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Home My WebLink About170-042170042 bp Date: 8/23/2019 3 1 1 5 5 Transmittal Number: 93703 C j BPXA WELL DATA TRANSMITTAL Enclosed are two (2) discs containing the information listed below. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendallgbo.com. SW Name API 02-02 500292007400 Date 7/27/2019 Com an BPXA Descri tion COMPOSITED GYROSCOPIC SURVEY Disk Number 1 02-02A 500292007401 7/27/2019 BPXA OMPOSITED GYROSCOPIC SURVEY 1 03-28 500292111400 7/24/2019 BPXA OMPOSITED GYROSCOPIC SURVEY 1 04-01 500292007800 8/3/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 04-01A 500292007801 8/3/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 09-44 500292208700 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 09-44A 500292208701 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 09-44APB1 500292208770 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 V-227 500292341700 7/20/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 riease Sign ana hinarl a copy of this transmittal to. GANCPDCna bp365 onmicrosoft com Thank you, .'ler -7Cendaff Subsurface Information Management AOGCC Department of Natural Resources ConocoPhillips Alaska, Inc. ExxonMobil, Alaska Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 • C10-0449.. v o 4--1' I Loepp, Victoria T (DOA) From: Quick, Michael J (DOA) Sent: Sunday,April 23, 2017 9:35 AM To: Foerster, Catherine P (DOA); Loepp,Victoria T(DOA); Schwartz, Guy L(DOA);Wallace, Chris D (DOA); DOA AOGCC Prudhoe Bay Subject: Fwd: NOT OPERABLE: Producer 01-03 (PTD#1952040) McEvoy Generation 1 Wellhead Follow Up Flag: Follow up Flag Status: Flagged r s FYI. BP identified and shut in 5 wells with the same wellhead that is on 02-03 from the well control event last week. Begin forwarded message: From: "AK,GWO SUPT Well Integrity"<AKDCWelllntegrityCoordinator@bp.com> Date:April 23,2017 at 7:08:55 AM AKDT To:"AK,OPS FS1 OSM"<AKOPSFSIOSM@bp.com>,"AK,OPS FS1 Facility OTL" <AKOPSFS1Facility0TL@bp.com>,"AK,OPS FS1 Field OTL"<AK OPSFS1FieldOTL@bp.com>, "AK, OPS FS1 DS Ops Lead"<AKOPSFS1DSOpsLead@bp.com>, "AK,OPS FS1 DS1 Operator" <AKOPSFS1DS1Operator(Wbp.com>,AKOpsProdEOCTL<AKOPSPCCEOCTL@bp.com>, "Cismoski, Doug A" <CismosDA@BP.com>, "Daniel, Ryan"<Ryan.Daniel@bp.com>, "AK, RES GPB West Wells Opt Engr" <AKRESGPBWestWellsOpt@BP.com>, "AK, RES GPB East Wells Opt Engr" <AKRESGPBEastWellsOptEngr Dbp.com>,"AK,OPS EOC Specialists"<AKOPSEOCSpecialists@bp.com>, "AK, OPS PCC Ops Lead"<AKOPSPCCOpsLead@bp.com>,"AK,OPS Prod Controllers" <sewellcr21@bp.com>, "G GPB FS1 Drillsites"<ggpbfsldrillsites@BP.com>,"Oestgaard, Finn" <Finn.Oestgaard@bp.com>, "'Regg,James B(DOA)(jim.regg@alaska.gov)' (jim.regg@alaska.gov)" <jim.regg@alaska.gov>,"michael.quick@alaska.gov"<mi shael.quick@alaska.gov> Cc:"AK,GWO DHD Well Integrity"<AKD&CDHDWelllntegriVbp.com>, "AK,GWO Projects Well Integrity"<AKDCProjectsWelllntegrityEngineer@bp.com>, "AK,GWO Completions Well Integrity" <AKDCWLCompletionsSupt@bp.com>, "AK, GWO Well Integrity Engineer" <AKGWOWellSiteEnginee(a@bp.com>, "AK, GWO SUPT Well Integrity" <AKDCWelllntegrityCoordinator@bp.com>, "AK,OPS FF Well Ops Comp Rep" <AKOPSFFWellOpsCompRep@bp.com>, "'chris.wallace@alaska.gov' (chris.wallace@alaska.gov)" <chris.wallace@alaska.gov>, "AK,GWO SUPT Special Projects" <akdcWellservicesoperationssuperintendent@bp.com>, "Kilfoyle,Jeffery A"<Jeffery.Kilfoyle@bp.com>, AKIMS App User<akimsuser.service@bp.com>,"Dempsey, David G"<David.Dempseyl@bp.com>, "Hibbert, Michael"<Michael.Hibbert@BP.com>,"Janowski,Carrie"<Carrie.Janowski@bp.com>, "Montgomery,Travis J"<Travis.Montgomery(a)bp.com>, "Munk,Corey"<Corey.Munk@bp.com>, "Obrigewitch, Beau" <BEAU.OBRIGEWITCH@bp.com>, "Pettus,Whitney"<Whitney.Pettus@bp.com>, "Sternicki,Oliver R"<Oliver.Sternicki@bp.com>,"Worthington,Aras Y'<Aras.Worthington@bp.com> Subject:NOT OPERABLE:Producer 01-03(PTD#1952040)McEvoy Generation 1 Wellhead All, Producer 01-03(PTD#1952040) has a McEvoy Generation 1 wellhead.While the cause of the unplanned release on well 02-03 is investigated,all other wells in GPB with this wellhead must be shut in.01-03 is reclassified as Not Operable. The complete list of affected wells is as follows: 1 • • • 01-03 • 01-06 • 04-01 • 04-05 • 04-06 Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 2 . ~~ .' STATE OF ALASKA . þ-~ø ALASKA OIL AND GAS CONSERVATION COMW§SION WELL COMPLETION OR RECOMPLETION REPORT AND LOGIska Oil & Gas Cons. Commission Anchorage Kf::Gt:IVt:U MAY 3 1 2007 1 a. Well Status: o Oil OGas o Plugged 181 Abandoned o Suspended 1 b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development o Exploratory OGINJ DWINJ o WDSPL o WAG o Other No. of Completions Zero o Service o Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or~anJ.J/ 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/29/2007 1P(;J)1 170-042 / 307-073 ~ 3. Address: 6. Date Spudded b' 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 11/27/1970 50-029-20078-00-00 /' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 12/27/1970 PBU 04-01 / 1327' FNL, 295' FEL, SEC. 34, T11 N, R15E, UM 8. KB (ft above MSL): 64' . 15. Field 1 Pool(s): Top of Productive Horizon: 3601' FNL, 1388' FWL, SEC. 35, T11N, R15E, UM Ground (ft MSL): Prudhoe Bay Field 1 Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 3821' FNL, 1464' FWL, SEC. 35, T11N, R15E, UM 9394 8689 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+ TVD) 16. Property Designation: Surface: x- 712575 y- 5950537 Zone- ASP4 9790 9039 . ADL 028324 . TPI: x- 714324 y- 5948313 Zone- ASP4 11. SSSV Depth (MD+ TVD) 17. land Use Permit: Total Depth: x- 714407 y- 5948094 Zone- ASP4 N/A N/A 18. Directional Survey 0 Yes 181 No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): (Submit electronic and nrinted informatinn ner 20 AAC 25.050\ N/A ft MSl 1900' (Approx.) 21. logs Obtained (List all logs here and submit electronic and printed information per 20 MC 25.071): Dll, FDC, SNP, BHC-Sonic, ll-3, SS Gyro Survey, CBL, Temp, GR 1 CBl 1 VDl, GR 1 CNl 1 CCl 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT Wr. PER FT. GRADE Top BOTTOM Top BOTTOM SIZE CEMENTING RECORD PUllED 30" 157# B Surface 115' Surface 115' 39" Cement to Surface 20" 133# 1 94# H&K Surface 1185' Surface 1185' 26" 750 sx Fondu Flvash 280 sx 'G' 13-3/8" 72# N-80 Surface 2686' Surface 2686' 17-1/2" 975 sx Fondu Flyash, 485 sx 'G', 330 sx Fondu 9-5/8" 47#, 43.5#, 40# S&N Surface 9749' Surface 9002' 12-1/4" 430 sx 'G', 80 sx 'G', 100 sx Fondu, 450 sx 'G' 23. Open to production or injection? 0 Yes 181 No 24. . TUBING RECORD . If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD) (MD+ TVD of Top & Bottom; Perforation Size and Number): 4-1/2", 12.6#, 13Cr80 9029' 8930' MD TVD MD TVD 25. . ACID, FRACTURE. CEMENT SQUEEZE,ETC. SCANNED JUL 1 1 2007 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9185' P&A w/19 Bbls Class 'G' (03/08/2007) 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 Oll-BBl: GAs-McF: WATER-BBl:. CHOKE SIZE: I GAS-Oil RATIO: TEST PERIOD .. Flow Tubing Casing Press: CALCULATED Oll-BBl: GAs-McF: WATER-BBl: Oil GRAVITY-API (CORR): Press. 24-HoUR RATE'" 27. CORE DATA Conventional Core(s) Acquired? DYes ONo Sidewall Core(s) Acauired? DYes DNo If Yes to either question, list formations and intervals cored (MD+ TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical re~~~sp!!r 2.~C 250.071. None RBDMS BFl JUL 11 2007 #~»,~ ~ ~\ \(S" ~~~~. .~ -. " -,'.-.-,. ~- Form 10-407 Revised 02/2007 0 RIG I N A CfNTINUr ON REVERSE SIDE G 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): NAME MD TVD Permafrost Top Permafrost Base 29. FORMATION TESTS Well Teste . 0 Yes 0 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top of Sadlerochit 9296' 8603' None Base of Sadlerochit 9754' 9007' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I ~erebY certify that the ~ing i~ true and correct to the best of my knowledge. Signed Terrie Hubble ¡ Title Technical Assistant DSj3//Ô Date / ( PBU 04-01 Well Number Prepared By Name/Number. Terrie Hubble, 564-4628 Drilling Engineer: Mel Rixse, 564-5620 170-042 307-073 Permit NO.1 A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IrEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 0212007 Submit Original Only Digital Wellfile . . Page 1 of 2 Well: 04-01 Well Events for SurfaceWell - 04-01 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS2 -> 04 -> 04-01 Date Range: 03/Feb/2007 to 01/Apr/2007 Data Source(s): DIMS, AWGRS Events Source Well AwGRS 04-01 AWGRS 04-01 AWGRS 04-01 AII:LGRS. 04-01 Date 03/18/2007 03/18/2007 03/17/2007 03/16/2007 AWGRS 04-01 03/15/2007 AWGRS 04-01 03/14/2007 AII:LGBS 04-01 03/13/2007 AWGRS 04-01 03/12/2007 AWGRS 04-01 03/12/2007 AYlGB.s. 04-01 AWGRS 04-01 AWGRS 04-01 AW.~JiS 04-01 AWGRS 04-01 03/11/2007 03/09/2007 03/08/2007 03/07/2007 03/07/2007 Description T/I/0=620/620/0 CMIT Tx IA to 3000 psi (PASSED) (pre-CTD) CMIT Tx IA pressured up to 3000/2980 with 5.8 bbls diesel. T/I lost 60/40 psi in 15 minutes and 0/20 psi in second 15 minutes. For a total of 60/60 psi in 30 minutes. Bled pressures down. FWHP's=O/O/O. ****JOB COMPLETE**** SET 6" CIW BPV THRU TREE PRE RIG WORK API VALVE SHOP T/I/0=420/420/0 Circ-out/ CMIT Tx IA to 3000 psi (UNABLE to test out of hrs)/ Freeze Protected Flow Line (pre-CTD) Pumped 5 bbls neat methanol down Flow Line to verify clear path. Pumped 10 bbls neat methanol spear, 1080 bbls 1 % kcl and 157 bbls 50*f diesel down TBG taking returns up IA to jumper line to Flow Line. Let U-tube for 1 hr. Freeze protected flow line with 5 bbls neat methanol and 90 bbls crude. FWHP's=500/500/300. ***Continued on 3/18/07 WSR*** T/I/0=20/30/0. PPPOT-T (PASS), McEvoy Gen I Retro Fitted to 13" 5m x 11" 5m McEvoy Gen 4 wellhead, 7" x 6 3/8" Upper Tree assembly. PPPOT-T: Opened test port bleeder screw on tubing hanger void, bled pressure to 0 psi. Visually inspected LDS no sign of bent or broken pins. Installed test pump, pressured void at 5,000 psi for 30 minutes, lost 100 psi in 30 minutes, bled void to 0 psi (PASS). Note: Test void has Alemite test fitting, packing port has 1/2" ball valve installed. *** AWGRS CONTINUED FROM 14 MAR 07 **** RUN TBG PUNCHER, PUNCH HOLES AT 8980' - 8982'. RUN CHEMICAL CUTTER, CUT 5 1/2" TBG AT 9028'. CUTTER HEAD LOOKED NORMAL AT SURFACE. ***JOB COMPLETE*** *** AWGRS CONTINUED FROM 13TH MAR 07 **** FINISHED SCMT RUN & STRING SHOT / REPAIR ICED-UP HEAD CATCHER. RIG UP TBG PUNCHER. UNABLE TO OPEN SWAB VALVE. WAITED FOR GREASE CREW TO FIX SWAB. **** AWGRS CONTINUED ON 15 MAR 07 **** *** AWGRS CONTINUED FROM 12TH MAR 07 **** WAITED FOR WEATHER UNTIL NOON. LOG SCMT FROM SURFACE TO TD. FREEPIPE FROM TD TO SURFACE. TD TAGGED AT 9185 FT. **** AWGRS CONTINUED ON THE 14TH MAR '07 **** *** STANDBY FOR WEATHER, WINDCHILL IS -60 DEGF *** *** AWGRS CONTINUED ON 13TH MAR 07 **** ***WSR continued from 3/11/07*** MIT-OA to 2000 psi. (PRE CTD). *PASSED* the 2nd attempt. Held tight for 30 min. Pumped 3 bbls of 4* diesel to achieve test pressure. Bled back 1.2 bbls. Well was shut in upon arrival. Bled TBG & IA below 200 psi for TBG cut. Final WHP= 0+/0+/0+/0+. T/I/O= 340/400/60/0. CMIT-TxIA to 3000 psi. (PRE CTD) *PASSED* the 1st attempt. TBG lost 40 psi & IA lost 120 psi / 1st 15 min. TBG lost 20 psi & IA lost 60 psi / 2nd 15 min. Pumped 12 bbls of 30* diesel to achieve test pressure. Bled back 6 bbls. Well was S/I upon arrival. *** WSR continues on 3/12/07*** ****WELL SHUT IN ON ARRIVAL *** (PRE SDTRK) RAN 4.5" CENT, SB . SAT DOWN @ 9148' SLM ( SB EMPTY) ***LEFT WELL SHUT IN AND TURNED OVER TO DSO *** CTU #9 w/1.75" CT. **** Cont from 3/7/07 WSR **** CTU #9 PM **** Reverse out fill to target at 9350' - short trips to TT - Dry tag at 9350' - Flag pipe at 9340' - CBU - swap well over to diesel - Keep hole full while cementers get ready. Pump 19 bbls of 17ppg cement and lay in from 9340' with full returns. PUH to safety. Check returns and have 1: 1. Bump up to 500 psi WHP and is plug is holding. Resume circulating and hold'" 500 psi for 30 minutes while getting 1: 1 returns. Drop ball and cleanout to 9151' (ELMD of XN). Make up/dn passes with biozan to contaminate cement. Make up/dn passes with 1% XS KCL and chase OOH at "'70% washing all mandrels on way OOH. Freeze protect well with 60/40 meth from 2500' to surface. Jet tree and BOP's. SI well and bump to 330 psi, plug holding, bleed down and SI well. Recovered ball. RD. Left well shut-in. *** JOB COMPLETE *** CTU #9 w/1.75" CT. Continued from 03/06/07 WSR. At flag. Line up to reverse. No returns up coil. Trouble shoot. POOH. Clear and flush coil. Pop off, inspect BHA. Some sluggets in nozzle. Stab back on w/2.3 BDJSN and RIH while pumping min rate to keep nozzle and coil clear. Tag at 9232' ctmd. PUH, clear coil and start reversing from 9080' ctmd. Reverse to flag and reset counter to 9215.6' (ELMD at flag), continue reversing. Difficult reversing thru 100 mesh sand cap - switch to coil and fluffed several times - cont reversing. from 9215 to 9313'. **** Continued on 3/8/07 WSR **** T/I/O = 0/vac/100. Temp = S1. IA FL (Coil request). IA FL @ 90'. http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 5/31/2007 Digital Wellfile AWGRS 04-01 03/06/2007 AWGRS 04-01 03/05/2007 AWGRS 04-01 03/05/2007 AWGB.5 04-01 03/04/2007 A WGR$ 04-01 03/04/2007 AWGRS 04-01 03/03/2007 AWGRS 04-01 03/03/2007 AWGRS 04-01 03/02/2007 AWGRS 04-01 03/02/2007 AWGRS 04-01 03/01/2007 AW_GRS 04-01 02/08/2007 AWGRS 04-01 02/06/2007 AWGRS 04-01 02/03/2007 . Page 2 of 2 . CTU #9 w/ 1.75" CT. MIRU CTU #9. MU BHA #1: GR/CCL in carrier w/ 2.25" OD DJN. RIH to dry tag at 9219' CTMD. Jet through top of sluggets to make sure it is soft. Let fill settle and re-tag, paint flag at 9235' CTMD. Log up from tag to 8200' at 40 fpm. Pull to surface and MU BHA #2: 2.25" OD BJN. RIH, depth correct at flag. Prepare to begin reversing out sand. Continued on 03/07/07 