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Home My WebLink About191-105 Pages NOT Scanned in this Well History File · · XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~'/'"/~" File Number of Well History File PAGES TO DELETE RESCAN Complete 1:3 n DIGITAL DATA Color items - Pages: Grayscale, halftones, pictures, graphs, charts- . Pages: Poor Quality Original - Pages: Other- Pages: Diskettes. No. Other, No/Type OVERSIZED · . . , Logs-of vadous kinds . Other COMMENTS: Scanned by: Bevy/Dian~Natha. Lowell · TO RE-SCAN Date: Notes: - Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is/ '\ STATE OF ALASKA ) ALASKA v1L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged 181 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: GR I RES I CNL I SONIC I SP, CET I CBT I GR, GCT GYRO CASING, LINER AND CEMENTING RECORD SETTING DEPTH. MD' ,.SETTINGDEPTHTVD HOLÈ Top BOTTOM:. Top BOTTOM' SIZE Surface 110' Surface 110' 30" Surface 3892' Surface 3521' 13-1/2" 3945' 9583' 3566' 8462' 9-7/8" 9280' 10286' 8193' 9096' 6-3/4" 0 GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2203' NSL, 1194' EWL, SEC. 32, T11N, R15E, UM Top of Productive Horizon: 2880' NSL, 226' EWL, SEC. 33, T11N, R15E, UM Total Depth: 2877' NSL, 411' EWL, SEC. 33, T11N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 698282 y- 5948397 Zone- ASP4 TPI: x- 702572 y- 5949189 Zone- ASP4 Total Depth: x- 702757 y- 5949190 Zone- ASP4 18. Directional Survey 0 Yes 181 No 22. CASING SIZE 20" WT. PER FT. 91.5# 45.5# 29# 17# GRADE H-40 J-55 L-80 13Cr80 10-3/4" 7-5/8" 5-1/2" 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD TUBING RECORD SIZE DEPTH SET (MD) 3-1/2",9.2#, L-80 8930' - 9142' 2-7/8",6.4#, 13Cr80 9142' - 9964' , 25; ACID, fRACTURE,' ÇEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6465' Set EZSV at 6465'; P&A wI 40 Bbls Class 'G'; 6378' (Approx.) Sting in and inject cmt below EZSV. Place 4 Bbls on top of EZSV. Set 2nd EZSV at 4100' Set 45 Bbls Cmt Kick Off Plug Zero Other 5. Date Comp., Susp., or Aband. 11/7/2004 6. Date Spudded 07/31/1991 7. Date T. D. Reached 08/13/1991 8. KB Elevation (ft): 70' 9. Plug Back Depth (MD+ TVD) 9000 + 7943 10. Total Depth (MD+ TVD) 10290 + 9100 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 24. TVD 26. Date First Production: Not on Production Date of Test Hours Tested 3891' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-Bsl PRODUCTION FOR TEST PERIOD -+ Flow Tubing Casing Pressure CALCULATED....... Oll-BSl Press. 24-HoUR RATE""'" GAs-McF W A TER-Bsl REceIVED JAN 0 7 2005 Alaska Oil J{¡ Cons. Commiss~'n 1 b. Well Class: . 181 Developmenl'~g~atory 0 Stratigraphic 0 Service 12. Permit to Drill Number 191-105 304-385 13. API Number 50- 029-22204-00-00 14. Well Name and Number: PBU 05-24 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028325 17. Land Use Permit: GAs-McF W ATER-Bsl 20. Thickness of Permafrost 1900' (Approx.) CEMENTING RECORD 11 Yards Arcticset AMOUNT PULLED 1300 sx CS III, 350 sx 'G', Top Job: 184 sx CS II 675 sx Class 'G', 254 sx Class 'G' 120 sx Class 'G' PACKER SET (MD) 8976' 9948' CHOKE SIZE GAS-OIL RATIO Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None SCi~N~~Er;. N -; 2f1fP: ~~ ...- ï.} "'...~} Form 1 0-407 Revised 12/2003 OR\G\NAL CONTINUED ON REVERSE SIDE RBDMS BFL .IAN ff) Z005 \s~ 128. ) 29. ) FORMATION TESTS GEOLOGIC MARKERS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 9475' 8366' None Shublik 9520' 8406' Top Sadlerochit I Zone 4 9596' 8473' Zone 3 9768' 8625' Zone 2 9833' 8683' Zone 1 B 10050' 8878' Base Sadlerochit 10144' 8964' 30. List of Attachments: Summary of Pre-Rig work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie HUbble~~..e_J-ltl~ Tide Technical Assistant Date 01/0& ( b5 PBU 05-24 191-105 304-385 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Dave Wesley, 564-5153 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None", ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ) ) Well: Field: API: Permit: 05-24A Prudhoe Bay Unit 50-029-22204-01-00 204-218 Accept: Spud: Release: Rig: 11/01/04 11/12/04 11/29/94 Nabors 2ES PRE-RIG WORK 04/26/04 DRIFT TO 8330' WLM WI 2.79" CENT & S-BLR. BAILER FULL OF CEMENT. (-8930' TARGET DEPTH) 05/16/04 FCO. RIH WITH 2.0" JSN W/DOWN JETS. TAG HARD SAND TOP @ 8353'. CLEANOUT TO 9010' CTM. MAKE 6 UPIDOWN PASSES AND FINAL UP PASS PUMP 20 BBLS 1.5 BIO, CHASE OUT AT 80%, FROM 9000'. FREEZE PROTECTED TUBING TO 3000' WITH METHANOL. OS/25/04 DRIFT TGB W 12.72" CENT. SET ON IN 3 1/2 X 2718 XO @ 8974' SLM. RDMO. LEAVE WELL SHUT-IN, READY FOR CHEM CUT. OS/27/04 SHOT CHC AT 8930' AS PER PROGRAM. STRING SHOT FROM 8920'-8932'. DEPTH CORRECTED TO TUBING TALLY 5-25-93. LOST LOWER HALF OF THE SEVERING HEAD AND LOWER CENTRALIZER. OS/28/04 WELL SHUT-IN UPON ARRIVAL DRIFT WITH 2.70" CENT AND 2.50" LIB TO 8890 SLM. 06/04/04 TAG TO WI 2.5 LIB @ 8916' SLM. LIB SHOWED SAND AND NO FISH. (SAND TOP TAG IS 58' HIGHER THAN IT WAS PRIOR TO CUTTING THE TBG) TAG TOP OF TBG CUT STUB @ 8890' SLM WI 2.75 LIB. (TBG CUT SHIFTED) 06/05/04 RAN 2.77 TUBING SWEDGE TO 8888 SLM COULD NOT PASS. RAN 2.77 DECENTRALlZER AND 2.75 LIB TO 8845 SLM. COULD NOT PASS. RAN 2.77 DECENTRALlZER AND 2.75 LIB TO 8886 SLM. MARKS INDICATE HITTING ON HIGH SIDE. RAN 2.250 BAILER TO 8886 SLM. REC 1 GALLON OF SAND. RIG DOWN, INSPECTED AREA, CALLED DSO, LEFTWELL SHUT IN. ) ) Page 1 .. BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 11/1/2004 Rig Release: 11/29/2004 Rig Number: Spud Date: 7/31/1991 End: 11/29/2004 Date From - To Hours Task Code NPT Phase Description of Operations 10/31/2004 05:30 - 00:00 18.50 MOB P PRE Blow Down And Disconnect Utilities Between Pit Complex And Sub Base - Move Cuttings Tank - Lower Cattle Shoot - Lay Mast Over And Pull Sub Base Off Of Well - Have Pre-Job Safety Meeting With Security, CPS, And Rig Team. Move rig to 5-24A 11/1/2004 00:00 - 04:30 4.50 MOB P PRE Transport sub from J Pad to DS 5. Prep and spot sub. Camp and pits left J Pad at 01 :30. 04:30 - 06:00 1.50 RIGU P PRE Set welding shop. Set mats and pits. 06:00 - 10:00 4.00 RIGU P PRE Troubleshoot SCR's. 10:00 - 12:00 2.00 RIGU P PRE Raise and pin derrick. Raise cattle shoot. Bridal down. Spot shop. 12:00 - 15:00 3.00 RIGU P PRE Spot cuttings tank and berm same. Rig up floor, spot shop landings. 15:00 - 15:30 0.50 P DECOMP Hold pre-operation HSE and PJS meeting with WSL, TP and all crew/drivers. 15:30 - 16:00 0.50 RIGU P Rig accepted for well work at 15:00 hours. DECOMP Install gauges and take pressure readings. 16:00 - 16:30 16:30 - 20:30 0.50 WHSUR P 4.00 CLEAN P DECOMP DECOMP 20:30 - 21 :00 0.50 EVAL P DECOMP 21 :00 - 22:30 1.50 WHSUR P DECOMP 22:30 - 00:00 1.50 BOPSUR P DECOMP 11/2/2004 00:00 - 01 :30 1.50 BOPSUR P DECOMP 01 :30 - 08:00 6.50 BOPSUR P DECOMP 08:00 - 08:30 0.50 BOPSUR P DECOMP 08:30 - 09:30 1.00 WHSUR P DECOMP 09:30 - 10:30 1.00 PULL P DECOMP 10:30 -11:00 0.50 PULL P DECOMP 11:00 -13:30 2.50 PULL P DECOMP 13:30 - 15:00 1.50 PULL P DECOMP 15:00 - 16:00 1.00 PULL P DECOMP OA = 0 psi IA = On Vac. Tbg = 0 psi Rig up DSM lubricator. Pull BPV. Rig down DSM. Rig up and test lines to 3,500 psi. Reverse circ 35 bbls fresh water. No returns noted. Change lines to pump down tubing. Pump 45 bbl soap spacer down tubing and displace well to 9.8 NaCI at 4 bpm. Taking all returns through choke to cuttings tank. Had returns during circulation. After shutting pumps down, tubing and well on vacuum. FMC dry rod BPV. Attempt to test from below. Filled void at 5 bpm at 200 psi. At 11 bbls away noted a 100 psi increase. Observed BPV and no leaks seen. Shut pumps down. Bleed off control line pressure. Nipple down tree and adapter and remove same from cellar. Screw XO into hanger. Install blanking plug. Install DSA and nipple up BOPE. Continue Nipple Up BOPE. Make up/Lay down 4.5" test joint. Test BOPE to 250 psi Low / 3,500 psi High, Annular tested to 250 psi Low - 2,500 psi High. Tested stack with both 4.5" and 3.5" test joints. Test witnessed by AOGCC Rep., John Crisp. Blow down all lines. Pull blanking plug. Break and lay down test joints. Make up lubricator. Pull BPV. Lay down lubricator. Rig up to pull completion tubing. Make up landing joint and make up to hanger. Attempt to pull tubing free. No success. Max pull 225K. Hole fill on fresh water. Land hanger. Lay down drill pipe landing joint. Change out bales and elevators. Pick up 4.5" tubing landing joint. Make up XO's and safety valve. Make up landing joint to hanger. Establish overpulVstretch measurements. Pick up and set slips. 165K Up Weight. 50K overpull. Circulate over top of hole with fresh water with hole fill pump. Losses average 1 Printed: 12/612004 10:55:25 AM ) ') BP EXPLO~TION Operations Summary Report Page 2- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 11/1/2004 Rig Release: 11/29/2004 Rig Number: Spud Date: 7/31/1991 End: 11/29/2004 Date From - To Hours Task Code NPT Phase Description of Operations 11/212004 15:00 -16:00 1.00 PULL P DECOMP BPH. 16:00 - 18:30 2.50 PULL P DECOMP PJSM with SWS and crew. Rig up e-line tools. 18:30 - 20:00 1.50 PULL P DECOMP Run in hole with chemical cutter. Make cut at 8,830'. E-line had good indication of cutter firing, no reaction at surface. 20:00 - 21 :30 1.50 PULL P DECOMP POOH with chemical cutter. PJSM prior to laying down cutter head. When tool out of hole noted half of firing head and bottom centralizer left in hole. Length of fish -2.5'. 21 :30 - 22:30 1.00 PULL P DECOMP Make up XO and TDS. Work tubing with 225K maximum up weight. Tubing not free. Break circulation at 6 BP, 300 psi and continue to work pipe. No success. Disconnect and blow down TDS. 22:30 - 23:30 1.00 PULL P DECOMP PJSM. Rig up SWS to RIH with free point. 23:30 - 00:00 0.50 PULL P DECOMP RIH on e-line with free point BHA. Problem with e-line rubbing TDS. Note: Losses at midnight averaging 1 BPH 11/3/2004 00:00 - 02:30 2.50 PULL P DECOMP SWS wire rubbing TDS due to close proximity of entry sub to TDS. POOH with wireline. Break entry sub and XO's. Make up side entry sub. 02:30 - 03:30 1.00 PULL P DECOMP RIH with free point tools to 3,200' and calibrate. 03:30 - 04:30 1.00 PULL N DFAL DECOMP SWS tool failure. Anchors not setting properly. POOH to change out tool. 04:30 - 07:30 3.00 PULL N DFAL DECOMP SWS troubleshooting tools. Tools OK. Found dead ground in wire. Troubleshooting same. 07:30 - 13:30 6.00 PULL P DECOMP SWS running free point. Established 100% stuck at 6,895' and 98% free at 6,825'. 13:30 - 14:30 1.00 PULL P DECOMP POOH with wireline and lay down free point tools. 14:30 - 15:30 1.00 PULL P DECOMP Break off and lay down side entry sub and DP single. 15:30 - 16:30 1.00 PULL P DECOMP Make up SWS tubing punch tools. 16:30 - 19:30 3.00 PULL P DECOMP RIH with tubing punch tools and perf 3.5" tubing from 8,470' to 8,472.5'. POOH and lay down punch tools. 19:30 - 22:00 2.50 PULL P DECOMP PJSM. Make up string shot tools. 22:00 - 23:30 1.50 PULL P DECOMP SWS RIH with string shot. Top of shot at 8,439', bottom at 8,451'. POOH and lay down string shot tools. 23:30 - 00:00 0.50 PULL P DECOMP Pull string into tension and set in slips with 150K up weight. Make up chemical cutter tools. Note: All depths are ELM. Zero BPH losses. 11/4/2004 00:00 - 01 :30 1.50 PULL P DECOMP PJSM. SWS make up chemical cutter assembly. 01 :30 - 04:00 2.50 PULL P DECOMP RIH with chemical cutter. Correlate depths. Set cutter head on depth, 8,450'. Fire cutter. Positive indication of cutter firing in SWS control cab, no indication of tubing free at surface. POOH and lay down cutter assembly. 04:00 - 04:30 0.50 PULL P DECOMP Connect TDS. Attempt to pull completion tubing. Work tubing with 225K maximum up weight. Tubing not free. 04:30 - 05:30 1.00 PULL P DECOMP SWS make up 2.68" Jet Cutter assembly. 05:30 - 08:00 2.50 PULL P DECOMP SWS RIH with Jet Cutter assembly to 6,800'. Fire cutter. POOH and lay down cutter tools. Pull 105K, pipe free. 08:00 - 09:00 1.00 PULL P DECOMP Rig down wireline. Clear floor of all tools. 09:00 - 09:30 0.50 PULL P DECOMP Rig up to pull and lay down tubing and spool control lines. 09:30 - 10:00 0.50 PULL P DECOMP Pull hanger to floor. Disconnect chemical injection and control lines. Break off and lay down hanger and landing joint. Printed: 12/6/2004 10:55:25 AM ') ) Page 3 ... BP EXPLORATION OperationsSumrnaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT Phase 11/4/2004 10:00 - 11 :00 1.00 PULL P DECOMP 11 :00 - 17:30 6.50 PULL P DECOMP 17:30 - 20:00 2.50 PULL P DECOMP 20:00 - 21 :30 1.50 PULL P DECOMP 21 :30 - 00:00 2.50 PULL P DECOMP 11/5/2004 00:00 - 01 :30 1.50 PULL P DECOMP 01 :30 - 03:00 1.50 PULL P DECOMP 03:00 - 05:00 2.00 FISH P DECOMP 05:00 - 06:30 1.50 BOPSUR P DECOMP 06:30 - 07:00 0.50 BOPSUR P DECOMP 07:00 - 07:30 0.50 BOPSUR P DECOMP 07:30 - 09:30 2.00 FISH P DECOMP 09:30 - 14:00 4.50 FISH P DECOMP 14:00 - 15:30 1.50 FISH P DECOMP 15:30 - 16:00 0.50 FISH P DECOMP 16:00 - 16:30 0.50 FISH P DECOMP 16:30 - 18:00 1.50 FISH N RREP DECOMP 18:00 - 00:00 6.00 FISH P DECOMP Start: 11/1/2004 Rig Release: 11/29/2004 Rig Number: Spud Date: 7/31/1991 End: 11/29/2004 Description of Operations Change out bails. Connect control lines to spooler. POOH laying down 4.5" tubing. Spooling control line and chemical injection line. Recovered 69 joints of tubing, SSSV, 2 flow couplings and 2 pups, 69 4.5" clamps and 3 SS bands. Change out elevators, clear and clean rig floor. POOH laying down 3.5" tubing and spooling chemical injection line to first GLM. Hole not taking proper fill. Monitor well, slight flow. Make up circulating sub. Circulate hole volume at 3,000' with 9.5 ppg salt water at 12 bpm, 690 psi. Stop circulation and monitor well. Hole now taking fluid. Control line spool full, change out same. Continue laying down 3.5" tubing from 3,000' to 1,260' while spooling chemical injector line. Static losses=20 bph. Continue POOH laying down 3.5" tubing. Found one hole in 3.5" tubing calculated to have been at 6,301' MD. Total 3.5" out - 119 joints, 2 GLM's, 1 cut joint (15.08'). Retrieved 6,790 feet of chemical injection line, 10 SS bands and 105-1/2 clamps. Top offish estimated at 6,781'. Lay down control line tools and spooler. Clear and clean rig floor. Rig up to test BOP with 4" drill pipe. Drained stack to run test joint and test plug. Could see several clamps laying across spool. Make up magnet and retrieve 12-1/2 clamps. Total 3.5" clamps recovered = 118. Rig up and test BOP with 4" drill pipe. Test rams to 250 psi low - 3,500 psi high. Test annular preventer to 250 psi low- 2,500psi high. Install wear bushing, lay down test joint. Clean rig floor Pick up wash pipe BHA assembly to 442'. Pick up 4" drill pipe from 442' to 5,878'. Tagged obstruction. Rotate from 5,878' to 5,946'. 80-100 RPM, 5K-6K Torque. POOH 9 stands to 5,105' to pick up singles to get back to 5,800'. Pick up drill pipe singles to 5,631'. Problem with TDS lube oil pump. Replace lube oil switch on top drive. RIH with wash pipe from 5,631' to 6,747'. Pump and ream as required. Ream: 6,156' to 6,165' 6,257' to 6,263' 6,357' to 6,747' 11/6/2004 P 135K UP, 115K ON, 130K ROT, 90 RPM, 10K WOB, 5K-10K TORO, 70 SPM, 170 GPM, 350 PSI DECOMP Washing and reaming from 6,747' to 6,748'. 00:00 - 01 :30 1.50 FISH 01 :30 - 04:30 3.00 FISH P DECOMP 04:30 - 05:00 0.50 FISH P DECOMP 135K UP, 115K ON, 130K ROT, 90 RPM, 10K WOB, 5K-10K TORO, 70 SPM, 170 GPM, 350 PSI Pump slug, blow down TDS. POOH to examine wash over shoe from 6,478' to BHA at 442'. Rack back drill collars. Printed: 12/612004 10:55:25 AM ) ') BP EXPLORATION Operations Summary Report Page 4- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 11/1/2004 Rig Release: 11/29/2004 Rig Number: Spud Date: 7/31/1991 End: 11/29/2004 Date From - To Hours Task Code NPT Phase Description of Operations 11/6/2004 05:00 - 06:30 1.50 FISH P DECOMP Pull wash over shoe to surface. 2.99' of the shoe was missing. Remainder of shoe and wash pipe packed with SS control line. lay down shoe and wash pipe. lay down and clean out boot baskets. 06:30 - 07:30 1.00 FISH P DECOMP Pick up new shoe and one joint of wash pipe. RIH with BHA to 441'. 07:30 - 09:00 1.50 FISH P DECOMP RIH to 6,400'. 09:00 - 10:00 1.00 FISH P DECOMP Slip and cut drill line. 10:00 - 10:30 0.50 FISH P DECOMP Service TDS. 10:30 - 12:00 1.50 FISH N RREP DECOMP Traction motor caliper brakes not working. Install hose, repair brake fluid reservoir fitting, test systems. 12:00 - 12:30 0.50 FISH P DECOMP RIH from 6,400' to 6,744'. 12:30 - 18:30 6.00 FISH P DECOMP Reaming junk from 6,744' to 6,758'. 8K WOB 100 RPM 5K-12K TQ 98 SPM 240 GPM 550 PSI Shoe worn out. 18:30 - 21 :00 2.50 FISH P DECOMP POOH from 6,758' to 441' 21:00 - 22:30 1.50 FISH P DECOMP lay down shoe and wash pipe. 1.5' of shoe worn away. lay down boot baskets and clean. Slivered pieces of SS control line in boot baskets. 22:30 - 23:30 1.00 FISH P DECOMP Make up boot baskets, new joint of 5-9/16" 10 wash pipe and 6.75" 00 shoe. RIH with drill collars to 441'. 23:30 - 00:00 0.50 FISH P DECOMP Pick up drill pipe singles, RIH to 908' 1117/2004 00:00 - 01 :30 1.50 DHB P DECOMP Continue RIH picking up drill pipe from 908' to 3,428'. 01 :30 - 02:30 1.00 DHB P DECOMP RIH with stands from derrick from 3,428' to 6,489'. Tagged obstruction. Set down 30K, no movement. 02:30 - 03:00 0.50 DHB P DECOMP Attempt to work through obstruction. No success. Discuss with Anchorage team. 03:00 - 04:30 1.50 DHB P DECOMP Detected pit gain with pumps off. Flow check, well flowing. Weighting up to 9.4 ppg salt water. With 9.4 ppg salt water around, well static. 04:30 - 06:30 2.00 DHB P DECOMP Blow down TDS. POOH from 6,489' to 441'. Encountered tight spot at 6,150', pulled through with 50K. 06:30 - 08:30 2.00 DHB P DECOMP Lay down BHA. Clear and clean rig floor. 08:30 - 09:30 1.00 DHB P DECOMP Make up RTTS and RIH to 1,503'. 09:30 - 10:00 0.50 DHB P DECOMP lubricate rig, service TDS. 10:00 - 11:30 1.50 DHB P DECOMP RIH from 1,503' to 4,105'. 11:30 -12:00 0.50 DHB P DECOMP Set RTTS and test 7-5/8" casing to 3,500 psi for 15 minutes, good test. Unseat RTTS. 12:00 - 13:00 1.00 DHB P DECOMP RIH from 4,105' to 6,470'. 13:00 - 13:30 0.50 DHB P DECOMP Set RTTS and test 7-5/8" casing to 3,500 psi for 30 minutes, good test. 13:30 - 15:00 1.50 DHB P DECOMP Bring pump up slowly to 5 BPM. Establish injection rate. 5 BPM @ 500 psi. Unseat RTTS. Blow down TDS. 15:00 - 17:30 2.50 DHB P DECOMP POOH and lay down RTTS. 17:30 - 18:00 0.50 DHB P DECOMP Make up running tool and EZSV. 18:00 - 21 :00 3.00 DHB P DECOMP RIH with EZSV to 6,465'. 21 :00 - 22:00 1.00 DHB P DECOMP Make up cement head. Break circulation. Set EZSV at 6,465' with 35 right hands turns. Establish injection rate at 3 BPM @ 400 psi. 22:00 - 23:00 1.00 DHB P DECOMP Rig up Dowell. Hold PJSM. Pump 5 bbls fresh water. Test lines to 4,500 psi, good test. Mix and pump 40 BBlS (200 sx), Class G 15.8 PPG cement. Displace with Dowell, using 9.2 Printed: 12/612004 10:55:25 AM ) ) BP EXPLORATION Operð~ions.'Summary~øport Page 5 ,.. Legal Well Name:. Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 11/1/2004 Rig Release: 11/29/2004 Rig Number: Spud Date: 7/31/1991 End: 11/29/2004 Date From - To Hours Task . Code NPT Phase Description of Operations 1117/2004 22:00 - 23:00 1.00 DHB P DECOMP PPG brine. Total pipe displacement 64.5 BBlS. At 60.6 BBlS displacement away, pressure reached 2,500 PSI. Shut down pumping. Release from EZSV. Dump remaining 4 BBlS cement on top of EZSV. POOH from 6,465' to 5,998'. 23:00 - 00:00 1.00 DHB P DECOMP Circulate bottoms up at 5.5 BPM, 600 PSI. lay down cementing equipment. 11/8/2004 00:00 - 03:00 3.00 DHB P DECOMP Install saver sub. POOH and lay down EZSV running tool. 03:00 - 03:30 0.50 DHB P DECOMP Test 7.625" casing to 3,500 psi for 30 minutes. Record on circular chart, good test. 03:30 - 05:30 2.00 DHB P DECOMP Make up running tool and EZSV. RIH to 4,100' 05:30 - 06:00 0.50 DHB P DECOMP Set EZSV with 35 right hand turns. Release from EZSV and check set. 06:00 - 07:30 1.50 DHB P DECOMP POOH from 4,100'. lay down EZSV running tool. 07:30 - 09:30 2.00 CASE P DECOMP Change out 3.5" X 6" variable rams to 7.625". Pull wear bushing, set test plug. Test doors seals to 3.500 psi, good test. Pull test plug, set wear bushing and rig down test equipment. 09:30 - 11 :30 2.00 CASE P DECOMP Make up 7.625" string cutter to 10'. RIH with drill pipe to 4,000'. Install blower hose. 11:30 - 12:30 1.00 PUll P DECOMP locate collar and position cutters at 3,975', 5' below a collar. Pumps up to 1,500 psi. Cut 7.625" casing. 12:30 - 13:00 0.50 PUll P DECOMP Attempt to circulate. Unsuccessful. 750 psi max. 13:00 - 14:30 1.50 PUll P DECOMP POOH from 3,975'. Lay down cutter assembly. 