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187-019
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~_ ~ ~- _0 J q Well History File Identifier Organization (done) ~ Two-Sided RESCAN DIGITAL DATA [] Color items: Grayscale items: [] Poor Quality Originals: [] Diskettes, No. O Other, No/Type TOTAL PAGES: 1~7~L NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other ~si Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ SCANNED BY; REN VINCENT SHERYL MARIA LOWELL Isl RESCANNEDBY; BEVERLY BREN VINCENT SHERY~OWELL ~si General Notes or Comments about this file: Quality Checked (done) Rev1 NOTScanned.wpd ~PG- 7/2//06 . STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG REcr§Qifi9 SËÞ 2 1)0 °2~8e6 C C mis: 5sil ,¡ask;¡ níi il.dJia,:t on~ om 1 a. Well Status: DOil DGas D Plugged 181 Abandoned D Suspended DWAG 1 b. ~~~;~f~;~ent ~_i~ry , 20AAC 25,105 20AAC 25,110 DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 5/14/2006 187-019 306-120 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 03/02/1987 50-029-21700-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 03/14/1987 PBU L5-16 1788' FSL, 19' FWL, SEC. 01, T11N, R15E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 1245' FSL, 1005' FWL, SEC. 01, T11N, R15E, UM 60' Prudhoe Bay Field / Lisburne Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 1079' FSL, 1211' FWL, SEC. 01, T11N, R15E, UM 9119 + 8894 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 717447 y- 5974920 Zone- ASP4 9575 + 9313 Ft ADL 028320 TPI: x- 718449 y- 5974407 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 718660 y- 5974247 Zone- ASP4 N/A MD 18. Directional Survey DYes 181 No 19. Water depth, if offshore 20. Thickness of Permafrost N/A MSL 1900' (Approx.) 21. Logs Run: DLL / NGT / SP, LDT / CNL / EPT / Cal/ GR, CBT, GCT, PDK-100 22. CASING, LINER AND CEMENTING RECORD '. cï:G ..... ..., , SË11'INGDËPTHMO SETTING DËPTH 1'10 i~r~.. ..... / .... ...... \~ .x Wr.PËRFt. GRADE Top BOTTOM Top BOTTÖM i, o. ,Äê .... ......,.... -pttÈ~h 20" 91.5# H-40 Surface 120' Surface 120' 30" 1800 # Poleset 10-3/4" 45.5# L-80 Surface 4006' Surface 3998' 13-1/2" 1300 sx AS III 325 sx Class 'G' 7-5/8" 29.7# L-80 Surface 9559' I Surface 9298' 9-7/8" 425 sx Class 'G' 4-1/2" 12.6# L-80 8803' 9206' 8603' 8974' Scab Lnr 97 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 124. x i ..i ., .... - .. ... .., .'}. '.' ii}} .<, iii<}>.>< ..' Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None None MD TVD MD TVD 25. ". ........ .'. po x. \t!.::~¡~..." ''''.' ..,.. ........ ···········<}x>J},···· ··..·i ·J.{>"Yi x. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Attempt to P&A w/ 4 Plugs over 4 days (All Class 'G'): 53 Bbls, 52 Bbls" 51 BBls, 28 Bbls -8951' (05/06/06 - 05/09/06), Unsuccessful, Still Flowing 8910' (05/14/06) P&A w/46 Bbls Class 'G' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BsL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED OIL-BSL GAs-McF WATER-BsL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE+ 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". RBDMS 8Ft SEP 2 5 2DD6 None Form 10-407 Revised 12/2003 o R f GIN AtNUED ON REVERSE SIDE G 28. GEOLOGIC MARKE 29. ORMATION TESTS 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". Wahoo Zone 6 8902' 8694' None Wahoo Zone 5 8988' 8773' Wahoo Zone 4 9093' 8870' Wahoo Zone 3 9227' 8993' Wahoo Zone 2 9294' 9055' Wahoo Zone 1 9356' 9112' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ . Title Technical Assistant Date DC¡ lie¡ (0 PBU L5-16 Well Number 187-019 306-120 Permit No. / A roval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Greg Sarber, 564-4330 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 Events for SurfaceWell - LS-16 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GPMA -> L5 -> L5-16 Date Range: 05/Mar/2006 to 31/Ju1!2006 Data Source(s): DIMS, AWGRS Digital Wellfile Events Source Well DIMS L5-16 DIMS L5-16 .DIM...s L5-16 DIMS L5-16 DIMS L5-16 AWGRS L5-16 AWGRS L5-16 AWGRS L5-16 AWGRS L5-16 AWGRS L5-16 DIMS L5-16 AWGRS L5-16 AWGRS L5-16 Date 07/31/2006 07/30/2006 07/29/2006 07/28/2006 07/27/2006 06/14/2006 06/13/2006 06/12/2006 06/11/2006 06/10/2006 06/01/2006 06/01/2006 05/31/2006 DIMS L5-16 05/31/2006 DIMS L5-16 05/30/2006 A WGR$ L5-16 OS/29/2006 DIMS L5-16 OS/29/2006 DIMS L5-16 OS/28/2006 DIMS L5-16 OS/27/2006 .DIMS L5-16 OS/26/2006 DIMS L5-16 OS/25/2006 DIMS L5-16 OS/24/2006 .DIM$ L5-16 OS/23/2006 DIMS L5-16 OS/22/2006 DIMS L5-16 OS/21/2006 DIMS L5-16 OS/20/2006 DIMS L5-16 05/19/2006 DIMS L5-16 05/18/2006 DIMS L5-16 05/17/2006 DIMS L5-16 05/16/2006 DIMS L5-16 05/15/2006 AWGRS L5-16 05/15/2006 . Page 1 of 3 Description Drill build section while UB well to 9252'. RIH w/ lateral BHA Finish milling window. Begin drilling build Prep new reel of 2" E-CT. Begin milling window MIRU. Swap reels. NU BOPE/PT. Move ASRC test sep and tanks/RU lines Move off of L5-28. PU mats and stack for L5-16 RUN 1: GR / CCL CORRELATION FOR WHIPSTOCK. RUN 2: SET BAKER 4-1/2" WHIPSTOCK TOP AT 9097', ORIENTED 2 DEGREES LEFT OF HIGH SIDE. 2 RA TAGS LOCATED 8.6' FROM TOP, AT 9105.6'. Job complete... CTU #9. Mill Cement. *** Continuation of WSR 06/12/2006 ***. RIH w/Weatherford 3.8" Junk Mill BHA. Dry tag at 9063' ctm. Mill from 9050' ctm to 9114' ctm using 560 bbls of 1 % XS KCI and 40 bbls of FloPro. Stall #1 motor at 9115' ctm. Back reamed up to 8800' and reamed back to 9114'. Pumped 15 bbl FloPro sweep from bottom and chased OOH at 80% of pump rate back reaming. Freeze protect well from 2500' using 40 bbls of 50:50 MeOH. RDMO. Notify Pad Operator of well status. *** Job Complete *** CTU #9. Mill Cement. MIRU CTU. RIH with Weatherford BHA with 3.8" 6-bladed junk mill. Tag at SSSV and GLM #5. Rotate through at minimum pump rate. Continue RIH to bottom. *** Continued on WSR 06/13/2006 *** ***CONTINUED FROM 06-10-2006*** RAN ASSORTED CENT. FROM 3.75 TO 2.15 CENT GOT DOWN TO 9046' WI 2.15 CENT., BAILED 1.5 GALS. OF WHAT APPEARS TO BE CEMENT, FINAL TAG OF 9,043' SLM W/ 3" BAILER. ***WELL LEFT SHUT IN*** ***WELL SI ON ARRIVAL *** PULL B&R CHANGED OUT GLV'S AS PER PULL RUN REPORT PULL RHC ( DATA FOR GLV'S WELL BE ON 06-11-06 AWGRS REPORT ***JOB IN PROGRESS CONTINUED ON 06-11-2006*** Set packer. ND BOPE. NU master valve. FP. RREL. RDMO PULL TWC THREW TREE RIG JOB *** ASSIST NORDIC 2 RIG *** RAN 4 1/2 GS,SAT DOWN @ 8753 SLM. LATCHED AND PULLED RHC. RAN 2' STEM,3.75 CENT. WENT DOWN TO 8860 SLM. PULLED TO 8800 SLM. WENT BACK DOWN SAT DOWN, @ 8834 SLM. POOH. RAN PDS GL/CCL LOG, SAT DOWN @ 9058 SLM, LOGGED 40' MIN, TO 7900 SLM. SET 4.5" RHC PLUG BODY @ 8753' SLM ***WELL TURNED OVER TO RIG*** WL diagnostics to determine EOT. Land tubing, displ to corrosion inhibitor Load pipe shed. Run completion. Tag up on TOL **** ASSIST NORDIC 2 RIG **** RAN 6.635 GAUGE RING JUNK BASKET, RECOVER MISC DEBRIS ***WELL TURNED OVER TO RIG*** Cement liner. Circ well. POH. LDDP. SLickline GR/JB. Load pipe shed. Run GR/JB. Run usn log. Run and cement 4-1/2" liner. Ream to btm. CBU. POH. LD BHA. RU e-line. Run GR/JB. Mill to 9200'. CBU. POH. Clean out BHA. MU reversing BHA. RIH. MU BHA. Run in hole. Mill f/ 9116' to 9180'. BHA trip. Cut & slip. MU milling BHA. RIH. Mill cement fr/8950' to 9127'. BHA trip. Test BOPE. MU BHA #4. TIH. Mill cement/junk fr/8886'-8950'. BHA Swap. TIH with BHA #3. Spear Fish POH. TIH with BHA #2. Missed fish. POOH. MU kelly. TIH. Fish tubing stub. POOH. Load pipe shed with drill pipe. MU fishing BHA #1. Trip in hole on DP. Pickup Kelly. Circ out well. Pull old 3-1/2" tubing string. ND 7-1/16" stack and tree. NU 13-5/8" BOP stack and tested. Pulled BPV and tbg hngr. Jet cut tbg at 8785'. Circulate to kill IA. Set BPV and test. ND BOP and production tree. T/I/O = 0/0/0 Could not test tubing hanger until rig was over the well and scaffolding had been removed. Pressured up tubing hanger void to 5000 psi. Pressure was 5000 psi at 15 min. and 5000 psi at 30 min. Test passed. Lockdown screws had been functioned on previous test. http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 9/19/2006 Digital Wellfile DIMS DIMS DLMS AWGRS L5-16 L5-16 L5-16 L5-16 AWGRS L5-16 AWGRs L5-16 AWGRS L5-16 AWGRS L5-16 AWGRS L5-16 AWGRS L5-16 AWGB.$ L5-16 AWGRS L5-16 AWGRS L5-16 AWGRS L5-16 AWGRS L5-16 AWGRS L5-16 05/14/2006 05/13/2006 05/12/2006 05/11/2006 05/11/2006 05/10/2006 05/09/2006 05/08/2006 05/07/2006 05/06/2006 05/05/2006 05/04/2006 05/03/2006 05/02/2006 05/02/2006 05/02/2006 . Page 2 of 3 . Test BOPE. RU and squeeze cmt perforations. Cleanout stack. Pickle 2" coil. RD coil. MIRU. Kill well. NU BOPE and RU 2" coil. Finish FP D-20. Move from D Pad to L5 Pad with rig camps. Rig enroute. T/I/0=350/0/180 Assist SLB w. MIT TBG to 3000 psi. (PASS), CMIT Tx IA to 3000 psi, (PASS), LLR Cement Plug (RWO Prep) Pumped 6.9 bbls of 50/50 meth to pressure TBG to 3000 psi. TBG lost 110 psi in 15 min and 35 psi in 2nd 15 in for 145 psi loss over 30 min. PASS. Bled TBG psi. Pumped 7.9 bbls 50/50 meth down IA to pressure IA/T6G to 3000 psi. TBG/IA lost 10/20 in 15 min and 20/15 psi after 2nd 15 min for a total psi loss of 30/35 psi over 30 min, bled TBG/IA down. Pumped 23 bbls of 50/50 meth to establish LLR past cement plug, LLR = 2.25 bpm @ 2450 psi. Final WHP's=500/240/200 ***J06 CONT. FROM 5/12/06*** SAT DOWN ON TOP OF CEMENT @ 8949' SLM, 8965' CORRECTED ELMD, RIH W A-2 BLANKING PLUG, D RUNNING TOOL ( EQU FN 1 3/4", PULL FN, 2.313) SET PLUG @ 8859' SLM LRS DID CMIT. PASSED. PULL A-2 BLANKING PLUG @ 8949' SLM. ***WELL 5/1 ON DEPARTURE*** ***WELL SHUT IN ON ARRIVAL *** DRIFT TUBING W/ 2.5 CENT, TEL, AND SAMPLE BAILER, TAGGED CEMENT TOP @ 8951' SLM PUMP DIESEL TO MIT-T, UNABLE TO PRESSURE UP, BLEED GAS OFF TUBING ***JOB CONT. ON 5/11/06*** CTU #5, P&A; Cont' from WSR 5/08/06 ... Wait on cement lab results. RIH with 2.0" BDN. Correct nozzle depth at flag. RIH to target depth of 8930'. Load well with 150 bbls of 1 % KCL; 3.4 bpm @ 2000 psig WHP. Follow with 50 bbls diesel to establish positive WHP. Establish injection down coil with 1% KCL; 1.5 bpm @ 1140 psig WHP. Mix on the fly and pump 28 bbl cement (10 with aggregate). Bullhead 20 bbls, establish 1775 psig WHP. Open choke, reduce WHP gradually and lay in 8bbl of remaining cement. Hesitate squeeze 2 bbl every hour for a total of 8 additional bbls. Drop ball and RIH jetting with biozan to 8930'. Washed TT multiple times with bio. Chase to surface pooh @ 80%. Freeze protect well to 2500' with diesel. Secure well trapping 200 psi WHP. RD CTU #5. *** Job Complete *** CTU #5, P&A; Cont' from WSR 5/07/06 ... Pumping 15.8 ppg cement. Total of 52 bbls cement pumped. Established 500 psi bump in WHP after 44 bbls cement out nozzle. Attempt to take returns and lay in last few barrels, 80% losses. Squeeze pressure fell off to balance WHP. POOH. Call for re-Ioad of fluids. Cementers houred out. POOH. Will discuss options for a smaller volume balanced plug. Wait on fluids/cementers. ... RBIH with 2.0" BDN. Correct nozzle depth at flag. RIH to target depth of 8930'. Load well with 150 bbls of 1% KCL; 3.4 bpm @ 1670 psig WHP. Follow with 50 bbls diesel to establish positive WHP. Establish injection down coil with 1% KCL; 1.5 bpm @ 1240 psig WHP. Cement tested at 68 mil 30 min fluid loss. Pumped 51 bbls cement. With choke closed, WHP increased slowly to 1900 psig. Attempt to take returns and lay in last 10 barrels, 80% losses. Flushed cement out of tubing. Squeeze pressure slowly fell off to balance WHP. POOH. Prep for squeeze with aggregate. Wait on fluids, cement and crews. Co nt' on WSR 5/09/06... CTU #5, P&A; Cont' from WSR 5/06/06 ... POOH. At surface. Pump 10 bbls diesel down backside to ensure cement top is at least down to 9200'. Saw no resistance to injection. Well likely already drank cement. Prep to cement again. Load and test 70 mil 30 min fluid loss cement. Wait on new batch of cement. First test ran short. Re-do and test OK. RBIH with 2.0" BDN. Correct nozzle depth at flag. RIH to target depth of 8930'. Load well with 159 bbls of 1 % KCL; 3.4 bpm @ 1525 psig WHP. Follow with 50 bbls diesel to establish positive WHP. Establish injection down coil with 1% KCL; 1.5 bpm @ 970 psig WHP. Cement tested at 69 mil 30 min fluid loss. Pumping 15.8 ppg cement. Co nt' on WSR 5/08/06 ... CTU #5, P&A; Co nt' from WSR 5/05/06 .., Pumped 1.25" ball to drift coil. Performed weekly BOP test - passed. RIH with nipple locator for depth control. Located 3 1/2" nipple and flagged pipe at 8882' ctmd. POOH. RIH with 2.0" BDN. Correct nozzle depth at flag. RIH to target depth of 8930'. Load well with 150 bbls of 1 % KCL; 3.8 bpm @ 745 psig WHP. Follow with 50 bbls diesel to establish positive WHP. Establish injection down coil with 1% KCL; 1.9 bpm @ 260 psig WHP. Cement tested at 51 mil 30 min fluid loss. Pump 53 bbls cement and displace to perfs (est TOC at 8950), taking no returns. Did not build squeeze pressure. POOH, FP coil with meth. Co nt' on WSR 5/07/06 ... CTU #5, P&A; MIRU CTU #5. Co nt' on WSR 5/06/06 ... ***CTU #5 Weld/Repair Coil*** ***CTU #5 Re-weld/Repair cut coil*** T/I/O= 10/0/220 Assist CTU # 5 -- Pumped 0.8 bbls of 60/40 meth/water to pressure up coil to 150 psi w/ SEL IH to perform chem cut. Chem cut complete. Pumped 28 bbls of 60/40 down coil for kill. Final Whp's 10/0/220 CHEM CUT 1-3/4" COIL TUBING @ 8964' WITH 1.25" CHEMICAL CUTTER. COULD NOT RUN CCL DUE TO RESTRICTIVE COIL ID, USED PRIMARY DEPTH CONTROL. CONFIRMED COIL CUT WAS SUCCESSFUL, RDMO **JOB COMPLETE** ***Job continued from 5-1-06 WSR.*** PJSM with e-line crew. RIH with 1.25" chemical cutter (corrected to RKB for depth control). Cut coiled tubing at 8964' MD. POOH with chemical cutter. Make up double cold roll to coil in well. POOH w/ CT. Blow down coil with N2. RDMO. http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 9/19/2006 Digital Wellfile A.'1f~RS. L5-16 AWGRS L5-16 AWGRS L5-16 AWG.....R,~ L5-16 AWGRS L5-16 AWGRS L5-16 AWGRS L5-16 AWGRS L5-16 AWGRS L5-16 AWGRS L5-16 AWGRS L5-16 05/01/2006 05/01/2006 04/30/2006 04/29/2006 04/28/2006 04/21/2006 04/18/2006 04/18/2006 04/17/2006 04/15/2006 03/06/2006 . Page 3 of 3 . ***Job not complete*** --Assist CTU #5, Released from job, to return in am-- ***Continue Job From 4/30/06*** Stand by on e-line unit. No flow well and coiled tubing. MU wireline guide on CT. Install p-sub and lubricator for e-line unit in prep for chem cut. ***Job in progress. Continue on 5-2-06 WSR. *** ***Job continued from 4-29-06*** Build scaffolding around wellhead for possible CT chem cut. Pump 50 bbls of 15% HCL down backside in attempt to free stuck CT and not successful. Perform CT cut at surface. On standby for e-line unit for chem cut. ***Job in progress. Continue on 5-1-06 WSR*** ***Job continued from 4-28-06 WSR*** Load IA w/ diesel. Kill well. RIH w/ 2.0" BDN. Load backside w/ diesel to maintain WHP. Tag TD at 9437' CTM, 9418' correct to rig depth. Paint flag at 9250'. PUH above perfs to 8913'. Continue to pump 1 % KCL down CT. RIH to 9408' and lay in cement 1: 1. CT stuck at 9192'. Flush CT with diesel. Pump 15 bbls of diesel down backside. Attempt to pump down CT and pressure up. Flush backside with 60 bbls of biozan and 54 bbls of diesel. Attempt to reverse out. No success. Call for acid. Build scaffolding around BOP stack in preparation for chem cut. ***Job in progress. Continue on 4-30-06 WSR*** MIRU CTU #5. MU BHA w/ 2.0" BDN. ***Job in progress. Continue on 4-29-06 WSR*** T/I/O =2180/2500/500 Tested casing packoff to 3000 psi. Pressure was 2900 psi at 15 min and 2900 psi at 30 min. Test passed. LDS were functioned and retorqued to 450 ft Ibs. Could not test the tubing hanger because well scaffold was in the way. LDS on tubing head were functioned and retorqued to 450 ft. Ibs. T/I/O= 2180/2200/440 MIT-OA to 2000 psi. [PASSED] on 1st attempt. Pumped 3 bbls of 20 deg. crude to reach test pressure. Lost 160 psi.in 1st 15 min. and 20 psi. in 2nd 15 min. for a total loss of 180 psi. bled pressure back. Final WHP= 2180/2200/500 ***CONTINUED FROM 4-17-06 WSR*** (SBHPS) RIH W/ 2.50" SWAGE, T.E.L., PETREDAT DUAL TANDEM GAUGES. LOC. TI @8861' (SLM), 8884' ELMD +23 CORR. MADE 20 MIN STOPS @9191' MD, 9082' MD, 8973' MD AND 9191' MD. ****LEFT WELL SHUT IN**** ***WELL 5/1 ON ARRIVAL*** (sbhps) PICKUP PACKAGES FROM PBOC, RIG UP ***CONT'D ON 4-18-06 WSR*** ***WELL 5/1 ON ARRIVAL***(pre-ctd) DRIFT W- 2.85 CENT. 10' 1.5 STEM AND FLAP. CHECKER. SIT DN. @ 1331' SLM. DRIFT W- 2.5 CENT. T.E.L. AND S.B. LOC. T.T @ 8866' SLM, 18' CORR. TO ELMD @ 8884' TAG FILL @ 9302' CORRECTED. ( S.B EMPTY) ****PERF.s @ 8964' TO 9378' = 76' FILL.***** ***WELL LEFT 5/1*** NOTIFIED DSO ***CONTINUE FROM 02-05-2006 WSR*** RIH W/2.5" CENT & PETREDAT GAUGES. MADE STOPS @ 8944', 9053', & 9162' SLM. GOOD DATA RECORDED. ***GIVE WELL BACK TO DSO*** AWGRS L5-16 03/05/2006 ***WELL S/I ON ARRIVAL ***(static) TAG TRSSSV @ 2186' SLM, UNABLE TO FUNCTION UNABLE TO LOC. TIL, TAG TD @ 9280' SLM, RECOVERED SAND IN SB. ***CONTINUE ON 03- 06-2006 WSR*** http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 9/19/2006 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-16 L5-1 6 WORKOVER NORDIC CALISTA NORDIC 2 Start: 5/12/2006 Rig Release: 6/1/2006 Rig Number: Spud Date: 5/12/2006 End: 6/1/2006 5/12/2006 08:00 - 08:15 0.25 MOB P PRE Safety mtg re: move off D Pad and head to L5 Pad 08:15 - 00:00 15.75 MOB P PRE Move from D-20 out to the Spine Rd. Head down the Spine to West checkpoint and through Deadhorse. Proceed thru East checkpoint to Y and park for crew change at 1730 hrs. Resume move and park off road at SRT at 1900 hrs. Held PJSM/THA with Peak crane crews. Removed 13-5/8" BOP stack and skid from behind D-20 wellhead at 1730 hrs. Made Post Rig Inspection with D pad DSO. Rig camps left D-20 location at 1830hrs. On L5-16 location at 2230hrs. Resume moving rig to location at midnight. Other: DSM finished removal of L5-16 well house and flowline at 2000hr. Held Pre Rig-Up Inspection with DSO. Tool Service removing snow from behind wellhead and leveling rig footprint area. 5/13/2006 00:00 - 04:30 4.50 MOB P PRE Continue mobilizing rig to location. Finished leveling wellsite. Spot 13-5/8" stack close to well. Rig on location at 0430hr 04:30 - 06:00 1.50 MOB P PRE Set mats. Take on rig water. 06:00 - 06: 15 0.25 MOB P PRE Crew change/TUsafety mtg Accept rig at 0600 hrs 06:15 - 07:30 1.25 MOB P PRE MI VECO lowboy w/ used e-free 2" CT. Open bombay doors and load reel into reel house 07:30 - 10:30 3.00 MOB P PRE Set injector on floor. RU packoff and gooseneck. Install internal grapple in CT and PT. Pull CT to floor and stab. Lay herculite around cellar. MIRU Peak 150T crane off lowboy 10:30 - 10:45 0.25 MOB P PRE Safety mtg re: Set 13·5/8" stack 10:45 - 12:00 1.25 MOB P PRE Remove 13-5/8" stack and trolley from skid and set behind well Move skid. RDMO Peak crane 12:00 - 13:30 1.50 MOB P PRE RU hardline in reel house Prespud during lunch Find out that Carlisle has misplaced our annular. Left Anchorage Thursday nite, but is still sitting in Fairbanks. Will go without it for cement squeeze 13:30 - 16:00 2.50 MOB P PRE Hang 7-1/16" BOP's in cellar and flange up to Otis connection Mobilize LRS and vac truck 16:00·18:45 2.75 MOB P PRE MIRU LRS and VECO vac to tree cap. PT 3500 psi. SITP 420 psi, IA 0, OA 100 Liquid pack well bore wI 150 bbls 1% KCI at 90 deg F at initial 3.0/2000. After 145bbls 1675psi. Final at 2bpm 1375psi Load kelly into pipeshed 18:45 - 19:00 0.25 MOB P PRE PJSM. Review procedures for moving over well. 19:00 - 19:45 0.75 MOB P PRE Spot rig over well. 19:45 - 21 :15 1.50 MOB P PRE Level rig. 21:15 - 00:00 2.75 BOPSU P PRE NU 7-1/16" BOP's (less annular) 5/14/2006 00:00 - 05:00 5.00 BOPSU P PRE Pressure test BOP's. 250psi low / 3500psi high for 5 min each. 05:00 - 09:00 4.00 ZONISO P DECOMP RU and pump coil dart at 2 bpm. Dart hit at 40.2 bbls. RD dart catcher. Install Kendall CTC. PT 4000, 35k. PT inner reel valve @ 4000 psi. MU big hole w/ side jet nozzle assy. Circ over top of swab wI pump #2 and calibrate MM's 1.13/680, 2.65/3500 w/ 8.31 ppg KCI at 81.5F MIRU DS cementers·have pilot test, but just put field blend test in this AM. Will be done at 1030 hrs MIRU diesel transport and dirty vac Printed: 6/512006 11 :48:03 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-16 L5-1 6 WORKOVER NORDIC CALISTA NORDIC 2 Start: 5/12/2006 Rig Release: 6/1/2006 Rig Number: Spud Date: 5/12/2006 End: 6/1/2006 5/14/2006 09:00 - 09:30 0.50 ZONISO P DECOMP Safety mtg re: well entry, RIH steps 09:30 - 10:30 1.00 ZONISO P DECOMP Open up to well and on a vac. IA 230, OA 110, PVT 246 RIH wI 2.375" nozzle wi 3' stinger assy #1 pumping 0.3/30 1 % KCI wi choke SI. By 1600' had 560 psi whp and rising. Bleed off WHP which was a little gas wi MeOH freeze protect to tiger tank then circ wi 1/1 returns, muse, muse. Continue RIH circ 0.5/250 wlopen choke taking returns to tiger tank. Strap occasionally and verify wi out MM as 1/1 returns 10:30-11:15 0.75 ZONISO P DECOMP Park at 5000' and do circ test 1.98/1.83/2300 wi 55 psi bp induced from hardline to TT. RIH 11: 15 - 11 :25 0.17 ZONISO P DECOMP Wt chk at 8500' 24.6k, 17.5k. RIH clean to 8992', clean. PUH 26.3k clean 11:25-12:15 0.83 ZONISO P DECOMP Park at 8840' and circ at min rate while wo Nordic crew XO Bleed IA from 360 psi to zero since GLV's are live, OA 220 12:15 - 12:35 0.33 ZONISO P DECOMP Safety mtg re: cement job 12:35 - 13:05 0.50 ZONISO P DECOMP Circulate 40 bbls 47 deg 6.82 ppg diesel down the CT 1.63/1770 wi full returns. SD pump wi 660 psi positive diff Meanwhile cementers take on FW and prep to pump cement 13:05 - 13:20 0.25 ZONISO P DECOMP Cementers fill lines wi 5 bbls FW bypassed thru Baker choke. PT at 4200 psi 13:20 - 13:50 0.50 ZONISO P DECOMP DS mix and pump on the fly 20 bbls neat, 20 bbls wi 12-14 ppb aggregate, 6 bbls neat 'G' cement at 91 deg wi field tested 82 ml and 3:30 TT 1.5/2800. Continue taking 1/1 returns to tiger tank until 40 bbls were pumped. Close in choke at 40 bbls which coincided wi a reduced out density indicating diesel at surface 13:50 - 14:20 0.50 ZONISO P DECOMP With nozzle at 8950' PUH 3'/min while bullhead cement at 1.5 bpm to perfs (at 8964'). Reduced cementer rate to 1.0 bpm and immediately had 2050 psi whp. DS displace cement wi 5 bbls washup water. Rig displace all cement wi diesel at 1.0/500 and had 2900 psi whp at 0.5 bpm before aggregate even out the nozzle IA 320 14:20 - 15:00 0.67 ZONISO P DECOMP POOH 1/1 0.5/400-1200 psi wi 3000 psi whp. After 20 bbls diesel displaced, swap to 40 bbls biozan then 2% KCI. Continue POOH 0.6/1260 wi 3000 psi whp to WCTOC. Looks like we had 40 extra bbls of cement. . . 15:00 - 15:15 0.25 ZONISO P DECOMP Park at safety at 4600' and SD pump wi biozan at nozzle and spot check was jft at 2930 psi. Reduce whp to 1300 psi while incr rate to 2.0/3400 to clear CT of any residual cement and circ biozan to surface. SD pump wi 20 bbls biozan on BS and 20 bbls in CT 15:15·15:30 0.25 ZONISO P DECOMP Incr whp to 3000 psi and monitor while mix another 40 bbls biozan. Lost 125 psi 15:30 - 16:10 0.67 ZONISO P DECOMP RIH 1.0 bpm at 100'/min holding 600-800 psi whp while diluting cement wi 20 bbls biozan, 20 bbls 1% KCI, 40 bbls biozan to 8910'. See actual TOC at 5400' 16:10 - 16:45 0.58 ZONISO P DECOMP Red RIH speed to 50'/min at 1.0/2700 and bleed whp to zero when at 8200' and getting 10.7 ppg returns (have 40 min left on TT). Clean out to initial 8900' and still have full returns. PUH while kill time and getting 11.3-11.9 ppg KCI contaminated cement back. RBIH at 1.0/2200 and clean out to 8910' wi full returns IA 485, OA 365 16:45 - 18:00 1.25 ZONISO P DECOMP POH jetting 1.57/1730 wi full returns Printed: 6/5/2006 11 :48:03 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-16 L5-16 WORKOVER NORDIC CALISTA NORDIC 2 Start: 5/12/2006 Rig Release: 6/1/2006 Rig Number: Spud Date: 5/12/2006 End: 6/1/2006 5/14/2006 18:00 - 18:35 0.58 ZONISO P DECOMP LD cementing BHA. PU swizzle stick. 18:35 - 20:00 1.42 ZONISO P DECOMP Cleanout 7-1/16" BOP stack. Circulate all choke manifold flow paths. 20:00 - 22:30 2.50 ZONISO P DECOMP Mix bleach and corrosion inhibitor. Pickle coil and blowdown with N2. 22:30 - 00:00 1.50 ZOINISO P DECOMP Prep coil to pull back and secure to reel. 5/15/2006 00:00 - 01 :00 1.00 ZONISO P DECOMP Pull back and secure 2" coil to reel. 01 :00 - 01 :45 0.75 PULL P DECOMP Wait on SWS for jet cutter 01 :45 - 02:00 0.25 PULL P DECOMP PJSM with SWS and crews. Review RU plans and procedures. 02:00 - 03:15 1.25 PULL P DECOMP RU SWS. 03:15 - 04:50 1.58 PULL P DECOMP RIH with 2.5" Jet Cutter and CCL. Log on depth useing Tubing Tally. On depth at 8785' in the middle of the first full joint above the packer. Fire Jet Cutter. Good indication on surface. POH 04:50 - 06:00 1.17 PULL P DECOMP RD SWS. 06:00 - 07:45 1.75 PULL P DECOMP RU to circulate the FP fluids from the IA IAP=300, OA 100 07:45 - 14:00 6.25 PULL P DECOMP Begin circulating fresh 1 % KCI down the tubing taking fluid and gassy returns from the IA to the tiger tank. After 70 bbls pumped at avg 1.3/1350 psi the lAP slowly rose to 470 psi and had minimal returns. Sort out the situation, blow down the TT lines, have a PJSM. Determine it must be hydrates just downstream of IA valve. Notify DSO of venting. Open back up to IA at 470 psi and bleed straight gas to TT. Resume pumping KCI down the tubing at 1.5-3.0 bpm and circulate all gas out until good fluid returns while empty pits of clean KCI in the process for rig move. Pumped a total of 313 bbls. Also, PT sqz at 1250 psi for 5 min and held, okay, both sides. OA rose 100 psi to 450 psi during pump ops. Bleed OA to 45 psi. Blow down lines 14:00 - 15:50 1.83 WHSUR P DECOMP ND tree scaffold so FMC could test packoff. NU same. Set BPV in tubing hanger profile at 27.5' RKB and test from below at 470 psi. Drain stack. Bleed off pressure. Dump TRSSSV 15:50·16:00 0.17 WHSUR P DECOMP Safety mtg re: ND BOPE, ND tree 16:00 - 20:45 4.75 WHSUR P DECOMP ND 7-1/16" BOPE. Crew change. Review plan forward. ND 3-1/2" tree as one piece. Secure in cellar. Secure blocks. 20:45 - 22:30 1.75 WHSUR P DECOMP THA review plan for backing off well. Back off well enough to drop BOP stack and tree. 22:30 - 22:45 0.25 WHSUR P DECOMP PJSM review plans and hazards for pulling over well. 22:45 - 23:30 0.75 WHSUR P DECOMP Move back on well and level rig. 23:30 - 00:00 0.50 BOPSU P DECOMP NU 13-5/8" BOP's 5/16/2006 00:00 - 05:00 5.00 BOPSU P DECOMP NU 11" x 13-5/8" DSA and 13-5/8" BOP's. Gave AOGCC 2hr notice. 05:00 - 06:30 1.50 BOPSU DECOMP Shell test stack. Leak on kill HCR. Repair retest. AOGCC witnessing waived by Chuck Sheave 06:30 - 09:30 3.00 BOPSU DECOMP Hydraulic leak found on top of bag. Continue and complete choke manifold test and blind ram test 09:30 - 15:30 6.00 BOPSU SFAL DECOMP ND riser. Remove top flange from annular and replace o-ring seal. MIRU 45T crane and load HES spooler onto floor 15:30 - 18:00 2.50 BOPSU DECOMP Continue with BOP test. 18:00 - 19:10 1.17 BOPSU DECOMP Pull FMC blanking plug. 19:10-19:25 0.25 BOPSU DECOMP PJSM Re: Pulling BPV. 19:25 - 19:50 0.42 BOPSU DECOMP Check IA for flow. No flow. 19:50 - 20:50 1.00 BOPSU DECOMP Attempt to pull BPV. No recovery. Redress pulling tool with Printed: 6/5/2006 11 :48:03 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-16 L5-16 WORKOVER NORDIC CALISTA NORDIC 2 Start: 5/12/2006 Rig Release: 6/1/2006 Rig Number: Spud Date: 5/12/2006 End: 6/1/2006 fresh grapple and attempt to pull again. No recovery. WAIT Wait while valve crew goes back to valve shop to get fresh dressed pulling tool. Make up landing joint on catwalk while we wait. 21 :45 - 22:05 0.33 DECOMP Rig up brand new pulling tool. Attempt to pull BPV. No recovery. 22:05 - 22:30 0.42 DECOMP Possibly debris on seat preventing pulling tool from seating all the way. Rig up nozzle on joint of PH6. Set down on top of BPV and circulate. 22:30 - 22:40 0.17 BOPSU DECOMP Rig up new pulling tool again. Recover BPV. (Whew) 22:40 - 23:15 0.58 PULL DECOMP PU landing jt. MU to tubing hanger. 7 turns LH to make up. 23:15 - 23:45 0.50 PULL DECOMP PJSM Re: LDS, picking up on pipe and circulating. 23:45 - 00:00 0.25 PULL DECOMP BOLDS. 5/17/2006 00:00 - 00:45 0.75 PULL DECOMP Continue to back out LDS. 00:45·01:05 0.33 PULL DECOMP Pull tubing hanger to rig floor. Took 95 klbs to pick up off seat, and pulled smoothly at 70 klbs afterwards. Clean pickup with no problems. 01:05 - 03:15 2.17 PULL P DECOMP Circulate 1.5 round trips to ensure hole is clean. Pumping at 6 bpm, 250 psi. 03:15 - 03:40 0.42 PULL P DECOMP Stop circulation, check for flow. None observed. While flow checking, hold PJSM to discuss rigging up spooling unit, laying down landing joint and preparing to pull tubing. 03:40 - 04:40 1.00 PULL P DECOMP Rig up HES spooling unit. Lay down landing joint and tubing hanger. 04:40 - 06:00 1.33 PULL P DECOMP Pull 3-1/2" IPC tubing. Pulling easy at 70 klbs. 06:00 . 06: 15 0.25 PULL P DECOMP PJSM/THA crew change. Review work ahead. Assign job tasks. Review hazards, pinch points, overhead loads on the rig floor. Review skate operations and hazards. 06:15 - 18:00 11.75 PULL P DECOMP LD first 72 jts. LD SSSV. Continue LD tbg and GLM's. On jt #160 of 287 at 1630 18:00 - 18:20 0.33 PULL P DECOMP PJSM with night crew to review pulling tubing. 18:20 - 23:15 4.92 PULL P DECOMP Continue pulling tubing. On joint 180 at 18:00 hrs. 23:15 - 00:00 0.75 PULL P DECOMP Recovered all expected jts of tubing OOH. Recovered tubing stub. Tubing stub length = 12.87'. OD +/- 4.0". Cut was a little egg shaped. (Photos emailed to town). 16' of pipe left in hole. Cut appears to be exactly where SLB said they cut it. Lay down miscelanious jts from the driller side of the pipe shed. (2" PH6, landing jt, etc) 5/18/2006 00:00 - 02:15 2.25 FISH P DECOMP Continue laying out miscelanious tubing from pipe shed. Pick up kelly swivel onto rig floor. 02:15 - 06:00 3.75 FISH P DECOMP Start loading pipe shed with 300 jts of 3-1/2" drillpipe. 06:00 - 06:15 0.25 FISH P DECOMP Crew change PJSM/THA's in pipe shed and indentify and discuss possible hazards, pinch point, elevator operations. 06:15 - 13:00 6.75 FISH P DECOMP Contiune loading pipe shed with 3-1/2" DP 168jts of 300 in. 13:00 - 13:30 0.50 FISH P DECOMP Set wear bushing 13:30 - 16:30 3.00 FISH P DECOMP Make up BHA #1, Mill guide and overshot to recover tubing stub. 16:30 - 18:00 1.50 FISH P DECOMP Trip in the hole with drill collars. 18:00 - 18:30 0.50 FISH P DECOMP Hold PJSM with night tour to discuss plans forward for tripping pipe and making up swivel and kelly. 18:30 - 20:00 1.50 FISH P DECOMP Pick up 3-1/2" DP singles until we get 30 klbs string weight. 20:00 . 20:20 0.33 FISH P DECOMP PJSM Re: picking up swivel and kelly. 20:20 - 00:00 3.67 FISH P DECOMP PU swivel and kelly. MU kelly hose. MU all jts to correct Printed: 6/5/2006 11 :48:03 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-16 L5-1 6 WORKOVER NORDIC CALISTA NORDIC 2 Start: 5/12/2006 Rig Release: 6/1/2006 Rig Number: Spud Date: 5/12/2006 End: 6/1/2006 5/18/2006 20:20 - 00:00 3.67 FISH P DECOMP torque. Kelly bushing rusted up. Had to spend 1 hour freeing it up. 5/19/2006 00:00 - 03:15 3.25 FISH DECOMP Rig up kelly hose to standpipe. Put oil in swivel. PT kelly hose and kelly valve. Pick up kelly sock. Break out kelly and stand back in sock. 03:15 - 06:00 2.75 FISH DECOMP Resume TIH with BHA #1. Picking singles up out of pipe shed. Dropping drift thru each joint as picked up. 06:00 - 06:30 0.50 FISH DECOMP PJSM Re: Picking up DP and TIH. 06:30 - 12:30 6.00 FISH DECOMP Resume TIH with BHA #1. Picking singles up out of pipe shed. Dropping drift thru each joint as picked up. 12:30 - 13:00 0.50 FISH DECOMP PJSM Re: Picking up the Kelly. 13:00 - 14:30 1.50 FISH DECOMP Pickup Kelly. Establish up and down wts. 122 klbs up, 115 klbs down, 118 klbs @ 30 RPM. Circ at 3 bpm, 380 psi. 14:30 - 18:00 3.50 FISH DECOMP Mill down over fish. Tagged top of tubing stub at 8779'. Engauge fish with mill. Not getting much torque. Tubing stub appears to be spinning in seal assembly. Work it up and down try very light weight, and it still seems to spin. Try it with low pump rates to try and heat it up and get it to lock up. Finally made an additional 3', but don't think that it is engaged in the overshot yet. May have a friction bite on it. Stack out wt 3 times trying to jam it up in the overshot. Order out a spear from Baker fishing just in case. 18:00 . 