WSR. Switch to normal ticket from weather standby. Standby for Veco to complete rig up. Continued on 03/06/07 WSR T/I/0=240/260/90 Temp=SI No A/L TBG, lA, OA FL's (pre CTU cement). TBG FL @ 108' (4 bbls). IA & OA FLs @ surface. Drive to DS 4. Go to weather standby, due to ambient. ***CONTINUED FROM 3/3/07*** FISHED IBP RUBBER ELEMENT FROM 9200'SLM ***NOTIFIED DSO LEFT WELL S/I*** ***WELLSHUT IN ON ARRIVAL *** JOB IN PROGRESS ( FISHING IBP RUBBER) ***CONTINUED ON WSR 3/4/07*** *** CONT FROM 03-02-07 WSR *** (RWO prep) RECOVERED IBP & ONE 6" ELEMENT. DRIFTED W/ 4.25 CENT & 3 PRONG WIRE GRAB TO 9214' SLM. NO ELEMENTS RECOVERED. RDMO *** WELL LEFT 51, DSO NOTIFIED OF WELL STATUS *** ***** NOTE: ONE 6" ELEMENT & 1" STIFFENING RING LEFT IN HOLE *** *** WELL SI ON ARRIVAL *** (RWO prep) SSV LEAKING WHEN DUMPED...VECO VLV CREW REPLACED POWER HEAD & SSV NOW WORKING PROPERLY. DRIFTED W/ 4.50 CENT & 3.50 LIB TO 9084' SLM, GOOD IMPRESSION OF IBP FISHING NECK. RAN IBP EQUALIZING SLEEVE W/ 4.40" MULE SHOE GUIDE & EQUALIZED IBP.....PULLING OOH W/ IBP @ REPORT TIME. *** JOB IN PROGRESS/ CONT ON 03-03-07 WSR *** T/I/O = 150/80/40. Temp=SI. No AL. Tbg, IA & OA FL's. (pre CTU cement). TBG FL @ surface. IA FL & OA FL @ surface. ** standby 1 hr for valve crew to replace barrel on SSV slickline on well. ** T/I/0=20/30/0. PPPOT-T (FAIL), PPPOT-IC (PASS). McEvoy Gen I Retro Fitted to 13" 5m x 11" 5m McEvoy Gen 4 wellhead, 7" x 6 3/8" Upper Tree assembly. PPPOT-T: Opened test port bleeder screw on tubing hanger void, bled pressure to 0 psi. Functioned all lockdown pins, no sign of bent or broken pins, Installed test pump, pressured void at 5,000 psi for 30 minutes, lost 800 psi in 30 minutes, bled void to 0 psi (FAIL). PPPOT-IC: Opened test port bleeder screw and bled pressure to 0 psi. Pumped through void until clean fluid was achieved. Pressured void to 3500 psi for 30 min test, pressure decreased 500 psi in 15 min. Functioned LDS, all moved with 4 tight, no sign of bent or broken pins. Pressured test void to 3500 psi, lost 100 psi in first 15 min, lost 20 psi in second 15 minI bled void to 0 psi (PASS). Note: Test void has Alemite test fitting, packing port has 1/2" ball valve installed. T/I/O= 30/40/0+. Temp= SI. No AL. CMIT-TxIA PASSED to 3000 psi w/ triplex (pre CTD). Tbg FL @ surface. IA FL @ surface. Pumped 10.25 bbls in 45 minutes to reach 3020/3000 psi test pressure on Tbg/IA. TBGP/IAP lost 60/60 psi in first 15 minutes & 20/30 psi in second 15 minutes, for a total loss of 80/90 psi in 30 minutes. Bled TBGP/IAP back to 30/20 psi in 20 minutes, (9.25 bbls) returned. Final WHP's= 20/30/0. TIO/OO = SSV/20/40/0. Temp = SI. No AL. WHPs, IA FL (pre CMIT). IA FL @ surface. IA needs a 2" integral flange (if FB does CMIT). SET A 3 3/8" RETRIEVABLE IBP IN 5 1/2" TUBING. MID ELEMENT SET AT 9100. 1.75" JDC FISHING NECK LOCATED AT 9093.5'. OVERALL PLUG LENGTH: 11.59'. TWO 6 INCH SEALING ELEMENTS, ONE 1 INCH STIFFENER RING. DID NOT TAG TD. WELL LEFT SHUT IN. *****JOB COMPLETE***** http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 5/31/2007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-01 04-01 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/1/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 11/27/1970 End: 4/15/2007 4/1712007 09:00 - 11 :00 2.00 RIGU P PRE Rig released from End 1-39 @ 09:00 on 4-17-2007. Prep to move rig off well. Warm moving system for 45 min. 11 :00 - 11 :30 0.50 MOB P PRE Held PJSM & THA for moving rig off well & pre-move safety meeting with crew, security & tool services. 11 :30 - 11 :45 0.25 MOB P PRE Jack-up rig & move rig off well. 11:45 -12:00 0.25 RIGU N HMAN PRE While laying down 16"x17' mouse hole, 15 gallons of condensate inside mouse hole leaked onto the pad (condensate was from steam hose used to thaw mouse hole). Informed Endicott environmental & front desk. Environmental informed us to chip up & bag the leak. 12:00 - 12:45 0.75 MOB P PRE Move off well. Meanwhile, SLB service injector & reel package. 12:45 - 18:00 5.25 MOB P PRE Held PJSM & THA prior to laying derrick down. Lower derrick & back fill mouse hole with gravel. 18:00 - 23:59 5.98 MOB P PRE Move Nordic 2 from Endicott Island to DS 04-01. 23:59 - 00:00 0.02 MOB P PRE Nordic 2 is - 8 mile into the journey. 4/18/2007 00:00 - 00:01 0.02 MOB P PRE Continue rig move from Endicott Island to DS 04-01. Currently - 8 miles into the journey. 00:01 - 05:00 4.98 MOB P PRE Nordic 2 is currently on the road to DS 17 05:00 - 05:45 0.75 MOB N HMAN PRE As Nordic 2 made the corner from Endicott turn off to DS 17, drilling mud from the sump in front of the draw works (which would normally be caught by the drip pan under the rotary table, but was taken off to be modified for DS 4-01) spilled onto the road. Incident was reported to 5700, 2-3 gallons of drilling mud spilling onto the road. Were instructed to clean it up and continue on with the rig move. 05:45 - 12:30 6.75 MOB P PRE Continue to the DS4 pad. 12:30 - 18:00 5.50 MOB P PRE Work on installing drip pan below rig floor prior to raising derrick. Windspeeds 30MPH - gusting to 40MPH. 18:00 - 19:00 1.00 MOB P PRE PJSM & THA & reviewed procedure for installing drip pan below rig floor. 19:00 - 23:30 4.50 MOB P PRE Drip pan has been installed. Needs to be leak tested. 23:30 - 00:00 0.50 MOB N WAIT PRE Currently in Phase 2 on all pads. 4/19/2007 00:00 - 06:00 6.00 MOB N WAIT PRE Wait on winds to lower below 30 MPH prior to raising derrick. Perform preventive maintenance on the pits/suction valves. 06:00 - 16:30 10.50 MOB N WAIT PRE Winds are 20-25 MPH. 16:30 - 17:00 0.50 MOB P PRE Get with DSO for permit to work for raising derrick, picking up BOP's & backing over well. PJSM & THA prior to rasing derrick. Reviewed procedure for raising derrick & assigned a leader (Driller). 17:00 - 18:00 1.00 MOB P PRE Raise derrick & secure it w/ pins. 18:00 - 18:15 0.25 MOB P PRE C/O With night crew, inspect rig & review job scope. 18:15 - 19:00 0.75 MOB P PRE Write procedure for installing tong line on D/S of derrick. Review procedure & assign a leader (Driller). Fill out Man rider permit. Review THA for skidding BOP's wI loader & assign a leader (Motorman). 19:00 - 20:30 1.50 MOB P PRE Install tong line on D/S. 20:30 - 20:45 0.25 MOB P PRE Review procedure for scoping out derrick & clearing floor, assign leader (Driller). 20:45 - 21 :30 0.75 MOB P PRE Scope out derrick & secure it. 21 :30 - 21 :45 0.25 MOB P PRE Review procedure for general R/U. 21 :45 - 00:00 2.25 MOB P PRE Release blocks from scoping cables, pick up and secure bridal cables in derrick, clear floor, M/U injector gooseneck & move injector off rotary table. Pick up bales. Printed: 5/21/2007 9:09:55 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-01 04-01 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/1/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 11/27/1970 End: 4/15/2007 4/20/2007 00:00 - 01 :00 1.00 MOB P PRE Write procedure I THA for picking & handling BOP's in cellar wi shipping stand & review wi crew. 01 :00 - 03:30 2.50 MOB P PRE Pick BOP stack wi draw works & secure it in the cellar. Install 135/8" to 11" XO. 03:30 - 05:00 1.50 MOB P PRE PJSM & THA for backing over well wi Nordic 2. Move from pad entrance. Simultaneously, lay down herculit liner & lay down rig mats around wellhead & bleed down OA from 100 psi to 0 psi to slop oil trailer in 5 min (initial fluid, went to gas). 05:00 - 06:00 1.00 MOB P PRE T/INONOOA WHP's = natO/O/O. Spot Nordic 2 over ramp area. 06:00 - 15:00 9.00 MOB P PRE Wait on DSO & clo Nordic crew. Spotted rig over well with 13-518" hanging in cellar Held THA I PJSM on Nipple down tree and adaptor flange. Spotted office trailer hook up communications and set cutting box. Sent TL camp to Nordic 1. Building stairs and walk ways up onto ice pad. 15:00 - 18:00 3.00 MOB P PRE ND MV and adaptor flange. Install rig mats for cutting box Welding stairs to rig mats for passage up on top of the ice pad. Approved by DSO Pulled the adaptor flange with blocks. 18:00 - 18:45 0.75 MOB P PRE CIO wi day crew, inspect location, PJSM & THA for handling adaptor flange & N/U BOP·s. Get measurments & verify spaceout for test joint 10.75" stub + 8" XO, have 21.75" from base of 11" flange to bottom of variable rams - 3.25" to spare. 18:45 - 20:30 1.75 MOB P PRE Remove adaptor flange & lifting slings from blocks. Inspect & clean hanger landing threads (threads are good), verift no trash on top of BPV. MU LH ACME x 7" XO & count # of tums - 9.5 turns. Cameron confirmed all LDS are operational. Lay down walking mats around rig. R/U rig mats for cuttings box (16). 20:30 - 23:00 2.50 MOB P PRE Clean ring groove, install studs & new ring gasket, N/U BOP's & torque studs to spec. Veco harline crew is R/U tiger tank line to choke line on rig, PT - 500/4000, blow down wi rig air. 23:00 - 00:00 1.00 MOB P PRE Release BOP stack from draw works. R/U 1502 x 2" integral on IA wi new ring gasket. R/U choke & kill line. 4/21/2007 00:00 - 00:30 0.50 MOB P PRE Raise & shim rig wi 2x6 'so 00:30 - 01 :00 0.50 MOB P PRE Torque remainder BOP studs to spec. 01:00 - 01:15 0.25 MOB P PRE PJSM & THA prior to handling & installing riser on BOP's. 01:15 - 03:30 2.25 MOB P PRE Pick up & install new riser wi new gasket, silicone & rubber gaskets. GBR modifying new top riser section, fill up piping & welding second set of stairs to rig matting. 03:30 - 04:20 0.83 MOB P PRE Hook up BOP hoses. Hook up jumper hose to read pressure on OOA. Hook up sensors to lA, OA, OOA & install guards over flanges. 04:20 - 04:30 0.17 MOB P PRE PJSM Prior to changing out current variable rams for 7" x 5.5" variable rams. 04:30 - 13:30 9.00 MOB P PRE Function test BOPE. Swap out current variable rams for 7"x4.5" variable rams. Cut off landing in cellar to open BOP doors. Loading pits with 120deg SW Building stairs I ramps up to cutting box. Fluid packed the new riser I boots (ok). Closed blinds. Fluid packed surface line. AOGCC wavered witnessing BOP test Lou Grimalli AOGCC. Pressure up on the BOP body and casing to 250 I 3,000 psi (ok). MU 7" SLB lubricator and pulled BPV and install TWC. Printed: 5/21/2007 9:09:55 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-01 04-01 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/1/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 11/27/1970 End: 4/15/2007 BOP test AOGCC Lou Grimalli wavered witnessing BOP test. Tested 7"-4-1/2" variables using 7" and 5-1/2" casing as per AOGCC. Temp today at +28deg F for most of the day 18:00 - 18:20 PRE C/O wi day crew. PJSM & THA for BOP testing. 18:20 . 19:30 PRE Continue wi BOP test. 19:30 - 20:00 PRE Finished BOP test. Chart recorded, as well as electronically recorded by SLB & Nordic. UD test joint, & PIU 7" lubricator for pulling TWC. 20:00 - 20:15 PRE PJSM & THA prior to pulling TWC wi Veco valve shop crew. 20:15-21:00 PRE Attempt to pull TWC. Install bow spring centralizer & attempt to pull TWC again. 21 :00 - 22:30 1.50 PRE Lay down 7" lubricator & tidy rig floor. Fill out THA & man rider permit for pinning tog bucket for ODS tings. 22:30 - 23:00 0.50 PULL P DECOMP PJSM & THA prior to picking up 3 1/2" elevators, making up stabbing valve & landing joint. 23:00 - 00:00 1.00 PULL P DECOMP PIU 3 1/2" elevators, make up & torque stabbing valve & xo's. PIU 31/2" 13.3# S-135 D.P. & make up & torque to 31/2" IFx4 1/2" IF & 41/2" IFx7" BUT & 7" BUTx7" LH ACME for the landing joint. Land in hanger 9112 turns to the left. Hook up 2" circulating hose from standpipe manifold to tiger tank line on choke manifold for reverse circulating. 4/22/2007 00:00 - 01 :30 1.50 PULL P DECOMP R/U circulating equipment. 01 :30 - 02:00 0.50 PULL P DECOMP PJSM & THA prior to circ out well. Inspect T.T. & cellar. 02:00 - 03:50 1.83 PULL P DECOMP T/IAlOAlOOA = 0/0/32/0. Reverse circulate 100 bbls wi S.w. down IA @ 4 BPM 600 psi taking returns up the TBG out to tiger tank to get diesel F.P. out of well bore. @ 100 bbls away, stop reverse circulating and line up to pump down the TBG, taking returns up the IA out to the tiger tank wi 2 bbls of Safe-Surf-O added to active pits. 03:50 - 04:00 0.17 PULL P DECOMP Returns have cleared up (210bbls returned to T.T.). Shut down pumping & blow down reverse circulating hose wi rig air to T.T. & disconnect it. Simultaneously, conduct PJSM & THA for picking up GBR equipment & SLB spooler. 04:00 - 07:30 3.50 PULL P DECOMP Resume pumping down TBG taking returns up IA back into the rig pits. Increase pump rate to 180 SPM - 6 bbllmin @ 1080 psi. 07:30 - 11 :15 3.75 PULL P DECOMP PU on tubing and hanger came out of tubing spool at 157,000. Pulled hanger to floor. RU GBR tongs. Backed off landing joint, well is unbalanced. Screwed landing joint in and circulated 600 bbl's and mixed up dry pill. Pilled 30 bbl 9.5 ppg down tubing. Backed off landing joint and hanger 11:15-17:00 5.75 PULL P DECOMP POOH laying down 7" 26#/ft completion Filling hole every 5 joints. Having some trouble with control lines bunching up. 30 jts lay down at 17:00 Lost 3 bands on 1 st 30 jts 7" 17:00 - 17:30 0.50 PULL P DECOMP Unload pipe shed and change out SLB control liner spool 17:30 -18:00 0.50 PULL P DECOMP POOH laying down 7" and 5-1/2" completion 18:00 - 18:30 0.50 PULL P DECOMP C/O wi day crew. PJSM & THA for pulling 7" & 5.5" completion. 18:30 - 23:00 4.50 PULL P DECOMP Currently @ the SSSV profile. Recovered 53 of 59 (according to Camco records) stainless steel bands holding control & balance lines in place. PJSM & THA prior to handling/laying Printed: 5/2112007 9:09:55 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-01 04-01 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/1/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 11/27/1970 End: 4/15/2007 4/22/2007 18:30 - 23:00 4.50 PULL P DECOMP down 7" completion outside. 23:00 - 23: 15 0.25 PULL P DECOMP PJSM & THA for C/O 7" elevators for 5.5" elevator & equipment. 