAC. BX3 -999.250 250 IRAT. FIL -999.250 NBAC.BX3 -999.250 SFNA.BX3 -999.250 250 SBNA.BX3 -999.250 SBFA.BX3 -999.250 SFNA.SIG -999.250 250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL -999.250 250 SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. BX3 -999.250 250 SFFC.BX3 -999.250 SIGM. BX3 -999.250 SIBF. SIG -999.250 250 TRAT. BX3 -999.250 TRAT. SIG -999.250 TRAT. FIL -999.250 210.268 95.031 3.000 0.010 GR.BX3 235.526 RDIX.BX3 37119.000 CRNI.BX3 443.343 CRFI.BX3 RSCS.BX3 8463.000 CTM. BX3 69.824 XTM. BX3 68.848 TAV. BX3 FICU. BX3 2.378 CACU. BX3 2.480 BUST. BX3 3.000 BUSP.BX3 RSXS.BX3 8878.000 TPHI.BX3 -999.250 TPHI.SIG -999.250 CCLC.BX3 WTEP.BX3 84.726 WPRE.BX3 0.000 DEPT. 9021.000 CS.BX3 1870.915 TENS.BX3 1161.000 NPHV. BX3 1474.610 NPDE.BX3 1451.608 NSCE. BX3 2.800 CRRA.BX3 2.102 NSCR.BX3 -0.191 AQTM. BX3 1.322 CHV. BX3 200.491 CPSV. BX3 5.055 CP2V. BX3 12.151 CM2V. BX3 -12.250 RCFR.BX3 0.000 RCLC.BX3 0.000 RCRC. BX3 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center RCAK. BX3 FSCE. BX3 HVPV. BX3 NBEF. BX3 BSTR.BX3 XP5 V. BX3 RXLC. BX3 BSAL. BX3 CIRN. FIL IR~T. BX3 SFFA. BX3 SFFA. SIG SFFA. FIL SFNC. BX3 SIGM. SIG GR. BX3 RSCS. BX3 FICU. BX3 RSXS. BX3 WTEP. BX3 O. 000 1. 912 160. 417 19. 010 57.484 5. 073 O. 000 163. 917 0.468 O. 472 36.282 1. 053 36. 363 37.399 0 872 214 883 8463 000 2 353 8878 000 62 805 RTDF. BX3 FSCR. BX3 BMCU. BX3 FBEF. BX3 BSPR. BX3 XP2V. BX3 RXRC. BX3 BSAL. SIG CIRF. FIL IRA T. FIL SBNA. BX3 SBNA. SIG SBNA. FIL SFFC.BX3 TRAT. BX3 RD IX. BX3 CTM. BX3 CACU. BX3 TPHI. BX3 WPRE. BX3 5-NOV-1998 15:24 0.000 FPHV. BX3 -0.006 AQTF.BX3 37.929 GDCU. BX3 39.968 NPGF. BX3 1.105 MARC.BX3 12.112 X~2V. BX3 0.000 RXAK. BX3 3.991 CIRN. BX3 0.837 DSIG.BX3 0.473 NBAC. BX3 61.482 SBFA.BX3 4.475 SBFA.SIG 64.482 SBFA.FIL 36.979 SIGM. BX3 1.195 TRAT. SIG 50433.000 CRNI.BX3 69.336 XTM. BX3 2.495 BUST.BX3 43.913 TPHI.SIG 0.000 1400.147 FPDE.BX3 1.322 SF6P.BX3 60.165 EXCU. BX3 1.008 FPGF. BX3 0.000 XHV. BX3 -12.377 RXFR.BX3 0.000 SHCU. BX3 0.473 CIRF. BX3 1.293 FBAC.BX3 2700.499 SFNA.BX3 56.442 SFNA.SIG 4.545 SFNA.FIL 55.756 SIBF.BX3 36.748 SIBF. SIG 0.035 TRAT. FIL 437.238 CRFI.BX3 68. 685 TAV. BX3 3 . 000 BUSP. BX3 1. 783 CCLC. BX3 PAGE: 52 1380.082 156.043 20.515 1.007 200.321 0.000 51.945 0.793 3534.582 34.092 1.147 35.721 84.068 1.667 1.211 208.023 95.003 3.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAM~ : EDIT DATE : 98/11/ 5 ORIGIN : FLIC TAPE NAME : 98563 CONTINUATION # : 1 PREVIOUS TAPE : COMI4ENT : ARCO ALASKA, P2-20, POINT MCINTYRE, API #50-029-22664-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 5 ORIGIN : FLIC REEL NAFiE : 98563 CONTINUATION # : PREVIOUS REEL : COFg4~2VT : ARCO ALASKA, P2-20, POINT MCINTYRE, API #50-029-22664-00 Sperry-Sun Drilling Services LIS Scan Utility Thu Mar 27 18:01:24 1997 Reel Header Service name ............. LISTPE Date ..................... 97/03/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/03/27 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIStening Library. Services TAPE H~DER%u- PRUDHOE BAY UNIT D/~D LOGSDo~O~ WELL N~E: API NUMBER: OPE~TOR: LOGGING COMPLY: TAPE CR~TION DATE: JOB DAT~ JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: DS 05-40 500292270700 ARCO ALASKA, INC. Scientific Technical SPERRY-SUN DRILLING SERVICES 2 7 -MAR- 9 7 MWD RUN 4 MWD RUN 5 MWD RUN 6 AK-MM-60140 AK-MM-60140 AK-MM-60140 M. GABEL M. HALL M. HALL R. BORDES R. BORDES R. BORDES JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MWD RUN 8 MWD RUN 9 AK-MM-60140 AK-MM-60140 AK-MM-60140 M. HALL M. HALL M. GABEL R. BORDES R. BORDES R. BORDES JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: MWD RUN 10 MWD RUN 11 MWD RUN 12 AK-MM-60140 AK-MM-60140 AK-MM-60140 M. GABEL M. GABEL M. GABEL R. BORDES R. BORDES J. HABERTHUR 32 liN 15E FSL: 2321 FEL: 4109 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 71.10 DERRICK FLOOR: 68.30 GROUND LEVEL: 33.70 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 9.875 117.0 2ND STRING 9.875 7.625 3890.0 3RD STRING 6.750 5.500 9631.0 PRODUCTION STRING 4.750 10987.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 THROUGH 3 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 4 THROUGH 12 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 4. THERE IS A GAP IN RATE OF PENETRATION (SROP) DATA DURING MWD RUN 4 FROM 5926'MD, 5445'TVD TO 5976'MD, 5489'TVD. 5. THERE IS A GAP IN GAMMA RAY (SGRD) DATA DURING MWD RUN 4 FROM 5841'MD, 5370'TVD TO 5881'MD, 5405'TVD. 6. THERE ARE INTERMITTENT GAMMA RAY (SGRD) DATA GAPS IN RUN 12 DUE TO LCM IN THE MUD PACKING OFF MWD SENSORS FROM 10600'MD, 9020'TVD TO 10909'MD, 9050'TVD. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10987'MD, 9058'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5818.5 10894.5 ROP 5903.5 10989.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 5818 9670 9671 9673 9680 9685 9734 9736 9739 9753 9755 9757 9761 9765 9768 9771 9782 9788 9790 9802 9806 9817 9821 9839 9842 9846 9847 9850 9854 9870 9872 9878 9880 9884 9904 9907 9909 9912 9948 9950 9958 9960 9975 9987 9992 10011. 10017. 10019 10028 10034 10041 10094 10099 10104 10114. 10171 10179 10183 10188 10190 10194 10196. GR 5821.0 9672.5 9674.0 9677.0 9683.0 9689 0 9732 5 9736 5 9739 0 9756 0 9758 5 9761 0 9764 5 9768 5 9770 5 9773 0 9783 0 9790 0 9792 0 9804 0 9807 5 9818 5 9824 0 9840 0 9843 0 9847 5 9849.0 9850 5 9855 0 9871 5 9873 5 9880 0 9881 5 9886 5 9905 5 9908 5 9910 5 9913 5 9949 0 9951.5 9959.0 9960.5 9979.0 9988 5 9994 5 10013 0 10017 5 10019 0 10030 5 10035 0 10042 0 10093 5 10098 0 10104 0 10112.5 10171.0 10179.0 10184.0 10189.5 10192.5 10194.5 10197.0 EQUIVALENT UNSHIFTED DEPTH -- 10293 0 10308 10312 10315 10318 10322 10327 10330 10348 10351 10353 10390 10392 10393 10396 10400 10403 10405 10409 10417 10423 10430 10435 10442 10450 10458 10461 10470 10470 10475 10585 10893 10990 $ 10293.0 10309.0 10313.0 10317.5 10320 5 10326 0 10328 5 10331 0 10348 0 10351 5 10353 5 10390 0 10392 0 10393 5 10396 5 10400 5 10403 0 10405.5 10409 0 10416 0 10423 0 10430 5 10436 0 10442 5 10448 5 10459 5 10463 5 10470 0 10471 0 10476 0 10584 5 10890 0 10987 0 MERGED DATA SOURCE PBU TOOL CODE MWD 4 MWD 5 MWD 6 MWD 7 MWD 8 MWD 9 MWD 10 MWD 11 MWD 12 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record BIT RUN NO MERGE TOP 5906 0 6633 0 8293 0 8551 0 9642 0 9661 0 9822 0 10316 0 10667 0 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 6633 0 8293 0 8551 0 9642 0 9661 0 9822 0 10316 0 10667 0 10987 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 Name Min Max Mean Nsam DEPT 5818.5 10990 8404.25 10344 ROP 4.1966 2239.45 75.9117 10073 GR 11.3314 568.46 77.2731 9574 First Reading 5818.5 5903.5 5818.5 Last Reading 10990 10990 10894.5 First Reading For Entire File .......... 5818.5 Last Reading For Entire File ........... 10990 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5821.0 6548.5 ROP 5906.0 6632.5 $ LOG HEADER DATA DATE LOGGED: 28-OCT-96 SOFTWARE SURFACE SOFTWARE VERSION: 4.88 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 6633.0 TOP LOG INTERVAL (FT) : 5906.0 BOTTOM LOG INTERVAL (FT) : 6633.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 27.6 29.4 TOOL NUMBER NGP 94 6.750 6.8 LSND 10.20 42.0 9.4 800 7.2 .000 .000 .000 .000 39.5 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 5821 6632.5 6226.75 1624 5821 GR 11.3314 88.3276 53.5111 1374 5821 RO? 17.7259 718.3 113.57 1353 5906 Last Reading 6632.5 6548.5 6632.5 First Reading For Entire File .......... 5821 Last Reading For Entire File ........... 