18:30 0.50 FISH DECOMP PJSM with night tour Re: standing back the kelly and tripping OOH. 18:30 - 19:30 1.00 FISH DECOMP Blow down the kelly and stand back in the kelly sock. 19:30 . 00:00 4.50 FISH DECOMP Trip OOH standing back doubles. 5/20/2006 00:00 - 01 :30 1.50 FISH P DECOMP Continue TOH with BHA #1. Standing back doubles. 01 :30 - 03:30 2.00 FISH P DECOMP Break down BHA #1. Got successful recovery of first fish. Recovered remaining 16' of cut joint, pup jt, and seal assembly. 03:30 - 05:00 1.50 FISH P DECOMP Make up BHA #2, Spear to recover Brown HB packer. 05:00 . 06:00 1.00 FISH P DECOMP Trip in the hole with 3-1/2" Drillpipe. 06:00 - 06:30 0.50 FISH P DECOMP Crew C/O PJSM on RIH,Service rig (Lub) 06:30 - 14:30 8.00 FISH P DECOMP RIH with stds 3 1/2" DP & BHA to 8780' 14:30 - 15:00 0.50 FISH P DECOMP PU Kelly 115K up I 106K dn I 108K r @ 30 RPM 4000' Ibs torque 15:00 - 16:00 1.00 FISH P DECOMP Attemp to work into fish, unsuccessful even thou it seemed to be going into the PBR it would not "bite" 16:00 - 16:30 0.50 FISH P DECOMP PJSM on standing back Kelly and POOH w/DP. BDSBK and RU to POOH 16:30 - 00:00 7.50 FISH P DECOMP POOH with DP and BHA 5/21/2006 00:00 - 01 :00 1.00 FISH P DECOMP Lay down spear from BHA #2. Pick up new spear. 01 :00 - 06:00 5.00 FISH P DECOMP TIH with BHA #3; Spear fishing assembly for recovering packer. 06:00 - 07:00 1.00 FISH P DECOMP Crew C/O, PJSM, Service rig (Iub) 07:00 - 09:00 2.00 FISH P DECOMP Con't RIH w/BHA #3 to 8755' 09:00 - 09:30 0.50 FISH P DECOMP PU/MU Kelly and Break Circ, Establish weights 104K up I 98K down 11 OOK rotating @ 30 RPM 4000' Ibs torque 09:30 - 09:45 0.25 FISH P DECOMP Tag TOF @ 8789', Engage spear and PKR released wi 53K over pull (157K) 09:45 - 10:00 0.25 FISH P DECOMP Let PKR elements rest I relax 10:00· 11 :05 1.08 FISH P DECOMP CBU @ 3 BPM 600psi, Gas to surface 11 :05 - 11 :45 0.67 FISH P DECOMP Circ 1 BPM thru Poorboy Degasser until 0 gas returns Printed: 6/512006 11 :48:03 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-16 L5-1 6 WORKOVER NORDIC CALISTA NORDIC 2 Start: 5/12/2006 Rig Release: 6/1/2006 Rig Number: Spud Date: 5/12/2006 End: 6/1/2006 5/21/2006 11 :45 - 12:00 0.25 FISH P DECOMP Monitor well, 0 flow 12:00 - 13:50 1.83 FISH P DECOMP Open annular and con't CBU @ 3BPM 560psi. Well dead. Standback kelly and blowdown. DP very small flow. 13:50 - 14:15 0.42 FISH P DECOMP Drop bar to open circ sub. RU TIW valve and open circ sub with 2035psi. Well dead. 14:15 - 18:00 3.75 FISH P DECOMP TOH 18:00 - 18:30 0.50 FISH P DECOMP PJSM for tripping pipe OOH. Make pretour spill champion walk around. 18:30 - 21:00 2.50 FISH P DECOMP Resume tripping OOH with BHA #3. 21 :00 - 23:30 2.50 FISH P DECOMP Break down BHA #3. Lay down recovered fish. Recovered all expected fish: PBR-Brown HB Packer-XO-2 Jts 3-1/2" tubing-D Nipple-Pup Jt-WLEG. 23:30 - 00:00 0.50 WHSUR P DECOMP Pull Wear bushing to set blanking plug for BOP test. 5/22/2006 00:00 . 07:30 7.50 WHSUR P DECOMP Set test plug. Perform weekly test of BOPE. 07:30 - 08:30 1.00 CLEAN P DECOMP Adjust drawworks brakes. 08:30 - 08:45 0.25 CLEAN P DECOMP PJSMfTL meeting with crews coming on. (later arrival due to cancelled flights yesterday) Discuss plan forward. 08:45 - 09:30 0.75 CLEAN P DECOMP Put away tools and testing equipment. Remove remaining fish fom pipe shed. 09:30 - 10:00 0.50 CLEAN P DECOMP Set wear bushing. MU BHA #4 with 6-3/4" junk mill, no casing scraper, no boot baskets. 10:00 - 11 :15 1.25 CLEAN P DECOMP PU BHA #4. Bit sub had 3-1/2" IF both ends. Wait 30 min for correct sub. 11 :15 - 19:30 8.25 CLEAN P DECOMP RIH with drill collars and 3-1/2" drillpipe. 19:30 - 20:20 0.83 CLEAN P DECOMP Tag up at 8886'. Expected tag depth was 8910' based on cleanout run made on cement job pumped on 5-14. Suspect a cement stringer. Pick up Kelly to begin milling cement. 20:20 - 22:00 1.67 CLEAN P DECOMP Begin milling cement. Pumping 1.5 ppb biozan. Gelling up seawater returns from the well. Pumping high vis biozan sweeps as needed. Had soft cement 0 8919', then hit hard cement. RIH wt = 100 klbs. Drilling with 20 klbs WOB, 80 klbs string wt. Pumping 5 bpm, 600 psi. 22:00 - 22:30 0.50 CLEAN P DECOMP PJSM with new crew coming on tour. (Late arrival of plane). Discuss current operations, and plan forward. 22:30 - 00:00 1.50 CLEAN P DECOMP Continue milling cement. 5/23/2006 00:00 - 03:00 3.00 CLEAN P DECOMP Continue milling cement from 8950'. Started getting ratty torque and ROP slowed at expected top of coil fish at 8965'. Depth at 03:00 is 9012'. Making +1- 20 fph. Getting metal on ditch magnets and good cement cuttings over shaker screen. 03:00 - 06:00 3.00 CLEAN P DECOMP Continue milling ahead. 06:00 - 07:00 1.00 CLEAN P DECOMP Problems whole kelly torquing up. Increase flowrate from 3bpm to 6.0bpm while off bottom. Circulate and cleanup hole. 07:00 - 12:40 5.67 CLEAN P DECOMP Continued milling to 9044' . Make connection continue milling 10-20k wob and pumping at 6bpm. Short wiper trip every 5'. Ocasional stalling, PU work back to btoom. Pumping 2 sweeps per kelly or as needed. 12:40 - 16:00 3.33 CLEAN P DECOMP Continue milling Milled to 9,127 ft. Lost torque while milling. Tried using 28k WOB with no increase in torque and no ROP. 16:00 - 17:30 1 .50 CLEAN P DECOMP Pumped 20 bbl HV sweep and circulated around. Va = 455 bbl and Vdp = 60 bbl 17:30 - 18:00 0.50 CLEAN P DECOMP SD pumps, stand kelly back and make ready to POOH 18:00-18:15 0.25 CLEAN P DECOMP Hold PJSM to discuss pulling out of hole. 18:15-18:45 0.50 CLEAN P DECOMP Bleed OA from 720 psi to 250 psi. Printed: 6/5/2006 11 :48:03 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-16 L5-16 WORKOVER NORDIC CALISTA NORDIC 2 Start: 5/12/2006 Rig Release: 6/1/2006 Rig Number: Spud Date: 5/12/2006 End: 6/1/2006 5/23/2006 18:45 - 19:30 0.75 CLEAN P DECOMP Pull out of hole with milling assembly. 115k# up wt. Pulling heavy as though there is junk along side BHA. Work pipe. Able to RIH ok. Pull up to 160k#. Not making any progress. At +1-8697'. 19:30 - 21 :00 1.50 CLEAN N DPRB DECOMP LD single. MU kelly. Break circulation. Circulate at 6 bpm at 1100 psi while rotating and working pipe. Alot of metal flakes over shaker with btms up. 21 :00 - 00:00 3.00 CLEAN N DPRB DECOMP Attempt to POH. Hanging up in same location. MU circulating hose. Able to pull out of hole while pumping at 1 bpm. Attempt to pull another single dry. Hanging up. MU hose and circulate another single out. COntinue pulling singles. Hole slowly cleaning up - as junk gets worn down? 5/24/2006 00:00 - 03:30 3.50 CLEAN P DECOMP Continue to POH, dragging junk with BHA. Free up weight: 70k#. Pulling up to 80k# over string wt. Seems to be getting more ratty. 71 jts out = 6861 ft 03:30 - 06:00 2.50 CLEAN N DPRB DECOMP Circulate 47 bbl hi vis bio sweep @ 6861 ft. Work pipe while circulating. Not much from btms up. Once circulation is achived, pipe pulls free. 06:00 - 07:25 1 .42 CLEAN N DPRB DECOMP Crew change, PJSM and service rig. 07:25 - 09:45 2.33 CLEAN N DPRB DECOMP PU kelly and worked mill while cir at 7 bpm. Found that the tight spot is ever 40 ft casing collar. SD pumps and dry drilled at 80 rpm's to remove debris from gauge of mill. With kelly PUH and LD 3 jts in pipe shed. Total of 12 jts LD. Blow down kelly and set back same 09:45 - 11 :00 1.25 CLEAN P DECOMP POOH. Dragging 10k to 20k. Seeing 7-5/8" collars while POOH. Uncorrect hole fill, last 5 stands swabbed in 5 bbl. 11 :00 - 11 :30 0.50 CLEAN N DPRB DECOMP SD and circulated while moving DP. No fluid lost to formation. 11 :30 - 14:30 3.00 CLEAN P DECOMP POOH Pulling good but still seeing collars. Stopped twice to circulate hole after hole filling while POOH was uncorrect. Started pulling ratty with jar usage. Pulling 60k to 80 k over string wt. Stopped at 81/57 stands out/in stds (3990 ft) to circulate. 14:30-16:15 1.75 CLEAN N DPRB DECOMP RU to circulate wellbore. Cir at 7 bpm, mix and pump 48 bbl HV pill YP = 70 . Some metal and cement material cir to surface. 16:15 - 17:50 1 .58 CLEAN P DECOMP POOH clean and correct hole fill. Pull to 2168 ft (110/28 stds) and last 2 stands started pulling 40k to 60 k over string wt and hole fill not correct. 17:50 - 18:30 0.67 CLEAN N DPRB DECOMP SD and RU cir hose. Pumped 50 bbl of 70 YP bio water and circulated around. Not many solids in sweep. 18:30 - 21 :00 2.50 CLEAN P DECOMP Continue to pull stands. Small amount of drag every 40', but pulling smooth overall. 28·30k# up wt. 21 :00 - 23:00 2.00 CLEAN P DECOMP Stand back drill collars, jares, etc. Pull wear bushing to floor on top of mill. Recovered a lot of coil pieces, up to several inches long, most worn paper thin. This likely caused overpulls during trip out. Mill showed a lot of wear, with MM buttons all gone. One nozzle and several water courses on side of mill were plugged. 23:00 - 00:00 1.00 CLEAN P DECOMP Cut and slip drill line. Replace hydraulic hose on draw works at the same same time. 5/25/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP Complete cut and slip drill line. 01 :30 - 04:00 2.50 CLEAN P DECOMP MU milling BHA including drill collars. 04:00 - 06:00 2.00 CLEAN P DECOMP Run in hole with drill pipe. 06:00 - 07:00 1.00 CLEAN P DECOMP Crew change, PJSM and Rig service Printed: 6/512006 11 :48:03 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-16 L5-1 6 WORKOVER NORDIC CAUST A NORDIC 2 Start: 5/12/2006 Rig Release: 6/1/2006 Rig Number: Spud Date: 5/12/2006 End: 6/1/2006 5/25/2006 07:00 - 10:30 3.50 CLEAN P DECOMP RIH with DP Company man had team building session with crew while TIH 10:30 - 01 :30 15.00 CLEAN P DECOMP PU kelly and W IR 8.866 ft to 9,116 ft. Found 2 spots in 250 ft that required extra reaming. 01 :30 - 18:00 16.50 CLEAN P DECOMP Tagged at 9,116 ft. Working to get it to mill, slow to start with severals stalls of rotary at 400 amps. Qp::: 8 bpm at 1,534 psi on bottom. AV::: 235 fpm. Vp::: 254 bbls. Added bio and flo vis to increase YP of mud system. Used LBS as WOB for CROP 18:00 - 21:00 3.00 CLEAN P DECOMP Mill ahead from 9118'. 1550 psiat8 bpm. 140rpm. 0-1k# WOB. PU 20'. 120k# up, 100k# dn wt. Drag junk with mill. Set down slowly. Resume milling. ROP finally icreased to 25-30 fph with 5-6k# WOB. Pump hi-vis sweeps every hour. Lots of cement and metal cuttings in returns. 21 :00 - 00:00 3.00 CLEAN P DECOMP Mill ahead from 9180'. 5/26/2006 00:00 - 01:15 1.25 CLEAN P DECOMP Mill cement and coil to 9200'. 01:15 - 02:15 1.00 CLEAN P DECOMP Pump 47 bbl hi vis sweep. CBU while working pipe. 02:15 - 03:00 0.75 CLEAN P DECOMP Stand back kelly. RU to pull pipe. 03:00 - 06:00 3.00 CLEAN P DECOMP Pull out of hole, standing back doubles. (32 as of 06:00 hrs). Seeing every casing collar at 40' intervals, but not nearly as bad as last trip. 06:00 - 06:45 0.75 CLEAN P DECOMP Crew change, PJSM and rig service 06:45 - 07:22 0.62 CLEAN P DECOMP POOH with DP to 50 stds out Hole fill is not correct. SD and circulated well as before to ensure correct hole fill and reduce the drag through every 7-5/8" collar 07:22 - 07:45 0.38 CLEAN P DECOMP Circulate well 07:45 - 08:30 0.75 CLEAN P DECOMP POOH, but lots better than last trip, still seeing 7-5/8" collars Pulled 8 more stands and drag increased to 60-90k over. 08:30 - 08:45 0.25 CLEAN P DECOMP Circulated BU at 8 bpm. Recovered lots of cement material 08:45 - 12:00 3.25 CLEAN P DECOMP POOH still dragging through 7-5/8" collars somewhat Pulled to 121 stds out of hole, well swabbing in. D= 1580 ft 12:00 - 12:30 0.50 CLEAN P DECOMP Circulate wellbore clean 12:30 - 14:00 1.50 CLEAN P DECOMP POOH 14:00 - 18:00 4.00 CLEAN P DECOMP OOH, standing back DC and BHA. Both junk baskets full of large and small pieces of SLB 1-3/4" CT. Mill was worn and small core in center. Gauged out at 6-3/4". All water cources on mill were plugged with metal. Recovered 1 slip segment from packer along with 3 gal of CT material. MU TSWP connects on rev cir basket with 2 junk baskets and BHA as before. 18:00 - 00:00 6.00 CLEAN P DECOMP RIH with 3·1/2" DP 5/27/2006 00:00 - 02:30 2.50 CLEAN P DECOMP Continue to run in hole with drill pipe. 02:30 - 04:45 2.25 CLEAN P DECOMP MU kelly at stand 135 (8900'). Attempt to circulate. Mud very thick, very difficult to establish circulation. Thin mud at surface and reduce pH. Slowly displace well over to thinned mud. 2,190 psi at 8 bpm. Pressure slowly dropping. 04:45·05:15 0.50 CLEAN P DECOMP Drop ball to reverse basket flow. Circulate ball down to BHA. 05:15 - 08:00 2.75 CLEAN P DECOMP W/R from 8,860 ft to 9,200 ft at Qp = 8 bpm and Pp =2,700 psi in 31 ft intervals with kelly. Tagged bottom at 9,200 ft and cored 1 ft of cement 08:00 - 13:15 5.25 CLEAN P DECOMP Circulate bottoms up (315 bbls) Line out vac trucks to conduct fluid swap to 2% KCL. Turned hole over using 400 bbl of 2% KCL Printed: 6/5/2006 11 :48:03 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-1 6 L5-16 WORKOVER NORDIC CALISTA NORDIC 2 Start: 5/12/2006 Rig Release: 6/1/2006 Rig Number: Spud Date: 5/12/2006 End: 6/1/2006 5/27/2006 13:15 - 17:45 4.50 CLEAN P DECOMP POOH, clean trip and hole fill is correct. 17:45 - 21 :00 3.25 CLEAN P DECOMP Stand back collars. LD BHA. Clean out baskets. Recover 3-4 gals of med to large coil metal pieces. 21:00 -21:15 0.25 EV AL P DECOMP PJSM with SLB and Nordic team to discuss logging job. Review hazards, procedures, roles and responsibilities. 21:15 - 22:15 1.00 EVAL P DECOMP Rig up SLB e-line. Arrange sheaves to avoid kelly hose and another rig components. 22:15 - 00:00 1.75 EVAL P DECOMP Run 6.75" GR/JB. Hanging up just below wear bushing. PU and run a 6.5" od GR/JB. 5/28/2006 00:00 - 00:30 0.50 EVAL P DECOMP Run 6.5" gr/jb. Tag at 9208' e-line. Recover 1 gal metal chunks. 00:30 - 01 :30 1.00 EVAL P DECOMP Re-run gr/jb. Tag TD. POH. Recover a half cup of metal. Call it good. 01 :30 - 04:00 2.50 EVAL P DECOMP MU USIT tool. Run in hole. Log tie in. Log from 9150' to 8400'. Repeat. Pull out of hole. 04:00 - 05:00 1.00 EVAL P DECOMP Rig down SLB loggers. 05:00 - 06:00 1.00 CASE P RUNPRD Load pipe shed with 4-1/2" liner and hanger 06:00 - 09:00 3.00 CASE P RUNPRD Prep 4-1/2" liner. Intalled 6-1/2" X 4-1/2" centralizers. Make ready to run same. 09:00 - 11 :00 2.00 CASE P RUNPRD Run 4-1/2" Scab liner as per design Ref to Scab Liner Summary for Collars and Centralizer placement 11:00 -11:15 0.25 CASE P RUNPRD Make ready to run DP 11:15 -17:30 6.25 CASE P RUNPRD RIH and fill every 25 stds DP and drift every stands to 2.4 in Presently conducting well prep for L5-28, removing well house and s-riser Crew change at 12:00 hrs. 17:30 - 18:00 0.50 CASE P RUNPRD Ran 75 tds DP, filled drill pipe and moved DC to driller off side. 18:00 - 18:30 0.50 CASE P RUNPRD Crew change, PJSM and rig service 18:30 - 19:00 0.50 CASE P RUNPRD Bring dp pup and cementing head to rig floor. 19:00 - 23:00 4.00 CASE P RUNPRD Continue to run in hole with liner on drill pipe. 23:00 - 00:00 1.00 CASE P RUNPRD Rig up cementing head and reversing ling line. 5/29/2006 00:00 - 00:15 0.25 CASE P RUNPRD Complete make up of cementing head. Make up reversing line on floor. 00:15 - 00:30 0.25 CASE P RUNPRD Hold PJSM with SLB cement crew and Nordic rig team. Discuss safety issues, job procedures, clean up procedures. 00:30 - 01 :00 0.50 CASE P RUNPRD Circulate well. Pressure test lines to 4500 psi. Ok. 01:00-01:15 0.25 CEMT P RUNPRD Batch mix 25 bbls 15.8 ppg Class G cement wI additives as per well plan. Circulate well at 1.0 bpm at 105 psi while batching. 01 :15 - 02:00 0.75 CEMT P RUNPRD Pump 20 bbls cement. Clean up lines. Drop dart. Displace with KCL water using SLB pumpers. 3 bpm at 288 psi once we caught up to cement. Dart latched and plug sheared at 59 bbls away. (1700 psi). Bump plug at 63.5 bbls at 2800 psi. Set hanger. Slack off 44k# on liner. Pressure liner to 4200 psi to set liner top packer. Bleed bac. Floats holding. CIP at 13:40. Liner top set at 8802 ELM. Liner btm at 9206' ELM (2' off btm). 4-1/2" liner length: 403.01' 02:00 - 02:30 0.50 CASE P RUNPRD Turn dp to right 20 turns at neutral wt. Pressure liner to 1000 psi. PU to unsting from liner. Circulate forward to push cement up hole. 02:30 - 02:45 0.25 CASE P RUNPRD Close annular. Attempt to reverse out excess cement. WHP up to 3500 psi at 0.5 bpm. Something is plugged off. Bleed pressure and RU to circulate long way. Printed: 6/5/2006 11 :48:03 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-1 6 L5-16 WORKOVER NORDIC CALISTA NORDIC 2 Start: 5/12/2006 Rig Release: 6/1/2006 Rig Number: Spud Date: 5/12/2006 End: 6/1/2006 5/29/2006 02:45 - 04:30 1.75 CASE P RUNPRD Circulate down drill pipe at 6 bpm at 2500 psi. CBU. Pump a 50 bbls 2# bio sweep. CBU a second time. Monitor retunrs for excess cement. Treat same for pH and add retarder as returns enter cuttings box. Cement very strung out in rtns. Not able to estimate volume. 04:30 - 06:00 1.50 CASE P RUNPRD Set 20k# on liner to verify set. Rig down cementing head and circ lines. 06:00 - 06:15 0.25 CASE P RUNPRD Crew change, PJSM and Rig Services. 06:15 - 13:00 6.75 CASE P RUNPRD POOH and LD 130 jts 3-1/2" DP in preparation of rig move. 13:00 - 15:30 2.50 CASE P RUNPRD POOH and stand 80 stds DP in derrick. 15:30 - 16:00 0.50 CASE P RUNPRD LD BOT LRT and inspected, looks OK, no debris in running tool. 16:00 - 16:15 0.25 CASE P RUNPRD Held PJSM with WL and Nordic crews and discussed the Hazards associated with RU and running the GR. 16:15 - 17:00 0.75 EVAL P RUNPRD RU WL with 6-5/8" GR and junk basket with tools string. 17:00 - 19:00 2.00 EVAL P RUNPRD RIH with 6-5/8" GR to 8800 ft. Tagged at 8804 ft. POOH 19:00 - 19:30 0.50 EVAL P RUNPRD Rig down SLB slickline unit. Call AOGCC. Waiver for BOP test granted due to well condition (no open perfs, cemented liner) and pending completion. 19:30 - 00:00 4.50 RUNCO P RUNCMP Load pipe shed with 4-1/2" IBT L-80 tbg. Load control line spooler. Load all completion jewelry. Sim ops: Pull wear bushing. Set test plug. Open BOP ram doors to clean out any metal or cement behind rams. 5/30/2006 00:00 - 06:00 6.00 RUNCO P RUNCMP Continue to load pipe shed with 4-1/2" tubing. Drift and strap same. Body test BOPs to 300 psi and 3500 psi. Pull test plug. Test 7-5/8" casing to 3500 psi for 10 minutes. Good test. Rig up floor to run completion. 06:00 - 06:30 0.50 RUNCO RUNCMP Crew change and PJSM 06:30 - 08:15 1.75 RUNCO RUNCMP Finish loading pipe shed and prep last 17 jts of 4-1/2" Make ready to run completion 08:15 - 09:00 0.75 RUNCO RUNCMP Held PJSM with crew on PU and running 4-1/2" tieback 09:00 - 11 :00 2.00 RUNCO SFAL RUNCMP While MU 1 st jt of 4-1/2" lost the hydraulic rig tongs. Called and had Nabors bing set 4-1/2" tongs. Re-building rig tongs. 11 :00 - 21 :00 10.00 RUNCO RUNCMP Picking up and running 4-1/2" tubulars. Run 155 joints 4-1/2" 12.6# L-80 IBT tubing w/ packer and GLM's 21 :00 - 00:00 3.00 RUNCO RUNCMP MU HES TRSSSV assy. Connect control line and PT 5000 psi. Continue running 4-1/2" tubing and banding CL w/ SS bands 5/31/2006 00:00 - 02:00 2.00 RUNCO RUNCMP Finish MU 4-1/2" tubing 02:00 - 03:15 1.25 RUNCO RUNCMP MU jt #208 w/ circ head. RIH circ 2.0/60 psi and tag at 8796' which is the TOL. Need to go 11' more to bottom out. Put 1/2 turn into string downhole and tag at the same spot. Discuss. Will RU slickline to drift and possibly memory log 03:15 - 05:15 2.00 RUNCO RUNCMP While WO slickline, MU spaceout pups and joint #206. Add landing joint (#207) and set in slips 2.5' above TOL to mirror final completion 05:15 - 06:15 1.00 RUNCO RUNCMP While WO slickline, RU to circ. 06:15 - 07:30 1.25 RUNCO SFAL RUNCMP Vac truck developed a leak. Unable to proceed with displacement to corrosion inhibitor. 07:30 - 08:15 0.75 RUNCO RUNCMP Rig up SLB slickline. Hold PJSM to discuss safety and procedures. Spot unit and rig up slickline. 08:15 -11:30 3.25 RUNCO RUNCMP Run in hole. Recover RHC plug. Pull out of hole. Well Printed: 6/512006 11 :48:03 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13:30 - 17:00 17:00 - 19:15 19:15 - 21:30 21 :30 - 00:00 6/1/2006 00:00 - 03:00 L5-16 L5-1 6 WORKOVER NORDIC CALISTA NORDIC 2 2.25 2.25 2.50 Start: 5/12/2006 Rig Release: 6/1/2006 Rig Number: Spud Date: 5/12/2006 End: 6/1/2006 swabbing. Having to pull out slowly. Run 3.75" centralizer style drift. Through liner top ok. Tag up at 8860'. PU heavy. Run back in hole. Set down at 8840'. This is 38' below the liner top. Suspect cement sheath or stringer. Pull out of hole. RUNCMP Run PDS GR/CLL memory log. Tag btm at 9046'. Log up hole to 8400'. Pull out of hole. Down load data. Tie GR into original CBL. SUbtract 3' correction. Evaluate CCL character. Determine that WLEG is fully stung into liner tie back sleeve. RUNCMP Run RHC plug back in hole on slcikline. Set at 8748'. Pull out of hole. RDMO SWS slickline unit RUNCMP LD temporary landing joint. MU hanger on landing joint. Hook up CL line. Land hanger at 25.6' BKB w/ 94k up, 78k hanging. RILDS Used 206 jts 4-1/2" 12.6# L-80 IBTM tubing and 53 SS bands RUNCMP RU to reverse. Reverse in 290 bbls corrosion inhibitor at 3.0/280 RUNCMP Drop ball-on-rod to RHC plug. PT tubing to 3500 psi for 30 min. Bleed off press to 1500 psi. PT IA to 3500 psi for 30 min. Bleed off tubing pressure to zero and see DCK shear at 2500 psi. Pump 2 bbls both directions to verify clear. Close TRSSSV and PT from below to 1000 psi for 10 min. Bleed off all pressures. Back out landing jt Safety mtg re: skid out BOP. Chugger stack. Open TRSSSV and set TWC. PT from below at 500 psi ND 13-5/8" BOPE Crew change and PJSM for skidding BOPs from cellar. Finsih ND BOPs. Skid same out back of cellar on trolley. Prep control line above hanger. NU master valve tree assembly. Test same to 5000 psi. Master valve leaking. Order replacement from BP Stores. NU new master valve. Test same to 5000 psi. RU DSM lubricator. Pull two way check valve. Ru tree and cellar lines to pump diesel freeze protect. Hold PJSM with Little Red. Pump thru sheared DCK valve w/ 100 bbls diesel down the IA. 3 bpm at 1300 psi. Take returns up tbg. Pump 110 bbls. U-tube diesel back into tbg. RDMO LRS POST RD circ lines. Close TRSSSV. Secure master and tree cap Prep to move Rig Released at 2030 hrs 6/1/2006 Further entries for 6/1/06 will be found under L5-28 03:00 - 03:45 0.75 BOPSU RUNCMP 03:45 - 06:00 2.25 BOPSU RUNCMP 06:00 - 06:30 0.50 BOPSU RUNCMP 06:30 - 07:30 1.00 BOPSU P RUNCMP 07:30 - 11 :30 4.00 WHSUR P RUNCMP 11 :30 - 14:00 2.50 WHSUR N RUNCMP 14:00 - 15:30 1.50 WHSUR P RUNCMP 15:30 - 16:15 0.75 WHSUR P RUNCMP 16:15 - 18:45 2.50 WHSUR P POST 18:45 - 20:30 1.75 RIGD P Printed: 6/5/2006 11 :48:03 AM Nipple in upper packer L5-1 : Window 4 1/2" X Nipple - 8664' MD 4 1/2" 12.6#, L-80, 1ST-Mod. Tbg. x 7 5/8" 4 112" X Nipple- Liner Hanger/Packer 8802' MD 6AL2:Window MD Guidestock Tray (See Detail Attached) ,2.31" ID MD Lower KB packer XN Nipple in KB packer 8973', 6A:Window MD 4 1/2" 12.6#, L-80, . . RECEIVED WELL LOG TRANSMITTAL AUG 2 9 2006 PROACTIVE DiAGNOSTIC SERvicES, INC. I\IðSka 011 & Gas Cons. Commission Anchorage To: State of Alaska - AOGCC. Attn: Helen J. Warman 333 W. 7th Ave. Suite 1 00 Anchorage. Alaska 99501 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to : ProActive Diagnositc Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 - 8952 L5 - 1 6 1 J 2) 3J 4J 5J 6J 7J Jewelry Log 31-May-06 ~(ìANNED AUG 3 0 2.005 Print Name: czLL--~ c.¡t()5HVl~ ~.el,1 Date: if 8O,! (k) Signed : PRoACTivE DiAGNOSTic SERvicES, INC., I ~o W. INTERNATioNAl AiRpoRT Rd SUiTE C, ANcl-tORAGE, AK 99'; 18 Pl-tONE: (907)24';;89'; I fAx: (907)24';;89';2 E;MAil: IldsANd!QnA(A~@M~M(mylQfj,q)M WEbsirE: MEMOrtylo<j.COM rt1-o l~ ¡i l'-IOfo T C:\My Documents\ W ork\ DistributionLablesN ew\ Transmit_Original. doc SChlumterger RECEIVED Alaska Data & ConSulting Services 2525 Gambell Street, Suite 400 AnChorage. AK 99503-2838 A TTN: 8eth JUN 0 8 2006 ~~ Cil & Gas Ccns. Commisslcn" ,,' "_. - Andlcmge3C)ìJ'\~PfEL) 06/01/06 NO. 3828 Cj Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage. AK 99501 , ( 1 Field: PrUdhoe Bay t <ò 1" 0 Well Job# Log Description Date BL Color CO I P2~Z2 1'-')-'"+ -d~ 11f36744 fGlS- 11/!J/05 1 IP2-16 c.~ - I;::J:~ 1105823~ /WFC 08/f8/05 1 P2-36 ¡ C¡'? - I~O N/A LoL 07/13/05 1 P2-50B "0,.<)- - O<7(~ N/A LoL 07/16/05 1 16-03 l~-I -c' " 11076454 INJECTION PROFILE 07/28/05 1 P2-36 FCit- -/ .aÒ 11051061 GLS/LoL 06/15/05 1 4-18/S-30 J-'r;':"- - ! /6 10564459 PSP GLS 04/18/03 1 1-33B/L_24 I q '?r _ ~~') 10889175 SCMT 10/12/04 1 04-41A IC1~ -D~-:<) N/A LoL 07/18/05 1 15-o9A 103 -C~~ N/A OIL PHASE BOTTOM HOLE SAMPLE 02102/05 1 09-17 T~ _(;:~ <;( 11076460 INJECTION PROFilE 08/18/05 1 16-o9A 'C¡-I-/)~~ )¡( 11051089 PRODUCTION LOG W/oEFT 08/18/05 1 16-11 1'5<;" -11'k- 11058249 LDL 09/14/05 1 17-02 I "ð () - 01-0 N/A SENSA MEMORY LoL 10/17/05 1 NK-38A .004 -/J~/ J 10687734 MDT 02/27/05 1 R-35 iC¡<:-/1f- 11212863 USIT OS/26/06 1 D-09A I '7<::;- -0:; ";<; - 11221576 USIT OS/27/06 1 L5-16 i--'?r'1 -nil; 11212864 US/T OS/28/06 1 K-oBA ;::)~).~ -. il../~) 11054182 MCNL -'F ì:-=<; --,..¡q ;.:l- 06/06/05 1 1 H-04A -')6~ ._/(/_/ 10715365 MCNL #" i'~ 'ŸCZf 7i 11/27/03 1 1 e e Petrotechnical Data Center lR2.1 900 E. Benson Blvd. Anchorage, Alaska 99508 /1 /. (~,I/ ! ¡ !/ ¡ / l.!.:¡ I ~jv Alaska Data & ConSultlOg ServIces 2525 Gambell Street, Suite 400 AnChorage, AK 99503-2638 ATTN: Seth 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: IjJ_n...r.~~gg@_,ªgf.Elf.t??tªtfU~_~JJ_~ ªº9.ç.~~mQn!.~twg..'þ'.ª.y.@.f!~i}IÜf.U~tªA~_,ªt_<¿2 þgJL.ngÇ_~!;m~.t~jn@_,ªgfX.ÜLt?.tªtfuh,!A~ Contractor: Nordic Rig No.: 2 DATE: 5/14/06 Rig Rep.: Mckeirnan / Sloan Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Sevcik/Feketi E-MaiI2.\!.ª~t{1.fAr.tnX!.Œ:g1~~;?t~~º!P!A~_b~~r@A!k\_G!:!J Well Name: L5-16 PTD # 187-019 Operation: Drlg: Test: Initial: XXX Test Pressure: Rams: 250-3500 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Stripper Annular Preventer #1 Rams #2 Rams #3 Rams #4 Rams #5 Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quantity 1 1 1 1 1 1 Workover: XXX Weekly: Annular: 250-2500 TEST DATA Test Result P P P Explor. : Bi-Weekly Valves: 250-3500 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly NT Lower Kelly NT Ball Type 1 P Inside BOP NT Well Sign Dr!. Rig Hazard Sec. Size/Type 2" 1 2 1 N/A Blind / Shear 2" Combi 2 3/8 Combi 2" Combi N/A 31/8'\ 3 1/8" 3 1/8" N/A CHOKE MANIFOLD: Quantity Test Result No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P Test Result P NA FP P P P NA P P P NA MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Visual P P P P P Alarm P P P P P Quantity Inside Reel valves 1 Test Result P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 2400 P 200 psi Attained :25 P Full Pressure Attained 1:10 P Blind Switch Covers: All stations Y Nitgn. Bottles (avg): 4@ 2150 Test Results Number of Failures: º Test Time: ~ Hours Components tested 27 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: .l1f.nmr.~!gg@_ªg¡r3.ln,??tªtfU:A~JJ.~ Remarks: Annular not used due to service operation Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector Coil Tubing BFL 11/09/04 YES Date Test start 24 HOUR NOTICE GIVEN NO 5/13/06 Time 01 :00 Finish x Waived By Chuck Scheve 16:00 Witness Feketi / Daniell 05: t..:'(' J., IJ\~ ~\:¡J~\1NED FEB 2 6 2007 Nordic 2 BOP 5-14-06.xls L5-16 Sundry 306-120 e e t f»l-~,..:t, Subject: L5-16 Sundry 306-120 From: "Stagg, Ted 0 (ORBIS)" <Ted.Stagg@bp.com> Date: Thu, 13 Apr 200614:53:22 -0800 To: Wînton Aubert <wînton_aubert@admin.state.ak.us> Winton, I received an approved Sundry Notice for the workover on L5-16 that will prepare the well for multi-Iat UBCTD soon. Since receipt of the Sundry Notice we have re-evaluated the workover procedure and wish to make the following change. The CIBP that was to be set at 9,250 ft MD following tubing and packer removal will not be set. Instead, the entire perforated interval, from top of fill to the top perforation, will be cement squeezed by service coil prior to the rig workover. This change is requested to improve conditions for achieving a high quality cement squeeze of behind pipe channels. A revised summary of operations is as follows: Pre-Rig Work Completed: 1. S 2. S Tagged TD @ 9,280' wI 2.50" cent on 3/5/06 SBHP on 3/6/06 measured 3,168 psi at 8900ss with 165 deg. F. :¿¡~AJ¡'\1~~~[' f~ Pre-Rig Work to be Done: 1. 0 2. 0 3. S 4. C 5. 0 6. E 7. 0 8. 0 9. 0 MIT-IA and MIT-OA. Purge CIV control line. Kill well with 2%KCI and note injection rates and pressures. Tag TD to confirm depth of fill (optional... recent tag may be good enough). Cement squeeze all perfs above fill. PPPOT-T & IC. Function lockdown screws. Drift tubing for jet cut. Jet cut 3-1/2" tubing in first full joint above the packer at 8,785' MD. Load well bore with 2% KCI brine (circ thru jet cut). FP tubing and IA. Bleed tubing, IA and OA to 0 psi. Install BPV. Remove wellhouse, flowline, AL line and level pad for Nordic 2. Nordic 2 CTD RWO Summary Procedure (info only) 1. RU Nordic 2. NU and test BOPE. 2. Pull 3 %" L-80 tubing above cut. 3. PU drill pipe. Recover seals, packer and tailpipe. 4. Make bit and scraper trip to ensure 7 5/8" casing is clean for scab liner. 5. Run 4 W', 12.6#, L-80, IBT-Mod scab liner (-9250 to 8800') and cement. PT to 3000 psi. 6. Run 4-1/2", 12.6#, L-80 tubing with TRSSSV, 5 GLM's, packer. Set packer and test. 7. Slickline: RU slickline & pull B&R/RHC plug. Drift to PBTD for whipstock and run memory GR/CCL across 4 W' scab liner. 8. Set TWC. ND BOPE. NU tree and test. Pull TWC. FP tubing and IA. RD Nordic 2 and move to L5-28 for RWO and UBCTD sidetrack. Please contact me or Greg Sarber for questions. Ted Stagg 564-4694 or cell 240-8074 Greg Sarber 564-4330 or cell 242-8000 1 of 1 4/13/2006 3:05 PM L5-16 eIBP depth e e I 17 ~ 0 I q Winton, Thank you for pointing out that the proposed CIBP depth for the L5-16 workover is out of compliance with 20ACC25.112. The CIBP setting depth of 9250' MD is requested due to the current top of fill at 9310' MD. The proposed CIBP depth of 9250' MD would be 60 feet above top of fill and118 feet above the deepest set of existing perforations. A primary objective of the scab liner to be installed immediately above the subject CIBP is to provide the means to most effectively squeeze off all remaining perforations and associated behind pipe channels in preparation for an upcoming multi-Iat sidetracking job on the well. Please consider these factors in this request for a waiver that will permit the CIBP for L5-16 to be set at 9250', or 118 feet above the perforations at 9368-9378' MD. Ted Stagg CT Drilling Engineer 907 564-4694 8CAN~tHJ I.· .. h (" O'·(\~ :J .J I.. Jut' 1 of 1 3/30/2006 9:38 AM e ~1f~1fŒ [ID~ ~~~~æ~ e AI~A.SIiA. OILAlWD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: --\tl /' D\~t Prudhoe Bay Field, Lisburne Oil Pool, PBU L5-16 Sundry Number: 306-120 Dear Mr. Stagg: p [\ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thiaJO day of March, 2006 Enc!. .", tp (ß*,,'~ fl'ce3/2-1/á I~ECE'VED ' /'ff:Jp\ 0 e · STATE OF ALASKA ø~ AjV" ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 2 9 2.006 ..f/~ APPLICATION FOR SUNDRY APPROVAL,. Q . C Commission t' .Jq /":.. 20 AAC 25.280 Alas!<8 (hi öl Gas ons. ~ Anchorage 1. Type of Request: II Abandon o Alter Casing o Change Approved Program o Suspend 0 Operation Shutdown 0 Perforate 0 Other .___________________ o Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 60' 9. Well Name and Number: 5. Permit To Drill Number 187-019 / 6. API Number: 50- 029-21700-00-00 PBU L5-16 / 99519·6612 8. Property Designation: 10. Field / Pool(s): ADL 028320 11- Total Depth MD (ft): 9575 Casina ~tro ,,...., or<>1 Prudhoe Bay Field / Lisburne Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): 9313 9479 9225 Lenath Size MD (' TVD Plugs (measured): None Burst Junk (measured): None CollaDse - . 