14:30 - 15:30 1.00 PUll P DECOMP Make up 7.625" casing spear assembly. Pull wear bushing. 15:30 - 16:00 0.50 PUll P DECOMP Spear and latch onto 7.625" casing. Back out lock down screws. Attempt to pull casing, unsuccessful. Maximum hook weight, 375K. 750 psi on pumps. 16:00 -17:30 1.50 PUll P DECOMP POOH and lay down spear assembly. 17:30 - 20:30 3.00 PUll P DECOMP Make up 7.625" cutter assembly with new knives. RIH and locate collar at 3.888'. Pull up to 3,853' (5' below collar). Cut 7.625" casing. When cutters through, OA pressure increased to 400 psi. 20:30 - 21 :00 0.50 PUll P DECOMP Circulate 7.625" X 10.75" annulus at 6 bpm at 1,100 psi until returns cleaned up. Total 185 bbls dumped to cuttings tank. 21 :00 - 23:30 2.50 PUll P DECOMP Blow down all lines and cap all valves. POOH from 3,853'. lay down cutting assembly. 23:30 - 00:00 0.50 PUll P DECOMP Make up spear assembly, RIH and engage 7.625" casing below well head. Back out lock down screws. Pull casing free with 135K up weight. Pull hanger to floor. 11/9/2004 00:00 - 00:30 0.50 PUll P DECOMP lay down hanger and clear rig floor. 00:30 - 01 :30 1.00 PUll P DECOMP Rig up to pull 7.625" casing. 01 :30 - 05:00 3.50 PUll P DECOMP Pull and lay down 7.625" casing. Hanger, 1 pup joint. 90 full joints, 1 cutoff joint (8.37) layed down. 05:00 - 06:30 1.50 PUll P DECOMP Rig down casing equipment. Clear and clean the floor. 06:30 - 08:30 2.00 FISH P DECOMP MU Baker Fishing Spear BHA to 322'. 08:30 - 09:30 1.00 FISH P DECOMP RIH with spear to the top of the 7-5/8" casing stub @ 3.853'. PU - 105K, SO - 9OK. 09:30 - 11 :30 2.00 FISH P DECOMP RIH to 3,891' to the stop ring and engage the top of the casing stub. Jar on casing stub - unsuccessful. Fire Jars - 300K, Max Pull atter firing - 400K. 11:30 -12:00 0.50 FISH P DECOMP Perform visual inspection of the derrick and the top drive. 12:00 - 13:30 1.50 FISH P DECOMP POH w/4" DP from 3,853' to 322'. 13:30 - 14:00 0.50 FISH P DECOMP lD Spear BHA from 322'. Printed: 12/6/2004 10:55:25 AM ) ) BP', EXPLORATION Operations...Summary.'.Report Page 6 ... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 11/1/2004 Rig Release: 11/29/2004 Rig Number: Spud Date: 7/31/1991 End: 11/29/2004 Date From-To Hours Task Code NPT Phase Description of Operations 11/9/2004 14:00 - 14:30 0.50 FISH P DECOMP MU 7-5/8" Cutting BHA and RIH to 3,936'. 14:30 - 15:30 1.00 FISH P DECOMP RIH w/4"DP to 3,936'. 15:30 - 16:00 0.50 FISH P DECOMP RIH with pupms on and locate collar@ 3,971'. PU and cut 7-5/8" casing @ 3,936' - 65 rpm, 296 gpm, 200 psi, Rot - 85K, PU - 95K, SO - 80K. 16:00 - 17:30 1.50 FISH P DECOMP POH from 3,936'. LD Cutting BHA. 17:30 - 18:30 1.00 BOPSUR P DECOMP Change top set of rams to 3-1/2" x 6" variable rams. MU test joint and set test plug. 18:30 - 22:30 4.00 BOPSUR P DECOMP Test BOPE to 250 psi/3500 psi. Test annular to 250 psi/2500 psi. Witness of the BOP test was waived by Jeff Jones of the AOGCC. 22:30 - 23:00 0.50 FISH P DECOMP MU Spear BHA to 322', 23:00 - 23:30 0.50 FISH P DECOMP RIH from 322' to top of the casing stub @ 3,853'. RIH to 3,891 to the stop ring and engage the spear. 23:30 - 00:00 0.50 FISH P DECOMP Jar on casing stub - unsuccessful. Fire Jars - 300K. Max Pull after firing - 400K. 11/10/2004 00:00 - 00:30 0.50 FISH P DECOMP Jar on casing stub @ 3,853' - unsuccessful. Fire Jars - 300K. Max Pull after firing - 400K. 00:30 - 01 :00 0.50 FISH P DECOMP Inspect the derrick and top drive. 01 :00 - 02:00 1.00 FISH P DECOMP Slip and cut drilling line. Inspect brakes 02:00 - 04:00 2.00 FISH P DECOMP POH wI 4" DP from 3,853' to 322'. LD spear BHA. Clear floor. 04:00 - 04:30 0.50 FISH P DECOMP PU 7-5/8" Cutting BHA. 04:30 - 05:30 1.00 FISH P DECOMP RIH with 4" DP to top of the tubing stub @ 3,853'. Install Blower hose. PU - 90K, SO - 80K, Rot - 85K. 05:30 - 06:30 1.00 FISH P DECOMP RtH and cut 7-5/8" casing @ 3,893' -13 bpm, 1,500 psi. 06:30 - 08:00 1.50 FISH P DECOMP Pump dry job and remove the blower hose. POH w/4" DP from 3,893'. LD casing cutter. 08:00 - 09:00 1.00 FISH P DECOMP MU spear assembly w'6.767" grapple. RIH with Spear BHA to 322'. 09:00 - 10:30 1.50 FISH P DECOMP Change out the elevators and RtH with 4" DP from 322' to 3,853'. 10:30 - 11 :00 0.50 FISH P DECOMP Engage the top of the 7-5/8" casing stub @ 3,853'. PU - 108K, SO - 91K. RIH to the stop ring @ 3,861'. PU to 200K and bleed off jars. Straight pull to 325K. Fish started to drag out of the hole. Once fish was free, PU - 11 OK. 11 :00 - 12:30 1.50 FISH P DECOMP POH with 4" DP from 3,853' to 322'. Change out elevators. Stand back BHA from 322' to 32'. 12:30 - 13:00 0.50 FISH P DECOMP Break off and LD 39.87' of 7-5/8" fish + 1 centralizer from casing cut @ 3,893'. LD fishing tools and clear the floor. 13:00 - 14:00 1.00 FISH P DECOMP MU Metal Muncher Milling BHA to 317'. 14:00 -15:30 1.50 FISH P DECOMP RIH with 4" DP to 3,893', 15:30 - 16:00 0.50 FISH P DECOMP Displace well over to hi-visc milling fluid. 16:00 - 00:00 8.00 FISH P DECOMP Mill on 7-5/8" casing stub from 3,893' to 3,926'. TO on - 7K, TO off - 5K, 115 rpm, 5k WOB. 475 gpm. 11/11/2004 00:00 - 06:00 6.00 FISH P DECOMP Mill on 7-5/8" casing stub from 3,926' to 3,945'. TO on - 7K, TQ off - 5K, 115 rpm, 5k WOB. 475 gpm. 06:00 - 07:30 1.50 FISH P DECOMP Pump Super Sweep. CBU. Work pipe @ 3,945'. 11 bpm, 600 psi. Monitor well - static. Pump dry job and remove the blower hose. Blow down surface equipment. 07:30 - 09:00 1.50 FISH P DECOMP POH w/4" DP from 3,945' to 316'. Change out handling equipment. 09:00 - 09:30 0.50 FISH P DECOMP Stand back BHA from 316' to 26'. LD BHA. Clean and clear the floor. Printed: 12/612004 10:55:25 AM " ,. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) Page 7 tI8Þ BP EXPLORATION Operations Summary Report 05-24 05-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From -To Hours Task Code NPT Phase DECOMP 11/11/2004 09:30 - 10:30 10:30 - 11 :00 11:00 - 13:00 13:00 - 14:00 14:00 - 15:30 15:30 -16:30 16:30 - 18:00 18:00 - 18:30 18:30 - 19:00 19:00 - 22:30 22:30 - 23:00 23:00 - 00:00 11/12/2004 00:00 - 01:00 01 :00 - 01 :45 01 :45 - 02:30 02:30 - 03:00 03:00 - 05:00 05:00 - 10:30 10:30 - 13:00 13:00 - 13:30 13:30 - 00:00 11/13/2004 00:00 -12:00 12:00 - 00:00 1.00 FISH P Start: 11/1/2004 Rig Release: 11/29/2004 Rig Number: Spud Date: 7/31/1991 End: 11/29/2004 0.50 FISH P 2.00 REMCM-P DECOMP WEXIT Description of Operations Flush the stack and all surface equipment of metal cuttings. Blow down all surface equipment. Service and set the wear ring. MU Mule Shoe on 4" DP. RIH to 2,900'. Pipe not taking the proper fill. Break circulation. RIH w/4" DP from 2,900' to 4,100' - wash and ream @ 3,943' and 4,060'. Circulate nut plug sweep @ 4,090'. POH to 3,925' to clear 7-5/8" casing stub. RIH to 4,090' Rig up Schlumberger cementers. Pump 5 bbls water and test lines to 4,500 psi. Batch mix and pump 45 bbls of 17 ppg cement kick of plug. Displace cement w/32 bbls 8.4 ppg mud and balance plug in place. CIP @ 1500 hrs. POH to 3,457'. CBU. POH from 3,457'. LD Mule Shoe. Bring 8-3/4" BHA components to the rig floor. Service the top drive. PU 8-3/4" BHA to 1,595'. Orient and upload MWD. 8-3/4" BHA: Hughes HCM605, 7" motor w/6 stg and 7/8 lobe @ 1.5 bend, non-mag pony collar, 8-5/8 sleeve type stabilizer, non-mag float sub, 6-3/4" GRlRES/PWD, 6-3/4" DM HOC, 6-3/4" TM HOC, 3 x non-mag dc's, 9 x dc's, 15 x hwdp, jar, 8 x hwdp, 12 x 5" DP, Weatherford Ghost Reamer, xo. RIH w/4" DP to 2,715'. Hole not taking proper fill, circulate bottoms up. Well static. RIH from 2,715' to 3,367'. PU -145K, SO -105K. Connect blower hose and fill pipe. Wash down from 3,367' and tag the top of cement @ 3,575' - 2 bpm, 300 psi. Pressure test 10-3/4" J-55 casing to 2,500 psi and hold for 30 minutes - good test. Drill cement from 3,575' to 3,675'. Clabbered up mud at the shakers. Circulate and condition mud @ 3,675'. Drill cement and 20' new formation to 3,965'. Displace well over to 9.8 ppg LSND drilling fluid. Clean beneath shakers. Perform FIT to 12.5 Ppg' Drill Directionally from 3,965' to 5,230'. AST - 2.69, ART- 3.41, PU - 165K, SO - 115K, ROT - 140K, TO on - off - 8K Drill Directionally from 5,230' to 6 U - 190K, SO - 125K, ROT -155K, TO on -13 off -12K. AST - 0.95, ART- 7.15. Drill D' nally from 6,353' to 7,253'. PU - 200K, SO - 135K, -165K, TO on - 12K, TO off - 11K. AST - 1.88, ART - 7.02. Drill 8-3/4" Directionally from 7,253' to 7,951'. PU - 215K, SO- 140K, ROT -175K, TO on -15K, TQ off -13K. AST - 0.59, ART - 6.96. Washout of valve and seat on #1 mud pump. Changeout valve and seat. Drill Directionally from 7,951' to 8,675'. PU - 230K, SO -145K, 11/14/2004 00:00 -11:00 1.00 REMCM-P WEXIT 1.50 REMCM-P WEXIT 1.00 REMCM-P 1.50 REMCM-P 0.50 STWHIP P 0.50 STWHIP P 3.50 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT 0.50 STWHIP P 1.00 STWHIP P 1.00 STWHIP P WEXIT WEXIT WEXIT 0,75 STWHIP P WEXIT 0.75 REMCM-P WEXIT 0.50 STWHIP P WEXIT 2.00 STWHIP P 5.50 STWHIP P 2.50 STWHIP P WEXIT WEXIT WEXIT 0.50 STWHIP P 10.50 DRILL P WEXIT INT1 12.00 DRILL P INT1 12.00 DRILL P INT1 11.00 DRILL N RREP INT1 12.50 DRILL P INT1 Printed: 12/612004 10:55:25 AM ') I q I - 10 ~ ) Su bject: 5-24 update From: "Wesley, Dave En <WesleyDE@BP.com> Date: Mon, 08 Nov 2004 07:22:30 -0900 To: 'Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> Winton, As we discussed over the weekend, the numbers are as follows. The RTTS was run and set at 6,470'md. The 7 5/8" casing tested to 3,500psi. Afterward, the rig set the 7 5/8" EZSVat 6,465'md,(-5,737'tvd). Established injection and placed 36bbls of class 'G' 15.8ppg cement below the retainer. This filled the void from 6,465' to the TOF at 6,781'md, plus possibly some in the 3 1/2" X 7 5/8" annulus, to the stuck point at -6,900'md. The calculated volume for this is 18.5bbls. The remaining 17.5bbls was squeezed away. There were 4bbls cement placed on top of the EZSV. This should leave top of cement at approximately 6,378'md. We are currently setting the second EZSV at 4,1 OO'md. thanks, Dave Wesley, Jr. Operations Drilling Engineer GPB Rotary Drilling 564-5153 office 440-8631 cell 564-4040 fax tb.-~ s \..Uud ~¡:?~I;t¡td 1\ {61 t(i04 ' \NG~*;-' ~, sc4" VP46a1lv¡ SCANNED NOV 0 8 200Ä 1. Type of Request: 181 Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate [] Alter Casing [] Pull Tubing [] Perforate New Pool [] Waiver [] Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well iA-/61t- IO/ZV (2.D01 0)):1 I gJ f\L ~ STATE OF ALASKA ~E E. VE ALASKA OIL AND GAS CONSERVATION COMMISSION R ~... I D APPLICATION FOR SUNDRY APPROVAL OC~LOO4 20 MC 25.280 Alaska Oil & Gas Cons. Commission Anchorage 1 0 Other 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 70' 4. Current Well Class: / B Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number 191-105 / 6. API Number: / 50- 029-22204-00-00 99519-6612 9. Well Name and Number: PBU 05-24 / ADL 028325 10. Field / Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool 8. Property Designation: Total Depth MD (ft): Total Depth TVD (ft): 10290 9100 Depth MD (ft): 9000 Depth TVD (ft): Plugs (measured): 7943 9000 Junk (measured): 8930 Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3892' 10-3/4" 3892' 3521' 3580 2090 Intermediate 9583' 7-5/8" 9583' 8462' 6890 4790 Production Liner 1006' 5-1/2" 9280' - 10286' 8193' - 9096' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 9902' - 10144' 8744' - 8964' 4-1/2" x 3-1/2" x 2-7/8" Packers and SSSV Type: 5-1/2" x 3-1/2" Baker 'SABL-3' packer; 7-5/8" x 4-1/2" Baker 'SABL-3' packer; 4-1/2" Otis HRQ SSSV Nipple Tubing Grade: Tubing MD (ft): L-80 1 13Cr80 9964' Packers and SSSV MD (ft): 9948'; 8976'; 2250' 12. Attachments: B Description Summary of Proposal D BOP Sketch D Detailed Operations Program r--\ 14. Estimated Date for 6 ) Commencing Operations: Octo r ~~y2'004 16. Verbal Approval: '. Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name BiIIlsaacson Title Senior Drilling Engineer Phone 564-5521 Date 1 (J /, f J t~ 13. Well Class after proposed work: D Exploratory B Development D Service 15. Well Status after proposed work: DOil DGas DWAG DGINJ // D Plugged B Abandoned D WINJ DWDSPL Contact Dave Wesley, 564-5153 Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3lJtf--3%¿- D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance T-e s. t- 'f,o r E to z;, ç 00 r t..: 0 f'- t\. S .e..U '^- d~ tnt- ~ eÔ L<£<A.. c¡ . Other: A-rpwl(fd ~I'''''?IIO - 40 I reÔ~ I"-Pd Æo r {¿ b f.-&"Cie. ~1I 0 s- 2..4 Æ-. ORIGINAL SCANNED OCT 7 2 2004 ~ Date fDþ 1/4f Submit l ;uPlicate Approved By: Form 10-403 Revi' COMMISSIONER {(f>cO/J? 5 APPROVED BY THE COMMISSION '""\ bp 0 To: Winton Aubert - AOGCC Date: October 14, 2004 From: Dave Wesley, Jr. - BPXA GPB Rotary Drilling Subject: Reference: 05-24 Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-22204-00 Approval is requested for the proposed P&A of PBU well 05-24. The 05-24A sidetrack is scheduled for Nabors~~~,/current estimates have it beginning around November 01,2004, following the completion of th~. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. Scope Notify the field AOGCC representative with intent to plug and abandon Pre-Ria Operations: 1. Well was secured with a sand-back on 2/29/2004, aft~T X IA communication and a PC leak was suspected. PC leak confirmed, but location uncertain. 2. MIT - T to 3,OOOpsi failed, with LLR of 3.0bpm at 1 ,000psi on 3/16/2004. ~' 3. MIT-OA failed to 3,OOOpsi failed on 5/5/2004. The 10 %" shoe was not cemented/"Arctic packed". 4. PPPOT -IC failed on 5/14/2004. LOS were ti , u tioned all LOS and re-torque to 450 ft-Ibs. 5. The 3 %" tubing has been chemical cut at ,9 md on 5/27/2004. 6. The latest drift/tag stopped at -8,890'. M e tùbing cut. Approximately 1 gallon sand recovered from bailer on 6/5/2004. 7. Circulate the well to brine, as necessary to balance, by circulating down the tubing through the tubing cut. Circulation may 'short circuit' at suspected tubing leak at -7,441'. Freeze protect to -2,200' MD with diesel. 8. Function all 7 5/8" casing and tubing Lock Down Screws; repair or replace as needed. The 7 5/8" casing will be cut and pulled and the tubing spool will likely be changed out during the work-over. ~/ 9. Bleed casing and annulus pressures to zero. 10. Set a BPV. Secure the well. Level the pad as necessary. Ria Operations: 1. MIl RU Nabors 2ES. 2. Pull BPV. Circulate out diesel freeze protection and di a e the well to brine. Install TWC. 3. Nipple down the tree. Nipple up and test BOPE to 3 0 i. Pull TWC. 4. RIU. Pull the 4%" X 3 %" tubing from the cut at ,__,30'md and above. Be prepared to spool up the Chemical Injection line. The CI mandrel is at 8,889'md. 5. Be prepared to RIU SWS E-line and run a 'Free-Point' if the tubing will not pull free from the tubing cut at 8,930'md. It is possible the tubing string is sanded in on the backside. If it becomes necessary to run the free-point tool, a second chemical cut will be made above the stuck point. An EZSV and cement plug will be set as deep as possible. 6. RIU e-line. RIH with a GRlJB to the tubing stump at -8,930'md. POOH. 7. Alternatively, M/U a milling assembly and RIH, P/U 4" drill pipe. Tag the tubing stump and circulate hole clean. POOH. ~/ 05-24 Application for Sundry SCANNED OCT 7 2 2004 4 "\ 8. RlU SWS E-line. M/U a HES 7 5/8" EZSV. RIH and set the bridge plug at the tubing stump. POOH. 9. RIH with 4" drill pipe and a enting stinger assembly. 10. RlU Dowell and place a 20 01 cement P&A plug on top of the EZSV. The 20bbl cement plug will fill -435' of the 7 5/8", 29.7 casing. POOH. 11. RlU SWS E-line. 12. M/U a HES 7 5/8" EZSV bridge plug. RIH and set the EZSV at -4,100'md. POOH. RID E-line. 13. M/U a Baker 7 5/8" casing cutting assembly. RIH to -4,000'md. Cut the 7 5/8" casing per Baker representative instructions. POOH and UD assembly. 14. RlU and pull the 7 5/8" casing from the cuæa - 000'. 15. M/U a cementing stinger. RIH and place 45b cement kick off plug on top of the EZSV. The top of cement should be approximately 3,800'm ;". OH. 16. M/U an 8 %" Dir/GRlRes/PWD drilling assembly. 17. RIH to the top of the cement plug. Test the 10 %", J-55 casing to ~!500 psi for)O minutes and repord. -18. Dress off cement to the 10%"casingshoeat3,891'md. TIvt~ lO - 4°~ ec..PP(\)"c.Lf, 19. Initiate kick off, per directional plan, just below the 1 0 %" surface shoe. Drill 20 feet of new formation. Conduct an FIT top 12.0ppg EMW. 20. Drill section to TO, according to directional proposal. 21. Condition hole, as needed, in preparation for running 7", 26#, L-80, BTC-M casing. 22. RlU and run -9,405' of 7" casing to the top of the Sag River formation. 23. Cement the casing, as recommended, by Dowell. 24. Freeze protect the 10 %" X 7" annulus, once the cement has reached 500psi compressive strength. 25. M/U a 6 1/8" Dir/GRlRes/ABI drilling assembly. RIH to the plugs/float equipment. Test the 7" casing to 3,500psi for 30 minutes. Record the test. 26. Drill out the float equipment to the 7" casing shoe. 27. Displace the well to 8.5ppg Flo-Pro drilling fluid. 28. Drill out the shoe plus approximately 20' of new formation. Circulate the well bore clean. 29. Pull up into 7" casing and attempt an FIT to 10.0ppg EMW. 30. Drill ahead, per directional proposal, to -10,185'md. This should place the well bore below the conglomerate, and at the beginning of the 15°/100' build and turn section. POOH for bitlBHA. 31. M/U assembly, per SSDS recommendation, to achieve the directional requirement. 32. RIH and drill ahead to the end of the 15°/100' directional interval. Trip as required for the final, horizontal BHA. 33. RIH and drill ahead, per directional proposal, to section, well TO. 34. Condition hole for running 4 1/2", 12.6#, L-80, IBT-M liner. 35. Run and cement the 4 %" production liner, extending the liner lap to -9,250'md. POOH. 36. P/U and RIH with Schlumberger 2 %" DPC perforating guns. Perforate approximately 1,000' of Z1A11B interval, per subsurface team. POOH. 37. RlU and run a 4 1/2", 12.6#, 13Cr-80, VAM TOP completion, stinging into the 4 1/2" liner tie back sleeve. 38. Set the packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 39. Install a TWC. 40. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC. 41. Freeze protect the well to -2,200'. Install BPV. Secure the well. 42. Rig down and move off. Post-Ria Operations: 1. MI/ RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Mil RU SWS E-line. RIH and perforate approximately 10' of Z2C interval, per subsurface team. 3. Install gas lift valves. 4. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: 10/20/04 Estimated Spud Date: 11/01/04 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 05-24 Application for Sundry SCANNED OCT 7 2 2004 . TRE5=' WELLHEAD = , ACTÜATÒR=' m... on.. .... KB. ELEV = BF.ËLEV ~ ' ........... .,,'n,..,... ... KOP = 1000' . '"' ......, .. .,,, ..., "..'.......'....."'..'.".'.".'.'.'Î Max Angle = 33 @,2900' Datum MD = 10041' Datum ïVD = 8800'S5 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-f I TOP OF 3-1/2" TBG l-f 110-3/4" CSG, 45.5#, J-55, ID = 9.950" l-f FMC FMC , ,. , BAKER C 70' ? 2966" 2966", . 3891" r- I FISH - CHEM CLITTER (05/16/04) l-f 8930" CHEM CUTTBG (05/27/04) l-f 8930" Minimum ID = 2.25" @ 9961' 2-7/8" OTIS XN NO-GO NIPPLE TOP OF SAND l-f 9000" I 3.1/2" TBG, 9.2#, L-80, .00870 bpf, ID = 2.992" l-f 9142" TOPOF 2-7/8" TBG l-f 9142" I TOP OF 5-1/2" LNR l-f 9279" 17-5/8" CSG, 29.7#, ID = 6.875" l-f 9583" ÆRFORA TION SUMMARY REF LOG: BHCS ON 08/13/91 ANGLE AT TOP ÆRF: 26 @ 9902' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9902 - 9922 C 08/18/91 2-1/8" 4 10098 - 10144 C 09/07/91 I PBTD l-f 10242" 1 I 5-1/2" LNR, 17#, 13.CR, .0232 bpf, ID = 4.892" l-f 10286" I DA TE REV BY COMMENTS 08/22/91 ORIGINAL COM PLETION OS/23/93 LAST WORKOVER 02/05/02 RNlTP CORRECTIONS 03/14/04 DAV/TLH GLV C/O 05/16/04 FWElKAK DUMP SAND; FISH OS/27/04 MJA/KAK CHEM CUT TBG 05-24 --- I ~ ~ c L -01IIII( '~W I IV I I 1 1 1 --\ ---\ . s X; I x 11 ~ DA TE REV BY SAFETY NOTES: ***CHROM E 5-1/2" LNR & 2-7/8" TBG*** 2250" 1-f4-1/2" OTIS HRQ SSSV NIP, 10 = 3.813" 1 2966" l-f 4-1/2" X 3-1/2" XO 1 -< f GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH 1 3259 2987 33 MC-FMHO DMY RK 2 6157 5475 32 MC-FMHO DMY RK 3 8674 7652 28 MC-FMHO DMY RK 4 8766 7733 27 MC-FMHO DMY RK CHEMICAL INJECTION MANDRELS I STI MD I TVD I DEV I TYÆ I VL V I LA TCHI PORTI DA TE I 1 8889 7773 26 CA-KBUG-L T DV BK-5 OS/24/93 A PORT DATE 0 03/07/04 0 0 0 8913" 1-f3-1/2" PARKER SWS NIP, ID = 2.813" 1 8976" 1-f7-5/8" X 4-112" BAKERSABL-3 PKRI 9020" l-f 3-1/2" OTIS XN NO-GO NIP, ID = 2.75" 1 PRODUCTION MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 9063 7929 27 CA-MMG-2 DV RK OS/24/93 2 9123 7982 27 CA-MMG-2 RK 0.250 10/16/95 9142" l-f 3-1/2" X 2-7/8" XO 1 . 