6632.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6490.0 8216.0 ROP 6560.0 8292.5 $ LOG HEADER DATA DATE LOGGED: 31-OCT-96 SOFTWARE SURFACE SOFTWARE VERSION: 4.88 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 8293.0 TOP LOG INTERVAL (FT) : 6633.0 BOTTOM LOG INTERVAL (FT) : 8293.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 23.6 MAXIMUM ANGLE: 32.8 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): TOOL NUMBER NGP 159 6.750 6.8 LSND 10.20 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (CS): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 45.0 9.3 1100 6.6 .000 .000 .000 .000 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 49.5 First Name Min Max Mean Nsam Reading DEPT 6490 8292.5 7391.25 3606 6490 GR 22.0238 151.115 73.0187 3453 6490 ROP 6.5217 2191.69 115.587 3466 6560 Last Reading 8292.5 8216 8292.5 First Reading For Entire File .......... 6490 Last Reading For Entire File ........... 8292.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8217.5 ROP 8269.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8482.0 8550.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 01-NOV-96 4.88 5.46 MEMORY 8551.0 8293.0 8551.0 27.4 31.9 TOOL NUMBER NGP 94 6.750 6.8 LSND 10.20 45.0 9.3 1100 6.6 .000 .000 .000 .000 49.5 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8217.5 8550.5 8384 667 8217.5 GR 20.851 103.884 77.618 530 8217.5 ROP 9.3264 4113.28 161.337 563 8269.5 Last Reading 8550.5 8482 8550.5 First Reading For Entire File .......... 8217.5 Last Reading For Entire File ........... 8550.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUN/WARY VENDOR TOOL CODE START DEPTH GR 8475.0 ROP 8553.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9564.0 9641.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 04-NOV-96 4.88 5.46 MEMORY 9642.0 8551.0 9642.0 21.3 33.8 TOOL NUMBER NGP 94 6.750 6.8 LSND 10.20 43.0 9.6 8OO 5.6 .000 .000 .000 .000 63.3 .6 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8475 9641.5 9058.25 2334 8475 GR 19.83 568.46 129.631 2179 8475 ROP 4.5472 600 56.5449 2177 8553.5 Last Reading 9641.5 9564 9641.5 First Reading For Entire File .......... 8475 Last Reading For Entire File ........... 9641.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 9610.0 9661.0 $ LOG HEADER DATA DATE LOGGED: 07-NOV-96 SOFTWARE SURFACE SOFTWARE VERSION: 4.88 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9661.0 TOP LOG INTERVAL (FT) : 9642.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9661.0 26.9 26.9 TOOL NUMBER NGP 159 4.750 4.8 XANVI S 9.70 32.0 8.4 600 10.8 .000 .000 .000 .000 -17.7 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 8 FT/H 4 1 68 4 2 First Name Min Max Mean Nsam Reading DEPT 9610 9661 9635.5 103 9610 ROP 11.5002 5899.22 356.528 103 9610 Last Reading 9661 9661 First Reading For Entire File .......... 9610 Last Reading For Entire File ........... 9661 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9561.0 9766.0 ROP 9617.0 9822.5 $ LOG HEADER DATA DATE LOGGED: 09-NOV-96 SOFTWARE SURFACE SOFTWARE VERSION: 4.88 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9822.0 TOP LOG INTERVAL (FT) : 9661.0 BOTTOM LOG INTERVAL (FT) : 9822.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 27.1 MAXIMUM ANGLE: 42.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE A_ND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: TOOL NUMBER NGP 159 4.750 4.8 XANVI S MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.80 49.0 9.0 10300 5.4 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 AAPI 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 53.9 First Name Min Max Mean Nsam Reading DEPT 9561 9822.5 9691.75 524 9561 GR 15.479 108.561 23.9065 411 9561 ROP 4.1966 264.231 58.257 412 9617 Last Reading 9822.5 9766 9822.5 First Reading For Entire File .......... 9561 Last Reading For Entire File ........... 9822.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9735.5 ROP 9782.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10262.5 10316.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): il-NOV-96 4.88 5.46 MEMORY 10316.0 9822.0 10316.0 52.7 84.7 TOOL NUMBER NGP 159 4.750 4.8 XANVI S 8.90 53.0 8.8 12000 5.1 .000 .000 .000 .000 58.6 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 10 AAPI 4 1 68 4 2 ROP MWD 10 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9735.5 10316 10025.8 1162 9735.5 GR 14.4862 169.587 42.7322 1055 9735.5 ROP 7.7778 4327.73 120.907 1068 9782.5 Last Reading 10316 10262.5 10316 First Reading For Entire File .......... 9735.5 Last Reading For Entire File ........... 10316 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10247.5 ROP 10298.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10599.0 10667.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined 12-NOV-96 4.88 5.46 MEMORY 10667.0 10316.0 10667.0 83.0 86.7 TOOL NUMBER NGP 94 4.750 4.8 XANVI S 8.90 54.0 8.5 11100 4.8 .000 .000 .000 .000 63.3 .3 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 11 AAPI 4 1 68 4 2 ROP MWD 11 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10247.5 10667.5 10457.5 841 10247.5 GR 28.3964 207.025 56.4405 704 10247.5 ROP 10.7537 373.146 72.0046 739 10298.5 Last Reading 10667.5 10599 10667.5 First Reading For Entire File .......... 10247.5 Last Reading For Entire File ........... 10667.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMNtARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10631.5 10891.5 ROP 10668.0 10987.0 $ LOG HEADER DATA DATE LOGGED: 14-NOV-96 SOFTWARE SURFACE SOFTWARE VERSION: 4.88 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 10987.0 10667.0 10987.0 .0 .0 TOOL NUMBER NGP 159 4.750 4.8 XANVIS 9.00 49.0 7.4 13500 4.6 .000 .000 .000 .000 -17.7 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 12 FT/H 4 1 68 4 2 GR MWD 12 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10631.5 10987 10809.2 712 10631.5 ROP 8.7723 230.273 85.588 639 10668 Last Reading 10987 10987 GR 55.1019 106.93 78.1945 92 10631.5 10891.5 First Reading For Entire File .......... 10631.5 Last Reading For Entire File ........... 10987 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/03/27 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/03/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File JAN 24 1997 .Aisska Oil & "' ~ · bas uo,~s. C, omrr~M~ .A, nc:hor~e * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 05-40 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA APINUMBER : 500292270700 REFERENCE NO : 96351 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE · 97/01/22 ORIGIN · FLIC REEL NAME · 96351 CONTINUATION # : PREVIOUS REEL : CONk4ENT : ARCO ALASKA INC, D.S. 05-40, PRUDHOE BAY, API #50-029-22707-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE . 97/01/22 ORIGIN : FLIC TAPE NAME : 96351 CONTINUATION # : 1 PREVIOUS TAPE : CO~4~ENT : ARCO ALASKA INC, D.S. 05-40, PRUDHOE BAY, API #50-029-22707-00 TAPE HEADER Prudhoe Bay OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL : FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING DS 05-40 500292270700 ARCO Alaska Inc. SCHLUMBERGER WELL SERVICES 2-JAN-97 RUN 1 96351 MARK BAILLIE BOB GRABB RUN 2 RUN 3 32 liN 1SE 2321 4109 71.10 33.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4. 750 5. 500 9621 . 