120' 4006' 20" 10-3/4" 120' 4006' 120' 3998' 1490 3580 470 2090 9559' 7-5/8" 9559' 9298' 6890 4790 I in¡:u Perforation Depth MD (ft),: I Perforation Depth TVD (ft): I 8964' - 9378' / 8751' - 9132' Packers and SSSV Type: 7-5/8" x 3-1/2" Brown 'HB' packer; 3-1/2" Camco 'TRDP-1 A' TRSSSV Tubing Size: / 3-1/2", 9.3# Tubing Grade: L-80 Packers and SSSV MD (ft): 8820'; 2215' I Tubing MD (ft): 8894' / 12. Attachments; 181 Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Verbal Approval: Commission Representative; 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Ted Stagg Title CT Drilling Engineer -?' /7// __ Sianature 1:1... ~ J ~..,. Phone 564-4694 "'tT Commission Use Only April 17 , 2006 Date: 15. Well Status after proposed work: DOil o Gas o WAG 0 GINJ o Plugged DWINJ 181 Abandoned o WDSPL Contact Ted Stagg, 564-4694 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance Date J/ z;/ot, ( { I Sundry Number: (?J11 f) - \ r;J ñ Prepared By NamelNumber: Terrie Hubble, 564-4628 Other: T-e.~ t- ß 0 ? E- to ~ 00 D (J \.....<,. Pu 'l.o ML 'Z.S. ~m2. (; ) l tkk te Subsequent Form Required: I 0 - D /,':~ f(~AI ~ APPROVED BY Approved By: COMMISSIONER THE COMMISSION Form 10-403 Revised 0712005 .. '-!""'\.;tf" I ì)([ \ U \~\\ lJ I ~ R8DMS BFL APR , , n-u I'\..{¡ Wi- L{,. W\. . wLll fl~~¡'~ pJVCRtk.^--<. ,'S 'YtýO(/~d, Date !;.,. 3/J ' r!J ';;;'", {) Z006~; ) Submit In Duplicate e e 0.: b " P To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Ted Stagg CTD Engineer Date: March 27, 2006 Re: Workover L5-16 in preparation for CTD sidetracking Sundry approval is requested to workover Lisburne L5-16 in preparation for multi-lateral, underbalanced sidetracking with coiled tubing. L5-16 has produced 1.53 MMBO since 1987 but is currently on cycle only 5 out of 25 days du 0 high GOR. L5-16 is an excellent candidate for underbalanced drilling in the Lisburne as it ,/ has excelle ock q ality, adequate reservoir pressure, lacks Zone 7, and has good standoff from the original GOC. T elate s are planned to be drilled in the underbalanced mode. A 4 W' scab liner will be installed in L5-16 du . e workover to improve conditions for successfully isolating existing perfs and to improve hole cleaning for underbalanced drilling. The workover ofL5-16 is scheduled to be performed by Nordic 2 on or about May 1 st, 2006. The plan calls for removal of existing 3 W' tubing and packer prior to installation of a 4 W' scab liner and new 4 W' tubing. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed workover is attached for reference. Pre-Rie: Work 1) Integrity of the IA and OA will be reconfirmed. 2) A static BHP was obtained on 3/06/06. 3) Tubing has been inspected with a PDS calliper an~ in good condition. 4) Kill well and liquid pack IA with 8.5 ppg KCl. 5) Existing 3 Vz" tubing will be chern. or jet cut in the first full joint above the production packer. 6) Remove flow line, remove well house, and level pad. The pre CTD work is slated to begin about April 17, 2006. Rie:Wou d 1) MIRV Nordic 2 and test orkov BOPE. Circulate tubing x IA with 2% KCl. 2) Recover 3 Y2" tubing abo r uction packer. /J 3) Overshot tubing stub and recover seal assembly from PBR. 4) Spear BOT HB packer and jar free. 5) RU slick line and run guage ring to top of fill at approx. 9300'. 6) RU e-line ~d et cmp at approx. 9250' MD (8955ss). / 7) Run 4 Vz", ~.6#1 L-80, mT-Mod scab liner [9250'(8955ss)to 8800' (8540ss)] an. d cement with a minimum 36 bls cement designed to put approx. 24 bbls cement behind 7 5/8" casing. 8) Run 4 Vz" P uction tubing with SB3-A packer, 5 GLM's and TRSSSV. /' 9) Install new 4 Vz" production tree in preparation for UBCTD to follow in approx. 6 weeks. .ß Freeze protect well and RDMO. T~~ CTD Drilling Engineer 564-4694 II!S¡) '-110 ()~ WGIt- .,/ CC: Well File Sondra Stewmanfferrie Hubble Date: To: From: Subject: e e March 30, 2006 File Jane Williamson Þ1l1øJ Lisburne 5-16 .. 0- BP has requested approval to plug-back Lisburne 5-16 in preparation for CTU sidetrack of three short radius laterals. As the laterals will contact the oil bearing portion of the Lisburne, no loss of reserves is anticipated. The well is on cyclic production due to high GOR. L5-16 is a very good candidate for underbalanced drilling as the Lisburne has excellent rock quality, relatively high reservoir pressure, lacks the Zone 7 thief zone, and has good standoff from the GOC. I worked as a DS engineer in charge of L5 wells and I agree that this will be a great opportunity to add reserves and rate at Lisburne. I recommend approval of this sundry request. OFM is not working right now so I can't provide production or decline curves. TREE = 3-1/8" McEVOY e WELLHEAD = MCEVOY L5-16 SAFETY NOTES: CAT I SSSV H2S (PPM)250 ACTUATOR - AXELSON KB. ELEV = 55' BF. ELEV = NA KOP= 3800' H 3-1/2" CA MCO TRDP-1 A TRSSSV, ID = 2.812" I Max Angle = 27 @ 7400' 2215' Datum MD = 9082' . Datum 1V D = 8800' SS CHEMICAL INJECTION MANDRELS ISTI MD 1VDI DEVI lYPE I VLV LATCH PORTI DATE c ~ I 1 12296 22361 3 KBMG-L TS I E BK-2 0 103/17187 GAS LIFT MANDRELS ST MD 1VD DEV lYPE VLV LATCH PORT DATE ~ 1 2822 2821 2 MC-FMHO DV RK 0 02/17/89 Minimum ID = 2.750" @ SSSS' 2 5080 5065 2 MC-FMHO DOME BK-2 16 01/30/00 3 6772 6747 15 MC-FMHO DV BK-2 0 02117189 3-1/2" CAMCO D NIPPLE 4 8109 7967 24 MC-FMHO DV BK-2 0 02/17/89 5 8723 8529 23 OT-LBX 510 T2 16 01/30/00 110-3/4" CSG, 45.5#, L-80, ID = 9.953" I 4006' µ ~ 8J ,.,..., 8820' 7-5/8" X 3-1/2" BROWN I'-" HB A<R, ID = 2.89" I . I 8888' H3-1/2" CAMCO D NIP, ID = 2.75" I 13-1/2" TBG-IPC, 9.3#, L-80, .0087 bpf, ID = 2.992" I 8893' I 8894' H3-1/2" BROWNSHEARSUBm I . I 8884' H ELMD TT LOGGED 01/11/92 I ÆRFQRA TION SUMMARY ] REF LOG: SWS CBL ON 03/19/87 ANGLEATTOPÆRF: 22@8964' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ] 4" 1/2 8964-8984 0 05/31/87 4" 1/2 9000-9056 0 OS/25/00 4" 1/2 9062-9072 0 OS/25/00 ) 4" 1/2 9080-9084 0 OS/25/00 4" 1/2 9110-9120 0 OS/25/00 4" 1/2 9132-9142 0 OS/25/00 4" 1/2 9148-9158 0 OS/25/00 4" 1/2 9178-9198 0 OS/25/00 2-1/8" 1/2 9368-9378 0 OS/25/00 ~ IPBTD I ] 9479' '. 17-5/8" CSG, 29.7#, L-80, ID = 6.875" I 9559' DATE REV BY COMMENTS DATE REV BY COMMENTS LlSBURE UNIT 03/17/87 ORIGINAL COMA-ErION WELL: L5-16 01/05/01 SIS-CS CONVERTED TO CANV AS ÆRMIT No: 187-0190 03/02/01 SIS-LG FINAL API No: 50-029-21700-00 12/29/01 CH/TP CORRECTIONS SEe 1, T11N, R15E 1788' FSL & 19' FWL 05/06/02 GClKAK FCO/ÆRF CORRECTIONS BP Exploration (Alaska) SAFETY NOTES: CAT I SSSV H2S (PPIvI)250 X x7 X and ZXP MD 4 1/2" 1 1ST-Mod Scab Liner -9250' MD - 1 5/8" CISP approx. 9250' MD MD N2 13" 1 ..~¡~~ "'I, ';~'. l~. ~.1~ ~~: (I ~.,.. }~::~: 'O'~Jt " .1>;..., , MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE .~ ..) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3489' FNL, 5260' FEL, Sec. 1, T11N, R15E, UM At top of productive interval 1245' FSL, 1006' FWL, Sec. 1, T11 N, R15E, UM At effective depth At total depth 4198' FNL, 4068' FEL, Sec. 1, T11N, R15E, UM 5. Type of Well: Development__X Explorato~___ Stratigraphic__ Service__ (asp's 717447, 5974920) (asp's 718448, 5974408) (asp's 718659, 5974247) 6. Datum elevation (DF or KB feet) RKB 60 feet 7. Unit or Property name Lisburne Unit 8. Well number L5-16 9. Permit number / approval number 187-019 10. APl number 50-229-21700 11. Field / Pool Lisburne Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 90' 20" Surface 3946' 10-3/4" Production 9499' 7-5/8" 9575 feet Plugs (measured) 9313 feet 9061 feet Junk (measured) 8841 feet Cemented 180o # Poleset 1300 Sx AS III & 325 Sx G 425 Sx Class G Top of Sand Plug @ 9061' 1/30/2000). Measured Depth True verticalDepth 90' 90' 4006' 3998' 9559' 9298' Perforation depth: measured 8964' - 8984' (gel sqz'd); 9000' - 9084' (Cement sqz'd but leaking); (9110' - 9198' & 9368' - 9378' both sets of perfs under sand plug). true vertical 8751' - 8770' (gel sqz'd); 8785' - 8862' (Cement sqz'd but leaking); . (8886' - 8967' & 9123' - 9132' both sets of perfs under sand plug). Tubing (size, grade, and measured depth) 3-1/2"9.3#, L-80 PCT @ 8884' MD. Packers & SSSV (type & measured depth) 7-5/8" X 3-1/2" BROWN HB PACKER, ID=2.89" (ELMD) @ 8808' MD. 3-1/2" CAMCO TRDP-1A SSSV, ID=2.812" @ 2215' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ORIGINAL RECEIVED FEiB 14 PO00 Alas~ 0il & Gas Cons. CommissJ0D Ancn0rag~ 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mci Water-Bbl (shut in for high GOR) 521 6670 286 Casing Pressure Tubing Pressure 601 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil .__X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.'~ -~ ~t~'7~,,,,~ Title ARCO Engineering Supervisor Erin Oba ~ Form 10-404 Rev 06/15/88 · Date Prepared by Paul Rauf 263-4990 SUBMIT IN DUPLICATE L5-16 DESCRIPTION OF WORK COMPLETED ACID WASH / LARC SQUEEZE FOR GSO & MARCIT/MARASEAL SQUEEZE FOR GSO Date Event Summary 10/05/1999: MITIA 10/07/1999: RIH & 10/08/1999: MIRU 10/09/1999: 10/11/1999: 10/21/1999: 10/25/1999: 11/20/1999: to 3000 psi - dropped 100 psi in 30 minutes. Passed. tagged PBTD @ 9419' ELM. CTU & tested BOPE. Killed well w/160° 2% KCL Water. RIH & tagged BTM @ 9386' CTM. Attempted to Icad well w/a gelled sand slurry containing 9700 lbs of 10% Carbolite & 90% Silica sand but CT plugged after 2 bbls of slurry away. Unplugged CT. RIH & tagged BTM @ 9385' ELM. Pumped a gelled sand slurry containing 11000 lbs of 20/40 mesh river, to place an isolation sand plug across the open perforation intervals below: 9110' - 9198' MD (Zone Wahoo 4) Reference Log: CNL/LDT (Porosity)S 3/14/1987. 9368' - 9378' MD (Zone Wahoo 1) Conducted injectivity test: 540 psi @ 1.5 bpm & 700 psi @ 2 bpm. Made a final tag on TOS @ 9113'. POOH. RD. RIH & tagged BTM @ 9095' ELM. Dump bailed 6 gal liquid Latex cap on sand top. A CTU Acid Wash & Cement Squeeze for Gas Shutoff were performed as follows: MIRU CTU. PT'd BOPE. Loaded wellbore w/160° 2% KCL Water. RIH & tagged TOS @ 9095' MD. Reciprocated an acid wash across the open perforations located above the sand plug/Latex cap @: 8964'- 8984' MD (Zone Wahoo 6) 9000'- 9084' MD (Zone Wahoo 5) Pumped: (a) 18 bbls of 80% Diesel - 20% Xylene @ 2.2 bpm, followed by RECEIVED AJaska Oil & Gas Cons. Commission Anchorage (b) 60 bbls of 15% HCL - 10% Xylene (90:10 DAD acid) @ 2 bpm, followed by (c) 100 bbls of 2% KCL Water @ 2 bpm, followed by (d) Shutdown. No break seen. Pumped 51 bbls of 15.8 ppg Latex Acid Resistive Cement to squeeze the open perforation interval listed above. No squeeze pressure attained. Contaminated Cement w/Biozan and jetted contaminated Cement f/wellbore to 9095'. Layed in TEA across perfs. POOH. FP'd well. RD. Performed injectivity test: 1000 psi @ 2.8 bpm, 800 psi @ 2 bpm, & 100 psi @ 1.5 bpm. RIH & tagged BTM @ 9089' ELM. Page 1 L5-16 DESCRIPTION OF WORK COMPLETED ACID WASH / LARC SQUEEZE FOR GSO & MARCIT/MARASEAL SQUEEZE FOR GSO Date Event Summary 11/28/1999: 11/29/1999: 1/16/2000: 1/30/2000: MIRU CTU. Tested BOPE. Killed well. RIH & tagged BTM @ 9089' MD. Pumped a gelled sand slurry containing 6750 lbs of 20/40 mesh river, to place an isolation sand plug across the open perforation intervals below: 9000' - 9084' MD (Zone Wahoo 5) Perfs took 300% over expected. Made a final TOS tag @ 8989'. Conducted injectivity test: 250 psi @ 0.5 bpm, 350 psi @ 1.0 bpm, 550 psi @ 1.5 bpm,& 750 psi @ 2.0 bpm. POOH. Left well fluid packed w/Crude. RD. RIH & tagged TOS @ 8995' ELM. AFB Marcit/Maraseal Gel Treatment for Gas Shutoff was performed as follows: MIRU & PT equip. Pumped the FB Gel Treatment in stages, through the perforation interval located above the sand plug f/8964' - 8984' MD (Zone Wahoo 6). Pumped: (a) 500 bbls of KCL Water w/Chrome Acetate Crosslinker @ 6.0 bpm, followed by (b) 200 bbls of Marcit Gel (Crosslinked / 3000 ppm Polymer) @ 5.4 bpm, followed by (c) 500 bbls of Marcit Gel (Crosslinked / 6000 ppm Polymer) @ 5.23 bpm, followed by (d) 920 bbls of Marcit Gel (Crosslinked / 9000 ppm Polymer) @ 5.2 bpm, followed by (e) 966 bbls of Marcit Gel (Crosslinked / 12000 ppm Polymer) @ 1-2 bpm, followed by (f) 300 bbls of Maraseal Gel (Crosslinked / 40000 ppm Polymer) @ 2 bpm, followed by (g) 75 bbls of Crude displacement @ 2 bpm, followed by (h) 5 bbls of Methanol Water @ 1-2 bpm, followed by (i) Shutdown. Had a 1520 psi final WHP. RD. RIH & tagged BTM @ 9061' ELM. Returned well to production & obtained valid welltest data. RECEIVED 1 4 2000 Alaska 0il & ( as Cons. C0mmissio Anchorage Page 2 Date: Subject: From: To' ARCO Alaska, Inc. Lisburne/Point Mclntyre ~Engineering May 26, 1993 Transmittal #671 ARCO Alaska Inc. Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Enclosed is the following data for Lisburne Log (1 blueline, 1 sepia) Well Title -!_2 Production Log, AVA Leak Detection ~ ~LGI12 Tubing Patch Set Record (Otis Merla) 15~L5-01 Production Profile Survey ~-16 L5-28 L5-28 Production Profile Survey PFC Gamma Ray (Packer Setting Record) Perforating Record Run 1 1 1 1 1 1 Run Date Company 3/29/93 Schlumberger 4/13/93 Schlumberger 10/25/92 Camco 10/24/92 Camco 2/12/93 Atlas 12/05/92 Halliburton Please sign and return to: .2~~ Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 Transmittal #671 PLEASE SIGN ONE COPY AND RETURN STATE OF ALASKA O A~ OIL AND GAS CONSERVATION COMMIS_~;ON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown w Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARQO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1788' FSL, 19' FWL, Sec. 1, T11N, R15E, UM At top of productive interval 1245' FSL, 1006' FWL, Sec. 1, T11N, R15E, UM At effective depth 1104' FSL, 1183' FEL, Sec. 1, T11N, R15E, UM At total depth 1079' FSL, 1212' FWL, Sec. 1, T11N, R15E, UM 6. Datum elevation (DF or KB) RKB 60' 7. Unit or Property name PRUDHOE/LISBURNE UNIT 8. Well number L5-16 9. Permit number/approval number 87-19 10. APl number 50-029-21 700-00 11. Field/Pool LISBURNE OIL POOL feet 12. Present well condition summary Total Depth: measured true vertical 9375' feet 9312' feet Plugs (measured) None Effective depth: measured 9479' true vertical 9224' feet Junk (measured) feet None Casing Length Structural Conductor 80' Surface 3 9 6 7' Intermediate Production 9523' Liner Perforation depth: measured 8964'-9198' true vertical 8751 '-8966' Size 20" 1 03/~4" Cemented Measured depth True vertical depth 1800 lb Poleset 90' 90' 1300 sc AS III & 4006' 3998' 325 sx Class G 425 sx Class G 9559' 9297' Tubing (size, grade, and measured depth) 3 X" L-80 tbg w/tail @ 8894' wired Packers and SSSV (type and measured depth) HB Pkr @ 8820' md, TRDP-1A-SSA SSSV @ 2215' md RECEIVED Alaska 0il & Gas Cons. Comm~ssioO 13. Stimulation or cement squeeze summary Anchorage Intervals treated (measured) Wahoo 6, 5, 4, 1 Treatment description including volumes used and final pressure please refer to the attached 14. Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 295 1405 1 583 Subsequent to operation 803 8085 51 706 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector __ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ne~~~, Title Lisburne Operations Engineering Aide Fnrm 1fl-4f'14 RRv 13R/17/R.q Date ~'/c~ //~ ~... RI IRMIT IN 1'311Pl I¢,ATF Date 1/11/92 1/24/92 Lisburne Well L5-16 Stimulation Procedure -Wahoo 6, 5, 4 & 1 Event Rigged Halliburton wireline. Perforated Wahoo 1 from 9368'- 78' with a 2-1/8" 20.5 gram through tubing gun. Rigged down wireline. Rigged up Halliburton. Pressure tested lines - ok. Closed Fracture Acidized perforations from 8,964' to 9,378 MD With the following fluids: 1455 BBL Emulsified Acid 1765 BBL Gelled Water 190 MSCF Nitrogen 30 BBL 60/40 Methanol/Water (freeze protect) Shut down pumps RD. Return well to production. RECEIVED JUN - B 1~92 Alaska Oil & Gas Cons. Commission Anchorage ARCO ALASKA INC. LISBURNE ENGINEERING DATE: FROM: February 12, 1992 Laura S. Lahrson ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: ~?-3° Log: Well Type I blueline, 1 mylar Log: Well Type 1 blueline, I rolled mylar LA-03 ~/Perforating Record ~,' Perforating Record L4-31 - Perforating Record L5-16 "/Perforating Record L5-26 -/Pressur.e Data Log "'/Engineering Parameters (2" MD) ~Engineering Parameters (2" TVD) ~' Integrated Formation Log (2" MD) /Integrated Formation Log (2" TVD) L5-26 L5-26 L5-26 L5-26 L5-26 L5-26 L5-26 ,L5-26 L5-08 L4-15 Gamma Ray 2" TVD Gamma Ray 5" TVD Gamma Ray 2" MD Gamma Ray 5" MD Leak Detection ,/~pilog -Prism Run Run Date Run Run Date 5 11/15/91 1 9/14/91 1 9/25/91 I 1111192 11107191 11/07/91 11107191 11/07/91 11/07/91 11/19-12/03/91 11/19 -12/03/91 11/19-12/03/91 11/19-12/03/91 I 11103191 12/22/91 Tape: Well Type L5-26 '/GCT Directional Survey (lis) ~v/DWL/SDL-CN-GR-CAL (lis) L5-26 Exlog Data Disk Run Run Date 12/04/91 10/29/91 11/07/91 Company Company Halliburton Halliburton Halliburton Halliburton Exlog Exlog Exlog Exlog Exlog Halliburton Halliburton Halliburton Halliburton Camco Atlas Company Schlumberger AAI SIGN AND RETURN TO: LAURA S. LAHRSON, ATe 409 ARCO ALASKA, INC. P.O. Box 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED BY: Exxon BPX TRANSMITTAL # 657 AOGCC D&M RECEIVED FEB 1 8 1992 Alaska 0il & (las Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. ~ype cT Hequest: Abandon Alter casing Change approved program 2. Name of Operator ARCO ALASKA INC. 3. Address P.O. BOX 100360 ANCH. AK 99510 Suspend Repair well__ Operation shutdown Re-enter suspended well Plugging Time extension~ Stimulate~X Pull tubing Variance Perforate X_~_ Other 5. Type of Well: Development X Exploratory. Stratigraphic Service 4. Location of well at surface 1788' FSL, 19' FWL, Sec. 1, T11 N, R15E,UM At top of productive interval 1245' FSL, 1006' FWL, Sec. 1, T11N, R15E, UM At effective depth 1104' FSL, 1183' FWL, Sec. 1, T11N, R15E, UM At total depth 1079' FSL, 1212' FWL, Sec. 1, TllN, R15E, UM 12. Present well condition summar, y Total depth: measureo 9375' feet true vertical 9312' feet Effective depth: measured 9479' true vertical 9224' Casing Length Size Structural Conductor 80' 20" Surface 3967' 10-3/4" Intermediate Production 9523' 7-5/8" Liner feet feet 6. Datum elevation (DF or KB) RKB 60' 7. Unit or Property name Pr~dhoe/Lisburne Unit 8. Well number L5-16 9. Permit number 87-19 10. APl number 50-029-21700 11. Field/Pool LISBURNE OIL POOL Plugs (measured) NONE 0 R- IN A I. Junk (measured) NONE Cemented 1800 lb. Poleset 1300 sx AS III & 325 sx Class G 425 sx Class G Perforation depth: Measured Depth 8964' - 9198' True Vertical Depth 8751'- 8966' Tubing (size, grade, and measured depth) 3-1/2" L-80 tbg w/tail @ 8894' wlmd Packers and SSSV (type and measured depth) HB Pkr @ 8820' md, TRDP-1A-SSA $SSV @ 2215' md feet Description summary of proposal X.~_ 13. Attachments Date approved 14. Estimated date for commencing operation January14r 1992 16. If proposal was verbally approved Name of approver Measured depth 90' 4006' True vertical depth 90' 3998' 9559' 9297' RECEIVI D DEC ~ ? 1991 .0il & 6as Cons. uommtss'~0~ ,-, ~tt0rage Detailed operations program 15. Status of well classification as: Oil~_ Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,qned "~ ~ ~~ T.E. Krawietz Title: Sr. Operation Enc FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative my witness Plug integrity ...... BOPTest__ Location clearance Mechanical Integrity Test Subsequent form required 10- .,y'l)4/ BOP sketch~ Original Signed By David W. JOhnston ' . ATe 484 Date [Approv.a.l.~ r'.oO¥ No. Commissioner SUBMIT IN TRIPLICATE Approved by order of the Commission Form 10-403 Rev 06/15/88 Lisburne Well L5-16 Perforate and Stimulate Procedure , . . . Perforate Wahoo I from 9368' md to 9378' md w/2-1/8" gun. RU stimulation company. Well control provided by surface chokes and production valves. Closed Fracture Acidize Wahoo 1, 4, 5 and 6 at maximum treating pressure of 6,500 psi with the following stimulation fluids: · 1200 bbls 40 pptg gelled water. · 1200 bbls 30:70 crude/10% HCL emulsified acid. Release service company and open well to flow. Estimated Static BHP = 3,050 psig at 8900' ss. WIRELINE BOP EQUIPMENT 4 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS 3. 5000 PSI 4 I/6" LUBRICATOR 4. 5000 PSI 4 1/5" FLOW TUBE PACK OFF RECEIV£ Alaska. Oil E 6~s Cot~s. Co~s~'te~ A~ohorage 1. I ype cT Heques~: Abandon Suspend Alter casing Repair well Change approved program Operation shutdown Re-enter suspended well Plugging Time extension . Stimulate..~_ Pull tubing . Variance Perforate Other 2. Name of Operator ARCO ALASKA INC. STATE OF ALASKA '- ' ~,SKA OIL AND GAS CONSERVATION COMM )N APPLICATION FOR SUNDRY APPROVALS 5. Type of Well: Development__~_ Exploratory Stratigraphic Service 3. Address P.O. BOX 100360 ANCH. AK 99510 6. Datum elevation (DF or KB) RKB 60 feet 7. Unit or Property name Prl,ldhoe/Lisburne Unit 8. Well number L5-16 9. Permit number 87-19 10. APl number 50-029-21700 11. Field/Pool LISBURNE OIL POOL 4. Location of well at surface 1788' FSL, 19' FWL, Sec. 1, T11N, R15E,UM At top of productive interval 1245" FSL, 1006' FWL, Sec. 1, T11 N, R15E,UM At effective depth 1104' FSL, 1183' FWL, Sec. 1,T11N, R15E, UlV~.t total depth 1079' FSL, 1212' FWL, Sec. 1, T11N, R15E, UM 9375' feet Plugs (measured) 9312' feet cement: none 12. Present well condition summa,ry Total depth: measurea true vertical Effective depth: measured 9479' feet Junk (measured) NONE true vertical 9224' feet NOV 2 0 990 & Gas Cons, (:; .mlilJs tll Measured depth True vertical depth 90' 90' 40O6' 3998' 9559' 9297' Casing Length Size Cemented Structural Conductor 80' 20" 180Ch~ Poleset Surface 3967' 10-3/4" 1300 sx AS III & Intermediate 325sx Class G Production 9523' 7-5/8" 425 sx Class G Liner Perforation depth: measured: 8964-8984', 9000-9042', 9044-9056', 9062-9072', 9110-9120', 9132-9142', 9148-9158' 9178-9198' true vertical: 8751-8769', 8784-8823', 8824-8836', 8841-8850', 8885-8894', 8905-8915', 8920-8929', 8948-8966' Tubing (size, grade, and measured depth)3-1/2" L-80, tbg w/tail @ 8894' WLM Packers and SSSV (type and measured depth HB pkr ~ 8820' & TRDP-1A-SSA SSSV @ 2215' 13. Attachments Description summary of proposal_[ Detailed operations program BOP sketch_x~._. 14. Estimated date for commencing operation November24, 1990 16. If proposal was verbally approved Name of approver 17. I hereby ?e~f,;y that th.~,e foreboding Oil_~ I t/t c~/.~ 0 Service Date approved is true and correct to the best of my knowledge. 15. Status of well classification as: Gas Suspended Kirk M. Bartko Title: Senior Operations Engineer Date 1[/~ ~/~q(:3 ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative my witness Plug integrity . BOP Test Location clearance Mechanical Inte~Irity Test Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commission Form 10-403 Rev 06/15/88 App~uv~d COp), Return, ed lappr°val N°. ~ ~ .-. ~:~ ~ Commissioner SUBMIT IN TRIPLICA I I:: Proposed Stimulation Lisburne- Well L5-16 1, 2. . 4~ Shut in well. Rig up service company to pump stimulation fluids. Well control provided by surface chokes and production valves. Closed Fracture Acidize Wahoo 4 and 5 with the following stimulation fluids: · 1,500 BBL emulsified acid 30:70 mixture [18,900 gallons (450 BBL) crude/44,100 gallons (1050 BBL) 10% HC1] (visc.=150-180 cp). Drop 7/8" ball sealers throughout. · 1,500 BBL crude. (Maximum treating pressure: 5000 psi) Release service company and open well to flow. RECEIVED NOV 2 o 1990 Alaska O.il & Gas Cons. (;o. ma3lsslO.~ ~choraoj~ STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMM,oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown :9 Stimulate I~ Plugging [] Perforate FI Pull tubing Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska Inc. RKB 60' 3. Address 6. UnitorProperty name P.O. Box 100360 Anchorage, Alaska 99510 Prudhoe Bay/Lisburne 4. Location of wellatsurface 1788' FSL, 19' FWL, Sec. 1, T11N, R15E, UM 7. Well number L5-16 At top of productive interval 1245' FSL, 1006' FWL, Sec. 1 , T11N, At effective depth 1104' FSL, 1183' FWL, Sec. 1, T11N, At total depth 1079' FSL, 1212' FWL, SEc. 1 , T11N, R1 5E, UM rl 5E, UM R1 5E, UM 8. Approval number 8-363 9. APl number 50-- 029-21700 10. Pool Lisburne Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical 9575 ' feet 931 2 ' feet Plugs (measured) NONE Effective depth: measured true vertical 9479 ' feet 9224 ' feet Junk (measured) NONE Casing Structural Conductor Surface Intermediate Production Liner Length Size 80' 20" 3967' 10-3/4~'~'' 9523" 7-5/8" Cemented Measured depth True Vertical depth 1800 # Poleset 120' 120' 1300 sx AS III & 4006' 3998' 325 sx Class G 425 sx Class G 9559' 9297' , 9062'-9072', , 8841 '-8850', Perforation depth: measured ,.,.64'-8984' , 9000'-9042' , 9044'-9056' 9148'-9158', 9178'-9198' true v%,.?~f~l,'~" "~ , , , 8751 ' 8769', 8823 , 8824 -8836 8920'-8929', 8948'-8966' Tubing (size, grade and measured depth) 3-1/2", L-80 Tbg tail @ 8894' Packers and SSSV (type and measured depth) HB pkr @ 8820' & TRDP--1A-SSA SSSV @ 2215' 9110'-9120', 9132'-9142' 8885'-8894', 8905'-8915' 12. Stimulation or cement squeeze summary Intervals treated (measured) Wahoo 4, 5, and 6 Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 324 3660 21 50 290 3473 32 50 Tubing Pressure 410 423 14. Attachments Daily Report of Well Operations I~ Copies of Logs and Surveys Run ['-I 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title T~chnica] Aide Date 7 - 1 - 88 Submit in Duplicate ATTACHMENT 1 L5-16 5/22/88 RIGGED UP HALLIBURTON TO PUMP HYDRAULIC FRACTURE TREATMENT. PUMPED THE FOLLOWING TREATMENT: PAD 1 PAD 2 PAD 3 167 BBLS XL WATER 167 BBLS XL WATER W/1PPG 100 MESH SAND 167 BBLS XL WATER PAD STAGES CONTAINED 30LB/M ADOMITE AQUA. PROP STAGE 1 PROP STAGE 2 PROP STAGE 3 - 83 BBL XL WATER WI2 PPA 20/40 MESH CARBOLITE - 119 BBL XL WATER W/4 PPA 20/40 MESH CARBOLITE - 119 BBL XL WATER W/5 PPA 20/40 MESH CARBOLITE TREATMENT PUMPED AT 31 BPM, 6200 PSI. FRAC TREATMENT WAS DESIGNED FOR 88,000 LBS OF PROPPANT BUT SCREENED OUT AFTER 67,000 LBS OF PROPPANT WAS PLACED IN THE FORMATION. SCREENOUT CAUSED BY HIGH LEAKOFF AND OPERATION PROBLEMS. PRESSURE SPIKES CAUSED BY DRAWING AIR THROUGH THE BLENDER CAUSED 4 OF THE 12 PUMPS TO TRIP. RIGGED DOWN HALLIBURTON. STATE OF ALASKA .... ALASK,-, OIL AND GAS CONSERVATION COMM._51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well E-] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate []<_ Pull tubing E] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO ~,laska Thc. RKB 60' feet 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, Alaska 99510 Prudhoe Bay/Lisburne 4. Location of well at surface 1788' FSL, 19' At top of productive interval 1245' FSL, 1006' At effective depth 1104' FSL, 1183' At total depth 1079' FSL, 1212' FWL, Seco 1 , T11N, R15E, UM FWL, Seco 1 ,~ T11N, R15E, UM FWL, Sec. 1 , T11N, R15E, UM FWL, Sec. 1 , T11N, R15E, UM 7. Well number L5-16 8. Permit number 87-19 9. APl number 50-- 029-21700 10. Pool Lisburne Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80 ' Surface 3967 ' Intermediate Production 9523 ' Liner Perforation depth: measured 8964'-8984' , 9000' true vertical 8751'-8769', 8784' -9042' -8823' 9575' feet feet 9312' 9479' 9224 ' Size feet feet Plugs (measured) NONE Junk (measured) N0N ~.h::;! . Cemented Measured depth True Vertical depth 20" 10-3/4" 7-5/8- 1800 # Poleset 1300 sx AS III & 325 sx Class G 425 sx Class G 120' 4006' 9559' 120' 3998' 9297' , 9044'-9056' , 9062'-9072' 9148'-9158', 9178'-9198' , 8824'-8836', 8841 '-8850' , 9110'-9120' , 8885'-8894' , 9132'-9142' , 8905'-8915' Tubing (size, grade and measured depth) 8920'-8929', 8948'-8966' 3-1/2", L-80, tbg w/ tail @ 8894' Packers and SSSV (type and measured depth) HB pkr @ 8820' & TRDP-1A-SSA SSSV @ 2215' 12.Attachments Description summary of proposal ~ Detailed operations program [J BOP sketch 13. Estimated date for commencing operation May 24, 1988 14. If proposal was verbally approved Name of approver Subsequent ~Vorl,: Reported on Form No./~'- S/O~f Dated__/_L/_~ Date approved 15.1 heret;,y,%certify that the foregoing is true and correct to the best of my knowledge L rnbar-I- Signed ]"l,,,t~l][-~ ___ Title Technical Aide Commission Use Only Date 5-4 -88 Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance .~,poroved Copy Returned Commissioner by order of the commission Date Sffbn~ in triplicate ATTACHMENT 1 WELL L5-16 · SHUTIN WELL 2~ 4~ RIG UP SERVICE COMPANY TO PUMP HYDRAULIC FRACTURE STIMULATION. (WELL CONTROL PROVIDED BY SURFACE CHOKES, TREE SAVER, AND PRODUCTION VALVES). FRAC JOB WILL BE PUMPED WITH 40,500 GALS OF CROSSLINKED WATER AND 88,000 LBS OF CERAMIC PROPPANT. FLUSH WITH 77 BBLS SLICK DIESEL. (MAX. TREATING PRESSURE 6000 PSI) RELEASE SERVICE COMPANY. OPEN WELL TO FLOW. * STATIC BHP WAS 4066 PSI ON JUNE 10, 1987 DATE' 12-29-87 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE' CH Finals L5:~.~1'6~ Production Profile t1-19-87 Run i 5" L5-29 Perforating Record 12-11-87 Run 2 5" C am c o k___?~--k'' Sch ~ ~. . , \/ -- /._.- ,,.. PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES PLANO D & M STANDARD EXXON STATE. OF ALASKA TRANSMITTIAL # 366 ARCO AL~KA INC. Date: 8-13-87 From: Para Lambert Enclosed are the following: CH Finals for Lisburne Wells Li-IO PDK-iO0 11-23-85 Run 1 5" DA L5-8 PDK-IO0 5-17~-87 Run 1 5" DA [f~ L5-12 PFC Log 6-4-87 Run 1 5'; DA Z~ L5-16 PDK-100 5-18-87 Run 1 5" DA ~ L5-28 PDK-100 5~-18.-87 Run 1 5': DA ~i L5-28 Flowmeter Fluid Density Temp Log 7727.-87 Run 1 5" Camco2~_ L5-29 GCT Directional Survey 6.-21787 Run 1 5" Sch Received by: Please sign and return tol Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 291 ARCO ALASKA INC. LISBURNE ENGINEERING Date: Aug 4, 1987 From: Pam Lambert Enclosed are the following: Magnetic Tapes for Lisburne Wells LI-10 put-100 11~23-85 ns-s eu~-~oo s-~y-8~ nA~~~4/- p-~e~- / / / 7g--/~/~ ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 EXXON. STANDARD: FILE ROOM CENTRAL FILES TRANSMITTAL # 284 ARCO ALASKA INC. LISBURNE ENGINEEI~ING Date: July 7, 1987 From: Pam Lambert ~ Enclosed are the following: CH Finals for Lisburne Wells ~L5-12 Collar Log Chemical Cutter 6-7-87 Run 1 5" GO ~ ~ L5-16 Collar and Perf Log 5-30-87 Run 1 5" GO -L5-16 Temperature Survey 6-10-87 Run 1 5" Otis ~ L5-28 Temperature Log 6-18-87 Run 3 5" Sch Commissbn ?lease s/ga and return co~ ~a~ ~ambert · ~d~.CO ~ I~C. 700 G Street ATO 477 Anchorage, Ar,, 99510 D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # " STATE OF ALASKA " 0 R 1 § lB/A ALASKA OIL AND GAS CONSERVATION ~,,.,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL .~' GAS [] SUSPENDED [] ABANDONED [] SERVICE [] · 2. Na~n~ of Operator 7. Permit Number ARCO Alaska, Inc. 87-19 3. Address 8. APl NUmber P. 0. Box 100360, Anchorage, AK 99510 50- 029-21700 4. Location of well at surface 9. Unit or Lease Name 1788' FSL, 19' FWL, Sec. 1, T11N, R15E, UM Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number 1245' FSL, 1006' FWL, Sec. 1, T11N, R15E, UM L5-16 At Total Depth 11. Field and Pool 1079' FSL, 1212' FWL, Sec. 1, T11N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Li sburne 0i 1 Pool RKB 60' ADL 28320 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116. No. of Completions 03/02/87 03/14/87 06/02/87* N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+TVD) 19. DirectionalSurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 9575'MD, 9312'TVD 9479'MD, 9224'TVD YES~ NO [] 2215' feetMDI 1900' (approx) 22. Type Electric or Other Logs Run DLL/NGT/SP, LDT/CNL/EPT/Cal/GR, CBT, GCT, PDK-100 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 Surf 120' 30" 1800# Pol eset 10-3/4" 45.5# L-80/K-55 Surf 4006' 13-1/2" 1300 sx AS Ill & 325 sx Class G 7-5/8" 33.7# L-80 Surf 9559' 9-7/8" 425 sx Class G : 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) pACKER SET (MD) See attached 3-1/2" 8894 ' 8820 ' / 26. ACID, FRACTURE, CEMENT sQuEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Treatnent Procedure/Check Sheet and Results for st mu]ation data 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ I '~low Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ i 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None i - · Note: Drilled RR 03/17/87. Perforated well and tubing run 06/02/87. Form 10-407 WC~/1U: DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29~. ..¢.'~ _. , , 30. GEOLOGIC MARKERS FORMATION TESTS , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Wahoo Zone 6 8902' 8693' N/A Top Wahoo Zone, 5 -, 8988' 8773' Top Wahoo Zone 4 9093' 8870' Top Wahoo Zone 3 9294' 9054' Top Wahoo Zone 2 9342' 9098' I 31. LIST OF ATTACHMENTS Treatment Procedure/Check Sheet and Results :32. I hereby certify that the foregoing is true and correct to the best of my knowledge Sigm~-d ~..