23:15 - 00:00 0.75 PULL P DECOMP Swap out 7" elevators for 5.5" & start pulling 5.5" completion. 4/23/2007 00:00 - 06:00 6.00 PULL P DECOMP Continue to pull 5.5" completion & jewelry from well bore. Currently @ GLM #4. Held PJSM & THA prior to bleed down OA for 9 5/8" casing spool removal. Bled OA from 59 psi to 0 psi in 20 min to a slope trailer. 06:00 - 07:00 1.00 PULL P DECOMP Crew change walk around and Conducted PJSM on LD completion 07:00 - 09:15 2.25 PULL P DECOMP LD completion Recovered all of the old completion as programmed. Cut off piece looks good and is 22.50 ft long. Top of stub at 9026 ft DD. 09:15 - 10:45 1.50 PULL P DECOMP Unloaded pipe shed and loaded out GBR and SLB equipment. 10:45 - 11 :30 0.75 EVAL P DECOMP PT 9-5/8" casing to 3,070 psi and in a charted 30 min the WHP = 3,008 psi Bleed the OA down and no flow, Also bled down the OOA and no pressure or flow 11 :30 - 14:45 3.25 WHSUR P DECOMP PU pipe spinners and load pipe shed with 3-1/2" DP 14:45 - 16:15 1.50 WHSUR P DECOMP Conversed with town on plan forward. Because of DWOP Regulation and RP, decided to PU 4-3/4" DC to set plug with. Loaded 124-3/4" DC, calipered, measured and drifted Load pipe shed with 124-3/4" DC's Talked to Schlumberger about loading 2-3/8" CT in reel house and install 2-3/8" blocks in injector 16:15 - 18:00 1.75 WHSUR P DECOMP RIH with 12-4-3/4" DC, RTTS /Storm Packer. RIH with 4 jts of 3-1/2" DP Set packer 18:00 - 18:30 0.50 WHSUR P DECOMP C/O w/ day crew. PJSM & THA prior to handling DP & setting RTTS/Storm Packer. 18:30 - 19:30 1.00 WHSUR P DECOMP RIH w/ 4 jts & set packer @ 134'. PT to 500 psi below packer & hold for 5 min. No flow, packer is set & is holding, bleed off pressure & unsting from packer & pull 4 jts of 3-1/2" DP. Close blinds & PT packer from above wI 500 psi & hold for 5 min. Packer is holding from above, bleed off pressure. 19:30 - 20:00 0.50 BOPSU P DECOMP PJSM & THA & review procedure for nipple down BOPE. 20:00 - 00:00 4.00 BOPSU P DECOMP Bleed off Komey unit, blow down kill line, suck down stack. Remove kill line from BOP's. Remove upper & lower riser section. Install BOP lifting ring. ND 13-3/8"x11" XO on bottom of BOP's & at tubing spool flange. Remove IA & OA crash guard & SLB sensors. CIW is bleeding down 9-5/8" packoff void. Ensure OA is @ zero. 4/24/2007 00:00 - 02:00 2.00 WHSUR P DECOMP PJSM & THA prior to lifting BOP's & tubing spool & changing out primary casing seal. Took - 12k to pop tubing spool free. Lift BOP's off adaptor flange. Lift off tubing spool w/ forklift & remove from wellhead. MU BOP spool piece on top of tubing spool. 02:00 - 03:00 1.00 WHSUR N SFAL DECOMP THA & PJSM prior to cutting seized bolt from casing spool. Fill out hot work permit & begin sawing bolt from casing spool. Schlumberger is changing out 2" gripper blocks to 2-3/8" gripper blocks on the injector. 03:00 - 06:00 3.00 WHSUR P DECOMP Ensure OA is 0 psi. Back out LDS on casing spool, remove screws on seallockdown mechanism. Having difficulty with the screws. Remove old seal. Clean the seal bore. Function LDS in Printed: 5/2112007 9:09:55 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-01 04-01 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/1/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 11/27/1970 End: 4/15/2007 4/24/2007 03:00 - 06:00 3.00 WHSUR P DECOMP & out. Installed seals, tested and RILDS. PU 13-5/8" spool and CIW 13-518" tubing hanger. 06:00 - 07:00 1.00 WHSUR P DECOMP Crew change, PJSM with crew and plan a way forward. 07:00 - 12:00 5.00 WHSUR P DECOMP Torque up tubing spool and lower BOP down on spools to complete the torque process. Cleaning out pipe shed. Installed riser and kill and choke lines. PT the casing hanger flange and packoff seal to 3,800 psi. Left pressure on for 30 min and witnessed the test. 12:00 - 14:00 2.00 WHSUR P DECOMP PJSM on install upper riser in BOP. Secured to drip pan. PJSM & THA prior to picking e-coil. Schlumberger picked up 2-3/8" e-coil, ID #13472e, used coil life peak of 63% @ 10,500', 322,515 R.F. Total length of 15,088 ft. 14:00 - 18:00 4.00 WHSUR P DECOMP Change out variables to 2-7/8" X 5-1/2". Hook up kill line. PU 13-5/8" test plug and set in spool working to get test plug in the 18:00 - 18:30 I 13-5/8" tubing hanger Checked the LDS. CIW inspected the tubing spool and ran in LDS, PT same. 0.50 WHSUR P DECOMP C/O with day crew. PJSM & THA for pressure testing BOPE - full body test & variable test. 18:30 - 20:00 1.50 WHSUR P DECOMP Fill BOP stack w/ sea water via mud cross. Leave IA valve open to atmosphere - contingency for hanger test plug leakage. Full body test against annular - low 250 psi & high 3500 psi for 5 minute each. Small leak on gray lock fitting on kill line, bleed off & tighten flange. Resume P.T. low & high. Annular passed. P.T. low & high on variable rams. Failed on high pressure test. Cycle variable rams. Repeat test low & high. Variable rams passed. 20:00 - 20:30 0.50 WHSUR P DECOMP Back out LDS & remove 4.5" tubing hanger test joint. Break out test joint on floor. 20:30 - 20:45 0.25 WHSUR P DECOMP PJSM & THA prior to pulling RTTS packer. Simultaneously, PJSM & THA w/ Schlumberger prior to C/O brass in stuffing box. 20:45 - 21 :45 1.00 WHSUR P DECOMP PU 2 stds of 3-1/2" dp & RIH to 134'. RU & close TIW. Set down on RTTS packer & spins 21 times into packer. Open TIW & check for flow - no flow. Break & LD TIW valve. PUH & LD 4 jts of 3-1/2" DP. Check for flow before bringing RTTS packer through BOP's - no flow. Break out & LD RTTS packer. Schlumberger has C/O brass in stuffing box. 21 :45 - 22:00 0.25 WHSUR P DECOMP PJSM & THA prior to PU & LD drill collars. 22:00 - 23:30 1.50 WHSUR P DECOMP POH & LD 12 jts of DC's. 23:30 - 00:00 0.50 CLEAN P DECOMP PJSM & THA w/ SLB slickline crew prior to PU & handling slickline. 4/25/2007 00:00 - 02:45 2.75 CLEAN P DECOMP Rig up .125" wire & slickline tools & equipment. Hang top slickline shive on blocks. Steam/clean junk basket. Zero bottom of tool string @ the rotary table, 23.15' correction to LDS. RIH w/8.50" junk basket to 9021' (9044' uncorrected), tag twice - same depth, RU line wiper & POH w/ slickline. Begin loading pipe shed w/4-1/2" 13Cr80 Vam Top tubing. 02:45 - 05:00 2.25 CLEAN P DECOMP POH w/ slickline. Pulling heavy due to small fluid bypass. 05:00 - 06:50 1.83 CLEAN P DECOMP Top of junk basket ports are plugged w/ paraffin. Recovered 1 S.S. control line band & 1 small partial control line band & 1/4 gallon of hard paraffin. Clean junk basket w/ steam. Zero SL @ rotary table. RIH w/ junk basket. Tagged at 9047 ft WLMD 06:50 - 08:30 1.67 CLEAN P DECOMP POH w/ slickline. Pulling heavy due to small fluid bypass. Printed: 5/2112007 9:09:55 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-01 04-01 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/1/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 11/27/1970 End: 4/15/2007 4/25/2007 06:50 - 08:30 1.67 CLEAN P DECaMP No material recovered , evidence on hard schmoo on the upper part of the junk basket 08:30 - 09:30 1.00 CLEAN P DECaMP RIH with 6" LIB, tagged at 9047 ft WLMD 09:30 - 10:15 0.75 CLEAN P DECaMP POOH with 6" LIB. Good indication of the 5-1/2" stub located at 9047 ft WLMD 10:15 - 10:30 0.25 CLEAN P DECaMP Held PJSM on RD wireline. 10:30 - 11 :00 0.50 CLEAN P DECaMP RD wireline 11:00 -17:15 6.25 RUNCO RUNCMP Load pipe shed with 4-1/2" completions. Loading out tool service equipment and make ready rig floor for running 4-1/2" completion 17:15 - 20:30 3.25 RUNCMP RU Doyon to run completion 20:30 - 21 :00 0.50 RUNCMP PJSM & THA & review procedure for running chrome completion. 21 :00 - 00:00 3.00 RUNCMP Running 4-1/2" tubing with Doyon Torque Turn (Torque = 4450 ft-Ib). 4/26/2007 00:00 - 06:00 6.00 RUNCMP Continue running 4-1/2" 13Cr Yam Top completion with Doyon Torque Turn (Torque = 4450 ft-Ib). 06:00 - 06:30 0.50 RUNCMP Crew change and held THA and discussed SOP for running completion tubulars 06:30 - 13:30 7.00 RUNCMP Continue running 4-1/2" 13Cr Yam Top completion with Doyon Torque Tum (Torque = 4450 ft-Ib). Kick while tripping tubulars drill. Ran 210 jts 4-1/2" Tubing. Tagged the top of the stub at 9,022 ft. Sheared the shear stock and went in the hole another 4 ft to 9,030 ft. Marked pipe and PUH LD 3 joints of 4-1/2" tubing. Calculated Space out and install 3 4-1/2" pup joints 13:30 - 16:00 RUNCMP Installed Space out PJ and CIW hanger. RIH and RU to reverse circulate wellbore. Set top of hanger below annular closed same. 16:00 - 16:30 RUNCMP PJSM with crew and truck drivers 16:30 - 17:25 RUNCMP Spot truck and add 1 drum Corrosion inhibitor in both truck 17:25 - 20:30 RUNCMP Reverse circulate in corrosion inhibitor in the well at 3.00 bpm. 20:30 - 21 :30 RUNCMP Stop pumping, suck out stack. Land tubing, take out LDS & verify hanger has landed. RILDS. Drop ball & rod. 21 :30 - 22:00 0.50 RUNCMP PJSM & THA prior to setting packer & pressure testing tubing/casing. 22:00 - 22:55 0.92 RUNCMP Pressure test tubing & chart it to 3500 psi for 30 min. 15 min for the chart to stabilize. Test was good. 22:55 - 23:30 RUNCMP Bleed of tubing pressure to 1500 psi. Install tee and gauge on top of landing joint to monitor pressure on tubing. 23:30 - 00:00 0.50 RUNCMP Pressure test IA & chart it to 3000 psi for 30 min. Let chart stabilize. 4/27/2007 00:00 - 01 :00 1.00 RUNCMP IA pressure test for 30 min passed. Line up & bleed TBG via Baker choke & shear top GLM. Sheared @ 400 psi. Pump 10 bbls of S.W. down IA taking returns up the TBG to confirm sheared GLV. 01 :00 - 01 :30 0.50 WHSUR P POST PJSM & THA w/ LRS prior to pumping diesel FP down IA & also setting BPV. 01 :30 - 03:00 1.50 WHSUR P POST RU LRS to IA. PT lines to 3500 psi & pump 140 bbls diesel down IA taking returns up tbg. 03:00 - 04:00 1.00 WHSUR P POST Set 4-1/2" H style BPV & LRS to tested from below. Good test, RD LRS. 04:00 - 04:15 0.25 WHSUR P POST PJSM & THA for the ND procedure. Printed: 5/21/2007 9:09:55 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-01 04-01 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/1/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 11/27/1970 End: 4/15/2007 12:00 - 15:00 3.00 WHSUR P POST Blow down lines in prep for ND BOP. Suck out stack. PJSM following crew change Open up 13-5/8" Stack and prep for stacking at Price Pad ND riser and 13-5/8" BOP's Installed 13-5/8" 5 k X 4-1/8" 5k tree adaptor and 4-1/8" master valve. Changed to Sidetrack Section of the Project. Reenter and Completion 4/16/2007 4/27/2007 04:15 - 12:00 7.75 WHSUR P POST Printed: 5/2112007 9:09:55 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-01 04-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/16/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 11/27/1970 End: 5/10/2007 4/27/2007 15:00 - 16:00 1.00 MOB P PRE Finished installing CIW Tree Adaptor and test to 5000 psi. Installed Master valve and companion flange on top of the valve. 16:00 - 16:15 0.25 MOB P PRE Held PJSM on moving off well with crew and DSO. Read the SOP and mitigated the hazards discussed 16:15 - 16:35 0.33 MOB P PRE Open doors, jack rig up and move off well 16:35 - 18:00 1.42 MOB P PRE Swap BOP out i.e. Change 13-5/8" to 7-1/16" BOP's 18:00 - 18:30 0.50 MOB P PRE PJSM & THA & review moving rig/CO BOP's 18:30 - 21 :30 3.00 MOB P PRE C/O configuration on BOP stack. MU 7-1/16"x4-1/16" XO on bottom of BOP's. 21 :30 - 22:00 0.50 MOB P PRE PJSM & THA prior to backing over well w/ Nordic & SLB & DSO. 22:00 - 22:30 0.50 MOB P PRE Back over well. 22:30 - 23:00 0.50 MOB P PRE PJSM & THA prior to NU 7-1/16" BOPE 23:00 - 00:00 1.00 MOB P PRE NU 7-1/16" BOPE 4/28/2007 00:00 - 01 :50 1.83 BOPSU P PRE Continue to NU BOPE, torque all flanges to spec. Hook up BOPE hoses. Hook up IA,OA & OOA sensors. 01 :50 - 03:30 1.67 BOPSU P PRE Shim rig. Hook up Choke & Kill line. Get BOP measurements. Label BOP controls. Stab 10' lubricator on top of annular. 03:30 - 04:00 0.50 BOPSU P PRE PJSM & THA prior to rigging up Veco to remove BPV. 04:00 - 04:30 0.50 BOPSU P PRE Pull BPV & set a TWC to test BOP's. 04:30 - 06:00 1.50 BOPSU P PRE Function test BOPs. Fill stack with water. Conducted shell test on BOP and master valve. 06:00 - 13:30 7.50 BOPSU P PRE Conducting BOP at 250 / 3500 psi. Jeff Jones wavered witness BOP 13:30 - 15:00 1.50 BOPSU P PRE RD BOP testing equipment. Called the valve shop to pull TWC. PU injector and stabbed packoff on. Pull injector to side and RU to pull TWC with lubricator Held PJSM on pulling CT across pipe shed and stabbing in injector and packoff. 15:00 - 16:00 1.00 BOPSU P PRE Pull TWC after repairing pulling tool RD and load out 16:00 - 18:00 2.00 RIGU P PRE Pull CT across and stab in injector 18:00 - 18:30 0.50 RIGU P PRE Day crew C/O. PJSM & THA prior to RU slickline. 18:30 - 20:00 1.50 RIGU P PRE RU slickline unit. 20:00 - 21 :00 1.00 RfGU P PRE RIH w/ slickline & retrieve ball & rod. Recovered ball & rod. 21 :00 - 22:00 1.00 RIGU P PRE RIH w/ 4.5" OM-1 & pull DCK from GLM #5. Recovered DCK valve. 22:00 - 22:40 0.67 RIGU P PRE RIH w/ 4.5" OM-1 & set 1.5" DMY valve in GLM #5. Set good. 22:40 - 23:30 0.83 RIGU P PRE Pressure test IA to confirm integrity. Passed test. 23:30 - 00:00 0.50 RIGU P PRE RIH w/ 4.5" GS to retrieve RHC plug @ 8976'. 4/29/2007 00:00 - 01 :30 1.50 RIGU P PRE Recovered RHC plug. 01 :30 - 01 :45 0.25 RIGU P PRE PJSM & THA prior to RD slickline. 01 :45 - 02:00 0.25 RIGD P PRE RD slickline unit. 02:00 - 02: 15 0.25 RIGU P PRE PJSM & THA prior to filling coil w/ fluid & CT slack management. 02:15 - 03:45 1.50 RIGU P PRE Fill coil w/ fluid @ 1.5 bbls/min. Caught fluid @ 53 bbls away. SID & bleed off. 03:45 - 03:50 0.08 RIGU P PRE Stab injector on well & conduct slack management. SD & bleed off, SLB hand noticed that the lower half of stuffing box is weeping fluid from the injection/wellhead port adaptor. Lower half of stuffing box is missing a boss fitting plug from the factory. Pop off well & stab over circulating hole on rig floor & circulate fluid. 