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 3RD STRING PRODUCTION STRING REMARKS: THE DATA CONTAINED HEREIN IS THE OPENHOLE LOG DATA ACQUIRED ON ARCO ALASKA'S D.S. 05-40 WELL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .00! SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SOW~4ARY LDWG TOOL CODE .............. DTE BCS SDN CNTG $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 10969.0 9648.0 10888.0 9623.0 10941.0 9623.0 10912.0 9623 . 0 BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REM_ARKS: THE DATA IN THIS FILE IS THE MAIN LOG DATA LOGGED IN OPENHOLE. THE DATA HAS BEEN CLIPPED OF INVALID DATA. THIS DATA IS CONSIDERED TO BE THE PRIVY DEPTH CONTROL AND NO DEPTH CORRECTIONS HAVE BEEN APPLIED. .......... EQUIVALENT UNSHIFTED DEPTH .......... DTE BCS SDN CNTG ............................ RUN NO. PASS NO. ............... MERGE TOP MERGE BASE ................... LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 645081 O0 000 O0 0 1 1 1 4 68 0000000000 GR DTE GAPI 645081 O0 000 O0 0 1 1 1 4 68 0000000000 ILD DTE OH~ 645081 O0 000 O0 0 1 1 1 4 68 0000000000 ILM DTE OH~I 645081 O0 000 O0 0 1 1 1 4 68 0000000000 SFL DTE OH~4 645081 O0 000 O0 0 1 1 1 4 68 0000000000 IMPH DTE 0H~4645081 O0 000 O0 0 1 1 1 4 68 0000000000 IDPH DTE OH~M645081 O0 000 O0 0 1 1 1 4 68 0000000000 SP DTE MV 645081 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DTE LB 645081 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DTE LB 645081 O0 000 O0 0 1 1 1 4 68 0000000000 MRES DTE 0H~4645081 O0 000 O0 0 1 1 1 4 68 0000000000 MTE~DTE DEGF 645081 O0 000 O0 0 1 1 1 4 68 0000000000 DT BCS US/F 645081 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 645081 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 645081 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 645081 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN 645081 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 645081 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 645081 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTC PU-S 645081 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 645081 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 645081 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 645081 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 645081 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: 4 NAME SERV UNIT SERVICE API API API API FILE NUMB ~FUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CFTC CNTG CPS 645081 O0 000 O0 0 1 1 1 4 68 0000000000 AZ DTE DEG 645081 O0 000 O0 0 1 1 1 4 68 0000000000 DEV DTE DEG 645081 O0 000 O0 0 1 1 1 4 68 0000000000 RB1 DTE DEG 645081 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10980.000 GR.DTE -999.250 ILD.DTE -999.250 ILM. DTE -999.250 SFL.DTE -999.250 IMPH.DTE -999.250 IDPH.DTE -999.250 SP.DTE -999.250 TENS.DTE -999.250 TEND.DTE -999.250 MRES.DTE -999.250 MTEM.DTE -999.250 DT.BCS -999.250 RHOB.SDN -999.250 DRHO.SDN -999.250 PEF. SDN -999.250 CAL1.SDN -999.250 NPHI.CNTG -999.250 NRAT. CNTG -999.250 CPHI.CNTG -999.250 CRAT. CNTG -999.250 NCNT. CNTG -999.250 FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 AZ.DTE 86.887 DEV. DTE 80.036 RB1.DTE 188.332 DEPT. 9623.000 GR.DTE 21.275 ILD.DTE -999 250 ILM.DTE -999.250 SFL.DTE -999.250 IMPH. DTE -999.250 IDPH.DTE -999 250 SP.DTE -999.250 TENS.DTE 2677.000 TEND.DTE 1767.185 MRES.DTE 0 166 MTEM. DTE 167.314 DT.BCS 90.800 RHOB.SDN 1.951 DRHO.SDN -0 817 PEF. SDN 6.172 CAL1.SDN 5.030 NPHI.CNTG 20.911 NRAT. CNTG 1 873 CPHI.CNTG 20.668 CRAT. CNTG 1.909 NCNT. CNTG 3692.256 FCNT. CNTG 1810 596 CNTC. CNTG 3358.178 CFTC. CNTG 1773.404 AZ.DTE -999.250 DEV. DTE -999 250 RB1.DTE -999.250 END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE : 97/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · 0 O1 CO1 DATE : 97/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run in~o casing. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SU~kr~RY LDWG TOOL CODE CNTG GRCH $ BASELINE CtrRVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 9623.0 8790.0 9623.0 8781.0 BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... CNTG GRCH REMARKS: THIS DATA IS THE MAIN LOG DATA ACQUIRED UP INTO CASING. $ LIS FO~T DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 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-JAN-1997 08:10 PAGE: ** 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 645081 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH DTE GAPI 645081 O0 000 O0 0 2 1 1 4 68 0000000000 TENS DTE LB 645081 O0 000 O0 0 2 1 1 4 68 0000000000 TEND DTE LB 645081 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 645081 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 645081 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 645081 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 645081 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 645081 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 645081 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 645081 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 645081 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9623.000 GRCH.DTE 21.275 TENS.DTE 2677.000 TEND.DTE NPHI.CNTG 20.911 NRAT. CNTG 1.873 CPHI.CNTG 20.668 CRAT. CNTG NCNT. CNTG 3692.256 FCNT. CNTG 1810.596 CNTC. CNTG 3358.178 CFTC. CNTG 1767.185 1.909 1773.404 DEPT. 8781.000 GRCH.DTE 160.446 TENS.DTE 95.000 TEND.DTE 1686.979 NPHI.CNTG -999.250 NRAT. CNTG -999.250 CPHI.CNTG -999.250 CRAT. CNTG -999.250 NCNT. CNTG -999.250 FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE . FLIC VERSION : O01CO1 DATE . 97/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: 7 FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU2R4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH DITE 10969.0 9623.0 BHC 10888.0 9623.0 LDT 10941.0 9623.0 CNTG 10912.0 9623.0 GPIT 10980.0 9630.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DITE LDT SDT GPIT CNTG AMS $ RESISTIVITY CART. LITHO DENSITY SONIC CARTRIDGE INCLINOMETRY TOOL COMPENSATED NEUTRON AUX. MEASUREMENT BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMER~ RECORDED TEMPERATURE (DEGF) : 15-NOV-96 8B0-538 1530 14-NOV-96 945 15-NOV-96 10987.0 10988.0 8781.0 10980.0 1800.O TOOL NUMBER DIC-EB 262 HLDC-AA 20 SDC-CB GPIT CNTG AMS 4. 750 9621.0 SHEARDRIL 9.10 50.0 184.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: RESISTIVITY (OI~4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 290 MUD AT BOTTOM HOLE T~4PERATURE (BHT) : MUD FILTRATE AT (MT): O. 270 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 230 MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAXIMUM DLS 17.55 DEG/HF MAXIMUM DEVATION 86.68 DEG @ 10313.5' LOGGING DONE IN ONE DESCENT CONVEYED ON THE END OF DRILL PIPE (TLC). DEPTH REFERENCE TO SPERRY-SUN MWD LOG. THIS FILE CONTAINS THE RAW MAIN OPEN HOLE LOG DATA. $ LIS FORMAT DATA EPITHERMAL SANDSTONE 2.65 62.0 62.0 62.