~/I'U);L.~. ,)C>~b~czk...~ Title Associate 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' If no cores taken, indicate "none". Form 10-407 WELL COMPLETION OR RECOMPLETION REPORT AND LOG L5-16 (cont'd) Item #24- Perforation depth MD TVD 8964 -8984 9000 -9042 9044 -9056 9062 -9072 9110 -9120 9132 -9142 9148 -9158 9178 -9198 8751 -8769 8784 -8823 8824 -8836 8841 -8850 8885 -8894 8905 -8915 8920 -8929 8948 -8966 Perforated w/0.5 spf, 0° phasing WC3/18a 07-01-87 LISBURNE L5-16 TREATMENT PROCEDURE/CHECK SHEET AND RESULTS 1. Circulat~ through bypass, pump '/~Xbbls acid. 2. Displace acid to bypass with ~ bbl brine. 3. Close bypass. 4. Establish injection rate at /3o~ psi at z_ BPM. 5. Squeeze 10 bbl acid from 9198'-g188'MD. Initial pressure /~a- psi at ~__ BPM. Broke back to /.is-6 psi. Initial casing pressure ,~o~ psi and<~)~~/decreased to ~o~, psi. 6. Pick up 10' to ~178'. 7. Squeeze 10 bbl acid from 9188'-9178'MD. Initial pressure/~-o psi at J BPM. Broke back to -~ psi. Initial casing pressure ~ pst and 4~)~~i~/decreased to ~ s~ psi. 8. PU 30' to 9148'. 9. Squeeze 10 bbl acid from 9158'-9148'MD. Initial pressure/~m.~, psi at i~ BPM. Broke back to --- psi. Initial casing pressure ~m~ psi and ~/decreased to '7~a psi. 10. PU 16' to 9132'. 11. Squeeze 10 bbl acid from 9132'-9142'MD. Initial pressure /Z~ psi at ~_ BPM. Broke back to ~ psi. Initial casing pressure I~__o- psi and ~ased/]~ecreased to ~ao psi. 12. PU 22' to 9110'. Squeeze 10 bbl acid from g120'-9110'MD. Initial pressure y~o~ psi at ~BPM. Broke back to ~ psi. Initial casing pressure ~- psi and increased/decreased to -- psi. 13. PU 30' to 9080'. Sque~eze~bbls acid from 9084'-9080'MD. Initial pressure ~x~psi at z~- BPM. Broke~back to /J~° psi. Initial casing pressure ~ psi and ~Jl_l:]~~l/decreased to ~ psi. 14. PU 18' to 9062'. Squeeze 10 bbl ,~cid from 9062'-9072'MD. Initial pressure /z~ psi at ~ BPM. Broke back to /~xoopsi. Initial casing pressure~-~ psi and i~_r~d/decreased to ~,~>~ psi. 15. Open bypass and circulate~',~bbl acid displaced by ~> bypass. bbl brine to LWPS/Sc 05-20-87 LISBURNE L5-16 TREATMENT PROCEDURE/CHECK SHEET AND RESULTS 16.. Close by. pass. 17. PU 16 'to 9046'. Squeeze 10 bbl acid from 9056'-9046'MD. Initial pressure /Y~ psi at ~ BPM. Broke back to ~mpsi. Initial casing pressure c~-~. psi and ~ed/decreased to ?~> psi. 18. PU 10' to 9036'. Squeeze 10 bbl acid from 9046'-9036.'MD. Initial pressure ~ psi at ~ BPM. BroKe back to ~- psi. Initial casing pressure F~ psi and i4~)~)~;~d/decreased to boo psi. lg. PU 10' to 9026'. Squeeze 10 bbl acid from 9036'-9026'MD Initial pressure ~ psi at ~- BPM. Broke back. to ~- psi. initial casing pressure ~'-em psi and i~/decreased to -r~o psi. 20. PU 10' to 9016'. Squ~eeze 10 bbl acid from 9026'-9016'.MD Initial pressure f~ psi at ~ BPM. Broke back to --- psi initial casing pressure ~a: psi andc]~Z~I~sed/decreased to ~ psi. 21. PU 10' to 9006'. Squeeze 10 bbl acid from 9016'-9006'MD. Initial pressure/~6ea psi at ~ BPM~_ Broke back to ~ psi. Initial casing pressure ~ psi and ~/decreased to ~t~o psi. 22. PU 6' to 9000'. Squeeze J~bbl acid from 9000'-9006'MD. Initial pressure /?'mm psi at ~ ~. Broke back to /~ psi. Initial casing pressure.ya~ psi and ~_o_Cd~stl/decreased to' ~o psi. · 23. Open bypass and circulate~O bbl acid, displaced by ~ bbl brine to brine. 24. Close bypass. 25. PU 26' to 8974'. _ueezeZSbblacid from 8984'-8974'MD Initial pressure® psi at B~I~. Broke back to/~ a~ psi. initial casing pressure J-~J psi and~/decreased to ~ psi. LWPS/5c 05-20-87 LISBURNE L5-16 TREATMENT PROCEDURE/CHECK SHEET AND RESULTS 26. PU 10' -to 8964'. S Z~p~.~'bbl acid from 8974'-8964'MD. Initial pressure/&%~ psi at q~_e Broke back to [ ~<~'~ psi. Initial casing pressure "g~, psi ~ncreased/~.~:i~;-~d to ~o psi. LWPS/Sc 05-19-87 $ UB.$ URFA CE DIRECTIONAL SURVEY r~-~ UIDANCE r~-~ ONTINUOUS F'fl OOL Company ARCO ALASKA, INC. Well Name LISBURNE L5-16(1788' FSL,19' FWL~SECI~TllN,R15E,UM) I=ield/I. ocation PRUDHOE BAY/LISBURNE POOL,NORTI-I SLUICE.ALASKA Job Reference No. Date 72266 19-MAR-87 LogGed B~ Computed By: RUBENSTEIN SINES SCHLUMBERGER GCT DIRECTIONAL SURVEY C~JSTOMER LISTING FOR ARCO ALASKA, INC. LISBURNE L5-16 PRUDHOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA SURVEY DATE: 19-MAR-87 ENGINEER: RUBENSTEIN METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTM INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 66 DEG 35 MIN EAST COMPUTATION DATE.* 8-APR-87 PAGE I ARCO ALASKA, INC. LISBURNE L5-16 PRUDHOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA DATE OF SURVEY: 19-MAR-87 KELLY BUSHING ELEVATION: 60.00 PT ENGINEER: RUBENSTEIN INTERPOLATED VALUES FOR EVEN 100 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 PEET DEG MIN 0.00 0.00 -60.00 0 0 N 0 0 E 100.00 100.00 40.00 0 11 S 13 30 W 200.00 200.00 1¢0.00 0 5 S 10 41 W 300.00 300.00 240.00 0 9 S 4 35 W 400.00 400.00 340.00 0 13 S 26 28 W 500.00 500.00 440.00 0 27 S 23 16 W 600.00 599.99 539.99 0 43 S 18 31 W 700,00 699.98 639.98 0 50 S 8 17 W 800.00 799.97 739.97 0 35 S 2 4 E 900.00 899.97 839.$7 0 29 S 9 30 E 0.00 0.00 0.00 N 0.00 E 0.02 0.25 0.26 S 0.09 W 0.07 0.00 0.46 S 0.13 W 0.11 0.25 0.63 S 0.15 W 0.15 0.03 0.98 S 0.26 W 0.12 0.20 1.52 S 0.53 W 0.14 0.17 2.45 $ 0.91 W 0.39 0.02 3.79 S 1.21 W 0.78 0.04 5.03 S 1.35 W 1.20 0.03 5.98 S 1.28 W 0.00 N 0 0 E 0.Z8 S 19 57 W 0.48 S 15 27 W 0.64 S 13 7 W 1.01 S 15 2 W 1.61 S 19 11 " 2.62 S ZO 25 3.98 S 17 44 W 5.20 S 14 51 W 6.12 S 12 5 W 1000.00 999.96 939.96 1100.00 1099.96 1039.96 1200.00 1199.96 1139.96 1300.00 1299.96 1239.96 1400.00 1399.95 1339.95 1500.00 1499.95 1439.95 1600.00 1599.95 1539.95 1700.00 1699.95 1639.95 1800'.00 1799.95 1739.95 1900.00 1899.94 1839.94 0 26 S 14 59 E 0 28 S 13 11 E 0 28 S 11 49 E 021 S 8 2 E 0 11 S 12 57 E 0 4 S 25 0 E 0 6 N 79 20 E 0 19 N 57 59 E 042 N 45 ? E 0 43 N 29 37 E 1.67 0.09 6.82 S 1.14 2.17 0.11 7.63 S 0.94 2.69 0.21 8.43 S 0.72 3.09 0.26 9,07 S 0.57 3.31 0.21 9.51 S 0.52 3.45 0.11 9.80 S 0.48 3.60 0.32 9.89 S 0.36 3.86 0.31 9.72 S 0.00 ~.23 0.22 9.12 S 0.66 4.58 0.18 8.13 S 1.4]' 6.91 S 9 28 W 7.69 S 6 59 W 8.46 $ 4 51 W 9.09 S 3 34 W 9.53 S 3, 6 W 9.81 S 2 49 W 9.~9 S 2 3 W g.72 S 0 0 E 9.14 $ 4 6 E 8.16 S I0 15 E 2000.00 1999.93 1939.93 2100.00 2099.92 2039.92 2200.00 2199.87 2139.87 2300.00 2299.79 2239.79 2400.00 2399.66 2339.66 2500.00 2499.55 2439.55 2600.00 2599.45 2539.45 2700.00 2699.37 2639.37 2800.00 2799.30 2739.30 2900.00 2899.23 2839.23 0 52 N 24 23 E 1 20 N 24 10 E I 59 N 29 35 E 2 38 N 38 53 E 2 53 N 44 9 E 2 37 N 54 25 E 2 3I N 62 15 E 2 8 N 64 13 E 2 7 N 65 14 E 2 18 N 68 15 E 4.63 0.34 6.91 S 2.05 4.65 0.85 5.23 S 2.81 4.82 0.60 2.64 S 4.11 5.60 0.72 0.72 N 6.42 7.17 0.19 4.39 N 9.71 9.21 0.56 7.56 N 13.32- 11.82 0.38 9.83 N 17.14 14.41 0.24 11.65 N 20.75 16.85 0.04 13.24 N 24.10 19.52 0.00 14.77 N 27.67 7.21 S 16 31 E 5.94 S 28 11 E 4.89 S 57 15 E 6.46 N 83 36 E 10.66 N 65 40 E 15.51 N 60 24 ~ 19.76 N 60 8 E } 23.80 N 60 41 i 27.50 N 61 13 E 51.37 N 61 54 E 3000.00 2999.14 2939.1~ 3100.00 3099.06 3039.06 3200.00 3198.99 3138.99 3300.00 3298.85 3238.85 3400.00 3398.60 3338.60 3500.00 3498.14 3438.14 3600.00 3597.41 3537.41 3700.00 3696.40 3636.40 3800.00 3795.06 3735.06 3900.00 3893.65 3833.65 2 18 N 74 58 E 2 17 N 82 45 E 2 26 S 84 30 E 3 39 S 69 2 E 4 33 S 60 7 E 6 18 S 44 27 E 7 27 S 32 42 E 8 46 S 23 53 E 9 49 S 16 51 E 9 23 S 11 36 E 22.49 0.40 16.09 N 31.48 25.76 0.22 16.84 N 35.37 29.42 0.78 16.98 N 39.41 34.53 1.39 15.73 N 44.45 41.61 1.60 12.64 N 50.83 50.72 1.97 6.82 N 58.23 61.20 1.63 Z.65 S 65.55 72.30 1.50 15.21 S 72.20 83.53 1.02 30.47 S 77.83 93.87 1.11 46.67 S 82.08 35.35 N 62 55 E 39.17 N 64 32 E 42.91 N 66 41E ¢7.15 N 70 30 E 52.38 N 76 I E 58.62 N 83 18 E 65.60 S 87 41 E 73.78 S 78 6 ~ 83.58 S 68 37 E 94.42 S 60 22 E ARCO ALASKAt INC. LISBDRNE 15-16 PRUDHOE BAY/LISBURNE POOL NORTH SLOPEtALASKA COMPUTATION DATE: 8-APR-87 PAGE DATE OF SURVEY: 19-MAR-87 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: RUBENSTEIN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTM TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HIM DEG MIN 4000.00 3992.10 3932.10 11 6 4100.00 4090.27 4030.27 10 41 4200.00 4188.75 4128.75 4300.00 4287.66 4227.66 4400.00 4386.93 4326.93 4500.00 4486.41 4426.41 4600.00 4586.05 4526.05 4700.00 4685.79 4625.79 4800.00 4785.61 4725.61 4900.00 4885.46 ~825.46 S 5 47 F. S 4 42 E 9 ZO S 3 27 E 7 30 S 2 56 E 622 S 1 10 E 5 16 S 3 4O W 4 29 S 6 33 W 3 43 S 7 30 W 318 S 5 35 W 2 53 S 3 45 ~ 5000.00 4985.35 4925.35 5100.00 5085.27 5025.27 5200.00 5185.20 5125.20 5300.00 5285.16 5225.16 5400.00 5385.13 5325.13 5500.00 5485.12 5425.12 5600.00 5585.11 5525.11 5700.00 5685.09 5625.09 5800,00 5785.08 5725.08 5900.00 5885.07 5825.07 2 28 S 0 25 E 2 17 S 0 54 E 145 S 3 38 E 1 28 S 7 47 E I 10 S 12 6 E 0 59 S 7 19 E 053 S 1 19 E 0 52 S 1 35 E 047 S 4 32 E 0 46 S 21 42 E 6000.00 5985.05 5925.05 1 34 6100.00 6084.97 6024.97 3 8 6200.00 6184.73 6124.73 4 49 6300.00 6284.19 6224.19 6 59 6400.00 6383.20 6323.20 9 2 6500.00 6481.71 6421,71 10 34 6600.00 6579.74 6519.74 12 1 6700.00 6677.32 6617.32 13 25 6800.00 6774.11 6714.11 15 40 6900.00 6869.85 6809.85 17 50 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG MIN 7000.00 6964.42 6904.42 20 6 7100.00 7057.54 6997.54 22 33 7200.00 7149.00 7089.00 25 8 7300.00 7238.76 7178.76 26 50 7400.00 7327.95 7267.95 26 52 7500.00 7417.22 7357.22 26 42 7600.00 7506.66 7446.66 26 23 7700.00 7596.35 7536.35 26 7 7800.00 7686.26 7626.26 25 47 7900.00 7776,45 7716.45 25 20 · 103.12 1.18 64.00 112.23 1.04 82.92 120.23 1.22 100.22 126.86 1.54 114.92 132.13 1.28 126.97 135.89 1.17 137.07 138.54 0.92 145.56 140.46 0.84 152.61 142.20 1.01 158.68 143.89 0.84 164.04 145.58 0.53 168.71 S 147.30 0.22 172.84 S 148.85 0.22 176.35 S 150.27 0.00 179.19 S 151.58 0.53 181.51 S 152.52 0.49 183.29 S 153.27 0.41 184.94 S 153.92 0.41 186.54 S 154.57 0.43 188.07 S 155.33 0.48 189.37 S S 55 9 E 157.08 1.15 S 67 55 E 161.05 2.03 S 75 25 E 167.87 2.40 S 79 45 E 177.98 2.01 S 80 50 E 191.53 2.15 S 80 15 E 208.23 1.31 S 79 3 E 227.43 1.06 S 76 53 E 248.86 2.31 S 76 44 E 273.58 2.17 S 76 1 E 301.99 2o4~ 84.66 E 106.13 S 52 54 E 86.39 E 119.74 S 46 10 E 87.6Z E 133.12 5 41 9 E 88.47 E 145.03 S 37 35 E 89.00 E 155.06 S 35 I E 88.7Z E 163.28 S 32 54 ~, 87.93 E 170.06 S 31 8 E 'I , 86.96 E 175.65 S 29 40 E 86.23 g 180.59 S 28 31 E 85.75 E 185.10 S 27 35 E S 74 37 E S 73 11E S 72 10 E S 71 22 E S 71 12 E S 71 4 E S 70 52 E S 70 41E S 70 S 68 41 E 85.58 E 189.17 S 26 53 E 85.66 E 192.90 S 26 21 E 85.83 E 196.13 S 25 57 E 86.15 ~ 198.82 S 25 40 E 86.51 E 201.09 S 25 29 E 86.82 E 202.82 S 25 20 E 86.93 E 204.35 S 25 10 E 86.94 ~ Z05.81 S 24 59 E 86.98 E 207.21 $ 24 49 E 87.25 E 208.50 S 24 44 E 190.77 S 88.55 E 210.32 S 26 54 E 192.60 S 92.08 E 213.48 S 25 33 E 194.77 S 98.5U E 218.29 S 26 50 E 196.88 S 108.68 E 2Z4.89 S 28 53 E 199.15 S 122.46 f 233.79 S 31 35 E 201.91 S 139.46 E 245.40 S 34 38 5 205.52 S 158.83 E 259.74 S 37 41 E } 210.05 S 180.22 E 276.77 S 40 37 E 215.85 S 204.64 E 297.44 S 43 28 E 222.60 S 232.68 E 322.01 S 46 16 E 334.10 2.49 370.22 2.45 410.39 Z.41 454.29 0.43 499.37 0.12 54~.29 0.11 588.89 0.40 632.98 0.18 676.66 0.44 719.81 0.88 230.84 S 264.11 E 350.77 S 48 50 E 240.98 S 299.08 E 384.08 S 51 8 E 253.01 S 337.64 E 421.92 S 53 9 E 266.86 S 379.48 E 463.92 S 54 ~3 E 281.37 S 422.32 E 507.47 S 56 19 E 295.96 S 464.96 E 551.16 S 57 31 E 310.52 S 507.2b E 594.T6 S 58 31 E 325.08 S 549.00 E 638.03 S 59 22 E 339.76 S 590.25 ~ 681.05 S 60 4 E 354.93 S 630.70 E 723.?1 S 60 37 E ARCO ALASKA, INC. LISBURNE L5-16 PRUDHOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA , _ COMPUTATION DATE: 8-APR-87 PAGE .3 DATE OF SURVEY: 19-MAR-SZ KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: RU6ENSTEIN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 8000.00 7867.04 7807.04 24 46 8100.00 7958.01 7898.01 24 12 8200.00 8049.42 7989.42 23 41 8300.00 8141.04 8081.04 23 39 8400.00 8232.71 8172.71 23 28 8500.00 8324.37 8264.37 23 35 8600.00 8416.04 8356.04 23 30 8700.00 8507.74 8447.74 23 32 8800.00 8599.47 8539.47 23 20 8900.00 8691.59 8631.59 22 23 VER'TICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTUkE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET PEET DEG MIN 9000.00 8784.15 8724.15 22 20 9100.00 8876.40 8816.40 23 Z 9200.00 .'8968.28 8908.28 23 28 9300.00 9059.93 8999.93 23 34 9400.00 9151.65 9091.65 23 28 9500.00 9243.38 9183.38 23 28 9575.00 9312.17 9252.17 23 28 S 67 38 E 762.15 S 66 53 E 803.66 S 65 18 E 844.20 S 63 54 E 884.27 S 62 10 E 924.12 S 60 55 E 963.94 S 59 14 E 1003.64 S 57 35 E 1043.13 S 56 7 E 1082.38 S 54 38 E 1120.52 S 53 13 E 1157.48 S 51 23 E 1194.87 S 50 36 E 123Z.90 S 50 7 E 1271.33 S 50 1 E 1309.48 S 50 1 E 1347.66 S 50 1 E 1376.29 0.58 1.20 0.93 0.85 0.65 0.60 0.78 0.59 0.85 1.04 370.72 S 670.00 E 765.72 S 61 2 E 386.72 S 708.30 E 807.00 S 61 21 E 403.12 S 745.38 ~ 847.40 S 61 35 E 420.32 S 781.60 f 887.45 S 61 43 E 438.47 S 817.16 E 9Z'7.36 S 61 46 E 457.49 S 852.32 E 967.34 S 61 46 E 477.40 S 886.96 E 1007.27 S 61 42 f ) 498.32 S 920.9~ E 1047.11 S 61 34 E 5Z0o06 S 954.30 E 1086.80 S 61 24 E 54Z.17 $ 986,28 E 1125.48 $ 61 12 E 0.90 0.73 0.52 0.57 0.00 0.00 0.00 564.45 S 1016.91 E 1163.06 S 60 58 E 588.10 S 1047.41 E 1201.22 S 60 41 E 612.97 S 1078.08 f 1240.16 S 60 22 E 638.45 S 1108.92 E 1279.58 5 60 4 E 664.05 S 1139.41 E 1318.80 S 59 45 E 689.64 S 1169.99 E 1358.07 S 59 28 E 708.83 S 1192.82 E 1387.54 S 59 16 E ARCO ALASKA, INC. LISBURNE L5-16 PRUDHOE 8AY/LISBURNE POOL NORTH SLOPE,ALASKA COMPUTATION DATE~ 8-APR-87 PAGE -~. DATE OF SURVEY: 1g-MAR-8? KELLY BUSHING ELEVATION: 60.00 PT ENGI, NEER: RUBENSTEIN INTERPOLATED VALUES FOR EVEN 1000 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -60.00 0 0 1000.00 999.96 939.96 0 26 2000.00 1999.93 1939.93 0 52 3000.00 2999.14 Z939.14 2 18 4000.00 3992.10 3932.10 11 6 5000.00 4985.35 4925.35 Z 28 6000.00 5985.05 5925.05 I 34 7000.00 6964.42 6904.42 20 6 8000.00 7867.04 7807.04 24 46 9000.00 8784.15 8724.15 22 20 VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 O E 0.00 0.00 S 14 59 E 1.67 0.09 N 24 23 E 4.63 0.34 N 74 58 E 22.49 0.40 S 5 47 E 103.12 1.18 S 0 25 E 145.58 0.53 S 55 9 E 157.08 1.15 S 74 37 E 334.10 2.49 S 67 38 E 762.15 0.58 S 53 13 E 1157.48 0.90 0.00 N 0.00 E 0.00 N 0 0 E 6.82 S 1.14 W 6.91 S 9 28 W 6.91 S 2.05 E 7.Z1 S 16 3I ~ 16.09 N 31.48 E 35.35 N 62 55 b 64.00 S 84.66 E 106.13 S 52 54 ~ 168.71 S 85.58 E 189.17 S Z6 53 E 190.77 S 88.55 E 210.32 S 24 54 { '! 230.84 S 264.11 E 350.77 S 48 50 ~ 370.72 S 670.00 E 765.72 S 61 2 E 564.45 S 1016.91 E 1163.06 S 60 58 E 9575.00 9312.17 9252.1'7 23 28 S 50 i E 1376.29 0.00 708.83 S 1192.82 E 1387.54 S 59 16 E ARCO ALASKA~ INC. LISBURNE L5-16 PRUDHOE 8AY/LISBURNE POOL NORTH SLOPEtALASKA COMPUTATION DATE: 8-APR-87 PAGE - 5 DATE OF SURVEY: ig-M:AR-S7 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: RUBENSTEIN 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 MIN 0.00 0.00 -60.00 0 0 N 0 0 E 60.00 60.00 0.00 0 50 S 24 6 W 160.00 160,00 100,00 0 6 S 7 36 W 260,00 260,00 200,00 0 4 S 5 4 W 360,00 360,00 300,00 0 13 S 22 2 W 460,00 460.00 400.00 0 2! S 27 1'1 W 560.01 560,00 500,00 0 35 S 22 30 W 660.01 660.00 600.00 0 47 S 10 32 W 760.02 760.00 700.00 0 38 S 4 26 W 860,03 860,00 800,00 0 32 S 2 37 E 960.03 960.00 900.00 1060.04 1060.00 1000.00 1160.04 1160.00 1100.00 1260.04 1260.00 1200.00 1360.04 1360.00 1300.00 1460,05 1460.00 1400.00 1560,05 1560o00 1500.00 1660.05 1660.00 1600.00 1760405 1760.00 1700.00 1860.05 1860.00 1800.00 0 29 S 8 56 E 0 30 S 12 40 E 0 28 S 16 30 E 0 20 S 15 29 E 0 13 S 6 37 E 0 9 S 2 40 E 0 6 S 51 25 E 0 15 N 65 31 E 0 33 N 46 33 E 0 44 N 38 35 E 1960.06 1960.00 1900,00 2060.08 2060,00 2000.00 2160.11 2160.00 2100.00 2260.17 2260.00 2200.00 2360.28 2360.00 2300.00 2460.41 2460.00 2400.00 2560.51 2560.00 2500.00 2660.60 2660.00 2600.00 2760.68 2760.00 2700.00 2860.74 2860.00 2800.00 0 45 N 24 24 E 1 3 N 23 48 E 1 43 N 27 lO E 2 26 N 35 21 E 2 53 N 42 21 E 2 43 N 49 38 E 2 31 N 60 40 f Z 14 N 63 54 E 2 7 N 64 27 E 2 lb N 67 6 E 2960.82 2960.00 2900.00 3060,90 3060.00 3000.00 3160.99 3160.00 3100.00 3261.09 3260.00 3200.00 3361,29 3360.00 3300.00 3461.65 3460.00 3400.00 3562.28 3560.00 3500.00 3663.19 3660.00 3600,00 3764.43 3760.00 3700.00 3865.89 3860.00 3800.00 2 18 h 71 38 E 2 15 N 80 12 E 2 18 N 89 0 E 3 5 S 75 12 E 4 7 S 63 28 E 5 39 S 50 13 E 7 2. S 36 0 E 8 23 S 26 41 E 9 35 S 19 19 E 9 33 S 14 4 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURf SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET gEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.05 0,07 0,40 S 0,12 W 0.09 0.02 0.54 S 0.14 W 0.15 0.03 0.84 S 0.20 W 0,12 0,16 1,26 S 0,41 W 0,10 0,36 2,03 S 0,76 W 0,25 0,23 3,23 S 1,13 W 0.61 0.57 4.60 S 1.33 W 1,03 0,27 5,63 S 1,37. W 0.00 N 0 0 E 0.00 N 90 0 E 0.41 S 16 26 W 0.56 S 14 31 W 0.86 S 13 15 W 1.33 S 18 4 W 2.11 S ZO 39 ~ ~ 3.42 S 19 14 W 4.79 S 16 7 W 5.79 S 13 10 W' 1.48 0.16 6.50 S 1.20 1.97 0.06 7.30 S 1.01 2.48 0.29 8.09 S 0.80 2.94 0.03 8.83 S 0.62 3,23 0.30 9.38 S 0.5~, 3.41 0,28 9.72 S 0.49 3.54 0.16 9.87 S 0.42 3,74 0.06 9.81 S 0.18 4.06 0.35 9.43 S 0.34 4.48 0,28 8.55 S 1.18 6,61 S 10 30 W 7,36 S 7 53 W 8,13 S 5 37 W 8.86 S 4 1 W 9,39 S 3 18 W 9.74 S 2 54 W 9.88 S Z 25 W 9.81 S I 1 w 9.43 S 2 ~ E 8.63 S 7 52 E 4.62 0.09 7.43 S 1.82 4.65 0.47 5.99 S 2.41 4.71 0.93 3.78 S 3.49 5,18 0,87 0.69 S 5.35 6.49 0.10 2.93 N 8.34 8.33 0.91 6.44 N 11.86 10.74 0.23 9.00 N 15.60 13.43 0.31 10.99 N 19.40 15.89 0.00 12.62 N 22.78 18.42 0.31 14.18 N 26.2.2 7.65 S 13 44 E 6.48 S 22 22 E 5.15 S 42 43 k 5.39 S 82 39 E 8.85 N 70 37 E 13.50 N 61 31 ~ 18.01 N 60 0 E ') 22.29 N 60 28 ~. 26.04 N 61 1 E 29.80 N 61 35 E 21.28 0.47 15.64 N 29.96 t~ 24.44 0.26 16.61 N 33.8.3 E 27.92 0.71 17.04 N 37.81 E 32.23 1.75 16.45 N 42.25 E 38.70 1.00 14.03 N 48.25 E 46.94 2.58 9.53 N 55.29 E 57.18 1.72 1.29 N 62.8'1 E 68.17 1.70 10.24 S 69.85 E 79.55 1.64 24.77 S 75.97 E 90.54 1.33 41.21 S 80.8l E 33.80 N 62 26 E 37.69 N 63 51 E 41.47 N 6b 44 E 45.34 N 68 43 E 50.24 N 73 47 E 56.10 N BO 1Z ~ 62.89 N 88 ~9 f 70.60 S 81 39 f 79.90 S 71 56 E 90.72 S 62 58 f COMPUTATION DATE: 8-APR-87 PAGE 6 ARCO ALASKA, INC. LISBURNE L5-16 PRUDHOE 8AY/LISBURNE POOL NORTH SLOPEgALASKA DATE OF SURVEY: 19-MAR-87 KELLY BUSHING ELEVATZON: 60.00 FT ENGINEER: RUBENSTEIN 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 MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 3967.32 3960.00 3900.00 10 23 4069.18 4060.00 4000.00 10 51 4170.84 4160.00 4100.00 4272.09 4260.00 4200.00 4372.90 4360.00 4300.00 4473.47 4460.00 4400.00 4573.87 4560.00 4500.00 4674.15 4660.00 4600.00 4774.35 4760.00 4700.00 4874.51 4860.00 4800.00 S 7 37 E S 5 4 E 942 S 3 39 E 8 0 S 3 8 E 6 40 S 2 27 E 532 S 3 5 W 443 S 6 20 W 354 S 8 3 W 327 S 6 25 W 3 2 S 4 54 W 100.06 2.99 57.91 S 109.50 0.29 77.17 S 118.04 1.24 95.40 S 125.17 2.00 111.15 S 130.82 1.1T 123.89 S 135.04 0.91 134.59 S 137.93 0.85 143.48 S 139.99 0.65 150.90 S 141.74 0.30 157.17 S 143.46 0.37 162.73 S 83.96 E 102.00 S 55 24 E 85.90 E 115.48 S 48 3 E 87.32 E 129.33 S 42 27 E 88.27 E 141.94 S 38 27 E 88.90 E 152.49 S 35 39 E 88.87 E 161.Z8 S 33 26 E 88.16 E 168.40 S 31 34 E 87.20 E 174.28 $ 30 I E 86.39 E 179.35 S 28 47 E 85.86 E 183.99 S 27 48 E 4974.62 4960.00 4900.00 5074.72 5060.00 5000.00 5174.79 5160.00 5100.,00 5274.83 5260.00 5200.00 5374.86 5360.00 5300.00 5474.88 5460.00 5400.00 5574.89 5560.00 5500.00 5674.91 5660.00 5600.00 5774,92 5760.00 5700.00 5874.93 5860.00 5800.00 2 35 S 1 44 W 218 S 0 3 W 1 50 S 4 13 E 1 31 S 7 58 E 1 16 S 13 25 E .1. 0 S 6 37 E 0 55 S 4 37 E 0 55 S 2 23 E 0 50 S 4 50 E 0 43 S 14 40 E 145.15 0.79 167.59 S 146.89 0.12 171.83 S 148.49 0.60 175.56 S 149.93 0.39 178.53 S 151.26 0.5~ 180.98 S 152.30 0.21 182.85 S 153.10 0.65 184.55 S 153.76 0.36 186.15 S 154.40 0.80 187.71 S 155.11 0.32 189.06 S 85.59 E 188.18 S 27 3 E 85.65 f 191.99 5 g6 29 E 85.7~ 6 195.39 S Z6 2 E 86.06 E 198.19 5 Z5 44 E 86.45 E 200.57 S 25 31 E 86.77 E 202.40 S 25 23 E 86.91 f 203.99 S 25 12 E 86.93 E 205.45 S 25 1 E 86.95 E 206.88 S Z4 51 E 87.14 E 208.18 S Z4 44 E 5974.9~ 5960.00 5900.00 1 19 6075.00 6060.00 6000.00 2 39 6175.19 6160.00 6100.00 4 18 6275.64 6260.00 6200.00 6 29 6376.52 6360.00 6300.00 8 34 6477.93 6460.00 6400.00 10 19 6579.83 6560.00 6500.00 11 47 6682.20 6660.00 6600.00 13 2 6785.36 6760.00 6700.00 15 21 6889.66 6860.00 6800.00 17 36 S 50 23 f S 64 53 E S 72 56 E S 79 10 E S 80 54 E S 80 33 E S 79 10 E S 77 20 E S 76 40 E S 76 9 E 156.47 1.10 159.79 1.96 165.92 2.08 175.20 2.09 188.05 1.92 204.34 0.99 223.38 1.19 244.8~ 2.12 269.74 Z.2O 298.88 2.31 190.39 S 88.05 E 209.76 S 24 49 E 192.10 S 90.93 E 212.54 5 15 19 E 194.23 S 96.69 E 216.97 S 26 27 f 196.36 S 105.88 E 223.09 S 28 20 E 198.58 S 118.92 E 231.46 S 30 54 E 201.25 S 135.52 E 242.62 S 33 57 E 204.73 S 154.76 f 256.64 S 37 5 E 209.13 S 176.23 E 273.48 S 40 7 E 214.95 S 200.85 e 294.18 S 43 3 E 221.84 S 229.6Z E 319.28 S 45 59 e 6995.28 6960.00 6900.00 19 59 7102.66 7060.00 7000.00 22 37 7212.18 7160.00 7100.00 25 26 7323.81 7260.00 7200.00 26 55 7435.92 7360.00 7300.00 26 48 7547.87 7460.00 7400.00 26 35 7659.50 7560.00 7500.00 26 12 7770.82 7660.00 7600.00 25 53 7881.80 7760.00 7700.00 25 27 7992.25 7860.00 7800.00 24 49 S 7w 41 E S 73 9 E S 72 2 E S T1 19 E S 71 6 E S 71 1 E S 70 45 E S 70 16 E S 69 0 E S 67 41E 332.4T 2.48 371.23 2.44 415.60 2.43 465.00 0.03 515.53 0.38 565.70 0.40 615.17 0.24 663.97 0.58 712.01 1.08 758.91 0.58 230.39 S 262.52 E 349.28 S 48 43 E 241.27 S 300.05 E 385.02 S 51 11 E 254.62 S 342.62 E 426.88 S 53 22 E 270.30 S 389.67 E 474.24 S 55 15 f 286.61 S 437.68 E 523.17 S 56 46 f 302.93 S 485.27 E 572.06 S 58 1 E 319.18 S 532.15 E 620.53 S 59 2 E 335.44 S 578.26 E 668.53 S 59 52 E 352.11 S 623.4Z E 715.99' S 60 32 ~ 369.49 S 667.00 E 762.50 S 61 0 E ARCO ALASKA, INC. LISBURNE L5-16 PRUDHOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA COMPUTATION DATE: 8-APR-87 PAGE .7 DATE DF SURVEY: 19-MAR-87 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: RUBENSTEIN 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 MIN 8102.19 7960.00 7900.00 24 8211.55 8060.00 8000.00 23 38 8320.70 8160.00 8100.00 23 36 8429.76 8260.00 8200.00 23 32 8538.87 8360.00 8300.00 23 33 8647.93 8460.00 8400.00 23 30 8756.99 8560.00 8500.00 23 28 8865.78 8660.00 8600.00 22 44 8973.91 8760.00 8700.00 22 13 9082.18 8860.00 8800.00 22 55 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 9190.97 8960.00 8900.00 23 25 9300.07 9060.00 9000.00 23 34 9409.10 9160.00 9100.00 23 28 9518.12 9260.00 9200.00 23 28 9575.00 9312.17 9252.17 23 28 S 66 52 E 804.56 S 65 5 E 848.83 S 63 30 E 892.55 S 61 49 E · 935.95 S 60 19 E 979.40 S 58 23 E 1022.58 S 56 49 E 1065.56 S 55 6 E 1107.66 S 53 36 E 1147.86 S 51 37 E 1188.15 S 50 38 E 1229.44 S 50 7 E 1271.36 S 50 I E 1312.96 S 50 I E 1354.58 S 50 I E 1376.29 1.25 0.76 0.84 0.58 0.62 0.61 0.60 1.28 0.6'7 0.97 387.07 S 709.13 E 807.89 S 61 22 E 405.06 S 749.59 E 852.03 S 61 36 E 424.01 S 789.02 E 895.73 S 61 44 E 444.04 S 827.64 E 939.Z3 S 61 47 465.11 S 865.87 E 982.89 $ 61 45 E 487.29 S 903.32 E 1026.37 S 61 39 510.63 S 940.05 E 1069.78 S 61 29 534.62 S 975.54 E 1112.43 S 61 16 E 558.57 S 1008.96 E 1153.26 S 61 1 583.76 S 1041.96 E 1194.35 S 60 44 E 0.57 0.57 0.00 0.00 0.00 610.69 S 1075.30 E 1236.61 S 60 24 ~ 638.47 S 1108.94 E 1279.61 S 60 4 E 666.38 S 11~2.19 E 1322.37 S 59 44 E 694.28 S 1175.47 E 1365.19 S 59 25 E 708.83 S 1192.82 e 1387.54 S 59 16 e ARCO ALASKA, INC. LISBURNE L5-16 PRUDHOE BAY/LISBURNE POOL NORTH SLOPEsALASKA MARKER TOP WAHOO ZONE 6 TOP WAHOO ZONE 5 TOP WAHOO ZONE 4 TOP WAHOO ZONE 3 TOP WAHOO ZONE 2 PBTD TO COMPUTATION DATE: B-APR-B7 PAGE 8 DATE OF SURVEY: 19-MAR-87 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: RUBENSTEIN INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB 8902.00 8988.00 9093.00 9294.00 9342.00 9479.00 9575.00 SURFACE LOCATION AT ORIGINm 1788 FSL, 19 FWL~ SEC l, TllN~ R15E, UM TYD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH. EAST/WEST 8693.45 8633.45 542.61 S 986.90 E 8773.04 8713.04 561.74 S 1013.25 E 8869.96 8809.96 586.39 S 1045.27 E 9054.44 8994.4e 636.92 S 1107.07 f 9098.43 9038.43 649.22 S 1121.77 f i,~ 9224.11 9164.11 684.27 S 1163.52 E 9312.17 S252.17 708.83 S 1192.82 E COMPUTATION DATE: 8-APR-87 PAGE .9 ARCO ALASKA, INC. LISBURNE L5-16 PRUDHOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA DATE OF SURVEY: 19-MAR-B? KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: RUBENSTEIN ~~~ STRATIGRAPHIC SUMMARY MARKER MEASURED DEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN= 1788 FSL~ 19 FWL, SEC 1, TllN~ R15E~ ~M TVD RECTANGULAR COORDINATES SU~-SEA NORTH/SOUTH EAST/WEST TOP WAHOO ZONE 6 TOP WAHOO ZONE 5 TOP WAHOO ZONE 4 TOP WAHOO ZONE 3 TOP WAHOO ZONE 2 PBTO TD 8902.00 8988.00 9093.00 9294.00 93~2.00 9479.00 9575.00 8693.a5 8633.45 5eZ.61 S 986.90 8773.04 8713.0a 561.?~ S 1013.25 8869.96 8809.96 586.~9 S 1045.27 9054°44 8994.4~ 636.92 S ~07o07 9098.43 9038.43 649.12 $ 1111.77 9224.11 9164.11 684.17 S 1163o52 9312.17 9252.17 ?08.~3 S 1192.82 FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 9575.00 9312.17 9252.17 1387.5% S 59 16 E SCHLUMBERGER O I RECT [ ONAL SURVEY COMPANY ARCO ALASKA, INC. WELL L I SBURNE LS- 1 eS FIELD PRUDHOE BAY/L I SBURNE POOL COUNTRY USA RUN DATE LOOOED REFERENCE FS]A. HELL- LI 3DUI~IIE L~- (1788' FSL, 19' FWL, SEC.1, TllN, R15E,UM) FIUK J./..UPI I ~L rKUUC~I LU~ 400 200 -200 -400 -600 -800 SOUTH - ! 000 -200 WEST :'" ~..?-.?,..-?? ............ ; ...t..?..-~.+*.r.-?--?.-?-?r"?r't'"t-'"r'r"?' '"??r"~"' '-?"r'"~', ..... · ~-? . : ~ ~ ' t · ' ~ , ~ I "'T .......... j ..... :': ~ ....................... ~ :":": ...... :'" ~' : ' :.::'[ '.L.::.::..L.~ ............. : ...... · ....... :..L] ............... ~ ........ :...L..: ..... I ....... ~.~ ~ ~;; J4..i .... ~...~ 1.4..~ ~...~ 0 ~00 400 ~00 800 1000 1200 ] 400 E~T WELL' LISBURNE L5-16 (1788' FSL, 19' FWL, SEC.1, TllN, R15E,UM) VERTICAL PROJECTION :::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::: ............... '"'~ .................................. 'f : .............................. 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I~ {, !{ ! :' :', : ;: : i:i: : : ' :-::,--~-?-~-f:i~ i~ o p..; ........... ;,...~ ............................. ,,~ .~:.~J ...... t,,... ...,...~...~...~ ...... ~ ..L..~ ..: ...... ;...~ ....... ~ ...... ~ ........... 2 I...; ........ :......i ....... ,...~ .......... ;...`...~...L.4...~...:.~.L..*...L..~...Z..z...~..4...:...i...~...:...~...*...~....;...~...~...;...~...~...~...~....i...:....:...z...i...: ........ : ...... l ....... : .............. :..:....;....: ..! i..:: ~ ' ' ~I:' ................. ..... t"'; ................................................................ t t ................. ': l Brlrlt]' :' ' ' * ....... !f::: :ii:: !,f .......... .: : : t ........ ! ..... :'f ....... :': 't''~'':'':'':''''r''~ ..... !""!' -~ TM'' PROJECTION ON VERTICAL PLANE 119. - 295. SCALED IN VERTICAL DEPTHS HORIZ SCALE = l/SOO IN/FT STATE OF ALASKA ALASr~A OIL AND GAS CONSERVATION COk. ,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate ,,~ Pull tubing COMPLETE Alter Casing [] Other X] 2. Name of Operator 5. Datum elevation (DF or KB) Fee¢~ ARCO Alaska, Inc 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1788' FSL, 19' FWL, Sec. 1, T11N, R15E, UM At top of productive interval 1245' FSL, 1006' FWL, Sec. 1, T11N, R15E, UM At effective depth 1104' FSL, 1183' FWL, Sec. 1, T11N, R15E, UM At total depth 1079' FSt., 1212' FWL, Sec. 1, T11N, R15E, UM RKB 50' 6. Unit or Property name Prudhoe Ba~,/Lisburne Unit 7. Well number L5-16 8. Approval number 7-211 9. APl number 50-- 029-21700 10. Pool Lisburne Oil Pool 11. Present well condition summary Total depth: measured true vertical 9575'MD 9312'TVD Effective depth: measured 9479'MD true vertical 9224'TVD Casing Length Size Conductor 80 ' 20" ,Surface 3967' 10-3/4" Producti on 9523 ' 7-5/8" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth True Vertical depth 1800# Pol eset 120 'MD 120'TVD 1300 sx AS III & 4006'MD 3998'TVD 325 sx Class G 425 sx Class G 9559'MD 9297'TVD Perforation depth: measured See attached true vertical See attached Tubing (size, grade and measured depth) 3-1/2", L-80, tbg w/tail ~ 8894' Packers and SSSV (type and measured depth) HB pkr ~ 8820' & TRDP-1A-SSA SSSV ~ 2215' 12. Stimulation or cement squeeze summary See attached Treatment Procedure/Check Sheet and Results, for stimulation data. Intervals treated (measured) Treatment description including VOlumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well Hi story w/Addendum, dated 5/19/87) Daily Report of Well Operations E~ Copies of Logs and Surveys Run E~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~.~- Signed Form 10-404 Rev. 12-1-85 (Dani) SW02/38 Submit in Duplicate REPORT OF SUNDRY WELL OPERATIONS L5-16 (cont'd) Item #11' Perforation depth MD TVD 8964 -8984 9000 -9042 9044 -9056 9062 -9072 9110 -9120 9132 -9142 9148 -9158 9178 -9198 8751'-8769 8784 -8823 8824 -8836 8841 -8850 8885 -8894 8905 -8915 8920 -8929 8948 -8966 Perforated w/0.5 spf, 0° phasing SWO2/38a 06/08/87 ARCO Oil and Gas COmpany Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space' is available. District ICounty or Parish I Alaska Field ILease or Unit I Prudhoe Bay Auth, or W.O. no. ITitle I ~L0397 North Slope Borough ADL #28320 IAccounting cost center code State Alaska Well no. L5-16 Completion Nordic #1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. Old TD 5/31/87 thru 6/01/87 6/02/87 6/03/87 Released rig AP1 50-029-21700 A.R.Co. W.I. rrotal number of wells (active or inactive) on this, lc@st center prior to plugging and 50~ Jabandonment of this well Date IH@ur I Prlor status If a W.O. 5/31/87 ! 0800 Hrs. Complete record for each day reported Classifications (oil, gas, etc.) Oil 7-5/8" @ 9559' 9479' PBTD, Circ 9.3 ppg Brine Accep.t r$~ @ 0800 hfs, 5/31/87. Tst csg to 3000 psi. NU & tst BOPE. Displ diesel cap. RU Gearhart, perf 9198'-9178', 9158'-9148' & 9142'-9132', 9120'-9110' & 9072'-9062', 9084'-9080' & 9056'-9044', 9000'-9042' & 8984'-8964' @ .5 SPF. Lost total of 7 bbls fluid. RU & rn 6.5" GR/JB. ND tree, 7-5/8" @ 9559' 9479' PBTD, NU tree 9.3 ppg Brine C&C, POOH w/3½" tbg. Rn 291 its, 3½", 9.3#, L-80 EUE 8RD tbg w/SSSV @ 2215', HB Pkr @ 8820', TT @ 8894'. Tst tbg to 2500 psi & ann to 1000 psi. Set BPV. ND BOPE, NU tree. 7-5/8'' @ 9559' 9479' PBTD, RR Diesel Tst tree to 5000 psi. Pull tst plug, open SSSV, displ well w/diesel. Tst SSSV; OK. Set BPV. RR @ 1000 hrs, 6/2/87. I New TD I PB Depth 9479' Date Kind of rig 1000 Hrs. 6/02/87 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Lisburne Potential te~t data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected I The above is correct Drillin~ Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. LISBURNE L5-16 TREATMENT PROCEDURE/CHECK SHEET AND RESULTS 1. Circulate through bypass, pump ~O~bbls acid. 2. Displace acid to bypass with ~ bbl brine. 4. Establish injection rate at /3o~ psi at 2_ BPM. 5. Squeeze 10 bbl acid from 9198'-9188'MD. Initial pressure ?~a~ psi at ~ BPM. Broke back to ~.3~-6 psi. Initial casing pressure ~o~ psi and<~[~:]~)~i~/decreased to ~o~ psi. 6. Pick up 10' to 9'178'. 7. Squeeze 10 bbl acid from 9188'-9178'MD. Initial pressure/z~-o psi at ~ BPM. Broke back to .--~ psi. Initial casing pressure ~o~ psi and ~/decreased to ~ psi. 8. PU 30' to 9148'. 9. Squeeze 10 bbl acid from 9158'-9148'MD. Initial pressure/~~ psi at ~ BPM. Broke back to ~ psi. Initial casing pressure ~mo psi and ~/decreased to q~ psi. 10. PU 16' to 9132'. 11. Squeeze 10 bbl acid from 9132'-9142'MD. Initial pressure /~ psi at ~_ BPM. Broke back to -- psi. Initial casing pressure ~__~ psi and <~kc~ased~]~ecreased to ~a~ psi. 12. PU 22' to 9110'. Squeeze 10 bbl acid from 9120'-9110'MD. Initial pressure/~o~ psi at ~-~BPM. Broke back to ~'~ psi. Initial casing pressure -- psi and increased/decreased to -- psi. 13. PU.30' to 9080'. d from 9084 -9080'MD Initial pressure ~x~psi at Squ~eze.