03:50 - 04:20 0.50 RIGU N HMAN PRE Install new boss fitting, stab injector on well & PT. PT was Printed: 5/21/2007 9:10:07 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-01 04-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/16/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 11/27/1970 End: 5/10/2007 4/29/2007 03:50 - 04:20 0.50 RIGU N HMAN PRE good. 04:20 - 08:00 3.67 RIGU P PRE Conduct slack management. Cut 68' of coil to find wire. Meg Ohm wire - good test. Install CTC and Pulled test to 35k and pressure tested to 3500 psi 08:00 - 10:00 2.00 STWHIP P WEXIT Cir CT working on floor. Circulated through CT at 1.52 bpm to finalize the slack management. PU Mill BHA #1 and confirmed scribed line and offset. Stab on well Open EDC 10:00 - 12:00 2.00 STWHIP P WEXIT RIH 12:00 - 13:00 1.00 STWHIP P WEXIT Logged tie-in with CCL from 8950 ft to 9150 ft and corrected -2 ft. Logged GR from 8,630 ft to 8,750 and no correction. 13:00 - 13:30 0.50 STWHIP P WEXIT RIH and tagged at 9185" confirmed again at 9185' PUH and start circulating and orient TF to 180 deg 13:30 - 19: 13 5.72 STWHIP P WEXIT Milling hard cement with LS TF Op = 2.48 / 2.49 bpm at 2,320 psi off bottom and 2500 psi on bottom pressure. ROP on cement started at 41 fph to 14 fph in 2 ft Stalled at 9,189 ft. Cement hard at 5-15 fph 19:13 - 19:20 0.12 STWHIP P WEXIT Stop pumping, pick up & orientate to 180 deg HS. 34k pick up weight. 19:20 - 19:54 0.57 STWHIP P WEXIT Begin milling cement ramp @ 9288' with HS TF Op = 2.48 / 2.49 bpm at 2,350 psi off bottom and 2552 psi on bottom pressure. ROP on cement ramp - 20 fph. 19:54 - 20:03 0.15 STWHIP P WEXIT Stop drilling, pick up and back ream cement ramp & pilot hole. Dress the entrance of the pilot hole. 20:03 - 21 :00 0.95 STWHIP P WEXIT Open EDC & pick up to 8940 ft. RIH @ 800 fph & tie in. No correction needed. 21 :00 - 21 :59 0.98 STWHIP N MISC WEXIT Stop moving coil. Reduce pump rate. SLB coil supervisor noticed the reel bushing end plate & bolt fell out of the reel. Stop & repair the problem. 21 :59 - 23:45 1.77 STWHIP P WEXIT Increase pump rate & POH to PU casing exit BHA. PJSM & THA prior to handling BHA's. 23:45 - 00:00 0.25 STWHIP P WEXIT Tag stuffing box brass, RIH to 200 ft. Stop pumping & close EDC. No flow check. 4/30/2007 00:00 - 01 :00 1.00 STWHIP P WEXIT LD cement pilot hole milling BHA. PU & MU window milling BHA. 01 :00 - 03:36 2.60 STWHIP P WEXIT BHI tool tested good. Open EDC & RIH. Set down in GLM #2 & GLM #1, orientate to get through. Set down in X profile @ 8909 ft, pump through motor to get passed. 03:36 - 04:10 0.57 STWHIP P WEXIT Logged tie-in with CCL from 8950 ft to 9150 ft and corrected -3 ft. 04:10 - 05:08 0.97 STWHIP P WEXIT Shut down pumps, orient TF to low side & RIH. Sit down @ 9250 ft. Try different orientations. Try different speeds. Orientate to LS & try pumping @ min rate. Suspect we are hitting a collar edge. RIH @ 3 Wmin while pumping 2.4 bbls/min. 05:08 - 05:17 0.15 STWHIP P WEXIT Tag @ 9300 ft. Pick up & orientate TF to HS. 05:17 - 09:47 4.50 STWHIP P WEXIT Milling 9-5/8" Casing as per schedule Op = 2.51/2.50 bpm at 2087 psi Note: Swapped MP1 to MP2 at 07:00 hrs. Seeing some motor work at 9301.3 ft with very little WOB Concern about damage mill while working through the collar at Printed: 5/21/2007 9: 1 0:07 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-01 04-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/16/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 11/27/1970 End: 5/10/2007 4/30/2007 05:17 - 09:47 4.50 STWHIP P WEXIT 9,251 ft. At 9301.4. the Pp inc 40 psi and short term WOB. Could be sliding down the wall instead of cutting a notch in casing 09:47 - 11 :35 1.80 STWHIP P WEXIT PUH ream out area between 9,255 ft to 9,230 ft. RIH WO pump. Tagged at 9248 ft PU and tried again and set down at 9248 ft HS TF Tried RIH at 2.00 BPM at HS and worked our way through NOTE: 9-5/8" casing collar at approximatel 9,251 ft. Could be bad casing or a damaged gage on the mill? Pumped 20 bbl HV biozan pill PUH from 9,300 ft and orient TF to 45L and back ream 9,255 ft to 9,230 ft. SD pump, orient TF to HS and RIH. Tagged at 9,248 ft. Worked through easier than before. RIH to 9,300 ft. Sweep out of CT, PUH, orient TF to 45R and back ream from 9,255 ft to 9,230 ft. Turn TF to HS SD pump and RIH Started sweep # 2 (25 bbl) Last RIH wo/ pump, clean at 9,248 ft. RIH chasing pill 11:35 -13:40 2.08 STWHIP P WEXIT POOH chasing sweep to surface. Open EDC at 9,137 ft. PJSM with crew on handling BHA 13:40 - 14:45 1.08 STWHIP P WEXIT Stood back Coiltrac BHA and broke off motor and bit. DP0088 gauge looked worn but not that bad. The center core point has a piece of dia matrix broken off the diameter and thickness of a quarter. PU New mill and 2.25 deg bend motor 14:45 - 17:00 2.25 STWHIP P WEXIT Open EDC. RIH. Set down at 7,405 ft (GLM#3). orient TF to HS from 30R RIH orient TF to 90R RIH and tagged 8,157 ft (GLM 2), orient TF around to get past. RIH, tagged at 8,857 ft (GLM1) with HS TF. RIH orienting TF around and got past. Stopped at 8940 ft to tie-in 17:00 - 17:10 0.17 STWHIP P WEXIT RIH at 1,000 ft/hr logging CCL from 8940 ft Corrected -2 ft 17:10 - 17:30 0.33 STWHIP P WEXIT RIH and tagged 9301.5 ft, Slacked off to 9200 ft and PU to 9301.5 Qp = 2.55 at 2320 psi off bottom, Vp = 369 bbls WEXIT Start milling window at 17:30 hrs 0<-l~\ ft Qp = 2.59/2.61 bpm CTP = 2318 psi Vp = 369 bbl Mixing in the pits @ 20:31 hrs. 5/1/2007 00:00 - 01 :40 1.67 STWHIP P WEXIT Continue milling 9-5/8" casing as per extended schedule Qp = 2.57 / 2.61 bpm CTP = 2278 psi WOB = 0.08 Vp = 371 bbl 01 :40 - 06:00 4.33 STWHIP P WEXIT Seeing some motor work at 9303.0 ft with an increase in WOB Qp = 2.57 / 2.61 bpm CTP = 2340 psi WOB = 0.82 - 0.58 Vp = 371 bbl 06:00 - 10:00 4.00 STWHIP P WEXIT Milling window at 0.1 ft/6 min Qp = 2.56 / 2.60 bpm at 2443 psi on bottom, (off bottom = 2300 psi) WOB and motor work consistance after slacking off. Samples show very little metal with mostly cement. Stopped at 9307.5 ft and picked up. Pumped 20 bbl HV pill and RIH and motor work Printed: 512112007 9:10:07 AM ~;""".-,"",-.,;"..;4-l.';"'~· iA.""'-",,"!ii~Äit STATE OF ALASKA '__I OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: .HIILE~99@ª9I:rÜfloâtªtg,ª~,h!.~ ªºfaç.~~...Qnf~iJ}~~g...Þ.fAY.f¡j}.fJ~i!J.Ün&tªlº.oª~o.~~ bob neckenstein©adrnin.statf':.8k.us ............................................................................).;.ß................................................................................... Rig No.: 2 DATE: 4/24/07 Rig Phone: 659-4398 Rig Fax: 659-4356 Op. Phone: 659-4393 Op. Fax: 659-4356 E-Mail gm~i~{tçArJ.g.n_m:g¡~~~.t~~ºlng§.b~~f@A1n,J~~!J PTD # 170-042 11/09/04 "-- Contractor: Nordic Rig Rep.: Mckeiman/Lancaster Operator: BPX Rep.: Hildreth/Ross Well Name: PBU D4-01 Operation: Drlg: Test: Initial: X 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 Well Sign Drl. Rig Hazard Sec. Workover: X Weekly: Annular: 250-3500 TEST DATA Test Result P P P Quantity SizelType Test Result NA 1 2 7/8 X 5 1/2' P NA NA N/A NA N/A NA CHOKE MANIFOLD: Quantity Test Result No. Valves Manual Chokes Hydraulic Chokes Explor.: Bi-Weekly Valves: 250-3500 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly NT Lower Kelly NT Ball Type Inside BOP 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 Test Result NA ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure Pressure After Closure 200 psi Attained Full Pressure Attained Blind Switch Covers: All stations Y Nitgn. Bottles (avg): Test Results Number of Failures: º Test Time: .5 Hours Components tested 1 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: I¡IIL.r~199.@ª9IIÜftâtªtfLª~,h!.~ Remarks: Tested 4.5 rams and all breaks from tbg spool c/o Distribution: orig-Well File c - Oper.lRig c - Database c - Trip Rpt File c - Inspector Coil Tubing BFL 11/09/04 YES 24 HOUR NOTICE GIVEN X NO Date 4/20/07 Time Test start 1900 Finish SCANNED APR 2 5 2007 Waived By Lou Grimaldi 18:00 Witness 1930 Nordic 2 BOP 4-24-07 4.5 Rams.xls 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: .uL"Ll..xgfHJ.@~9LI3.lLU¿.t9.tJU:A~,!J_§ 9.Qíaç_~~...Q.nE1jJ~~g...Qª.Y.@Æt~tŒÜfL~~tª1fi.,9.K,_~? tm.t!...Jjgç.~~~fl§1º.¡r.l@~9f.I3.lfl,§?.t9.t~Lª-~,!J.§ Contractor: Nordic Rig No.: 2 DATE: 4/21107 Rig Rep.: Mckeiman/Lancaster Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Hildreth/Ross E-Mail §.~!.ª~t{f.gxJ.mf.~!!:ºj~~;?1~~Q¡tw.§.hgf@A-m&ø Well Name: PBU D4-01 PTD # 170..042 Operation: Drlg: Test: Initial: X Test Pressure: Rams: 250-3500 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity Stripper Annular Preventer 1 #1 Rams 1 #2 Rams 1 #3 Rams #4 Rams #5 Rams Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves 1 Check Valve Workover: X Weekly: Annular: 250-3500 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 2 P Well Sign Dr!. Rig Hazard Sec. SizelType 13/5/8" Blinds 51/2 x 7" N/A 3 1/8" 3 1/8" 31/8" N/A CHOKE MANIFOLD: Quantity Test Result No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P Test Result NA P P P NA NA 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 Test Result NA ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 2900 P Pressure After Closure 1550 P 200 psi Attained 40 sec P Full Pressure Attained 140 sec P Blind Switch Covers: All stations Y Nitgn. Bottles (avg): 4 @ 2300 Test Results Number of Failures: Q Test Time: Z Hours Components tested 24 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: I¡Ln..x~!g9.ay'ª9f.ElLt§?_19.t~u?K!J5 Remarks: we will test the kelly valves if we pick up the kelly SCANNED APR 2 Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector YES Date Test start Coil Tubing BFL 11/09/04 24 HOUR NOTICE GIVEN X NO 4120107 Time 13:00 Finish Waived By Lou Grimaldi 18:00 Witness 20:00 Nordic 2 BOP 4-21-07.xls Schlumb8rger APR 2 0 Z007 NO 4214 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons 'Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 r1 C'- c:</) ;~JI)!¡*;j Oil & Gas Cons. GOI'I'!m!m~ Anct1~ Field: Prudhoe Bay Well Job# Loa DescriDtion Date BL Color CD DS 04-01 11637323 SCMT 03/13/07 1 2-34/P-14 11638622 USIT 03/20/07 1 N-22B , 11594483 SÇMT 03/06/07 1 N-22B N/A USIT (CORROSION) 02/13/07 1 N-22B N/A USIT (CEMENT BOND) 02/13/07 1 P2-50B 11626472 SCMT 03/17/07 1 09-11 _ 11638619 USIT (CEMENT EVALUATION) 03/16/07 1 09-11 . 11638619 USIT (CORROSION) 03/16/07 1 09-11 11638621 CEMENT BOND LOG 03/19/07 1 L2-32 11221617 RST 10/13/06 1 1 A-24 11221856 RST 03/23/06 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. 5 2007 Petrotechnical Data Center LR2-1 5GANNED APR 2 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: + 04/16/07 . . RE: Request for 3000 PSI Maximum Pressure Test on DS4-01A Ri... . . Mel, You might need to add a little clarity so that the folks at the AOGCC can understand what you are requesting. DETAILS The rig is moving on to OS 4-01, which is a very unusual well. It has a very high wellhead. In order to rig up on this well we have built a 4' elevated ice pad on top of 084, and we have nippled the tree down to the master valve. In order for the rig to move over the well, they will have the 13-5/8" BOP stack hanging in the cellar. Once over the well, we can not rig up to pull the BPV prior to NU the BOPE. The first operation by the rig will be to nipple down the master valve, and nipple up the BOPE. Prior to pulling the BPV, we need to body test the BOPE. This will result in the entire wellbore down to the cement P&A plug being pressured up to BOP test pressure. After we have performed the body test, we will pull the BPV, and set a TWC. The full BOPE test will then be performed to the pressures as required by the sundry. REQUEST What you are requesting is that the AOGCC allow you to perform an initial body test to 3000 psi instead of 3500 psi. This pressure is above the maximum expected wellhead pressure with a full column of gas. This pressure is the maximum that our standard operating proceedures allow on the 9-5/8" casing. If you present the information to the AOGCC like this, they should have no problem with allowing you to proceed with the operation. Cheers, Greg sCANNED APR 1 9 2007 From: Rixse, Mel G Sent: Tuesday, April 17, 20072:13 PM To: Thomas Maunder Cc: NSU, ADW Drlg Nordic 2 Supervisor Subject: Request for 3000 PSI Maximum Pressure Test on DS4-01A Rig Work Over Date: 17 -April-2007 To: Tom Maunder, AOGCC Drilling Engineer I would like to request that Nordic 2, while it is doing the rig workover on DS04-01, internal pressure test the 9-5/8" casing to no more than 3000 psi. The pre-rig well work tested this casing to 3000 psi. I would like to not expose this casing to 500 psi additional pressure. I believe that based upon a reservoir pressure of 3400 psi, in the worst case scenario with the casing filled only with gas, the expected maximum pressure at surface will be 2520 psi. 10f2 4/19/2007 12:04 PM RE: Request for 3000 PSI Maximum Pressure Test on DS4-01A Ri... . . BP is planning to change the 9-5/8" casing pack-offs. The 9-5/8" annulus will be exposed while we change those seals. Please let me know if you approve this change. Sincerely, Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (907)564-5620 - Office (907)223-3605 - Cell 20f2 4/19/2007 12:04 PM RE: Request for 3000 PSI Maximum Pressure Test on DS4-01A Ri... . . Tom, Thank you for getting back to me. We are doing the workover on 04-01 in preparation for the sidetrack. I should have referred to this workover as 04-01 not 04-01A which will be drilled once the workover is done. I will note this 3000 psi pressure test in the handover notes to production operations. Mel From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, April 17, 2007 2:22 PM To: Rixse, Mel G Cc: NSU, ADW Drlg Nordic 2 Supervisor Subject: Re: Request for 3000 PSI Maximum Pressure Test on DS4-01A Rig Work Over Mel, et al: Testing to 3000 psi looks appropriate for the well conditions you give. It is probably appropriate to be sure that the handover notes to production conspicuously note that the 9-5/8" casing has not been tested beyond 3000 psi. With regards to changing the packoff, I believe the BOP will still be in place which will give you a mechanical well control device if needed. One other question, has the redrill been accomplished yet? If no new hole has been drilled, by convention the work is still within DS 04-01. Call or message with any questions. Tom Maunder, PE AOGCC Rixse, Mel G wrote, On 4/1712007 2: 12 PM: .....rA~INNED APR 1 9 2007 ::¡.....n Date: 17 -April-2007 To: Tom Maunder, AOGCC Drilling Engineer I would like to request that Nordic 2, while it is doing the rig workover on DS04-01, internal pressure test the 9-5/8" casing to no more than 3000 psi. The pre-rig well work tested this casing to 3000 psi. I would like to not expose this casing to 500 psi additional pressure. I believe that based upon a reservoir pressure of 3400 psi, in the worst case scenario with the casing filled only with gas, the expected maximum pressure at surface will be 2520 psi. BP is planning to change the 9-5/8" casing pack-offs. The 9-5/8" annulus will be exposed while we change those seals. Please let me know if you approve this change. Sincerely, Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. 