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 220 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 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-JAN-1997 08:10 PAGE: ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NO~4B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 645081 O0 000 O0 0 3 1 1 4 68 0000000000 ILD DTE OPiFff~ 645081 O0 000 O0 0 3 1 1 4 68 0000000000 ILM DTE OHMM 645081 O0 000 O0 0 3 1 1 4 68 0000000000 SFLU DTE OH~M 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IMPH DTE OPi~I 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IDPH DTE OP~ff4645081 O0 000 O0 0 3 1 1 4 68 0000000000 CIDP DTE f4~qO 645081 O0 000 O0 0 3 1 1 4 68 0000000000 CIMP DTE ~ff/l~O 645081 O0 000 O0 0 3 1 1 4 68 0000000000 CDER DTE I~4}IO645081 O0 000 O0 0 3 1 1 4 68 0000000000 IDER DTE OH~ff~645081 O0 000 O0 0 3 1 1 4 68 0000000000 CMER DTE ~!M~O 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IMER DTE OPIUM645081 O0 000 O0 0 3 1 1 4 68 0000000000 CDVR DTE MM~O 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IDVR DTE OH~4~ 645081 O0 000 O0 0 3 1 1 4 68 0000000000 CMVRDTE ~IHO 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IMVRDTE OH~4M 645081 O0 000 O0 0 3 1 1 4 68 0000000000 CILD DTE l~¢i~tO 645081 O0 000 O0 0 3 1 1 4 68 0000000000 CILMDTE f/k4~O645081 O0 000 O0 0 3 1 1 4 68 0000000000 IDQF DTE 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IMQF DTE 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IIRDDTE ~J4~IO645081 O0 000 O0 0 3 1 1 4 68 0000000000 IIXI~DTE I¢k4~0645081 O0 000 O0 0 3 1 1 4 68 0000000000 IIRMDTE I~/i~O645081 O0 000 O0 0 3 1 1 4 68 0000000000 IIXMDTE MMHO 645081 O0 000 O0 0 3 1 1 4 68 0000000000 SP DTE MV 645081 O0 000 O0 0 3 1 1 4 68 0000000000 GR DTE GAPI 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TENS DTE LB 645081 O0 000 O0 0 3 1 1 4 68 0000000000 HTENDTE LB 645081 O0 000 O0 0 3 1 1 4 68 0000000000 ~4~ES DTE OPi~4~645081 O0 000 O0 0 3 1 1 4 68 0000000000 MTEMDTE DEGF 645081 O0 000 O0 0 3 1 1 4 68 0000000000 DT BHC US/F 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TT1 BHC US 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TT2 BHC US 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TT3 BHC US 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TT4 BHC US 645081 O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LDT G/C3 645081 O0 000 O0 0 3 1 1 4 68 0000000000 DRHO LDT G/C3 645081 O0 000 O0 0 3 1 1 4 68 0000000000 PEF LDT 645081 O0 000 O0 0 3 1 1 4 68 0000000000 CALI LDT IN 645081 O0 000 O0 0 3 1 1 4 68 0000000000 DPHI LDT PU 645081 O0 000 O0 0 3 1 1 4 68 0000000000 LSHVLDT V 645081 O0 000 O0 0 3 1 1 4 68 0000000000 SSHVLDT V 645081 O0 000 O0 0 3 1 1 4 68 0000000000 LSRHLDT G/C3 645081 O0 000 O0 0 3 1 1 4 68 0000000000 NPHILDT PU 645081 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR LDT PU 645081 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR LDT 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LDT PU 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA LDT 645081 O0 000 O0 0 3 1 1 4 68 0000000000 RCNTLDT CPS 645081 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT LDT CPS 645081 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: 10 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) CNTC LDT CPS 645081 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC LDT CPS 645081 O0 000 O0 0 3 1 1 4 68 0000000000 HAZI GPI DEG 645081 O0 000 O0 0 3 1 1 4 68 0000000000 DEVI GPI DEG 645081 O0 000 O0 0 3 1 1 4 68 0000000000 RB GPI DEG 645081 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10980.000 ILD.DTE IMPH.DTE -999.250 IDPH.DTE CDER.DTE -999.250 IDER.DTE CDVR.DTE -999.250 IDVR.DTE CILD.DTE -999.250 CILM.DTE IIRD. DTE -999. 250 IIXD. DTE SP. DTE -999. 250 GR. DTE IViRES. DTE - 999. 250 MTEM. DTE TT2.BHC -999.250 TT3.BHC DRHO.LDT -999.250 PEF.LDT LSHV. LDT -999.250 SSHV. LDT NPOR.LDT -999.250 RTNR.LDT RCNT.LDT -999.250 RCFT. LDT HAZI.GPI 86.887 DEVI.GPI DEPT. 9623. 000 ILD. DTE IMPH.DTE 1950. 000 IDPH.DTE CDER . DTE 168.820 IDER . DTE CDVR . DTE 199. 453 IDVR . DTE CILD . DTE -228.217 CILM. DTE IIRD.DTE -203.266 IIXD.DTE SP. DTE 276.93 8 GR. DTE MRES.DTE O . 166 MTEM.DTE TT2 . BHC 304. 800 TT3 . BHC DRHO. LDT -0.817 PEF.LDT LSHV. LDT 1127. 000 SSHV. LDT NPOR. LDT 19.485 RTNR. LDT RCNT. LDT 3692.256 RCFT. LDT HAZI. GPI -999. 250 DEVI. GPI -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 80.036 1950.000 1950.000 5.923 5.014 -1.005 3510.019 21.275 167.314 526.400 6.172 1166.000 1.873 1810.596 -999.250 ILM. DTE - 999.250 SFLU. DTE CIDP.DTE -999.250 CIMP.DTE CMER.DTE -999.250 IMER.DTE CMVR. DTE - 999.250 IMVR. DTE IDQF. DTE - 999. 250 IMQF. DTE IIRM. DTE - 999.250 IIXM. DTE TENS.DTE -999.250 HTEN. DTE DT. BHC -999. 250 TT1. BHC TT4. BHC -999. 250 RHOB. LDT CALI. LDT - 999. 250 DPHI. LDT LSRH. LDT - 999. 250 NPHI. LDT TNPH. LDT -999.250 TNRA.LDT CNTC. LDT - 999.250 CFTC. LDT RB. GPI 188. 332 I LM. DTE CIDP. DTE CMER . DTE CMVR. DTE IDQF. DTE IIRM. DTE TENS. DTE DT. BHC TT4 . BHC CALI . LDT LSRH. LDT TNPH. LDT CNTC. LDT RB. GPI 1950.000 -196.349 -23.263 3 974 0 000 -0 958 2677 000 90 800 330 400 5.030 2.768 20.668 3358.178 -999.250 SFLU. DTE CIMP. DTE IMER . DTE IMVR . DTE IMQF. DTE I I XM. DTE HTEN. DTE TT1. BHC RHOB. LDT DPHI. LDT NPHI. LDT TNRA. LDT CFTC. LDT -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.095 -11 941 1950 000 251 635 0 000 -310 887 1767 185 520 400 1 951 42 341 20.911 1.909 1773.404 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION ' O01CO1 DATE : 97/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE . 97/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUM~VzARY FILE HEADER FILE NUMBER 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH DITE 10969.0 10738.0 BHC 10888.0 10734.0 LDT 10932.0 10742.0 CNTG 10930.0 10742.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DITE RESISTIVITY CART. 15-NOV-96 8B0-538 1530 14-NOV-96 945 15-NOV-96 10987.0 10988.0 8781.0 10980.0 1800.0 TOOL NUMBER ........... DIC-EB 262 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: 12 LDT SDT GPIT CNTG AMS $ LITHO DENSITY SONIC CARTRIDGE INCLINOMETRY TOOL COMPENSATED NEUTRON AUX. MEASUREMENT BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (0B7~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REN~RKS: MAXIMUM DLS 17.55 DEG/HF MAXIMUM DEVATION 86.68 DEG @ 10313.5' LOGGING DONE IN ONE DESCENT CONVEYED ON THE END OF DRILL PIPE (TLC). DEPTH REFERENCE TO SPERRY-SUN MWD LOG. THIS FILE CONTAINS THE RAW OPEN HOLE REPEAT DATA. $ LIS FORMAT DATA HLDC-AA 20 SDC-CB GPIT CNTG AMS 4. 750 9621.0 SHEARDRIL 9.10 50.0 184.0 0.290 0.270 0.230 EPITHERMAL SANDSTONE 2.65 62.0 62.0 62.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 220 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CIDP DTR ~4~I~0 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IDPH DTR 0H~4~645081 O0 000 O0 0 4 1 1 4 68 0000000000 CIMP DTR I~iHO 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IMPH DTR Otk4M 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CDER DTR I~!HO 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IDER DTR OH~4M645081 O0 000 O0 0 4 1 1 4 68 0000000000 CMER DTR l¢k4~0645081 O0 000 O0 0 4 1 1 4 68 0000000000 IMER DTR OH~J4 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CDVRDTR Iv~IHO645081 O0 000 O0 0 4 1 1 4 68 0000000000 IDVR DTR OPIUM 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CMVRDTR MlvIHo645081 O0 000 O0 0 4 1 1 4 68 0000000000 IMVRDTR OH~ff4645081 O0 000 O0 0 4 1 1 4 68 0000000000 CILD DTR I~!