9898" IjTOPOF 2-7/8" BLAST JOINT 1 9938" HBOTTOMOF2-7/8" BLAST JOINT 1 9948" 1-f5-1/2" X 3-1/2" BAKERSABL-3 PKRI 9961" J-f2-7/8" OTIS XN NO-GO NIP, ID = 2.25" 1 9964" 1-f2 7/8",6.4#, 13CR-80tubing.I.D. =2.441" I I 10144" H FISH - 1.5" HES-0-20R-RK (LOST 10/16/95) 1 ~GANNFn OGT 1 2 2004 COMMENTS PRUDHOE BAY UNrr WELL: 05-24 ÆRMrr No: 1911050 API No: 50-029-22204-00 SEC 32, T11 N, R15E 4866.57 FEL 2400.84 FNL BP Exploration (Alaska) . TREE. =' WELLHEAD = , ACTUATOR= . ",.... .. nn ...n KB. ELEV = BF. ELEV = ,,,. '",.. ,"n, . . . KOP = 1000' '.m. .. ..,. '. ,. "., .....,.. ,.. . Max A~gle ~ . 33 @ 29~0' Datum MD = 10041' . ..... . .... Datum lVD = 8800' SS 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" -i I TOP OF 3-1/2" TBG l-i 110-3/4" CSG, 45.5#, J-55, ID = 9.950" l-i FMC FMC BAKER C 70' ? 05-24 Pre Rig SAFETY tÐTE5: ***CI-RJME 5-1/2" L~ & 2-7/8" TBG*** ...JilL. I 2966' ~ 2966" ~ 3891" -- I FISH - CHEM CUTTER (05/16/04) l-i 8930" I CHEM CUT TBG (05/27/04) l-i 8930" Minimum ID = 2.25" @ 9961' 2-7/8" OTIS XN NO-GO NIPPLE TOPOF SAND l-i 9000" I 3-1/2" TBG, 9.2#, L-80, .00870 bpf, ID = 2.992" l-i 9142' TOPOF 2-7/8" TBG l-i 9142" I TOP OF 5-1/2" LNR l-i 9279" 17-5/8" CSG, 29.7#, ID = 6.875" l-i 9583' ÆRFORA TION SUMMARY REF LOG: BHCS ON 08/13/91 ANGLE AT TOP ÆRF: 26 @ 9902' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9902 - 9922 C 08/18/91 2-1/8" 4 10098 - 10144 C 09/07/91 I PBTD l-i 10242" 1 1 5-1/2" LNR, 17#, 13-CR, .0232 bpf, ID = 4.892" l-i 10286" I DA TE REV BY COMMENTS 08/22/91 ORIGINAL COM PLETION OS/23/93 LAST WORKOVER 02/05/02 RNlTP CORRECTIONS 03/14/04 DAVITLH GLV C/O 05/16/04 FWElKAK DUMP SAND; FISH OS/27/04 MJA/KAK CHEM CUTTBG DA TE REV BY --L. C L -< I~W I Iv I 1 I 1 1 --\ --\¡ " . 11 B X; I 11 = :x 2250" 1-i4-1/2" OTIS HRQ SSSV NIP, ID = 3.813" 2966' 1-i4-1/2" X 3-1/2" XO I -< f GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH 1 3259 2987 33 MC-FMHO DMY RK 2 6157 5475 32 MC-FMHO DMY RK 3 8674 7652 28 MC-FMHO DMY RK 4 8766 7733 27 MC-FMHO DMY RK CHEMICAL INJECTION MANDRELS I STI MD IlVDI DEVI TYÆ IVLVI LATCHI PORTI DATE I 1 8889 7773 26 CA-KBUG-L T DV BK-5 OS/24/93 A PORT DATE 0 03/07/04 0 0 0 8913" 1-i3-1/2" PARKERSWSNIP, ID=2.813" 8976" 1-i7-5/8" X 4-1/2" BAKERSABL-3 PKR 9020" l-i 3-1/2" OTIS XN NO-GO NIP, ID = 2.75" I PRODUCTION MANDRELS ST MD lVD DEV TYÆ VLV LATCH PORT DATE 1 9063 7929 27 CA-MMG-2 DV RK OS/24/93 2 9123 7982 27 CA-MMG-2 RK 0.250 10/16/95 9142" 1-i3-1/2" X 2-7/8" XO 1 9898" IjTOPOF 2-7/8" BLAST JOINT 9938' HBOTTOMOF2-7/8" BLAST JOINT 1 9948" 1-i5-1/2" X 3-1/2" BAKER SABL-3 PKR 9961" 1-i2-7/8" OTIS XN NO-GO NIP, ID = 2.25" I 9964' 1-i2 7/8", 6.4#, 13CR-80 tubing. 1.0. = 2.441" I 10144" HFISH - 1.5" HES-0-20R-RK (LOST 10/16/95) SCANNED OCT 7 2 2004 COMMENTS PRUDHOE BA Y UNrr WELL: 05-24 ÆRMrr No: 1911050 API No: 50-029-22204-00 SEC 32, T11 N, R15E 4866.57 FEL 2400.84 FNL BP Exploration (Alaska) TREE = WB-LHEAD = ,. ..... ACTUATOR = .. .., ... ......"... . KB. B-EV = ,. .. .", ",.'" m.. BF. B-EV = KOP= Max Angle = .. . . Datum MD = . .. ... Datum ND = 05-24 Decomplete 2 FMC FMC . BAKER ë .. .,.. "". . 70' ? 110-3/4" CSG, 45.5#, 11 3891' J-55, ID = 9.950" I P & A cement plug 11 -8,465' 1 Chemical cut tbg (05/27/04). Fish- lower half severing head 8930' TOPOF SAND 1-1 9000' 175/8",29.7#, L-80 11 Casing I.D. = 6.875" 9583' 15 1/2" X 3 1/2" Baker 11 9948' SABL-3 A<r 151/2", 17#, 13~r-80, 11 10286' 1 liner I.D.=4.892 DA TE REV BY COMMENTS 08/22/91 ORIGINAL COM PLETION OS/23/93 LAST WORKOVER 02/05/02 RNlTP CORRECTIONS 03/14/04 DA V /TLH GL V C/O 05/16/04 PNE/KAK DUMP SAND; FISH OS/27/04 MJA/KAK CHEM CUT TBG 1000' .. " .~. . 33 @ 2900' . . . . . . . 1 0041 ' ..... .,.. 8800' SS tÐ bb/s ~t. ? , ~.~, Q I ~~r ---t ---I, . 'I ~ X ~ III ~ ~ 8976' 1-17-5/8" X 4-1/2" BAKERSABL-3 PKRI 9020' 1-13-1/2" OTIS XN NO~GO NIP, ID = 2.75" 1 PRODUCTION MANDRB-S ST MD ND DEV TYÆ VLV LATCH PORT DATE 1 9063 7929 27 CA-MMG-2 DV RK OS/24/93 2 9123 7982 27 CA-MMG-2 RK 0.250 10/16/95 . ÆRFORA TION SUMMARY REF LOG: BHCS ON 08/13/91 ANGLEATTOPÆRF: 26 @ 9902' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 9902 - 9922 C 08/18/91 2-1/8" 4 10098 - 10144 C 09/07/91 I 10144' HFISH-1.5" HES-0-20R-RK(LOST10/16/95) 1 SGl\NNED OCT 7 2 2004 DA TE REV BY COMMENTS 09/22/04 dew De-completion phase 2 PRUDHOE BAY UNrr WB-L: 05-24 ÆRMrr No: 1911050 API No: 50-029-22204-00 SEC 32, T11 N, R15E 4866.57 FEL 2400.84 FNL BP Exploration (Alaska) . 05-24A Proposed Completion 110-3/4" CSG, 4~.5#, 11 3,891' I J-55, ID = 9.950 17 5/8" EZSV Bridge plug 4ç hb! s. ~i. 11 4,100' I TOPOF SAND 1-1 9000' 175/8",29.7#, L-80 11 Casing I.D. = 6.875" 9583' 151/2",17#,13:r-so'll 10286' I liner 1.0.=4.892 I TREE = WRLHEAD = ACTUATOR = KB. Ei:.EV ~.. . ." . ",. ...................... BF. REV = KOP= Max Angle = Datum MD = Datum 1VD = FMC FMC BAKER C 70' ? 1000' 33 @ 2900' 10041 ' 8800' SS I I 2,200' H4 1/2" 'X'landing nipple, ID = 3.813" 1 I 3,950' ~I Sidetrack off cement plug I 9,190' I I I I ~14 1/2" 'X' landing nipple, ID = 3.813" 1 ~17" X 4 1/2" Baker S-3 packer I ~14 1/2" 'X' landing nipple, ID = 3.813" 1 ~141/2"'XN'landing nipple, ID= 3.75" I 1-14 1/2", 12.6#, 13Cr-80, VAM TOP 9,205' 9,225' 9,235' 9248' II ~ ~ ... I '11 7" X 5" Baker HMC Lnr hngr and I 9,250 ZXP pkr with TBS '"" I 9,405' H 7", 26#, l-80 BTC-M Drl9 liner I II 0 0 0 0 0 0 0 0 0 0 0- 00000000000 oooooooooo~ ~ I 12,287' ~14 1/2", 12.6#, L-80, IBT-M solid liner I SCANNED OCT 7 2 2004 DA TE REV BY COMMENTS OS/22/91 ORIGINAL COM PLETION OS/23/93 LAST WORKOVER 02/05/02 RNlTP CORRECTIONS 03/14/04 DAV/TLH GLV C/O 05/16/04 FWE/KAK DUMP SAND; FISH OS/27/04 MJA/KA K CHEI'v1 CUT TBG DA TE REV BY 09/22/04 dew COMMENTS Proposed corrpletion PRUDHOE BAY UNIT WRL: 05-24A ÆRMIT No: API No: 50-029-22204-01 SEC 32, T11 N, R15E 4866.57 FEL 2400.84 FNL BP Exploration (Alas ka) ~lJ ~ IT Œ (ill ~ L~ ~fÆ ~ ~~l~~ FRANK H. MURKOWSK', GOVERNOR AI~ASIiA OILAlO) GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 B ill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 05-24 Sundry Number: 304-385 Dear Mr. Isaacson: 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. 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. BY ORDER OF THE COMMISSION DATED this~~y of October, 2004 Encl. SCANNED OCT 7 2 2004 o' STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandonD Alter Casing 0 Change Approved Program 0 2. Operator Suspend D Repair Well 0 Pull Tubing 0 Operation ShutdownD Plug Perforations ŒI Perforate New Pool D 4. Current Well Class: Perforate D WaiverD Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 191-1050 OtherD Name: BP Exploration (Alaska), Inc. 70.00 8. Property Designation: ADL-0028325 11. Present Well Condition Summary: Development ŒI Stratigraphic D 9. Well Name and Number: 05-24 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD ServiceD 6. API Number 50-029-22204-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 10290 feet true vertical 9099.8 feet Effective Depth feet Plugs (measured) Junk (measured) None measured 9277 10144 true vertical 8190.0 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 38 118 38.0 - 118.0 1490 470 Liner 1007 5-1/2" 17# 13Cr80 9279 - 10286 8191.7 - 9096.0 7740 6280 Production 9547 7-5/8" 29.7# L-80 36 - 9583 36.0 - 8461.5 6890 4790 Surface 3854 10-3/4" 45.5# J-55 37 - 3891 37.0 - 3520.5 3580 2090 Perforation deDth: Packers & SSSV (type & measured depth): 4-1/2" 12.6# L-80 3-1/2" 9.3# L-80 3-1/2" Baker SABL-3 Packer 4-1/2" Baker SABL-3 Packer @ 35 @ 2966 @ @ RECE\VEO {).PR -" 'L004 2966 ~\SS\On 8915 tn & Gas CO"S' \,u ~\as~a \ ~nr.\\Ot",e Measured depth: All Below Sand Plug True vertical depth: All Below Sand Plug Tubing ( size, grade, and measured depth): 9949 8976 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Iniection Data Gas-Met I Water-Bbl Casing Pressure 0.1 15 1300 13 Well Shut-In 550 Tubing Pressure 348 208 Prior to well operation: Subsequent to operation: Oil-Bbl 7 14. Attachments: 15. Well Class after proposed work: ExploratoryO Development!!] ServiceD Contact Printed Name Garry Catron Garry Catron .11acr rcdr~ RBf)MS 8fL Form 10-404 Revised 12/2003 16. Well Status after proposed work: Operational Shutdown 0 OilŒJ GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Copies of Logs and Surveys run - Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Production Technical Assistant Signature Phone 564-4657 Date 4/2/04 APR7 1884 ORIGINAL 05-24 DESCRIPl:lONOF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/29/04 T/I/O = 260/1300/80. Tbg Sandback. (Secure Well) MIRU LRS and DS. PJSM. PT lines to 3500 psi. Pumped 5 bbls of Methonal, 355 bbls of Inhibited Seawater and 90 bbls Crude down IA. At 200 bbls of Seawater down IA came on line down TBG and pumped the following: 5 bbls Methonal, 165 bbls of Seawater, 2 bbls of 30 ppt Gel, 22.3 bbls of Sand Slurry (20/40 river sand mixed 8 ppg). Displaced Sand with 10 bbls of Seawater, 2 bbls of 30 ppt Gel, 10 bbls of Seawater and 72 bbls of Crude. Did not see a pressure increase when sand was displaced to bottom, may be due to PC leak. After SD Tbg pressure was 790 psi, lAP was 680 psi. Monitored pressures for 30 min. Final WHP's = 560/550/100. Sand plug set @ 9277'- 10144' FLUIDS PUMPED BBlS 15 162 4 22.3 185 355 743.3 Methanal Crude 30 ppt Gel 20/40 River Sand Sea Water Inhibited Sea Water TOTAL Page 1 .. TREE = WELLHEA D = ACTLJð. TOR = KB. 8.EV = BF. 8.EV = KOP= Max Angle = Datum M) = Datum TVD = Fr./C Fr./C BAKERC 70' ? 1000' 33 @ 2900' 1Õ041 ' 8800' 55 14-112" TBG, 12.6#. L-80, 0.0152 bpf, ID = 3.958" H 1 TOP OF 3-1/2" TOO H 110-3/4" COO, 45.5#, J.55, ID = 9.950" H Minimum ID =225" @9961' 2-7/8" OTIS XN NO-GO NIPPLE 13-1/2" TBG, 9.2#, L-BO, .00870 bpf, ID = 2.992" H 1 TOP OF 2-7/8" TOO H I TOP OF 5-112" Lt-R H 17-5I8"CSG, 29.7#.ID= 6.875" H 12-7/8" TBG, 6.4#, 13-CR, .00579 bpf, ID = 2.441" H I TOP OF 2-7/8" TOO H 2966' 2966' 3891' 05-24 . ~-1' ~ :J z( 9142' 1 \ 9142' r--- 9279' 9583' 9898' 9838' ... I-- I I 12-718" TBG, 6.4#, 13-CR, .00579 bpf, ID = 2.441" H 9964' f ÆRFORA 1l0N SLMfv\6. RY Re= LOG: BHeS ON 08113/91 ANGLEATTOPPERF: 26@ 9902' Note: Refer 10 Produetion œ for historieal perf data SIZE SA' INTERVAL OpnlSqz DATE 3-318" 4 9902 - 9922 0 08/18/91 2-1/8" 4 10098 - 10144 0 09/07/91 I AHD H H f 5-1/2" LNR, 17#, 13-CR, .0232 bpf, ID = 4.892" DA "IE RBI BY COMrvENTS 08122/91 ORIGINAL COMPLEI'ION 05123193 LAST WORKOVER 02105102 RNITP CORREC1l0NS 03114/04 DAV /TLH GLV CIa 10242' 10286' .J . DATE REV BY SAFETY NOTES: ".CHROM E5.1/2" L/lR & 2.7/8" TBG". 2250' H4-1/2" OTIS HRQ SSSV I\IP, ID = 3.813" I H4-1/2" X 3-1/2" XO I 2966' )& GAS LIFT MA I\ÐRELS ST MD lVD DBI TYPE VLV LATCH 1 3259 2987 33 MC-FMHO DMY AI< ... 2 6157 5475 32 MC-FMHO DMY AI< 3 8674 7652 28 MC-FMHO DMY AI< 4 8766 7733 27 MC-FMHO DMY AI< CHEMCAL INJECTION fv\6.I\ÐR8.S 1ST I MD I TVDI DBI I TYPE Iv LV LATCH PORTI DATE I 1 8889 7773 26 CA-KBUG-L T DV BK-5 05124/93 8913' H3-1/2"PAAI<ERSWSNIP,ID=2.813" 1 8973' H3-1/2" x 4-1/2" XO I 8976' H7-5I8" x 4-1/2" BAKER SABL-3 PKRI 9020' H3-1/2" OTIS XN NO-GO NIP, ID = 2.75" I PRODJCTION fv\6.NrR8.S lVD DEV TYPE VLV LATCH PORT DATE 7929 27 CA-MMG-2 DV RK OS/24/93 7982 27 CA-MMG-2 RK 0.250 10/16/95 PORT DA TE 0 03107/04 0 0 0 L L ST MD 1 9063 2 9123 9142' H3-1/2" X 2-7/8" XO 1 . ~ 9898' 9938' WTOPOF2-7/8" BLAST JOINT 1 HBOTTOM OF 2-7/8" BLAST JOINT H2-7/8" X 3-1/2" XO 1 H5-1/2" X 3-1/2" BAKER SABL-3 PKRI H3-1/2"X 2-7/8" XO I H2-7/8" OTIS XN NO-GO NIP, ID = 2.25" I H2-7/8"TUBINGTAIL WLB3 HELM) TT LOGGED 05122/93 1 9944' 9948' 9953' 9961' 9964' 9963' 1 10144' HASH-1.5" HES-0-20R-RK(LOST10/16195) I COMrvENTS PRUDI-OE BAY U\J[f WELL: 05-24 PERMTI'b: 1911050 AA I'b: 50-02¡}'22204-00 SEC 32, T11N, R15E 4866.57 FEL 2400.84 FNL BP Exploration (Alaska) THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2, 2000 E E C:LORBMFILM. DOC PL E W M A TE R IA L U N D ER TH IS M ARK ER STATE OF ALASKA ALASKA ~ND GAS CONSERVATION CO?'"h~ISSION REPORT GF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator ARCO Alaska~ Inc. 3. Address Operation shutdown Pull tubing ....- ~ Stimulate X Plugging ...- Perforate..__ Alter casing ....- Repair well .....- Other -.... 5. Type of Well 6. Datum of elevation(DF or KB) Deve~pment X 70' RKB Exptoml~'y Straligraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2203' NSL, 1194' EWL, Sec 32, T11N, R15E, UM. At top of productive interval 2405' SNL, 224' EWL, Sec 33, T11N, R15E, UM. At effective depth 2397' SNL, 392' EWL, Sec 33, T11N, R15E, UM. At total depth 2391' SNL, 407' EWL, Sec 33, T11N, R15E, UM. 12. Present well condition summary Total depth: Effective depth: Casing Conductor Surface Production Liner Servk~ ...- Prudhoe Bay Unit 8. Well number 5-24 9. Permit number/approval number ,. 91-105 ORIGINAL 10. APl number 50 - 029-22204 11. Field/Pool Prudhoe Bay Oil Pool feet measured 10290 feet Plugs(measured) "" ~' ' ~ L' i-) true vertical 91o0 feet [~OV 'i :J i995 measured 10242 feet true vertical 9055 feet Junk(measured) A_.li~$._~. ,0il & Gas Cons. C0mmiss! ..... ' ~nchorage.' ' Length Size Cemented Measured depth True vertical depth 110' 20" 11 Yds AS 110' 110' 3822' 10-3/4" 1300 Sx CS III, 300 Sx G, & 3892' 3521' 184 Sx CS II 9513' 7-5/8" 940 Sx G 9583' 8461' 1007' 5-1/2" 120 Sx G 10286' 9097' Perforation depth: measured 9902 -9922'; 10098- 10144' ,;,,;~ ,i' '~ ~ ~(~ '!'~:" ~:" "' i:.: iii:i'', true vertical 8735-8754';8919- 8934' .ate_- Tubing (size, grade, and measur~ depth) 4-1/2", 12.~, L-80 T~ to 2966' MD; 3-1/2"~9.2~, L'~O T~I~ 8906' MD; 3-1/2", 9.2g, 13 CrT~ to 91~' MD; 2-7/8", 6.~, 13 Crag tail to 9965' MD. Pa~em and SSSV (~ and measured depth) 7-5~' ~ SABL~ Pa~er ~ 8976' MD & 5-1/2" SABL~ P~ker ~ ~49' MD; ~1/2" HRQ ~ 22~' MD. 13. Stimulation or cement squeeze summaw Intewals treated(measured) see A~ached Treatment de~ription including volumes used and final pressure 14. Reomsentative Daily Averaoe Pr~u~ion or Ini~n Date OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pre, urn Prior to well operation 1117 41~ 132 - 351 Su~equent to operation 1730 5204 173 - 453 15. A~achments 16. St~us of well cla~ff~ation ~: ~pies of Logs and Suweys run Daily Re~ of Well Operat~ns X~ Oil. X G~ Suspe~ Se~e 17. I hereby cedEy that the foregoing is true and ~rm~ to the best of my knowledge. Signed ~,~ ~, ~ T~le E~ineeringSupe~isor Date Form 10~04 Rev 06/15/88 SUBMIT IN DUPLICAT~ / GSS cc: KZ. JWP. 5-24 DESCRIPTION OF WORK COMPLETED ROPE TREATMENT & HYDRAULIC FRACTURE TREATMENT OF ZlB 9/1/95: RIH & tagged PBTD at 10213' MD. 9/7/95: Injected Nitrogen to displace tubing fluid level down to 9900' MD. 9/9/95: RIH w/shear plug assembly. Set XXN shear plug at 9994' MD. 9/1 0/95: A Pre-Frac High Energy ROPE Treatment was performed as follows: MIRU. PT equipment & hardline running from 5-05A accumulator well to 5-24 to 10000 psi. Pumped Nitrogen down wells 5-05A & 5-24 to load both wells. Ruptured the shear disk at 9196 psi to ROPE the perforations located at: 10O98 - 10144' MD (Z1B) Ref. Log: BHCS 8/13/91. Bled down wells. Rigged down. 9/1 I/95: RIH & retrieved the ruptured shear plug. 9/24/95: MIRU & PT equipment. Pumped a Hydraulic Fracture Treatment using 20/40 mesh proppant, through the open perforations (listed above). Note: Straddled Open perforations located at 9902' - 9922' MD were not exposed to the Frac. Pumped: a) 200 bbls 20# Pre Pad @ 20 bpm, followed by b) Shutdown. ISIP @ 1700. Resumed pumping: c) 57 bbls 40# Crosslinked Pad @ 15 - 20 bpm, followed by d) 312 bbls Cross Linked Slurry @ 1 - 8 ppg, followed by e) 102 bbls Flush, followed by f) Shutdown. F,".OV 'i :', i9~ & gas Cons. C0mmissi0~ Anchorage Placed a total of 43,000 lbs of proppant into the formation. Rigged down. 9/25/95: RIH w/CT & jetted a proppant fill cleanout to 10060' MD. Returned well to production & obtained a valid welltest. · '- co Inc. P.O.BOx 100360 Anchorage, ~IAS~A 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE 5-[S- 3 5-13 77- pb 5-28-93 5-24~/-/0~ 5-22-93 5-32 ~ I~?~ 5-27-93 6-12A fT'&~ 5-29-93 6-14A ~75-19-93 7-147~-~1 5-25-93 9-3 ?~ 7~.- 5-18-93 9-3 5'24-93 * 9-4A ?~-~ ¥ 5-26-93 9-5A ? ~-o- ~ 5-30-93 ** 9-28A q$-~ 5-28-93 9-31A 7~-~35-19-93 9-32 ~-1~5-30-93 12-15 ~-~ 5-27-93 12-23 ~ ~- ~ 5-27-93 14-22A~.~-23-93 14-22A 5-23-93 ~ ~./~ ~-- 18-29A ~5-18-93 AGI-I~.i ~ 5-20-93 AGI-1 5-20-93 Completion Record TDTP (Borax) GR/Coll~ TDTP (Borax) TDTP (Borax) Production Log Prod Profile Perf Record Prod Profile Production Log Completion Record Production LOg CBT Completion Record Completion Record Le_~k Detection Perf Record PITS Perf Record Jewelry Perf Record AGI-2 q~.~¢c~j-23-93 Jewelry AGI-2 ~5-23-93 Perf Record AGI-3 ~.~$~ 5-20-93, GR/(XIL AGI-3' ,~5-21-93 Primary Perf Record AGI-4 ~A~ 5-22-93 Initial Perf Record $onya Wallace ATO-1529 R,m 1.5" Sch R-n 1, 5" Sch R-n 1, 5" Atlas R-n 1, 5" Sch R-n 1, 5" Sch R-n 1, 5" Sch R-~ 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch R-~ 1, 5" Sch Run 1, 5" Sch R'" 1, 5" Sch Run 1, 5" Sch' Rlm 1, 2" Sch Run 1, 5" Sch R.n 1, 5" Sch R!1n 1, 5" Sch R.n 1, 5" Sch Run 1, 5" Sch R-~ 1, 5" Sch R'~ 1, 5" Sch R'-n 1, 5" Sch R,n 1, 5" Sch Run 1, 5" Sch APPR OVED_~__/~ Trans# 93071 # (2~ri-uAL lm~ #~ #BPX # STATE OF ALASKA The correct well name for this log is 9-4A. The correct APl# for 9-28A is 50-029-21292-01. ~: ; STATE OF ALASKA AI_A;:'~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2203' NSL, 1194' EWL, SEC. 32, T11N, R15E At top of productive interval 2405' SNL, 224' EWL, SEC. 33, T11N, R15E At effective depth 2397' SNL, 392' EWL, SEC. 33, T11N, R15E At total depth 2391' SNL, 407' EWL, SEC. 33, T11N, R15E 12. Present well condition summary Total depth: measured true vertical Stimulate Plugging Alter casing Repair well 5. Type of Well: Development X Exploratory Strafigraphic Service Effective depth: measured true vertical Perforate '~'~/~ Other 6. Datum elevation (DF or KB) RKB 70' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 5-24 9. Permit number/approval number 91-105/Conservation order 258 10. APl number 50- 029-22204 11. Field/Pool Prudhoe Bay Field~Oil Pool 10290 feet Plugs (measured) 9100 feet 10242 feet Junk (measured) 9055 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth true vertical Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 2966'; 3-1/2", 9.2#, L-80 to 8906'; 3-1/2", 9.2#, 13CR to 9143'w/ 2-7/8", 6.4#, 13CR tubing tail to 9965' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 4-1/2" Otis HRQ @ 2250' MD;7-5/8" Baker SABL-3 Packer ~ 8976'; 5-1/2" Baker SABL-3 Packer ~ 9949' MD Intervals treated (measured) Treatment description including volumes used and final pressure J U L 1 § 1993 Alaska 0il & Gas Cons. Commission 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Anchorage Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil x Gas Suspended Service 17, I hereby ce. rt~y that the foregoing is true and correct to the best of my knowledge. Signed/VI- - Title Form 10-404 Rev 06/1"5~88 Drilling Engineer Supervisor Date SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATIONS PagE: 1 WELL: DS5-24 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: APl: 50- PERMIT: APPROVAL: ACCEPT: 05/09/93 05:00 SPUD: RELEASE: 05/23/93 02:00 OPERATION: DRLG RIG: WO/C RIG: NABORS 2ES 05/10/93 ( 1) RU TO PULL TUBING MW: 0.0 TD:10290 ACCEPTED RIG 1700 HRS. 05/09/93. TAKE ON SEAWATER & RU TO PB:10242 CIRCULATE WELL. RU LUBRICATOR & PULL BPV. ClRC APPROXED. 200 BBLS DIESEL FROM WELL. MONITOR WELL, WELL STABLE. SET BPV. ND TREE, SECURE CONTROL & INJECTION LINES. NU BOP STACK. TESTED DOPE. RU LUBRICATOR & PULL BPV. 05/11/93 ( 2) TESTING KELLY VALVES MW: 0.0 TD:10290 FINISHED PULLING BPV. RD LUBRICATOR, MU LANDING JOINT. PB:10242 BOLDS. PULL TUBING HANGET TO FLOOR W/110K# PUW. TESTED BOTTOM PIPE RAMS. INSTALLED WEAR BUSHING. MU BHA #1. PU DP & RIH W/BHA #1. CHANGED OUT KELLY & TEST VALVES ON SAME.. 05/12/93 (3) LD 2-7/8" TUBING MW: 0.0 TD:10290 FINISHED TESTING KELLY VALVES. RIH, PU 3-1/2" DP, PU PB:10242 KELLY. TAGGED PACKER @ 8944.. MILLED PACKER F/8944 - 8947. CBU. POH W/FISH. TOOK 8~BBI,. GAIN W/TOF @ 4255'. ClRC THROUGH CHOKE UNTIL WELL STABLE. CONTINUED TO POH, LD PACKER ASSEMBLY. RU cAS,.!NG,T ~OOLS. HELD 30 MIN. SAFETY MEETING. LD STRADDLE 05/13/93 (4) TD:I O29O PB:10242 MILLING 5-1/2" PACKER MW: 0.0 FINISHED LD STRADDLE ASSEMBLY. RECOVERED 2 PRODUCTION MANDRELS, 5 JTS. 3-1/2" FOX 13 CR TUBING, 16 JTS 2-7/8" FOX 13 CR TUBING, 1 JT2 7/8" FOX W/BLAST RINGS, 1 SEAL ASSEMBLY. RD CASING TOOLS AND CLEARED FLOOR. MU BHA #2. RIH. TAGGED TOF @ 9946% MILLED/PUSHED PACKER TO 9960. GAS OBSERVED @ SURFACE AFTER 1400 STKSo SHUT IN WELL. ClRC THROUGH CHOKE, WELL STABLE AFTER BOTTOMS UP. MILLED ON PACKER. MILLED F / 8 HRS W/1' PROGRESS, THE PACKER BEGAN TO INTERMITTENTLY MOVE DOWNHOLE. 