1 ofl~ 4/19/200712:03 PM . . SARAH PALIN, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mel Rlxse CT Dnlling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 \1D-04&- Re: Pn.1dhoe Bay Field, Prudhoe Ba.y Oil Pool, PBU 04-01 Sundry Number: 307-073 SCANNED MAR 0 1. 2007 Dear Mr. Rixse: 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 ptovi.ding notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3fJJ7 (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 IIUiY 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 woIking 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 fuisa!fday of February, 2007 Encl. , . ~%S CIQ ,.'~ fI STATE OF ALASKA . ~? RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION f.~ 2 20 7 APPLICATION FOR SUNDRY APPROVAL p-~~ FEB 6 0 20 MC 25 280 ion AI........ na 2. Ca. ('I\n. - 1. Type of Request: 181 Abandon o Suspend o Operation Shutdown o Perforate o Time Extension Anchorage o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 170-042 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20078-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 04-01 . Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field 1 Pool(s): ADL 028324 " 64" Prudhoe Bay Field 1 Prudhoe Bay Pool .1?( . '. I -.... ......... .... 'f> .......( ..i.i..······>(i . ....... .. II ....... ...... Total Depth MD (ft): Total Depth TVD (ft):Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9790 . 9039 ' 9394 8689 9246 None Casino L enoth Sizp. MD TVD Burst CollaDse Structural 115' 30" 115' 115' Conductor 1185' 20" 1185' 1185' 1530 520 Surface 2686' 13-3/8" 2686' 2686' 4930 2670 Intermediate Production 9749' 9-5/8" 9749' 9002' 5120 2370 Liner Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): All Perfs Below Sand Plug 9371'·9578' 8669' _ 8851' 7", 26# x 5-1/2". 17# L-80 9184' Packers and SSSV Type: 9-5/8" x 5-112" Baker 'FB-1' Packer I Packers and SSSV MD (ft): 9063' 13. Attachments: 14. Well Class after proposed work: 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development o Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commendn!:! Operations: As Soon As Possible DOil DGas D Plugged 181 Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mel Rixse, 564-5620 Printed Name Mel Ri~e A~ Title CT Drilling Engineer Signatu'£ ~ ~-/~ ) Prepared By Name/Number: Phone 564-5620 Date~-Fl!/lÍ'L'L Terrie Hubble, 564-4628 ~ Commission Use Onlv Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: au ,. (')"'7'; - . ...., , D Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance Other: 35ûa~, m\7~~~, ,~~,~\\ ~,~\\ Subsequent Form Required: L-\Q) APPROVED BY 1.-;'1,D f' THE COMMISSION Date Form 1~3 Revised 06I2Õ R G I¥À ~ ,-, Submit In Duplicate 6Ft 2 2007 . . To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission Obp From: Me! Rixse CTD Engineer Date: February 21,2007 Re: DS04-0l Sundry Approval- Rev.! Sundry approval is requested for well 04-01. A tubing swap and coiled tubing drilling sidetrack from 04-01 is proposed. The parent well was a drilled and was completed January of 1971. In July 1990 a RWO was performed to repair the leaking DV collar in the 9-5/8" casing and to install a 7" x 5-1/2" completion. All perforations were squeezed again in November 1993 due to excessive gas and water production. Zone 4 perforations were added in September 1997. Starting around the middle of2003, 04-01 was shut-in most ofthe time due to high GOR. In December 2004 an unsuccessful attempt was made to reduce the GOR by performing a sand back with a cement cap. Well 04-01 also has T x IA communication due to tubing corrosion and a broken latch in GLM #6. A cement abandonment of all of the existing perforations is planned. The existing sand cap above the cement will be lowered to 9350'MD then the 9-5/8" casing will be cemented from 9350' to the base of the existing tubing tail at 9184'MD. ~ V\~~O \~~ \ "J. d ~\) \~ M'1IJv\..=>!";:) Cø The planned rig workover will pull and replace the existing 7"x 5-1/2" tubing and replace it with 4-1/2" chrome tubing with a packer to isolate the IA from the tubing at 8989'MD. The planned CTD sidetrack will exit the 9-5/8" cemented casing at 9300' and drill a 1730' lateral into the lower Ivishak. REASON FOR WORKOVER AND SIDETRACK: This existing well (04-01) RWO and coiled tubing sidetrack will restore well integrity by replacing the tubing and production will be increased by sidetracking the well to a more optimal zone and orientation within the surrounding patterns. The well will be sidetracked using Coil Tubing from the top ofthe Ivishak section in the 43P at -9300' MD. The proposed wellbore targets reserves in Zone 2A, Zone 1B and Zone 1A. The primary target is 600' of producible Zone 1B. The sidetrack is planned on or around March 10, 2007. The following describes the work planned and is submitted as an attachment to Form 10-401. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Ri Summary: " ~ E..-~\ \ 1. 0 Check the tubing hanger and IC casm k down screws for free movement. Completely back out and check each lock down screw or eck one at a time). PPPOT - T & IC. . . 2. S Dn -1/2" tubing for composite plug/jet cutter and 3-3/4" bit to base oftubi 3. S Pull 3 3/8" retne Pin 5 1/2" tubing. 4. C Run memory gamma ray/C 5. C Reverse circulat ' to 935 6. C ga cement sidetrack plug from 9350'MD to bas S<è£t <¿~\\ Me! Rixse CTD Engineer 564-5620 CC: Well File Sondra StewmanlTerrie Hubble Pre Rig and Rig Work for DS04-0I A...will call . . Pre-Rig Work Summary: 1. 0 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT - T & IC. 2. S Drift 7" x 5-1/2" tubing for composite plug/jet cutter and 3-3/4" bit to base of tubing tail. 3. S Pull 3 3/8" retrievable IBP in 5 1/2" tubing. 4. C Run memory gamma ray/CCL 5. C Reverse circulate sand plug 9246' to 9350' MD. 6. C Set 17#/gal cement sidetrack plug from 9350'MD to base of 5-112" tubing tail at 9184'MD. 7. 0 Perform MIT -IA to 3000 psi 8. E Run SCMT (CBL) to assure existing 7" x 5-112" tubing has no external backfill. 9. E Jet cut 5-1/2" tubing @ ~9028'md 10. F Circulate well with seawater and freeze-protect with diesel through the cut 11. 0 Bleed WHPs to 0 psi. 12. 0 Bleed production flow lines and GL lines down to zero and blind flange 13. 0 Set a BPV in the tubing hanger 14. 0 Build 4' ice pad 15. 0 Remove wellhouse Rig Work: 1. MIRU. 2. Set TWC and test to 1000 psi. 3. ND tree and tubing adapter flange. NU 13-5/8" BOPE with 2-7/8" x 5-1/2"" VBR pipe rams. Pressure test to 3500 psi. Annular preventer tested to 3500 psi. Circulate out freeze protection fluid and circulate well to clean kill weight brine through the cut. 4. Pull TWC 5. Pull and LD 7" x 5-1Iz" tubing string to the cut. Inspect jet cut once OOH. 6. PU 3-1/2" DP and overshot and casing scraper to polish top of tubing stub (9028'md). 7. Change out 9-5/8" packoff and test to 5000 psi. 8. RU slickline. Run Junk basket/gauge ring for new 9-5/8" packer down to top oftubing stub. 9. RU Eline. Run USIT log on 9-5/8" interval (9059' - surface). Check for casing damage and cement quality. 10. Run 4-1/2",12.6# 13CR-80 Vam Top completion 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at ~8989' MD. Install new packoff. Space out TTail with custom overshot on tubing stub. Screw in lock down screws. Circulate inhibited 8.7 ppg NaCl lof2 2/26/20074:02 PM brine into the T x IA annulus above the packer. 11. Drop ball and rod, set PKR, test tubing and annulus to 3500 psi. 12. Shear DKR valve in upper GLM. Circulate in diesel freeze protection on T and IA to 2200'. 13. Set TWC and test to 1000 psi. 14. ND BOPE. NU and test tree to 5,000 psi. Pull TWC. 15. NU 7-1116" CTD stack and test. 16. Dummy top GLM. 17. Mill Cement Ram 18. Mill 3.80" window at IO,940'and 10' of rat hole. Swap the we 19. Drill 4.125" build section and land well. 20. Drill Lateral: 3.75" OH, , with resistivity 21. Run 3-3/16" x 2-7/8" solid liner leaving TOL at 9150', 5 bbls of 15.8 ppg cmt 22. Pump primary cement leaving TOC at TOL 9150' 23. Cleanout liner 24. MCNL/GR/CCL log 25. Test liner lap to 2000 psi. 26. Perforate liner per asset instructions (~100') 27. Freeze protect well, Set BPV, RDMO Pre Rig and Rig Work for DS04-01A...will call . . . . ~7~~~" <À~ Ç>\\:)~(L\ Post-Rig Work: 1. Move wellhouse, Install production flowline, pull BPV 2. Run GLVs Mel Rixse CTD Engineer 564-5620 20f2 ~ ~, \ t'\ t \)....) () t'\ \ ~ ,~~ ~~-\- ) 2/26/2007 4:02 PM . ' .= WCBIOY I ~Lt-EAD = WCBIOY 04-01 SAFETY NOTES: CTUA TOR = AXB.SON :e. a.EV = 64' F. a.EV = ? OP= 3200' . 2182' T' CAMCO BAL-O SSSV NP, ID = 5.94" I IIIIx Angle = 33@6700' IBtLm M) = 9592' GAS LIFT MAN:JREI..S laturn lVD = 8800' 55 ST M) lVD œJ TYPE VLV LATCH PORT DATE L 3110 3108 9 OTIS LB OOI'Æ RM 16 12128f04 I 9-518" CSG, 47#, L-80, D = 8.681" 2464' -- 2 5312 5121 30 OTIS LB OOI'Æ RM 16 12128f04 3 6641 6268 33 OTIS LB DMV RO-5 0 4 7249 6188 29 OTIS LB DMV RO-5 0 5 7585 7084 28 OTIS LB DMV RO-5 0 6 7923 7381 29 OTIS LB SO !\OM: 28 \13-318" CSG, 72#, N-SO, ID = 12.347" 2886' µ ~7 8259 7õl7 28 OTIS LB DMV RO-5 0 8 8602 7983 27 OTIS LB DMY RO-5 0 9 8941 8288 26 OTlSLB DMY RO-5 0 17" TBG, 26#, L-BO, .0383 bpf , ID = 6.276" 3009' H 7" X 5-112" XO I ) ~ 3009' Minimum ID = 4.45'" @ 9171' , 9069' 5-112" BAKER SEAL ASSY I 5-112'" OTIS XN NIPPLE . Z ~ 9083' 9-518" X 5-112" BAKER FB-1 PKR I . I 9171' 5-112" OTIS XN NO-GO NIP, ID = 4.45" I I 5-112" TBG, 17#, L-BO, .0232 bpf , D = 4.892" 9184' 9183' 5-112" BAKER SHEA ROUT SUB I ÆRFORA TION SUMMARY I 9184' H 5-112" TUBING TAIL I REF LOG: BHCS ON 12J27nD I 9183' H B..MD TT LOGGED 08113190 I ANGLE A T TOP PERF: 28 @ 9371' Note: Refer to A'oduction œ for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 9371 - 9379 C ælO9I97 -= 9246' H TOP OF SAND CAP 03124/05 I 3-318" 4 9404 - 9402 5 11/15193 3-318" 2 9417 - 9446 5 11/15193 3-318" 6 9425 - 9445 C 12/06f93 3-318" 4 9429 - 9457 S 11/15193 9394' H TOP OF CEMENT CAP 12103104 I 3-3/8" 0.5 9479 - 9499 5 02124190 3-318" 6 9507 - 9514 C 12/06f93 3-318" 2 9507 - 9519 S 02124190 3-318" 0.125 9512 - 9536 5 02124190 9429' TOP OF 20140 SAND CAP 12/03104 I 3-318" 0.5 9556 - 9577 5 02124190 3-318" 6 9570 - 9578 C 12/06f93 2-7/fJ' 4 9õZT - 9647 5 02124190 2-7/fJ' 4 9642 - 9662 5 02124190 2-7/fJ' 4 9666 - 9678 5 02124190 H BOTTOM OF SAND CAP I 3-3/8" 1 9681 - 9695 S 11/15193 9674' 2-7/fJ' 4 9682 - 9721 S 02124190 3-3/8" 4 9695 - 97æ 5 11/15193 I 3-318" 4 9708 - 9728 5 11/15/93 PBTD H 9848' I 9-518" LNR, 47#, SOO-95, .0732 bpf, D = 8.681" 9747' DATE REV BY CONtÆNTS DATE REV BY COWÆNTS PRUDHOE BAY UNIT 01/10171 OIIGlNAL COMPLErION 12103J04 KEY ITLP SAND CAP / caerr CAP W8..L: 04-01 07107190 LAST WORKDVER 12108105 DAVITLP MN. Ð & OPEN PERF CORRECT. PERMT No: 1700420 05f31101 RHtIh CORRECTIONS 12128104 RAcm..P GLV ClO APlI\b: 50-029-20078-00 11123J02 ?fTP MNMJM ID CORRECTION 03124105 KEY ITLH SAND CAP SEC 34, T11 N, R15E. 3815.26' Fa. & 3818.38' FIlL 08116104 M..I"rn.p ADD PERFS FROM 12106J93 11108104 JLWfTlP WAIVER SAFETY NOTE BP Exploration (Alaska) I\¡[;B!OY I\¡[;B!OY REF LOG: SHCS ON 12f27no ANGLEATTOPÆRF: 28 @9371' Note: Refer to Production DB for historical perf dam SIZE 3-318" 3-:318" 3-318" 3-3/8" 3·318" 3-318" 3-3/8" 3-318" 3-318" 3-318" 3-318" 2-718" 2-718" 2-718" 3-3/8" 2·7/8" 3-318" 3-318" - 6 4 2 6 4. 0,5 6 2 0.125 0.5 6 4 4 4 1 4 4 4 INTERVAL 9371 - 9379 9404 - 9402 9417 - 9446 9425 - 9445 9429 - 9457 9479 - 9499 9507 - 9514 9507 - 9519 9512 - 9536 9556 - 9577 9570 - 9578 9627 - 9647 9642 - 9662 9666 - 9678 9681 - 9695 9682 - 9721 9695 - 9109 9708 - 9728 Roo p" R;g and R;g Wnckfoc D804-01 A...WI¡ . Thanks Mel, I am sending the sundry to be finalized. By copy of this email, you have approval to move ahead with the pre-rig work. Tom Maunder, PE AOGCC SCANNED MAR 0 1 2007 Rixse, Mel G wrote, On 2/26/2007 4: 16 PM: Tom, Thanks for your quick response. Terrie Hubble wi!! make sure this all gets properly placed in your approved Sundry and we don't go out with anything else. Mel From: Thomas Maunder (mailto:tom maunder@admìn.state.ak.us] Sent: Monday, February 26, 2007 4:02 PM To: Rixse, Mel G Subject: Re: Pre Rig and Rig Work for DS04-01A...will call Mell, Here is your note. I have separated the proposed operations into sundry and permit to drill. Essentially we (the worker bees) consider all work done prior to exiting the casing to be done in the existing well bore. We look at the exit as being the spud of the sidetrack or lateral. Hope this helps. Tom Maunder, PE AOGCC Rixse, Mel G wrote, On 2/26120073:39 PM: ,,'....... 