~IO645081 O0 000 O0 0 4 1 1 4 68 0000000000 ILD DTR 0H~645081 O0 000 O0 0 4 1 1 4 68 0000000000 CILMDTR I~4~0 645081 O0 000 O0 0 4 1 1 4 68 0000000000 ILM DTR OH~M 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IDQF DTR 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IMQF DTR 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IIRDDTR I~/IHO645081 O0 000 O0 0 4 1 1 4 68 0000000000 IIXDDTR f~viHo645081 O0 000 O0 0 4 1 1 4 68 0000000000 IIRMDTR ~0 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IIXMDTR IZ~iHO645081 O0 000 O0 0 4 1 1 4 68 0000000000 SFLU DTR OH~ff~645081 O0 000 O0 0 4 1 1 4 68 0000000000 SP DTR MV 645081 O0 000 O0 0 4 1 1 4 68 0000000000 GR DTR GAPI 645081 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: 14 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) TENS DTR LB 645081 O0 000 O0 0 4 1 1 4 68 0000000000 MTE~DTR DEGF 645081 O0 000 O0 0 4 1 1 4 68 0000000000 MRES DTR OH~M 645081 O0 000 O0 0 4 1 1 4 68 0000000000 HTENDTR LB 645081 O0 000 O0 0 4 1 1 4 68 0000000000 DT BHR US/F 645081 O0 000 O0 0 4 1 1 4 68 0000000000 TT1 BHR US 645081 O0 000 O0 0 4 1 1 4 68 0000000000 TT2 BHR US 645081 O0 000 O0 0 4 1 1 4 68 0000000000 TT3 BHR US 645081 O0 000 O0 0 4 1 1 4 68 0000000000 TT4 BHR US 645081 O0 000 O0 0 4 1 1 4 68 0000000000 DPHI LDR PU 645081 O0 000 O0 0 4 1 1 4 68 0000000000 RHOB LDR G/C3 645081 O0 000 O0 0 4 1 1 4 68 0000000000 DRHO LDR G/C3 645081 O0 000 O0 0 4 1 1 4 68 0000000000 PEF LDR 645081 O0 000 O0 0 4 1 1 4 68 0000000000 LSHVLDR V 645081 O0 000 O0 0 4 1 1 4 68 0000000000 SSHVLDR V 645081 O0 000 O0 0 4 1 1 4 68 0000000000 LSRH LDR G/C3 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CALI LDR IN 645081 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNR PU 645081 O0 000 O0 0 4 1 1 4 68 0000000000 RTNR CNR 645081 O0 000 O0 0 4 1 1 4 68 0000000000 TNPH CNR PU 645081 O0 000 O0 0 4 1 1 4 68 0000000000 TNRA CNR 645081 O0 000 O0 0 4 1 1 4 68 0000000000 NPOR CNR PU 645081 O0 000 O0 0 4 1 1 4 68 0000000000 RCNT CN~ CPS 645081 O0 000 O0 0 4 1 1 4 68 0000000000 RCFT CNR CPS 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNR CPS 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNR CPS 645081 O0 000 O0 0 4 1 1 4 68 0000000000 DEVI GPR DEG 645081 O0 000 O0 0 4 1 1 4 68 0000000000 HAZI GPR DEG 645081 O0 000 O0 0 4 1 1 4 68 0000000000 RB GPR DEG 645081 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10976. 000 CIDP.DTR 77. 860 IDPH.DTR 12. 844 CIMP.DTR IMPH.DTR 12. 797 CDER.DTR 77. 486 IDER.DTR 12. 905 CMER.DTR IMER. DTR 12.837 CDVR. DTR 79.127 IDVR. DTR 12.638 CMVR. DTR IMVR.DTR 12.581 CILD.DTR 83.516 ILD.DTR 11.974 CILM. DTR ILM. DTR 12.224 IDQF.DTR O. 000 IMQF.DTR O. 000 IIRD.DTR IIXD.DTR 3. 044 IIRM. DTR 86. 473 IIXIf. DTR -8. 024 SFLU. DTR SP.DTR 159. 375 GR.DTR 129. 818 TENS.DTR 1274 . 000 MTEM.DTR I~gES.DTR O. 140 HTEN. DTR 121. 470 DT.BHR 85. 568 TT1. BHR TT2. BHR 338. 914 TT3 . BHR 534 . 320 TT4. BHR 349. 200 DPHI. LDR RHOB.LDR 2.490 DRHO.LDR -0.062 PEF. LDR 2.386 LSHV. LDR SSHV. LDR 1165.500 LSRH. LDR 2.552 CALI.LDR O. 811 NPHI. CNR RTNR. CNR 2. 284 TNPH. CNR 25.241 TiVRA. CNR 2. 221 NPOR. CNR RCNT. ClVR 4789.565 RCFT. CNR 2036.379 CNTC. CNR 4402.616 CFTC. CNR DEVI. GPR 82.220 HAZI.GPR 85.480 RB.GPR 179.107 78.144 77.900 79.486 81.808 78.479 4.808 184.147 498.857 9.670 1126.000 25.834 24.848 2027.987 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: 15 DEPT. 8766. 000 CIDP.DTR IMPH. DTR 274.195 CDER . DTR IMER . D TR 274. 229 CD VR . DTR IMVR . DTR 274.214 CILD. DTR ILM. DTR 263. 090 IDQF.DTR IIXD.DTR 111 . 936 IIRM. DTR SP. DTR 4 64 . 500 GR. DTR M~ES.DTR 0.144 HTEN. DTR TT2. BHR 2 68.400 TT3. BHR RHOB.LDR 2.302 DRHO.LDR SSHV. LDR 1161.500 LSRH.LDR RTNR. CNR 2. 600 TNPH. CNR RCNT. CArR 1581 . 201 RCFT. CI~R DEVI. GPR 17. 045 HAZI. GPR 18 861 18 854 18 862 19 876 0 000 3 622 256. 717 1356 563 375 600 -0 213 2 514 29 399 601 612 15 534 IDPH. DTR IDER.DTR IDVR . DTR I LD . DTR IMQF.DTR I IX~. DTR TENS. DTR DT.BHR TT4. BHR PEF. LDR CAL I . LDR TNRA. CNR CNTC. CNR RB. GPR 53. 019 CIMP.DTR 53.038 CMER . DTR 53. O17 CMVR . DTR 50. 311 CILM. DTR O. 000 IIRD.DTR -161 . 648 SFLU.DTR 715. 000 MTEM.DTR 53. 900 TT1. BHR 267. 600 DPHI. LDR 8. 932 LSHV. LDR O. 829 NPHI. CNR 2.519 NPOR. CNR 1496. 760 CFTC. CNR 198. 328 3. 647 3. 647 3. 647 3. 801 18.127 0. 271 138. 029 376. 000 21 . 108 1123. 000 30.309 29. 399 61 O. 396 END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION . O01CO1 DATE . 97/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~i~Y VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9623.0 8781.0 CNTG 9623.0 8790.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: 16 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DITE LDT SDT GPIT CNTG AMS $ RESISTIVITY CART. LITHO DENSITY SONIC CARTRIDGE INCLINOMETRY TOOL COMPENSATED NEUTRON AUX. MEASUREMENT BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 15 -NOV- 96 8B0-538 1530 14 -NOV-96 945 15-NOV-96 10987.0 10988.0 8781.0 10980.0 1800.0 TOOL NUMBER DIC-EB 262 HLDC-AA 20 SDC-CB GPIT CNTG AMS 4. 750 9621.0 SHEARDRIL 9.10 50.0 184.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.290 TOOL STANDOFF (IN): RE~ARKS: MAXIMUM DLS 17.55 DEG/HF MAXIMUM DEVATION 86.68 DEG @ 10313.5' LOGGING DONE IN ONE DESCENT CONVEYED ON THE END OF DRILL PIPE (TLC). 0.270 0.230 EPITHERMAL SANDSTONE 2.65 62.0 62.0 62. 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: 17 DEPTH REFERENCE TO SPERRY-SUN ~4~D LOG. THIS FILE CONTAINS THE RAW MAIN LOG DATA ACQUIRED INTO CASING. $ LIS FORMAT DATA ** DATA FO~T SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** Ngl'4~ 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 645081 O0 000 O0 0 5 1 1 4 68 0000000000 GR CSG GAPI 645081 O0 000 O0 0 5 1 1 4 68 0000000000 TENS CSG LB 645081 O0 000 O0 0 5 1 1 4 68 0000000000 HTENCSG LB 645081 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CSG PU 645081 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR CSG PU 645081 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR CSG 645081 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH CSG PU 645081 O0 000 O0 0 5 1 1 4 68 0000000000 TNNA CSG 645081 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT CSG CPS 645081 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT CSG CPS 645081 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC CSG CPS 645081 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC CSG CPS 645081 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-JAN-1997 08:10 PAGE: 18 ** DATA ** DEPT. 9623.000 GR.CSG NPHI.CSG 20.911 NPOR.CSG TNRA.CSG 1.909 RCNT. CSG CFTC. CSG 1773.404 DEPT. 8781.000 GR.CSG NPHI.CSG -999.250 NPOR.CSG TNRA.CSG -999.250 RCNT. CSG CFTC. CSG -999.250 21.275 TENS. CSG 19.485 RTNR.CSG 3692.256 RCFT. CSG 160. 446 TENS. CSG -999. 250 RTNR. CSG -999. 250 RCFT. CSG 2677.000 HTEN. CSG 1.873 TNPH. CSG 1810.596 CNTC. CSG 95.000 HTEN. CSG -999.250 TNPH. CSG -999.250 CNTC. CSG 1767.185 20.668 3358.178 1686.979 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 97/01/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/01/22 ORIGIN : FLIC TAPE NAME : 96351 CONTINUATION # : 1 PREVIOUS TAPE : CORR4ENT : ARCO ALASKA INC, D.S. 05-40, PRUDHOE BAY, API #50-029-22707-00 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 97/01/22 ORIGIN · FLIC REEL NAME · 96351 CONTINUATION # : PREVIOUS REEL : CO~2VENT : ARCO ALASKA INC, D.S. 05-40, PRUDHOE BAY, API #50-029-22707~00 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 05-40 FIELD NAME : PRO. HOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API N-UMBER : 500292270700 REFERENCE NO : 96351 R CEIVED LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: **** REEL HEADER **** SERVICE NAF~E : EDIT DATE : 97/01/ 2 ORIGIN : FLIC REEL NAME : 96351 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, D.S. 05-40, PRUDHOE BAY, API #50-029-22707-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 97/01/ 2 ORIGIN : FLIC TAPE NAME : 96351 CONTINUATION # : 1 PREVIOUS TAPE : COI4~ENT : ARCO ALASKA INC, D.S. 05-40, PRUDHOE BAY, API #50-029-22707-00 TAPE HEADER Prudhoe Bay OPEN HOLE WIRELINE LOGS WELL NAME: API NOWBER : OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL : FSL : FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING DS 05-40 500292270700 ARCO Alaska Inc. SCHLUMBERGER WELL SERVICES 2-JAN-97 RUN 1 96351 MARK BAILLIE BOB GRABB RUN 2 RUN 3 32 liN 1SE 2321 4109 71.10 33.