05/14/93 ( 5) RIH W/CLEANOUT ASSEMBLY MW: 0.0 TD:10290 CONTINUED MILLING ON PACKER @ 10061'. POH TO TOL. HOLE PB:10242 STABLE. CUT DRILLING LINE. POH. FOUND RUBBER & SLIPS IN JUNK BASKETS. MU BHA #3. RIH, TAGGED FISH @10067', POH 2 STANDS. CLOSED BAG & CIRCULATED THROUGH CHOKE. POH W/ FISH. HOLE STABLE. LD BHA, MU BHA #4 & RIH. RECEIVED d U L 1 5 1993 Alaska Oil & Gas Cons. C;omm~ss~On Anchorage WELL · DS5-24 OPERATION: RIG · NABORS 2ES PAGE: 2 05/15/93 ( 6) RIH W/SCRAPERS MW: 0.0 TD:10290 FINISHED RIH W/CLEANOUT BHA. TAGGED FILL @ 10092'. PB:10242 WASHED F/10092 - 10117 @ 4 BPM/2000 PSI. POH. L/D BHA #4 & MU BHA #5. RIH W/SCRAPERS. 05/16/93 (7) TD:10290 PB:10242 RUNNING COMPLETION MW: 0.0 FINISHED RIH W/SCRAPERS. TAGGED PBTD @ 10236'. REVERSED IN 25 BBL XANVIS SPACER FOLLOWED BY CLEAN SEAWATER. POH. CUT DRILLING LINE. FINISHED POH. LD 2 7/8" DP & SCRAPERS. PU 5 1/2 BAKER TEST PACKER & RIH. SET PACKER @ 9340'. TEST LINER LAP & 7 5/8" CASING TO 3000 PSI F/30 MIN. POH. LD 3 1/2" DP. CHANGED OUT KELLY. FINISHED LD DP. PULLED WEAR RING & CLEARED FLOOR. RU NABORS CASING SERVICES & CAMCO. BEGAN RUNNING COMPLETION. 05/17/93 ( 8) POH W/COMPLETION MW: 0.0 TD:10290 RAN 2 7/8" TAILPIPE ASSEMBLY, 5 1/2" PACKER, 26 JTS 3 1/2" PB:10242 FOX TUBING, 2 PROD MANDRELS '7 5/8" PACKER, ClM, 184 JTS 3 1/2 EUE 8RD TUBING, 4 GLMS. LOST POWER DUE TO SHORT CIRCUIT IN ELETRICAL SYSTEMMM; REPAIR SAME. CONTINUED RUNNING COMPLETION. ATTEMPTED TO ENTER LINER TOP W/WLEG REPEATEDLY W/O SUCCESS. POH, LD 4 1/2" TUBING. 05/18/93 (9) TD:I O290 PB:10242 RD CAMCO MW: 0.0 POH. LD 4 1/2 TBG. RAN COMPLETION. TAGGED TOL. ATTEMPTED TO WORK WLEG INTO TOL W/O SUCCESS. , 05/19/93 (10) L/D DRILL PIPE MW: 0.0 TD:10290 RIG UP & LAY DOWN TBG. RIG DOWN CSG. TOOLS. CLEAR FLOOR, PB:10242 INSTALL WEAR BUSHINGG. MU BHA #7. CUT & SLIP 80" DRLG LINE. PICK UP 3 1/2 DP. TAG @9273. POLISH TOP OF TIE BACK SLEEVE. LAY DOWN DRILL PIPE. 05/20/93 ( 11 ) PULL TBG MW: 0.0 TD:10290 LAY DOWN DP & BHA. CLEAR FLOOR, RIG UP TO RUN TBG. MU PB:10242 SSSV, HOOK UP LINES & TEST W/5000 PSI. CONT. TO RUN 4 1/2 TBG. ATTEMPT TO WORK THRU TOL @ 9297. RU TO PULL TBG. LD 4 1/2 MOD BU'i-i- L-80. STAND BACK 3 1/2 MOD EUE 8 RD JAWS. 05/21/93 (12) POH MW: 0.0 TD:10290 CHANGE OUT AIR RELAY ON DRAWORKS. LD 3 1/2 CHROME TBG. LD PB:10242 CHROME TBG TONGS, CLEAR FLOOR. TEST BOPE. RIG UP TO PICK · ' UP 2 7/8 BHA. PICK UP BHA #8. PICK UP 3 1/2 DP & RIH. CiRC @ LINER TOP. RIH TO 10236. POH TO TOL, WORK THRU TOP LINER SEVERAL TIMES. RECEIVED JUL 1 5 199 Oil & Ga~ Cons. Anchorage WELL :DS5-24 OPERATION: RIG : NABORS 2ES PAGE: 3 05/22__/93 (13) CORRELATE FOR BLAST RINGS MW: 0.0 TD:10290 WORK PIPE @ TOP OF LNR, POH, R/U & I./D 2-7/8" BHA, R/U TO PB:10242 RUN 2-7/8" CR TBG, RIH W/STRADDLE ASSEM, TAG TOL @ 9273', RUN TO 9283',R/U ATLAS W/L, RUN GR/CCL TO CORRELATE TIE-IN 05/23/93 (14) LAND TBG MW: 0.0 TD:10290 TEl IN W/ATLAS LOGS, SET 5-1/2" & 7-5/8" PKRS, PRESSURE UP PB:10242 TO 4500 PSI, STING INTO 7-5/8" PKR, TEST ANNULUS W/3000 PSI, L/D DP, R/U CAMCO & NCS, RIH W/3-1/2" MOD EUE, RUN 4-1/2" MOD BUTT L-80, STING INTO PKR, PRESSURE UP TO 500 PSI, NO SPACE OUT NEEDED, LAND TBG & RILDS 05/24/93 (15) RIG RELEASED 5/23/93 14:00 MW: 0.0 TD:10290 TEST ANNULUS W/3500 PSI, PUMP 97 BBL DIESEL DOWN ANNULUS, PB:10242 LET U-TUBE TO TBG, BACK OUT LDS, CLEAR FLOOR, SET BPV, N/D BOPE, N/U TREE, SECURE WELL, RIG RELEASED 5/23/93 14:00 SIGNATURE: (drilling superintendent) DATE: Alaska Oil & Gas Cons. Commission Anchorage MEMORANDUM ' State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnsto.~ Chairman DATE: June 1, 1993 THRU: Blair Wondzeli, ~'~. P. I. Supervisor FILE NO: jh-,,rep54.doc FROM: Jerry Herring, {)f'~ SUBJECT: Petroleum Inspector BOP Test - Nabors 2ES ARCO, PBU, Well 5-24 Prudhoe Bay Oil Pool ~/::~T~ .~#91. t-05 Thursday, May 20. 1993: I traveled to Nabors rig 2ES to witness a BOP test. The rig was completing a workover on PBU well 5-24. The 5-1/2" liner was installed to 10,286 Ft. The BOPE Test Report is attached for reference. Tool pusher Charlie Henley kept the test moving smoothly. The rig was clean and in good shape. The test started at 7:30 PM and lasted for 3 hours. There were 2 failures; 2 valves on the choke manifold which failed to hold pressure were greased and retested satisfactorily. All other BOP equipment tested satisfactorily. Summary: The BOP test on Nabors 2ES lasted 3 hours and there were 2 failures. ,..-,. Attachment STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report opERATION: Drlg: Workover: /~/ DATE; .O~-- ~-~4:~- ~",.~ ''~ DdgContractor: ^//~/~o,E.5 . ' _ RigNo. L~'~ PTD# ~t-J.O~ RigPh.# Operator:' ~(.~ /J.~.A-~,/<,4-.~ .~'~J,,'.. ' - Rep.:~.. ~'~A~ (--~/~'/ff~-7' '. .. ' WellName:_._ i D:~ ,~'-- .~. z~_ .......... RigRep.: J ~.~,~/t/~,/..IZ~ J-J'~AJ/--~"}/ ' . ' Casing Size:. ~/z' Set~ It) .~ 2,~Co'.' Location:Sec. · Test: Initial Weekly '~' Other 'Test MISC. INSPECTIONS: Location Gen.: Housekeeping:--~ (Gen) Reserve Pit ~ Well Sign Drl. Rig Test Qian. Pressure P/F: ! I P I F Ii _ '. BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams ChOke Ln. VaNes HCR Valves Kill Une Valves Check Valve FLOOR SAFETY VALVES: -" Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP ..' CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes .Test Pressure .... p/F · IF:' ' ~ ~ ' ACCUMULATOR SYSTEM: System Pressure .. ~ ~D I "~" Pressure After Closure " J' 200 psi Attained Alter Closure O., minutes '2.5' Sec. System Pressure Attained ' l minutes ~-.;Y sec. Blind Switch Covers: Master: , , ,,~'" Remote: .Nitgn. Btl's: ~ , MUD SYSTEM: Visual Alarm Trip Tank , __/_ Pit Level Indicators -... FloW Indicator Gas Detectors '~' ' v/ ' .... [ . , i i ii~11 .Jill IJ, , I I J I ~1 I J I. J _ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ',:. ,. . .:.:: . : . ... :. ;:::.:... '; : ~;~;~.~,~:~:~:~:~:'.:.::- ......... ~, .... .::::.' ::..-. '....~ .... .:::?:'::.:-...:..,:.-.~,,:,:::.:- .:.,::.:.'.:.::..".::;.~::.'. :~?TEST RESULTS ~;i:"~i ~ailUres .... ~" Test Time . ~_ ._' 'H0'u~'""l~'~ber ~f valves Equipment will be made ~hin ~ da~. No~ the Inspector and follow ~th W~en or Faxed ve~flca~on to · e AOGCC Commi~on O~ce ~t: F~xNo.' ' 276-7~2 Inspector NoAh Slope Pager No. 6~9.3607 or 3687 If your call ~ not returned by the inspector ~hin 12 houm please contact the P. I. Supe~sor at 279-1433 REMARKS: Distribution: orlg-Well File c - OperJRig ~- Database o - Trip Rpt File c - Inspector _ '::-;:~:~':: '. Fi-021L'(Rev, "'STATE wIT.blESS REQUIRED? YES ~ ..'.,/, NO 24 HOUR/NOTICE GIVEN YES V/ NO Waived By: , , Witnessed By: _ ~ A BoPtst3 ARCO ~!~sb~; Inc. P.O.Box 100:360 Anchorage, Alaska 99510 DATE: 1-31-92 REFERENCE: 'Cci,...,' ARCO CASED HOLE FnqAL8 1-11-92 Prod Profile Run 1, 5" Camco 1-11-92 Prod Profile Run 1, 5" Camco 1-10-92 Prod Profile Run 1, 5" Camco 1-10-92 Prod Profile Run 1, 5" Camco 1-15-92 CNL Run 1, 5" Sch 1-18-92 Collar Log Run 1, 5" Atlas 12-27-91 Prod Profile Run 1, 5" Camco 1-12-92 Jewelry Run 1, 5" Camco 1-20-92 Tubing Cutter Run 1, 5" Atlas 1-13-92 Leak Detect Run 1, 1" Camco 1-12-92 Prod PrOfile Run 1, 5" Camco 1-17-92 CNL-GR Run 1, 2'&5' Atlas 1,9-92 Prod Profile Run 1, 5" Camco 1-19-92 CCL/Perf Run 1, 5" Atlas Please sign and return the. attached copy as receipt of Have A Nice Dayt - Sonya Wallace APPROVED__~w ATO- 1529 Trans# 92025 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL ~ R&D # BPX # STATE OF ALASKA TEXACO * The correct tPI# for 13-2A is 50-029-20324-01. FEB 0 3 1992 At~k~ Oi~ & e.~ Cons. Comm:~.~lon -,. ii~i' STATE OF ALASKA ' ~ ALASKA OIL AND GAS CONSERVATION COMMISSION 'WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SLISPENDED I-I ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 91-105 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22204 4. Location of well at surface 9. Unit or Lease Name 2203'FSi, 1194'FWL, Section32, T11N, R15E, UM 1 c°r~, ~L.~I0~ I PrudhoeBay Unit At Top Producing IntervalI?~~.~! 1~' 10. Well Number 2405' FNL, 224' FWL, Section33, T11N, R15E, UM . ,4~R~FjEO t~/~~'"""'"'"'"'""VEi/ii=IED DS5-24 i _ . .~:,,,,- 11. Field and Pool At Total Depth Prudhoe Bay Field/Prudhoe Bay Pool 2391' FNL, 407' FWI_, Section 33, T11N, R15E, UM. .J":, , -- 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 70' RKB I ADL 28325 12. Date Spudded 13.' Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offsho'~e 116. No. of Completion~ 7/31/91 8/13/91 9/7/91'I N/A feet MSL I ONE 17. Total Depth (MD+TVD) 1'8. Plug Back Depth (MD+TVD', 19. Directional Survey 120. Depth where SSSV set J21. Thickness of Permafrost I 10290'MD/9100' TVD 10242'MD/9055' TVD YES ~ NV [] 2016feet MD I 1900' . 22. Type Electric or Other Logs Run GR/RES/CNL/SONIC/SP, CET/CBT/GR, GCT GYRO 23. CASING, LINER AND CEMENTING RECORD , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,= 20" 91.5# H-40 Surface 110' 30" 11 Yards AS 10-3/4" 45.5# J-55 Surface 3892' 13-1/2" 1300 sx CSIII & 350 sx CI Gl Top Job w~ 184 sx CSII 7-5/8" 29# L-80 Surface 9583' 9-7/8" 675 sx Cl G & 265 sx Cl G 5-1/2" 17# 13 Cr-80 9280' 10286' 6-3/4" 120 sx Cl G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MDI 9903'-9923'MD/8735'-8754' TVD 4 SPF 4-1/2"x 3-1/2" 9965' 8956' 10098'-10114'MD/8919'-8934' TVD 4 SPF 26." ACID, FRACTURE, CEMENT SQUFF71=. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL US~ ,, ,, 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 9/7/91 ~ Flowing Date of Test Hours' T~ted 3RODUC'rlON FOR OIL-BBL GAS-MCF WATER-BBL CHOKESiZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,, 28. CORE DATA , Brief description of lithoiogy, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. None RECEIVED JAN 31 *NOTE: Drilled, Tubing Ran, & Perforated 8/21/91; Perforated 9/7/91 Alaska 0ii & Gas Cons. Anchorage ,, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE iir~ 30. (:;)GLO MARKERS _,RMAT1ON TESTS NAME Include interval tested, pressure data. all fluids recovered and gravity, !, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time ot each phase. Sag 94 76' !Shublik 9520' $405' Top Saddlerochit 959 7' 84 73' Zone 4 9597' 8473' Zone 3 9781' 8636' Zone 2 9836' 8685' GOC 9858' 8704' Low Gas 10023' 8853' Zone lB 10048' 8876' Base Saddlerochit 10144' 8963' ~ . 31. LIST OF ATTACHMENTS 32. I hereby cattily that the foregoing is true and correct to the best of my knowledge / ,/ ,~ , .,' .._..~.~-. ,- , ~ ~ ,_..-.,/--,~ Signed -- ---- Tit le Area Drilling Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and. the location of the cementing tool. ,: Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas:Injection, Shut-in, Other-explain. Item 28:.Jr no .-cores taken, indicate "none". Form 10-407 ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY DS 5-24 DOYON 9 SURF DRIL: 11.0 CIRC: 0.5' BOPE: 2.5 OTHR: 2.0 08/01/91 ( 1) DRLG. MW: 8.7 VIS:300 TD: 710' ( 710) RIG ACCEPTED @ 14:00 HRS, 7/31/91. N/U DIVERTER. P/U BHA. SUPV:GLC TEST DIVERTER. CIRC. SPUDDED WELL @ 19:00 HRS, 7/31/91. HOLE ANGLE:28 0 DRLG F/ 110'-710' DAILY:S149,800 &UM:$149,800 ETD:S149,800 EFC:$2,418,000 SURF DRIL: 24.0 08/02/91 (2) TD: 2100'(1390) SUPV:GLC HOLE ANGLE:28 0 DRLG. DRLG F/ 710'-2100'. MW: 9.0 VIS:330 DAILY:S72,286 CUM:$222,086 ETD:S220,386 EFC:$2,419,700 SURF DRIL: 15.2 TRIP: 6.2 RIGS: 0.3 CIRC: 2.0 PROB: 0.3 PROB CODE: TH 08/03/91 (3) TD: 3903'(1803) SUPV:GLC HOLE ANGLE:28 0 CIRC. MW: 9.1 VIS:330 DRLG F/ 2100'-3903'. CIRC. POOH. RIH. REAM F/ 2588'-3903'. WASH TO 3903'. CIRC. DAILY:S57,283 CUM:$279,369 ETD:S277,669 EFC:$2,419,700 SURF TRIP: 2.5 SURV: 2.5 CASG: 10.2 BOPE: 5.2 OTHR: 2.8 PROB: 0.8 PROB CODE: TH 08/04/91 (4) TD: 3903' ( 0) SUPV:GLC HOLE ANGLE:28 0 N/U BOPE. MW: 8.3 VIS: 0 POOH. R/U GBR. RIH W/ 10-3/4" CSG. ;AND HGR. CIRC. PUMP 100 BBLS WATER, 445 BBLS (1300 SX) CSIII, 72 BBLS (350 SX) 'G'. DISP W/ 366 BBLS WATER. BUMP PLUG W/ 2000 PSI. PUMP 32 BBLS (187 SX) CSII. N/U BOPE. DAILY:S241,340 CUM:$520,709 ETD:S520,709 EFC:$2,418,000 P1 DRIL: 14.3 TRIP: 1.7 CIRC: 2.0 CASG: 0.5 BOPE: 3.2 OTHR: 2.3 08/05/91 ( 5) DRLG. MW:10.5 VIS: 39 TD: 5140'(1237) TEST BOPE. RIH. DRLG CMT F/ 3793'-3804' TEST CSG. DRLG SUPV:GLC FC, CMT TO 3880'. CIRC. TEST CSG. DRLG ~MT, FS TO 3892'. HOLE ANGLE:28 0 CIRC. DRLG CMT, 10' NEW HOLE TO 3913'. CIRC. PERFORM LOT (12.3 PPG EMW). DRLG F/ 3913'-5140' DAILY:S77,733 CUM:$598,442 ETD:~598,442 EFC:$2,418,000 P1 DRIL: 20.5 PROB: 3.5 PROB CODE: HP 08/06/91 ( 6) POOH. MW:10.5 VIS: 38 TD: 6657'(1517) DRLG F/ 5140'-6657'. POOH. SUPV:GLC HOLE ANGLE:28 0 DAILY:S69,766 CUM:$668,208 ETD:S668,208 EFC:$2,418,000 P1 DRIL: 16.2 PROB: 7.8 PROB CODE: DS 08/07/91 ( 7) DRLG. MW:10.6 VIS: 38 TD: 7760'(1103) POOH. RIH. REAM F/ 5340'-5426'. RIH. DRLG F/ SUPV:JAWS 6657'-7760'. HOLE ANGLE:28 0 DAILY:S50,687 CUM:$718,895 ETD:S718,895 EFC:$2,418,000 RECEIVED JAN ;~ 1 t992 Alaska 0il & Gas Cons. Comm'~ss~on Anchorage ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY DS 5-24 DOYON 9 P1 DRIL: 16.2 TRIP: 7.0 CIRC: 0.8 08/08/91 ( 8) DRLG. MW:10.5 VIS: 37 TD: 8872' (1112) DRLG F/ 7760'-8052'. CBU. POOH. RIH. DRLG F/ SUPV:JAWS 8052'-8872'. HOLE ANGLE:28 0 DAILY:S51,952 CUM:$770,847 ETD:S770,847 EFC:$2,418,000 P1 DRIL: 15.3 TRIP: 8.7 08/09/91 ( 9) DRLG. MW:10.5 VIS: 44 TD: 9260' ( 388) DRLG F/ 8872'-8926'. POOH. RIH. DRLG F/ 8926'-9260'. SUPV:JAWS HOLE ANGLE:28 0 DAILY:S90,627 CUM:$861,474 ETD:S861,474 EFC:$2,418,000 P1 DRIL: 8.2 TRIP: 8.0 CIRC: 5.0 BOPE: 1.0 OTHR: 1.8 08/10/91 (10) CHANGE RAMS. MW:10.5 VIS: 39 TD: 9583' ( 323) DRLG R/ 9260'-9583'. CIRC. 2 15 STD SHORT TRIPS. CIRC. SUPV:JAWS POOH. HOLE ANGLE:28 0 DAILY:S57,890 CUM:$919,364 ETD:S919,363 EFC:$2,418,001 P1 CIRC: 2.5 CASG: 13.8 BOPE: 2.2 OTHR: 5.5 08/11/91 (11) L/D DP. MW: 8.3 VIS: 0 TD: 9583'( 0) RIH W/ 7-5/8" CSG. CIRC. FS @ 9575'. CMT CSG. BUMP PLUG SUPV:JAWS W/ 2000 PSI. RUN PACKOFF. TEST SAME. L/D DP. HOLE ANGLE:28 0 DAILY:S325,323 CUM:$1,244,687 ETD:S1,244,686 EFC:$2,418,001 PROD DRIL: 6.2 TRIP: 6.0 RIGS: 2.5 CIRC: 1.0 EVAL: 0.5 CASG: 1.0 BOPE: 4.0 OTHR: 2.8 08612/91 (12) DRLG. MW: 8.9 VIS: 36 TD: 9839'( 256) TEST BoPE. RIH. TEST CSG. DRLG FC, CMT TO 9554'. TEST SUPV:JAWS CSG. CIRC. DRLG FC, 10' NEW HOLE TO 9593'. PERFORM LOT HOLE ANGLE:28 0 (12.5 PPG EMW). DRLG F/ 9593'-9839'. DAILY:S45,325 CUM:$1,290,012 ETD:S1,290,011 EFC:$2,418,001 PROD DRIL: 16.7 TRIP: 6.8 PROB: 0.5 PROB CODE: TH 08/13/91 (13) DRLG. MW: 9.1 VIS: 39 TD:10166' ( 327) DRLG F/ 9839'-10158'_,6 POOH. RIH. REAM F/ 10076'-10158'. SUPV:JAWS DRLG F/ 10158'- 1016 . HOLE ANGLE:28 0 DAILY:S56,048 CUM:$1,346,060 ETD:S1,346,059 EFC:$2,418,001 PROD DRIL: 7.3 TRIP: 7.7 SURV: 1.7 CIRC: 1.8 EVAL: 5.5 08/14/91 (14) CIRC. MW: 9.1 VIS: 38 TD:10290' ( 124) DRLG F/ 10158'-10290' TD WELL @ 13:15 HRS, 8/13/91. SHORT SUPV:GLCS TRIP TO SHOE. CIRC. ~OOH. R/U ATLAS. LOG RUN #1: HOLE ANGLE:28 0 GR/RES/CNL/SONIC/SP. R/D ATLAS. RIH. CIRC. SHORT TRIP TO SHOE. CIRC. DAILY:S100,318 CUM:$1,446,378 ETD:S1,446,376 EFC:$2,418,002 ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY DS 5-24 DOYON 9 RCSG: 24.0 08/15/91 ( 15) TD:10290 PB:10290 SUPV:GLC RCSG: 24.0 08/16/91 ( 16) TD:10290 PB:10242 SUPV:GLC RIH. MW: 9.1 WBM CIRC. POOH. TEST BOPE. R/U WEATHERFORD. RIH W/ 5-1/2" 13 CR LNR ON DP. PUMP 50 BBLS PREFLUSH, 120 SX (36 BBLS) 'G' CMT W/ 50% SS, 100 GHS BA86L, 1% FL-20, .3% CD-31, .08% A-2, 2 GHS FP10L @ 15.7 PPG, 1.7 YIELD. DISP W/ 82 BBLS MUD. BUMP PLUG W/ 3500 PSI. SET HGR. 5-1/2" LNR F/ 9274'-10286'. POOH 20 STDS. L/D CMT HD. POOH. RIH. DAILY:S122,714 CUM:$1,569,092 ETD:S1,569,090 EFC:$2,418,002 TEST LNR. MW: 9.3 WBM RIH TO 9212'. DRLG CMT F/ 9212'-9280' (TOL). CIRC. POOH. RIH. TAG CMT @ 10141'. DRLG CMT TO 10201'. CIRC. TEST LNR. DRLG LC, CMT TO FC TO 10242'. CIRC. DAILY:S72,064 CUM:$1,641,156 ETD:S1,641,154 EFC:$2,418,002 RCMP: 8.5 LPRF: 15.5 08/17/91 (17) POOH W/ LOG TOOLS. MW: 8.4 Seawater TD:10290 DISP W/ WATER, SEAWATER. TEST LNR. OK. POOH. L/D DP. PB:10242 R/U SWS. LOG RUN #1: CET/CBT/GR. STUCK TOOL @ 9550'. RIH SUPV:GLC W/ OVERSHOT. WASH TO 10179'. ENGAGE FISH. POOH. DAILY:S41,641 CUM:$1,682,797 ETD:S1,682,795 EFC:$2,418,002 LPRF: 24.0 08/18/91 ( 18) TD:10290 PB:10242 SUPV:GLC POOH. MW: 8.4 Seawater POOH W/ LOG TOOL. L/D SAME. R/U SWS. RIH W/ GR/JB. R/D SWS. RIH W/ BIT. REAM F/ 9100'-9280' (TOL). CIRC. POOH. RIH TO 10029'. REAM TO 10242'. CIRC. POOH. DAILY:S43,775 CUM:$1,726,572 ETD:S1,726,570 EFC:$2,418,002 COUT: 5.0 RPKR: 1.0 LPRF: 18.0 08/19/91 (19) RIH W/ PKR. MW: 8.4 Seawater TD:10290 POOH. R/U SWS. LOG RUN #1: CET/CBT/GR. LOG RUN #2: GCT. PB:10242 RIH W/ 20' 3.375" HYPERJET PERF GUN W/ 60 DEG PHASING, 4 SUPV:GLC SPF. PERF F/ 9903'-9923'. L/D PERF GUN. RIH W/ GR/JB TO TOL. RIH W/ GR/JB TO PBTD. RIH W/ OTIS 'BWD' PKR ASS'Y DAILY:S48,620 CUM:$1,775,192 ETD:S1,775,171 EFC:$2,418,021 RPKR: 24.0 08/20/91 (20) TD:10290 PB:10242 SUPV:GLC POOH. MW: 8.4 Seawater RIH W/ OTIS 'BWD' PKR. SET @ 9934'. RIH W/ BLAST JT, 7-5/8" OTIS 'BWD' PKR. CIRC. STUNG INTO PKR. TEST. SET PKR. POOH. DAILY:S366,861 CUM:$2,142,053 ETD:S2,142,032 EFC:$2,418,021 ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY DS 5-24 DOYON 9 COUT: 4.5 RCMP: 19.5 08/21/91 (21) LAND TBG. MW: 8.4 Seawater TD:10290 L/D DP. TEST BOPE. RIH W/ 4-1/2" X 3-1/2" TBG. PB:10242 SUPV:JAWS DAILY:S56,305 CUM:$2,198,358 ETD:S2,198,337 EFC:$2,418,021 NDNU: 10.0 RCMP: 2.0 08/22/91 (22) RIG RELEASED @ 18:00 HRS. MW: 8.4 Seawater TD:10290 TEST TBG, ANNULUS. INSTALL BPV. N/D BOPE. N/U TREE. TEST PB:10242 TREE. DISP WELL W/ 240 BBLS DIESEL, F/P ANNULUS W/ 110 BBLS SUPV:JAWS DIESEL. RIG RELEASED @ 18:00 HRS, 8/21/91. DAILY:S119,869 CUM:$2,318,227 ETD:S2,318,227 EFC:$2,418,000 OIIIGIN'AL SUB - S URFA CE DIRECTIONAL SURVEY UIDANCE r~-j ONTINUOUS F'~ OOL RECEIVED JAN ~ 1 1992 Alaska Oil & Gas Cons. Commission Anchorage Company ARCO ALASKA, INC. Well Name D.S. 5'24(2203'FSL,1194'FWL,SEC 32,T11N,R15E) Field/Location PRUDHOE BAY, NORTH SLOPE, ALASKA Job Reference No. 74857 Logged By: K. BARNARD Date 18-AUG-91 Computed By: d. KOHRING SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMEF LISTING FOR ARCO ALASKA INC. D.S. 5-24 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE: 18-AUG-91 ENGZNEER: K.BARNARD METHODS OF COMPUTATZON TOOL LOCATION: [NTERPOLAT[ON: VERTZCAL SECTZON: TANGENTIAL- Averaged ~eviation and azimuth LINEAR HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 81 DEG 28 MIN EAST GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC, D.S. 5-24 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE: 18-AUG-g1 METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: ENGINEER: K.BARNARD TANGENTIAL- Averaged deviation and azimuth LINEAR HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 81 DEG 28 MIN EAST ARCO ALASKA [NC. D.S. 5-24 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 21-NOV-91 PAGE 1 DATE OF SURVEY: 18-AUG-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/5OUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00. 