1. 0 ck the tubing hanger and IC casing hanger lock do ews for free movement. Completely out and check each lock down screw fo eakage (check one at a time). PPPOT - T & IC. 2. S Drift 7" x 5-1/2" tu . tail. 3. S 4. C 5. C 6. C Set 17#/ 9184 'M 7. 0 erform MIT-IA to 3000 psi Run SCMT (CBL) to assure existing 7" x 5-1/2" tubing has no external bac 10f3 3/2/2007 8:20 AM ," STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION ECEIVED REPORT OF SUNDRY WELL OPERATIONS MAY 107005 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D Repair WellD Pull Tubing D Operation Shutdown D Pluç Perforations[K] Perforate New Pool 0 Perforate 0 Stimulate 0 Ala$;k!~ lM G~she~. Commissinl WaiverD Time E'I\wtt\~~ Re-enter Suspended Well rf 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development Œ] ExploratoryD 5. Permit to Drill Number: 170-0420 6. API Numbe 50-029-20078-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.00 8. Property Designation: ADL-028324 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: 04-01 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 9790 feet true vertical 9038.6 feet Plugs (measured) None Effective Depth measured 9246 feet Junk (measured) None true vertical 8558.8 feet Casing Length Size MD TVD Burst Collapse Conductor 823 20" 94# H-40 30 853 30.0 853.0 1530 520 Conductor 332 20" 133# K-55 853 - 1185 853.0 - 1185.0 2320 1500 Production 2709 9-5/8" 43.5# SOO-95 5551 - 8260 5327.8 - 7677.8 7510 4130 Production 1495 9-5/8" 47# N-80 8260 - 9755 7677.8 - 9007.7 6870 4760 Production 3070 9-5/8" 40# SOO-95 2481 - 5551 2481.0 - 5327.8 6820 3330 Production 2464 9-5/8" 36# L-80 25 - 2489 25.0 - 2489.0 5120 2370 SURFACE 1158 13-3/8" 72# N-80 28 - 1186 28.0 - 1186.0 4930 2670 SURFACE 1504 13-3/8" 72# N-80 1182 - 2686 1182.0 - 2685.9 4930 2670 Perforation depth: Measured depth: All perforations below sand plug True vertical depth: All perforations below sand plug SCANNED MAY .1 1 2005 Tubing ( size, grade, and measured depth): 7" 26# L-80 7" 29# L-80 7" 26# L-80 @ 22 @ 2146 @ 2156 2146 2156 2172 Packers & SSSV (type & measured depth): 5-112" Baker FB-1 Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: @ 9063 RBDMS BFl MAY 1 1 2005 13 Prior to well operation: Subsequent to operation: Oil-Bbl 219 Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 27 0 702 Well Shut-In 490 Tubing Pressure 2178 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ! 15. Well Class after proposed work: Exploratory 0 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ] Service D Signature Garry Catron Garry Catron )j~ r~ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Phone 564-4657 Date 5/6/05 Form 10-404 Revised 4/2004 l) ¡.-\ ! G I r~ A I 04-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/21/05 Sand plug set @ 94921-9492.51 03/23/05 T/I/O=1820/1750/300 ASSIST COIL UNIT WITH WELL KILL FOR SAND PLUG JOB. BLEEDING DOWN lAP CONTINUED TO 3-24-05 03/24/05 Sand plug set @ 92461.94181 03/25/05 Sand plug set @ 92461-9261' FLUIDS PUMPED BBLS 122 60/40 Methonal/Water 230 Diesel 462 1 % KCL 15 Fresh Water 5 Clean Gel 834 TOTAL Page 1 MCEVOY MCEVOY ,."".,.,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, AXELSON 64' TREE = WËLLHEA 0 = ÄCrUÄrÒR; .."..", """" ' '" ",. KB. ELEV = ~""...,..,...".,.",."..,..",..,. BF. ELEV = KõP;-"~M-"~M"-'~"'-32ÕÕ;' ~ax~~rïglë·.·~..····._.~.~~®'.6!þ~' Datum MD = 9592' ·ÖaiumTVO; . ... ... ·sábO'SS 2162' l-i 7" CAMCO BAL-O SSSV NIP, ID = 5.94" 1 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LA TCH PORT DATE 1 311 0 31 08 9 OTIS LB DOME RM 16 12/28/04 2 5312 5121 30 OTIS LB DOME RM 16 12/28/04 3 6641 6268 33 OTIS LB DMY RO-5 0 4 7249 6788 29 OTIS LB DMY RO-5 0 5 7585 7084 28 OTIS LB DMY RO-5 0 , 6 7923 7381 29 OTIS LB SO NONE 28 7 8259 7677 28 OTIS LB DMY RO-5 0 8 8602 7983 27 OTIS LB DMY RO-5 0 9 8941 8288 26 OTIS LB DMY RO-5 0 3009' l-i 7" X 5-1/2" XO 1 9059' l-i 5-1/2" BAKER SEAL ASSY 1 9063' l-i 9-5/8" X 5-1/2" BAKER FB-1 PKR 1 9171' l-i 5-1/2" OTIS XN NO-GO NIP, ID = 4.45" 1 9183' l-i 5-1/2" BA KER SHEA ROUT SUB 9184' l-i 5-1/2" TUBING TAIL I 9163' 1-1 ELMD TT LOGGED 08/13/90 04-01 - 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 2464' -- L 113-3/8" CSG, 72#, N-80, ID = 12.347" l-i 2686' µ \7" TBG, 26#, L-80, .0383 bpf , ID = 6.276" l-i 3009' Minimum ID = 4.45" @ 9171' 5-1/2" OTIS XN NIPPLE 1 5-1/2" TBG, 17#, L-80, .0232 bpf , ID = 4.892" l-i 9184' PERFORA TION SUMMARY REF LOG: BHCS ON 12/27/70 ANGLE AT TOP PERF: 28 @ 9371' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 9371 - 9379 C 09/09/97 3-3/8" 4 9404 - 9402 S 11/15/93 3-3/8" 2 9417-9446 S 11/15/93 3-3/8" 6 9425 - 9445 C 12/06/93 3-3/8" 4 9429 - 9457 S 11/15/93 3-3/8" 0.5 9479 - 9499 S 02/24/90 3-3/8" 6 9507 - 9514 C 12/06/93 3-3/8" 2 9507 - 9519 S 02/24/90 3-3/8" 0.125 9512 - 9536 S 02/24/90 3-3/8" 0.5 9556 - 9577 S 02/24/90 3-3/8" 6 9570 - 9578 C 12/06/93 2-7/8" 4 9627 - 9647 S 02/24/90 2-7/8" 4 9642 - 9662 S 02/24/90 2-7/8" 4 9666 - 9678 S 02/24/90 3-3/8" 1 9681 - 9695 S 11/15/93 2-7/8" 4 9682 - 9721 S 02/24/90 3-3/8" 4 9695 - 9709 S 11/15/93 3-3/8" 4 9708 - 9728 S 11/15/93 I PBTD l-i 9648' 9-5/8" LNR, 47#, SOO-95, .0732 bpf, ID = 8.681" l-i 9747' DATE 01/10/71 07/07/90 05/31/01 11/23/02 08/16/04 11/08/04 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOV ER RHltlh CORRECTIONS ?rTP MINIMUM 10 CORRECTION MLH/TLP ADD PERFS FROM 12/06/93 JLWITLP WAIVER SAFElY NOTE DATE 12/03/04 12/08/05 12/28/04 03/24/05 , ~ z ~ ! l I~ REV BY COMMENTS KEY /TLP SAND CAP / CEMENT CAP DA V ITLP MIN. ID & OPEN PERF CORRECT. RAClTLP GLV C/O KEYITLH SAND CAP SAFETY NOTES: 9246' l-i TOP OF SAND CAP 03/24/05 1 9394' l-i TOP OF CEMENT CA P 12/03/04 1 9429' l-i TOP OF 20/40 SAND CAP 12/03/04 1 9574' l-i BOTTOM OF SAND CAP I PRUDHOE BAY UNIT WELL: 04-01 PERMIT No: "1700420 APt No: 50-029-20078-00 SEC 34, T11 N, R15E, 3815.26' FEL & 3818.38' FNL BP Exploration (Alaska) 04-01 (PTD # 1700420) Classified as Problem Well ) Subject: 04-01 (PTD #1700420) Classified as Problem Wen . Frpm: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> D,t~.:_~~, O? ~o~ 2?0~~1~~~!~~~~?9?0, .~-_. .--~-- ~~'- .~~~ -WI( - fnj.=t '7()-~ .. All, Well 04-01 (PTD #1700420) has been found to have sustained casing pressure on the IA after being secured by TTP. The TIOls on 11/06/04 were 1140/2150/60/0. The plan forward for this well is as follows: 1. SL: Set TTP - DONE 2. DHD: Bleed WHPs < 300 psi - DONE, well not secured 3. SL: Pull TTP 4. CT: Sandback A wellbore schematic has been included for reference. «04-01.pdf» The well has been classified as a Problem well. Please questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 call if you have any SCANNED NO\J 2, 920011. Content-Description: 04-01.pdf Content-Type: application/octet-stream Content-Encoding: base64 frec;s(}æ~ T \Ab¡~ ~ O,~ SCf ~f 4~~ ~ft;Y¡,if 6t~~$)~ \/\\ or 'fl? - Zl5U bV18t5D 2:i:Ýlz- ./ () t:)Y&J 24-Z.- \ ~ frodJ.l~}( ck.--hbeJ- wû4- Zc¿60 bL.,1 \4d~ bb\ '$ ~lS <6 ~ - ~K \41, ~ Z4- .~ J w~~ ~~ ')DPt 7GÐ4 C'~~~ ~ 1 of 1 11/8/2004 11 :14 AM ) lREE = WELLHEA D = 'ACTUÄ Tö R; . KB. B..Bi ;. .. ... WB..EV = KOP= flAax ,:\~.~.Ie .= [Sturn MD = 'DiiÙïm ïV b ; ... MCEV OY MCEVOY "AxELsc>"t~j ... . 64' ? 3200' ...33 (gJ .6.7o.~.: 9592' ... áãö"ëjïSS 19-5/8"CSG, 47#, L-80, 10=8.681" 1-1 2464' 113-3/8" CSG, 72#, No80, 10= 12.347" H 2686' IT' lBG, 26#, L-80, .0383 bpf , 10 = 6.276" H 3009' Minimum ID = 3.95" @ 2162' 7" CAMCO 0 SSSV 15-112" lBG, 17#, L-80, .0232 bpf, 10= 4.892" l-t 9184' PERF ORA llON SUlllMA. RY REF LOG: BHCS ON 12/27170 ANGLEA TTOP PERF: 28 @ 9371' Note: Refer to A"oduction DB for historical perf data SIZ E S R= IN1£RV A L OpnlSqz OA 1£ 3-3/8" 6 9371 - 9379 0 09/09/97 3-3/8" 4 9404 - 9402 S 11/15/93 3-3/8" 2 9417 - 9446 S 11/15/93 3-3/8" 6 9425 - 9445 0 12/06/93 3-3/8" 4 9429 - 9457 S 11/15/93 3-3/8" 0.5 9479 - 9499 S 02/24/90 3-318" 6 9507 - 9514 0 12/06/93 3-318" 2 9507 - 9519 S 02/24/90 3-3/8" 0.125 9512 - 9536 S 02/24/90 3-3/8" 0.5 9556 - 9577 S 02/24/90 3-3/8" 6 9570 - 9578 0 12/06/93 2-718" 4 9627 - 9647 S 02/24/90 2-718" 4 9642 - 9662 S 02/24/90 2-7/8" 4 9666 - 9678 S 02/24/90 3-3'8" 1 9681 - 9695 S 11/15/93 2-718" 4 9682 - 9721 S 02/24/90 3-3/8" 4 9695 - 9709 S 11/15/93 3-3/8" 4 9708 - 9728 S 11/15/93 I PBTO H 9648' 19-518" LNR, 47#, 800-95, .0732 bpf, 10= 8.681" H 9747' [}!), 1E REV BY COMNENTS 01/10171 ORlG~AL COMPLETION 07/07/90 LAST WORKOVER 05/31/01 RH/tlh CORRECllONS 11/23/02 ?/lP MINlMUIIIIO CORRECTION 02/14/03 JMP/KAK WAIVER SAFETY NOTE 08116/04 MLHIll.P AOO FERFS FROM 12/06/93 DATE REV BY 04-01 8 L -.J \ I ) SAFETY NOTES: ***T X IA COMM. MAX lAP = 2500 PSI; MAX OAP = 1000 PSI (02114/03 WAIVER)*** 2162' 1-17" CAMCO BA L-O SSSV NIP, 10 = 5.94" I GAS LIFT MANDRELS DEV lY FE V LV LATCH PORT DA.1£ 9 OTIS LB RO-5 30 OTIS LB RO-5 33 OTIS LB RO-5 29 OTIS LB RO-5 28 OTIS LB RO-5 29 OTIS LB BROKEN 28 OTIS LB RO-5 27 OTIS LB RO-5 26 OTIS LB INTGRL ST MO TVO 1 3110 3108 2 5312 5121 3 6641 6268 4 7249 6788 5 7585 7084 .. 6 7923 7381 a 7 8259 7677 8 8602 7983 9 8941 8288 3009' l-f 7" x 5-1/2" XO I ~ ~ 9059' 1-1 5-1/2" BAKER SEA.L ASSY I :8: ~ 9063' 1-1 9-5/8" x 5-1/2" BAKER FB-1 PKR 1 j l 9171' 1-1 5-1/2" OTIS XN NO-GO NIP, 10 = 4.45" I 9183' 1-1 5-1/2" BAKER SHEA ROUT SUB I 9184' l-t 5-1/2" TUBING TAIL I 9163' H ELIVD TT LOGGED 08/13/90 1 COMfÆNTS PRUDHOE BAY U'Jrr V'ÆLL: 04-01 PERMT 1'«>: 1700420 APII'«>: 50-029-20078-00 SEC 34, T11 N, R15E, 3815.26' FEL & 3818.38' FNL 8P Exploration (Alaska) Problem Well Notification: 04-01 (PTD #1700420) ') Subject: Problem Well Notification: 04-01 (PTD #1700420) From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Fri, 15 Oct 200421 :29:54 -0800 T~:' "Harris, Marvin L (CONOeO)" <h~ITml@ap.com>, "GPB, FS2TL" <GPBFS2TL@BP.cóm>, "Rp.ssberg,R Steven" <RossbeRS@BP.com>,."NSU,ADW:v.¡ellOperationsSupervisor'" . '. <1iSUADWWeIlOperationsSuperVisor@BP.com>,"GPB,Wells Opt Eng" . .. ".'...... <QPBWellsOptEng@BP.com>, "AOGCC"Jim}<egg (E~DJàil)1t <jim~regg@aclmin:~tate.ak~us>, "ADGCC' Winton Aubert (E-mail)..<winton~aubert@admin.state.ak.us>~ "NSU; ADW WL &' .'. Co.1l1pletion Supervisor" '<NSUADWWL&CompletionSupervisor@BP;com>,"GPB;:FS2 DS Ops. Le~d" <GPBFS2DSOpsLead@ap.com>, "dPB, Ops':Mgr" .<GPBOps~Mgr@BP.c6m> ,.. . ..:.. .' .... . ce.: "NSU, ADW.Well Integrity Engineer" <NSUAD.WWellIntegrityEngineer@BP.com>;"Reeves, Dcjnald.P" <ReevesDf@BP.com> .. :. . .. . ... . . ) All, Well 04-01 (PTD #1700420) has sustained casing pressure on the IA and the well has been classified as a Problem well. The well is currently waivered for TxIA communication and failed a NFT-IA for annual waiver compliance. TIOIS on 10/12/04 were T/I/O = 2310/2260/340. The plan forward for this well is as follows: 1. DHD: NFT-IA - FAILED 2. SL: Pull DSSSV, caliper Tubing, re-set DSSSV. 3. DHD: NFT-IA Attached is a wellbore schematic. Please call if you have any questions. «04-01.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943 -1154 Pager: (907) 659-5100, xl154 Email: NSUADWWelIInteg-rityEngineer@bp.com Content-Description: 04-01.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCANNED 02 2DD4 1 of 1 10/20/2004 3: 17 PM ) lREE = MCEV OY WELLHEA D= MCEVOY ÄCTÜÄ'i6R:..;m. Ä")(E[SÖÑ 'Ks, ELËV~';- -....--- -64' mSF-:-ELEV ;'''---7 KOP= 3200' - . . .~~.~.~.QI~.::::.... ..33....~m~.!.0~.: Datum MD = 9592' "Datum iV"1S ,.;m. ""'Š80Ö;S"S 19-5/8" CSG, 47#, L-80, ID = 8,681" 1-1 2464' 113-3/8" CSG, 72#, N-80, ID = 12.347" 1-1 2686' 17" lBG, 26#, L-80, ,0383 bpf , ID = 6.276" 1-1 3009' Minimum ID = 3.95" @ 2162' 7" CAMCO 0 SSSV 15-112" lBG, 17#, L-80, .0232 bpf, ID= 4,892" 1-1 9184' PERFORA 1l0N SUV11\N\ RY REF LOG: BHCS ON 12/27/70 ANGLEA TTOP PERF: 28 @ 9371' Note: Refer to A"oduction DB for historical perf data SIZ E SA= INlERV A L OpnlSqz DA 1£ 3-3/8" 6 9371 - 9379 0 09/09/97 3-3/8" 4 9404 - 9402 S 11/15/93 3-3/8" 2 9417 - 9446 S 11/15/93 3-3/8" 6 9425 - 9445 0 12/06/93 3-3/8" 4 9429 - 9457 S 11/15/93 3-3/8" 0,5 9479 - 9499 S 02/24/90 3-3/8" 6 9507 - 9514 0 12/06/93 3-3/8" 2 9507 - 9519 S 02/24/90 3-3/8" 0.125 9512 - 9536 S 02/24/90 3-3/8" 0.5 9556 - 9577 S 02/24/90 3-3/8" 6 9570 - 9578 0 12/06193 2-7/8" 4 9627 - 9647 S 02/24/90 2-7/8" 4 9642 - 9662 S 02/24/90 2-7/8" 4 9666 - 9678 S 02/24/90 3-3/8" 1 9681 - 9695 S 11/15/93 2-7/8" 4 9682 - 9721 S 02/24/90 3-3/8" 4 9695 - 9709 S 11/15/93 3-3/8" 4 9708 - 9728 S 11115/93 IpBTD H 9648' 19-518" LNR, 47#,000-95, .0732 bpf, ID= 8.681" H 9747' D\lE REV BY COMWENTS 01/10/71 ORIGINAL COMPLErION 07/07/90 LAST WORKOVER 05/31/01 RH/Uh CORRECllONS 11/23/02 ?/lP MINIMUV1ID CORRECTION 02/14/03 JIVP/KA K WAIVER SA FETY NOTE 08116/04 MLHnLP AOO F£RFS FROM 12/06/93 DATE REV BY 04-01 8 L ~ \ ! ") SAFETY NOTES: ***T X IA COMM. MAX lAP = 2500 PSI; MAX OAP = 1000 PSI (02/14/03 WAIVER)*** 2162' 1-I7"CAMCOBAL-0 SSSV NIP,ID=5,94" I GAS LIFT MANDRELS DEV 1Y Æ V LV LATCH PORT D\ 1£ 9 OTIS LB RO-5 30 OTIS LB RO-5 33 OTIS LB RO-5 29 OTIS LB RO-5 28 OTIS LB RO-5 29 OTIS LB BROKß\I 28 OTIS LB RO-5 27 OTIS LB RO-5 26 OTIS LB INTGRL ST MD TVD 1 3110 3108 2 5312 5121 3 6641 6268 4 7249 6788 5 7585 7084 .. 6 7923 7381 . 7 8259.7677 8 8602 7983 9 8941 8288 3009' 1-1 7" X 5-1/2" XO I , ~ 9059' 1--1 5-1/2" BAKERSEALASSY I ~ ~ 9063' l-i 9-5/8" X 5-1/2" BAKER FB-1 PKR I ! l 9171' 1-1 5-1/2" OTIS XN NO-GO NIP, ID = 4.45" I 9183' H 5-1/2" BAKER SHEA ROUT SUB I 9184' 1-1 5-1/2" TUBING TAIL I 9163' H ELM:> TT LOGGED 08/13/90 I COMM::NTS PRUDI-OE BAY LNrr VVELL: 04 -01 PERMT f'o.b: 1700420 API f'o.b: 50-029-20078-00 SEC 34, T11 N. R15E, 3815.26' FEL & 3818.38' Ff'L BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown m Stimulate~ Plugging __ Perforate _X Pull tubing__ Alter casing :2' Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 64' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagmpic__ Anchorage, AK 99510-0360 Se~ce__ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number:. 