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ................................ 4. 750 5. 500 9621.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 3RD STRING PRODUCTION STRING REMARKS: THE DATA CONTAINED HEREIN IS THE OPENHOLE LOG DATA ACQUIRED ON ARCO ALASKA'S D.S. 05-40 WELL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUNk4ARY LDWG TOOL CODE START DEPTH DTE 10969.0 BCS 10888.0 SDN 10941.0 CNTG 10912.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE RUN NO. $ RENARKS: THE DATA IN THIS FILE IS THE MAIN LOG DATA LOGGED IN OPENHOLE. THE DATA HAS BEEN CLIPPED OF INVALID DATA. THIS DATA IS CONSIDERED TO BE THE PRIMARY DEPTH CONTROL AND NO DEPTH CORRECTIONS HAVE BEEN APPLIED. $ STOP DEPTH .......... 9648.0 9623.0 9623.0 9623.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... DTE BCS SDN CNTG PASS NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PA GE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT !1 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 645081 O0 000 O0 0 1 1 1 4 68 0000000000 GR DTE GAPI 645081 O0 000 O0 0 1 1 1 4 68 0000000000 ILD DTE OHMM 645081 O0 000 O0 0 1 1 1 4 68 0000000000 ILM DTE OH~4~ 645081 O0 000 O0 0 1 1 1 4 68 0000000000 SFL DTE OHMM645081 O0 000 O0 0 1 1 1 4 68 0000000000 IMPH DTE OH~ff4645081 O0 000 O0 0 1 1 1 4 68 0000000000 IDPH DTE 0H2~645081 O0 000 O0 0 1 1 1 4 68 0000000000 SP DTE MV 645081 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DTE LB 645081 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DTE LB 645081 O0 000 O0 0 1 1 1 4 68 0000000000 ~ES DTE 0H~645081 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMDTE DEGF 645081 O0 000 O0 0 I 1 1 4 68 0000000000 DT BCS US/F 645081 O0 000 O0 0 1 1 1 4 68 0000000000 RttOB SDN G/C3 645081 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 645081 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 645081 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN 645081 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 645081 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 645081 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTC PU-S 645081 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 645081 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 645081 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 645081 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 645081 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: NAI~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) CFTC CNTG CPS 645081 O0 000 O0 0 1 1 1 4 68 0000000000 AZ DTE DEG 645081 O0 000 O0 0 1 1 1 4 68 0000000000 DEV DTE DEG 645081 O0 000 O0 0 1 1 1 4 68 0000000000 RB1 DTE DEG 645081 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10980.000 GR.DTE -999.250 ILD.DTE SFL.DTE -999.250 IMPH.DTE -999.250 IDPH.DTE TENS.DTE -999.250 TEND.DTE -999.250 MRES.DTE DT. BCS -999.250 RHOB.SDN -999.250 DRHO.SDN CAL1.SDN -999.250 NPHI.CNTG -999.250 NRAT. CNTG CRAT. CNTG -999.250 NCNT. CNTG -999.250 FCNT. CNTG CFTC. CNTG -999.250 AZ.DTE 86.887 DEV.DTE DEPT. 9623.000 GR.DTE 21.275 ILD.DTE SFL.DTE -999.250 IMPH.DTE -999.250 IDPH.DTE TENS.DTE 2677.000 TEND.DTE 1767.185 MRES.DTE DT.BCS 90.800 RHOB.SDN 1.951 DRHO.SDN CAL1.SDN 5.030 NPHI.CNTG 20.911 NRAT. CNTG CRAT. CNTG 1.909 NCNT. CNTG 3692.256 FCNT. CNTG CFTC. CNTG 1773.404 AZ.DTE -999.250 DEV. DTE -999 250 ILM. -999 250 SP. -999 250 MTE~. -999 250 PEF. -999 250 CPHI. -999 250 CNTC. 80 036 RB1. DTE DTE DTE SDN CNTG CNTG DTE -999 250 ILM.DTE -999 250 SP.DTE 0 166 MTEM. DTE - 0 817 PEF. SDN 1 873 CPHI. CNTG 1810 596 CNTC. CNTG -999 250 RB1.DTE -999. -999. -999. -999. -999. -999. 188. -999. -999. 167. 6. 20. 3358. -999. 25O 25O 250 250 250 25O 332 250 250 314 172 668 178 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION . O01CO1 DATE : 97/01/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE . FLIC VERSION . O01CO1 DATE . 97/01/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: FILE HEADER FILE NOPI~ER: 2 EDITED CASED HOLEMAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SOlv~LARY LDWG TOOL CODE CNTG GRCH $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (I~EASUREDDEPTH) START DEPTH STOP DEPTH 9623.0 8790.0 9623.0 8781.0 BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... CNTG GRCH THIS DATA IS THE MAIN LOG DATA ACQUIRED UP INTO CASING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: ** SET TYPE - CHAN ** 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) DEPT FT 645081 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH DTE GAPI 645081 O0 000 O0 0 2 1 1 4 68 0000000000 TENS DTE LB 645081 O0 000 O0 0 2 1 1 4 68 0000000000 TEND DTE LB 645081 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 645081 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 645081 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 645081 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CI~fG 645081 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 645081 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 645081 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 645081 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 645081 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA DEPT. 9623. 000 GRCH.DTE 21 . 275 TENS.DTE 2677. 000 TEND.DTE NPHI. CNTG 20. 911 NRAT. CNTG 1 . 873 CPHI. CNTG 20. 668 CRAT. CNTG NCNT. CNTG 3692. 256 FCNT. CNTG 181 O . 596 CNTC. CNTG 3358.178 CFTC. CNTG 1767.185 1.909 1773.404 DEPT. 8781.000 GRCH. DTE 160.446 TENS.DTE 95.000 TEND.DTE 1686.979 NPHI.CNTG -999.250 NRAT. CNTG -999.250 CPHI.CNTG -999.250 CRAT. CNTG -999.250 NCNT. CNTG -999.250 FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE ' FLIC VERSION : O01CO1 DATE ' 97/01/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE ·FLIC VERSION .O01CO1 DATE : 97/01/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: 7 FILE HEADER FILE ~ER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NURIBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUNm!ARY VENDOR TOOL CODE START DEPTH DITE 10969.0 BHC 10888.0 LDT 10941.0 CNTG 10912.0 GPIT 10980.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 9623.0 9623.0 9623.0 9623.0 9630.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DITE LDT SDT GPIT CNTG AMS $ RESISTIVITY CART. LITHO DENSITY SONIC CARTRIDGE INCLINOMETRY TOOL COMPENSATED NEUTRON AUX. MEASUREMENT BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 15-NOV-96 8B0-538 1530 14-NOV-96 945 15-NOV-96 10987.0 10988.0 8781.0 10980.0 1800.0 TOOL NUMBER DIC-EB 262 HLDC-AA 20 SDC- CB GPIT CNTG AMS 4. 750 9621.0 SHEARDRIL 9.10 50.0 184.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: RESISTIVITY (OH~fl~) AT TEMPERATURE (DEGF) : MUD AT M~ASURED TE~IPERATURE (MT): 0.290 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): 0.270 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 0.230 MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 TOOL STANDOFF (IN) '. REMARKS: MAXIMUM DLS 17.55 DEG/HF MAXIMUM DEVATION 86.68 DEG @ 10313.5' LOGGING DONE IN ONE DESCENT CONVEYED ON THE END OF DRILL PIPE (TLC). DEPTH REFERENCE TO SPERRY-SUN MWD LOG. THIS FILE CONTAINS THE RAW MAIN OPEN HOLE LOG DATA. $ LIS FORMAT DATA 62.0 62.0 62.