~bbls aci ' ~ BPM. Broke back to /~-~ psi. initial casing pressure ~ psi and ~dlI~)~U/decreased to~i~-opsi. 14. PU 18' to 9062'. Squeeze 10 bbl acid from 9062'-9072'MD. Initial pressure /~ psi at ~ BPM. Broke back to /xoopsi. Initial casing pressure~.~-~ psi and in~]_r~d/decreased to ~J psi. 15. Open bypass and circulate ~4) bbl acid displaced by ~> bypass. bbl brine to LWP5/5c 05-20-87 LISBURNE L5-16 TREATMENT PROCEDURE/CHECK SHEET AND RESULTS 16 C1 ose bypass. 17. PU 16'to 9046'. Squeeze 10 bbl acid from 9056'-9046'MD. Initial pressure //Jm psi at ~- BPM. Broke back to ~Jm ~psi. Initial casing pressure ~ psi and ~ed/decreased to ?~ psi. 18. PU 10' to 9036'. Squeeze 10 bbl acid from 9046'-90367MD. Initial pressure/z~a psi at ~ BPM. BroKe back to ~- psi. Initial casing pressure ~ psi and i~/decreased to ~o psi. 19. PU 10' to 9026'. Squeeze 10 bbl acid from 9036'-9026'MD. Initial pressure /~m psi at ~' BPM. Broke back to ~-- psi. Initial casing pressure <s-~m psi and i~/decreased to ~o psi. 20. PU 10' to 9016'. Squ~eeze 10 bbl acid from 9026'-9016'MD Initial pressure ~m psi at ~ BPM. Broke back to -~ psi. initial casing pressure ~ psi and<]~D~)~ed/decreased to ~o psi. 21. PU 10' to 9006'. Squeeze 10 bbl acid from 9016'-9006'MD. Initial pressure/~maa psi at ~ BPM. Broke back to ~ psi. Initial casing pressure ~ psi and ~/decreased to ~>~o psi. 22. PU 6' to 9000'. Squeeze J~bbl acid from 9000'-9006'MD. Initial pressure /From psi at ~/ B~I. Broke back to /~ psi. Initial casing pressure ~aJ psi and ~hc~/decreased to ~o psi. 23. Open bypass and circulate~) bbl acid, displaced by ~ bbl brine to brine. 24. Close bypass. 25. PU 26' to 8974'. _ueeze'bbl acid from 8984'-8974'MD Initial pressure F~~ psi at ~B~J~. Broke back to/<~ ~ psi. initial casing pressure~JJ psi ~~~/decreased to ~ ps~. LWP5/5c 05-20-87 LISBURNE L5-16 TREATMENT PROCEDURE/CHECK SHEET AND RESULTS 26. PU 10' to 8964'. SqueezeZ~bbl acid from 8974'-8964'MD. Initial pressure/~~ psi at ~ BPM'. Broke back to F%~s~opsi. Initial casing pressure ~, psi a-'~-~ncreased/~d to ~ psi. LWPS/5c 05-19-87 ADDENDUM WELL: L5-16 5/~8/87 Rn PDK-100 Pulsed Neutron log f/9436'-8800' in 3 passes. Drilling Supervisor A~CO ALASKA INC. LISBURRE ENGINEERING Date: 4-21-87 From: Pam Lambert Enclosed are the following: Magnetic Tape for L5-16 OH LIS Shifted_ 3-14-87 Run 1 ARCO Received by: ~ ~s Cor~s. Co~mission Please sign and re~urn to~ ~ La. bert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 214 Date: 4-21-87 Enclosed are the following: CH Finals for Lisburne Wells -""L5-16 GCT Directional Survey 3-19-87 Run 1 Sch '""4L5-16 CBL (CBT) 3-19-87 Run 1 5" Sch '"'"'L5-16 CBL(CBT) 4-6-87 Run 2 5" Sch '"~L3-18 Perforation Record 4-2-87 Run 1 5" Sch ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 TRANSMITTAL # 211 Date: 4-14-87 From: Para Lambe~ Enclosed are the following: Magnetic Tape for L5-16 GCT LIS 3-19-87 Run 1 Tape Number 72266 Sch Received by: Please sign and FILE ROOM tozpamLambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 EXXON STAI~ARD CENTRAL FILES TRANSMITTAL # 208 STATE OF ALASKA ..... ALAS~.., OIL AND GAS CONSERVATION COMN ~31ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~. Re-enter suspended well [] Alter casing [-£ Time extension []. Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate ~ Other 2, Name of Operator ARCO Alaska~ Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1788' FSL, 19' FWL, Sec. 1, T11N, R15E, UM At top of productive interval 1320' FSL, 1100' FWL, Sec. 1, T11N, R15E, UM (approx.) At effective depth 1136' FSL, 1227' FWL, Sec. 1, T11N, R15E, UM (approx.) At total depth 1114' FSL, 1259' FWL, Sec. 1, T11N, R15E~ UM (approx.) 11. Present well condition summary Total depth: measured 9575 ' MD feet Plugs (measured) true vertical 9309 ' TVD feet Effective depth: measured 9479 ' MD true vertical .9221 ' TVD Casing Length Size Conductor 80 ' 20" Surface 3967 ' 1 0-3/4" Production 9523' 7-5/8" feet Junk (measured) feet 5. Datum elevation (DF or KB) RKB 60 ' 6. Unit or Property name Prudhoe Ba~,/Lisburne Unit 7. Well number L5-16 8. Permit number 87-'19 9. APl number 50_029-21 700 10. Pool Lisburne Oil Pool None None Cemented Measured depth 1800# Poleset 120'MD 1300 sx AS II I & 4006'MD 325 sx Class G 425 sx Class G 9559 'MD ~ue Verticaldepth 120'TVD 3998'TVD 9294'TVD Perforation depth: measured None true vertical N o n e Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Description summa~ ofproposal [] ~ELL HISTORY & Addendum (~ate~ 3/25/87) 13. Estimated dateforcommencing operation August~ 1987 Detailed operations program [] BOP sketch 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~/~/gj~(~/ ¢~j~~ Title Ass cc ia t e E ng i n eer Commission Use Only (Dani) SA2/34 Date Conditions of approval Notify commission so representative may witness J Approval No. ~.~ _.~)/j_ / [] Plug integrity [] BOP Test [] Location clearancel . ~ _¢~_,.,::: :: ?. ~"__.: by order of / .... Commissioner the commission Date '~' feet Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District [State Alaska Alaska I County. parish or borough I North Slope Borough ~Lease or Unit IWell no. Field I ADL #28320 Prudhoe Bay L5-16 ! Auth. or W.O. no. ~Title AL0397 I Drill Rowan #41 API 50-029-21700 Operator ]ARCO W.l. ARCO Alaska, Inc. 50% Spudded or W.O. begUnspud Joate 3/02/87 J,our 1730 Hrs. JPr,orste,us,sW.O. Date and depth as of 8:00 a.m. 3/02/87 thru 3/03/87 3/04/87 3/05/87 3/06/87 3/07/87 thru 3/09/87 3/10/87 Complete record for each day reported (ss) 20" @ 120' 1200', (1080'), Drlg Wt. 8.6, PV 21, YP 33, PH --, WL 14.6, Sol 3 Accept rig @ 1300 hfs, 3/2/87. NU diverter sys. 3/2/87. Drl 13½" hole to 1200'. Spud well @ 1730 hfs, 20" @ 120' 4020', (2820'), Circ Wt. 9.3, PV 6, YP 44, PH 8.3, WL 22, Sol 7 Drl to 4020', short trip, circ f/surf csg. 10-3/4" @ 4006' 4020', (0'), NU BOPE Wt. 9.5, PV 6, YP 38, PH 8.5, WL 24, Sol 8 Circ, POH. RU & rn 105 its, 10-3/4", 45.5#, L-80 BTC csg w/FS @ 4006', FC @ 3921'. Cmt w/1300 sx AS III & 325 sx C1 "G" w/2% CaC12. ND diverter, NU BOPE. 3980', 10.5°, S8.75E, 3972 TVD, 115 VS, 48S, 105E 1.0-3/4" @ 4006' 4445', (425'), Drlg Wt. 8.5, PV 2, YP 3, PH 12, WL 100, Sol 1.5 NU & tst BOPE. TIH, DO cmo & FC. Tst csg to 2500 psi. Conduct formation tst to 12.8 ppg EMW. 4150', 9.5°, S1.25E Fin DO cmt. 10-3/4" @ 4006' 7253', (2808'), POH Wt. 9.1+, PV 5, YP 4, PH 11.8, WL 8.5, Sol 6 Drl & surv 9-7/8" hole to 7253'. 4365', 6.5°, S 4.8E, 4353 TVD, 144 VS, 104S, l12E 4911', 2.6°, S 2.8W, 4897 TVD, 158 VS, 145S, 109E 5437', 0.9°, S 3.5E, 5423 TVD, 166 VS, 162S, llOE 5868', 0.9°, S28.5E, 5854 TVD, 169 VS, 168S, l12E 6386', 9.1°, sg0.gE, 6370 TVD, 206 VS, 179S, 148E 6663', 12.7°, S77.3E, 6642 TVD, 259 VS, 189S, 200E 7133', 24.8°, S73.8E, 7087 TVD, 405 VS, 227S, 343E 10-3/4" @ 4006' 8074', (821'), Drlg Wt. 9.2, PV 8, YP 7, PH 12.5, WL 6.4, Sol 6 Drl & surv to 8074'. 7432', 26.8°, ST1E, 7356 TVD, 534 VS, 266S, 467E 7893', 25.3°, S68.5E, 7770 TVD, 737 VS, 335S, 658E The above is correct Signat~ IDate 3/24/87 Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Oil and Gas Company Daily Well History--Interim r Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska ICounty or Parish North Slope Borough IState Lease or Unit ADL #28320 Prudhoe Bay Alaska Date and depth as of 8:00 a.m. 3/11/87 3/12/87 3/13/87 3/14/87 thru 3/16/87 3/17/87 Complete record for each day while drilling or workover in progress 10-3/4" @ 4006' 8381', (307'), Drlg Wt. 9.6, PV 9, YP 8, PH 12.1, WL 6.3, Sol 8 Drl & surv to 8381'. 8115', 24.1°, S67.1E, 7972 TVD, 829 VS, 370S, 744E 8296', 23.6°, S63.6E, 8137 TVD, 903 VS, 400S, 810E 10-3/4" @ 4006' 8897', (516'), Drlg 9-7/8" hole Wt. 9.6, PV 7, YP 8, PH 11.4, WL 6, Sol 8 Drl to 8823', 5 std short trip, circ, POH. RIH, drl to 8897' 8474', 23.6°, S62E, 8300 TVD, 973 VS, 432S, 873E 8763', 23.5°, S57E, 8565 TVD, 1088 VS, 490S, 973E 10-3/4" @ 4006' 9325', (428'), Drlg 9-7/8" hole Wt. 9.6, PV 7, YP 9, PH 11, WL 5.7, Sol 8 Drlg 9-7/8" hole. 10-3/4" @ 4006' 9575', (250'), Rn 7-5/8" csg Wt. 9.6, PV 7, YP 7, PH 11.6, WL 6.6, Sol 8.5 Drl to 9575', 10 std short trip, POH. RU Schl, rn DLL/NGT/SP, LDT/CNL/EPT/CAL/GR, DIT-E/GR; tl failed. RD Schl. Make CO rn, rm 9545'-9575', 10 std short trip, circ, POH. RU & rn 7-5/8", 33.7#, L-80 NS-CC csg. 9253', 23.5°, S52E, 9014 TVD, 1280 VS, 601S, 1134E 7-5/8" @ 95~9' 9575' TD, 9489' PBTD, NU tree 9.3 ppg NaC1 Rn 241 jts, 7-5/8", 33.7#, L-80 NSCC csg w/FS @ 9559'. Cmt w/425 sx C1 "G" w/.85% D-60 & .06 gal/sx D-135. Displ w/421 bbls 9.3 ppg NaC1, bump plug. WOC w/3000 psi on csg. Ddispl top 400' w/diesel. ND BOPE. NU tree. ?%7 . The above is correct 5' For form ~reparation and distribution see Procedures Manual Section 10, Drilling. Pages 86 and 87 IDate 3/24/87 Drilling Supervisor -ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish I State Alaska North Slope Borough I Alaska Lease or Unit ADL #28320 Field Prudhoe Bay Auth. or W.O. no. Title AL0397 Drill Rowan #41 API 50-029-21700 Well no. L5-16 Operator IA.R.Co. W.I. ARCO Alaska, Inc. 50% Spudded or W.O. begun Date Spud 3/02/87 Complete record for each day reported Iotal number of wells (active or inactive) on this~ ost center prior to plugging and I bandonment of this well our I Prlor status if a W,O, I 1730 Hrs. Date and depth as of 8:00 a.m. 3/18/87 Old TD Released rig 1200 Hrs. 7-5/8" @ 9559' 9575' TD, 9479' PBTD, RR 9.3 ppg NaC1 ND BOPE, NU & tst tree. 3/17/87. Freeze protect well. RR @ 1200 hrs, New TD Date 9575' PB Depth 9479 ' K nd of rg Rotary 3/17/87 Classifications (oil, gas, etc.) 0il Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Lisburne Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C,P. Water % GOR Gravity Allowable Effective date corrected The above is correct ~"~ Sign tu '×' ~'" IDate I Title 3/24/87 Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ADDENDUM WELL: 3/20/87 L5-16 Rn CBT f/9438'-8380' w/O psi and w/1000 psi. Rn GCT gyro. Drilling Supervisor \ Bate Date: 3-26-87 From: Para Lambert Enclosed are the following: OH Final Prints for L5-16 ~Natural GR Spectrometry Log 3-14-87 RUn 1 2"&5" Sch -'~Cyberlook w/ARCO Algorithums 3-14-87 RUn 1 5" Sch '"--EPT 3-14-87 Run 1 2"&5" Sch ---LDT/CNL (Raw) 3-14-87 Run 1 2"&5" Sch ~LDT/CNL (Poro) 3-14-87 Run 1 2"&5" Sch "'-'Dual Laterolog 3-14-87 Run 1 2"&5" Sch Please sign and return tof Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 190 MEMORANr UM Statr' of Alaska ALASKA ~L AND GAS CONSERVATION COI.~ISSION TO: C.V. Ch~~t~ DATE: March ]3, 1987 Chairmanl. ~ ~,.%.~/_ ' ;_/ FI LE NO.: D. BDF. 17 THRU: Lonnie C. Smith~z~j.~,~ TELEPHONE NO.: Commissioner FROM: Bobby Foster Petroleum Inspector SUBJECT: BOP Test ARCO PBU L5-16 Permit #87-19 Lisburne Oil Pool Thursday, March 5, 1987: The BOP test began at 9:30 a.m. and was concluded at-11:30 a.m. As the attached BOP test report shows, there were no failures. In summary, I witnessed the BOP test on ARCO's L5-16. Attachment ~.ATE OF ALASKA AI-~KA OIL & C;_~ CONSERVATION CO.-~?~--SSION B.O.?.E. Inspection Location, General G~neral Hous ekeepln~Ri Rese~e Pit Mud Svst~s Visual Audio Trip Tank Pit Gauge Flow MonA:or Cas Detectors Test Pressure BOPE Stack - Annular Preventer Pipe Blind P~_s Choke Line Valves tull Charge Pressure ~ ~u:p incr. cios. ~res. 200 psiE ~ Contra!s: Yaster &~ ~ Remote f~~B!inds sw~Ych cover. Ke!iv and Floor Safety Vztves ' Upper Kel!~ /, ,Tes= Pressure ~'~ Lower Ke~y / Test Pressure Ball T)~e / Tes: Pressure ~~ ......... inside BOP J Test Pressure ~~ Choke Ymnifoid ~~ Test Pressure No. Va!yes', Test Results: - Failures Test Time ~ hrs. Repair or iep!acemen: cf failed equipment to be made ~:hin ---. Eay4 and Inspector/ . . Co~-issio~ office not~__~ied. -' Rema~: -- Dist_-~ibu;ion . orig. - AO&GCC CC -- cc - Supe.-~'isor February 27, 1987 Telecopy: (907) 276-7542 Mr. T. P. Oostermeyer Regional Drilling Engineer ~RCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit L5-16 ARCO Alaska, Inc. Permit No. 87-19 Sur. Loc. 1788'FSL, 19'FWL, Sec. 1, TllN, R15E, UM. Btmhole Loc. l!88'FSL, 1406'FWL, Sec. 1, TllN, R15E, UM. Dear Mr. Oostermeyer.. Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the~probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Chairman of Alaska Oil and Gas Conser~at:ion Commission BY ORDER OF THE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o~ encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery TELECOPY MO. (907) 276-7542 February 26, 1987 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Use of "J-55" and "L-80" Grade Pipe as Surface Casing, Endicott Oil Pool, Endicott Field. Dear Mr. Oostermeyer: Your application of February 20, 1987 requested approval to utilize 10 3/4", 45.5 lb/ft "J-55" and "L-80" grade pipe for surface casing in the Endicott Field. The Commission has previously determined that "J-55" and "L-80" grade pipe is suitable for use as surface casing through perma- frost intervals, therefore your request to use !0 3/4", 45.5 lb/ft "J-55" and "L-80" grade pipe for surface casing in the Endicott Field is hereby approved. Ver~ truly .yours, Lonnie C. Smith Commissioner 6.BEW. 1 ARCO Alaska, Inc. ?ost Office Bo× 400360 ~;~nchorage, A~aska 99510-0360 Tefe~hone 907 276 1215 February 24, 1987 Mr. B. E. Wondzell State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' L5-16 Permit - Vam Connections Dear Mr. Wondzell' Per our conversation on 02/23/87, I have enclosed some literature on Vam connections. I highlighted a few points in the literature which state that Vam is a modified Buttress connection. The difference between Vam and Buttress is Vam has a shouldered metal to metal seal. A shouldered Buttress connection can withstand higher compressive loads (i.e., loads resulting from thaw subsidence) because the shoulder prevents thread jump, so Vam has all the advantages of a Buttress connection, plus the added advantages of being able to withstand higher compressive loads. I have also enclosed some API specifications on Buttress threads from API Standard 5B to compare with Vam specifications. If you have any questions, or would like to discuss this matter further, please contact me at 265-1635. Sincerely, Ri chard B. Gremley Senior Drilling Engineer RBG-O08 Enclosures cc: R.A. Ruedrich, ARCO T.P. Oostermeyer, ARCO D.E. Breeden, ARCO F.P. Gunkel, ARCO inc. is a Subsidim'y of ' OEC 5237 No Otis PTS offers you he VAM alternafiv. e... a premium conne.cfion engineered for superior performance un(let no,mai and extreme well con(lifions. Why Otis-PTS? Otis Premium Threading Services (PTS) is a division of Otis Engineering Corporation, a com~ pany with over 50 years experience in oil and gas well completions. Now Otis-PTS has an exclusive license to machine VAM thread on tubing and casing throughout the United States. And with Otis-PTS' seven-step in- tegral threading line with such features as pipe-end preparation, numerically-controlled threading processes and 100% inspection, you are assured of getting full benefits from VAM thread. A well-trained Otis-PTS field service department is also available to assist in the correct installation of VAM-cut tubulars at the wellsite. Why VAM Thread? Developed and patented by Vallourec to meet pressing needs in the North Sea, the VAM thread now enjoys full acceptance throughout most oil producing countries overseas. The reason for this acceptance is VAM's superior performance under extreme conditions, especially the hot, sour environments usually associated with deep wells. With drilling and completion efforts moving increasingly towards deep and deviated wells, the time has never been better to make the VAM thread available for use in the U.S. And due to VAM's better performance in the face of rising drill- ing and workover costs, many operators are also con- sidering VAM for use under normal conditions as well. VAM, as strong as the body of the pipe under all service conditions. VAM, completely gas tight VAbl, easy stabbing and fast make up VAM, oil field tough with its self-repairing seal VAM, best resistance to H2S VAM, flush internal profile VAM, uniform metallurgy VAM, non-upset VAM, superior performance at a lower cost Tapered buttress-type thread, strong, high resistance to pull-out Heavy duty conical lip avoiding any inside buckl- ing Metal-to,metal seal ensuring gas-tightness Robust internal shoulder acting as a positive make- up stop Internal profile reducing turbulence and allowing free passage of tools Reduced outside diameter VAM Thread< , Special Bevel (optional) (4) Non-U set (3) (5) Full Engagement (1) Special Clearance Coupling (4) )nai) OD(4) (6) :2) Smooth In1 ,mai Profile eck hese VAM Premium Fea ureso (1) Full Pipe Strength -Provides full pipe yield strength in tension, burst and collapse. (2) Superior Metal Seal - Provides the best available seal even under maximum internal and external ¥ ¥ ¥ ¥ ¥ Dallas, Tx ......................... (214) 323-3985 Houston, Tx ....................... (713) 676-7593 Midland, Tx ....................... (915) 683-4552 pressures as well as maximum tensile loading. (3) Maximum H2S Resistance - Non-upset connections provide a uniform hardness of pipe. Thread design also keeps that portion of connection subject to well effluents in compression. This is especially important for L-80, C-75 and other materials used in an H2S environment. (4) Smaller Joint OD - Low-profile coupling provides standard coupling diameters less than other premium connections in most cases. Special clearance couplings are available where even greater clearance is required. (5) Lower Cost Factor - Elimination of the need for upset tubes provides lower cost to the end user. __ (6) Self-Repairing Seal - "Wedging" effect of metal seal and torque shoulders usually repair minor damage to seal surfaces during normal thread make up. __ (7) Lessened Risk of Corrosion/Erosion- Flush internal profile provides continuity of smooth inter- nal surfaces thereby helping to eliminate corrosion/erosion related to turbulence or CO2. This also helps eliminate obstruction of wireline tools. __ (8) Fast Make-Up -Buttress-type threads are designed to minimize the possibility of cross-threading even when stabbing is out of line. Tapered thread design facilitates fast make-up with Iow torque until the final turns. Torque ranges are well-defined. __ (9) Worldwide Acceptance - Over 80% of all premium threads in use outside the U.S. are VAM threads. For more information contact the Otis-PTS o[£ice nearest you. New Orleans, La .................... (504) 5814054 Oklahoma City, Ok ................. (405)8424648 Denver, Co ........................ (303) 837-0542 PREMIUM THREADING SERVICES A DIVISION OF OTIS ENGiNEERiNG CORPORATION GA Halliburton Company 4-2000/801289 casing VAM VAM ATAC Shoulder 15° Tapered seal 10 % (2° 51 ') 5 threads per inch 0,0625 taper SPECIAL CLEARANCE coupling REGULAR coupling Special bevel (optional) Pipe inside diameter Pipe outside diameter tubing VAM Tapered seal (30°) Shoulder 20° 23/a and 2?/8 in 8 threads per inch 31/2-4-4~/2in 6 threads per inch SPECIAL CLEARANCE coupling REGULAR coupling Special bevel (optional) Pipe inside diameter Pipe outside diameter VAM Catalo(aue 11/3 - Jan. 1977 American Petroleum Institute Foreword Th is supplement supersedes Sup 3 and covers changes in API Std 5B (Ninth edition, March 1974): SpecificationJbr 7'hreadiug, Gaging, and Thread htspection of Casing, Tubing. u~tc7 Li~e Pipe Threads, adopted at the 1974, 1975. 1976 and 1977 Standardization Conferences. Page 4, Par. 1.1; Add the following se~tence: All thread dimensions shown without tolerances are related to the basis for joint design and are not subject to measurement to determine acceptance or rejection of product. Page 5, Par. 2.2; Replace existing paragraph with the following: 2.2 Threads shall be free from visible tears, cuts, grinds, shoulders, or any other imperfections which break the continuity of the threads, within the minimum length of full crest threads from end of pipe (Lc). Imperfections between the Lc length and the vanfsh point are permissible providing their depth does not extend below the root cone of the thread, or extend beyond 12~% of nominal wall (measured from the projected pipe surface) whichever is greater. Grinding to probe or to eliminate defects is also permitted in this area, with the depth of grind having the same limits as imperfections in this area. Imperfections include such other discontinuities as seams, overlaps, pits, tool marks, dents, handling damage, etc. Imperfections within the above described permissi- ble limits will be permitted under the following conditions: a. If imperfections are detected at the mill, the pipe end with imperfections must be the end with the exposed pipe threads. No imperfections detected at the mill or grinds are permitted on the coupling end of the pipe. b. Imperfections or grinds within the above limits are acceptable on the end with the exposed pipe threads. Imperfections running u. nder the cou- pling, which are detected after shipment from the mill, are not acceptable unless it can be demon- strated that the imperfection is within the above described permissible limit. If the imperfection is within the permissible limits the coupling may be reapplied and the length of pipe is acceptable product. If the imperfection exceeds permissible limits, it shall be considered a defect and the length of pipe is rejectable, or it may be reconditioned by cutting the threads off, rethreading and reapplying the coupling. Imperfection. An imperfection is a discontinuity or irregularity in the product detected by methods outlined in the applicable specification. Defect. A defect is an imperfection of sufficient magnitude to warrant rejection of the product based on the stipulations of the applicable specifi- cation. Page 6, Fig. 2.1; Add the following note: The vanish cone angle is optional for round threads on downhole tools. Page 8, Table 2.2, Col 3; Change 94.00 in last line to read "All". Page 12, Fig. 2.5; Replace existing drafting with the following: -- 26C ' "- w: , : -": __!__: ~-~ gOTE T~[~D CRESTS ~ ~ ~ ~ . ~ ~OOTS ~E PeRA~LEL ~. ...... 13 ~ ~-- I 475 ~O CONE ~ ~ - '!~: ......... .031 ' I ' I ~ ,~.o08a_'ooz~ Ii' % ' / , i ~ ................. ~ ~ .... . TAPEE.~:f~[~, PER ~ (62,5 M~ PER M) ON DIA~. FIG. 2.5 BUTTRESS CASING THREAD FORM AND DIMENSIONS For casing sizes 4~ through 13% in. See Appendix B for metric dimensions. Page 13, Table 2.10; Add the following footnote: Tolerances for long thread external-upset tubing are applicable only to reinforced thermosetting resin tubing. See Table 2.6a. Page 13, Footnote 1 to Table 2.10; Replace existing footnote .with the following: ~For pipe (external threads) the lead tolerance per inch is the maximum allowable error in any inch within the length L4 -g. See Sect. 4 for g dimensions. The cumulative lead tolerance is the maximum allowable error over the entire length L4-g. For internal threads, lead measurements shall be made within the length from the counterbore to a plane located at a distance J + one thread turn from the center of the coupling or fr0'm the small end of the thread in the box of integral joint tubing. Page 13, Table 2.11; Change tolerances for lead to read as follows: Lead:2 Per inch: 13~ in. and smaller .................. ~-0.002 in. 16 in. and larger ................... x'-0.003, in. Cumulative ........................... x'-0.004 in. 12 American Petroleum Institute TABLE 2.8 LINE-PIPE THREAD HEIGHT DIMENSIONS -All dimensions in inches. See Fig. 2.3 See Appendix B for metric tables. I 2 3 4 5 6 H-- 0.866p 0.0321 0.0481 0.0619 0.0753 0.1082 hs--ha-- 0.760p 0.0281 0.0422 0.0543 0.0661 0.0950 frs--fra-- 0.033p 0.0012 0.0018 0.0024 0.0029 0.0041 f~--f*n-' 0.073p 0.0027 0.0041 0.0052 0.0063 0.0091 :$ ~c~i_..- TAPER ----- 3/4 IN. PER FI {62,5 MM PER M) ON DIAM. FIG. 2.3 LINE-PIPE THREAD FORM See Table 2.8 for dimensions. -~ .io~±:§§o~ ..~ \ ~ '. ooo No~E' ~.~E~D CRESTS \ i~. ROOT'5 ARE PARALLEL TO CONE. ~,~- 10°~3°4 ~o~ ~x,~-~ ~o<' ~ s_*:~§~ CASING J ?1/1////////// ~ ~ .!00e · I · JO0e ,200 AND DIMENSIONS For casing sizes 4% through 13% in. See Appendix B for metric dimensions. .03[ TABLE 2.9 CASING AND TUBING ROUND THREAD HEIGHT DIMENSIONS All dimensions in inches. See Fig. 2.4. See Appendix B for metric tables. 1 2 3 10 Threads 8 Threads Thread Element per Inch, per Inch, p -- 0.1000 p -- 0.1250 H --0.866p hs --hn --0.626p---0.007 Srs = Srn -- 0.120p + 0.002 Sos-- Sca -- 0.120p ~- 0.005 0.08660 0.10825 0.05560 0.07125 0.01400 0.01700 0.01700 0.02000 scs ~ TAPER SHOWN EXAGGERATED p/2 rn 6~a' PITCH hn SC TAPER = V4 IN. PER FT 162,5 MM PER M) ON DIAM. FIG. 2.4 CASING AND TUBING ROUND THREAD FORM See Table 2.9 for dimensions. --_ \ ~, O31 .082t oo, ~23.17' .031 TAPER = 1 IN. PER FT [83,3 MM PER M) ON DIAM. FIG. 2.6 BUTTRESS CASING THREAD FORM AND DIMENSIONS For sizes [64n. and ]3t~et. See Appendix B ~or metric dimensions. i I Std 5B: Specification for Inspection'of Pipe Threads TABLE 2.4 BUTTRESS CASING THREAD DIMENSIONS All dimensions in inches, except as indicated. See Fig. 2.2. See Appendix B for metric tables. 1 2 8 4 5 6 7 8 9 10 11 12 13 14 'est is, Outside Major Diameter Diameter D D, End of End of Total Pipe to Pipe to Length: Center of Center of Length: No, of End of Coupling, Coupling, Face of Threads Length: Length: Pipe to Power- Hand- Coupling Per Imperfect Perfect Vanish Pitch Tight Tight to Inch Threads Threads Point Diameterl Make-Up Make-Up Plane F~ g L? L,~ E~ J J~, Minimum Length, Length: Hand- Full Crest End of Tight Diameter Threads Pipe to Standoff, of From Triangle Thread Counterbore End of Stamp Turns in Coupling Pipe A~ A Q Lc* 5 0 5 :5 ~0 ~0 i0 )0 ]5 41~ 4.516 5 1.984 1.6535 3.6375 4.454 0.500 0.900 1.884 3i~ % 4.640 1.2535 5 5.016 5 1.984 1.7785 3.7625 4.954 0.500 1.000 1.784 4~ i 5.140 1.3785 5~ 5.516 5 1.984 1.8410 3.8250 5.454 0.500 1.000 1.784 4% I 5.640 1.4410 6% 6.641 5 1.984 2.0285 4.0125 6.579 0.500 1.000 1.784 4~ 1 6.765 1.6285 7 7.016 5 1.984 2.2160 4.2000 6.954 0.500 1.000 1.784 4% I 7.140 1.8160 7% 7.641 5 1.984 2.4035 4.3875 7.579 0.500 1.000 1.784 4~ i 7.765 2.0035 8% 8.641 5 1.984 2.5285 4.5125 8.579 0.500 1.000 1.784 4i~ I 8.765 2.1285 9% 9.641 5 1.984 2.5285 4.5125 9.579 0.500 1.000 1.784 4i~ I 9.765 2.1285 10SA 10.766 5 1.984 2.5285 4.5125 10.704 0.500 1.000 1.784 4~ I 10.890 2.1285 11~ 11.766 5 1.984 2.5285 4.5125 11.704 0.500 1.000 1.784 4i~ 1 11.890 2.1285 13% 13.391 5 1.984 2.5285 4.5125 13.329 0.500 1.000 1.784 4~ i 13.515 2.1285 16 16.000 5 1.488 3.1245 4.6125 15.938 0.500 0.875 1.313 4~} % 16.154 2.7245 18% 18.625 5 1.488 3.1245 4.6125 18.563 0.500 0.875 1.313 4½~ % 18.779 2.7245 20 20.000 5 1.488 3.1245 4.6125 1~.938 0.500 0.875 1.313 4½] % 20.154 2.7245 ]5 Z5 Included taper on diameter: Sizes 13% in. and smaller -- 0.0625 in. per in. Sizes 16 in. and larger -- 0.0833 in. per in. 75 75 ~gth, Crest ends, a End Pipe ~C$ 875 25O 375 750 875 .000 .375 .625 .125 NOTE: At plane of perfect thread length Lz, the basic major diameter of the pipe thread and plug gag~ thread is 0.016 in. greater than nominal pipe diameter D for sizes 13% in. and smaller, and is equal to the nominal pipe diameter ~or sizes 16 in. and larger. · xPitch diameter on buttress casing thread is defined as being midway between the major and minor diameters. *Lo -- L? -- 0.400 in. for buttress thread casing. Within the Lo length, as many as 2 threads showing the original out- side surface of the pipe on their crests for a circumferential distance not exceeding 25% of the pipe circumference is permissible. The remaining threads in the Lc thread length shall be full crested threads. --PLANE OF CENTER OFCOUPLING THE FACE OF THE COUPLING ADVANCES TO WITHIN ONE THREAD TURN OF THE BASE OF THE TRIANGLE ,,,.~PLANEOF END OF STAMP FOR MINIMUM POWER-TIGHT MAKEUP AND PIPE, POWER-TIGHT TO THE APEX OF THE TRIANGLE FOR MAXIMUM MAKEUP. .,._..PLANE OF ENO OF I IPLANE OF OF VANISH POINT PIPE~HAND-TIGHT [- [PERFECT THREAD I [LENGTH II ~ ~ IPLANE OF FIRST CONTACT I -x I Fi 300 FOR SIZES I ~,3/8" AND SMALLER ~ CS' I '--"dA ~"-'I-[200FOR SIZE 16" AND LARGER L7 g L4 BASIC HAND-TIGHT POSITION BASIC POWER-TIGHT POSITION 1.400 FOR SIZE 41/~'' ~ 1-'---I.500 FOR SIZES 5'THROUGH 15~8" ON MILL END STAMP ON FIELD END ~ FIG. ~.2 BASIC DIMENSIONS OF BUTTRESS CASING THREADS HAND-TIGHT MAKE-UP See Appendix B for metric dimensions. See Fig. 2.5 for detail of thread form and dimensions. See Fig. 2.1 for line-pipe threads and casing and tubing round threads. See Sect. q for extreme-line casing threads. Technical data sheet isSUed: January 1977 ;in minimum thread length L., 5.t18 in Coupling outside regular W tl.748 in diameter ~5~ ~1 ,., : cTearance vvc 11.266 in length NL 10.669 in t make~up loss L e 5 039 in Calculated weights Critical cross-section Outside diameter 10 a/~ in Nominal weight 45.50 Ib/ft Wall thickness 0.40(~ in Threads per inch 5 White?APl derivation Derivation of data on this sheet is explained in Part IV of VAM catalogue Notes For figures marked with lB see Part IV § 2.6.4 Performance properties ~ K-55 C-75 L-80 N~80 C-95 P-110 Q-125' V-150' ~ co~aose resistance os 2090 24t0 2480 2480 2580 2610 2610 2610 n[ernai weK] eressure Ds 3580 4880 5210 5210 6190 7160 8140 9770 eodv v e~d s[rengti~ 1000 ID 715 975 1040 1040 1236 1431 t626 1951 715 975 715 975 636 868 926 926 1040 1040 samegraoe 10001~ 931 1037 1063 1097 1111209 ~11t423 lB1570 m1870 regular - mgner grade 1000 lb 931 1037 1063 1097 [] 1423 I~11570 same graoe 1000 lb 931 1037 1044 1097 ~154 1374 t484 t758 specla clearance hlghergraoe 10001~ 931 1037 1063 1097 1~11423 ~1570 Rig floor operating data 1000 lb 375 511 Recommended make-up torque using a thread compound with a correction factor of 1'* ft-lb 9400 9400 9400 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill ~-' Redrill ~1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen~, Service [] Developement Gas ~ Single Zone~ Multiple Zone [] 2. Name of Operator-- 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO A]aska~ Inc' RKB 60' PAD 21' · ' feet Prudhoe Bay Fi el d 3. Address 6. Property Designation Li sburne 0i ] Pool P.0. Box 100360 Anchorage, AK 99510-0360 ABL 28320 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1788'FSL, 19'FWL, Sec. 1, TllN, R15E, UN Prudhoe Ba),/Lisburne S'cat:ewide '1 32~| I~PL of ~{(~,c~.i~eL interval 8L ~/-e~16nu rpber I~ll~n8b8e-r 26- 27 , :~ec. 1 TllN R15E UN At total depth 9. Approximate spud date Amount 1188'FSL, 1406'FWL, Sec. 1, T11N, ELSE, UN 03/01/87 $500,000 12. Distance to nearest 1L3.~_Dis2tan~e2: ~o, nearest well 14. Number of acres in property 15. Proposed depth(Mo P3roperty line 492'@ Surface feet 2251'ND/2251'TVD feet ~5'C,:,O 9643'ND/9299'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (,e ~ A^C 25.035 (eX2)) -? Kickoff depth 5800'feet Maximum holeangle27 1°5° 3438 4490 . · Maximum surface psig At total det3th II'VD) psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 40' 40' 120! 120' 2000# Poleset. 13-1/2" 10-3/4'I 45.5# J-55 BTC 70' 39' 39' 109 109' 13-1/2 10-3/4' 45.5# L-80 VAN 3891' 109' 109' 4000 4000' 325sx (; cat & 1100ex ^ ~-7/8' 7-5/8" 33.0# L-80 NSCC 9605' 38' 38' 9643 9299' 450 sx Class "(;" cmt: & 200 sx AS I & AP "-Con]: t. nc.'en cy: 9-7/8" 7-5/8" 33.0# L-80 NSCC 8842' 38' 38' 8880' 8620' 300 sx Class G & ' 200 sx AS i & AP 6-1/2" 5-1/2" 17.0# L-8"O FL4S 963'~' 8680' 8442' 9643' 9299' 190 sx Class C, . Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat C.. BOP Sketch .~ Diverter Sketch ~ Drilling program ~, Drilling fluid program ~, Time vs depth plot ~ Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify tha/t/t~ f/el~egoing is true and correct to the best of my knowledge ~p~~ Title Eegiona, Dri,,ing Engineer Date~/~/oC-~ Signed Commission Use Only (FP(::;) PD2/07 PermitNumber~.~.?__t~ I APinumber [Approvaldate ]Seecoverletter · 50- o :~. ~/-~.;~_i 7oo 02/27~87 for other requirements _ Conditions of approval Samples required - Yes ~ No Mud log required ~ Yes X No Hydrogen sulfide measures ~ ~ ~_.No .~ire.ctiona. I survey required ~ Yes ~ No Required working,,l:3'F~sure..,for/t~OPF~.,/~M~3M; ~ 5M; 7 10M; '-' 15M / ~//'~'~' ( ~ by order of ~;;~ .~ Other:· ....... _. ~... ' - t't~mrni~ei~, n~r the commission Date II L5-16 DRILLING PROGRAM 1. Set 20" conductor. A 20", 2000 psi annular diverter will be installed per attached schematic. This is variance from 20ACC25.035. 