100.00 100.00 30 200.00 200.00 130 300.00 300.00 230 400.00 400.00 330 500.00 499.98 429 600.00 599.88 529 700.00 699.63 629 800.00 799.08 729 900.00 898.07 828 0.00 -70 O0 0 0 N 0 0 E O0 0 10 S 78 36 E O0 0 7 N 30 3 E O0 0 19 S 82 16 E O0 0 10 N 61 0 W 98 2 5 N 89 41E 88 3 17 N 89 15 E 63 4 57 N 86 28 E OB 7 10 N 84 27 E 07 8 39 N 81 46 E 0.00 0.08 0.42 0.58 0.74 2.22 6.55 13~43 23.88 38.05 1000.00 996.69 926.69 10 30 N 80 28 E 54 58 1100.00 1094.52 1024.52 13 6 N 81 15 E 75 23 1200.00 1191,25 1121.25 16 18 N 83 17 E 100 53 1300.00 1286.73 1216.73 18 7 N 82 30 E 130 22 1400.00 1381.38 1311.38 19 43 N 82 7 E 162 50 1500.00 1474.75 1404.75 22 14 N 80 39 E 198 27 1600.00 1566.34 1496.34 25 2 N 81 5 E 238 38 1700.00 1655.89 1585.89 27 24 N 81 53 E 282.87 1800.00 1744.34 1674.34 28 11 N 81 18 E 329.51 1900.00 1832.51 1762.51 28 10 N 79 28 E 376.70 0 O0 0 60 0 26 0 79 0 76 0 47 I 66 "~ 95 3 27 1 23 2.95 2.90 2.50 0.70 2.21 3.11 3.55 0.82 0.63 0.62 0.00 N 0.03 S 0 0.03 S 0 0.14 S 0.00 N 0 0.09 N 2 0.11 N 6 C.27 N 13 1.11 N 23 0 O0 E 0.00 N 0 0 E 0.8 E 0.09 S 72 52 E 43 E 0.43 $ 85 23 E 60 E 0.62 S 76 41E 75 E 0.75 N 89 59 E 24 E 2.24 N 87 47 E 6~ 5 6.61 N 89 2 E 5~ E 13.55 N 88 51 E 98 E 24.01 N 87 21 E 2.91 N 38 04 E 38.15 N 85 38 E 5.53 N 54.36 E 54.64 N 84 11 E 8.88 N 74.74 E 75.27 N 83 13 E 12,18 N 99.82 E 100.56 N 83 2 E 15,80 N 129 31 E 130,27 N 83 2 E 20.13 N 161 30 E 162.55 N 82 53 E 25.47 N 196 67 E 198.31 N 82 37 E 32.05 N 236 24 E 238.41 N 82 17 E 38.51 N 280 25 E 282,89 N 82 11 E 45.23 N 326 41 E 329.53 N 82 7 E 53.13 N 372 94 E 376.71 N 81 54 E 2000.00 1920.30 1850.30 29 16 N 77 49 E 424.50 2100.00 2006.74 1936.74 30 45 N 78 26 E 474.67 2200.00 2092.48 2022.48 31 5 N 80 13 E 526.10 2300.00 2178.01 2108.01 31 25 N 80 34 E 577.91 2400.00 2263.10 2193.10 31 49 N 79 37 E 630.43 2500.00 2348.12 2278.12 31 50 N 80 34 E 683.06 2600.00 2432.94 2362.94 32 11 N 80 52 E 736,02 2700.00 2517.51 2447.51 32 16 N 76 52 E 789.31 2800.00 2601.85 2531.85 32 47 N 78 7 E 842.90 2900.00 2685.66 2615.66 33 19 N 79 50 E 897.39 2.36 1.66 1 .20 1 .10 0.25 0.43 0.91 0.76 0.94 0.93 62 54 N 419.87 E 424.50 N 81 32 E 73 09 N 469.02 E 474.68 N 81 9 E 82 61 N 519.60 E 526.13 N 80 58 E 90 97 N 570.74 E 577.94 N 80 57 E 100 22 N 622.45 E 630.46 N 80 51 E 109 24 N 674.31 E 683.11 N 80 48 E 117 64 N 726.60 E 736.07 N 80 48 E 128.05 N 778.93 E 789.39 N 80 40 E 139.88 N 831.35 E 843.04 N 80 27 E 150.35 N 884.88 E 897.56 N 80 21 E 3000.00 2769.36 2699.36 32 46 N 79 30 E 952.09 3100.00 2853.60 2783.60 32 40 N 81 13 E 1005.95 3200.00 2937.55 2867.55 33 7 N 84 51 E 1060.25 3300.00 3021.37 2951.37 32 44 N 85 12 E 1114.64 3400.00 3105.70 3035.70 32 21 N 79 44 E 1168.36 3500.00 3190.15 3120.15 32 24 N 80 7 E 1221.88 3600.00 3274.73 3204.73 32 10 N 79 2 E 1275.20 3700.00 3359.32 3289.32 32 28 N 79 10 E 1328.50 3800.00 3443.42 3373.42 32 53 N 79 1 E 1382.55 3900.00 3527.70 3457.70 32 17 N 79 47 E 1436.34 1.10 2.42 2.09 2.38 1 .83 0.41 0.26 1 .23 1 .41 0.59 159.90 N 938.76 E 952.28 N 80 20 E 169.28 N 991.81 E 1006.16 N 80 19 E 175.75 N 1045.75 E 1060.42 N 80 28 E 179.90 N 1100.13 E 1114.74 N 80 43 E 186.93 N 1153.39 E 1168.44 N 80 48 E 196.58 N 1206.07 E 1221.98 N 80 45 E 206.15 N 1258.55 E 1275.32 N 80 42 E 216.02 N 1310.96 E 1328.64 N 80 39 E 226.61 N 1364.02 E 1382.72 N 80 34 E 236.38 N 14t6.95 E 1436.53 N 80 32 E COMPUTATION DATE: 21-NOV-91 PAGE 2 ARCO ALASKA [NC. D.S. 5-24 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 18-AUG-91 KELLY BUSHZNG ELEVATION: 70.00 FT ENGINEER: K.BARNARD [NTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTZCAL DEVIATZON AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 4000.00 3612.35 3542.35 31 57 N 79 54 E 1489.55 4100 O0 3697.48 3627.48 30 59 N 76 37 E 1541.95 4200 O0 3783 52 3713.52 30 36 N 74 52 E 1592 61 4300 O0 3869 61 3799,61 30 33 N 74 37 E 1643 13 4400 O0 3955 66 3885,66 30 40 N 74 24 E 1693 71 4500 O0 4041 60 3971,60 30 50 N 74 20 E 1744 45 4600 O0 4127 51 4057,51 30 44 N 74 15 E 1795 23 4700 O0 4213 68 4143,68 30 27 N 74 42 E 1845 58 4800,00 4300 15 4230,15 29 52 N 78 24 E 1895 63 4900.00 4386.88 4316.88 29 38 N 78 44 E 1945 33 0,21 3,45 0.48 0,27 0,94 O, 68 0,86 1,15 0,80 0,64 245,75 N 1469,35 E 1489.76 N 80 30 E 255,89 N 1520.82 E 1542,19 N 80 27 E 268,81 N 1570,11 E 1592,95 N 80 17 E 282,25 N 1619.18 E 1643,59 N 80 7 E 295,82 N 1668,29 E 1694 31 N 79 57 E 309,61 N 1717,52 E 1745 21 N 79 47 E 323.44 N 1766,80 E 1796 16 N 79 38 E 337.17 N 1815,65 E 1846 70 N 79 29 E 348,72 N 1864.53 E 1896 86 N 79 24 E 358,54 N 1913,31 E 1946 61 N 79 23 E 5000,00 4473 88 4403,88 29 25 N 78 56 E 1994 59 5100,00 4561 17 4491.17 29 0 N 79 7 E 2043 5200,00 4648 46 4578,46 29 37 N 79 5 E 2092 5300,00 4735 27 4665,27 29 49 N 79 28 E 2141 5400,00 4822 18 4752,18 29 32 N 79 59 E 2191 5500,00 4909 17 4839,17 29 53 N 79 28 E 2240 5600,00 4995,57 4925,57 30 10 N 79 7 E 2290 5700,00 5082,15 5012,15 29 52 N 79 34 E 2340 5800,00 5169,10 5099.10 29 25 N 79 59 E 2390 5900,00 5255,61 5185,61 31 2 N 77 40 E 2440 32 08 68 12 43 73 74 10 20 0,13 0,26 0,95 1 ,16 0,53 2,01 0,72 0,30 0,33 1 ,67 368,07 N 1961,70 E 1995,93 N 79 22 E 377,38 N 2009,58 E 2044 71 N 79 22 E 386,57 N 2057,50 E 2093 395,85 N 2106,26 E 2143 404.69 N 2154.93 E 2192 413,23 N 2203,51 E 2241 422,79 N 2252,94 E 2292 432,04 N 2302.12 E 2342 440.76 N 2350.73 E 2391 450,45 N 2399,94 E 2441 50 N 79 22 E 14 N 79 21 E 60 N 79 22 E 93 N 79 23 E 27 N 79 22 E 31 N 79 22 E 69 N 79 23 E 85 N 79 22 E 6000,00 5340,98 5270 98 31 34 N 77 2 E 2492,14 6100,00 5426,11 5356 6200,00 5511,36 5441 6300,00 5596,59 5526 6400,00 5681,84 5611 6500,00 5767.16 5697 6600,00 5852,53 5782 6700,00 5937,74 5867 6800,00 6023,07 5953 6900.00 6108.54 6038 11 31 33. N 76 47 E 2544,43 36 31 35 N 76 52 E 2596,53 59 31 30 N 77 12 E 2648,69 84 31 32 N 77 43 E 2700,83 16 31 '22 N 78 15 E 2752,89 53 31 22 N 78 31 E 2804,90 74 31 34 N 78 50 E 2857,17 07 31 17 N 78 54 E 2909,25 54 31 22 N 79 3 E 2961,12 0,71 0,38 0.96 0.46 0,49 0,50 1,22 0.32 0.20 0.79 461.96 N 2450.73 E 2493,89 N 79 20 E . 473,85 N 2501,82 E 2546,30 N 79 17 E 485,73 N 2552.73 E 2598.53 N 79 14 E 497,51 N 2603.70 E 2650.80 N 79 11 E 508.89 N 2654.71 E 2703.05 N 79 9 E 519,72 N 2705,73 E 2755,19 N 79 8 E 530.27 N 2756.74 E 2807.27 N 79 7 E 540.51 N 2808.05 E 2859.60 N 79 6 E 550.59 N 2859.21 E 2911.74 N 79 6 E 560.48 N 2910.17 E 2963.66 N 79 6 E 7000.00 6193.94 6123.94 31 19 N 78 33 E 3013.09 7100.00 6279.55 6209.55 30 52 N 79 50 E 3064.72 7200.00 6365.78 6295.78 29 55 N 83 48 E 3115.34 7300.00 6452.42 6382.42 29 59 N 83 49 E 3165.23 7400.00 6539.02 6469.02 30 7 N 83 53 E 3215.19 7500.00 6625.45 6555.45 30 20 N 83 54 E 3265.45 7600.00 6711.69 6641.69 30 27 N 83 49 E 3316.03 7700.00 6797.97 6727.97 30 12 N 83 59 E 3366.54 7800.00 6884.56 6814.56 29 57 N 84 40 E 3416.49 7900.00 6971.35 6901.35 29 27 N 85 54 E 3466.06 0.47 2.31 0.52 0.21 0.65 0.59 0.57 0.55 1.12 0.75 570.63 N 2961.21 E 3015.69 N 79 6 E 580.59 N 3011.92 E 3067.37 N 79 5 E 587,53 N 3062,06 E 3117,92 N 79 8 E 592.97 N 3111,70 E 3167.69 N 79 13 E 598.33 N 3161.41 E 3217.54 N 79 17 E 603.72 N 3211,43 E 3267.68 N 79 21 E 609,13 N 3261,76 E 3318,15 N 79 25 E 614,53 N 3312,02 E 3368,55 N 79 29 E 619.54 N 3361,78 E 3418,39 N 79 33 E 623,60 N 3411.30 E 3467.83 N 79 38 E COMPUTATION DATE: 21-NOV-91 PAGE 3 ARCO ALASKA [NC. D.S. 5-24 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 18-AUG-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST D[S~. AZZMUTH DEPTH DEPTH DEPTH DEG MIN DEG M[N FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 7058.70 6988.70 28 54 N 87 13 E 3514.55 8100.00 7146.36 7076.36 28 40 N 87 37 E 3562.41 8200.00 7234.07 7164.07 28 42 N 87 2 E 3610.17 8300.00 7321.85 7251.85 28 31 N 86 31 E 3657.88 8400.00 7409.71 7339.71 28 34 N 85 50 E 3705.48 8500.00 7497.55 7427.55 28 29 N 85 27 E 3753.14 8600.00 7585.66 7515.66 28 3 N 84 49 E 3800.33 8700.00 7674.03 7604.03 27 49 N 84 17 E 3847.0B 8800.00 7762.75 7692.75 26 58 N 83 42 E 3893.16 8900.00 7852.27 7782.27 26 1 N 83 25 E 3937.69 0 93 0 72 0 63 0 77 0 63 0 03 0 74 0 69 1 36 0 70 626.56 N 3459 89 E 3516.16 N 79 44 E 628'.57 N 3507 630.85 N 3555 633.49 N 36O3 636.72 N 3651 640.39 N 3699 644.38 N 3746 648.84 N 3792 653.65 N 3838 658.66 N 3882 98 E 3563.84 N 79 50 .E 94 E 3611.46 N 79 56 E 78 E 3659.04 N 80 2 E 43 E 3706.52 N 80 7 E 07 E 3754.09 N 60 11 E 19 E 3801.20 N 80 14 E 79 E 3847.89 N 80 18 E 67 E 3893.92 N 80 20 E 94 E 3938.41 N 80 22 E 9000.00 7942.16 7872.16 26 11 N 84 2 E 3981.48 9100.00 8031.68 7961.68 26 38 N 85 3 E 4025.98 9200.00 8120.93 8050.93 27 2 N 85 44 E 4070.98 9300.00 8209,94 8139.94 27 18 N 86 36 E 4116 38 9400.00 8298.80 8228.80 27 18 N 86 36 E 4162 07 9500.00 8387.65 8317.65 27 19 N 86 36 E 4207 77 9600.00 8475.87 8405.87 28 34 S 88 23 E 4253 59 9700.00 8563.95 8493.95 28 2 S 88 48 E 4300 22 9800.00 8652.49 8582.49 27 2 S 89 20 E 4346 08 9900.00 8742.07 8672.07 25 58 S 89 52 E 4390 O0 1 37 0 65 0 14 0 O0 0 O0 0 O0 0 47 0 66 2 12 1 15 663.51 N 3926.49 E 3982.16 N 80 25 E 667.76 N 3970.85 E 4026.61 N 80 27 E 671.31 N 4015.83 E 4071.55 N 80 31 E 674.22 N 4061.30 E 4116.88 N 80 34 E 676.94 N 4107.10 E 4162.51 N 80 38 E 679.66 N 4152.89 E 4208.14 N 80 42 E 674.00 N 4200.08 E 4253.82 N 80 53 E 672.80 N 4247.41 E 4300.37 N 81 0 E 672.09 N 4293.89 E 4346.17 N 81 6 E 671.83 N 4338.34 E 4390.05 N 81 12 E 10000.00 8832.42 8762.42 24 55 S 88 54 E 4432.29 10100.00 8923.39 8853.39 24 5 S 88 21 E 4473.20 10200.00 9015.29 8945.29 21 41 S 88 48 E 4511.97 10242.00 9054.90 8984.90 21 40 5 88 49 E 4527.18 0.85 0.56 1 .81 0.00 671.33 N 4381.18 E 4432.32 N 81 17 E 670.38 N 4422.69 E 4473.21 N 81 23 E 669.08 N 4462.08 E 4511.97 N 81 28 E 676.91 N 4476.29 E 4527.18 N 81 24 E COMPUTATION DATE: 21-NOV-91 PAGE 4 ARCO ALASKA INC. D.S. 5-24 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 18-AUG-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -70.00 0 0 1000.00 996.69 926.69 10 30 2000.00 1920.30 1850.30 29 16 3000,00 2769,36 2699,36 32 46 4000.00 3612,35 3542.35 31 57 5000.00 4473.88 4403.88 29 25 6000.00 5340.98 5270.98 31 34 7000.00 6193.94 6123.94 31 19 8000.00 7058.70 6988.70 28 54 9000.00 7942.16 7872.16 26 11 N 0 0 E N 80 28 E 54 N 77 49 E 424 N 79 30 E 952 N 79 54 E 1489 N 78 56 E 1994 N 77 2 E 2492 N 78 33 E 3013 N 87 13 E 3514 N 84 2 E 3981 0 O0 58 50 09 55 59 14 09 55 48 0.00 2.95 2.36 1.10 0.21 0.13 0.71 0.47 0,93 1 ,37 0.00 N 5.53 N 54 62.54 N 419 159.90 N 938 245 75 N 1469 368 07 N 1961 461 96 N 2450 57O 63 N 2961 626 56 N 3459 663 51N 3926 0 O0 E 0.00 N 0 0 E 36 E 54.64 N 84 11 E .87 E 424.50 N 81 32 E 76 E 952.28 N 80 20 E 35 E 1489.76 N 80 30 E 70 E 1995.93 N 79 22 E 73 E 2493.89 N 79 20 E 21 E 3015.69 N 79 6 E 89 E 3516,16 N 79 44 E 49 E 3982.16 N 80 25 E 10000.00 8832.42 8762.42 24 55 S 88 54 E 4432.29 10242.00 9054.90 8984.90 21 40 S 88 49 E 4527.18 0.85 0.00 671.33 N 4381.t8 E 4432.32 N 81 17 E 676.91 N 4476.29 E 4527.18 N 81 24 E COMPUTATION DATE: 21-NOV-91 PAGE 5 ARCO ALASKA INC. DATE OF SURVEY: 18-AUG-91 D.S. 5-24 KELLY BUSHING ELEVATION: 70.00 FT PRUDHOE BAY NORTH SLOPE, ALASKA ENGINEER: K.BARNARD INTERPOLATED VALUE5 FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -70.00 0 0 N 0 0 E 0 O0 70.00 70.00 0.00 0 4 N 85 0 E 0 02 170.00 170.00 100.00 0 10 N 64 37 E 0 36 270.00 270.00 200.00 0 17 S 43 30 E 0 45 370.00 370.00 300.00 0 7 N 8 53 E 0 76 470.01 470.00 400.00 1 35 N 89 48 E 1 25 570.08 570.00 500.00 2 42 N 89 55 E 5 O0 670.27 670.00 600.00 4 17 N 88 19 E 1~ 06 770.72 770.00 700.00 6 22 N 85 $ E 20 45 871.62 870.00 800.00 8 27 N 82 5 E 33 84 972.89 970.00 900.00 9 54 N 80 37 E 49.76 1074.86 1070.00 1000.00 12 30 N 80 52 E 69.68 1177.90 1170.00 1100.00 15 35 N 83 4 E 94.46 1282.40 1270.00 1200.00 17 56 N 82 37 E 124.78 1387.92 1370.00 1300.00 19 29 N 82 8 E 158 45 1494.87 1470.00 1400.00 22 5 N 80 44 E 196 34 1604.03 1570.00 1500.00 25 10 N 81 9 E 240 07 1715.90 1670.00 1600.00 27 32 N 81 54 E 290 19 1829.11 1770.00 1700.00 28 14 N 80 55 E 343 27 1942.59 1870.00 1800.00 28 28 N 78 50 E 396 87 2057.32 1970.00 1900.00 30 24 N 77 50 E 452.99 2173.75 2070.00 2000.00 31 4 N 79 41 E 512.56 2290.62 2170.00 2100.00 31 22 N 80 42 E 573.03 2408.12 2270.00 2200.00 31 48 N 79 40 E 634.70 2525.76 2370.00 2300.00 31 53 N 80 46 E 696.65 2643.81 2470.00 2400.00 32 17 N 79 2 E 759.38 2762.16 2570.00 2500.00 32 34 N 77 24 E 822.52 2881.27 2670.00 2600.00 33 13 N 79 32 E 887.11 3000.76 2770.00 2700.00 32 46 N 79 29 E 952.50 3119.49 2870.00 2800.00 32 45 N 82 7 E 1016.48 3238.76 2970.00 2900.00 33 11 N 85 58 E 1081.40 3357.72 3070.00 3000.00 32 29 N 82 2 E 1145.70 3476.13 3170.00 3100.00 32 24 N 79 53 E 1209.10 3594.41 3270.00 3200.00 32 10 N 79 3 E 1272.23 3712.66 3370.00 3300.00 32 33 N 78 54 E 1335.30 3831.63 3470.00 3400.00 32 42 N 79 32 E 1399.67 3950.04 3570.00 3500.00 32 14 N 79 51 E 1463.07 4067.86 3670.00 3600.00 31 31 N 78 32 E 1525.33 4184.29 3770.00 3700.00 30 37 N 74 57 E 1584.67 4300.45 3870.00 3800.00 30 33 N 74 37 E 1643.36 FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.12 0.68 0.77 0.34 3.21 2.10 2.63 1 .86 0.31 1 .70 2.04 3.79 1 .46 1 .68 3.00 3.68 0.75 0.94 1 .51 1 .26 1 .00 0.95 0.36 0.57 3.11 1 .44 1.10 1 .08 2.62 0.81 4.06 0,98 0.34 1 .55 0.62 1 .88 3.65 0.25 0.28 0.00 N 0.00 E 0.00 N 0 0 E 0.02 S 0.03 E 0.03 S 54 6 E 0.08 S 0.38 E 0.39 S 77 51 E 0.08 S 0.46 E 0.47 S 80 41 E 0.05 S 0.78 E 0.78 S 86 7 E 0.08 N 1.25 E 1.25 N 86 9 E 0.10 N 5,04 E 5.04 N 88 53 E 0.16 N 11.16 E 11,16 N 89 11 E 0.80 N 20.56 E 20.57 N 87 46 E 2.32 N 33,87 E 33.95 N 86 5 E 4.74 N 49.63 E 49.85 N 84 32 E 8.01 N 69.26 E 69.72 N 83 24 E 11.46 N 93.80 E 94.49 N 83 2 E 15.09 N 123.91 E 124.83 N 83 3 E 19.58 N 157.28 E 158.50 N 82 54 E 25.16 N 194.76 E 196.38 N 82 38 E 32.31 N 237.91 E 240.10 .N 82 16 E 39.54 N 287.50 E 290.21 N 82 10 E 47..36 N 340.00 E 343.29 N 82 4 E 56.92 N 392.77 E 396.87 N 81 45 E 68.60 N 447.77 E 452.99 N 81 17 E 80.24 N 506.26 E 512.58 N 81 0 E 90.18 N 565.91 E 573.05 N 80 57 E 100.99 N 626.66 E 634.74 N 80 51 E 111.45 N 687.73 E 696.70 N 80 48 E 121.71 N 749.62 E 759.43 N 80 47 E 135.55 N 811.39 E 822,63 N 80 31 E 148.51 N 874.76 E 887.28 N 80 22 E 159.98 N 939.16 E 952.69 N 80 20 E 170.81 N 1002.23 E 1016.68 N 80 20 E 177.45 N 1066.88 E 1081.53 N 80 33 E 183.29 N 1131.03 E 1145.78 N 80 48 E 194.36 N 1193.47 E 1209.19 N 80 45 E 205.60 N 1255.63 E 1272.35 N 80 42 E 217.30 N 1317.64 E 1335.44 N 80 38 E 229.80 N 1380.86 E 1399.85 N 80 33 E 241.10 N 1443.27 E 1463.27 N 80 31 E 252.29 N 1504.55 E 1525.56 N 80 29 E 266.72 N 1562.39 E 1584.99 N 80 19 E 282.31 N 1619.40 E 1643.82 N 80 7 E ARCO ALASKA INC. D.S. 5-24 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 21-NOV-91 PAGE 6 DATE OF SURVEY: 18-AUG-91 KELLY BUSHING ELEVATZON: 70.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4416.67 3970 O0 3900.00 30 41 4533.07 4070 4649.35 4170 4765.21 4270 4880.55 4370 4995,55 4470 5110.09 4570 5224.79 4670 5340.00 4770 5454.93 4870 N 74 21 E 1702.15 O0 4000.00 30 50 N 74 21 E 1761.27 O0 4100.00 30 24 N 74 12 E 1820.14 O0 4200.00 30 3 N 77 30 E 1878.28 O0 4300.00 29 49 N 78 43 E 1935.68 O0 4400.00 29 26 N 78 56 E 1992.41 O0 4500.00 29 1 N 79 8 E 2048.22 O0 4600.00 29 47 N 79 5 E 2104.35 O0 4700.00 29 39 N 79 39 E 2161.5~ O0 4800.00 29 27 N 80 17 E 2218.15 0 96 0 65 051 2 29 1 O0 0 15 0 22 0 15 081 0 88 298.11 N 1676.48 E 1702.78 N 79 55 E 314.19 N 1733.85 E 1762.08 N 79 44 E 330.27 N 1790.96 E 1821.16 N 79 33 E 345.11 N 1847.53 E 1879.49 N 79 25 E 356.65 N 1903.84 E 1936.96 N 79 23 E 367.65 N 1959.55 E 199,3.74 N 79 22 E 378.30 N 2014.39 E 2049.60 N 79 22 E 388.90 N 2069.56 E 2105.78 N 79 21 E 399.45 N 2125.78 E 2162,98 N 79 21 E 409.32 N 2181.57 E 2219,64 N 79 22 E 5570.40 4970.00 4900.00 30 19 N 78 56 E 2275,84 5685.98 5070.00 5000.00 29 54 5801.03 5170.00 5100.00 29 25 5916.81 5270.00 5200.00 31 14 6034.08 5370.00 5300.00 31 42 6151.48 5470.00 5400.00 31 30 6268.82 5570.00 5500.00 31 28 6386.11 5670.00 5600.00 31 33 6503.32 5770.00 5700.00 31 22 6620.48 5870.00 5800.00 31 26 N 79 30 E 2333 N 79 58 E 2390 N 77 23 E 2448 N 76 56 E 2509 N 76 53 E 2571 N 77 3 E 2632 N 77 37 E 2693 N 78 15 E 2754 N 78 39 E 2815 75 61 87 96 26 46 58 62 56 1 .25 0.45 0.39 1.11 0.50 0.26 0.31 0.38 0.46 1 .08 419.95 N 2238.31 E 2277.36 N 79 22 E 430.77 N 2295.25 E 2335,32 N 79 22 E 440.85 N 2351.23 E 2392.20 N 79 23 E 452.32 N 2408.42 E 2450.52 N 79 22 E 465.98 N 2468.14 E 2511.75 N 79 19 E 479.98 N 2528.03 E 2573.19 N 79 15 E 493.88 N 2587.83 E 2634.53 N 79 12 E 507.34 N 2647.62 E 2695.79 N 79 9 E 520.07 N 2707.42 E 2756.92 N 79 8 E 532.39 N 2767.20 E 2817.95 N 79 7 E 6737.85 5970.00 5900.00 31 29 6854.89 6070.00 6000.00 31 14 6971.97 6170.00 6100.00 31 22 7088.87 6270.00 6200.00 30 56 7204.87 6370.00 6300.00 29 56 7320.29 6470.00 6400.00 29 59 7435.81 6570.00 6500.00 30 7 7551.64 6670.00 6600.00 30 27 7667.61 6770.00 6700.00 30 21 7783.20 6870.00 6800.00 29 54 N 78 51 E 2876.94 N 79 3 E 2937.70 N 78 36 E 2998.53 N 79 28 E 3059.00 N 83 47 E 3117.76 N 83 50 E 3175.36 N 83 50 E 3233.15 N 83 51 E 3291.53 N 83 53 E 3350.23 N 84 28 E 3408.12 0.64 0,11 0.28 1 .84 0.42 0.19 0.41 0.47 0.55 0.81 544.35 N 2827.47 E 2879.40 N 79 6 E 556.04 N 2887.17 E 2940.22 N 79 6 E 567.74 N 2946.91 E 3001.11 N 79 6 E 579.55 N 3006.30 E 3061.65 N 79 5 E 587.79 N 3064,48 E 3120.34 N 79 9 E 594.07 N 3121.78 E 3177,80 N 79 14 E 600.25 N 3179.28 E 3235,45 N 79 18 E 606.50 N 3237.38 E 3293.70 N 79 23 E 612.80 N 3295.79 E 3352,28 N 79 28 E 618.74 N 3353.44 E 3410.05 N 79 33 E 7898.45 6970.00 6900.00 29 28 N 85 53 E 3465.30 8012.91 7070.00 7000.00 28 49 N 87 24 E 3520.76 8126.94 7170.00 7100.00 28 39 N 87 24 E 3575.26 8240.95 7270.00 7200.00 28 41 N 86 55 E 3629.74 8354.81 7370.00 7300.00 28 32 N 86 2 E 3683.96 8468.65 7470.00 7400.00 28 30 N 85 29 E 3738.22 8582.25 7570.00 7500.00 28 6 N 84 57 E 3791.99 8695.45 7670.00 7600.00 27 50 N 84 18 E 3844.96 8808.13 7770.00 7700.00 26 52 N 83 40 E 3896.84 8919.72 7870.00 7800.00 25 57 N 83 27 E 3946.33 0.72 1 .05 0.70 0.46 0.39 0.18 O. 64 0.79 1 .02 0.30 623.55 N 3410.54 E 3467.07 N 79 38 E 626.86 N 3466.12 E 3522.35 N 79 45 E 629.13 N 3520.89 E 3576.65 N 79 52 E 631.88 N 3575.57 E 3630.97 N 79 59 E 635.19 N 3629.90 E 3685.05 N 80 4 E 639.21 N 3684.16 E 3739.20 N 80 9 E 643.63 N 3737.87 E 3792.88 N 80 14 E 648.62 N 3790.68 E 3845.78 N 80 17 E 654.05 N 3842.33 E 3897.60 N 80 20 E 659.65 N 3891.53 E 3947.05 N 80 23 E COMPUTATION DATE: 21-NOV-91 PAGE 7 ARCO ALASKA INC, D.S. 5-24 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 18-AUG-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: K,BARNARD [NTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 9031,05 7970 O0 7900.00 26 26 9142,90 807O 9255,07 8170 9367,59 8270 9480.13 8370 9592,85 847O 9706,85 8570 9819,62 8670 9931,02 8770 10041,39 8870 N 84 18 E 3995.23 O0 8000,00 26 43 N 85 33 E 4045,23 O0 8100.00 27 7 N 86 33 E 4095,90 O0 8200,00 27 18 N 86 36 E 4147,26 O0 8300,00 27 19 N 86 36 E 4198.69 O0 8400.00 27 37 N 87 48 E 4250.22 O0 8500.00 28 0 S 88 51 E 4303.40 O0 8600.00 26 38 S 89 29 E 4354.83 O0 8700.00 25 33 S 89 31 E 4403.32 O0 8800,00 24 41 S 88 48 E 4449.40 0.65 0.95 0.67 0 O0 0 O0 011 0 97 2 06 1 29 0 76 664,91 N 3940,19 E 3995,90 N 80 25 E 669,36 N 3990.08 E 4045.84 N 80 29 E 673,01 N 4040.77 E 4096.43 N 80 33 E 676.06 N 4092,25 E 4147.72 N 80 37 E 679,12 N 4143.79 E 4199,07 N 80 42 E 680.19 N 4195.75 E 4250.52 N 80 47 E 672.73 N 4.250.63 E 4303.54 N 8~ 0 E 671.99 N 4302.75 E 4354.91 N 8~ 7 E 671.76 N 4351.82 E 4403,36 N 81 13 E 670.97 N 4398.53 E 4449.42 N 81 20 E 10150,93 8970.00 8900.00 23 19 S 87 52 E 4493.40 10242,00 9054,90 8984,90 21 40 S 88 49 E 4527.18 1 . 99 0.00 669,73 N 4443,21 E 4493.41 N 81 26 E 676,91 N 4476,29 E 4527.18 N 81 24 E ARCO ALASKA INC. D.S. 5-24 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER SAG SHUBLIK A ZONE 4 ZONE 3 ZONE 2 GAS/OIL CONTACT LOW GAS ZONE 18 BASE SADLEROCHIT GCT LAST READING TD COMPUTATION DATE: 21-NOV-91 DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: PAGE 8 18-AUG-91 70.00 FT K.BARNARD INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2203' FSL & 1194' FWL, SEC32 TllN R15E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 9476.00 9520.00 9597.00 9781.00 9836.00 9858.0O 10023.00 10048.D0 10144.00 10200.20 8366 33 8405 42 8473 41 8635 60 8684 66 8704 37 8853 29 8876.0~ 8963.64 9015.47 8296.33 8335.42 8403.41 8565.6O 8614.66 8634.37 8783.29 8806.01 8893.64 8945.47 679.01 N 4141.90 E 680.20 N 4162.05 E 676.54 N 4198.27 E 672.19 N 4285.20 E 671.94 N 4310.06 E 671.88 N 4319.83 E 671.14 N 4390.84 E 670.91.N 4401.28 E 669.83 N 4440.46 E 669.07 N 4462.16 E 10242.00 9054.90 8984.90 676.91 N 4476.29 E COMPUTATION DATE: 21-NOV-91 PAGE 9 ARCO ALASKA INC. D.S. 5-24 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 18-AUG-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: K.BARNARD SURFACE LOCATION = 2203' FSL & 1194' FWL, SEC32 T11N R15E MARKER MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDZNATES NORTH/SOUTH EAST/WEST SAG SHUBLIK A ZONE 4 GAS/OIL CONTACT LOW GAS TD 9476.00 8366.33 8296.33 679.01 N 4141.90 E 9520.00 8405.42 8335.42 680.20 N 4162.05 E 9597.00 8473.41 8403.41 676.54 N 4198.27 E 9858.00 8704.37 8634.37 671.88 N 4319.83 E 10023.00 8853.29 8783.29 671.14 N 4390.84 E 10242.00 9054.90 8984.90 676.91 N 4476.29 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 10242.00 9054.90 8984.90 4527.18 N 81 24 E DIRECTIONAL SURVEY COMPANY ARCO ALASKA INC. F,'=L= PRUDHOE BAY w,;u. D.S. 5-24 COUNTRY USA ONE DATE LOGGED 18 - AUGI - 91 DEPTH UNIT FEET 74857 All In~fpretallone are oplrdon~ baaed on I~erenoee ltom el~attloal or other mea~emenl~ and we ~ att4 40 n~ ~uara~ee me accuracy or c:on~:lnee- M any Inl~lxeMEon~ and we MtMI nM. e~c~ept m Ihe oa~e M gmee M MIIk~ M~/Mte resulting horn any In~eqxet~lon made by any of our MIIMm agertl or employee& Theae Wq)/eMEMll Me Mac) subJeM k) our GenMM TMm$ and Cofldik)fle al aetoM it ou/oufren~ p~oe 8(~hedlJe. WELL' D.S. 5-24 (2203' FSL,1194' FWL,SEC 32,T11N,R15E) HORIZONTAL PROJECTION ~F 74e67 8o~J.~ - 1 I 1000 -2000 -1000 0 1000 2000 3000 4000 5000 6000 ~T WELL' D.S. 5-24 (2203' FSL, 1194' FWL,SEC 32,T11N,R15E) VERTICAL PROJECTION -2000 -t000 0 0 1000 2000 3000 4000 5000 6000 ...i...!...i...i ...... i...!_%.~ ...... !...i...L..i ...... L..L..LJ ...... ,..,...,...,,.....,...,...,..., ...... i...i...i...i ...... i...L..L..i ...... !...i...i...!...i...i...i...!...i ..... L..i...i...i ...... i...i...i...i ....... 