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 220 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: ** 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 645081 O0 000 O0 0 3 1 1 4 68 0000000000 ILD DTE OH~M 645081 O0 000 O0 0 3 1 1 4 68 0000000000 I~4 DTE OH~4M 645081 O0 000 O0 0 3 1 1 4 68 0000000000 SFLU DTE 0H~I645081 O0 000 O0 0 3 1 1 4 68 0000000000 IMPH DTE 0H~645081 O0 000 O0 0 3 1 1 4 68 0000000000 IDPH DTE OPIUM645081 O0 000 O0 0 3 1 1 4 68 0000000000 CIDP DTE I~HO 645081 O0 000 O0 0 3 1 1 4 68 0000000000 CIMP DTE I¢~fHO645081 O0 000 O0 0 3 1 1 4 68 0000000000 CDER DTE ~!M~tO645081 O0 000 O0 0 3 1 1 4 68 0000000000 IDER DTE OI~/iM645081 O0 000 O0 0 3 1 1 4 68 0000000000 CMER DTE I4~FHO645081 O0 000 O0 0 3 1 1 4 68 0000000000 IMER DTE OH~iM 645081 O0 000 O0 0 3 1 1 4 68 0000000000 CDVR DTE f4Fl}IO 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IDVR DTE OH~M 645081 O0 000 O0 0 3 1 1 4 68 0000000000 CMVR DTE Rff4~tO 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IMVR DTE OHMM645081 O0 000 O0 0 3 1 1 4 68 0000000000 CILD DTE f¢~!}tO 645081 O0 000 O0 0 3 1 1 4 68 0000000000 CILMDTE l~Vl~O645081 O0 000 O0 0 3 1 1 4 68 0000000000 IDQF DTE 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IMQF DTE 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IIRDDTE I4M~O 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IIXIgDTE 14MHO 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IIRMDTE I~4~0 645081 O0 000 O0 0 3 1 1 4 68 0000000000 IIX~IDTE 14Fi~O645081 O0 000 O0 0 3 1 1 4 68 0000000000 SP DTE MV 645081 O0 000 O0 0 3 1 1 4 68 0000000000 GR DTE GAPI 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TENS DTE LB 645081 O0 000 O0 0 3 1 1 4 68 0000000000 HTEN DTE LB 645081 O0 000 O0 0 3 1 1 4 68 0000000000 MRES DTE Otff4M645081 O0 000 O0 0 3 1 1 4 68 0000000000 MTEMDTE DEGF 645081 O0 000 O0 0 3 1 1 4 68 0000000000 DT BHC US/F 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TT1 BHC US 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TT2 BHC US 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TT3 BHC US 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TT4 BHC US 645081 O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LDT G/C3 645081 O0 000 O0 0 3 1 1 4 68 0000000000 DRHO LDT G/C3 645081 O0 000 O0 0 3 1 1 4 68 0000000000 PEF LDT 645081 O0 000 O0 0 3 1 1 4 68 0000000000 CALI LDT IN 645081 O0 000 O0 0 3 1 1 4 68 0000000000 DPHI LDT PU 645081 O0 000 O0 0 3 1 1 4 68 0000000000 LSHVLDT V 645081 O0 000 O0 0 3 1 1 4 68 0000000000 SSHV LDT V 645081 O0 000 O0 0 3 1 1 4 68 0000000000 LSRHLDT G/C3 645081 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI LDT PU 645081 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR LDT PU 645081 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR LDT 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LDT PU 645081 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA LDT 645081 O0 000 O0 0 3 1 1 4 68 0000000000 RCNTLDT CPS 645081 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT LDT CPS 645081 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: 10 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEN CODE (HEX) CNTCLDT CPS 645081 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC LDT CPS 645081 O0 000 O0 0 3 1 1 4 68 0000000000 HAZI GPI DEG 645081 O0 000 O0 0 3 1 1 4 68 0000000000 DEVI GPI DEG 645081 O0 000 O0 0 3 1 1 4 68 0000000000 RB GPI DEG 645081 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10980.000 ILD,DTE IMPH. DTE -999.250 IDPH,DTE CDER.DTE -999.250 IDER.DTE CDVR.DTE -999.250 IDVR.DTE CILD.DTE -999.250 CILM. DTE IIRD.DTE -999.250 IIXD.DTE SP. DTE - 999. 250 GR. DTE t4~ES. DTE - 999. 250 MTE~. DTE TT2. BHC -999. 250 TT3 . BHC DRHO.LDT -999.250 PEF.LDT LSHV. LDT -999.250 SSHV. LDT NPOR.LDT -999,250 RTNR.LDT RCNT.LDT -999.250 RCFT. LDT HAZI.GPI 86.887 DEVI.GPI DEPT. IMPH. DTE CDER . DTE CDVR. DTE CILD. DTE IIRD. DTE SP. DTE MRES . DTE TT2 . BHC DRHO. LDT LSHV. LDT NPOR. LDT RCNT. LDT HAZI. GPI 9623. 000 1950. 000 168. 820 199. 453 -228. 217 -203. 266 276. 938 0.166 304 800 -0 817 1127 000 19 485 3692 256 -999 250 ILD. DTE IDPH. DTE IDER. DTE IDVR . DTE CILM. DTE I I YiD . D T E GR. DTE MTEN. DTE TT3 . BHC PEF. LDT SSHV. LDT R TNR . LD T RCFT. LDT DEVI. GPI -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 80,036 1950,000 1950. 000 5,923 5. 014 -1. 005 3510. 019 21.275 167. 314 526. 400 6.172 1166. 000 1. 873 1810. 596 -999.250 ILM. DTE -999.250 SFLU. DTE CIDP.DTE -999.250 CIMP.DTE CMER.DTE -999.250 IMER.DTE CMVR.DTE -999.250 IMVR.DTE IDQF. DTE -999.250 IMQF. DTE IIRM. DTE -999.250 IIX~.DTE TENS.DTE -999.250 HTEN.DTE DT.BHC -999.250 TT1.BHC TT4.BHC -999.250 RHOB.LDT CALI.LDT -999.250 DPHI.LDT LSRH.LDT -999.250 NPHI.LDT TNPH.LDT -999.250 TNRA.LDT CNTC.LDT -999.250 CFTC.LDT RB.GPI 188.332 I LM . DTE CIDP. DTE C~IER . DTE CMVR. DTE IDQF. DTE I IRM. DTE TENS. DTE DT. BHC TT4. BHC CALI . LDT LSRH. LDT TNPH. LDT CNTC. LDT RB. GPI 1950.000 -196.349 -23 263 3 974 0 000 -0 958 2677 000 90 800 330 400 5 030 2 768 20 668 3358.178 -999.250 SFLU. DTE CIMP. DTE IMER. DTE IMVR. DTE IMQF. DTE I IXN. DTE HTEN. DTE TT1. BHC RHOB. LDT DPHI. LDT NPHI. LDT TNRA. LDT CFTC. LDT -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.095 -11 941 1950 000 251 635 0 000 -310 887 1767 185 520 4O0 1.951 42.341 20.911 1.909 1773.404 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: 11 **** FILE TRAILER **** FILE NAYZE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE~ER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE · 97/01/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE Stmff4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH DITE 10969.0 10738.0 BHC 10888.0 10734.0 LDT 10932.0 10742.0 CNTG 10930.0 10742.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DITE RESISTIVITY CART. 15-NOV-96 8B0~538 1530 14-NOV-96 945 15-NOV-96 10987.0 10988.0 8781.0 10980.0 1800.0 TOOL NUMBER DIC-EB 262 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: 12 LDT SDT GPIT CNTG AMS $ LITHO DENSITY SONIC CARTRIDGE INCLINO~iETRY TOOL COMPENSATED NEUTRON AUX. MEASUREMENT HLDC-AA 20 SDC-CB GPIT CNTG AMS BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) '. DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 4. 750 9621.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (0t~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) '. MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : SHEARDRIL 9.10 50.0 184.0 0.290 0.270 0.230 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL S~NDSTONE 2.65 TOOL STANDOFF (IN): REMARKS: MAXIMUM DLS 17.55 DEG/HF MAXIMUM DEVATION 86.68 DEG @ 10313.5' LOGGING DONE IN ONE DESCENT CONVEYED ON THE END OF DRILL PIPE (TLC). DEPTH REFERENCE TO SPERRY-SUN MWD LOG. THIS FILE CONTAINS THE RAW OPEN HOLE REPEAT DATA. LIS FORMAT DATA 62.0 62.0 62.