2. MIRU Rowan 41. Install 10" diverter lines and function test. 3. Drill 13-1/2" hole to surface casing point at 4000'MD/TVD. 4. Set 10-3/4" surface casing and cement to surface. Do top job if cement does not return to surface. Test casing to 2000 psi. 5. Install 13-5/8", 5000 psi RSRRA BOP stack. Test BOP stack to 5000 psi and annular to 3000 psi. Test BOP stack weekly. Drill 10' of new formation and perform leak off test. 6. Drill 9-7/8" hole to KOP @ 5800'MD. Build 2.5°/100'MD to 27o09' oriented S66°35'E. 7. Continue drilling 9-7/8" hole through the Lisburne (Wahoo) maintaining angle and direction to TD 9643'MD/9299'TVD. NOTE: There is no Sadlerochit present in the area of L5-16. 8. Run open hole logs. 9. Run and cement 7-5/8" casing to TD. Displace cement with brine. 10. Test 7-5/8" casing to 3000 psi. Leave a 400' diesel cap on the well. 11. Secure well and release drilling rig. 12. Run cased hole logs and gyro. 13. MIRU completion rig. 14. Perforate. Run 2-7/8" production tubing and subsurface safety valve. 15. NU tree and test to 5000 psi. 16. Secure well and release completion rig. 17. Perforate additional zones if required. Stimulate. PD2/O7a 02/19/87 R'x NOTE' a. In accordance with Area Injection Order No. 4, excess non-hazardous fluids developed from well operations and as necessary to control the fluid level in the reserve pit, will be disposed of down the 7-5/8" x 10-3/4" annulus. The annulus will be left with a non-freezing fluid ~ ee ~during any extended interruption in the disposal process. The annulus will be sealed with 200 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20 AAC 25.033. c. Maximum surface pressure is based upon BHP of 4490 psi @ 8960'TVD, less an oil column to 8660', less a gas column to the surface. d. L5-16 is within 200' of the following wells: L5-12, 120' from L5-16 @ 2251'MD/2251'TVD L5-13, 197' from L5-16 @ surface If hole conditions dictate, 7-5/8" casing will be set 30'TVD above the Lisburne, and a 5-1/2" contingency liner will be set at TD. PD2/O7a L5-16 1000 2000 3000 4000 50OO 6000 7000 8OOO 9000 10000 11000 0 1000 2000 3000 4000 5000 6000 7000 ...... i I i~'I ] I I I 1 iCONDUCT(tR ......... TVD m11gl i,' ..... il I I ii i i i i i i i i i i ............. 0 _ ARCED AL),SKA, INC. ;CALl= I IN = 1000 Fl. SHL:178!/FSL, 19' FW SEC 1,' I1N, R15E, U~l THL:1320' FSL, 1100' F~ ~L RF~ 1_ T I1N. R1RF. H~ 10-3/4" RIIRFj~F TVD = 4ann 8 88 DI~Q ~S MINE 1171 F~ (TO T~RGET) COP TVD ~ 2.5 AVERAGE ANGLE · 7 BEG I MIN ,2 EOC TVO ~ B84B MD -- ~1 aB DEP ~ K-lO ~ VD -- 74~0 ME - 7B7B OEP - BBS K-~ TVD - 7980 ~D - ~1B1 DEl -- 8~4 ,,, _~ 7-6/8'CONq:INGENCYCSG ~T TVD=862 MD-8880 ['EP-1163 - ~ = LCU/TOPWI~HOO TVD~81tS0 MD"891~ OEP--1178 TARGET TV D - 8650 MD = 8914 OEP - 1i 78 , go00 7-5/8' CSG PT/TO TVI) ~ 9299 MD = 9643 OEP m AL~a"~' ~.,~ & Gas , , , , , , , , , , , , , , , , , , r , , , r , , , i , , , , , , , , , , , , , , , ~ , , , , r , i~"1 , , , , , , , 1000 2000 3000 ~000 5000 801]0 7000 VERIIOBL S50TION 1000 2000 3000 4000 5000 8000 7000 8000 10000 11000 -r- F~ O_ W r-~ __J W W E - W O00ROINBTES o -?000 o 0 W n~ 0 0 Z - 1000 - 0 1000 2000 3000 4000 SO00 -2000 -1000 0 1000 2000 3000 4000 5OOO E - W COOROINB?ES F. - ~4 O00ROINBTF. S -2000 CD 0 c~ w z -1000 . 0 1000 2000 3000 4000 5000 .. I i ! ! i ! i I I I I i i i i I i i i i i i I ! i i i i i i ! i i i i i i i i i i i i i i i i ! I i i i i i i i i i i ! I ' L5-13 ~ L i i i i i i I ! i i ! i i i i i i i I i i i i i i i i i i i i i i I i i ! i ! i i i i i i i i i i i I i i i i i i i i i i I O I -2000 -1000 0 1000 2000 3000 4000 E - 14 COORDINFtTES 5OOO F. - ~ O00ROINFI~S -~00 -300 -7 - 1 oo 0 l oo 200 300 ~oo 0 o LS-1 0 I -400 -300 -200 - 1 O0 0 1 O0 200 300 400 P, - ~ COORDINBI~ES .t . L5-16 MUD PROGRAM Plas Density Visc. Depth (TVD) #/gal (CP) Surf 8.8 Funnel to to 100- 10-3/4" 9.7 300 Csg Point 10-3/4" Csg Shoe 8.3 to to K-lO 9.4 Yield Point #/1 O0 ft2 40-60 20+ Initial Gel 1OM FL % % pH and Gel CC/30M Oil Solids Type of Mud 40+ 20+ 0 8-10 Spud Mud Mi nimum 6 2 5 25 Possible to to to to 20 10 30 10 0 3 Low Solids to to Non-dispersed 2 7 K-lO 9.2 to to Top of Lisburne 10.2 10 4 4 8 8 to to to to to 20 10 8 20 4 2 4 pH 11-12 to to Low Sol ids/Low Lime 5 15 Non-di sper sed Top of Lisburne to TD 9.2 4 6 2 8 10 2 4 to to to to to to to to 9.8 10 10 8 20 4 8 8 Low Solids/ Non-Dispersed NOTE: Exact mud properties will be selected by ARCO representative based on hole conditions. EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Shakers 4, Pit level indicator (with both visual and audio warning devices) Drilling fluid flow sensor (with read out convenient to the driller's console) 5. Trip tank 6. Agitators 7. Desander 8. Desi 1 ter 9. Centrifuge PD2/O7a ROWAN 41 MUD SYSTEM mixing pit ~1-145 bbls mixing pit ~2-1 45 bbls pill pit 60 bbls I pit ~5 trip tank 145 bbls pit ~4 115bbls pit ~3 suction 1 lSbbls Injection pit 145 bbls pit ~6 -90 bbls pit~7- 90 bbls pit ~8 40 bbls Brandt Double-Decker Shale Shakers-(3) Demco Desander with 3-12" diam. cones Demco Desilter with 14-6" diam. cones Dri lco Degasser P i oneer Centri f uge Main Pumps: National 12-P-160, (2) Gasbuster well i . I ARCO ALASKA !NC. ROWAN 41 D IUERTER Filtup line Riser Flowline 10" ball 20" 2000 ps1 diverter v~v 1 l~O,, ball i vlv Conductor 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 a variance from 20 AAC ~5.035 13-5/8" 5000 PSI BOP STACK DIAGRAM ACCI_IMI_ILATOR CAPACITV TEST I ANNULAR 1 [ PREVE#TER J ¢1 [ I BLINDRA"5 1 ¢1 I3~] ~.--~ DRI LLI NG SPOOL ' ¢1 · DI~LG fSPOOL ~ SPOOL i ~ 13-3/8" ._ .~ ST ART lNG HEAD ALL 80P EQUIPMENT t. CHECK AND FILL ACCUMULATOR I~ESERYOIRTO PPOPER LEVEL WITH HYDRAULIC FLUID. 2 ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSt 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 CHARGING PUMP OFF. 4. RECORD ONIADC REPORT. THE ACCEPTABLE LOWER LIMIT 15 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE 13-5/8" BOP STACK TEST 1 FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. 2. CHECK THAT ALL HOLI~ DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. RUN I N LOC K DOW N SCREWS. 3. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4 FUNCTIONALLY TEST CHOKES. 5. IN EACH OF THE FOLLOWING TESTS, FIRST HOLDA 250 PSI LOW PRESSURE TEST FOR A MINIMUM OF $ MINUTES, THEN TEST AT THE HIGH PRESSURE. 6 INCREASE PRESSURE TO $000 PSI AND HOLD FOR A MINIMUM OF SMINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAM5 THEN CLOSE BOTTOM SET OF PIPERAMS. INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST 3 MINUTES. 10. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. I 1. BLEE~D PRESSURE TO ZERO. OPEN BOTTOM SET OF PIPE RAMS. 12. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST 3 MINUTES. 1];. BLEED PRESSURE OFF ALL EQUIPMENT. OPEN BLIND RAMS MAKE SURE MANIFOLD AND LINES ARE FULL OF NON- FREEZING LIQUID AND ALL YALYES ARE SET IN DRILLING POSITION. 14. TEST STANDPIPE VALVES TO 5000 PSI. 15 TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. 16. CHECK OPERATION OF DEGASSER. 17 RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN ANDSENDTO DRILLING SUPERVISOR 1 8. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. JG 8- 26- 85 ARCO Alaska, Inc. ~- Post Office Box 1, .~0 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 23, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - L5 Pad (Wells 1, 4, 5, 8, 9, 12, 15, 16, 20, 21, 23, 28,29 ) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer If JG/dmr GRU1/44 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany SEC.. 2 SEC. i NS72&00 L-5 NORTH )o$.oo L-5 SOUTH O- PROPOSE D 0- EXISTING N 34S2.74 NOTES: ~uYH ~s mcnm m miLL SiT[ C-4 ca(m~ D~IN~ m, r. IK)M~T tLr~L · Z)~IIBI ~ CO(XqDINA,1Y.I If.r. I)Ot'FILrTI TO ICgTIGN LII4:S ~ CCMPUTLrD &4.qcD I HEREBY CERTIFY THAT I AM PROPERC~ REGISTERED AND LICENSED TO LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUlL? SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. DATE No. (VICINITY lea,) ARCO LIS~URN[ FACILmES ~C1 A.$.P. GEODETIC SIC. LIE (ZONC 4) (LAT..-LO#e.) OFFSETS ARCO Drill Site L-5 Well As-Built Location LOCATED IN' SECTIONS I ~ 2 PREPARED BY: PREFRRED FOR-' IIII -V~CO, /NC. DATE ' SHE ET: 12.' Ig' 86 I Of I DRAWN: CHECK E D, JSP GMS FIELD BOOK, JOB NO. L86-95 86052 CHECK LIST FOR NE]~ W~.I. PERMITS ~ APPROVE DATE Fe& ~ ~- -~-h';~-? i. (2 thru 8) 1 (3) Admin ~ ~-;R' -t? 9. (9 thru 13) 10. 13) , 12. 13. (4) Casg ~~ ~]/Z{o/~7 (14 thru 22) (5) BOPE ~4(.(~.~'. ~-~_s--/¢,~, (23 thru 28) (6) OTHER /%/,/~. (29 thru 31) (6) Add: Is the permit fee attached .......................................... ~ · Lease & Well No. NO Is well to be located in a defined pool ....................... ~ Is well located proper distance from property line ...... ~~ .~~i~~~i~. i~ ! Is well located proper distance from other wells ............. Is sufficient undedicated acreage available in this pool . .. Is well to be deviated and is wellbore plat included ................ ~ Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force ........................ , ......... Is a conservation order needed ...................................... Is administrative approval-needed Is the lease number appropriate ..................................... ~ Does the well have a unique name and number .......................... ~, 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandommnt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25~ 26. 27. 28. For 29. 30. 31. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~ psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented- 32. Additional requirements ............................................. Geology: WVA ~, EngiI3~eering: rev: 01/28/87 6.011 INITIAL GEO. UNIT 3N/OFF POOL CLASS STA/US AREA NO. SHORE / 8 /.4: / Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. SE~,~VICE NAqE :Li.~,~' ~T O T~: :04/iO/U,l ~,n R I G I N ' TAPE NAM~' : CDNTi NUAT I J~'~ PREVIOUS T~Pt: : COMMENi'S ' MCCLSR3-LEWIS ENERGY SERVICES - P/'Tfq~S WELL L(]'$ ,~NaLYSIS Svsr't,! '~-LL LO'--' AFi&LYSIS APR 2 a 1987 Al~sk~ 0~ & Gas Oons, Gommission Anchorage LiS~jURNE W?_LL L5-i6 SHIFTcn. TAPE ~ =S I:~ CAT D 5Y 'TOOL .... --'; -4: F t L E ~q E A FILE NAME SaRV-ICE ~J.AML ~R MAX~'MUM LENGi'Fi ; iOZg FILE TYPL: : LO mk*~IOUS, ,.,~ FiLE : -,--- COMMENT.:, FIELD 29~i~_ WELL 70000 LiS3URNL: WELL L5-i6 SHIt-Tb_[~ YA~:~· ~Y R. CHRTSTi~NS!:fN MAI?~, PASS ~j ~TF.D ~_.~-~v. T,.i']~,_.~_ ,'~.td;~;~In~,~ICS,.. .~:,.,..~ (I.E. LDT='qAI.:'~,,.. o'~cS,, ., LOR:=REP~T ~ASS), TYPE S'[ZE R E P.~:( C.(jDE UP/DOWN FLAG FRAME ABe;zNT..~,~_,. VALUE DATUM SP~CIF!CATIG'H GL'3CKS HT~N EPT TEl,IS EP~ ?0907 HTEH EPR 7066? tqTEH EPT TOOSi ~ R E S ~ P FVD EPR ~Vi) EPT F VU E P 1' l 0531 N V O E P ~ 7 () 5 Z 7 ~0 ~PT ~ ~ V U E P F. 7 0 51 7 ~'VU,~ LPT '/051 l EPHt EPR 7029'1 CPHI EPT 70291 EATf EPA 70Z7 7 :3, O. O. O, 0, O, 0, O, 0. Oo 0 ~, O, Oo 0 - 0 ,, f) ~ . O~ 1, l- Lo 1o 1- t- i' 1- 1, 1- 1o 4. 4~ 4~ 4 m i 2 o 0,, O. O, O.., 0 · 0"` '3, O. 0,. 68., 68. 63, ./ TENS 4200,000 ~TEM NRES 0.940 FVD FVU O~ 5 2Z ~'J VD NVU 2.057 EPHI ~ATI 364,500 - 99 ? 9 · 000 -gggg,Jo0 - 9999.00C -9999-00'0 9 9 9 '9 ,~ () 0 0 HTEN FVO E PH L Z9t.,~25 0.. 004 2.021 TENS r VU NVU ~-A TT -9909,000 -9999.000 -9999,000 -9O09,000 -99~9.000 ...... F I ' ~- T R "'"' g FILE NAME. Sb~¥ICc .,' V ER S I ON f~ OA'TE : MA'(I~UH' LE4GTH Fi'Lb TYPE ' PREVIOUS FILE *::-' FILE H FILr:c NAME.. :LtSWRT.002 SE!:~VIC~: NA~4L : V ER, S I DATE : MAX[?4U~ LENGTH FILL TYP:~ : LO P.R~ V I DUg FILt~ -,- -,- COMMENTS FieLD 2921 LISSU~N~ WELL L5-15 SHIrT~L~ TA,t;i:- SY ;l~ CHqIST~r'¢Sf~¢,i p ,..*, ,q q ,, CNTRY TY?;:: SI ZE R'.: P~ C OOb FRAME SP.a C I ~',iG FRAME. SPACINg ~.~'i'qZTS A~S~fqT VALOr 60.01 8' 4, 68. nATU !Vl Sf cCIF!CATION MNEM SEP,.'\!tCE SEgViCE UNIT AP1 ~ ~ , -. TPL ~PR IO2GY ~S/'~ 0 TPL EPT ~028t CALk tPR 70067 CALi ~PT 70061 IN GR EPK 70017 GAP I O GR ~PT tO0.l I GAP I 0 HT~,v DLR xtn9 l-f HTEN OLL ~091i LD 0 T~NS DLK 40907 LG 0 T~NS DLL 4390t L~ 0 D V 1 O L R ~ 0 ~ -t 1 ~4 V 0 r V ) 1 DLL G067 L 0 :qTEM DLR 40~67 DEOF 0 ~qRES DLR ~35S'7 (1 H~q b'! 0 MRES DLL ~0051 .... h:',, 0 U L ~ 405 47 U A OIO DLL ~064I UA ~ 0 M V OV = OLK qO63Y 0 OVO aLL 40631 MV 0 AP! ~ILE SIZE pROCESS HOi) ?.J!? ~ LL: V~.. L O. Z · ~, 0 · O, 2, 12, n. Z ~ 12 O. 2. ~. O. 0, 2, ~, O · O, Z, 4, O, O. 2. 4- 0 · 2. 4, 0- O, Z, 4. O. Z, 4. 0. 2 · 4. O. Z, 4. O, 2, 4, O. -9999 ~, O()O Tf'~L 1.3 o(~7o CALl -9999.00C- TENS -99°9~00G DVZ -99~9~000 MT tL'F~ - 999:').':) 90 Hi:(f 3 -9999.000 OlO -09?9,000 OV~ -9999.~000 -9909.000 -9999, GO0 - 99q9,., 000 ~? L I S~RT,,uu_ ..... C 0 M H E H T FIELD 2921 i'4ELL 70000 - - c H N Lt$~URNE wELL L5 MAIN PASS L [>K=K EPE A'f P~SS) -,--,- OAfA FO ENTRY DESCRIPTION ENTRY TYP~ SIZ~ RE PR UP/OOWN :LAG 255~ FRAME SPACING FRAME SPACING dN~TS .lin ABSENT VA Li.J~ SP~C.IF tCAT SERVICE VIrE:~ ~JNI T OE°T FT S I O O L R '~. t) ~ 2 '? U StO DLL ~06'~' 1 ~JA S VO DLR 4061 7 SVO DLL ~06t2 MV L L D DL R 40177 () ~t q M L ~ D L L q 017 i [:] il ~ M LLS DLR 4016 t OHM;4 SGR DLR qOtt7 GAPt SG~ DEL ~01 11 S P DLR ~002 7 ~4V SP OLL ~002 i cN 50 91 7 L HT~:?4 NGr 309'i.1 LS TENS ,. rs:, TENS NGt- 30901 MTEM NGR 30o67 OEGF MTSM N&'[ 39061 ~RES NGI' 50051 PROCESS S~MPL_t: RaPa LEVEL CODE O. 1 * 6 $. O, 1' O, [, 68. O. l* 6;5, O. i. O. L- U, i- O, i. O, l, 68, O, i* O. 1. 63. O, I . 0, 1 . 68., O. L* f) E P l- 3550 - C 0 0 S £ O S V LO - 9 9 '? 9 ,~ (] fl ,;] I ] :~ -9'49 9.000 $ I 0 -Ogoq .;'][];l I i ;q Sp SVO LLS SP TENS SVO LLS SP TENS SVO LLS SVO LLS SP D SVO LLS SP TENS MAES D L P [ SVO LL$ SP O E°T SVO LLS SP TENS SVO LLS SP TENS - 99 '-79 ~, OOO -99'O9.000 -9999,, GO0 -99~9~, OOO -99:?S~. 000 -999'9. OOO 8650~,000 -99?9. OOC -99'79 ~, 000 -9999. OOG -99}9~ -9999~000 -'7999. CO0 -:}9'}9.000 -99~9.000 -9999.000 -9999~00G '3 '150 * O O 0 -9999,~ 000 -9999-,000 -9999.800 -q979,.000 8 S 90.,. 000 5~, 596 ":' '~ 500 3670,,~ 000 a, 6 5 o~ ooo 3. 926 -20., i88 0~941 3,, 7:36 Z-~298 -29.359 3774~000 75,.374 - 53 ,,, 2 ,,,::q 1. 3194~, GO0 H T E N SiO LLD HTE N SIO LLO HTE. N SIO LLD S GR H T E N ~a T E iq LLg' :, g R H T E d SI0 L LD SGP. H :iF E N flTEM St9 LL9 SGA c I 0 LL 9 H T E -9999~000 HTEN -99~9~u ~u T ..... -9999,,000 SIO -99'; 9-000 LLD -9999. ~" '~ - u 0 U S G q -9999.000 HTEN -9999~000 MTEM -q999.000 Si9 - 99 :~9~, 0,3© LLD -9999.000. ":. b'-' R -9999*000 NTEN -9999.000 .MTFi'I - 9999,. OOG S I a -9999-000 LLD -9999.000 SGR -9999~,00G HTEN -9999~00Q' *4TE: ~ - 99 :'~ :~. 00 O g l 0 -9999,,000 LLD -9999,,006 SGR -9999.000 HTEN --0999.000 ~qTEF~ tZ3.50C S~O 226.875 SGR 17 1 ,, 500 }4 T F: N 142,531 ~TEM 59 5o 500 S I0 9,24~ LLD 143,262 ':qT ~M 74 ~3,500 SiC 9. 396 LL 0 i03.313 SGR 511.500 HI'EN i~t3,~O0 ~4TEM --q9Pg..O )0 TENS -0999.030 SVO -0999.0~o LLS -9999.000 SP -9999.000 TENS -9999.000 qRES -99o9 ,, Or)d SVO -09~9.8 ~0 LL S -9999.000 SP -0999.000 TbNS -9999.~ O (') J ~"~g~ .... -99°9,. OOO SVO -99c)9.030 LLS -9999~,000 SP -9999,0!30 TENS - 9999... d()O MRE% -0999.390 SVO -9999,. O:'}O LLS O q 8 ,, 309 S V q °~lIo LLS 223....125 SP 7 TO.n ,.,, '30 T E iq .z. 142,000 9~.576 LL~'.., 103.°13 SP UOO,uqO TENS 144,500 30 1o'150 3V,9 77 o o 77 L L S 46.156 SP 752 ,;]O0 TENS 144. 725 ~P, E 3 -(~999,000 -99~9.000 -O999.00'"'u -9999,000 -q990~000 -9999~000 -9999,000 -0999,000 -9999,000 -9999.000 -o999.000 -999q,000 -9999~003 -P999.000 -oggg.co0 -9999.000 -9999.000 -9999.000 -9999.000 -9999e000 Z, 596 5-020 -.2.2.000 3660. CO0 O, 954 9,5 ..,3 950 3 · 744 - ? 7.875 3770.000 0,940 76 o ~*fiO 38 O0 ,, O00 0. 040 SVO SP TENS S¥0 LLS SP TENS F~RES DhPT SVO LLS SP 1' ENS "RES © EP 'T S VO LLS SP T t:NS []E°T SVO LLS SP TENS LLS SP T EMS 0 ~ P T SV© LLS SP T c:Nc' DEPT SVO LLS SP TbNS ~RES S VO 20 ~46 ? -59,400 3050,.000 9050,000 I0~539 -71~i8& 0.927 110,117 -31,313 9150.000 :_~ --, ~, 44 7 -:56.000 3770,000 O~gZZ 92'30 i 7.~000 · -41 ~ 5 3770 * 0 0.,917 900 000 0,9t5 0300, 00© 5,,,,250 16~ 742 -:'i 750 _3 o ,.;- 4 ~ Lc O C 0.* 909 9350.000 142~ 153 - 2 7 ~ 6 8- S 3844-. 000 9~,'00 ~ 090 Si© f~T S I O L L3 HTg ~J MTHH S _£ 0 L LO ~4TEN SiO L LD SGR HTEN .::~ I 0 LLO fqTEN SiO LLD H T E N !~! T F ~4 LL 3 SIO L L [} S GR SiO LaP f--i rl 0 5i9 7 * i 25 2 ~. 575 7 = 2.5'90 ..~ i~4,, 106 37 g. 5': '~ 0 07.423 25 * 2'33 '772~,000 i44.500 ZZ 6,,6Z5 143,040 38,ZSG 754., 500 t44. 950 332~.50u !59 ,, 579 2 1 ,.92Z 796, !3.3.0 14 5.6f-~ 1 112 ,~57b ~ 01 · :' "' 147.031 500,~500 1 4, 45~ 750 79 I. 000 147.4Z5 i7 i ,250 i31.i09 ~:.. ~,, 406 79 1 ,~ DOG 147, 9g7 '! 5 2 ..~., u 0 C 5,500 S I C LLO SGR '--I T E N ~I'EM SIO LLO HTEN SIS) LLi) SGR ?l' .rfH SiO LLO SI3 LL D SGR H1 EN SIO t.Ln H T E N LLD H T E U ¢. i 0 LLD $ GR Sin LLC i99.37~ i78.490 77 731.500 144.o69 346,,250 ZqZ ~, 17_9,92Z 34~, 150 765,000 i45,d50 59,071 20.<591 '749,090 14o, 5 1 ~7.109 759.0!'}0 147 · 1512 ~Sq,~ 15. 44~ 5~4 L 01 , 147 21. C.,C 9b i C -fi. i 0 7 23 ,,, i0'9 77 .:,. 5 q 0 Svo LLS SP TENS SVO LLS SP TENS S ¥ C LLS SVO LLS SP 'rE NS :"; V 0 LLS S? TENs S VO LLS S P TEN S SP TLNS -'.'IRES S V:) LLS SP 'rE ",J ::~ L L S 20,2i9 149.44£ -57.7~L 3124o000 0,939 t0.78i 49° gl 3 -70.500 3770.000 ;3 · 93 7 125.82.5 -29. 000 3/64,~000 i2.500 '50.020 -86.500 3~24,.000 OogBO 16,,934 90.079 -4U,056 -2'.5.750 305~.,000 C o 921 1.5°Z51 -2G.93& 0.919 2,727 , m :: S 0 ,.-, 9 0 0 DEPT 9A. 50.00O .c., I© SVO 27,.53i LL3 LLS 355:~ 566 SGq TENS 393~.000 MI-E~4 /' 3 b - fi 00 .".-t ? C- N .lXt9,, lie ~-~T::t"t., 65,~250 SIO 969,, 159 LL,r) 20,531 SGF', 755.000 ¼fEN 14 ::2.. l 1 Z *4 l' E/% 31 g,'lSO SiO 74,141 L£.D - ~ ._ ~'I ~: ~'-: 27.575 345,,~74 3950.000 60 ,, Z 09 -45,Z19 7004 :. -' '"', ' ,._ , .J ~' -~ 0.905 - O 9 q ~ -9999 - '-~9 o W .... ,- FILE TRAILEil ;::-4~ FiLE NA¢4~ :LiSWAT.OO3 V E R S I O N DATE : HAXi~UM LL~qGYH : i02q FILE 9R~V'IOUS FILH : FiL~: NAtqE 'L!SWP. T.004 SE~VIC=:. ,~ NA?~:_ : V E R S I ON ",~ MAXIMUM Lt:NGTH : FILE TYPE * L(3 PREV IGUS F 1024 L I S~J?, T ' ,~ , .00'~ :::'4:. C O M M E :"] T S ::: ::: FI~ZLD 2921 WeLL 70000 LIS3URN~ ~LL L5-16 SHIFTEO TAOE [~Y ~I~ CHf~ST~N$<-~:N MAI¢~ P~SS.TS -""DILATE'"'~ u 3Y TO3L ;',IN~U~4OF.~ICS ( t.,~. LDT.=~,~I?..~. Li'hi-<=t<FP~}AT .... PAe''b) OESCR l~T ~ O?q UP/OO~N ~-LAG FRAME S P ':x C I i'qT.; FRAME SPACING UNITS o~L,.,T VALOE 255,, 4. 1~, 60. 60,,00 8.. 4. (>8. -0999,,00 12. G. 68:, OATUM SPECIFICATION ELOCKS SERVICE SERV iC~ :)1:? T WSNG NGR .5~)847 WSNG NGT 506~i W4NG NGR 30637 NgNG NGR 30027 W3NG NGT 30621 W2NG NGR 30617 WZNG NGT 30611 WING NGR ~0607 N1NG NGT ~060i C G R N G R 30317 CGR NGT 39311 POTA NGR 3021~ POTA NGT ~02: I 1 URAN NG~ 50~07 THOR NGR 53197 THOR NOT 39191 SGR ~ ~ P SGR NGT 5001 i L,':N!T API AP1 .AP1 AP! FiLE LOC, IYPE CLASS Fl' O. O, O, Fp° ~ c, O~ O. O. O. 4 , CPS O, O, O, ~PS CPS O. O. O. CPS O~ 0. O. CPS O~ O- O. C P .S u~ 0 · 0, 0 CPS O~ O. O. O- CPS O~ O~ O. O. 4. G.API O- O, O. SAPI O~ O, O, PU O. O, O. P PM C) · 0 · 0, PPM 0- O~ O. PPM O. O. O~ P P ~ 0 0 Q G'API O, O. O, O. 4, GAPI O, O~ O~ LEVEL O. O, O. O. O. O, O. O. O. O, O. O. O. Oo O. O, Oo O, SAM -9999oD00 WSNG -g'99c) , u,..} O W 3 i"lG -9999~, OOo WING - 9999.000 POTA -9999.000 TH~A -9909.800 -9999.000 - 9999 ,~ :33 0 - 9999 ,, 9 ::) 0 -9999,,000 -999g ~ O;:)C -9909, ,J ('3 O -99'g9.090 :42N$ URAN Jd,~o CG'~ -7999,000 -9999~000 -9999.G03 -9<?99,300 -9'999~000 -9999,0g0 -9999~000 -9999.000 -9999~003 -9997,000 0999.0 -9909.000 -'7999.003 -q979,000 CGR UR ~N n ...... LPT W 2 N G CG~ SGn W2NG CGR U R A N DE? 1' W 2 N G SGR DEp-1- C &P 9E~T U R A N S OEPT W£NG URAN SGR -9999. OOO -99?9,000 -9999~,000 -9999-000 - 9999.~ GOO -99q9~ 000 O0~ -g999, 223,125 i].7.203 375 305 3'750~, 000 0, 7 5 0 6~ 438 3°805 40, t~: 0000., 000 3~787 ZO, 563 O,V09 27~016 4.055 40~ 344 12~ 703 1. 935 2 5. '760 "-2i 30:~ 000 POTA T HO R WS~G W i N G P~TA T H L I R W.3NG NtNG PGTA T HO R POTA T H 9 R ~ I NG T ;.tg R - 9909 ~,, 000 - 9999. C (3 b -99.79,u00 -q999,000 -9999~ 000 -99o9°000 - 9999 ,, 000 -99q9., O00 -9999.000 !90,750 740~500 2.~, 539 7Z,04i 5'75 10,Z77 7,04'7 51.34~ S33~250 2~t9'? I0.510 4,02'7 i45,000 0,342 2,035 0.g52 ~. 02'7 7'6.500 i · J0,O '~ ' Jk 25 i I ....... ~ v P U T A WiNG PQT A TH 2Fi W lNG L.Ji THEIR W 5 NC POTA T H 0 R W 3 N & P ',3 T A T H :q R W i H G POTA THOR :,? 5 N C - 99a9 · O©u - 99 '99 ,. L) 90 -9999~ 0'30 -9909.090 -9999~00U -9999.030 -9999~:y00 l~O&O 22,266, 7.0 T :3 .322, O 9 © 9.539 30,2 o 7 15q ~, 500 O, .'-; 3:3 i ~, 590 ! '/· 1:+i (.13 · 7 $ 0 W U R A ,'i SGR C S F{ ~.IR A N SGR ',4 ~ %1' '.q Z N C '.SC,;{ S (; R C GR uRA?¢ W 4 f'"l & SGR W q- '4 S G 2 -9909. OOO -q9c)9., OOu - q999. OOO -9909~.0fl0 -999q °000 -0999.000 -9909.000 -0999o00G -99~?.000 -9999~000 2-1 70,313 22,141 226,,d7~ I Z, 195 2 30.000 t0~,063 6,529 151.500 5,055 Io¥°125 T2.375 3.564 i03~3!3 50 ° .34 q' t 2 ,, 734 2.207 r-"4. d75 19.059 25.203 2,~,)I 2 ,' 1,2 'I A_~'iA'4 W4~ URAN SG° Wz~NG CGR URAN SGR DbPT WZNG CGR 0 OEPT W2NG URAN W4NG C~R L;RAP~[ SGR W 4NG W2qG CGR U RAN SGR 3E?T Cbt, SGR 9150.000 o.,~ 051 ~.i.~ 344 17.063 0.,528 20.o91 9200,,000 O* 946 ,29- 328 11,,563 2 ,. 4'77 25,,516 9250~000 7.070 i~457 9300~,000 2,,o40 i>4. 375 2.473 44~594 28.£c, 7 o i$~Z42 1.o15 '~'3~ 109 i45~,375 73,,d75 2~352 G~947 583 lo~53 i75 9500. u u 0 1 ,, 010 7.113 W 5 NG WiNG w 5t4G W ~ ¢4 G W LNG T H 8 R WSNG WiNG POTA POTA W LNG F' ::3 T A Wi t-4O PO FA T H 0 R FOTA T H O P, W 3 4 G T ~-i 0 R O. 000 9,,703 79,,81'3 0.391 0,145 1.0 07 16-109 Z ,97'_7 2,014 16-,i09 0.977 3,270 0.._ 000 125.i25 2 ,, '*90 3.250 0-000 10.070 6.5 0.39i 1.336 550. 375 HSNG W i N (; P {3 T A TH ~''' R W i NG P GTA T H 0 R WSNG W3FqG ~{ '1 '-,' PO TA THOR W 3 N G P C! T A T h 0 R iNC- PUTA Tr:OR W 5 ~,i {5 W i q g PUTA id I. ~q G L; TA T HF]K 53,459 i · ,"53 ;: ~. 19,859 106 ,b r5 0., 95 .J C., } '? i i57~ 4 0. 7 · S 73 iN 4 ~'! G C3R S 3R UR A;,i SSa '4 2 N C; CSF: l_lk A 5 SGR W2 l'.i" C GR C GR C Gq 'JR A ;" :44 !:; .L, '-~ 38.2_50 3 13 :343 922 3 . 020 4.6.313 27 · '~ 38 3.020 4~o313 27.3t3 0.469 29.563 49 .. 150 0.37b 45 ,, 750 g ,014 53.54~ ii,,313 2.'54~ 24.406 :: . i ? 5 3.225 94~. i86 ' 016 29.219 -O. 5q8 I S ..34e 1.0~7 79.2O3 2 0.98 ~ -0,, 005 2 0 o 5 3 i THQR 50~,553 0, 3 !~ C a,,, 72Y P G T A - °99g.~ 0 O0 37 ~ -t,251 -99~9 ~000 -7999~,00U -g999~000 - 99e9,,. 000 THO~. -0.9o9,000 -9999 ~, -9999~,000 *::: ~-IL~: TRAILLR SERVICE ',lAME,', ' V ER q I 0~,~ OATL" O~/iO/~7 MAXIMUM LENGTH : 1024 FILE TY~E ' La PREVIOUS rfL~ : FILE NAME V~ cRSION ,- : DAT~ : 04/!"' :qAXIMU¢4 LENGTH : io24 FILE ~YP6 PRhVI OUS ~iL{: L l SW,&T .'-' 04,--, ---.- C O M M E ~"J T S *.:;: ,_9~.1 i4~LL 'lnOOo FIELD ? 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NL HT ZN ~-'~ T F <'~ r'i P H I FCNL M T &: d 11/-+ ° 3.512 2q 2. l 75 7,3 t. 1 l :) Z. J ") 0 2 ? 4. I >' 5 3 9 ~, 9 7 0 3 · 3:9 5 545.5 0;..) 57d,.030 1 O ? 7', (,, 0 .) NPN I N P H I N R A T F',' P ,q I 74 C 'F [: "12 ~.~- '.; P H I NCNu - 0999. GO0 - 999 9. - 0999. 000 - ?995 ~OOt) -7999.000 - 9999 * -9909 - o797, OOC -q999 .,JO0 -mgm'? ,, - 99 ? 9,0 aU - 9909 .,, 000 -99o9..'306 -'79o9, O0 J -9909~000 -0909 .<)00 -q909 .dO0 - 99 q 9.0 3 -9999.30U - 0909. - q90, 9,, 000 N C NL {} t P I- N PH[ NRA T NCNL TENS MRES N PHI NRAT NCNL DEPT TENS Mile S q PHI NEAT NCNL 9EPI' TENS NPH1 NRAT NCNL RAT NCNL DEPT' ~qRt S NPHi N R A T NCNL 'IF ENS ~q PH. i N aA t' N CN L g~PT' T E N $ N PHI NEAT NCNL 40::~0,, O00 dTEFi i- Tea FCa'IL 4516,+000 1045,000 3, ? 13 V, ....... Zgs', 330 30. 3°229 1062,, 000 2q? · 750 11.06I Z~g3d 233 ¥~ ! 032 ,,, 000 301,. i00 30.613 1698. 000 1039 ~ OOO 302.e50 .i ,,354 i03Z~O00 30 '4 · Z c'; O .l 9. i 57 I. 3 '1o~, OOO ~i T 5 N p:--I I F C ~',i L H'T EN *' T ':: k! 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FtL2 :')ATE MA× I ~IL~ P Ri V P A S S ) i'Yc''-, c SIZE :X;,-P~'` , .~rOrlF- il) ~, T r-~ T CALI CUR 20007 ~ALI CNL i GA CNA 20017 GA?I '"R C~,~L 200] ~ C:A°i HTEN tOR 10917 L6 HTE{'4 LDT iOeli L~:~ TENS LDR 10907 T~NS L,. T ingdl SSHV LDR i() i0~ V SSHV CDT 13T'.)t V LSHV LDR l'~o~l V LSHV LOT [~)~9 L V S S 2 L 0 R i 0 6 ~,-.~ -/ C P SS1 LOR 1So77 CPS SSI Lgl i067 i CPS :~ TE 71 LO'[ .i 06-f~ I DE:3F LSHV SSi. HRE.. S DEPT T~NS LSHV SSi ~4RE! $ GR L SH¥ DEPI' TENS LSHV SS1 TENS LSHV SSt qR~:S :..; c F T G~ T~NS LSHV SS1 H RES L S~-~ V SS1 r'4 R E S 3690~000 .llg/~OPO Z75.750 1/90,,oOO 239 · ~75 0,930 o u,-, ~, 000 222,025 t ::~ _i ,, 00 O O:, 915 3d50,, 000 OOC 375 000 ~'75 CALl H T E ~'~ oSHV SS2 cALi H T ~:: N cALI H T E >J S SHY SS2 'TE. 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() 00 3oi53 0.025 3.445 u ,. 22'q' 223.000 00612 - 0,003 LL <'~ SS PEF Dr:UT LS LL ;~ SS !_S LL '~ S S -0,012 0.04i 3~iq9 O~Ui~ LiTH C! L S L[TH LU 5..516 r~L ¢ ~ P H I LI TH L U L C,L S ['i i ~ f'J "' 2 Z 3 ,, 6 :'~ b L L 2. :', 1. 5 '~ 4, H 7'50 -0.302 231..3t5 q~!TZ 0°033 223,:525 l l 5., 50U FILE YER S DA'T£ ~!AXI FILE PRE V N a?q ~: : LI SW~:T,O07 ICE ?,,~ A ME MUM L ~ NG'TF~ IOUS FILl] i fi d ~:~ L I S ~! ii 'F ,. 007 ...... C©MM TS FIELD 292i ~JLLL 70000 LI. oLJRNE W~LL L5-16 SHrFTEr~ .......... ~qAIF~ PASS i :3 lh,iUlCA'FEu. - ~v, TOOL L":'r< =P,-P'-AT ?ASS) ENTRY BLOCK:J DESC,~,~ iPTI 0, C.NTRY TYP~ SIZ~ R::PP. CO[',E !,j [:i I T :S O E P T ' ":" d :) :,,j,,, OOO CALt GR [ J5.750 DF_PT GR J-'% ~** 250 D E P 'T !.~ 790 ,, 000 C A t t 159,~000 9EPT !~830,,,O00 CAt t OEPf 3aCO,OOO CALI GR 14Z. i 2 5 q -'P 9 0 ,~. b T d, 00,, OG (}AL I OEPT %950,000 CAt i D E P '[ 9 ;3 '!~ 0 ,~ 00 O rd A L i ,...,r'~ t ;), T 9100 ,, 0 O O C. A L I G A 31 ,, ~ '3 9 DEPI c~gO0., OOO C,qL i ,,.;, i< 75 ,~ 45% OEPT :)250,000 CALl DEPI' 93 30,,000 CALl -9999,000 1 O, 859 l_i ~305 10,533 10,4.77 i 0 ~ ~ 75 CALl EALI r' AL I CALl CALl r ~AL I CALI CALl CALI CALI CALl c~Lt CALl ""ALi CALl CALi i U, 77 ~ 10 ,:L~7 2 I 0 * 5 ~ 9 iOogC, l I t -, 'J :3 .l .1 * b % 'T (.; R G R G R - 9 9 9 q :, 0 0,3 - 99q9. 000 - 9999,000 - 9 9 99 ,, 0 r'~,, n...,. - 9 q 9 q, 0 0 O 2 1 3 ,, 500 1 5i, Z !:~;0 9 i °875 15,070 GR~ Dt;~ T G R GR DEPT 719 '9 :S 0 O,~ O00 3i,719 2.'. 7 ,, 2 -50 -79:~9,000 C^ti C A t i C~Li CAtr~. CALl 1 1 ,, 7 5 ia ! 0 ,, 27 3 10. 28 9 ,..ALI CALl C ;, t I ~ At.I 10,5'~9 GR · .:i 9 · !) 0 0 FiLE S ER V Vt_RS PATE MAXI Ftt.~ P RE V SERVICE NA-'a.E :LiS~,,~RT OATh :04~/I0/8 0 R I G I N : TAPE: NAME : C 0 N f I NU A T I (] N PREVIOUS TAPE WELL LgG m r" T"M ;:-'~ RrSEL TRAILER SbRVICE r.~A...q~ :LiS~,~PT DATE :0~/19/87 ORtG IN : REEL NAME : CONTINUATIJN fi- : PREVIOUS REEL : COMMEN'TS : M, r,.,~,.FORD_L?:~,¢tS [~NC._ ,oQY :~'.:: KV I CE S - p£ Ti<OS :~ELL t 0 C, '~i~&LYSIS .SYSTEr4 ** REEL MEAOER ** REEL NAME : DATE : ...... ORIGIN : FSYS SERVICE NAME: B!TLIS REEL CONTINUATION NUMBER: 01 PREVIOUS REEL NA~E : COMMENTS: DRESSER ATL.&S LIS CUSTOMER TAP: --- CREATEC BY SDS P~CGRAM R 2.0 LEN,GTH: 132 BYTES ** TAPE HEADER TAPE N~ME : DATE : ORIGIN : FSYS SERVICE NAME: PASS1 TAPE C~NTINUATI~N NUMBER: 01 PREVIOUS TAPE NAME : COMMENTS: LENGTH:~ 132 B~?ES ** FILE HEADER # I ** FILE NAME: P~SS1 .001 SERVICE KAME: VERSION # : 1 OATE: $5/11/2~ M&X RECORD LENGTh: 102~ BYTES FILE TYPE: LO PREVIOUS FILE NAME: . ** INFORMATION RE£ORDS ** MNEM CONTENTS APIN : 50029217~0 CN : ARCO ALASKA, WN : L5-16 FN : LISBURNE COUN : NORTH SLOOP STAT : ALASKA LOC : 1 50.QO ** FORMAT ** UNITS AUG O 5 1981 :N'TR Y BLOCKS TYPE ENTRY DESCRIPTION 8 9 11 0 I DEPTHS DECREASE 60.0 FRAME SPACING .lIN FR~E SPACING UNITS 12 M 4XI~UM FRAMES/RECORD TERMINATOR -0.500 LEVEL SPACING DATUM SPECIFICATION BLOCKS CURVE NAME ~CCL REPR CODE SIZE SAMPLE ~NITS 68 4 I DIM CURVE NAM: .SPD REPR COCE SIZE S~MPLE UNITS 68 4 ~ F/MN G1 68 4 1 G2 68 4 1 MON 68 4 1 BKS 68 .4 1 ISS 68 4 1 MSD 68 4 1 RBOR 68 4 1 RICS 68 4 I CPS CPS CPS CPS CPS CPS SU DIM DIM S'S GElS GR BKL CSS SGMA RATO RIN 6'8 68 68 68 68 68 68 68 4 4 4 4 4 4 4 CPS CPS AP1 CPS SU DIM ** FORMAT ** ENTRY BLOCKS TYP: ~NTRY z, 1 8 - 60.0 9 ,lIN 11 12 0 -0.500 DESCRiPTiON CEPlHS DECREASE F ...R,'~ M E SPACING FRAME S~ACiNG UKITS MAXIMUM FRAM~S/R~CORO TERMINATOR LEVEL SP~CiNG DATUM SPECIFICATION BLOCKS CURVE ~EPR NAME CODE SIZE SAMPLE bNITS CCL 68 4 1 DI~ LS 68 4 ! CPS G1 68 ~ I C~S G2 68 4 1 C~S MON 68 4 1 CPS BKS ~$ 4 I CPS ISS 68 4 I CPS MSD 68 4 I SU RBOR 68 4 I ~iM RICS 68 4 I ~iM ** DATA ** CURVE NAME SS GE!S BKL CSS SGM.~ RiN REPR CCC~ 68 6~ 4 4 S~PLE 1 1 1 1 1 1 1 1 1 UNITS F/~N CPS CPS C~S CIM jIM CEPT~ 9438.C00 F? 2876.7C8C M CCL. O.CO0 SPD 8 G1 9169.~82 GElS 854~! MON 363,964 BKL 1~9 ISS 3~9~39.1~ SGMA 12 R~OR t.~33 ~IN 9 .CO0 .44~ .989 .411 .716 LS G2 6KS MSD RICS 1 97c .8C2 404~.595 89.g,910 C.288 18.777 SS G2 CSS RATC 21227.880 22.981 10/,58.350 10.746 DEPTH 94GO.COO FT 2565.126C M CCL 0.000 SPD 14 G1 3906,588 GElS 77~96 MON 360,137 BKL 44 ISS 300498.900 SGM~ 22 RBOR 2,C19 R!N 9 .999 ,380 .952 ,273 ,872 LS G2 BKS MSD RICS 896,041 1381,977 594,682 1,372 26,574 SS GR CSS RATO 13941,840 33,951 11307.820 16,101 DEPTH 9300,G00 FT 2834,646C M CCL 0.~00 SPD 14 G1 4216,367 GElS 81.947 MON 368,929 8KL 34 ISS 304810.900 SGMA 18 RBOR I ,986 RIN 10 ,999 .C6C, ,742 .702 ,105 LS 'G2 BKS MSD RICS 974,41C 1267,266 571.489 C,59C 25,14C SS GR CSS RATC 1~529,400 21 ,031 12124,510 16.098 OEPTM' 9200 .COO F'[ 2804.1660 M m mm m -- m m mm mm~m m m mm--m m mm mmmm ,m mmmm CCL 0.000 SPO 14. 999 G1 7915.762 GElS 82221.5~ MO~ 386.248 BKL 47-~661 ISS 300393.400 SGMA I 2.263 R~OR 1.873 RIN 9.9~5 LS 62 BKS MSD RICS DEPTH glO0.CC-O FT 2773.6860 M CL 1 ON SS 0.~00 SPD 14.999 8107.176 GElS B6596.C60 3Q1.001 BKL 58.807 313227.900 SGM~ 12.835 I .897 RIN 9.755 LS G2 BKS MSD RICS OEPT~ 9CCO.OCO FT '2743.2C6C, M CCL O.gO0 SPD 14.999 G1 8968.621 GElS 82761.130 MON 389.414 BKL 20.956 ISS 306522.600 SGMA 12.335 R~OR 1.899 RIN 9.9C~ L S G2 BKS MSD RZCS ,SEPTH 8900.0~0 F~ 2712.726C M CCL O.gOO SPC 14.99,o G1 1765.557 GElS ?23SO.PCS MON 356.627 BKL 171 .762 ISS 292320.800 SGM~ 32.~09 RBOR 2.C13 RIN 10.~92 LS BKS MSD RiCS CEPTH 880C.CC0 FI 2682.245C M CCL O.GO0 SPO 1~.999 G1 830.314 GElS 71778.560 MON 346.348 BKL 219.C9~ ISS 280923.400 SGMA RBOR 2.091 RIN 10.827 LS G2 :KS MSD RICS DEPTH 8766.500 F? 2672.035C M CCL 0.~00 SPO 14.999 G1 969.903 GElS 68683.130 MON 366.96~ BKL 409.959 ISS 279602.100 SGMA 46.755 RBOR 2.054 RIN 11.005 LS G2 BK S MSO RICS STARTING ~EPTH = 9438.000 FT ENDING DEPTH : 8766.500 ~T 2876.7050 M 2672.0350 M ** FILE TRAILER *~ FILE NAME: P~SS1 .001 SERVICE NAME: VERSION # : 1 DATE: 85/11/ MAXIMUM LENGTH: ~024 FILE TYPE: LC NEXT FILE NAME: *- FILE HE~DER # 2 ** FILE NAME: PASS2 .002 SERVICE NAME: VERSION # : 1 1633.623 3562.42C 597.645 G.2gC 19.9G3 1729.846 3492.177 ~a9.64C C.196 2C.066 1782.99~ 3911.371 617'.'7C 1 0.151 19.413 464.308 2C7.,~47 663.524 2.762 31 .?~C 31~.4C~. 56.322 6~4.1 57 0.9C9 33.771 389.961 G.OCC 889.911 1.072 33.772 SS GR CSS R~TC SS GR CSS R~TO SS GR CSS SS GR CSS R~TC SS GR CSS R~TO SS GR CSS R~TC 19174.180 14.253 15092.980 11.752 19790.080 15.971 1 5610.090 11 2C148.130 10.872 1~78~.730 11.361 11379.&99 63.752 9204.125 2&.209 9622.~A13 106.115 ~.31~.438 30.137 11~308.970 112.052 8279.172 26.&36 OAT~: 85/1t/20 MAX RECORO LENG]M: FILE TYP=: LO PREVIOUS FILE NAME: lO24 ~YTES . ** INFORMATION ~ECORDS ** MNEM CONTENTS mmmm mmmmm mm APIN : 5002921700 CN : ARCO AL~'SKA, INC. 'WN : L5-16 FN : LISSU~E COUN : NORTh ST~T' : AL~SK~ LCC : ** FORMAT ** ., UNITS ENTRY BLOCE. S TYPE ';NTRY OESCiRIDT!ON 4 1 DEPTHS DECRE~S~ 8 6C.0 FRAME SPACING 9 .liN FRAFE SPACING UNITS 11 12 MAXIMUM FRAMES/RECORD 0 TER~NflTOR -0.500 LEVEL SPACING DATUM SD:~IFICAT~ON~" BLOCKS CURVE REPR NAME CODE SIZE SAMPLE UNITS CCL 68 ~ 1 LS 68 4 I CPS G1 68 4 I CPS G2 68 ~ I CPS MON 68 4 1 CPS BKS 68 4 I C~S ISS 68 4 I CPS MSD 68 ~ I SU- RBOR 68 ~ 1 RICS 68 4 I DiM ** FORMAT CURVE NAME SPO SS GElS GR BKL CSS SGMA RATO RIN REPR CO~E 6~ 68 ~8 68 ~8 SIZE ... m--~. 4 4 4 4 S~MPLE 1 1 1 1 1 1 1 1 1 UNITS F/MN CPS CPS CPS SU ~IM ENTRY BLOCKS TYPE ENTRY DESCRIPTION IIim m mm 4 I D~PIMS DECREASE 8 60.0 FRAME SPACING 9 .lIN FRAME SPACING U~ITS 11 12 .MAXIMUM FRAMES/RECORD 0 TERMINATOR -0.500 LEVEE SPACING ~ATUM SPECIFICATION BLOCKS CURVE DEPR NAME CODE SIZE S~MPLE 'UNITS CURVE N~ME REPR CODE SIZE SAMPLE UNITS CCL 68 & I DIM LS 68 4 1 CPS G1 68 & I CPS G2 68 4 1 CPS MON 68 4 I CPS B~KS 68 4 I CPS ISS 68 ~ I CPS MSD 68 4 I SU RSOR 68 4 I DIM RICS 68 4 1 DIM ~* D4TA ** OEPTH 9439.000 FT 2877.013C M CCL 0.000 SPO 0 G1 8909.117 GElS 85C41 MON 336.96.6 BKL 89 iSS 300549.900 SGM~ 12 RBOR 1.823 RIN 9 .COO .5~0 .g91 .514 .816 DEPTH 9400.CC0 FT 2865.1260 M CCL C.CO0 SPD 13 G1 2298.619 GElS 72134 MON 354.C21 BKL 70 ISS 284524.100 SGM~ 3'3 RBOR 2.C16 R-TN .999 .690 .278 .630 .132 DEPTH 9300.C'C0 FT 2834.