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Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' 0 0 0.0 0.0 0.00 0.01 0.01N 0.01E 0.01 N 45.00E 0.00 391 Teleco MWD Surveys 391 0.1 189.9 391.00 -0.09 0.29S 0.05W 0.30 S 9.46W 0.03 481 90 0.9 88.0 481.00 0.59 0.34S 0.64E 0.73 S 61.84E 1.03 602 121 3.1 92.5 601.92 4.76 0.45S 4.86E 4.88 S 84.66E 1.82 661 59 4.4 89.0 660.79 8.57 0.49S 8.72E 8.73 S 86.82E 2.24 PAGE 1 Company: Prudhoe Bay Drillinq, Well: DS 5-24, Location: Prudhoe Bay, Rig: Doyan 9 Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' 781 120 6.6 86.8 780.23 20.02 0.02S 20.21E 20.21 S 89.94E 1.84 811 30 7.6 85.1 810.00 23.72 0.25N 23.91E 23.91 N 89.41E 3.41 871 60 7.9 82.3 869.45 31.81 1.14N 31.95E 31.97 N 87.96E 0.80 960 89 9.8 80.9 957.39 45.50 3.15N 45.49E 45.60 N 86.03E 2.15 990 30 10.2 79.5 986.93 50.70 4.04N 50.62E 50.78 N 85.43E 1.56 1020 30 11.3 78.8 1016.40 56.29 5.10N 56.12E 56.35 N 84.81E 3.69 1110 90 13.6 81.3 1104.28 75.67 8.41N 75.23E 75.70 N 83.62E 2.62 1205 95 16.5 83.7 1196.01 100.33 11.58N 99.68E 100.35 N 83.37E 3.12 1235 30 17.0 84.4 1224.74 108.98 12.48N 108.29E 109.00 N 83.43E 1.83 1457 222 20.6 84.4 1434.86 180.48 19.46N 179.49E 180.55 N 83.81E 1.62 1551 94 24.1 83.1 1521.78 216.20 23.38N 215.01E 216.28 N 83.79E 3.76 1680 129 27.2 84.8 1638.06 272.00 29.22N 270.54E 272.11 N 83.84E 2.47 1743 63 28.1 84.1 1693.86 301.22 32.05N 299.64E 301.34 N 83.90E 1.52 1903 160 28.5 80.8 1834.75 377.04 42.02N 374.80E 377.15 N 83.60E 1.01 PAGE 2 Company: Prudhoe Bay Drillinq, Well: DS 5-24, Location: Prudhoe Bay, Riq: Doyan 9 Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/i00' 1934 31 27.9 80.9 1862.07 391.69 44.35N 389.27E 391.78 N 83.50E 1.94 2094 160 30.8 79.5 2001.52 470.05 57.74N 466.52E 470.08 N 82.94E 1.86 2253 159 31.4 82.3 2137.67 552.13 70.71N 547.60E 552.15 N 82.64E 0.98 2571 318 32.2 82.3 2407.93 719.70 93.16N 713.66E 719.72 N 82.56E 0.25 2699 128 32.4 77.4 2516.15 787.99 105.22N 780.94E 787.99 N 82.33E 2.05 2794 95 32.9 78.5 2596.13 839.10 115.91N 831.06E 839.10 N 82.06E 0.82 2922 128 33.5 81.6 2703.25 909.12 128.00N 900.08E 909.13 N 81.91E 1.41 3049 127 32.6 79.9 2809.70 978.35 139.12N 968.43E 978.37 N 81.82E 1.02 3240 191 33.6 86.9 2969.76 1082.48 151.01N 1071.90E 1082.48 N 81.98E 2.07 3335 95 32.6 85.5 3049.34 1134.23 154.44N 1123.66E 1134.23 N 82.17E 1.32 3430 95 32.5 78.8 3129.45 1185.27 161.41N 1174.23E 1185.27 N 82.17E 3.79 3493 63 32.8 80.6 3182.49 1219.22 167.48N 1207.67E 1219.22 N 82.10E 1.61 3653 160 32.3 80.6 3317.36 1305.27 181.54N 1292.59E 1305.28 N 82.01E 0.31 PAGE 3 Company: Prudhoe Bay Drillinq, Well: DS 5-24, Location: Prudhoe Bay, Riq: Doyan 9 Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/i00' 3843 190 33.0 80.6 3477.33 1407.75 198.29N 1393.74E 1407.77 N 81.90E 0.37 3993 150 32.1 80.6 3603.76 1488.43 211.47N 1473.37E 1488.47 N 81.83E 0.61 4025 32 31.8 80.6 3630.91 1505.36 214.23N 1490.08E 1505.40 N 81.82E 0.94 4152 127 30.8 76.0 3739.44 1571.14 227.56N 1554.65E 1571.22 N 81.67E 2.04 4279 127 30.7 75.7 3848.59 1635.68 243.43N 1617.61E 1635.83 N 81.44E 0.15 4470 191 30.9 76.4 4012.65 1732.91 267.01N 1712.53E 1733.22 N 81.14E 0.21 4629 159 30.8 75.3 4149.15 1813.94 286.94N 1791.59E 1814.42 N 80.90E 0.36 4788 159 30.1 79.9 4286.24 1894.20 304.26N 1870.23E 1894.81 N 80.76E 1.53 4947 159 29.1 79.9 4424.49 1972.67 318.03N 1947.54E 1973.34 N 80.73E 0.63 5107 160 29.2 79.9 4564.22 2050.54 331.70N 2024.27E 2051.27 N 80.69E 0.06 5262 155 29.8 80.6 4699.13 2126.82 344.62N 2099.49E 2127.59 N 80.68E 0.45 5422 160 29.5 80.2 4838.18 2205.93 357.82N 2177.54E 2206.74 N 80.67E 0.22 5549 127 30.6 79.9 4948.11 2269.48 368.81N 2240.18E 2270.33 N 80.65E 0.87 PAGE 4 Company: Prudhoe Bay Drillinq, Well: DS 5-24, Location: Prudhoe Bay, Riq: Doyan 9 Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/i00° 5771 222 29.7 81.3 5140.07 2380.93 387.04N 2350.17E 2381.83 N 80.65E 0.51 5959 188 31.6 77.4 5301.82 2476.60 404.83N 2444.29E 2477.59 N 80.60E 1.46 6086 127 31.8 78.5 5409.87 2543.15 418.76N 2509.56E 2544.26 N 80.53E 0.48 6246 160 31.7 78.1 5545.93 2627.14 435.83N 2592.00E 2628.39 N 80.46E 0.15 6404 158 31.5 79.2 5680.50 2709.77 452.13N 2673.17E 2711.14 N 80.40E 0.39 6592 188 31.6 79.9 5840.71 2808.03 469.97N 2769.91E 2809.49 N 80.37E 0.20 6624 32 31.6 79.2 5867.97 2824.78 473.01N 2786.39E 2826.26 N 80.37E 1.15 6720 96 31.7 79.5 5949.69 2875.09 482.32N 2835.90E 2876.62 N 80.35E 0.20 6879 159 31.4 79.5 6085.19 2958.19 497.48N 2917.70E 2959.81 N 80.32E 0.19 7029 150 31.6 78.8 6213.08 3036.45 512.24N 2994.68E 3038.17 N 80.29E 0.28 7192 163 30.2 84.4 6352.97 3120.07 524.53N 3077.39E 3121.77 N 80.33E 1.96 7352 160 30.1 85.1 6491.33 3200.35 531.89N 3157.41E 3201.90 N 80.44E 0.23 7511 159 30.5 84.8 6628.61 3280.48 538.95N 3237.32E 3281.88 N 80.55E 0.27 PAGE 5 Company: Prudhoe Bay Drillinq, Well: DS 5-24, Location: Prudhoe Bay, Rig: Doyan 9 ~ .Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/I00' 7670 159 30.4 84.8 6765.68 3360.98 546.25N 3317.57E 3362.24 N 80.65E 0.06 7829 159 30.1 85.5 6903.03 3440.97 553.03N 3397.38E 3442.10 N 80.75E 0.29 7987 158 29.2 87.6 7040.34 3518.90 557.75N 3475.39E 3519.86 N 80.88E 0.87 8141 154 28.8 88.0 7175.03 3593.21 560.61N 3549.99E 3593.99 N 81.03E 0.29 8303 162 28.7 87.6 7317.06 3670.76 563.60N 3627.86E 3671.37 N 81.17E 0.14 8462 159 28.7 86.6 7456.53 3746.83 567.46N 3704.11E 3747.32 N 81.29E 0.30 8621 159 28.0 85.5 7596.45 3822.17 572.65N 3779.44E 3822.58 N 81.38E 0.54 8779 158 27.3 84.0 7736.40 3895.43 579.34N 3852.47E 3895.78 N 81.45E 0.63 8866 87 26.5 84.8 7813.99 3934.76 583.19N 3891.64E 3935.09 N 81.48E 1.01 8997 131 26.2 84.8 7931.38 3992.85 588.46N 3949.54E 3993.14 N 81.53E 0.23 9160 163 27.0 86.2 8077.12 4065.72 594.17N 4022.31E 4065.96 N 81.60E 0.63 9315 155 27.1 87.2 8215.16 4136.00 598.23N 4092.69E 4136.18 N 81.68E 0.30 9442 127 27.0 90.2 8328.27 4193.38 599.54N 4150.43E 4193.51 N 81.78E 1.08 PAGE 6 CompaR¥: Prudhoe Bay Drillinq, Well: DS 5-24, Location: Prudhoe Bay, Riq: Doyan 9 Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/i00' ******************************************************************************************************* 9508 66 28.0 91.5 8386.80 4223.52 599.08N 4180.91E 4223.61 N 81.85E 1.77 PAGE 7 T~CO O~lfield PLAN VIEW S e F' V :l 12800 Prudhoe Bay Drilling DS 5-24 Prudhoe Bay Doyan 9 JOB# 842tak/O0 SCALE: 1 inch = 1600 feet 11200 9600 8000 6400 z CD 4800 3200 1600 1600 1600 '1600EAST 32(~fOt) 4800 6400 SO00 1000 2000 '~3000 ~4000 >5000 6000 7000 8000 9O00 -1000 TEOCO Oilfield Service VERTICAL PROJECTION 1000 2000 3000 4000 5000 602 ' 3. 1 deg Prudhoe Bay Dr'illing 811 ' 7.6 deg DS 5-24 ~.020 ' 11.`3 deg Prudhoe Bay ~ 1235 ' 17.01 dog goyan 9 -1457 ' 20.6 (::leg dOB# 842tak/O0 SCALE' \ k ~s`34 · 27.9 ~.g 1 inch = 1000 feet -~2253 ' 31.4 deg 2571 ' .32.2 aeg -kk2922 ' :3`3.5 deg k3240 ' :33.6 cleg -1~493 ' :32.8 oleg -~3843 ' 33.01 cteg 4152 ' 30.8 aeg -~4470 ' _30.9 cleg -~4788 ' 30..1 deg -~5 ~ 07 ' 29.2 cleg -~5422 ' 29.5 deg -~5771 ' 29.7 deg -1~6086 ' 31.8 oleg -~8404 ' 3'1 .5 oleg -~6720 ' 3!.7 deg -~7029 ' 31.6 cleg \ -]~7352 ' 30. 1 cleg -~7670 ' 30.4 cleg -~7987 ' 29.2 cleg -~8303 ' 28.7 d~ -]~8621 ' 28.0'1 9508 ' deg deg O~ oleg !B .0~. aeg VERTICAL SECTION (fi:) AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PERMIT # C~I - 10~ WELL NAME ~U~ ~ 5-~,~ COMPLETIONDATE (~ I '7 I ql CO. CONTACT ~k1~O check off o¥' list'data as it is receivcd.*list received date for 407. if not required list as NR ' 407 ! * I J ~l JqZ drillin~ history, v" ' survey, !.._?) ! well tests O ! core descriptiorlNl~ , ,cored int~rval's core analysis ~ dry ditch intervals digital data , , , ..~o'/I ON i LOG TYPE RUN INTERVALS SCALE · , NO. [to the nearest foot) [inchl100'! i iii i 13i , i iii i 1~] .. ~q . i'81 ' i ARCO ALASKA, INC~ F'.O. BOX 100360 ANCHORAGE, ALASKA 995i0 DATE' i2-5i-9i REFEF,'ENCE: .e. LS-i 4 S-24 7-20 _t'~-6 ¢~i t--22 '2 - 5: ~4-~ PLEASE ARCO CASED HOLE FINALS t t~8-9i ~ .CCL FOR AVA PACKER &CIRC. 9-2,1-~i '-'""PERF RECORD i0-25-9i '~'.CORRELATION (TUBING F'AI'CH) i2-5-9i ~PERF RECORD 9-7-9i'/' /,PERF RECORD t~-29-9t ¢ COLLAR LOCATOR 9-27-9i ~'ERF' RECORD ~ o-~ 2-~~7'~- ~E~:~ . i0-i0-9t ~'ERF RECORD t~-28-9t ~/~ERF RECORD , i~-28-9i ~ORRELATION NEUTRON ii-sS-gl/zW.RERF RECORD , ii-22-9i ~UORRELATION ~TUBING RATCH) ii,-2s-gi~ ~" ~'ERF RECORD ii-25-9i ~PERF RECORD SIGN AND RETURN THE ATTACHED RECEIVED BY __~ ~ HAVE A NICE DAY! SONYA WALLACE AT0-t529 HOLES RUN i, 5" RUN t, 5" RUN t, 2"&5" RUN RUN t, 5" RUN 1, 5' RUN i, 5' RUN i, 5' RUN i, 5' RUN RUN i, 5' RUN t, 5" RUN i, RUN t, 5' RUN t, 5' RUN t, 5' COPY AS RECEIP]' O~ DAT~I. AF'F'ROVED i" ,;: ici ,"~t .3' :~- '/iIv E D HLS HLS HLS HL$ HLS HLS HLS HLS HLS HLS HLS HLS HLS HLS HLS HLS JAN 10 1992 DISTRIBUTION "- CENTRAL FILES ~.-~'CHEVRON · "' EXTENSION EXPLORATION · "' EXXON MARAI'HON ~'~ MOBIL Alaska Oil & Gas Cons. Commission Anchorage PHILLIPS PB WELL FILES ~"' BF'X · .-'"' STATE OF ALASKA TEXACU REFERENCE' ARCO CASED HOLE FINAL.,.$ PROD F'ROFILE GR/CCL 6R/CCL I"'ERF BREAK DOWN 6R/CCL LEAK DIETECT F:' F;: U i..' P' I-,: L.'. 1'- j. I... ~:. LEAK ~;,E'i" !E F: T PROD PROFILE F;,'UN i , 5:" CA F,'UN i , 5" CAHCC' f:'. I...I i'..-I ~ , c~- , I"..' A t'i ' '~ ' t-,'UN i .. :!!::" Cr-~"iC:L, RUN 'i , 5" CA RIjN i , 2 ' ,~.~.,_.." CAi'dC(?: F'.: i...! ?..~. i , 5-" RUt,! i , "'".,. · RUN i, 5" CAHCO PLEASE $IC-N AND RETURN THE A'FTACHF_'D COF'Y Al: RECEIF'T OF DATA. · RECEIVED BY~~ H A V'"':::. '.':, ~,,'-! ]: C, 'i.:.: :(}, A. Y ! .- .' ~ '~' ~g "' I/.....""~ u,',~ ' - c,o~,.,ssW~ E.;FiNYA WA ~ ,-',r--~ .... .......... ' ........ '-,s u~ .... A P P R 0 V E D '-".' '"" ;;_,.. ,s~ i//344 T 0 5 2 9 i~ I~l~ r u:, -- ,a~o~-,~ "- R ~ ~". S-'~ 9 'i "" 4 :~ r"'!zX.!T.~:AL F."-r~ ~:-.'.- .,, ~::,~..~'r~ i TF:',?? · .-- I... ~ .. , ? .. 4. ~.- L_ ,.:. '~ ~ , : 4. ,.. ~....~. ~ r'. t'- ~ ~ ', '-' ~ , . . . _. ", ~' . ' ' . ' ' ~' . ............. : -- -' .... : ....:"" :'"'~"- ...... ~":'D '~:"~ '~''::":' -'.:':'~: ' · R & D ....... · :~ E X X 0 N ;~ ::~' '~" ~::~ "I !:~: U i::' ~ L. A ::':. i'::: A MARATHON TEXACO ~ MOBIL ARCO AI...A;?KA, INC.. ~ F:'., 0, B 0 X i ,:.'") (-) S 6,3 !Jj~ :!~ A N C I-.I 0 R A (.~.E, A 1.. A ,S' K A 9 9 5 "i ,'-", DATE · i C,-'i .... 9i R E F:' E R E N C E ' A R C 0 H A Cf N E'i" I C i" A P E ( S ) W I 1' i"1 t_ I S; T I N G ( ,S' ) ..,~'~ '""~ 4.~. 8-i S-9i D I F" I.. / B H C. A / C NI_ / G R ,J 0 B :-~: 8 9 '7 8 9 F:'LE]A3'E". ,S'I6N AND RETURN Tt"iE ATTACI"tED COF:'Y AS RFZCE.1]PT OF DATA, HAVE A NICE DAY! SONYA WALLACE A 't' 0 - i 5 2 9 A I::' P R 0 V E D .'~/~r~..~..~ ~ TRANS:~ 9 A'¥LA;? D I S l'f;,' I BUT I ON CENTRAL FII_E$ (CFI) C I.-t E V R 0 N D & H TAHHAS' BROWN (OH/GCT) EXXON HARAI"HON HOB l L.. · " P H I k L_ I !::' F:'B WEI..I.. I::'IL.E.S,' R & D · ,-'" B P X STATE: OF ALASKA T E X A C 0 ARCO ALASKA, INC~ F'.O. BOX tOOS60 ANCHORAGE, ALASKA DATE' 9-6-9~ REFERENCE' ARCO CASED HOLE FINALS ~~'~\)~9 2-30 no , 8-~-9~ CBT RUN ~ 5' 2-30 8-22-9t CET RUN ~, 5' 2-30 8-22-9~ F'ACKER SETTING REC RUN ~, 5' / 5-24 8-~7-9~ CBT RUN ~, 5' 5-24 8-t T-9~ CET RUN 5-24 8-~8-9~ COMPLETION RECORD RUN ~3-3 8-25-9t PERK RECORD RUN ~, 5' F'LEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIPT OF DATA. HAVE A NICE DAY! $ONYA WALLACE AT0-~529 AF'F'ROVED ~ TRANY~ 9t 66 SCH $CH S'CH SCH $CH $CH $CH D I £'TR I BUT I ON CENTRAL FILE~ CHEVRON D & M EXTENSION EXF'LORATION EXXON MARATHON MOBIL PHILLIP~ PB WELL FILES' R & D BPX gTATE OF ALASKA TEXACO ARCO ALA~'KA, INC. F'.,O, BOX i ANCHORAGE, ALA~'KA 995i DATE:' 9-6-9t REFERENCE' ARCO DIRECTIONAL DAi'A qi-/O. DIRECTIONAL ~'LIRVEY JOB~843 ~1-/0¢ 5-24 8-t3-9~ MWD DIRrECTIONAL SURVEY JOB:~84"2 PLEASE ~IGN AND RETURN THE ATTACHED COPY AS' RECE:IPT OF RECEIVED BY _ HAVE A NICE DAY! $ONYA WALLACE ATO- t 529 APF'ROVEDt~ TRANI'~ 9 TELECO 'i'EI_ECO DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL F'HILL IF'~' $ F'B WELL FILES (2 COPIES) R & D ~T BPX ~'"' STATE OF ALA~'KA TEXACO ARCO ALASKA, INC F'..O. BOX t00360 ANCHORAGE, ALASKA 99.55t DATE ' 8-'~6-9.. t REFERENCE' ARCO OPEN HOLE FINALS /2-30 2-30 2- e 5-24 ~5-24 8-t 9-9t SSTVD 8-t 9-9t BHCA-GR 8-t 9-9t DIF'L-GR 8- t 9-9 t CNL-GR 8--t 3-9t SSTVD 8-t $-9t BHCA-GR 8-t 3-9t DIF'L-GR 8- t 3-9 t CNL-GR RUN t , 2' RUN t , .5' RUN t, 5:' RUN t , .5' RUN t, t'&2' RUN t, 2'&5' RUN RUN t, 2'&5' PLEASE SIGN AND RFTURN THE ATTACHED COPY AS' REC:EIF'T OF DATA, HAVE A NICE DAY! $ONYA WAr_LACE AT0-t.529 AI::'PROVED · '8~~'--' 'I'RANS~ 9t ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS Al'LAS DISTRIBUTION CENTRAL FILES CHEVRON D&M EXTENSION EXPLORATION EXXON MARATHON MOBIL ~ PHILLIPS PB WELL FILES R & D BPX STATE OF ALASKA TEXACO * 2' LOGS WILL BE DISTRIBUTED SHORTLY, TO: THRU: MEMORAh JUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Stol DATE: AUgUSt 15, 1991 Commissioner FILE NO: HH815-4 TELEPHONE NO: SUBJECT: BOP Test P.B.D. PBU DS5-24 Permit No. 91-105 Prudhoe 0il Pool FROM: Harold R. Hawkins Petroleum Inspector SundaV.Auau.st..:{, .1991: I witnessed the BOP test on Doyon rig 9 for P.B.D. PBU DS5-24. There were no failures. I filled out an ~C field report which is attached. In summary: The WP test on P.B.D., PBU DS5-24 was satisfactorily performed. Attachment. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 ? TELl 1 Teleco Oilfield S Inc. ~uu~m~ 6116 Nielson way i i Anchorage, AK 99518 (907) 562-2646 August 14, 1991 JOB #842 PRUDHOE BAY DRILLING WELL: DS 5-24 PRUDHOE BAY RIG: DOYON 9 Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to Prudhoe Bay Drilling. Teleco is committed to providing the highest quality MWD Service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Jonathan Field Operations Supervisor JGM/el Enclosures A S~NAT COMPANY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COI~IISSION BOP Test Report OPERATION: Drlg. ~ Wkvr~ Operator p/~m/~/'/4~ Location: Sec Dr lg contrc[r Location (general) Housekeeping (general) Reserve pi~ Vi sual Audio Trip tank J J Pit gauge Flow monitor Gas detectors /' J MUD SYSTEMS: BOPE STACK: Test Pressure Annular preventer Pipe rams Blind rams Choke line valves HCR valve Kill line valves Check valve ! Rig# Upper Kelly Lower Kelly Ball type Inside BOP Choke manifold Number valves /: Number flanges ~ Adjustable chokes ~ Z//~ /~/r~? Hydraulically operated choke / TEST: Initial ~/ Weekly,~ Other Representative ~/~'W° /["~'~ Permit # 9/'/¢~,~ /~ Casing set ~ F~ /~ ft ~ ep' ACCUMULATOR SYSTEM: Full charge pre~aure ~~ p~tg Press after closure /~ p~ig Pump inor clos pre~ 200 p~tg ~ mtn Full charge pre88 attained ~ mtn Remo~e~R~ Blind switch cove~ KELLY AND FLOOR SAFETY VALVES= Tes~ pressure Tes~ p~essu~e .~ Tes~ p~essu~e Tes~ p~essure Tes~ p~essure TEST RESULTS: Failures ./j/~//A& Test time ~ hfs Repair or replacement of failed equipment to be made within - days. Notify the Inspector, and follow with written/FAXed verification to Commission office. Remarks: Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 07/08/91) WITNESS TO: THRU: FROM: MEMORANoUM State .,of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION LOnnie C. Smith. S' Commissioner /'---"'~ DATE: August 14, 1991 FILE NO: HH814-1 TELEPHONE NO: SUBJECT: Diverter test/ walk-thru inspection P.B.D. PBU DS5-24 Permit No. 91-105 Prudhoe 0il Pool Harold R. HaWkins Petroleum / Wednesda[~,3ul~,_31. 1991: I ~itnessed a diverter test and made a walk-thru inspection for Prudhoe Bay Drilling (PBD), PBU at DS5-24 on Doyon 9 rig. The dlverter was up to specifications and the walk-thru inspection went o.k. with no infractions that I had found. I filled out a RIG/BOPE inspection report which is attached. In summary: The diverter test and walk-thru inspection was satisfactorily performed with no infractions found for Prudhoe Bay Drilling on DS 5-24. Attachment. 02-001A (Rev. 6,'89) 20/ll/MEMO1.PM3 OPERATION: Drlg / Comp1__ Wkvr UIC Operator /0/~,~/)4~4c ~'~)~/ Z)RJ~ Permit ~ ~- Drlg contr ~/ Rig~ Location (gert'l) ~ Well sign I N COMPL I ANCE: ~ no n/a A. DIVERTER 1. (~ (~ .( ) ~n~'~ngth 2 (~/ ( ) ( ) line conn& anchored 3 (~ ( ) (~f~rc~t~d&d~,w~nd 4 (~ ( ) (~ 90° ~rgeted turns 5 (~ ( ) ( ) vlvs: auto & simultaneous () p c -o f 7.(~) ' ( )( ) condition B. BOP STACK 8. ( ) ( ) (~ wellhead fl g wkg press 9. ( ) ( ) (~ stack wkg press 10. (~ ( ) ( ) annular preventer 11. ( ) ( ) (~ Pipe rams 12. ( ) ( ) (~' blind ~ams 13. ( ) ( ) (~ stack anchored, 44. 14. (~) ( ) (~ chke~kill line sz 45. 15 (~ ( ) ~ 90o~,~u~s targeted (chke & 16. ( ) ( ) (d HCR vl~s (chke & kill) 47. 17. ( ) ( ) (~ manU~,vlvs (chke'& kill) 18. (~ ( ) ( ) Conn~otions (flgd, whd, clmpd) . ~9. (-~ ( ) ( ) ,~] spoo~ 20. (~ ( ) ( ) ' f:i°~:n~'pple 21. (~ ( ) ( ) 22 (~ ( ) ( ) do~bi lines fire' protected C. CLOSING uNITS 23. (~ ( ) ( ) wkg press 24. (~ ( ) ( ) flUid..l~evel . 25. (~) ( ) (.) Oprtg press.' , 26. (~ ( ) ( ) press gauges 27. (~ ( ) ( ) suffiCient vlvs 28. (~ ( ) .( ) .regulator bypass 29. (~ ( ) ( ) 4-Way. vl.vs (actuators) 30. (~ (') ( ) 'blind handle cover 31.' (~ ( ) (). driller control panel 32. '('~ ( ) ( ) remot~ control panel STATE OF ALASKA J~n~iASKA 01L AND GAS CONSERVAT ION COMM I SS ION Rig/BOPE Inspection Report DATE: 7/~ t/Y~ Representative ~/~y/ /~fy~/~)~ We11 name ~ ~-~ ~ / Representative ~~ ~E~ ~ IN COMPLIANCE; yes/ no n/~ 33. (?~)' (--~ ( i. firewall 34. (/~ ( ) ( ) nitrogen power source (back-up) 35. (~ ( ) ( ) condition (leaks, hoses, etc) D. MUD SYSTEM 36. (1~ ( ) ( ) pit level floats Installed 37. ( I~' ( ) ( ) flow rate sensors 38. (~)~ ( ) ( ) mud gas separator ', 39. (~)/ ( ) ( ) degasser 40. (~ ( ) ( ) separator bypass 41. (~ ( ) ( ) gas sensor 42. (>~' ( ) ( ) chke I n conn 43. (~/ ( ) ( ) trip tank E. RIG FLOOR '~ ( ) ( ) kelly cocks (upper,lower, IBOP) ( ) ( ) floor vlvs (dart vlv, ball vlv) ( ) ( ) kelly & floor vlv wrenches ( ) ( ) driller's console (flow monitor, flow rate indicator, pit level indicators, gauges) 48. (//) ( ) ( ) kill sheet up-to-date 49. (~) ( ) ( ) gas ~etectton monitors (H S & methane) 50. (/'0. ( ) ( ) hydr chke panel 51. (~ ( ) ( ) chke manifold F. MISC EQUIPMENT 52. (vg// ( ) ( ) flare/vent line 53. (~ ( ) ( ) 90° turns targeted (dwn strm choke 1ns) 54. (~ ( ) ( ) reserve pit tankage 55.'(~' ( ) ( ) personnel protective equip avail 56. (~// ( ) ( ) all dr1 site suprvs trained for procedures 57. (~ ( ) ( ) H2S probes 58. (~ ( ) ( ) rig housekeeping RECORDS: Date of last BOP inspection: ~// Date of last BOP test: 7/~/ Resul ting non-compl i ance~ Non-compliances not corrected & why: . Date corrections will be completed: BOP test & results properly entered on daily record?/~ Kill sheet current? , . WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1991 Michael Zanghi ARCO Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 5-24 ARCO Alaska, Inc. Permit No. 91-105 Sur. Loc. 2203'FSL, l194'FWL, Sec, 32, TllN, R15E, UM Btmhole Loc. 2436'FNL, 598'FWL, Sec. 33, TllN, R15E, UM Dear Mr. Zanghi: 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. The Commission will advise you of.those BOPE tests that it wishes to witness. David W. JohnSton, Chairman Alaska Oi~D~~' Ga~ Conservation Commission 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 ~"'"'~ ALASKAblL AND GAS CONSERVATION coMMIsSION ' PERMIT TO DRILL 20 AAC 25.005 1a. Type of work Drill [] RedriliBIlb. Type of well. Exploratoryr-I Stratigraphic TestD Development OilE! Re-Entry [] DeepenI"!I Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, inc. KBE = 70'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28325 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 ^^c 25.025) 2203' FSL, 1194' FWL, SEC. 32, T11N, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2450' FNI_, 4780' FEL, SEC. 33, T11N, R15E DS 5-24 U.630610 At total depth 9. Approximate spud date Amount 2436' FNL, 598' FWL, SEC. 33, T11N, R15E July 28, 1991 $200,000. O0 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(~Oand'rVD) property line ADL 28326 ~ 598'feet DS 5.27 ~ 100Y59' feet 2560 10326'MD/9054'TVD~eet 16. To be completed for deviated wells 17. Anticipated pressure Kickoff depth 5oofeet Maximum hole angle = ~ o Maximum surface 2770pslg At total depth (TVD) ~650pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 30" 20" 91.5~ H-40 WELD 80' 35' 35' 115' 115' 2000# POLESET 13-1/2" 10-3/4" 45.5# J-55 BTC 3821' 35' 35' 3856' 3500' 1260 sx CSIII & 350 sx "G" 9-7/8" 7-5/8" 29.7# L-80 BTC/MOD 9579' 35' 35' 9614' 8445' 265 sx "G" 6-3/4" 5-1/2" 17# CR13 FL4S" 1012' 9314' 8187' 10326' 9054' 95 sx"G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Production .. · Perforation depth: measured '.,!.. Anchoral~ true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l"~ Drilling fluid progra.m [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify, th/~t the/oregoing/is true and correct to the best of my knowledge Si,ned ?~ h( ("-~' ~'"~ (, Title ARCO Area Dr#ling Engineer Date'~-Z.