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 220 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CIDP DTR ~4~t0 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IDPH DTR OHt4~ 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CIMP DTR MF~IO 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IMPH DTR OHt4M 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CDER DTR ~tHO 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IDER DTR Otff4M645081 O0 000 O0 0 4 1 1 4 68 0000000000 C~ER DTR Pff4~O645081 O0 000 O0 0 4 1 1 4 68 0000000000 IMER DTR 0H2~4 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CDVR DTR ~ff4HO645081 O0 000 O0 0 4 1 1 4 68 0000000000 IDV-RDTR OH~4 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CMVR DTR ~fHO 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IMVR DTR OPTS4 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CILD DTR R~4~O 645081 O0 000 O0 0 4 1 1 4 68 0000000000 ILD DTR OH~4 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CILM DTR M~iHO 645081 O0 000 O0 0 4 1 1 4 68 0000000000 ILM DTR OH~ff4645081 O0 000 O0 0 4 1 1 4 68 0000000000 IDQF DTR 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IMQF DTR 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IIRD DTR B~{HO 645081 O0 000 O0 0 4 1 1 4 68 0000000000 IIXD DTR ~fl~HO645081 O0 000 O0 0 4 1 1 4 68 0000000000 IIRM DTR P94H_O645081 O0 000 O0 0 4 1 1 4 68 0000000000 IIXM DTR ~fi~HO645081 O0 000 O0 0 4 1 1 4 68 0000000000 SFLU DTR OH~4 645081 O0 000 O0 0 4 1 1 4 68 0000000000 SP DTR WV 645081 O0 000 O0 0 4 1 1 4 68 0000000000 GR DTR GAPI 645081 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: 14 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUNiB SAMP ELEM CODE (HEX) TENS DTR LB 645081 O0 000 O0 0 4 1 1 4 68 0000000000 MTEMDTR DEGF 645081 O0 000 O0 0 4 1 1 4 68 0000000000 MRES DTR Ott~I4 645081 O0 000 O0 0 4 1 1 4 68 0000000000 HTENDTR LB 645081 O0 000 O0 0 4 1 1 4 68 0000000000 DT BHR US/F 645081 O0 000 O0 0 4 1 1 4 68 0000000000 TT1 BHR US 645081 O0 000 O0 0 4 1 1 4 68 0000000000 TT2 BHR US 645081 O0 000 O0 0 4 1 1 4 68 0000000000 TT3 BHR US 645081 O0 000 O0 0 4 1 1 4 68 0000000000 TT4 BHR US 645081 O0 000 O0 0 4 1 1 4 68 0000000000 DPHI LDR PU 645081 O0 000 O0 0 4 1 1 4 68 0000000000 RHOB LDR G/C3 645081 O0 000 O0 0 4 1 1 4 68 0000000000 DRHO LDR G/C3 645081 O0 000 O0 0 4 1 1 4 68 0000000000 PEF LDR 645081 O0 000 O0 0 4 1 1 4 68 0000000000 LSHVLDR V 645081 O0 000 O0 0 4 1 1 4 68 0000000000 SSHVLDR V 645081 O0 000 O0 0 4 1 1 4 68 0000000000 LSRHLDR G/C3 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CALI LDR IN 645081 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNR PU 645081 O0 000 O0 0 4 1 1 4 68 0000000000 RTNR CNR 645081 O0 000 O0 0 4 1 1 4 68 0000000000 TNPH CNR PU 645081 O0 000 O0 0 4 1 1 4 68 0000000000 TNRA CNR 645081 O0 000 O0 0 4 1 1 4 68 0000000000 NPOR CNR PU 645081 O0 000 O0 0 4 1 1 4 68 0000000000 RCNT CNR CPS 645081 O0 000 O0 0 4 1 1 4 68 0000000000 RCFT CNR CPS 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNR CPS 645081 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNR CPS 645081 O0 000 O0 0 4 1 1 4 68 0000000000 DEVI GPR DEG 645081 O0 000 O0 0 4 1 1 4 68 0000000000 HAZI GPR DEG 645081 O0 000 O0 0 4 1 1 4 68 0000000000 RB GPR DEG 645081 O0 000 O0 0 4 1 1 4 68 0000000000 DATA ** DEPT. IMPH. DTR IMER . DTR IMVR . DTR ILM. DTR I IXD . DTR SP. DTR Ni~ES . DTR TT2 . BHR RHOB. LDR SSHV. LDR RTNR. CNR R CNT . CNR DEVI. GPR 10976. 000 12. 797 12. 837 12. 581 12. 224 3. 044 159.375 0.140 338 914 2 490 1165 500 2 284 4789 565 82 220 CIDP.DTR 77. 860 IDPH.DTR 12. 844 CIMP.DTR CDER.DTR 77. 486 IDER.DTR 12. 905 CMER.DTR CDVR.DTR 79. 127 IDVR.DTR 12. 638 CMVR.DTR CILD.DTR 83.516 ILD.DTR 11.974 CILM. DTR IDQF.DTR O. 000 IMQF.DTR O. 000 IIRD.DTR IIRM. DTR 86. 473 IIX~I. DTR -8. 024 SFLU. DTR GR.DTR 129. 818 TENS.DTR 1274 . 000 MTEM. DTR HTEN. DTR 121 . 470 DT. BHR 85. 568 TT1 . BHR TT3 . BHR 534. 320 TT4. BHR 349. 200 DPHI. LDR DRHO. LDR - O. 062 PEF. LDR 2.386 LSHV. LDR LSRH.LDR 2. 552 CALI~LDR O. 811 NPHI. CNR TNPH. CNR 25. 241 TNRA. CNR 2. 221 NPOR. CNR RCFT. CNR 2036. 379 CNTC. CNR 4402. 616 CFTC. CNR HAZI. GPR 85. 480 RB. GPR 179. 107 78.144 77.900 79.486 81 808 78 479 4 808 184 147 498 857 9 670 1126 000 25834 24 848 2027.987 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: 15 DEPT. 8766. 000 CIDP.DTR IMPH.DTR 274.195 CDER.DTR IM~R.DTR 274.229 CDVR.DTR IMVR.DTR 274.214 CILD.DTR ILM. DTR 263. 090 IDQF. DTR IIXD.DTR 111.936 IIRM. DTR SP. DTR 464. 500 GR. DTR FflqES.DTR O. 144 HTEN. DTR TT2. BHR 268. 400 TT3. BHR RHOB. LDR 2.302 DRHO. LDR SSHV. LDR 1161.500 LSRH. LDR RTNR. CNR 2. 600 TNPH. CNR RCNT. CNR 1581. 201 RCFT. CNR DEVI.GPR 17. 045 HAZI.GPR 18. 861 IDPH.DTR 18. 854 IDER.DTR 18.862 IDVR. DTR 19. 876 ILD.DTR O. 000 IMQF. DTR 3 . 622 IIXM. DTR 256.717 TENS. DTR 1356. 563 DT. BHR 375. 600 TT4. BHR - O. 213 PEF. LDR 2.514 CALI. LDR 29. 399 TNRA . CNR 601 . 612 CNTC. CNR 15. 534 RB. GPR 53. O19 CIMP. DTR 53.038 CMER . DTR 53. O17 CMVR . DTR 50. 311 CILM.DTR O. 000 IIRD. DTR -161 . 648 SFLU. DTR 715. 000 MTEM. DTR 53. 900 TT1. BHR 267. 600 DPHI. LDR 8. 932 LSHV. LDR 0.829 NPHI.CNR 2.519 NPOR.CNR 1496.760 CFTC. CNR 198.328 3. 647 3. 647 3. 647 3.801 18.127 0.271 138.029 376.000 21.108 1123.000 30.309 29.399 610.396 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT . 004 SERVICE : FLIC VERSION ' O01CO1 DATE . 97/01/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 97/01/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9623.0 8781.0 CNTG 9623.0 8790.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: 16 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~iR CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VF2VDOR TOOL CODE TOOL TYPE DITE LDT SDT GPIT CNTG AMS $ RESISTIVITY CART. LITHO DENSITY SONIC CARTRIDGE INCLINOMETRY TOOL COMPENSATED NEUTRON AUX. MEASUREM~VT 15-NOV-96 8B0-538 1530 14-NOV-96 945 15-NOV-96 10987.0 10988.0 8781.0 10980.0 1800.0 TOOL NUMBER DIC-EB 262 HLDC-AA 20 SDC- CB GPIT CNTG AMS BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 4. 750 9621.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (0H~24) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : SHEARDRIL 9.10 50.0 184.0 0.290 0.270 0.230 62.0 62.0 62.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EP I THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): REMARKS: MAXIMUM DLS 17.55 DEG/HF MAXIMUM DEVATION 86.68 DEG @ 10313.5' LOGGING DONE IN ONE DESCENT CONVEYED ON THE END OF DRILL PIPE (TLC). LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: 17 DEPTH REFERENCE TO SPERRY-SUN MWD LOG. THIS FILE CONTAINS THE RAW MAIN LOG DATA ACQUIRED INTO CASING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 645081 O0 000 O0 0 5 1 1 4 68 0000000000 GR CSG GAPI 645081 O0 000 O0 0 5 1 1 4 68 0000000000 TENS CSG LB 645081 O0 000 O0 0 5 1 1 4 68 0000000000 HTEN CSG LB 645081 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CSG PU 645081 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CSG PU 645081 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CSG 645081 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CSG PU 645081 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA CSG 645081 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT CSG CPS 645081 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT CSG CPS 645081 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC CSG CPS 645081 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC CSG CPS 645081 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-JAN-1997 14:40 PAGE: 18 ** DATA ** DEPT. 9623.000 GR.CSG NPHI.CSG 20.911 NPHI.CSG TNRA.CSG 1.909 RCNT. CSG CFTC. CSG 1773.404 DEPT. 8781.000 GR.CSG NPHI.CSG -999.250 NPHI.CSG TNRA.CSG -999.250 RCNT. CSG CFTC. CSG -999.250 21.275 TENS.CSG 19.485 NPHI.CSG 3692.256 RCFT. CSG 160.446 TENS.CSG -999.250 NPHI.CSG -999.250 RCFT. CSG 2677.000 HTEN. CSG 1.873 NPHI.CSG 1810.596 CNTC. CSG 95.000 HTEN. CSG -999.250 NPHI.CSG -999.250 CNTC. CSG 1767.185 20.668 3358.178 1686.979 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 mATE · 97/01/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/01/ 2 ORIGIN : FLIC TAPE NAFIE : 96351 CONTINUATION # : 1 PREVIOUS TAPE : COMME2VT : ARCO ALASKA INC, D.S. 05-40, PRUDHOE BAY, API #50-029-22707-00 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 97/01/ 2 ORIGIN : FLIC REEL NAME : 96351 CONTINUATION # : PREVIOUS REEL : COM2~JT~ · ARCO ALASKA INC, D.S. 05-40, PRUDHOE BAY, API #50-029-22707-00