~46C M CCL O.~D S=D 13.99g G1 3623.376 GElS 77961 MON 359.141 BKL 66.256 ISS 29361 5.300 SGM~ 21.900 RBOR I .967 RIN 1~.125 DEPTH 9200.CC0 FT 2804.'166C M CCL O.OO0 SPD 13.999 G1 7710.325 GElS 79431.060 MON 378.225 BKL 42.832 ISS 292718.600 SGMA 12.745 RBOR 1.856 RIN 9.826 DEPTH 9100.000 FT 2773.6860 M CCL O.COO SPD 13.g99 G1 7616.473 GElS 83650.250 MON 383.404 BKL 59.589 ISS 305339.100 SGMA 12.756 RBOR 1.892 RZN 9.785 DEPTH 9000.CC0 FT 2743.206C M mmmmmImmmmlmmmmmmmmmmmmmmmmmmm CCL 0.000 SPD 13.999 G1 8602.141 GElS 77370.000 MON 380.239 BKL 42.902 ISS 294656.900 SGMA 12.814 RBOR I .904 RIN 10.041 SPD SS GElS GR BKL CSS SGMA RATC RIN LS G2 BKS HSD RICS LS G2 BKS MSC ~ICS LS G2 BKS MSD RICS LS G2 BKS HSD RICS LS G2 BKS MSD RICS LS G2 BKS MSD RICS 68 ~8 68 68 68 186g.813 3929.6C7 8cg.91g 0.12C 6C6.742 631.431 535.964 2.312 29.884 83E.159 871.07~ S34.221 26.018 1586.651 3364.631 511 .9C1 0.171 19.943 1755.454 330~.243 5C2.537 ~.25~ 2~.421 158~.361 3742.61C 494.54C, C.294 19.671 4 4 4 4 4 4 4 4 4 1 1 1 1 1 1 1 1 1 m/MN CPS CPS ~Pl CPS ~P! SU DIM DIM SS GR CSS R~TC 2'~ ~17 950 ~ ,., . ~6,264 1606~.39~ 10.~35 SS GR CSS R&TO 11473.450 42.9~g 9520.867 19.534 SS GR CSS R~TO 146~6.50'~~ . 2Z.7~0 11285.160 17.642 SS GR CSS RATC 1~S89.380 18.384 1'4677.840 11 .931 SS GR CSS RATO 18945.380 20.O45 14952.230 10.822 SS GR CSS RATC 19382.070 17.517 14978.990 12.259 DEPTH 8goo.oGO FT 2712.726C M lmmmmmmmmmmlmm mmmmmmmm CCL 0.000 SPD 13.999 LS 543.584 SS 11661.700 G1 2246.825 G~IS 71027.750 G2 411.711 GR 62.087 .... ,ON, 341.618 BKI~ 174'.076 B'KS ISS 282526.800 SGMA 28.504 HSD RBOR 2.031 RIN 10.635 RIOS DEPTH 8800.000 FT 2682.2450 M COL O.CO0 SPD 13.999 LS G1 753.439 GElS 68484.940 G2 MON 338.052 BKL 215.156 BKS ISS 274504.200 SGMA 5C.248 MSD RBOR 2.C20 RiN 10.995 RIOS DEPTH 8767.500 FT 2672.339C M CCL O.CSO SPD 13.999 G1 0.000 GE1S 89.991 G2 MON 12.999 8KL 499.950 BKS ISS 19.998 SGM~ -45~6.559 MSD RBOR I .COO RIM C.. COO RIOS STArTiNG DEPTH = 9439.000 FT ENDING DEPTH = 8767.500 FT 2877.0130 M 2672.3390 M ** ~IL~ TRAILER ** FILE N4ME: PASS2 .002 SERVICE NAME: VERSICN# : 1 DATE: 85/11/ MAX!MUM LENGTH: 102~ FILE TYPE: LC NEXT FILE NA~E: ** FILE HEAOER FILE N~ME: PASS3 .003 SERVICE NAME: VERSION # : 1 D~TE: 85/11/20 M~X RECORD LENGTH: 1024 SYTES FiLE TYPE: LO PREVIOUS FILE NAFE: . ** INFORMATION RECORDS ** MNEM CONTENTS APIN : 50CE921700 CN : ARCO ALASKA, INC. WN : L5-16 FN : LISBURNE COUN : ~.NORTH SLOPE STAT : ALASKA LCD : 150.00 ** FORMAT ** UNITS ENTRY BLOCKS TYPE ENTRY 4 1 8 6C.0 9 .lIN OE$CRIPTION DEPTHS DECREASE FRAME SPACING .FRAME SPACING UNITS 5~1'.13C 2.78~ 30.1~ 3C5.02C 3C..087 626.749 O .999 34.261 C.OCC 59.9~4 3~9.9~3 23.1d2 C.657 DSS RATe SS GR DSS R/~T.C SS GR CSS RATC 9367.527 21,245 9270.742 11G.156 :8012.234 30.782 ~9.991 29.997 C.OOO ~11 ' 12 0 -G.500 DATUM SPECIF M ~XIMUM FRAMES/RECORD TERMINATOR LEYEL SPACING ICATION BLOCKS CURVE REDR NAME CODE · i, .m ,~. ,m i ii .j l,. ,.,. i COL 68 LS 68 G1 68 G2 68 MON 68 B!K S 68 ISS 68 MSD 68 RBOR 68 RIOS ' 68 SIZE SAMPLE UNITS 4 I DIM 4 I CPS 4 1 C PS 4 I CPS 4 I CPS ~ 1 CPS 4 1 CPS ~ I SU 4 I DIM -' 4 I DIM CURVE REPR NAME CODE SIZE SAMPLE mlmmiI mlmm mmIm ImmIml SPO 68 4 1 SS 68 4 1 GElS 68 4 1 GR 68 4 1 BKL 68 4 1 CSS 68 4 1 SGMA ~8 4 1 RATO 68 4 1 RIN 68 4 1 ** FORMAT ** UNITS F/MN C~S CPS CPS SU CZM DIM ENTRY BLOCKS TYPE ENTRY DESCRIPTION 4 I DEPTHS DECRE.&SE 8 6O.O FR~ME SPACING 9 .1 TN .~R~ME SPACING UNITS 11 12 MAXIMUM FR~M-=S/RECORD O T ERt~INATOR -0.500 LEYEL SPACING DATUM SPECIFICATION BLOCKS CURVE REPR NAME. CODE SIZE SAMPLE .... UNITS COL 68 4 I DIM LS 68 4 1 CPS G1 68 ~ I CPS G2 68 4 1~ CPS MON 68 4 I CPS BKS 68 4 I :CPS iSS 68 4 I CPS MSD 68 4 I SU RBOR 68 4 I CIM RICS 68 4 I DIM ** DATA ** DEPTH 9439.000 FT 2877.013C M COL O.O00 SPD G1 8259.17~ GElS 8248 MON 387.961 BKL 6 ISS 298440.300 SGMA 1 RBOR I .74Z RIN I O.CCO 1 '750 9.993 I .673 0.264 DEPTH 9400.000 FT 2865.126C CCL O.CC~ SPD 1 G1 1388.38S GElS 6991 MON 341.1 51 BKL .8 ISS 273968.5Cg SGMA M 4.999 4.750 4.300 5.062 CURVE REPR NAME CCCE SIZE SAMPLE SPg 68 ~ 1 SS 68 4 1 GElS 68 4 1 GR 68 4 1 .BKL 68 4 1 Css 68 4 1 SGMA 68 4 1 RATO 68 ~ 1 RZN .68 4 1 LS G2 BKS MSC RICS LS G2 8KS MSD 1899.810 37C9.629 909..909 C.244 18.855 431.104 242.749 464.810 2.279 SS GR CSS RATO SS GR CSS RATO UNITS IImmm F/MN CPS CPS CPS SU DIM DIM 2C827.920 36.770 15828.420 10.894 1C312.640 45.262 8547.352 24.10.4 RSOR, 2.015 RTN 10,510 RICS DEPTH 9300.00C FT 2834.6460 M CCL O.OOO SPD 14.999 G1 3401.516 GElS 76481.690 MON 370.251 BKL 56.816 ISS 29C996.000 SGM4 22.651 RBOR 1.923 RIN 10.280 LS G2 BKS HSD RICS DEPTH 9200.00 mm~m--mlII CCk 0.000 SPD G1 7256,750 GElS MON 389.909 BKL ISS 292309.300 SGM4 RBOR 1.833 RIN 0 FT 2804.1660 M 14.999 78368.31~ 32.52C; 12.881 10.~50 LS G2 BKS HSD RICS ~EPTH 9100.C~0 FT 2773.686C M m mmmm mmm,~ m m m.mm~mm,mm mm m--m~mI mmm m CCL O.OO0 SPD t5.3,~8 G1 7464.828 GElS 82493.250 MON 391 .~94 BKL 43.460 ISS 303167.9G~ SGM~ . 13.55~ RBOR I .827 RZN 9.705 LS G2 BKS MS~ RICS DEPTH 9000.000 FT 2743.206C M mmmmm--m m CCL O.CCO SPD 15.800 G1 8391.4~9 GElS 75933.0d0 NON 377.382 9KL 54.462 ISS 288493.C00 SGMA 12.666 RBOR 1.836 RIN 1~~. 057 LS 62 BKS ~,S3 RiCS DEPTH .8900.CCC FT 2712.726C M CCL O.OgO SPD 13.999 G1 2958.S23 GElS 71C52.75~ MON 361.437 BKL 139.C44 ISS 2~0335.700 - SGMA 24.649 RBOR I .879 RIN 10.628 LS G2 BKS HSD RI C.S DEPTH 8800.C00 FT 2682.2450 M CCL 0.000 SPD 13.g99 G1 838.385 GElS 67858.690 MON 347.495 BKL 192.421 ISS 271806.500 SGMA 47,625 RBOR 1.981 RIN 10.885 LS G2 .5KS MSC RiCS DEPTH 8751.500 FT 2667.463C M mmmmmmmmmmmmmmmmmmmmmmmmmmmm--m CCL 0.000 SPO 13.999 G1 O.CO0 GElS 49.995 MON 8.999 BKL 179.982 ISS O.CO0 SGMA -4.977 RBOR 0,000 RiN O.O00 LS 62 BKS HSD RICS STARTING DEPTH = 9&3'9.000 FT ENDING DEPTH = 8751.500 FT 2877.0130 M 2667.4630 M ** FILE TRAILER FILE NAME: PASS3 .0~3 SERVICE N~ME: VERSION # : I 31 .682 777.793 514.767 C.729 26.438 1537.578 3122.507 489.158 0.3:8 20.453 1742~176 339G.294 493.499 C.19C 20.436 1531.117 3672.590 529.~14 C.1~3 19.463 684.939 67C.984 543.215 ... C.957 27.6C5 345.179 6~.388 555.677 1.795 ]3.914 ~.000 29.997 219.978 4.08C C.OCC SS GR CSS RATC SS GR CSS R~TC SS Gq CSS R~TC SS GR CSS RATC SS GR CSS R4TC SS GR CSS R4TO SS GR CSS RATO 14192.680 29.400 .11006.860 18.605 18464.400 21.433 14291.430 12.040 19C04.610 21.402 14834.320 10.g02 192~3.733 18.276 14822.290 12.619 13C36.150 63.937 1C155.160 18.953 9209.965 112.255 8014.~92 26.949 0.000 87.328 0.000 0.000 MAXIMUM LENGTH: 1024 FILE TYPE: LO NEXT FILE NAME: ** TAPE TRAILE~ ** TAPE NAME: SERVICE NAME: PASS3 DATE: ORIGIN OF DATA: FSYS TAP.E CONTINUATION # : 01 NEXT TAPE NAME: COMMENTS: ** ~E.EL TRAILER ** REEL NAM=::_ SERVICE NAME: B-ITLIS DATE . C~IGIN Gm DATA: FSYS REEL CONTINUAT!O,N # - ~1 NEXT REEL NA,UE: COMMENTS: DRESSER ATLAS LIS CUSTCM~ER T~,mE --- CRE~TE~ 5Y SDS PROG~,~. R 2.0 REEL HEADER - 1 TAPE HEADER - 1 FILE HEACER - 3 INFORMATION - 3 FORMAT - 6 DATA - 339 TABLE DUMP - 3 FiLE T~A[LER - 3 TAPE T~AILER - 1 REEL TRAILER - ] TOTAL R=CORDS· 3~1 * ALASKA COMPUTING CENTER * ****************************** * ............................ * ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : LS- 16 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292170000 REFERENCE NO : 99140 RECEIVED 1999 klm~Oil&~Coos.~~n LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/03/23 ORIGIN : FLIC REEL NAME : 99140 CONTINUATION # : PREVIOUS REEL : COF~IENT : ARCO ALASKA, L5-16, PRUDHOE BAY, API# 50-029-21700-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/03/23 ORIGIN : FLIC TAPE NAME : 99140 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA, L5-16, PRUDHOE BAY, API# 50-029-21700-00 TAPE HEADER PRUDHOE BAY/LISBURNE CASED HOLE WIRELINE LOGS WELL NAME: L5 - 16 API NUMBER: 500292170000 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 23-MAR-99 JOB NUMBER: 99140 LOGGING ENGINEER: VETROMILE OPERATOR WITNESS: MIDDENDOERF SURFACE LOCATION SECTION: 1 TOWNSHIP: 11 N RANGE: 15 E FNL: FSL: 1788 FEL: FWL: 19 ELEVATION (FT FROM MSL O) KELLY BUSHING: 60. O0 DERRICK FLOOR: 59. O0 GROUND LEVEL: 21. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 625 9559.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: SDN LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: MAR-87 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 9360.0 9359.0 9355.5 9354.5 9348.5 9348.0 9344.0 9340.5 9339.5 9334.5 9328.5 9324.0 9322.5 9317.5 9314 0 9313 0 9311 5 9310 5 9308 0 9304 5 9302.5 9301.5 9297.0 9292.5 9292.0 9290.5 9289.5 9287.0 9286.5 9282.0 9281.5 9277.5 9270.0 9268.5 9268.0 9267.0 9266.5 9265.5 9262.5 9260.0 9258.0 9256.5 9246.0 9244.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88886.5 88889.0 9357.5 9354.5 9346.5 9339.5 9323.5 9312.5 9310. 5 9308.5 9305.5 9302.0 9291.5 9289.0 9285.5 9280.5 9268.5 9267.0 9265.5 9259.0 9256.0 9246.0 9243.0 9361.0 9354.5 9349.0 9343.0 9339.5 9334.5 9328.0 9323.0 9317.0 9312.5 9311.0 9304.5 9302.0 9297.0 9291.5 9289.0 9286.0 9282.5 9277.5 9268.5 9267.0 9265.5 9263.0 9259.0 9246.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9243.0 9243.0 9240.0 9241 . 0 9233.0 9233.5 9230.5 9230.5 9229.5 9230.5 9226.5 9226.0 9225.5 9226.0 9219.0 9219.0 9215.0 9216.0 9210. 5 9209.5 9207.0 9206.5 9206.0 9206.5 9204.0 9204.0 9199.0 9197.5 9196.0 9196.5 9194.5 9193.5 9193.0 9193.5 9189.5 9188.0 9179.5 9179.0 9179.0 9179 , 0 9169.5 9170.0 9168.0 9167.5 9163.5 9164.5 9161.0 9161.5 9160.0 9161 . 5 9156.5 9158.5 9153.5 9157.0 9153.0 9153.5 9150.5 9151.5 9139.0 9139.5 9128.5 9128.0 9127.5 9128.5 9122.5 9123.0 9122.0 9123.0 9112.0 9113.5 9111 . 0 9113.0 9105.5 9108.5 9105.0 9107.5 9101.0 9104.0 9098.5 9100.0 9094.5 9095.0 9094.0 9095.0 9086.0 9087.0 9078.5 9079.0 9077.5 9079.0 9075.0 9075.5 9074.5 9075.5 9067.5 9068.0 9058.5 9058.0 9057.5 9058.0 9052.0 9052.0 9049.5 9050.0 9048.0 9048.0 9040.0 9040.0 9039.5 9040.0 9034.5 9033.5 23-MAR-1999 10:53 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 9028.5 9025.0 9021.0 9016.0 9013.5 9012.5 9007.5 9004.5 9004.0 8995.0 8994.5 8993.0 8990.0 8986.5 8985.5 8983.5 8975.5 8974.0 8964.0 8961.0 8957.0 8950.5 8950.0 8948.0 8939.5 8938.5 8936.5 8920.0 8917.0 8914.0 8906.0 8903.5 8900 0 8898 0 8894 5 8889 0 8884 0 8880 0 8879 5 8874 0 8873 0 8868 0 8864 0 8863.0 8859.5 100.0 REMARKS 9030.0 9026.0 9026.0 9020.5 9016.0 9013.5 9013.5 9008.5 9004.5 9004.5 8995.0 8995.5 8993.5 8990.5 8986.5 8986.5 8984.0 8975.5 8975.0 8965.5 8960.5 8961.0 8957.0 8950.5 8950.0 8947.5 8939.0 8940.5 8939.5 8935.0 8920.5 8916.0 8916.0 8906.0 8904.0 8904.0 8898.0 8898.0 8893.5 8889.0 8885.0 8880.5 8880.5 8873.5 8873.5 8868.0 8865.0 8862.5 8860.0 99.5 100.5 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON ARCO ALASKA'S L5-16 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE SDN GA~P~A RAY, ALSO BASE PASS #1 SIGMA AND THE SDN GAIV~4A RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/23 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 ArUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~rzARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9358.5 8849.5 RST 9379.0 8850.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** ....................................................................................... 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 6085769 NBAC RST CPS 6085769 FBAC RST CPS 6085769 SBNA FIL CU 6085769 SFNA FIL CU 6085769 SBFA FIL CU 6085769 SFFA FIL CU 6085769 TRAT FIL 6085769 IRAT FIL 6085769 CIRNFIL 6085769 CIRF FIL 6085769 BSALRST PPK 6085769 O0 SIBF RST CU 6085769 O0 TPHI RST PU-S 6085769 O0 SFFC RST CU 6085769 O0 SFNC RST CU 6085769 O0 SIGM RST CU 6085769 O0 DSIG RST CU 6085769 O0 FBEF RST UA 6085769 O0 CRRARST 6085769 O0 GRCH RST GAPI 6085769 O0 TENS RST LB 6085769 O0 CCL RST V 6085769 O0 GR SDN GAPI 6085769 O0 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9490.000 NBAC.RST -999.250 FBAC. RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC. RST -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: SIGM. RST -999.250 DSIG.RST GRCH. RST -999.250 TENS.RST DEPT. 8496.500 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF. RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH. RST -999.250 TENS.RST -999.250 FBEF. RST -999.250 CCL.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC.RST -999.250 FBEF. RST -999.250 CCL.RST -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 CRRA.RST GR.SDN SBNA.FIL TRAT. FIL BSAL.RST SFNC.RST CRRA.RST GR.SDN -999.250 28. 984 -999.250 -999.250 -999.250 -999.250 -999.250 134.500 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001 CO1 DATE : 99/03/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE '. FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SU~FiARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9359.5 8850.0 RST 9378.5 8850.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: BASELINE DEPTH .............. 88888.0 9360.5 9355.0 9354.5 9352.5 9348.0 9346.5 9344.5 9341.5 9335.5 9334.0 9330.0 9329.5 9326.0 9324.5 9323.0 9318.0 9316.5 9313.0 9311.5 9310.5 9309.5 9305.0 9302.0 9298.0 9297.0 9293.0 9291.0 9290.0 9283.5 9282.5 9279.0 9277.0 9274.0 9271.5 9268.0 9267.5 9259.0 9250.0 9246.5 9246.0 9243.5 9243.0 9241.5 9237.5 9233.5 9226.5 9225.5 9219.5 9217.5 9215.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88887.5 88888.5 9361.0 9354.5 9354.5 9350.5 9346.5 9345.0 9343.5 9340.0 9334.0 9334.0 9329.0 9328.5 9324.0 9323.5 9323.5 9317.0 9314.5 9312.5 9310.5 9311.0 9308.0 9305.0 9302.0 9297.0 9297.0 9291.5 9289.0 9289.5 9282.5 9282.5 9278.0 9275.0 9272.5 9271.5 9267.0 9267.0 9259.5 9250.0 9246.0 9246.0 9243.0 9243.0 9241.0 9237.5 9233.5 9226.0 9226.0 9219.5 9216.5 9216.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 9210.0 9209.5 9206.5 9204.5 9203.5 9202.0 9200.5 9200.0 9198.5 9196.5 9194 0 9189 5 9182 5 9181 5 9180 0 9174 0 9167 5 9160 5 9157 0 9153.5 9151.5 9145.5 9141.0 9133.0 9128.0 9127.5 9123.0 9122.5 9114.0 9111.5 9108.0 9103.0 9101.5 9097.0 9095.0 9094.5 9087.0 9085.0 9079.5 9078.0 9075.0 9073.5 9072.5 9070.5 9064.0 9063 0 9059 0 9058 0 9054 5 9045 0 9042 0 9033.5 9031.5 9027.0 9025.5 9209.5 9206.5 9204.0 9199.0 9197.5 9193.5 9188.0 9181.5 9179.0 9168.0 9161.5 9151.5 9141.5 9128.0 9123.0 9114.0 9106.5 9100.0 9098.5 9095.0 9087.5 9085.0 9079.0 9075.5 9073.0 9068.0 9062.5 9061.5 9058.0 9045.0 9034.0 9026.5 921 O. 0 9207.0 9204.0 9202.0 9200.0 9197.0 9194.0 9181.5 9174.0 9161.5 9158.0 9153.5 9146.0 9134.0 9128.5 9123.5 9113.0 9106.0 9095.5 9088.0 9079.5 9075.5 9073.5 9063.5 9058.0 9054.5 9042.5 9032.5 9026.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 10 9022.5 9022.5 9021.0 9021.5 9015.0 9013.5 9013.0 9014.0 9010.5 9011.0 9009.0 9008.5 9007.0 9008.0 9005.0 9005.0 9000.0 8998.5 8995.0 8995.5 8991.0 8991.5 8987.0 8986.5 8986.0 8987.0 8983.0 8984.0 8977.0 8975.5 8961.0 8961.0 8959.5 8961.0 8957.0 8957.0 8950.5 8950.5 8950.5 8948.5 8947.5 8942.5 8938.5 8940.5 8941.0 8938.5 8937.0 8938.0 8939.5 8937.0 8934.5 8934.0 8932.5 8928.5 8929.5 8927.0 8925.0 8921.0 8921.0 8914.5 8916.5 8905.5 8906.0 8904.0 8904.0 8900.0 8898.5 8891.5 8891.0 8883.5 8883.5 8880.5 8880.5 8879.5 8880.5 8874.0 8873.5 8873.0 8873.5 8868.0 8868.0 8863.5 8864.5 8860.0 8861.0 8856.0 8857.5 8854.5 8854.5 8852.0 8852.0 100.0 100.0 100.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 11 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11' 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** 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) DEPT FT 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 BSALRST PPK 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 6085769 O0 000 O0 0 2 1 i 4 68 0000000000 TPHI RST PU-S 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 12 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS RST LB 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 6085769 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9378.500 NBAC.RST 2011.765 FBAC.RST 3039.395 SBNA.FIL SFNA.FIL 19.315 SBFA.FIL 44.318 SFFA.FIL 15.648 TRAT. FIL IRAT. FIL 0.517 CIRN. FIL 1.154 CIRF. FIL 2.632 BSAL.RST SIBF. RST 31.422 TPHI.RST 18.673 SFFC. RST 12.922 SFNC.RST SIGM. RST 12.911 DSIG.RST 1.729 FBEF. RST 62.509 CRRA.RST GRCH. RST -999.250 TENS.RST 1319.000 CCL.RST 0.000 DEPT. 8850.000 NBAC. RST 2017.825 FBAC.RST 2926.842 SBNA.FIL SFNA.FIL 36.118 SBFA.FIL 46.280 SFFA.FIL 36.057 TRAT. FIL IRAT. FIL 0.576 CIRN. FIL 0.507 CIRF.FIL 0.885 BSAL.RST SIBF. RST 45.459 TPHI.RST 29.282 SFFC. RST 32.859 SFNC.RST SIGM. RST 32.883 DSIG.RST -1.237 FBEF. RST 42.542 CRRA.RST GRCH. RST 57.320 TENS.RST 1205.000 CCL.RST 0.060 52.586 0.843 26.688 14.337 1.943 58. 727 O. 991 65. 523 31.567 1. 734 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: AVERAGED CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 13 Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, RST $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF BASE PASSES 1 & 2. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS'CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA RSAV CU 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA RSAV CU 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA RSAV CU 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA RSAV CU 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PA GE: 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) TRAT RSAV 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT RSAV 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNRSAV 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF RSAV 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 BSALRSAV PPK 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RSAV CU 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RSAV PU-S 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RSAV CU 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RSAV CU 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RSAV CU 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RSAV CU 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RSAV UA 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 CRRA RSAV 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 6085769 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9379.000 NBAC. RST 1835.935 FBAC. RST 2939.150 SBNA.RSAV SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV SIBF. RSAV -999.250 TPHI.RSAV -999.250 SFFC. RSAV -999.250 SFNC.RSAV SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF. RSAV -999.250 CRRA.RSAV GRCH. RST -999.250 DEPT. 8849.500 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.RSAV SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV IRAT. RSAV - 999. 250 CIRN. RSAV - 999 . 250 CIRF. RSAV - 999.250 BSAL. RSAV SIBF. RSAV - 999. 250 TPHI. RSAV - 999. 250 SFFC. RSAV - 999. 250 SFNC. RSAV SIGM. RSAV - 999. 250 DSIG. RSAV - 999. 250 FBEF. RSAV - 999. 250 CRRA. RSAV GRCH. RST 46. 046 -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 NAME : EDIT .003 SERVICE : FLIC VERSION : O01COi DATE : 99/03/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 99/03/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 23-MAR-1999 10:53 PAGE: 15 FILE HEADER FILE~BER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUMg~a~Y VENDOR TOOL CODE START DEPTH ........................... RST 9412.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 8758.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESEVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 12-MAR-99 8Cl-205 9418.0 9410.0 8850.0 9378.0 TOOL NUMBER ........... CGRS-A 864 RST-A 8.500 9559.0 CRUDS/SORAX LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 16 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: LOG TIED INTO SWS CNL DATED 14-MAR-87 SBHP AT 8900'=3408 PSI AND AT 9010'=3418 PSI LOGGED THREE BASELINE [SIC] RST SIGMA PASSES AND THREE BORAX RST SIGMA PASSES ON SECOND BORAX PASS IT APPEARS BORAX WAS OVERPUMPED WITH FLUSH FLUIDS, ON THIRD PASS INDICATION WAS DEEPER. PUMPED 1-1/2 WELLBORE VOLUME OF CRUDE AND LOGGED BASELINE AT 1/2 TO 1 BPM. PUMPED WELLBORE OF BORAX AND THEN CRUDE, FOR 20 BBLS BORAX BEHIND PIPE. LOGGED ONE GOOD PASS AND THE SECOND PASS SEEMS TO BE OVERPUMPED ALREADY POSSIBLE VACUUM, TAKING BORAX RAPIDLY (WELLBORE VOLUME=i 02 BBLS) PUMPED 373 BBLS CRUDE, 100 BBLS BORAX, AND 18 BBLS DIESEL. SWHP: 2300 PSI BEFORE, 300 PSI AFTER; IAP:350 PSI; OAP: 0 PSI; DID NOT TAG TD THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CS PSlF/HR 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 TENS PS1 LB 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 NPHVPS1 V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 NPDE PS1 V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 NSCE PS1 V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CRRA PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 NSCR PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 AQTMPS1 S 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CHV PSl V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CPSV PS1 V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CP2V PS1 V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CM2V PS1 V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 RCFR PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 RCLC PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 RCRC PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 RCAKPS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 RTDF PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 FPHVPS1 V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 FPDE PS1 V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 FSCE PS1 V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 FSCR PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 AQTF PS1 S 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SF6P PS1 PSIG 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 HVPV PS1 V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 BMCU PSI UA 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 18 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) GDCU PS1 MA 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 EXCU PS1 UA 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 NBEF PS1 UA 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF PS1 UA 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 NPGF PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 FPGF PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 BSTR PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 BSPR PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 MARC PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 XHV PSi V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 XPSV PS1 V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 XP2V PS1 V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 X~2V PS1 V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 RXFR PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 RXLC PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 RXRC PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 RXAKPS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SHCU PS1 MA 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL PS1 PPK 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL SIG PPK 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNPS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG PS1 CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC PS1 CPS 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC PS1 CPS 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA PS1 CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA PS1 CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA PS1 CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA PS1 CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA SIG CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA SIG CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA SIG CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA SIG CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF PS1 CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC PS1 CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC PS1 CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PS1 CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF SIG CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM SIG CU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT SIG 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 GR PS1 GAPI 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 19 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) RDIX PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CRNI PS1 KHZ 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CRFI PS1 KHZ 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CTM PS1 DEGC 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 XTM PS1 DEGC 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 TAV PS1 KV 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 FICU PS1 AMP 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CACU PS1 AMP 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 BUST PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 BUSP PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 RSXS PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PS1 PU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI SIG PU 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 CCLC PSl V 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 RSCS PS1 6085769 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9412.000 CS.PS1 1831.129 TENS.PSi 1244.000 NPHV. PS1 NPDE. PS1 1569.368 NSCE. PS1 2.531 CRRA.PS1 1.865 NSCR.PS1 AQTM. PS1 0.661 CHV. PS1 200.127 CPSV. PS1 5.079 CP2V. PS1 CM2V. PS1 -12.133 RCFR.PS1 0.000 RCLC. PS1 0.000 RCRC. PS1 RCAK. PS1 0.000 RTDF. PS1 0.000 FPHV. PS1 1511.231 FPDE. PS1 FSCE. PS1 1.756 FSCR.PS1 0.014 AQTF. PS1 0.661 SF6P. PS1 HVPV. PS1 179.932 BMCU. PS1 35.742 GDCU. PS1 60.668 EXCU. PS1 NBEF. PS1 30.740 FBEF. PS1 57.329 NPGF. PS1 0.988 FPGF. PS1 BSTR.PS1 41.526 BSPR.PS1 1.183 MARC. PSI 0.000 XHV. PS1 XP5V. PS1 5.069 XP2V. PS1 12.144 X~I2V. PS1 -12.407 RXFR.PS1 RXLC. PS1 0.000 RXRC. PS1 0.000 RXAK. PS1 0.000 SHCU. PS1 BSAL.PS1 -999.250 BSAL.SIG -999.250 CIRN. PS1 -999.250 CIRF. PS1 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG. PS1 -999.250 FBAC. PS1 IRAT. PS1 -999.250 IRAT. FIL -999.250 NBAC. PS1 -999.250 SFNA.PS1 SFFA.PS1 -999.250 SBNA.PS1 -999.250 SBFA.PS1 -999.250 SFNA.SIG SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PS1 SFNC. PS1 -999.250 SFFC. PS1 -999.250 SIGM. PS1 -999.250 SIBF. SIG SIGM. SIG -999.250 TRAT. PSi -999.250 TRAT. SIG -999.250 TRAT. FIL GR.PS1 33.647 RDIX. PS1 113208.000 CRNI.PS1 450.349 CRFI.PS1 CTM. PS1 83.496 XTM. PS1 81.543 TAV. PS1 95.175 FICU. PS1 CACU. PS1 2.554 BUST. PSI 3.000 BUSP. PS1 3.000 RSXS.PS1 TPHI. PS1 -999.250 TPHI.SIG -999.250 CCLC. PS1 0.000 RSCS.PS1 DEPT. 8758.500 CS.PS1 NPDE. PS1 1561.166 NSCE. PS1 AQTM. PS1 1.102 CHV. PS1 CM2V. PS1 -12.113 RCFR.PS1 RCAK. PS1 0.000 RTDF. PS1 FSCE. PS1 1.917 FSCR.PS1 HVPV. PS1 179.639 BMCU. PS1 1858.431 TENS.PSI 2 522 CRRA.PS1 199 279 CP5V. PS1 0 000 RCLC. PS1 0 000 FPHV. PS1 -0 098 AQTF. PS1 30 136 GDCU. PS1 1218.000 NPHV. PS1 3 346 NSCR.PS1 5 084 CP2V. PS1 0 000 RCRC. PS1 1501 466 FPDE. PS1 1 102 SF6P.PS1 60 296 EXCU. PS1 1560.060 0.010 12.143 0.000 1509.286 136.001 3.945 0.986 198.916 0 000 56 909 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 241.479 2.163 8878.000 8192.000 1544.191 -0.087 12.195 0.000 1501.046 129.229 7.522 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 2O NBEF. PS1 BSTR. PS1 XP5V. PS1 RXLC. PS1 BSAL. PS1 CIRN. FIL IRAT. PS1 SFFA. PSI SFFA. SIG SFFA. FIL SFNC. PS1 SIGM. SIG GR. PS1 CTM. PS1 CACU. PSi TPHI. PS1 23.891 66.310 5.069 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 75 544 67 139 2 547 -999 250 FBEF. PS1 79.931 NPGF. PS1 BSPR.PS1 1.136 MARC. PSi XP2V. PSl 12.144 X~2V. PS1 RXRC. PS1 0.000 RXAK. PS1 BSAL.SIG -999.250 CIRN. PS1 CIRF. FIL -999.250 DSIG. PS1 IRAT. FIL -999.250 NBAC. PS1 SBNA.PS1 -999.250 SBFA.PS1 SBNA.SIG -999.250 SBFA.SIG SBNA.FIL -999.250 SBFA.FIL SFFC.PS1 -999.250 SIGM. PS1 TRAT. PS1 -999.250 TRAT. SIG RDIX. PS1 130969.000 CRNI.PS1 XTM. PS1 64.779 TAV. PS1 BUST. PSl 3.000 BUSP. PS1 TPHI.SIG -999.250 CCLC. PS1 1.007 FPGF. PS1 0.000 XHV. PS1 -12.417 RXFR.PS1 0.000 SHCU. PS1 -999.250 CIRF. PS1 -999.250 FBAC. PS1 -999.250 SFNA.PS1 -999.250 SFNA.SIG -999.250 SFNA.FIL -999.250 SIBF. PS1 -999.250 SIBF. SIG -999.250 TRAT. FIL 437.302 CRFI.PS1 94.993 FICU. PS1 3.000 RSXS.PS1 -999.250 RSCS. PS1 1.001 198.512 0.000 43.316 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 130.766 2.157 8878.000 8192.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 99/03/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS AKIMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUF~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH RST 9413.0 8798.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 21 $ 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 RST RESEVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~IPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: LOG TIED INTO SWS CNL DATED 14-MAR-87 12-MAR-99 8Cl -205 9418.0 9410.0 8850.0 9378.0 TOOL NUMBER ........... CGRS-A 864 RST-A 8.500 9559.0 CRUDE/BORAX THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 22 SBHP AT 8900'=3408 PSI AND AT 9010'=3418 PSI LOGGED THREE BASELINE [SIC] RST SIGMA PASSES AND THREE BORAX RST SIGMA PASSES ON SECOND BORAX PASS IT APPEARS BORAX WAS OVERPUMPED WITH FLUSH FLUIDS, ON THIRD PASS INDICATION WAS DEEPER. PUMPED 1-1/2 WELLBORE VOLUME OF CRUDE AND LOGGED BASELINE AT 1/2 TO 1 BPM. PUMPED WELLBORE OF BORAX AND THEN CRUDE, FOR 20 BBLS BORAX BEHIND PIPE. LOGGED ONE GOOD PASS AND THE SECOND PASS SEEMS TO BE OVERPUMPED ALREADY POSSIBLE VACUUM, TAKING BORAX RAPIDLY (WELLBORE VOLUME=102 BBLS) PUMPED 373 BBLS CRUDE, 100 BBLS BORAX, AND 18 BBLS DIESEL. SWHP: 2300 PSI BEFORE, 300 PSI AFTER; IAP:350 PSI; OAP: 0 PSI; DID NOT TAG TD THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 23 ** 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 ELE~ CODE (HEX) DEPT FT 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS2 F/HR 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS2 LB 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 NPHVPS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 NPDE PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS2 S 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CPSV PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 RCAKPS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 FPHVPS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 FPDE PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 FSCR PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS2 S 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SF6P PS2 PSIG 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 HVPV PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 BMCU PS2 UA 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 GDCU PS2 MA 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 EXCU PS2 UA 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 NBEF PS2 UA 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF PS2 UA 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 FPGF PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 BSTR PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 MARC PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 XHV PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 XPSV PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 ~2~2V PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 RXFR PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 RXLC PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 RXRC PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 RXAKPS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SHCU PS2 MA 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL PS2 PPK 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL SIG PPK 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CIRN PS2 6085769 O0 000 O0 0 5 1 1 4 68 ,0000000000 CIRF PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 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) DSIG PS2 CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS2 CPS 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC PS2 CPS 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA PS2 CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA PS2 CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA PS2 CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA PS2 CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA SIG CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA SIG CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA SIG CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA SIG CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF PS2 CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC PS2 CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC PS2 CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS2 CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF SIG CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM SIG CU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT SIG 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT FIL 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS2 GAPI 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 RDIX PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PS2 KHZ 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CRFI PS2 KHZ 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CTM PS2 DEGC 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 XTM PS2 DEGC 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 TAV PS2 KV 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS2 AMP 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CACU PS2 AMP 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 BUST PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 BUSP PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 RSXS PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS2 PU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI SIG PU 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 CCLC PS2 V 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 RSCS PS2 6085769 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9413.000 CS.PS2 1863.354 TENS.PS2 1015.000 NPHV. PS2 1555.177 NPDE. PS2 1558.839 NSCE.PS2 2.644 CRRA.PS2 1.852 NSCR.PS2 -0.295 AQTM. PS2 0.661 CHV. PS2 199.400 CP5V. PS2 5.069 CP2V. PS2 12.173 CM2V. PS2 -12.133 RCFR.PS2 0.000 RCLC. PS2 0.000 RCRC. PS2 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 25 RCAK. PS2 0.000 RTDF. PS2 FSCE. PS2 1.972 FSCR.PS2 HVPV. PS2 179.932 BMCU. PS2 NBEF. PS2 30.508 FBEF. PS2 BSTR.PS2 36.235 BSPR.PS2 XP5V. PS2 5.069 XP2V. PS2 RXLC. PS2 0.000 RXRC. PS2 BSAL.PS2 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS2 -999.250 IRAT. FIL SFFA. PS2 -999.250 SBNA.PS2 SFFA. SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC. PS2 -999.250 SFFC.PS2 SIGM. SIG -999.250 TRAT. PS2 GR.PS2 66.791 RDIX. PS2 CTM. PS2 65.918 XTM. PS2 CACU. PS2 2.563 BUST. PS2 TPHI.PS2 -999.250 TPHI.SIG 0.000 FPHV. PS2 0.190 AQTF. PS2 36.621 GDCU. PS2 56.511 NPGF. PS2 1.095 MARC. PS2 12.129 XI~2V. PS2 0.000 RXAK. PS2 -999.250 CIRN. PS2 -999.250 DSIG.PS2 -999.250 NBAC. PS2 -999.250 SBFA.PS2 -999.250 SBFA.SIG -999.250 SBFA.FIL -999.250 SIGM. PS2 -999.250 TRAT. SIG 135419.000 CRNI.PS2 64. 