~ ~-~::;~/ C~Prf~um- Commission Use Only Permit Number lAP ber IApproval date. JSee cover letter Conditions of approval Samples req,uir, ed [] Yes ~'NO Mud Icg required. [] Hydrogen sulfide measures [] Yes ~ No Oirectiona_~l survey requ,recl ~ Yes Yl-lS' NO Requir~ure][~3.~;~E-~2M; 1-13M; ~.]~LSM; F'I10M; I-i15M; Approve __ Commissioner tne commission_ .Da!e~JzzJt/. Form 10-401 Rev. 12-1~ Submit DS5-24 Operations Summary 1. MIRU drilling rig. NU diverter and function test same. 2. Spud well and drill a 13 1/2" hole to 500'tvd/'md. . At 500'tvd/md (KOP), build angle at 2.5 degrees/100'md in the N 82' 12" E direction to 30 degrees at 1674'tvd/1732'md (EEC). Hold angle at 30 degrees to 3500'tvd/3856'md (10 3/4" casing set point). 4. Set 10 3/4" casing and cement same. Test casing to 2500 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. . Pick up 9 7/8" bit and BHA and drill 10' of new hole and perform leakoff test. Continue drilling 9 7/8" hole in the N 82' 12" E direction to 8445'tvd/9614'md (7 5/8" set point) while maintaining a 30 degree angle. 5. Set 7 5/8" casing and cement same. 6. PU 6 3/4" BHA and test casing to 3000 psi. Drill 10' of 6 3/4" hole and perform formation integrity test to12.5 ppg EMW. 7. Continue drilling 6 3/4" hole in the N 82' 12" E direction to 9054'tvd/10326'md while maintaining a 30 degree angle hole. 8. Run wireline logs as programmed. 9. Set 5 1/2" liner and cement same. 10. Clean out liner and test liner to 3000 psi for 30 minutes.~ ~,,EIv. F,~D 11. Circulate well to brine and freeze protect with diesel. ~,~t,~.~,...2 ~99! 12. Release drilling rig. Run cased hole logs 7 days after rig ,,,~,.~ ~h0ra~ "' ~' release. 13. MI and RU completion rig. Run 4 1/2" x 3 1/2" tubing and packer assembly. NU tree and test to 3000 psi. Release cA,rp, p,~[k)lr~jrig.~ 14. Rig up wireline unit and perforate well. ,,!~i 2,':. 1.991 DS5-24 Operations Summary-continued NOTES: a. Excess non-hazardous fluids developed from well operations and as necessary to control fluid level in reserve pit will be pumped down the 10 3/4" x 7 5/8" annulus. The annulus will be left with a non-freezing fluid during any extended period. The annulus will be sealed with 300 sxs of cement followed by Arctic Pack. b. Wells within 200' 'of the proposed well are: DS5-4 DS5-27 61' at 500'tvd/md 59' at 100'tvd/md ¢. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. d. The maximum surface pressure is based upon the BHP and a full column of gas to TD (0.10 psi/ft). e. Based upon previous logs obtained from DS5 wells, no productive zones are anticipated above 4000'tvd. f. No hazardous levels of H2S are anticipated in this well. ......... 1 i i I i i i i [ i i i i ! ri I I I I ........... ' ' ' ' '/~N%,A ' ~ ' ~ ' ' 0 RI(lq I~_I.1TVATION 70' 20" CASING TVE :115 TMD=I '~o~ ~:~. AR{ ~O ~A S~, ~C. ,.o DS5-.24 ~',., 2 IS'0 ~.s SHL: U 1 IN o THL: U 11N 15~ 33 2450' fi~L 4780' ~~22~.s BHL: U 11N ~ ~o :16~4 T~1~32 D~ :a2a N 82 12' ~ 2~ 3~ &s~G ~35~ ~D:3856 D~1411 4~ ~5~ ~D :5021 ~ K15 ~0 ~5335 5~ 6~ K5 ~:~780 T~=: 839 D~:3~ S~BL~ ~83~) ~9550 DE~3~ 7 TOP St tDL~O~ ~ 55 T~~ D~ GOC ~ :~40 T~S7 DE1 ~S36 T~G~ ~8887 T~=10131 DS~6~ 1~ ................................................................ 0 1~ 2~ 3~ 4~ 5~ ~RTICAL SE~ION ARCO ALASKA, INC. DS5-24 N 82 12' E E - W COORDINATES -1000 0 1000 2000 3000 4000 5000 6000 ~ i , i i i i i ~ i i i i i i I i ~ i i i i i ......... , , , , , , , , , , , , , , ~ , , , , , , , ~ ........ ds i-32 8810 05 -0.~6~ ~ , 05-0~ .~;~o ~~s, 7: 15 -- ---.2-- ~ ~ 5oa3. 52 8201 ~88'~ 4$1 7 7267 ~7~56____ ~ ~ N~61'' ........ ~'~-~7 .~ ,~ ..... ~-m~¢7~ ................ 4000 4000 3000 3000 2000 :~000 1000 1000 < 05~)8 ro o o -lOOO .lOOO -2000 -2000 05 -06 -3000 -1000 -3000 0 1000 2000 3000 4000 5000 6000 Mud Program for Slimhole WeII-PBU-EOA Date Well Field Type Depth, tvd 7/1g/91 DS5-24 Prudhoe Bay Slimhole Density, ppg PV, cp Spud 8.8 300 to to to 10 3/4" csg point 9.2 100 SET 10 3/4" CASING Depth, tvd 10 3/4" csg pt to 5000' 5000' to K-10 Densi~, ppg PV, cp 8.8 1 0 to to 10.6 15 YP, #/ft Int Gel 10 min Gel FL cc/30min 4 0 30+ 50+ 2 5 to to to to 70 - - - YP, #/ft 6 to 10 10.6 10 6 to to to 10.7 15 10 K-1 0 10.7 1 0 6 to to to to 7 5/8" csg pt 10.7 1 5 1 0 YP, #/ft SET 7 518" CASING Depth, tvd 7 5/8" csg pt to SET 5 1/2" Liner Densi~, ppg PV, cp 8.8 10 6 to to to 9.1 15 1 0 Int Gel 10 rain Gel FL cc/30min Oil, % 0 to Oil, % Solids, % 2 to 6 Solids, % 2 4 25 0 2 to to to to to 4 10 10 0 6 2 4 10 0 2 to to to to to 4 10 15 0 6 2 4 6 0 4 to to to to to 4 10 10 0 9 Oil, % 0 tO 0 Int Gel 10 min Gel FL cc/30min 2 1 4 to to to 4 10 8 Solids, % 4 to 6 Mud Type GeI-Benex Spud Mud GeI-Benex Spud Mud Mud Type Lightly Treated Polymer Lightly Treated Polymer Lightly Treated Polymer Lightly Treated Polymer Lightly Treated Polymer Lightly Treated Polymer Mud Type Lightly Treated Polymer Ughtly Treated Polymer 7/19/91 -DOYON DRILLING RIG ~'~ 9 MUD SYSTEM SANDTRAP CENTRIFUGE f VACUUM ~ 83 BBLS , , DESILTER PIT 97 BBLS 97 BBLS PILL PIT 36 BBLS 36 BBLS , , SHAKER DESANDER SHAKER MUD CT.~.~NER SUCTION PIT 448 RBLS MIX PIT 122 BBLS psi BOP STAC,' DIAGRAM AN' ~ NULARtl B ' IPE RAMS IND RAMS I ~ DRILLING SPOOL BRADEN~ HEAD ~ ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVIOR TO THE PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT THE ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSi DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH THE CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRES- SURE. 1 5/8" STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING FLUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK .THE RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN THE TEST PLUG ON DRILL PIPE AND SEAT IN WELL- HEAD. 3. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4. FUNCTION TEST CHOKES. 5. IN EACH TEST, FIRST HOLD 250 PSI FOR 3 MINUTES PRIOR TO THE HIGH PPRERSSURE TEST. 6. INCREASE PRESSURE ON ANNULAR TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF THE CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS. CLOSE BOTTOM PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 10. TEST REMAINING MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF THE VALVE AND ZERO PRESSURE DOWNSTREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM PIPE RAMS. 12. BACK OFF RUNNING JOINT AND POH. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. 13. BLEED OFF ALL PRESSURE. OPEN BLIND RAMS. FILL MANIFOLD AND LINES WITH NON-FREEZING FLUID. SET ALL VALVES IN THE DRILLING POSITION. 14. TEST STANDPIPE VALVES TO 5000 PSI. 15. CHECK DEGASSER OPERATION. 16. RECORD BOP TEST INFORMATION ON THE BOP TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 17. PERFORM COMPLETE BOP TEST WEEKLY AND FUNCTION TEST DAILY. DOYON 9 DIVERTER SYSTEM ARCO ALASKA, INC. FILLAJP UNE RISER FLOWUNE 20" :20(X) PSI DIVERTER BALL VALVE I [, I 1(7' BALL VALVE I i I ! CONDUCTOR I NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS THIS IS A VARIANCE FROM 20AAC25.035. ; ; o WELL: wE~r¢[IV,~D / ~i~a ~l .~ Gas uon~ .... · .............. -1- ............... -~l'r~~~-~' ..... DIVERTER LINES DISCHARGE 100 FT. FROM RIG IGNITION SOURCE. ALL TURNS ARE TARGETED TEE& ITEM, (1) .Fee (2) Loc · '"* CHECK LIST FOR NEW WELL PERMITS ;"* APPROVE D~TE / [2 thru [23 thru ~28]' ' (6) Other [29 thFu ~1~ (6) Addl Company le 2. 3. 4 5 6 7 8 9. 10. 11. 12. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Is pemit fee attached ............................................... Is well to be located in a defined pool ................ , .......... Is'well located proper distance from property line. 'p~i '''i'i''] is' well located proper distance from other wells ....... Is sufficient undedicated acreage available in this Is well to be deviated & is wellbore plat included,. Is operator the only affected party .................. Can permit be approved before 15-day wait ........... Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed ........................ Is lease nLmber appropriate ........................ Does well have a unique name ~ ~'~er~ ..... Is conductor string provided ....................................... Will surface casing protect ai; zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Wi]] all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wel]bore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to__~psig Does choke manifold c°~Ply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY S 5TRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are'seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... ~ Additional requirements ............................................. Lease & Well _ , £ eeeeeeeeeee® NO REMARKS 0 "rz ~0 geology' DWJ~ RP~ eng i neer i ng' MTM---~ LCS rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' 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 APPENDIXi ,. No special'effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * , .............................. ~U~ 0 6 ~99B , ............................ , .............................. COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D. S . 5-24 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292220400 REFERENCE NO : 98389 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/07/30 ORIGIN : FLIC REEL NAME : 98389 CONTINUATION # : PREVIOUS REEL : COF~ENT : ARCO ALASKA INC, D.S. 5-24, PRUDHOE BAY, 50-029-22204-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/07/30 ORIGIN : FLIC TAPE NAME : 98389 CONTINUATION # : 1 PREVIOUS TAPE : CO~fENT : ARCO ALASKA INC, D.S. 5-24, PRUDHOE BAY, 50-029-22204-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D. S . 5-24 API NUMBER: 500292220400 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 30-JUL-98 JOB NUMBER: 98389 LOGGING ENGINEER: BAILEY OPERATOR WITNESS: S.SCHUDEL SURFACE LOCATION SECTION: 32 TOWNSHIP: liN RANGE: 15E FNL: FSL: 2203 FEL: FWL: 1194 ELEVATION(FT FROM MSL O) KELLY BUSHING: 70.00 DERRICK FLOOR: 69.00 GROUND LEVEL: 35.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 6. 750 6. 875 2ND STRING 4 . 900 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 13-AUG-91 LOGGING COMPANY: WESTERN ATLAS .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88888.5 88888.5 10090.5 10091.0 10091.0 10079.0 10079.0 10079.0 10069.5 10070.0 10070.0 10062.0 10062.0 10062.0 10043.0 10043.0 10032.0 10032.0 10032.0 10027.0 10027.5 10027.5 10011.0 10011.5 10011.5 9999.5 9999.5 9999.5 9990.5 9991.5 9991.5 9983.0 9983.0 9983.0 9973.0 9973.5 9973.5 9963.5 9962.0 9962.0 9948.5 9949.0 9949.0 9932.5 9933.5 9933.5 9920.0 9921.0 9921.0 9910.5 9911.5 9911.5 9888.0 9889.5 9889.5 9812.5 9814.5 9814.5 9802.5 9804.0 9804.0 9776.5 9778.5 9778.5 9774.0 9775.5 9775.5 9761.0 9763.0 9763.0 9755.0 9757.0 9757.0 9751.0 9752.5 9752.5 9747.0 9749.0 9749.0 9725.0 9726.5 9726.5 9714.0 9715.5 9715.5 9695.0 9697.0 9697.0 9685.5 9687.5 9687.5 9675.5 9676.5 9674.5 9676.5 9653.0 9654.5 9654.5 9647.5 9649.5 9649.5 9636.0 9637.5 9635.5 9637.5 9620.0 9621.5 9619.5 9621.5 9610.0 9611.5 9611.5 9593.5 9597.5 9591 . 5 9593.0 9593 . 0 100.0 101.5 101 . 5 $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL~1998 15:52 CONTAINED HEREIN IS THE TDTP DATA ACQUIRED ON ARCO ALASKA, INC. WELL D.S. 5-24 ON 16-MAY-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT TDTP PASS #1 GRCH TO THE BASELINE GAM~A RAY PROVIDED BY THE CLIENT (GR.BCS) ; AND TDTP PASS #1 SIGM TO GR.BCS. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMmArY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10098.0 9585.0 TDTP 10123.0 9585.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. REMARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTH CORRECTED DATA FOR TDTP PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 .............................. ** SET TYPE - CHAN ** ....................................................................................... NAIV~ 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 FT 1161099 O0 000 O0 0 1 1 1 4 68 SIGMTDTP CU 1161099 O0 000 O0 0 1 1 1 4 68 TPHI TDTP PU-S 1161099 O0 000 O0 0 1 1 1 4 68 SBHF TDTP CU 1161099 O0 000 O0 0 1 1 1 4 68 SBHN TDTP CU 1161099 O0 000 O0 0 1 1 1 4 68 SIGC TDTP CU 1161099 O0 000 O0 0 1 1 1 4 68 SIBH TDTP CU 1161099 O0 000 O0 0 1 1 1 4 68 TRAT TDTP 1161099 O0 000 O0 0 1 1 1 4 68 SDSI TDTP CU 1161099 O0 000 O0 0 1 1 1 4 68 BACK TDTP CPS 1161099 O0 000 O0 0 1 1 1 4 68 FBAC TDTP CPS 1161099 O0 000 O0 0 1 1 1 4 68 TCAN TDTP CPS 1161099 O0 000 O0 0 1 1 1 4 68 TCAF TDTP CPS 1161099 O0 000 O0 0 1 1 1 4 68 TCND TDTP CPS 1161099 O0 000 O0 0 1 1 1 4 68 TCFD TDTP CPS 1161099 O0 000 O0 0 1 1 1 4 68 TSCN TDTP CPS 1161099 O0 000 O0 0 1 1 1 4 68 TSCF TDTP CPS 1161099 O0 000 O0 0 1 1 1 4 68 INND TDTP CPS 1161099 O0 000 O0 0 1 1 1 4 68 INFD TDTP CPS 1161099 O0 000 O0 0 1 1 1 4 68 GRCH TDTP GAPI 1161099 O0 000 O0 0 1 1 1 4 68 TENS TDTP LB 1161099 O0 000 O0 0 1 1 1 4 68 CCL TDTP V 1161099 O0 000 O0 0 1 1 i 4 68 GR BCS GAPI 1161099 O0 000 O0 0 1 1 I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: ** DATA ** DEPT. 10235.000 SIGM. TDTP -999.250 TPHI. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAF. TDTP -999.250 TCND.TDTP -999.250 TCFD. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP TENS.TDTP -999.250 CCL. TDTP -999.250 GR.BCS DEPT. 9578.000 SIGM. TDTP -999.250 TPHI.TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAF. TDTP -999.250 TCND.TDTP -999.250 TCFD. TDTP TSCF. TDTP -999.250 INND.TDTP -999.250 INFD. TDTP TENS. TDTP -999.250 CCL.TDTP -999.250 GR.BCS -999.250 SBHF. TDTP -999.250 TRAT. TDTP -999.250 TCAN. TDTP -999.250 TSCN. TDTP -999.250 GRCH. TDTP 135.622 -999.250 SBHF. TDTP -999.250 TRAT. TDTP -999 . 250 TCAN. TDTP -999. 250 TSCN. TDTP -999. 250 GRCH. TDTP 73.951 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUF1BER : 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER: 2 DEPTH INC~: 0.5000 FILE SU~1MARY LDWG TOOL CODE START DEPTH ......................... GRCH 10098.0 TDTP 10123.0 STOP DEPTH 9585.0 9585.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.O 10120.5 10094.0 10085.0 10076.5 10058.0 10054 0 10049 5 10037 0 10027 5 10027 0 10020 0 10011 5 10005 0 10002 5 9994 0 9983 5 9973 5 9969 5 9963 0 9959 5 9946.5 9942 0 9935 5 9920 5 9888 0 9887 5 9860 0 9857 0 9846. O 9812 0 9802 5 9802 0 9783 0 9775 5 9772 5 9761 0 9752 5 9752 0 9747 0 9738 5 9729 0 9726.0 9720.0 9713.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88888.5 88889.0 10121.5 10095.0 10085.5 10058.5 10054.5 10037.0 10027.5 10012.0 9984.0 9974.0 9947.0 9890.0 9804.5 9778.5 9755.0 9749.5 10077.0 10050.0 10028.0 10020.5 10006.0 10002.5 9994.5 9970.5 9961.5 9959.0 9943.0 9937.0 9922.0 9889.5 9862.0 9859.5 9848.0 9815.0 9804.5 9785.5 9775.0 9763.5 9754.5 9740.5 9731.5 9729.0 9722.0 9715.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 9713.0 9716.0 9695.0 9697.5 9698.0 9685.0 9688.0 9674.5 9676.5 9674.0 9677.0 9647.0 9650.0 9649.5 9636.0 9638.0 9630.5 9633.5 9619.5 9621.5 9609.5 9611.5 9601.5 9605.0 9595.0 9597.0 9593.0 9598.0 9590.0 9593.0 9589.0 9591.5 9591.5 100.0 102.5 102.5 REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR TDTP PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT TDTP PASS #2 GRCH TO TDTP PASS #1 GRCH; AND TDTP PASS #2 SIGM TO TDTP PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ~ ~ 30-GUL-1998 15:52 PAGE~ 8 LIS Tape Verification Listing Schlumberger Alaska Computing Center ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELE~ CODE (HEX) 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 DEPT FT SIGMTDTP CU 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 SBHNTDTP CU 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 TCANTDTP CPS 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 TSCNTDTP CPS 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 TSCFTDTP CPS 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1161099 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10124.000 SIGM. TDTP 14.591 TPHI. TDTP 23.857 SBHF. TDTP SBHN. TDTP 44.744 SIGC. TDTP 1.509 SIBH. TDTP 53.325 TRAT. TDTP SDSI. TDTP 0.326 BACK. TDTP 176.652 FBAC. TDTP 50.995 TCAN. TDTP TCAF. TDTP 17452.496 TCND. TDTP 28338.516 TCFD. TDTP 9452.010 TSCN. TDTP TSCF. TDTP 3468.038 INND. TDTP 1840.919 INFD. TDTP 438.076 GRCH. TDTP TENS. TDTP 1323.000 CCL. TDTP 0.000 37.589 1.780 41851.969 8316.531 -999.250 DEPT. 9587.500 SIGM. TDTP 23.605 TPHI.TDTP 35.805 SBHF. TDTP 50.735 SBHN. TDTP 57.972 SIGC. TDTP 0.904 SIBH. TDTP 91.815 TRAT. TDTP 1.733 SDSI. TDTP 0.882 BACK. TDTP 205.761 FBAC. TDTP 53.815 TCAN. TDTP 14523.229 TCAF. TDTP 5362.107 TCND. TDTP 17880.891 TCFD. TDTP 5131.921 TSCN. TDTP 2994.074 TSCF. TDTP 1105.439 INND. TDTP 2098.241 INFD. TDTP 427.901 GRCH. TDTP 78.553 TENS. TDTP 1319.000 CCL.TDTP 0.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 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 NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~M~ARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10098.0 9586.0 TDTP 10123.0 9586.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFiBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP ............................ 88888.0 88889.5 88889.0 10120.5 10121.5 10093.0 10094.5 10090.5 10091.5 10090.0 10090.5 10084.5 10085.5 10079.0 10079.5 10069.0 10070.0 10058.0 10058.5 10049.5 10050.0 10042.0 10042.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 10 10027.0 10027.5 10020.0 10021.0 10010.5 10011.5 10005.5 10006.0 10006.0 9986.0 9987.0 9983.0 9984.0 9973.0 9974.0 9972.0 9973.0 9969.5 9970.5 9967.5 9967.5 9962.0 9961.5 9954.0 9955.0 9948.0 9949.5 9942.0 9943.5 9932.5 9933.5 9934.0 9920.0 9921.5 9888.0 9889.5 9845.5 9848.5 9825.0 9827.5 9802.0 9804.5 9804.5 9773.0 9775.5 9739.0 9742.0 9719.5 9722.0 9712.5 9715.5 9694.5 9697.5 9697.5 9685.0 9687.5 9674.0 9677.5 9663.5 9666.0 9647.0 9649.5 9646.5 9649.5 9635.0 9638.0 9619.0 9622.0 9609.5 9611.5 9605.5 9608.5 9601.5 9605.0 9597.0 9597.5 9593.0 9598.0 9591.0 9593.5 9589.0 9591.5 9591.5 100.0 102.5 102.5 $ R~KS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR TDTP PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT TDTP PASS #3 GRCH TO TDTP PASS #1 GRCH; AND TDTP PASS #3 SIGM TO TDTP PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** 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 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1161099 O0 000 O0 0 3 1 1 4 68 0000000000 ....................................................................................... ~ 30-JUL-1998 15:52 PAGE: 12 LIS Tape Verification Listing Schlumberger Alaska Computing Center ** DATA ** DEPT. 10124.000 SIGM. TDTP SBHN. TDTP 44.771 SIGC. TDTP SDSI.TDTP 0.343 BACK. TDTP TCAF. TDTP 18418.098 TCND. TDTP TSCF. TDTP 3609.328 INND. TDTP TENS.TDTP 1343.000 CCL. TDTP DEPT. 9588.500 SIGM. TDTP SBHN. TDTP 60.609 SIGC. TDTP SDSI.TDTP 0.609 BACK. TDTP TCAF. TDTP 8193.338 TCND. TDTP TSCF. TDTP 1599.009 INND. TDTP TENS. TDTP 1306.000 CCL.TDTP 15. 467 TPHI. TDTP 23.230 SBHF. TDTP 36. 452 1.121 SIBH. TDTP 53 . 251 TRAT. TDTP 1 . 729 248. 786 FBAC. TDTP 68. 347 TCAN. TDTP 42437.133 28361. 480 TCFD. TDTP 9573. 670 TSCN. TDTP 8316. 252 2055. 680 INFD. TDTP 447. 621 GRCH. TDTP -999. 250 -0. 032 20.204 TPHI.TDTP 30.903 SBHF. TDTP 54.232 0.842 SIBH. TDTP 98.928 TRAT. TDTP 1.714 226.623 FBAC. TDTP 63.383 TCAN. TDTP 20581.867 19497.340 TCFD. TDTP 6040.483 TSCN. TDTP 4016.751 1989.855 INFD. TDTP 400.984 GRCH. TDTP 71.009 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS TDTP 1, 2, 3, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 13 REFIARKS: THE ARITH~ETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 80 4 66 1 5 66 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 ** N~rIE 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 FT 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN PNAV CU 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN PNAV CPS 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF PNAV CPS 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 TCND PNAV CPS 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD PNAV CPS 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 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) INND PNAV CPS 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1161099 O0 000 O0 0 4 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 10123.500 SIGM. PNAV 16.068 TPHI.PNAV 24.799 SBHF. PNAV SBHN. PNAV 45.125 SIGC. PNAV 1.110 SIBH. PNAV 54.420 TRAT. PNAV SDSI.PNAV 0.370 BACK. TDTP 53.569 FBAC. TDTP 17.176 TCAN. PNAV TCAF. PNAV 16771.340 TCND.PNAV 27894.313 TCFD.PNAV 9266.309 TSCN. PNAV TSCF. PNAV 3331.311 INND.PNAV 1962.485 INFD.PNAV 455.452 GRCH. TDTP 36.308 1.760 39885.148 7922.568 -999.250 DEPT. 9586.