1327' FNL, 295' FEL, Sec 34, T11N, R15E, UM. 4-01 At top of productive interval: 9. Permit number/approval number: 1672' FSL, 1448' FWL, Sec 35, T11N, R15E, UM. 70-42 At effective depth: 10. APl number: ' !1467' FSL, 1508' FWL, Sec 35, T11N, R15E, UM. 50-029-20078 At total depth: 11. Field/Pool: 1449' FSL, 1513' FWL, Sec 35, T11N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary ' Total Depth: measured 9790 feet Plugs (measured) PBTD Tagged at 9591' MD (9/4/97). true vertical 9039 feet Effective Depth: measured 9591 feet Junk (measured) true vertical 8863 feet Casing Length Size Cemented Measured depth True vertical depth Structural 115' 30" Cement to Surface 115' 115' Conductor 1121' 20" 1030 Sx Fondu 1185' 1185' Surface 2622' 13-3/8" 1305 Sx Fondu & 2686' 2686' 485 Sx Class G Production 9685' 9-5/8" 970 Sx Class G & 9749' 9002' 100 Sx Fondu Perforation Depth measured 9371 - 9379'; 9425 - 9445'; 9507 - 9514'; 9570 - 9578 true vertical 8669 - 8676'; 8717 - 8734'; 8789 - 8795'; 8845 - 8852' Tubing (size, grade, and measured depth)7", 26~, L-S0, IPCT (~ 3009' MD; 5.1/'Z', 17#, L.80, IPCT {~[~)~ 9184, MD. Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 9063' MD; 7" Camco Bal-O S88V @ 2162' MD. ~ ~:C) .~ ~. \';3.32 13. Stimulation or cement squeeze summary treated (measured) see attached Intervals Intervals treated (measured) 1'4. Representitive Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1345 25948 6580 1384 Subsequent to operation 1905 39801 3872 1901 _ 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ _ Daily Report of Well Operations_X Oil _X Gas ~ Suspended ~ Service 117. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~gned '~,~.~/ ~,'~ ~ ~ Title: Engineering Supervisor Date , Form 10-404 Rev 06/15188 SUBMIT IN DUPLICATE o 0 r c' 0 0 0 '.,7. 0 29. , ~30. ,GEOLOGiC ' ' ' ' . ' RI~IATION TESTS / . NAME . Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9296' 8603' N/A Bottom S.~dleroch~t , . 975Z~' 9007' · ~ ' ' , '"' /' ': . ; ," '~ , I"~ , ' ~ . ,, , ~ , ~, , , '\,~ ,'~.~ 31. LIST OF ATTACHMENTS 32. I hereby certify that th~ foreg0l~g is true and Correct to'thebest of my' knowledge' ' ' · . " Sign ' Title Opt. Engr. Mslr, 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. I, tem 1: Classification_ of Service Wells: Gas injection, water injection, steam ....... 'inj~ctmn,' mr""mject~on, ........... salt water disposals, :wate~ supply for injection; Observati:on, injection for ms~tu cornbustl6n. 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 separ~{~ form for ea~h:addition'gl'~lnterval to be separately produced, shoWing'the data pertinent:~o 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". 4-01 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 914/97: RIH & tagged PBTD at 9591' MD. 919197: MIRU & PT equipment. RIH w/perforating gun & shot 8' of add perforations as follows: Added perforations: 9371 - 9379' MD (Z3) Ref. Log: BHCS 12/27/70. Used a 3-3/8" carder & shot the perforations at 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Rigged down. Returned the well to production & obtained a valid welltest. ALASK.(,,~ STATE OF ALASKA 'AND GAS CONSERVATION (~' /IISSION REPORT SUNDRY WELL OPi:.RATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well O~er X 5. Type of Well Development Exploratory Stratigraphic 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1327' FNL & 295' FEL, Sec 34, T11N, R15E, UM. At top of productive interval 1672' FSL & 1448' FWL, Sec 35, T11N, R15E, UM. At effective depth 1467' FSL & 1508' FWL, Sec 35, T11N, R15E, UM. At total depth 1449' FSL & 1513' FWL, Sec 35, T11N, R15E, UM. 6. Datum of elevation(DF or KB) 64' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-1 9. Permit number/approval number 70-42 10. APl number 50 - 029-20078 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9790 feet 9039 feet Plugs(measured) PBTD Tag @ 9577' MD (6/18/95) Effective depth: measured 9577 feet true vertical 8851 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Structural 115' 30" Cemented to Surface 115' 115' Conductor 1121' 20" 1030 Sx Fondu 1185' 1185' Sudace 2622' 13-3/8" 1305 Sx Fondu & 485 Sx CIG 2686' 2686' Production 9685' 9-5/8" 970 Sx CIG & 100 Sx Fondu 9749' 9002' Perforation depth: measured 9425 - 9445'; 9507 - 9514'; 9570 - 9578' true vertical 8717 - 8734'; 8789 - 8795'; 8845 - 8852' Tubing (size, grade, and measured depth) 7", 264¢, L-80, IPCT @ 3009' MD; 5-1/2", 17#, L-80, IPCT @ 9184' MD. Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 9063' MD; 7" Camco BaI-O SSSV @ 2162' MD. 13. Stimulation or cement squeeze summary ~~"i V ~.,D Intervals treated(measured) see Attached Treatment description including volumes used and final pressure ,lAN 1 6 1 96 Alaska 0il & Gas Cons. Commission 14. PriOr to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2085 17605 10897 -- 2064 13293 12172 -- .,~chorage Tubing Pressure 366 357 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil~ Gas ~. Suspended ..._ Service 17. I hereby certify that the fo~and correct to the best of my knowledge. Signe Title Engineering Supervisor Form ~,~4 Rev 06/15/88 AJB cc: JWP, KZ. SUBMIT IN DUPLICATE ,~ 4-1 DESCRIPTION OF WORK COMPLETED 13-3/8" ANNULUS CEMENT SQUEEZE 12/14/95: Loaded the wellbore w/Crude, then RIH & set a PXN plug in the 5-1/2" tubing tail at 9162' MD. PT tubing to 2500 psi; OK. Rigged down. 12/15/95: A 13-3/8" Annulus Cement Squeeze was performed as follows: MIRU & PT equipment. Loaded the 13-3/8" annulus w/Hot Seawater, then pumped 194 bbls of Arctic Set I Cement w/0.25 lb per sack Cellophane & 20 ppb Aggregate, to down squeeze the 13-3/8" annulus. Briefly attained 1700 psi maximum squeeze pressure, then pressure broke back to 300 psi. Hesitated squeeze up to a 600 psi final squeeze pressure following several additional pressure breaks, and held for one hour. Rigged down. 12/17/95: RIH & retrieved the PXN plug from the tubing tail. Returned the well to production & obtained a valid welltest. JAN 1 6 Alaska Oil & Gas Cons. Commission Anchor~e GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9602 L. Company: 7/31/9 5 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive . Anchorage, AK 99501 Well Job # Log Description Date Field: ·,.'~'., . Prudhoe Bay · BL RF Sepia DIR MWD Floppy Disk D.S. 1-3 -7/~) ~ ~ LEAK DETECTION 950712 I ~' 1 D.S. 1-33 "'~'~2~ -~ ~¥- PRODLOG : 950710 I 1 D.S. 3-34A , I INJEC PRORLE 950711 1 1 D.S. 4-01 "~/1 (~L~ ~ PRODLOG 950710 ",'1 1 D.S. 16-21 ~ ~ ~ ~ BAKER INFLATABLE 950712 ':1 1 D.S. 16-29A ~Z,- (:)~'o (:~ PERFRECORD 95071 2 1 · 1 · D.S. 18-3A ~"/./. / /~ ,,~ DUAL BURST TDT-P 950710 1' 1 D.S. 18-3A / --/ / U ~-- PRODPRORLE 950708 I '," 1 D.S. 18-18A ~ O ! ~-~ DUAL BURST TDT-P 950707 I ' 1 .. , : , . · SIGN ~ Please<~ign and return one copy of this transmittal to Sherrie at the above address. Thank you. Drill Site: 4 Well: 1 Fri Apr 15 14:39:56 1994 K-VALVE DESIGN DOME SET PRESSURE: FTP @ CLOSE (PSIG): K-VALVE CLASS (A, B, C ): 285 PSIG @ 60 DEG F 244 PSIG B COMMENTS: K-valve is designed to test in situ. Well may h~ve to be choked back to keep the valve open. When CLP is high, flow may have ko be restricted to test 4-01. ~esting to a SI well or tank may not work due to CC:Engineering File PRB 24 (WITH ATTACHMENTS) J.C. SMART / M.G. SHOEMAKE (WITHOUT ATTACHMENTS) R.A. WELLS / K.L. BLACKBURN (COVER ONLY) PRB 2O PRB 14 J.R. Versteeg ATO 1505 (WI' DESIGNED BY: A.W. Brooks Oil ~ ~a~ Co~s. .~CO Alaska, Inc. te: ~bject: sm/Location: *!ephone: /Location: P.O. Box 100360,(-~horage, AK /, Mar 15,~ 1994 Transmittal #: 04029 ~_ John E. DoOroy/ATO-1520 (907) 263-4310 Distribution 99510~ ~ Well Log Date Tool Type Run, Contrac~r Number (M-D-y) Scale I i~. 01-02 2-26-94 Prod/Spin/Temp/1~ 1, 5" Schlumber I 01-03 "'2-19-94 'Prod~.BS/Temp{l~'~ 1, 5" Schlumbff~" :5~, '_01-09 '3-01-94 Tubi~ Cutter ~ 1~'5" Schlumbe~' S';- 01-11 ~ ' 2-27-94' Prod Prof/Spin 1, 5" ~chlumber' j:. i,~ 01-18 2-23-94 Leak Detection l"& 5" Schlumber !' 01-25, ~ 3.06.94 1, 5" Schlumber ~4"~ . /03-20~ r ........ 2-17-94 Perf 1, 5' Schlumber ,'~03'20A 3-03-94 Dual Burst '~,~.~'~' 1, 5" Schlumber tt~'"x' ,03-32 '-' 2.26.94 Leak/Press/Temp. I 1, 2" Schlumber I.e~ 03-34A '2-24-94 P, md/Press/Temp 1, 2"&'5" $chlumbe~ ~'z. 04-01 ,2-19-94 Prod 1~ 5" $chlumber ?*"~ " 04-24 2-22-94 Pr~)d 1, 5" Schlumbe? "04-40 "2-22-94 Perf · 1, 5' t $chlumber i Jll i i I ii ~"4- 04-46 2-16-94 Rope Perf 1, 5" Schlumber I i i i J iii ii t:)~ '"i ~_04.47 2-18-94 v perf, 1, 5" .Schlumber ~0 5' $chlumber , 4.47 '2-15-94 ,,. CBT. GR u , i ~.04-4 ' 2-15-94 vCET-GR 1,5" Schlumber i i 50 Ih _05-06. i 2'11'94 Perf 1T 5' Schlumber ~7.. ~_ 05-14A 7-11-93 USIT/Cem&Corr ( ;~k~l~ 5" Schluml~er i i i et'~' 05-15A i 05-15A '~t~ ~ND/GR-L.~> ~., 1, 5" Schlum,~er~ tt"5 ! ...... 05-26 ! 3-02-94 Dual Burst ~ f 1~ 5" Schlumb?r~_ ~'z. ~i/06-15 ,, 2-21-94 Prod 1~ 5' Schlumber i i Il II ~ 06-15 2-22~94 Comp Neutron 1~., 5" Schlumb,er , 5' Schlumber 5~ 06'22A 3-01-94 Perf 1, ......... !1o 07-08 ~'3-02-94 15r:~d~ ~ 1, 5" 'Schlumber Iq~ ..07-23 . 3-07-94 Leak/$pin/Temp/~ ',i~ 1, 5" $chlumb~r' ~ . 09-34 ~2'21'94 i Tubing Cutter & c. 1, g" I $c'hluml:;e~_ 02. . ~ ~ _11 , 2-10-94 Inj Prof/5~ ~, ~ Schlumber ~ / 11-04 2-20-94 Tubing Cutter 6. :. 1~ 5' Schlumb.er ~.11-04, i .2-17-94 'Tubing {)~ ~(~.v..1, 5," Schlumb.e.~, t-'+~. 11-7ST t 3-06-94 ,,, Inj Pmf,/Spin ~. I/aL 1~.,,.5." Schlumber ~/ 11- 2125-94 LealdPres~/Temp 1, 1'&5" $cl~lumber ~ 16$T , , /s,p,,in/~t~b D-~[~ '\111' Comp/l~l~table ~6ST 3-08-94 1,5' i ,/11.17 . 2:20-94 Leal 1, 5;. SC.Number ,"~,11-17 3-08-94 Prod 1, 5" Schlumber tt.~ 11-23 . 8-09-91 ~ TMD~ 1,. 5" Hal!ibu~o~ i ~ ~. /11-24A i ~,,3,'05'94 Perf/GR/CCL 1~ 5" $chlumber .... p/Pe ~! 1-24A 2-22-94 Corn rf 1, 5" Schlumber ~;) ~ Inc. I~ · ~ d AlantleFIl~ I 12-01 ! 3-06-94 Prod ~ 1, 1'&5" Schlumber i 13-10 f 2-24-94 Perf ! 1,5' Schlumber ! 14-2B 1-16-94 CNL/GR t 1, 2'&5' Schlumber 14-2B 1-16-94 Sub-Sea ~ 1, 1"&2.' Schlumber !t14-2B 1-16-94 BI-lO. Acoustilocj/l~ 1, 2'&5' Scl{lumber Il14-2B t 1-16-94 Dual Laterlo~/eRl,~ 1, 5' S0hlumber I 14'2B I 1-19-94 Secj Bond/GR{c~, 1, 5' SchlUmber 14-2B 1-23-94 PFC/GR/CCL I 11 5" Schlumber i,.14-2B 1-23-94 PFC/Collar i 1, 5' Schlumber I 14-24 2-19-94 Leal~ t 1, 5" Schlumber 14-28 3-05-94 LeakI 1, 1"&5" Schlumber 14-34 2-15-94 Pmd/Press/Temp I 1, 2"&5" Schlumber 16-08 3-07-94 Prod Prof/Spin ~ 1, 2"&5" Schlumber 17-21 2-24-94 Perf 1, 2~&5" Schiumber PWDW 2-09-94 Water 1, 5" Schlumber _..02-01 Inj/FBS/TempI~ Well ~-~ the correct ^PI # is $0-0P~-~150~-00 Number of Records: eGrey Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon :=St~.'te-~fAiaSka '~ Mobil Please acknowledge receipt by signing and retuming a copy of transmiEal. By: .~~/~ ~~ Date: RECEIVE ~' ~,~' STATE OF ALASKA ALAS~ /IL AND GAS CONSERVATION'( ~MISSION REPORi' OF SUNDRY WELL OPmRATIONS 1. Operations performed: Operat~n shutdown .~- Stimulate --- Plugging ..-. Perforate Pull tubing Alter casing ---= Repair well ----. Other X 2. Name of Operator ARCO Alaskar Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1327' FNL & 295' FEL, Sec. 34, T11 N, R15E, UM At top of productive interval 1672' FSL& 1448' FWL, Sec. 35, T11N, R15E, UM At effective depth 1467' FSL & 1508' FWL, Sec. 35, T11N, R15E, UM At total depth 1449' FSL & 1513' FWL, Sec. 35, T11N, R15E, UM 12. Present well condition summary Total depth: measured 9790 feet true vertical 9039 feet 5. Type of Well Development X~ Exploratmlf -- StralJgraphic ~ 6. Datum of elevation(DF or KB) 64' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-1 9. Permit number/approval number 70-42 Q// ! ,10. APlnumber ~ 50 - 029-20078 ~ 11. Field/Pool ("~//~,,~, J Prudhoe Bay Oil Pool Plugs(measured) PBTI3,Tag @ 9587' MD (12/3/93) feet Effective depth: measured 9587 feet true vertical 8860 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 115' 30" to Surface 115' 115' Surface 1121' 20" 1030 sx 1185' 1185' Production 2622' 13-3/8" 2090 sx 2686' 2686' Liner 9685' 9-5/8" 1060 sx 9749' 9002' RECEIVED Perforation depth: measured 9425-9445'; 9507-9514'; 9570-9578' 1 0 1994 true vertical 8717-8734'; 8789-8795'; 8845-8852' ,,~K~ u, & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 7", L-80, tbg @ 3009' MD; 5-1/2", 17#, L-80, Tbg @ 9184' MD Packers and SSSV (type and measured depth) Baker FB-1 packer @ 9063' MD; Camco SSSV @ 2162' MD 13. stimUlation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Reoresentative Daily Averea_ e Production or In!ection D~,ta OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well oper..ati.~on 2118 18~54 15835 -- Subsequent to operation 1341 / 2874 4409 -- Tubing Pressure 433 273 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 Title Engineering Supervisor Form 10-404 8 1094/8 GSS cc: JED, JWP SUBMIT IN DUPLICATE 4-1 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZES FOR WATER & GAS SHUT OFF 11111/93: RIH & tagged bottom fill at 9701' MD. 11/14193: A CTU Cement Squeeze for Water & Gas Shutoff was performed as follows: MIRU CTU & PT equipment to 4500 psi. Loaded the wellbore w/Seawater, then RIH w/CT pumping 1% KCl Water, followed by 27 bbls Neat Latex Acid Resistive Cement, followed by 48 bbls Latex Acid Resistive Cement w/0.5% (by weight of cement) 12 mm polypropylene fibers, followed by 2 bbls Neat Latex Acid Resistive Cement, to squeeze the perforations located at: 9405 - 9406' MD (Z4) 9418 - 9458' MD (Z3/2) 9682 - 9721' MD (ZIB) Ref. Log: BHCS 12/27/70. Placed all 77 bbls of cement pumped behind pipe without attaining any significant squeeze pressure. Contaminated cement & jetted wellbore clean down to 9600' MD. POOH w/CT. Rigged down.' 11115193: A CTU Cement Resqueeze for Water & Gas Shutoff was performed as follows: MIRU CTU & PT equipment to 4000 psi. Loaded the wellbore w/Seawater, & RIH w/CT to tag bottom at 9674' MD. Pumped 50 bbls Latex Acid Resistive Cement, to resqueeze the perforations (above). Placed 13 bbls of cement behind pipe at 2000 psi maximum squeeze pressure, held for 90 minutes. Pressure broke back from 2000 psi, & pressure had to be hesitated twice in 15 minute increments, to regain a sustainable 2000 psi squeeze pressure. Contaminated cement & jetted wellbore clean down to 9595' MD. Left a cement plug in the wellbore below 9595' MD. POOH w/CT. Rigged down. 1212193: MIRU CTU & PT equipment. RIH w/CT milling assembly & milled through cement bridges from 9015' to 9070' MD. Tagged PBTD at 9580' MD. POOH w/milling tools. Rigged down. 1213193: RIH & tagged top of cement plug at 9587' MD. 1216193: Reperforated: 9425 - 9445' MD (Z3) 9507 - 9514' MD (Z2) 9570 - 9578' MD (Z2) Ref. Log: BHCS 12/27/70. Returned the well to production w/liftgas & obtained a valid welltest. Note: Oil rate decreased by 777 BOPD, but the decrease in the gas rate provided an incremental rate benefit of 1558 BOPD, resulting in a net oil benefit of 781 BOPD. RECEIVED FEB 1 0 1994 Uil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-3-94 REFERENCE: ARCO CASED HOLE FINAI~ 79-5'~ _1-11 12-18-93 CNL (Cfi] 1 ~?..2.c---i c.