453 TAV. PS2 3 . 000 BUSP. PS2 -999. 250 CCLC. PS2 DEPT. 8798.000 CS.PS2 1795.797 TENS. PS2 NPDE. PS2 1562.615 NSCE. PS2 2.582 CRRA.PS2 AQTM. PS2 0.441 CHV. PS2 199.885 CP5V. PS2 CM2V. PS2 -12.133 RCFR.PS2 0.000 RCLC. PS2 RCAK. PS2 0.000 RTDF. PS2 0.000 FPHV. PS2 FSCE. PS2 1.907 FSCR.PS2 0.321 AQTF. PS2 HVPV. PS2 179.688 BMCU. PS2 31.347 GDCU. PS2 NBEF. PS2 24.509 FBEF. PS2 40.460 NPGF. PS2 BSTR.PS2 63.849 BSPR.PS2 1.143 MARC. PS2 XPSV. PS2 5.069 XP2V. PS2 12.142 X~2V. PS2 RXLC. PS2 0.000 RXRC. PS2 0.000 RXAK. PS2 BSAL.PS2 -999.250 BSAL.SIG -999.250 CIRN. PS2 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG. PS2 IRAT. PS2 -999.250 IRAT. FIL -999.250 NBAC. PS2 SFFA.PS2 -999.250 SBNA.PS2 -999.250 SBFA.PS2 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC. PS2 -999.250 SFFC. PS2 -999.250 SIGM. PS2 SIGM. SIG -999.250 TRAT. PS2 -999.250 TRAT. SIG GR.PS2 95.142 RDIX. PS2 152770.000 CRNI.PS2 CTM. PS2 67.383 XTM. PS2 66.341 TAV. PS2 CACU. PS2 2.549 BUST. PS2 3.000 BUSP. PS2 TPHI. PS2 -999.250 TPHI.SIG -999.250 CCLC. PS2 1499.024 0.661 60.996 1.002 0.000 -12.407 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25O -999.250 -999.250 467.617 95.031 3.000 0.010 1205.000 1.651 5.069 0.000 1499.024 0.441 60.274 1.008 0.000 -12.412 1.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 446.633 94.955 3.000 -999.250 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS. PS2 RSCS. PS2 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P.PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS. PS2 1499.864 130.372 5.129 1.009 198.431 0.000 35.121 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 252.444 2.275 8878.000 0.000 1547.853 -0.532 12.143 0.000 1502.954 130.082 8.180 1.008 198.447 0.000 42.926 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 270.547 2.161 8878.000 8192.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-MAR-1999 10:53 PAGE: 26 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001 CO1 DATE : 99/03/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/03/23 ORIGIN : FLIC TAPE NAME : 99140 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, L5-16, PRUDHOE BAY, API# 50-029-21700-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/03/23 ORIGIN : FLIC REEL NAME : 99140 CONTINUATION # : PREVIOUS REEL : CO~4ENT : ARCO ALASKA, L5-16, PRUDHOE BAY, API# 50-029-21700-00 *----SCHLUMBERGER----~ LIS TAPE VERIFICATION LIS?ING ,VP OlO.HO2 VERIFICATION LISTING ,~ R:EL HEADER ~ ,ERVICE NAME :EDIT ~ATE :87/03/19 IRIGIN : iEEL NAME : BLAN :ONTINUATION ~ :01 'REVIOUS REEL : iOMMENTS :LIBRARY TAPE := TAPE HEADER ,ERVICE NAME :EDIT tATE :87/03/19 IRIGIN :7222 'APE NAME : ;ONTINUATION ~ 'REVIOUS TAPE ;OMMENTS :LIBRARY TAPE PILE HEADER :ILE NAME :EDIT ..001 iERVICE NAME : 'ERSION ~ : ~TE : IAXIMUM LENGTH : 1024 :ILE TYPE : ~REVIOUS FILE INFORMATION RECORDS INEM CONTENTS ',N : ARCO ALASKA, INC. IN : LISBURNE L5-16 :N : PRUOHOE BAY/LISBURNE POOL ',ANG: 1SE 'OWN: ;ECT: ~OUN: NORTH SLOPE ;'TAT: ALASKA ~TRY: USA INEM CONTENTS 'RES: E :X~ COMMENTS PAGE UNIT TYPE CATE SIZE CODE 000 OOO 0'18 065 000 000 014 065 000 000 026 065 00:0 000 004 065 000 000 004 065 000 000 001 065 000 000 012 065 000 000 006 065 000 000 004 06:5 U~NIT TYPE CATE SIZE CODE 000 000 00I 065 VP 810:.~02 VERIFICATION LISTING PAGE 2 SCHLUMBERGER ALASKA COMPUTING CENTER OMPANY = ARCO ALASKA INC !ELL = L5-16 :IELD = PRUDHOE BAY/LISBURNE FIELD 'OUNTY = NORTH SLOPE 'BOROUGH iTATE = ALASKA 'URFACE LOCATION = 1788' FSL & lg' FEL~ SEC l~ TIIN~ R15E IDB NUMBER AT AKCC: 72226 :UN #1~ DATE LOGGED: 1~-MAR-87 ,DP: R. KRUWELL ~PI SERIAL NO: 50-020-21700 PERMANENT DATUM: MSL ELEV OF PERM. DATUM: 0 F LOG MEASURED FROM: RKB DRLG MEASURED FROM: RKB ELEVATIONS: KB: 60.0 F DF: 59.0 F GL: 21.0 F )EPTH-DRILLER = 9575 F )EPTH-LOGGER = 9542 F ITM. LOG INTERVAL: 9527 F 'DP LOG INTERVAL: 8797 F CASING-DRILLER CASING-LOGGER CASING BIT SIZE = ~006 F = NOT LOGGED = 10.75" = 7.625" VP .010.~02 VERIFICATION LISTING PAGE 3 DEPTH = 9575 F 'YPE FLUID = LOW-LIME SOURCE OF SAMPLE = CIRCULATED ~ENSITY = 9.6 LB/G RM = 1.96 @ 75 DF 'ISCOSITY = 39.4 S RMF = 2.4! @ 76.5 DF 'H = 11.7 RMC = 3.04 @ 71 OF :LUID LOSS = 6.6 C3 SOURCE RMF/RMC = MEAS/MEAS 'IME CIRC STOPPED= 11:45 MAR 14 87 RM AT BHT = 1.024 @ 150 DF 'IME LOGGER ON BTM.= 16:19 MAR 14 87 RMF AT BHT = 1.282 @ 150 DF lAX REC. TEMP. : 155 DF RMC AT BHT = 1.510 @ 150 DF .OGGING UNIT NO: 8266 .OGGiNG UNIT LOC: PRUDHOE BAY :IELD ENGINEER: T. WEST tITTNESSED BY: ROBINSON/CAMERON tATRIX = LIMESTONE tDEN = 2.71 G/C3 IHC = NONE tC = CALI :LUID DENSITY = 1.0 GM/C3 IEMARKS: 1.) CHANNELS WITH THE EXTENSION DLR,LDR,CNR,EPR:,NGR' ARE REPEAT FILES 2 ). CHANNELS WITH THE EXTENSION DLL'LDT~CNL,EPT,NGT ARE LOG FILES 3.) NPHI.CAL IS 'THEE ENVIRONMENTALLY CORRECTED NEUTRON POROSITY FOR .VP 010.H02 VERIFICATION LISTING PAGE LOG FILE 4.) NPHI.CAR IS THE ENVIRONMENTALLY CORRECTED NEUTRON POROSITY FOR REPEAT FILE !QUIPMENT NUMBERS: TOOL ~1 AMM AA 742 TOOL ~2 TCC A 107 TOOL ~3 SGC SA 404 TOOL #4 NGC C 1935 TOOL #5 NGD B ?56 TOOL ~6 OLS F 754 TOOL ~7 DEE E 724 TOOL #8 DLC D 761 TOOL #9 TCM 19 ILL INTERPRETATIONS ARE OPINIONS BASED ON INFERENCES FROM ELECTRICAL OR 1THER MEASUREMENTS AND WE CANNOT. AND DO NOT GUARANTEE THE ACCURACY OR :ORRECTNESS OF ANY INTERPRETATIONSt AND WE SHALL NOT, EXCEPT IN THE CASE OF ~ROSS OR WILLFUL NEGLIGENCE aN OUR PARTy BE LIABLE OR RESPONSIBLE FOR ANY .OSS, COSTS, DAMAGES OR EXPENSES INCURRED OR SUSTAINED BY ANYONE RESULTING :ROM ANY INT'ERPRETATION MADE BY ANY OF OUR OFFICERS~ AGENTSs OR EMPLOYEES. tHESE INTERPRETATIONS ARE ALSO SUBJECT TO OUR GENERAL TERMS AND COMDITIONS ~S SET OUT IN OUR CURRENT PRICE SCHEDULE. VP 010.~02 VERIFICATION LISTING PAGE 5 THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS X-'~ SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: DUAL LATERLOG LOG FILE (OLL) DUAL LATERLOG REPEAT FILE (DLR) LITHO DENSITY COMPENSATED LOG FILE (LOT) LITHO DENSITY COMPENSATED REPEAT FILE (LDR) COMPENSATED NEUTRON LOG FILE CCNL) COMPENSATED NEUTRON REPEAT FILE (CNR) NPHI.CAL ENVIRONMENTALLY CORRECTED POROSITY LOG FILE NPHI.CAR ENVIRONMENTALLY CO,RRECTED POROSITY REPEAT ELECTROMAGNETIC PROPAGATION TOOL LOG FILE (EPT) ELECTROMAGNETIC PROPAGATION TOOL REPEAT FILE (EPR) NATURAL GAMMA TOOL LOG FIiLE (NGT) NATURAL GAMMA TOOL REPEAT FILE (NGR) VP OlO.HO2 VERIFICATION LISTING PAGE :, DATA FORMAT RECORD ** NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 1 66 1 8 4 73 60 9 4 65 .liN 16 ! 66 1 0 1 66 0 tATUM SPECIFICATION BLOCKS )NEM SERVICE SERVICE UNIT AP1 API API AP1 FILE SIZE SPL REPR ID ORDER # CODE )EPT .LS DL:L .LD DLL ;GR DLL ;P OLL ;V 0 DLL ;i 0 DLL )VO DLL )I0 DLL 4R E S O:LL ~TEM DLL tENS D=LL ~TEN DLL )VI DLL ~RAT CNL ~NRA CNL ~ P H i C A L ~P H I CNL ~CNL CNL :CNL CNL ~R CNL FENS CNL tTEN CNL 4.R ES CNL 4T E M C NL :ALI CNL ;R LOT ~ALI 'LDT ~H05 LDT 2R HO LDT LOG TYPE CLASS MOD NO. PROCESS COCTAL) FT O0 000 O0 OHMM O0 220 Og OHMM O0 220 10 GAPI O0 310 O1 MV O0 010 O1 MV O0 000 O0 UA O0 000 O0 MV O0 000 O0 ~A. O0 000 O0 OMMM O0 823 50 DE'GF: OO 660 50 LB O0 635 LB O0 000 O0 MV O0 000 O0 O0 420 O0 000 P~ O0 8gO PU O0 890 CPS O0 330 CPS O0 330 GAPI O0 310 L8 O0 635 LB O0 000 OHMM O0 823 DEGF O0 660 IN O0 28,0 GAPI O0 IN O0 280 G/C3 O0 350 G/C3 O0 356 O1 O0 O0 O0 3O O1 21 O0 0 0 0 0 0 0 0 O: 0 0 0 0 0 0 0 0 0 0 0 O: 0 0 0 50 0 50 0 Ol 0 O! 0 01 0 02 0 O1 O. 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000.000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 000000~00000000 6800000000000000 68 00000000000000 $8 00000000000000 68 00000000000000 VP OlO.H02 VERIFICATION LISTING PAGE 7 ~PHI LOT ~EF LOT ,L LOT ,U LOT ,S LOT ,ITH LOT ;S1 LOT ;S2 LOT )SS LOT tLS LOT 'ENS LOT IRES LOT ITEM LOT tTEN LOT .SHV LOT iSHV ~LDT ;GR NGT ~GR NGT ~OTA NGT tHOR NGT JRAN NGT ~[NG NGT ¢2NG NGT ~3NG NGT ¢4NG NGT ¢SNG NGT 4R E S NGT 4TEM NGT FENS 'NGT ITEN NGT ~R EPT SALI EPT 4RES EPT ~'TEM EPT rENS EPT iT EN EPT PU O0 890 O0 358 CPS O0 354 CPS O0 354 CPS O0 354 CPS O0 354 CPS O0 000 CPS '00 000 O0 000 O0 000 LB O0 635 OHMM O0 823 DEGF O0 660 LB O0 000 V O0 000 ¥ O0 000 GAPI O0 310 GAPI O0 310 PU O0 719 PPM O0 790 PPM O0 79Z CPS O0 310 CPS O0 310 CPS O0 310 CPS O0 310 CPS O0 310 OHMM 00. B23 DEGF O0 660 LB O0 635 LB O0 000 GAPI O0 310 IN O0 280 OHMM O0 823 DEGF O0 660 LB O0 635 LB O0 000 O0 O1 O1 O1 O1 O1 O0 O0 O0 O0 50 50 O0 O0 O0 O1 O1 50 50 50 O1 O1 O1 Oi 01 50 50 21 O0 01 01. 50 50 O0 DATA DE PT SP DIO flTEN NPHI GR MT EM RHOB LL SS1 TENS LSHV PDT A WZNG 9569.500~0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999'2500 -999.250~0 -999.2500 -999-2500 -999.2500 -999.2500 -999.2500 LLS -999.2500 S¥0 -999.2500 MRES -999.2500 OVl -999.2500 NP'HI -999-2500 TENS -999.2500 CALI -999'2500 DRHO -999.2500 LU -999.250'0 5S2 -999.2500 MRES -999-250:0 SSHV -999.2500 THOR -9:99.2500 W3NG -999.2500 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0: 0 0 0 0 0 0 0 0 0 0 0 LLD SIO MTEM N R A T NCNL H. TEN GR DPHI LS QSS MTEM SGR URAN 'W4NG 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 -999.25:00 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999o2S00 -999.2S00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 t 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 6B 68 68 68 68 68 68 68 68 68 68 68 68 68 SGR O¥O TE:NS RNRA FCNL MRE S CALl PEF LITH QLS HTEN CGR WiNG WSNG 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000,0:00000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000'000000 00000000000000 000~00000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 -999-2500 -999.Z500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9:99.2500 -999.2500 VP.OIO.H02 VERIFICATION LISTING PAGE 8 RES -999.2500 MTEM -999.2500 R -999.2500 CALI -999.2500 ENS -999.2500 HTEN -999.2500 EPT 9500.0000 LLS P -48.5313 SVO IO 41.0000 MRES TEN 752.0000 OVl PHi 4.7743 NPHI R 31.7188 TENS TEM 311.6750 CALI HOB 2.6172 DRHO L 109.7500 LO S1 Z06.0000 SS2 ENS 4388°0000 MRES SHV 1190.0000 SSHV 'OTA 0.2930 THOR !2NG 33.3125 W3NG iRES 0.9033 MTEM .R 31.7188 CALI ~ENS 4388.0000 HTEN 810.9910 34.8125 0.9033 47.4063 1.6602 4388.0000 10.3516 -0.0132 217.6250 278.0000 0.8745 1159.0000 0.6431 7.0703 148.1000 10.3516 1054.0000 ~EPT 9400.0000 ,P -20.1250 ,IO 578.0000 tTEN 762.5000 )PHI 17.3875 ;R 78.0000 ~TEM 310.7750 ~HOB 2.5586 .L 179.3750 ;S1 300.7500 "ENS 437:2.0000 .SHV 1191.0000 'OTA 2.7344 12NG t45.3750 [RES 0.8999 ;R 78'0000 'ENS 4372.0000 LLS SVO MRES DV1 NPHI TENS CALI DRHO LU SS2 MRES SSHV THOR W3NG MTEM CALI HTEN 5.5458 2.6738 0.8999 3.7188. 21.4844 4372.0000 11.8984 0.2090 337.250.0 368.5000 0.8721 1159.0000 8.6875 52.5000 148.3250 I1.8984 1060.0000 )EPT 93,00.0000 ;P -21.7500 )IO 392.5000 tTEN 801-0000 iPHI 16.0414 ;R 39.4063 ITEM 309.6500 :HOB 2.6504 .L 128.0000 ;$1 254.8750 'ENS 4348.0000 .SHV 1191.0000 ~OTA 1.0742 12NG 64.3750 LLS SVO MRES DV1 NP'HI TENS CALI DRHO SS2 M. RES SSHV THOR W3NG 16,7418 5.2500 0.9087 6.9141 10.2051 4348.0000 10.8281 0.1069 247-7500 322.750'0 0.8745 1158.0000 3-1855 21.7656 TENS' MRES LLD SiO MTEM NRAT NCNL HTEN GR DPHI LS QSS MTEM SGR URAN' W4NG TENS MRES LLD StO MTEM NRAT NCNL HTEN GR DPHI L S QS S MTEM SGR UR AN W4NG MRES LLD SIO. MTEM NRAT NCNL HTEN GR OPHI LS QSS MT EM SGR :UR A N W4NG -999.2500 -999.2500 1038.4927 62.2500 148.1000 1.2373 6192o0000 1054.0000 31.7188 5.3711 218.6250 -0.0034 311.6750 21.7813 2.0469 1.0098 3910.0000 0.8745 5.7780 699.0000 148.3250 2.6621 2100.0000 1060.0000 78.0000 8.7402 348.2500 0.0903 310.7750 91.9375 2.3516 10.09.38 3880.0000 0-8721 15.8252 454.7500 147,8750 1.8770 3584.0000 1064.0:000 39-4063 '3.4180 252.0000 0.0459 309.6500 44.5938 2.4727 2.8398 HTEN MTEM SGR DVO TENS RNRA FCNL MRES CALI PEF LITH QLS HTEN CGR )W1NG WSNG HTEN M?EM SGR DVO TENS RNRA FCNL MRES CAL, I PEF LITH QLS H T E N CGR W1NG WSNG HTE N MTEM SGR DVO TENS RNRA FCNL MRES CALl PEF LITH QLS HTEN CG:R W1NG W 5NG -999.2500 -999.2500 21.7813 47.8437 3910.0000 1.2871 4880.0000 0.8745 10.3516 4.0703 44.4375 -0.0220 1054.0000 7.1133 75.7500 0.0000 752.0000 .311.6750 91.9375 3.7520 3880.0000 2.9531 649.0000 0.8721 11.8984 3.3066 84.0625 -0.0415 1060.0000 73.8750 298.7500 7.0'703 762.5000 310.7750 44.5938 6.9805 3864.0000 1.7520 1560.0000 0.8745 10,8281 3.7813 58.1250 -0.0254 1064.0000 28.6719 157.1250 3.7871 VP 010.H02 VERIFICA?ION LISTING PAGE RES 0.9087 MTEM R 39.4063 CALI ENS 4348.0000 HTEN EPT 9200.0000 LLS P -41.5313 SVO IO 156.1250 MRES TEN 759.0000 D¥1 PHI 7.1672 NPHI R 25.4844 TENS !TEM 306.5000 CALI HOB 2.5527 DRHO ,L 128,6250 LU S1 226.1250 SS2 ENS 4264.0000 MRES ,SHV 1191.0000 SSHY ~OTA 0.4883 THOR 12NG 29.3281 W3NG IRES 0.9175 MTEM ~R 25.4844 CALI 'ENS 4264.0000 HTEN ~EPT 9100.0000 LLS P -31.3125 SV'O ~IO 157.2500 MRES iTEN 765.0000' DV1 IPHI 4.6468 NPHI ~R 31.4688 TENS iTEM 304.2500 CALi HOB 2,5781 DRHO ,L 118,8750 'LU :$1 208.5000 SS'2 'ENS 4172.0000 .MRES ,SHV 1191-0000 SSHV 'OTA 0.6836 THOR !2NG 50.5000 W3NG IRES 0.9229 MTEM ,R 31.4688 CALI 'ENS 4172.0000 HTEN )EPT 9000.0000 LLS ip -59.4063 SVO )I0 128'7500 MRES ITEN 731.5000 iPHI 9.6208 NPHI iR 19.2031 TENS ITEM 302.6750 CALI ~HOB 2.5820 DRHO L 121.0000 LU S1 220.7500 SS2 'ENS 4.080.0000 MRES SHV 1191.0000 SSHV' OTA 0.7324 THOR ~2NG 43.5313 W3NG 147.8750 10,8281 1064.0000 117.3140 17.0000 0.9175 22.0781 4.7852 4264.0000 11.5703 0,0107 24.1.1250 303,5000 0.8813 1158.0000 0.9634 19.8594 146.6375 11.5703 1066.0000 110,1174 1 B. 3750 0,9229 22,6563 1,7090 41 72' 0000 10. 9844 -0.0132 223.7500 286.7500 0.8955 I159.0000 i. 8379 20,1875 145, 8500 10. 9844 I036. 0000 148.8583 20.4688 0 · 9292 25.6719 5.9570 4080.0000 10'5547 0. 0059 231.2500 288.2500 O. 89 94 I 159. 0000 2.5117 i 1.3594 TENS MR ES LLD SIO MTEM NRAT NCNL HTEN GR DPHI LS QSS MTEM SGR UR~N W4NG TENS MRES LLD SIO MTEM NRAT NCNL H T E N GR DPHI LS QSS MTEM SGR URAN W4N'G TENS MRES LLD SI 0 MTEM NRAT NCNL HTEN GR DPHI LS QSS MTEM SGR UR AN 3864.0000 0.8745 127.1693 210.1250 146.6375 1.5313 4972.0000 1066.0000 25.4844 9.0820 249.2500 0.0127 306.5000 28.5156 2.4766 0.9458 3770.0000 0.8813 129,9818 242,0000 145,8500 1,2793 5836.0000 1036.0000 31.4688 7.5684 230.7500 -0'0112 304.2500 34.1562 2.4082 3.0293 3744.0000 0.8955 178.4899 199.3750 144.6687 1,5'771 5260.0000 1019.5000 19.2031 7-3730 236.6250 0.0288 302.67 50 27.0156 O. 9087 3.7871 HTEN MTEM SGR OVO TENS RNRA :FCNL MRES CALI PEF LITH QLS HTEN CGR WING WSNG HTEN MTEM SGR DVO TENS RNRA FCNL MRES CALI PEF. LITH QLS HTEN CGR WING WSNG HTEN MTEM SGR DVO TENS RNRA FCNL MRES CALI PEF LITH QLS HTEN CGR WiNG WSNG 801.0000 309.6500 28.5156 22.3125 3770.0000 1,7500 2920.0000 0.8813 11.5703 4.9844 47.2500 0.0029 1066.0000 11.5625 106.8750 1.8916 759.0000 306.5000 34.1562 22.9687 3744.0000 1.2920 3962.0000 0.8955 10.9844 4.9922 43.7188 1036,0000 17.2656 103.00:00 3.0293 765.0000 304.2500 27.0156 25.8281 3650.0000 1.6465 27:18.0:000 0.8994 10.5547 5.1016 45.4063 -0.0044 t019.5000 20.5625 .77.6250 2.8398 .V? 01,0.H02 VERIFICATION LISTING PAGE 10 IRES 0.9292 MTEM 144 ;R 19.2031 CALI 10 'ENS 4080.0000 HTEN 1019 .6687 5547 .5000 )EPT 8900.0000 LLS 7 ;P -29,3594 SVO 3 )IO 563.5000 MRES 0 (TEN 800.0000 DVl 6 IPHI 37.3781 NPHI 31 ;R 108.8750 TENS 4144 ITEM 301.3250 CALI 11 tHOB 2.5371 ORHO O .L 141.0000 LU 260 ;SI 238.0000 SS2 308 tENS 4144.0000 MRES 0 .SHV 1191.0000 SSHV 1158 ~OTA 1.9531 THOR 9 ~2NG 182.75-00 W3NG 50 ~RES 0.9370 MTEM 144 ;R 108.8750 CALI 11 tENS 4144.0000 HTEN 1084 .2978 .7363 .9370 .0313 .3965 .0000 .8437 .0371 .7500 .5000 .9077 .0000 .5391 .5000 .5000 .8437 .0000 )EPT 8800.0000 LLS 5 ;P -23.5000 SVO 2 )IO 539.0000 MRES 0 ~TEN 770.0000 DV1 3 4PHI 43.17'29 NPHt 36 ;R 222-6250 TENS 4020 iTEM 299-3000 CALI 10 ~HOB 2.5527 DRHO 0 .L 126.6875 LU 239 ;SI 219.7500 5S2 291 tENS 4020.0000 MRES 0 .SHV tlgl.O000 SSHV 1159 ~OTA 1.6602 THOR 6 ~2NG 328.25:00 W3NG 100 iRES 0.9463 MTEM 143 ;R 222-6250 CALI 10 tENS 4020.0000 HT'EN I027 .5965 .5020 .9463 .6992 .0352 .0000 .9687 .0'015 . ,6250 .0000 .9150 .0000 .9492 .5625 .6000 .9687 · 0000 )EPT 8700.0000 LLS ;P -999.2500 SVO )IO -999.2500 MRES iTEN -999'2500 DV1 4PHI 45.9466 NPHI ;R 275.?500 TENS iTEM 295.9250 CALi ~HOB 2.3281 DRHO .L 195.6250 LU ;Si 239.8750 SS2 tENS 4070.0000 MRE$ .SHY 1190.0000 SSHV ~OTA -999.2500 THOR ~2NG -999.2500 W3NG -999.2500 -999-25~00 -999.2500 -999.2500 39-6484 4070.0000 10.7734 0'00,73 341.0000 325.2500 0.9302 1159.0000 -999.2500 -999,2500 TENS MRES LLD SIO MTEM NRAT NCNL HTEN GR OPHI LS QSS MTEM SGR URAN W4NG TENS MRES LLD SIO MT'EM NRAT NCNL HTEN GR DPHI LS QSS MTEM SGR W4NG 'TENS MRES LLD SIO MT EM NRAT NCNL HTEN GR DPHI LS QS S MTEM SGR URAN W4NG 3650.0000 0.8994 9.5760 742.0000 144.5000 3.3203 2192.0000 1084.0000 108.8750 10.0098 271.2500 0.0430 301.3250 103.8125 4.7852 16.1562 3774.0000 0.9077 6.11:63 648.0000 143.6000 3.6016 1977.0000 1027.0000 222-6250 9.0820 OZ20 299.3000 223.1250 24.0781 27.5000 3670'0000 0.9150 -999.2~00 -999.2500 -999.2500 3.8320 2000'0000 1034.0000 275.7500 22.2168 366.0000 0.0386 295.9250 -99:9.Z500 -999.2500 -999.2500 HTEN MTEM SGR DVO TENS RNRA FCNL MRES CALI PEF LITH QLS HTEN CGR WING WSNG HTEN MTEM SGR DVO TENS RNRA FCNL MRES CALI PEF LITH QLS HTEN CGR WING WSNG HTEN MTEM SGR OVO TENS RNRA FCNL MRES CALI PEF LITH QL S HTEN CGR W1NG WSNG 731.5000 302.6750 103.8125 6.0625 3774.0000 3.6094 776.0000 0.9077 11.8437 3.2852 68.1250 0.0010 1084.0000 65.1250 322.0000 7.0703 800.0000 301.3250 223.1250 3.7051 3670.0000 3.9512 552.5000 0.9150 10.9687 4.5859 49.5313 -0.0029 1'027.0000 51.3438 734.0000 9.4844 770.0000 299.3000 -999.2500 -999.2500 -999.2500 4.I680 510.7500 0-9302 i0.7734 3-4102 86.7500 0.0107 1034.0000 -999.2500 -999,2500 -999.25001 VP ,010.~02 VERIFICATION LISTING PAGE 11 RES -999.2500 MTEM -999 ,R 275.7500' CALI 10 ENS 4070.0000 HTEN 1034 .2500 .7734 .0000 IEPT 8600.0000 LLS P -999.2500 SVO 110 -999.2500 MRES ITEN -999.2500 DV! iPHI 35.6991 NPHI iR 144.2500 TENS ITEM 292.7750 CALI IHOB 2.4980 DRHO .L 138,6250 LU ;S1 220.7500 SS2 'ENS 4060.0000 MRES .SHV 1191,0000 SSHV 'OTA -999.2500 THOR t2NG -999.2500 W3NG ~RES -999.2500 MTEM ;R 144.2500 CALI tENS 4060,0000 HTEN -999.2500 -999.2500 -999.2500 -999.2500 29.3945 4060.0000 10.8047 -0.0029 260.5000 300.0000 0.9380 1158.0000 -999.2500 -999.2500 -999.2S00 10.8047 1072.0000 )EPT 8500.0000 ;P -999.2500 )IO -999.2500 4TEN -999.2500 4PHI 31.4993 ;R 131.7500 ~TEM 290'5250 ~HOB 2.4082 .L 161.5000 ~S1 225.3750 rENS 3990.0000 .SHV 1190.0000 ~OTA -999.2500 ~2NG -999.2500 4RES -999.2500 DR 131.7500 rENS 3990.0000 LLS SV0 MRES DY1 NPHI TENS CALI ORHO LU SS2 MRES SSH¥ THOR W3NG MTEM CALI HTEN -999.2500 -999.2500 -999'2500: -999.2500 31-0547 3990.0000 10.4766 -0.0049 301.2500 312'0000 0.9429 1159.0000 -999.2500 -999'2500 -999.2500 10-4766 1036'000:0 :)EPT 8496. 5000 SP -999.2500 ]IO -999. 2500 -tTEN -999.2500 qPHI -999,2500 DR 134. 5000 MT.EM 290.. 3000 RHOB 2,.4453 LL 159. 5000 SS1 232. 2500 TENS 413 2,0000 LSHV 1190.0000 POTA -999. 2500 W2NG -999'2500 LLS SrO MRES DV1 NPHI TENS :CALI 'DRHO LU SS2 MRES SSHV THOR W3NG -999.2500 -999.2500 -999*2500 -999.2500 33.3984 4132.0000 10. 4375 0.OOB3 280.0000 309.5000 0.9468 1158.0000 -999.2500 -999.2500 TENS MRES LLD SIO MTEM NRAT NCNL HTEN GR DPHI LS MTEM SGR URAN W4NG TENS MRES LLD SIO MTEM NRAT NCNL HTEN GR DPHI LS QS S MTEM SGR ' URAN W~+NG TENS MRES LLO SIO MTEM NRAT NC NL HT EN GR DP Hi LS QSS MTEM SGR, UR AN W4NG -999.2500 0.9302 -999.2500 -999.2500 -999.2500 3.1641 2210.0000 1072.0000 144.2500 12.2559 268.7500 0.0103 292.7750 -999.2500 -999~2500 -999.2500 -999.2500 0.9380 -999.2500 -999.2500 -999.2500 3.2500 2264.0000 1036.0000 131.7500 17.5781 312.0000 0.0098 290.5250 -999.2500 -999'2500 -999.2500 -999'2500 0.94z9 -9:99. 2500 -999.2500 -999. 2500 3.4023 2236.0000 I126.0000 1.34.50,00 15-4297 299,5000 0.0342 29.0-30'00 -999.2500 -999.2500 -999.2500 HTEN MTEM SGR OVO TENS RNRA FCNL MRES CALI PEF LITH QLS HTEN CGR WiNG WSNG HTEN MTEM SGR OVO TENS RNRA FCNL MRES ~CALI PEF LITH QLS HTEN CGR WING WSNG HTEN MTEM SGR DV0 TENS R:NRA FCNL MRES CALI PEF' LITH QLS HTEN CGR WING WSNGi -999.2500 295.9250 -999.2500 -999.2500 -999.2500 3.3438 701.0000 0.9380 10.8047 3.7285 59.6250 -0.0107 1072.0000 -999.2500 -999.2500 -999.2500 -999.2500 292.7750 -999.2500 -999.2500 -999.2500 3.2598 634.0000 0.9429 10.4766 3.6250 72.5000 -0.0244 1036.0000 -999-2500 '-999.2500 -999.2500 -999..2500 290.5250 -999.2500 -999.2500 -99'9.2500 3.4609 626.0,000 0.9468 10.4375 3.8945 66.5000 0,0298 I126-0000 -999.2500 -999.2500 -999.2500 ,VP OlD.H02 VERIFICATIDN LISTING PAGE I2 IRES ;R 'ENS -999.2500 MTEM 134.5000 CALI 4132.0000 HTEN -999.2500 TENS 10.4375 MRES 1126.0000 -999.2500 HTEN 0.9468 MTEM -999.2500 290.3000 :* FILE TRAILER *~ :ILE NAME :EDIT .001 ;ERVICE NAME : IERSION ~ : )ATE : IAXIMUM LENGTH : 1024 :ILE TYPE : tEXT FILE NAME : EOF ******~*** :* FILE HEADER ** :ILE NAME :EDIT .002 ;ERVICE NAME : ~ERSION ~ : )ATE : 4AXIMUM LENGTH : 1024 :ILE TYPE ~REVIOUS FILE :. DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY: 2 i 66 0 4 1 66 1 8 4 73 20 9 4 65 .lin 16 1 66 0 1 66 0 )ATUM SPECI'FICATION BLOCKS 4NEM SERVICE SERVICE UNIT' API API APl AP1 FILE SIZE SPL REPR ID )EPT rPL EPT ': A T'T E P T ~VU E PT qV D E PT =¥U EPT :VD EPT ~PHI EPT PRDCESS ORDER LOG TYPE CLASS MOD NO. FT O0 000 O0 O: NS/M~ O0 132 :01 0 OB/M O0 130: O! 0 V O0 000 00. 0 V 00 0 O0 O0 0 V O0 000 O0 ~0 V: O0 000 O0 0 PU O0 890 O0 0 0 4 0 4 0 4 0 4 0 4 0 '4 0 4 0 4 CODE COCTAL) 1 68 ,00000000000000 1 68 00000000000000 1 68 00000000000000 i 68 o:ooooooo~oooooo t 68 00000000000000 1 68 00000000000000 .1 68 00000000000000 1 68 000000000000:00 )~ DATA ~ )EPT 9561.1660 T'PL ~VD 1.6338 FVU 9.7031 EATT 0.8232 FVD 109'6250 NVU 0.8994 EPHI. 1.1543 3.0762 ,VP Ol,OoHO2 VERIFICATION LISTING PAGE 13 IEPT 9500.1660 TPL fVD 1.3662 FVU IEPT 9400.1660 TPL IVD 3°0742 FVU )EPT 9300.1660 TPL IVD 1.3926 FYU )EPT 9200.1660 TPL IVD 1.4297 FVU )EPT 9100.1660 TPL JVD 1.6094 FVU )EPT 9000.1660 TPL ~VD 1.3672 FVU )EPT 8900.1660 TPL 4VD 3.0742 FVU )EPT 8800.1660 TPL ~VD 2.7871 FVU )EPT 8700.1660' TPL ~VD 2.3145 FVU )EPT 8600.1660 TPL ~VO Z.7461 F'VU )EPT 8500.1660 TPL ~VD 2.1914 iFV'U )'EPT 84.96.3320 TPL ~VD 2.1797 FVU 9.5156 0.8999 18.5313 0.5566 10.7031 0.8784 11. 1406 0.8594 9.8906 1.0986 10.7656 0.8569 13.6406 0.6104 14.0156 0.5254 11. 3906 0.4668 13.7656 0.5698 I1. 7031 0.5322 12.0156 O. 4604 EATT FVD EATT FV D EATT FVD EATT FVD EATT FVD EATT FYD EATT FVD EATT FVO EATT FVD EATT FVD EATT FYD EATT FVD ~* FILE TRAILER *~ :ILE NAME :EDIT .002 ~ERVICE NAME : IERSION # : ]ATE : ~AXIMUM LENGTH : I024' :ILE TYPE : qEXT FILE NAME : ,~ FILE HEADER =ILE NAME :EDIT SERVICE NAME : ~ERSION # DATE : · 00 3 89.1250 0.8350 472.5000 0.6489 157.2500 0.4609 114.1250 0.7715 109.6250 1.0381 123.1250 0.6865 460.5000 0.6958 422.5000 0.5991 330.5000 0.5098 412.500:0 0.6069 314.5000 0.5254 312.500'0 0.5210 NVU EPHI NVU EPHI NVU EPHI NVU EPHI NVU EPHI NVU EPHI NVU EPHt NVU EPHI NVU EPHI N~U EPMI NVU EPHI NVU EPHI 1.2354 2.1973 2.7207 45.5078 1.4775 8.2031 1.3105 11.2305 1.5967 4.1504 1.3740 8.9844 2.7285 15.1855 2.4629 19.4336 1.8799 7.2266 2.4492 18.3105 1.9453 9.7168 1.8477 11.6699 VP 010.H02 VERIFICATION LISTING PAGE iAXIMUM LENGTH : 1024 :ILE TYPE : REVIOUS FILE : DATA FORMAT RECORD !NTRY BLOCKS TYPE 8 16 0 )ATUM SPECIFICATION ~NEM SERVICE SERVICE ID ORDER # )EPT .LS DLR .LO DLR ;GR DLR ~P DLR ~VO DLR 5IO DLR )VO DLR )IO DLR iRES DLR 4TEM DLR FENS DLR tTEN DLR )Vi DLR ~R A'T C NR ~NRA CNR ~PHI CAR ~PHI CNR ~CNL CNR =CNL CNR DR CNR r'ENS CNR ,1RES CNR ,,ITEM CNR · iT EN CNR ;A. LI CNR DR LDR SALI LDR RHOB LDR DRHO LDR D~HI LDR PEF LDR LL LDR LU LDR LS LDR LITH LDR SS 2 LDR SIZE 1 1 4 1 1 BLOCKS UNIT API API LOG TYPE FT O0 000 OHMM O0 220 OHMM O0 220 GAPI O0 310 MV O0 020 MV O0 000 UA O0 OOO MY O0 000 UA O0 000 OHMM O0 823 DEGF O0 660 LB O0 635 LB O0 000 MV~ O0 000 O0 ~20 O0 000 PU O0 B90 PU O0 B90 CPS O0 330 CPS O0 330 GAPI O0 320 LB O0 635 OHMM O0 8,23 DEGF; O0 660 LB: O0 000 IN O0 280 GAPI O0 310 IN O0 280 G/C3 O0 350 G/C3 O0 356 PU O0 89,0 O0 358 CPS O0 354 ,CPS O0 354 CPS O0 354 CPS O0 354 CPS O0 000 REPR CODE 66 66 73 65 66 66 API A CLASS M O0 09 I0 O! O1 O0 O0 O0 O0 50 5O 21 O0 O0 O1 O0 O0 O0 3I 30 O! 21 50 50 O0 O! 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API FI~LE SIZE SPL REPR ID ORDER # )EPT TPL EPR EATT EPR YVU EPR 4VD EPR ~VU EPR FVD EPR EPHI EPR LOG TYPE CLASS MOD NO. PROCESS CODE (OCTAL) FT O0 000. O0 0 0 4 NS'/M O0 132 01' 0 0 4 DB/M O0 130 Ol O: 0 4 V O0 000 0.0 0 O~ 4 V O0 000~ O0 0 0 4 V O0 000 O0 0 0 4 V 0:~0 000 O0 0 0 4 PU O0 890 O0 0 0 4 68 00000000000000 68 00000000000000 68 00000000000000 6800000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 DATA DEPT NVD DEPT NVD DEPT NVD OEPT 9568.1660 TPL 1.7793 FVU 9500.1660: TPL 1.2881 FVU 9400.1660 TPL. 3.0352 FVU 9300'1660 TPL' 9.5781 EATT 0.9634 FVD 9-8281 EATT 0-8101 FVD 19.2813 EATT 0.5547 FVD 10-4531 EAT'T. 118.125'0 NVU 1-0371 EPHI 9'0.1250 NV'U 0.7896 EPHI 456.5000 NVU 0.6572 EPHI 124.1250 NVD 1. 3643 2.2949 1.1836 3.95:51 2.6133 50.6836 0.8369 ,VP OlO.H02 VERIFICATION LISTING PAGE 21 IVO 1.4365 FVO iEPT 9200.1660 TPL IVD 1.6357 FVU )EPT 9100.1660 TPL IVD 1.7422 FVU )EPT 9000.1660 TPL iVD 1.5605 FVO )EPT 8900.1660 TPL iVD 3.0938 FVU )EPT 8800.1660 TPL IVD 2.4707 FVU )EPT 8791-3320 TPL iVD 2.3418 FVU 0.3481 FVD 10.9531 EATT 0.9541 FVD 9.9531 EATT 1.0859 FVD 9.8281 EATT 1.2451 FVD 16.7813 EATT 0.5181 FVD 13.3828 EATT' 0.6221 FVD 12.7656 EATT 0.5908 F¥'D ~ FILE TRAILER ~ :ILL NAME :EDIT .004 ;ERVICE NAME : /ERSION # )ATE : ~AXIMUM LENGTH : 1024 :ILL TYPE : ~EXT FILE NAME : ~ TAPE TRAILER *~ ;ERVtCE NAME :EDIT' )ATE :8'7/03/19 )RIGIN :7222 rAPE NAME : ;ONTINUATION # :01 ~EXT TAPE NAME : 'OMMEN~TS :LIBRARY TAPE ~;',~ REEL TRAILER ~ SERVICE NAME :EDIT )ATE :87/03/19 ]RIGIN : ;:EEL NAME : BLAN ;ONTINUATiON # :01' ~EXT REEL NAME : ~OMMENTS :LIBRARY TAPE 0.7212 123.1250 0.9263 108.1250 1.0947 115.6250 1.0254 438.5000 0.5879 378.5000 0.5879 386.5000 0.5547 EPHI NVU EPHI NVU EPHI NVU EPHI NVU EPHI EPHI NVU EPMI 7.2Z66 1.~404 10.0586 1.4873 4.5410 1.3301 3.7598 2.2578 35.8887 2.4160 17.5293 2.5625 13.2813 .VP OlO.H02 VERIFICATION LISTING PAGE 22 ~u~;--- S C HL U M B E R G E R-'"-~ ,--..-.----------------, ****************************** VERIFICATION ' LISTIN:G ~VP 010oH02 VERIFICATION LISTING ~-'~* REEL HEADER SERVICE NAME :GCT DATE :87/04/ 8 ORIGIN : REEL NAME :302521 CONTINUATION ~ :01 PREVIOUS REEL : COMMENTS' :SCHLUMBERGER GCT LIS TAPE ~ TAPE HEADER SERVICE NAME :GCT DATE :87/04/ 8 ORIGIN :7226 TAPE NAME CONTINUATION # PREVIOUS TAPE COMMENTS :SCHLUMBERGER GCT LIS TAPE · ~ FILE HEADER ** FILE NAME :GCT! *001 SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS.FILE : INFORMATION RECORDS MNEM CONTENTS · ~ CN : ARCO :ALASKA~ INC. WN : LISBURNE L5-16 FN : PRUDHOE BAY/LISBURNE POOL RANG: TOWN: SECT: COUN: NORTH SLOPE STAT: ALASKA CTRY: USA MNEM CONTENTS . . PRES: E ~, COMME'NTS ** PAGE UNI'T TYPE CATE SIZE CODE 000 000 018 O65 000 000 014 065 000 000 026 065 000 000 004 065 DO0 000 004 065 000 000 002 065 000 000 O1Z 065 000 000 0'06 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 001 065 .VP 010.H02 VERIFICATION LISTING PAGE 2 ~ SCHLUMBERGER ~ ALASKA COMPUTING CENTER :OMPANY = ARCO ALASKA INC. ~ELL = LISBURNE L5-16 =IELD = PRUDHOE BAY/LISBURNE POOL :OUNTY = NORTH SLOPE 80ROUGH STATE = ALASKA JOB NUMBER AT ACC: 72266 ~UN #19 DATE LOGGED: 19-MAR-87 LOP: R. SINES ~ZIMUTH OF PLANNED VERTICAL PLANE: 113.42 RFACE ~LOCATION: 1788',FSL & I9° FWL ********************************************************************************** ,VP 010.H02 VERIFICATION LISTING PAGE 3 GYRO CONTZNUOUS TOOL CGCT) OEFINIIXONS: HLAZ~ AZIMUTH GDEP= GYRO DEPTH VDEP= TRUE VERT[CAL DEPTH NSOR= NORTH OR SOUTH DEPARTURE E~DR= EAST OR WEST DGL = DOG LEG (CURVATURE .VP 010.H02 VERIFICATION LISTING PAGE ~= DATA FORMAT RECORD ENTRY ))LOCKS TYPE SIZE 2 8 16 1 0 I REPR CODE 66 66 73 65 66 66 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API API API FILE ID ORDER # LOG TYPE CLASS MOO NO. DEPT FT O0 000 O0 0 0 GDEP GCT FT 99 000 O0 O. 0 VDEP GCT FT O0 000 O0 0 0 HLAZ GCT DEG O0 000 O0 0 0 OEVI GCT DEG 99 620 11 0 0 NSDR GCT FT O0 000 O0 0 0 EWDR GCT FT O0 000 O0 0 0 DGL GCT FT O0 000 O0 0 0 ENTRY 0 1 60 .lIN 1 0 SIZE SPL 4 REPR PROCESS CODE (OCTAL) 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O00000OO000000 68 00000000000000 68 00000000000000 DEPT 8191.5000 GDEP OEVI 0.8405 NSDR 60.0000 .VDEP 0.0000 E~gDR DEPT 8100.0000 GDEP DEVI 5°5067 NSDR 3454.0483 'VDEP i0.0253 EWDR OEPT 8000.0000 GDEP OEVI 25.9590 NSDR 7752.0967 YDEP -332.6866 'EWDR DEPT 7973.5000. GOEP DEVI 23.5039 NSOR 9399.996! VDEP -664.0488 E~OR ~ FILE TRAILER FILE NAME :GCT .001 SERVICE.NAME : VERSION # : DATE : MAXIMUM LENGTH: 1024 FILE TYPE NEXT FILE'NAME : 60.0000 HLAZ 0.0000 DGL 3452,4375 HLAZ 54a7110OGL 7643'1562 ~HLAZ 570.5889 DGL: 9151,6523 HLAZ · 1139,4131 DGL 204o1057 0.0000 128.5838 2.6666 109.5472 0'6804 129.9825 0.0000 '~ TAPE TRAILER *~) SERVICE. NAME :GCT .VP OlO.H02 VERIFICATION LISTING PAGE 5 )ATE :87/04/ 8 )RIGIN :7226 rAPE NAME CONTINUATION $ :01 4EXT TAPE NAME COMMENTS' :SCHLUMBERGER GCT LIS TAPE ~* REEL TRAILER ** SERVICE NAME :GCT DATE :87/04/ 8 ORIGIN : REEL NAME :302521 CONTINUATION # :01 NEXT REEL NAME: COMMENTS :SCHLUMBERGER GCT LIS TAPE