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 139.765 FBAC. TDTP 44.297 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND. PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND. PNAV -999.250 INFD. PNAV -999.250 GRCH. TDTP 71.885 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTgM~ER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file LIS Tape Verification Listing Schlumberger Alaska computing Center 30-JUL-1998 15:52 PAGE: 15 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... TDTP 10138.5 $ 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): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAM~A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL STOP DEPTH .......... 9572.5 16-MAY-98 8Cl -205 1726 16-MAY-98 10144.0 10133.0 9580.0 10127.0 1800.0 NO TOOL NUMBER ........... CGRS-A TDT- P 6. 750 CRUDE 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 16 FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): ~S: CORRELATED TO WA BHC DATED 13-AUG-91. ALL PASSES LOGGED AT 30 FT/MIN. PUMPED 200 BBLS CRUDE AT 5 BPM THEN SLOWED TO 1.5 BPM TO LOG. NOTICED DURING PASS #1 THAT THE INFD READ HIGHER THAN USUAL WHICH WOULD TEND TO INDICATE GAS NEAR THE WELLBORE. INCREASED THE INJECTION RATE TO 2.5 BPM FOR THE 2ND AND 3R PASS WHICH DID TEND TO SLIGHTLY REDUCE INFD. BUT EITHER INFD WAS HIGH DUE TO NEAR-WELLBORE GAS OR SOME OTHER DOWNHOLE PHENOMENON. THERE WAS NOT ENOUGH CRUDE AVAILABLE TO INCREASE INJECTION RATE ABOVE 2.5 BPM AND THERE WAS NOT AN OPTION FOR GETTING MORE CRUDE. WHILE INJECTING AT 2.5 BPM THE INDICATED INJECTION PRESSURE WAS ONLT 65 PSI. THIS WAS A HIGH GAS WELL WHICH WENT ON A VACUUM ONCE THE WELLBORE WAS FILLED WITH CRUDE. APPROXIMATE GOC=9202 '. GAS UNERRUNS APPEAR TO BE PRESENT FROM 9950' TO 9964' AND FROM 10004' TO 10046'. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 17 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PS1 CU 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNPS1 CU 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PS1 CU 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PS1 CU 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 · SDSI PS1 CU 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 BACK PS1 CPS 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 TCANPS1 CPS 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 TCAFPS1 CPS 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 TCND PS1 CPS 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD PS1 CPS 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PS1 CPS 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PS1 CPS 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 INND PS1 CPS 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 INFD PS1 CPS 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1161099 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10138 SBHN. PS1 -999 SDSI.PS1 -999 TCAF. PS1 -999 TSCF. PS1 -999 GR.PS1 0 DEPT. 9572. SBHN. PS1 48. SDSI. PS1 0. TCAF. PS1 9852. TSCF. PS1 1289 . GR. PS1 35. 500 SIGM. PS1 -999.250 TPHI.PS1 -999.250 SBHF. PS1 250 SIGC. PS1 -999.250 SIBH. PS1 -999.250 TRAT. PS1 250 BACK. PSI -999.250 FBAC. PS1 -999.250 TCAN. PS1 250 TCND.PS1 -999.250 TCFD.PS1 -999.250 TSCN. PS1 250 INND.PS1 -999.250 INFD. PS1 -999.250 TENS.PSi 000 CCL.PS1 -0.048 000 SIGM. PS1 26.330 TPHI.PS1 42.890 SBHF. PS1 483 SIGC. PS1 0.775 SIBH. PS1 67.153 TRAT. PS1 763 BACK. PSi 142.241 FBAC. PS1 48.292 TCAN. PS1 238 TCND. PS1 19836.453 TCFD. PS1 5593.941 TSCN. PS1 465 INND.PS1 1992.905 INFD. PS1 420.210 TENS. PSi 369 CCL.PS1 -999.250 -999.250 -999.250 -999.250 -999.250 898.000 40.454 1.878 30256.402 3791.286 1274.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 18 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE lVTgFI~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFZBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMF~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 10144.0 9569.5 TDTP $ LOG HEADER DATA DATE LOGGED: 16-MAY-98 SOFTWARE VERSION: 8C1-205 TIME LOGGER ON BOTTOM: 1726 16-MAY-98 TD DRILLER (FT) : 10144.0 TD LOGGER (FT) : 10133.0 TOP LOG INTERVAL (FT) : 9580.0 BOTTOM LOG INTERVAL (FT) : 10127.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GA~WZA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER ........... CGRS-A TDT-P 6. 750 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 19 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) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO WA BHC DATED 13-AUG-91. ALL PASSES LOGGED AT 30 FT/MIN. PUMPED 200 BBLS CRUDE AT 5 BPM THEN SLOWED TO 1.5 BPM TO LOG. NOTICED DURING PASS #1 THAT THE INFD READ HIGHER THAN USUAL WHICH WOULD TEND TO INDICATE GAS NEAR THE WELLBORE. INCREASED THE INJECTION RATE TO 2.5 BPM FOR THE 2ND AND 3R PASS WHICH DID TEND TO SLIGHTLY REDUCE INFD. BUT EITHER INFD WAS HIGH DUE TO NEAR-WELLBORE GAS OR SOME OTHER DOWNHOLE PHENOMENON. THERE WAS NOT ENOUGH CRUDE AVAILABLE TO INCREASE INJECTION RATE ABOVE 2.5 BPM AND THERE WAS NOT AN OPTION FOR GETTING MORE CRUDE. WHILE INJECTING AT 2.5 BPM THE INDICATED INJECTION PRESSURE WAS ONLT 65 PSI. THIS WAS A HIGH GAS WELL WHICH WENT ON A VACUUM ONCE THE WELLBORE WAS FILLED WITH CRUDE. APPROXIMATE GOC=9202 '. GAS UNERRUNS APPEAR TO BE PRESENT FROM 9950' TO 9964' AND FROM 10004' TO 10046'. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 2O ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NglVlE SERV ONIT SERVICE API API API API FILE NUMB Nr.~B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELM CODE (HEX) DEPT FT 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNPS2 CU 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS2 CPS 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PS2 CPS 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 TCND PS2 CPS 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PS2 CPS 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS2 CPS 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 INNDPS2 CPS 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS2 CPS 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1161099 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 21 ** DATA ** DEPT. 10144.000 SIGM. PS2 SBHN. PS2 -999.250 SIGC. PS2 SDSI.PS2 -999.250 BACK. PS2 TCAF. PS2 -999.250 TCND. PS2 TSCF. PS2 -999.250 INND. PS2 GR.PS2 52.647 CCL.PS2 DEPT. 9569.000 SIGM. PS2 SBHN. PS2 50.147 SIGC. PS2 SDSI.PS2 0.915 BACK. PS2 TCAF. PS2 6564.510 TCND. PS2 TSCF. PS2 1357.564 INND. PS2 GR.PS2 45.224 CCL.PS2 -999.250 TPHI.PS2 -999.250 SIBH. PS2 -999.250 FBAC.PS2 -999.250 TCFD.PS2 -999.250 INFD.PS2 0.057 24.085 TPHI.PS2 1.634 SIBH. PS2 201.506 FBAC. PS2 19871.840 TCFD.PS2 2030.903 INFD.PS2 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 35. 025 71. 678 53. 462 5808. 711 405. 901 SBHF. PS2 TRAT. PS2 TCAN. PS2 TSCN. PS2 TENS. PS2 SBHF. PS2 TRAT. PS2 TCAN. PS2 TSCN. PS2 TENS. PS2 -999.250 -999.250 -999.250 -999.250 982.000 38. 537 1. 740 17618. 344 3643. 538 1316. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREFiENT: O. 5000 FILE SU~qARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... TDTP 10150.0 9574.5 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 22 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): 16-MAY-98 8Cl -205 1726 16-MAY-98 10144.0 10133.0 9580.0 10127.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAF~A RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CGRS-A TDT- P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6. 750 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (F~: BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO WA BHC DATED 13-AUG-91. ALL PASSES LOGGED AT 30 FT/MIN. LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 23 PUMPED 200 BBLS CRUDE AT 5 BPM THEN SLOWED TO 1.5 BPM TO LOG. NOTICED DURING PASS #1 THAT THE INFD READ HIGHER THAN USUAL WHICH WOULD TEND TO INDICATE GAS NEAR THE WELLBORE. INCREASED THE INJECTION RATE TO 2.5 BPM FOR THE 2ND AND 3R PASS WHICH DID TEND TO SLIGHTLY REDUCE INFD. BUT EITHER INFD WAS HIGH DUE TO NEAR-WELLBORE GAS OR SOME OTHER DOWNHOLE PHENOFZENON. THERE WAS NOT ENOUGH CRUDE AVAILABLE TO INCREASE INJECTION RATE ABOVE 2.5 BPM AND THERE WAS NOT AN OPTION FOR GETTING MORE CRUDE. WHILE INJECTING AT 2.5 BPM THE INDICATED INJECTION PRESSURE WAS ONLT 65 PSI. THIS WAS A HIGH GAS WELL WHICH WENT ON A VACUUM ONCE THE WELLBORE WAS FILLED WITH CRUDE. APPROXIMATE GOC=9202 ' . GAS UNERRUNS APPEAR TO BE PRESENT FROM 9950' TO 9964' AND FROM 10004' TO 10046'. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** 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 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 24 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) ....................................................................................... TPHI PS3 PU 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPS3 CU 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS3 CU 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS3 CPS 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 TCAFPS3 CPS 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 TCNDPS3 CPS 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 TCFDPS3 CPS 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS3 CPS 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 INNDPS3 CPS 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS3 CPS 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1161099 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 10150.000 SIGM. PS3 -999.250 TPHI.PS3 -999.250 SBHF. PS3 SBHN. PS3 -999.250 SIGC.PS3 -999.250 SIBH. PS3 -999.250 TRAT. PS3 SDSI.PS3 -999.250 BACK. PS3 -999.250 FBAC.PS3 -999.250 TCAN. PS3 TCAF. PS3 -999.250 TCND.PS3 -999.250 TCFD.PS3 -999.250 TSCN. PS3 TSCF. PS3 -999.250 INND.PS3 -999.250 INFD.PS3 -999.250 TENS. PS3 GR.PS3 131.618 CCL.PS3 0.038 DEPT. 9574.000 SIGM. PS3 24.427 TPHI.PS3 36.592 SBHF. PS3 SBHN. PS3 58.216 SIGC. PS3 0.910 SIBH. PS3 92.518 TRAT. PS3 SDSI.PS3 1.016 BACK. PS3 229.132 FBAC. PS3 61.737 TCAN. PS3 TCAF. PS3 5290.801 TCND.PS3 17239.855 TCFD.PS3 4921.313 TSCN. PS3 TSCF. PS3 1027.614 INND.PS3 2009.683 INFD.PS3 389.105 TENS.PS3 GR.PS3 67.011 CCL.PS3 -999.250 -999.250 -999.250 -999.250 -999.250 781.000 51.413 1.723 14360.902 2789.270 1311.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 15:52 PAGE: 25 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/30 MAX REC SIZE : 1024 RILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/07/30 ORIGIN : FLIC TAPE NAME : 98389 CONTINUATION # : 1 PREVIOUS TAPE : COl~_2~f : ARCO ALASKA INC, D.S. 5-24, PRUDHOE BAY, 50-029-22204-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/07/30 ORIGIN : FLIC REEL NAME : 98389 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, D.S. 5-24, PRUDHOE BAY, 50-029-22204-00 Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. Tape Subfile 1 is type: LIS Ail rights reserved. **** REEL HEADER **** 91/ 9/25 01 **** TAPE HEADER **** 911 9~25 01 Tape Subfile: 1 Minimum record length: Maximum record length: 2 reco~°ds... 132 bytes 132 bytes %'% Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA RUN1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 05-24 5002922204 ARCO ALASKA ATLAS WIRELINE SERVICES 25-SEP-91 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 89789 BRAD ESARY K. LAWLER/G. C RUN2 RUN3 32 liN 15E 2203 1194 70.00 69.00 35.00 OPEN HOLE CASING DRILLER' S BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.630 10298.0 CIRCULATION STOPPED @ 14:00 ON 13-AUG-91. MADE AN ADDITIONAL REPEAT SECTION ON BOTTON DUE TO STICKY HOLE CONDITION. HIGH GAMMA RAY COUNTS FROM 10170 TO 10195 ON REPEAT SECTION DUE TO NEUTRON SOURCE ACTIVATION CAUSED WHILE CALIBRATING DIFL OVER THIS SECTION JUST PRIOR TO LOGGING. $ **** FILE HEADER **** FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; all runs merged; no case hole data. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH BCS 9578.0 DIL 9578.0 2435 9578.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA BASELINE DEPTH 10312.0 10312.0 10312.0 GR FROM DIFL-GR (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH RFOC AC CNC 9570.0 9581.5 9583.5 9780.0 9780.5 9781.5 9794.0 9829.5 9832.0 9934.0 9938.5 9940.5 9941.0 9970.0 9972.5 10168.5 10172.5 10192.5 10193.0 10201.0 10202.0 10203.0 $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: CN WN FN COUN STAT 9570.0 9570.0 9570.0 9582.0 9584.0 9933.0 9970.0 RUN NO. : ARCO ALASKA : 05-24 : PRUDHOE BAY : N. SLOPE : ALASKA 9938.5 9972.5 10166.5 10170.5 10193.0 10193.5 PASS NO. 9781.0 9781.5 9782.0 9794.5 9829.0 9831.5 9941.0 9941.5 10204.0 10205.0 10205.5 MERGE TOP * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Code Samples Units Size Length MERGE BASE 1 DT 68 1 US/F 4 2 GR 68 1 GAPI 4 3 MTEM 68 1 DEGF 4 4 SP 68 1 MV 4 5 TENS 68 1 LB 4 6 ILD 68 1 OHMM 4 7 ILM 68 1 OHMM 4 8 LL8 68 1 OHMM 4 9 FUCT 68 1 cPs 4 10 NPHI 68 1 PU-S 4 11 NUCT 68 1 CPS 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 71 4 4 4 4 4 4 4 4 4 4 4 44 Tape File Start Depth = 10312.000000 Tape File End Depth = 9569.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17845 datums Tape Subfile: 2 174 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0. 5000 FILE SUMMARY PBU TOOL CODE STOP DEPTH START DEPTH 2435 9182.0 9578.0 GRCH 9182.0 9578.0 $ BASELINE CURVE FOR SHIFTS: GR FROM DIFL-GR CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CN : ARCO ALASKA WN : 05-24 FN : PRUDHOE BAY COUN : N. SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Code Samples Units Size Length 1 FUCT 68 1 CPS 4 4 2 GRCH 68 1 GAPI 4 4 3 NPHI 68 1 PU-S 4 4 4 NUCT 68 1 CPS 4 4 5 TEND 68 1 LB 4 4 6 TENS 68 1 LB 4 4 * DATA RECORD (TYPE# 0) 1014 BYTES * 24 Total Data Records: 23 Tape File Start Depth = 9578.000000 Tape File End Depth = 9177.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5622 datums Tape Subfile: 3 51 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS 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 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH AC DIFL 2435 $ 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 9578.0 10312.0 9578 . 0 10312 . 0 9578.0 10312.0 13-AUG-91 FSYS256 REV: G002 VER: 2.0 1400 13-AUG-91 2153 13-AUG-91 10290.0 10298.0 9578.0 10238.0 0.0 TOOL NUMBER CHT MIS TEMP GR CN PCM AC DIFL $ CABLE HEAD TENSION MASS ISOLATION SUB TEMPERATURE GAMMA RAY COMP. NEUTRON PULSE CODE MODULATOR ACOUSTILOG DUAL INDUCTION 3974 3967 2806 1309 2435 3506 1609 1503 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 6.750 9575.0 9578.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): LT POLYMER 9.10 38.0 8.5 0.0 165.0 2.230 72.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: CN : ARCO ALASKA WN : 05-24 FN : PRUDHOE BAY COUN : N. SLOPE STAT : ALASKA 1.020 2.040 0.000 2.510 0.000 THERMAL SANDSTONE 0.00 7.875 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Code Samples Units Size Length 1 GR 68 1 GAPI 4 4 2 RFOC 68 1 OHMM 4 4 3 RILD 68 1 OHMM 4 4 4 RILM 68 1 OHMM 4 4 5 SP 68 1 MV 4 4 6 AC 68 1 US/F 4 4 7 CHT 68 1 LB 4 4 8 CLSN 68 1 CPS 4 4 9 CNC 68 1 PU-S 4 4 10 CSSN 68 1 CPS 4 4 11 TEMP 68 1 DEGF 4 4 12 TTEN 68 1 LB 4 4 * DATA RECORD (TYPE# 0) 994 BYTES * 48 Total Data Records: 157 165.0 72.0 0.0 72.0 0.0 Tape File Start Depth = 10312.000000 Tape File End Depth = 9569.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 56495 datums Tape Subfile: 4 236 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: RAW OPEN HOLE Curves and files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH 4 REPEAT PASSES log header data for each pass, tool string, and run in separate 1 1 1 0.2500 STOP DEPTH ---------------- ----------- ---------- AC DIFL 2435 $ 9490.0 9490.0 9490.0 10312.0 10312.0 10312.0 .# LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRI LLER ( FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 13-AUG-91 FSYS256 REV: GO02 1400 13-AUG-91 2111 13-AUG-91 10290.0 10298.0 9578.0 10238.0 0.0 VER: 2.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- CHT CABLE HEAD TENSION 3974 MIS MASS ISOLATION SUB 3967 TEMP TEMPERATURE 2806 GR GAMMA RAY 1309 CN COMP. NEUTRON 2435 PCM PULSE CODE MODULATOR 3506 AC ACOUSTILOG 1609 DIFL DUAL INDUCTION 1503 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 6.750 9575.0 9578.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: LT POLYMER 9.10 38.0 8.5 0.0 165.0 2.230 1.020 2.040 72.0 165.0 72.0 MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 0.000 2.510 0.000 # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 7.875 # # TOOL STANDOFF (IN): 0.0 REMARKS: $ # CN WN FN COUN STAT : ARCO ALASKA : 05-24 : PRUDHOE BAY : N. SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Code Samples Units Size Length 1 AC 68 1 US/F 4 4 2 CHT 68 1 LB 4 4 3 CLSN 68 1 CPS 4 4 4 CNC 68 1 PU-S 4 4 5 CSSN 68 1 CPS 4 4 6 GR 68 1 GAPI 4 4 7 RFOC 68 1 OHMM 4 4 8 RILD 68 1 OHMM 4 4 9 RILM 68 1 OHMM 4 4 10 SP 68 1 MV 4 4 11 TEMP 68 1 DEGF 4 4 12 TTEN 68 1 LB 4 4 ------- 48 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 174 Tape File Start Depth - 10314.000000 Tape File End Depth - 9490.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 48484 datums 0.0 72.0 0.0 Tape Subfile: 5 Minimum record length: Maximum record length: 251 records... 62 bytes 994 bytes Tape Subtile 6 is type: LIS FILE HEADER FILE NUMBER: RAW OPEN HOLE Curves and files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH 5 REPEAT PASSES log header data for each pass, too! string, and run in separate 1 1 3 0.2500 STOP DEPTH ---------------- ----------- ---------- AC DIFL 2435 $ 9826.0 9826.0 9826.0 10313.0 10313.0 10313.0 # 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): 13-AUG-91 FSYS256 REV: GO02 1400 13-AUG-91 2300 13-AUG-91 10290.0 10298.0 9578.0 10238.0 0.0 VER: 2.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- CHT CABLE HEAD TENSION 3974 MIS MASS ISOLATION SUB 3967 TEMP TEMPERATURE 2806 GR GAMMA RAY 1309 CN COMP. NEUTRON 2435 PCM PULSE CODE MODULATOR 3506 AC ACOUSTILOG 1609 DIFL DUAL INDUCTION 1503 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 6.750 9575.0 9578.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: LT POLYMER 9.10 38.0 8.5 0.0 165.0 2.230 1.020 2.040 72.0 165.0 72.0 MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 0.000 2.510 0.000 0.0 72.0 0.0 # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 7.875 # # TOOL STANDOFF (IN): 0.0 REMARKS: $ # CN WN FN COUN STAT : ARCO ALASKA : 05-24 : PRUDHOE BAY : N. SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Code Samples units Size Length 1 AC 68 1 US/F 4 4 2 CHT 68 1 LB 4 4 3 CLSN 68 1 CPS 4 4 4 CNC 68 1 PU-S 4 4 5 CSSN 68 1 CPS 4 4 6 GR 68 1 GAPI 4 4 7 RFOC 68 1 OHMM 4 4 8 RILD 68 1 OHMM 4 4 9 RILM 68 1 OHMM 4 4 10 SP 68 1 MV 4 4 11 TEMP 68 1 DEGF 4 4 12 TTEN 68 1 LB 4 4 ------- 48 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 103 Tape File Start Depth - 10314.000000 Tape File End Depth - 9828.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 81781 datums Tape Subfile: 6 Minimum record length: Maximum record length: 180 records... 62 bytes 994 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CASED HOLE MAIN PASS Curves and log header data PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH for open hole !ogs run into casing. STOP DEPTH ---------------- ----------- ---------- 2435 GRCH $ 9182.0 9182.0 9578.0 9578.0 # 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): 13-AUG-91 FSYS256 REV: GO02 1400 13-AUG-91 2153 13-AUG-91 10290.0 10298.0 9578.0 10238.0 0.0 VER: 2.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- CHT CABLE HEAD TENSION 3974 MIS MASS ISOLATION SUB 3967 TEMP TEMPERATURE 2806 GR GAMMA RAY 1309 CN COMP. NEUTRON 2435 PCM PULSE CODE MODULATOR 3506 AC ACOUSTILOG 1609 DIFL DUAL INDUCTION 1503 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: # 6.750 9575.0 9578.0 LT POLYMER 9.10 38.0 8.5 0.0 165.0 2.230 1.020 2.040 0.000 2.510 0.000 72.0 165.0 72.0 0.0 72.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # REMARKS: $ # CN . ARCO ALASKA . WN . 05-24 . FN . PRUDHOE BAY . COUN . N. SLOPE . STAT . ALASKA . * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Code Samples units 1 CHT 68 1 LB 2 CLSN 68 1 CPS 3 CNC 68 1 PU":,S 4 CSSN 68 1 CPS 5 GR 68 1 GAP I 6 TTEN 68 1 LB * DATA RECORD (TYPE# 0) THERMAL SANDSTONE 0.00 7.875 0.0 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 ------- 24 Total Data Records: 45 1014 BYTES * Tape File Start Depth - 9578.000000 Tape File End Depth - 9177.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 59720 datums 68 Tape Subfile: 7 118 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfi!e 8 is type: LIS **** TAPE TRAILER **** 91/9/25 01 **** REEL TRAILER **** 91/9/25 01 Tape Subtile: 8 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes End of execution: Wed 25 SEP 91 10:16a Elapsed execution time = 52.95 seconds. SYSTEM RETURN CODE = 0