~0 Run 1, 5" ?-2~-q !-18 12-12-93 LeakDetect}<.t~}T~nt~'/~re~r' Runl, 5" ~/?~i__1-22 12-03-93 Perf Record v/'~ ~0 --[05o~ Run 1, 5" ~z-~_1-25 12-17-93 Prod Prome / %;~ ~__~i~2-6 12-05-93 Perf Record ~c~_t Itili~ ' Run 1, 5" fl-/;(~ 2-22 10-22-93 TDTP (depth corrected) Run 1, 5" .~ -- 3-4 12-20-93 Inj Profile j .~,c~ )'[¢.m~l~ct%$ Run 1, 5" ___~~3-36 12-11-93 Perf Record I Z~ ct 0 ~- { 7--a~I/3 Run 1, 5" ~52 4o''t/7'' 4-1 12-06-93 Perf Record fl~0 -~$~ Run 1, 5" -llA 12-13-93 Perf Record ] 9~ co - I [u[0~ Run 1, 5- ~}.~7 4-23A 12-14-93 Dual Burst TDT-p (~'~ , Rrm 1, 5" **'~:L~--J4-31 12-11-93 Prod Profile ~ ,~'i.- i~}.~ 4-41 12-14-93 Perf Record ~'"~0~' -.n;':.; C' ~ 1, 5" q/'-iic 5-28 12-10-93 DualB~st~T-P [i~ ~., ~ ~1,5" '; ~4~?'~._.6-2 12-20-93 Produc~on/.~:.f. :', :-L;..~',9 "..::, -Li~? 5;/:~.~ 1, 5" ?';::~ '~.'~ 6-16 12-15-93 Prod ................ -;~ ? c, .. 9-1 12-5-93 Mak DetectJ'?~ ~- ~~- 1 12-9-93 Leak Detect? ?' ~-}- ~.~ ...... 9-20 12-19-93 MI Inj ~oflle ~ct ~___9-29 12-13-93 M~ Detect i~¥~ !~em~' ~.~ ? ~~-36A 12-17-93 CNL}c~T& ~-36A 12-17-93 Du~ B~t ~T-P/GR ~z~iqi 9-51 12-07-93 Prod ' ' Produc~on} ~a [~i~Sl&r ~H~ 1-12 12-06-93 ~ - 12-5-93 ~G Cutter ~ 5-9A 12-9-93 ~-~o ~6-17 12-4-93 Mak DetecUon _ ~0.-~16-23 12-10-93 M~ Detec~on ~~~16-29A 12-18-93 Peal Record it ~0a-iZl/~ ~~18-29A 10-19-93 m~ (depa co~ected} ~ 1, 5" Please sign and return t~e attaphed cgpy a~ ~ceipt of data. RECEIVED BY__~,-_~..X-~ / John E. DeGrey APPROVED /. ATO- 1529 Trans# 94002 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA The correct well name is 4-1lA and the corrected API# is 50-029-20286-01 The correct well name is 4-31 and the corrected API# is 50-029-21334-00 The correct well name is 18-29A and the corrected API# is 50-029-22316-01 ARCO ~l._=Im, Inc. P.O.Box 100360 Anchorage, 99510 DATE: 11-23-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS ?o-qZ~ 4-1 t~5~02 7~$ 4-12~5a10 65- Z~z_ 4-29 7q-%z 5-1 ~Z-lzq 6-20 %5-~g7 6-24 78-1b 7-8 ~-7o 11-28 9-23-93 ~ CNL ~5-~Run I Job#93453 7-18-93 ~ CNL~qo-~oz5 Run I Job#93320 9-3-93 ~a TDT-P ~l~,~Run 1--~0 Job#93441 9-3-93 ¢~ TDT-P ~-Run 1SLAV Job#93440 10-21-93~ CNL~qt-~ Run 19t~ Job#93496 8-24-93 c~ CNTD ~-- Run 1~1 Job#93397 9-2-93 ¢~ TDT-P ~zS?-Run I ~l~ Job#93439 9-5-93 ~a CNTD ~ac~--Run lla~ Job#93442 Please sign and return the attached copy as receipt of data. Have A Nice Day! Sonya Wallace ATO-1529 AP P R OV ED__~.~ ~.. )_.---:. Trans# 93141 Sch Sch Sch Sch Sch Sch Sch Sch # CENTRAL FILES (CH) # EXXON # BPX # PHILIAPS # STATE OF ALASKA RECEIVED DEC 0'1 199b Alaska 0il & Gas Cons, Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-21-93 REFERENCE: /2-16A 9-25-93 %2-16A 9-26-93 3-29 9-19-93 4-1 9-23-93 4-4 9-17-93 4-78T 9-19-93 4-8 9-23-93 4-16 9-13-93 9-5A 9-16-93 9-29 9-15-93 /9-35A 9-17-93 ~, 9-35A 9-18-93 \.-q-35A 9-19-93 9-42 9-14-93 9-44 9-15-93 2-22 9-25-93 /~-~ (12-22 9-26-93 12-30 9-22-93 14-4 9-24-93 14-31 9-20-93 15-2 9-14-93 15-18 9-21-93 16-29A 9-24-93 17-12 9-22-93 18-25 9-20-93 Collar (c-mb ~o$~o-lo~1 Production %(00 CNL '1 Peri Record Run Run Run Run Run 1, 1, 1, 1, Peri Record ~0-qz~ Run 1, Inj Proffie]~ol;~a~lw~J~mRun 1, Leak Detect/~vl~ta~- Run 1, ProductionRa~ ~'~-~1®~ 1, Leak Detectl ~tv~/,~,~ 1, Peri Record %~ ~11 ~-/~ 1, Peri Record ~ql~/o ?~ 1, Prod ...Proille / s~ ~)~~ 1, Prod Profile ~ ~l~/~i~ 1, Prod Profile i~r~ 1, Jewelry I al c'c 1, Peri Record ~q0o~c~o 1, POGLM Set/TBG Punch 1, Perf Record I~t~ 1, Production ~-qs~0 1, Prod Profile 1, B~ker Inflatable Packer Run 1, Production l~H~l~l~ Run 1, Production]~l~l~r~~un 1, Prod Profile u~o~t%v~o Run 1, Run Run Run Rl~n Run Run Run Run Run Run Run Run Run l',&5" .Sch 5" 2~~c/Sch 5" I~l~lu~ Sch 5'q~00-~Z Sch 5" Sch 5" ~0-'aSo Sch 5" Sch 5" Sch 5" t~0~ Sch 5" 15.~--~5o Sch 5,,~-lz~ZSch 5" :~l~:~.-~1773 Sch 5" Sch Have A Nice Day! Sonya Wallace ATO-1529 Please sign and return the attached copy as receipt of data. RECEIVED BY__ '~_~ / Trans# 93118 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA # PHILLIPS # LILLIAN TiULANA # EXXON # MOBIL Drill Site: 4 Well: 1 K-VALVE DESICN Tue Sep 21 16:49:29 1993 DOME SET PRESSURE: 410 PSIC @ 60 DEO F FTP @ CLOSE (PSIC): 260 PSIC K-VALVE CLASS (A,B,C): B COMMENTS CC: ENCINEERINC FILE /-~O~ii{A~OK Pm 24 (WITH ATTACHME~S) J.C. SMART / M.~. SHOEMAKE PRE 20 (WITHOUT ATTACHME~S) R.A. ~LLS / K.L. BLAC~U~ PRE 14 (covER ONLY) K-valve is designed to be tested by cutting lift gas and opening the choke. Choking the well back to hold open the k-vlv is expected. Due to PI variation the well may have to be hardlined to an offset SI well to (WITHOUT ATO 1582 DESIGNED BY: A.W. BROOKS . Drill Site: 4 Well: K-VALVE DESIGN Sun Aug 29 13:04:34 1993 DOME SET PRESSURE: 450 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 380 PSIG K-VALVE CLASS (A,B,C): A COMMENTS: Redesign due to increase in. GOR and lack of lift gas Pulled for wellwork. C~,}~ ~..£ ~,.- /~.,.,.,~.,,¥-,./ ~-U~ · CC: ENGINEERING FILE / C~r~I::ATGR- PRB 24 (WITH ATTACm NTS) J.C. SMART / M.G. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) R.A. WELLS / K.L. BLACKBURN PRB 14 (coVER ONLY) J. Versteeg ATO-15 (WITHOUT ATTACHMENTS) STATE OF ALASKA (COVER ONLY) DESIGNED BY: K.L.Martin~jz/% Printing contents of current screen - wait for message to clear Drill Site: 4 Well: 1 Sun Aug 29 13:05:22 1993 K-VALVE DESIGN CHECKLIST RECENTWELL TEST DATA IS ACCURATE AND SHAKEOUT DATA CONFIRMS WATERCUT ? y SUBJECT WELL IS PRODUCING INTO THE HIGH OR LOW PRESSURE COMMONLINE ? lp PAST '7 DAY AVERAGE COMMONLINE PRESSURE: 270 AND LOW PRESSURE: 260 SUBJECT WELL'S PAST 7 'DAY AVERAGE SURFACE FLOWING TUBING PRESSURE: 438 PAST 7 DAY LOW FTP: 438 REASON: n/~ IS THE FTP SWINGING OR SPIKING ? n HOW MUCH ? 0 DOES THE FTP vs CML PRESSURE INDICATE A CHOKE RESTRICTION OR UNDERSIZE ? n CURRENT CHOKE SETTING IS AT CFR OR HIGH LIMIT (WIDE OPEN) ? no SUBJECT WELL IS GAS LIFTED ? no GAS LIFT OPERATING SMOOTHLY ? Printing contents of current screen - wait for message to clear zl ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: ~~-24A ~-I~ 1-30 ~-30 ~2-6 -21 -1 ~4-40 97..~_~ 9-13 ~-26 ~11-22 3 -1 '7~--60 3-1 ~-1 ~7-1~ ~7-10 7-14-93 7-5-93 7-11-93 7-17-93 7-17-93 7-10-93 7-6-93 7-6-93 7-8-93 7-11-93 7-3-93 7-3-93 7-9-93 7-4-93 7-4-93 7-8-93 7-2-93 7-16-93 7-16-93 7-5-93 7-6-93 7-9-93 7-13-93 7-12-93 Completion Record ~°~1~,°5" Perf Record ~s0o~z/5 Run 1, 5" InJ Profile ~ ~ vo-~ ~ Run 1, 5" Perf Record~°~-~-~ Rs~u 1.5" Prod Profile ~tso-t~qS~ Rsm 1, 5" P~/~J ~o~e~~~m 1, 5" Sch Sch Sch [ich Sch Sch Sch Production LognC°-~S~Ru_n 1, l"&5" Sch Completion.Record R~m 1, 5"~~55Sch Perf Record ~O~b~ Run 1, 5" Sch Peff Record ~- t~ ~ R~m 1, 5" ~h Peff Record%~a~ R~ 1, 5" ~h ~ ~tect ~-'~ R~ 1, 5" ~mpleflon Record ~ ~tect R~m 1, 2" o- qo~ Sch ~ ~ct ~~o R~m 1, 2"&5" ~h ~ml Brat ~ R~ 1, 5"~-~ch Peff Record ~1~- ~z~5~ R~ 1, 5" ~h ~e-~ ~g- ~P lo~b~m 1, 5" Sch ~ ~tect ~-%~o R~m 1, 2" Sch Pe~ ReCord ~~~ R~m I 5" ~h ~j ~~/~ ~c Pe~ Record ~10~ I R~m 1, 5" Sch ~ ~tect ~- ~ ot~ R~m 1, 2" ~h Please sign and return the attached copy ~ receipt of data. _ ........ Have A Nice Day! ATO- 1520 ~s~ 93~ 1 ~ CE~~ F~ ~ ~~ ~ C~~ON ~ CLOT C~~ # BPX # EXXON # STATE OF ALASKA # MOBIL * The correct top logged interval for 11-22 is 380 feet. Drill Si~e: 4 Well: I K-VALVE DESIGN Tue Jan 05 10:36:57 1993 DOME SET PRESSURE: 320 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 150 PSIG K-VALVE CLASS (A,B,C): C COMMENTS: The dome charge has increase since the last design because the well's PI has increased. The new design should allow the well to flow at full choke. The k-valve must be bench tested. CC: MART~//M~.W~D.. COOPER J. C · S SHOEMAKE C.L. CLARK ! K.L. BLACKBURN ENGINEERING WELL FILE PRB 24 PRB 20 PRB 14 T.C. COLLIER ATO 1582 STATE' OF ~SKA (COVER) DESIGNED BY: R. J. Reints Printing contents of current screen - wait for message to clear RECEIVED 0. 1993 Drill Site: 4 Well: ----- , , SSSV DEPTH (MEA~): FTP @ CLOSE (PSIG): K-VALVE DESIGN 2162 150 PRESS ADJUSTMENT: 220 Tue Jan 05 10:37:42 1993 TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: CK LGR FTP OIL %WTR GOR 86 3253 384 2267 86.9 3997 CONDITIONS AT CLOSURE: 86 3253 150 2767 86.9 3997 WELL TEST TEMPERATURE @ SSSV: 165 PRESSURE @ SSSV: 738 ' SEP COML GLR LIQ PWF PI TEMP PRES DATE SEL 709 17355 2645 17.66 159 0 12/25f92 Y 675 21190 2373 17.66 159 @CLOSE 165 517 DOME SET PRESSURE: 320 PRIOR DESIGNS: DATE: 03/29/92 SET PRESSURE: 195 FTP @ CLOSURE: 183 340 183 305 195 TEMP: LINEAR LINEAR NA ESC=EXIT; Fl=HELP; F2=WELL TESTS~ F4=DISTRIBUTION~ FS--SENSITIVITY TABLE~ F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST~ CFg=CYCLE DATA; WPS C= . .73759e-2 N= 1.000000 NEW C= . .77564e-2 ENTERED N= 1. 000000 Printing contents of current screen - wait for message to clear Tue Jan 05 10:38:26 1993 P.I. 18.00 15.00 18.00 15.00 %WTR 87.0 87.0 92.0 92.0 GOR 3500 3500 3000 3000 LGR 3250 3250 3000 3000 FTP 1 150 508 508 506 505 FTP 2 125 493 492 481 48O FTP 3 · 100 482 481 457 ~ 456 "~:"::~" ENTER VALUES FOR PRODUCTIVITY INDEX, WATER CUT, GAS-OIL RATIO, LIFT GAS RATE, AND FLOWING TUBING PRESSURE 1, 2, or 3. PRESSURES AT THE SSSV WILL BE CALCULATED FOR EACH GROUP OF ITEMS ENTERED. ESC=EXIT; Fl=HELP; F2=WELL TESTS; F3=DESIGN; F4=DISTRIBUTION LIST; F6=CHECKLIST; F10=ACCEPT; Printing contents of current screen - wait for message to clear P. I. 18.00 .80e4 %WTR 87.0 92.0 GOR 3500 3000 LGR 3250 2500 SENSITIVITY TABLE \ o.o o 0 Tue Jan 05 10:49:13 1993 ........ .,1o A/z- FTP 1 175 525 536 535 0 FTP 2 150 508 509 508 0 482 460 0 ENTER VALUES FOR PRODUCTIVITY INDEX, WATER CUT, GAS-OIL RATIO, LIFT GAS RATE, AND FLOWING TUBING PRESSURE 1, 2, or 3. PRESSURES AT THE SSSV WILL BE CALCULATED FOR EACH GROUP OF ITEMS ENTERED. ESC=EXIT~ Fi=HELP~ F2=WELL TESTS~ F3=DESIGN~ F4=DISTRIBUTION LIST~ F6=CHECKLIST~ F10=ACCEPT~ Printing contents of current screen - wait for message to clear 4 Well= ~e Jan 05 10=53=12 19~3 ....... K-V~ DESIGN C~C~IST ~CENT ~LL TEST DATA IS ACCU~TE ~ S~OUT DATA CONFI~ WA~RC~ 7 y SUBJECT WELL IS PRODUCING INTO THE HIGH OR LOW PRESSURE COMMONLINE ? low PAST 7 DAY AVERAGE COMMONLINE PRESSURE: 230 AND LOW PRESSURE: 210 SUBJECT WELL'S PAST 7 DAY AVERAGE SURFACE FLOWING TUBING PRESSURE: 360 PAST 7 DAY LOW FTP: '340 REASON: no IS THE FTP SWINGING OR SPIKING ? no HOW MUCH ? 0 DOES THE FTP vs CML PRESSURE INDICATE A CHOKE RESTRICTION OR UNDERSIZE ? yes CURRENT CHOKE SETTING IS AT CFR OR HIGH LIMIT (WIDE OPEN) ? yes SUBJECT WELL IS GAS LIFTED ? yes GAS LIFT OPERATING sMOOTHLY ? yes The selected action ke'y is not available for ~his screen WT44 4-1 12 01-05-'73 1003 ~ TEST REPORT .......... TESTED RATES ---EXPECTED--: AVG AVG AVG AVO TOTAL LIFT FOfl~ TOTAL TEST DRAW FORH TTAF ORIF UE_LL DATE TIME --CHOKE-- SE.P FTP SEP GL OIL WTR GAS GAS i( GOR GLR LEN LIO DOWN OIL C'43R i~ SYI. L DIA NO. COMP POS SIZE THP TEST PRES PRES STBD BPD MSCFD I'LACF1) WI'R SCF/B SCF/B HRS PI PSI STBD SCF/B WTR TPLG INCH 04-01 12-~ 0.930 86MV 176 159 L'-q)4 266 1711 2267+ 1,~)9 12316+ 3253 87 3.998+ 710 6.0 17.7 .982 1936 2599 87 ERNG. 04-01 12-14 0822 86MV 176 160 ~ 259 1705 2042 13911 8810-~ 87 2599 552 6.0 17.4 919 2042 2599 87 ERYG 04-01 12-02 O,~,~/d 86HV 176 160 343 249 1712 2245+ 14227 10169+ 3517 86 2963+ 617 6.0 16.7 986 20~ 2'599 87 ERNG (.:)0 04-01 11-23 0230 86MV 176 161 301 247 1817 1945+ 12607+ 5576 3540 87 1047- ,°,83 6.0 20.8 701 2122 2599 87 ERNG 3.00 04-01 10-24 0102 ~4']V 176 151 295 247 1320 1078 6942 9391+ 3520 87 5446+ 1171 6.0 3.7 2145 2133 25%' 87 ERNG 4.00 04-01 10-23 0056 86MV 176 150 ~3 249 1373 1016 6655 9235+ ~'54, 87 5592+ 1198 6.0 3.5 2181 2139 2599 87 ERNG 4.00 04-01 10-22 0034 8~V 176 151 306 2b'5 1314 1137 7092 9602+ 3577 86 5299+ 1167 6.0 3.9 2105 2114 2599 87 ERNG 4.00 04-01 10-21 0014 $6MV 176 151 296 254 13~ 1130- 7265 9612+ 3480 87 5427+ 1145 5.9 4.0 2106 2126 2599 87 ERNG 4.00 04-0! 10-09 2'3,04 86MV 176 155 297 244 1396 1379 8450 9.394 3492 86 4280 956 6.0 5.2 1876 21~ 2600 87 NRi~G 4.00 04-01 I0--07 1540 86.,~,~ 176 155 295 241 1,~..5 1352 ~ 9105 3541 B6 4115 940 5.9 5.2 1873 2134 ~9~ 87 NRItl 4.00 04--01 09-17 0500 78)~ 176 154 295 246 1329 1348 7760 9045 3012 85 4475 993 6.0 4.6 1975 2(F)2 251~ 87 NRNG4.00 04-01 09-16 0128 7..0~ 176 153 271 242 1327 1215 8003 9007 2955 87 4981+ 977 6.0 4.7 1965 2095 ~.9<) 87 ERNG 4.00 WELL SHAE-OUT DATA WELL ENTRY PERCENT PERCENT H~ PER EHULSION LOC SAMPLE NO, NO, DATE TIME ~TER SOLIDS MILLION ~R 7. ENTERED BY TAKEN FROM 04-0.'.' 12 12-2~92 0900 89,00 0,00 750,0 0,00 PRODUCTION HIEADIER 11 12-14-92 0200 90.00 0,00 860,0 0.00 PRODUCTION HEADER 10 07-28-~ 021,5 9,5,00 0,00 77,5,0 0,00 PRODUCTION HEADER 9 07-27-92 0410 94.00 0,00 ,54,5,0 0,00 PRODUCTION HEADER 8 03-18-92 171,5 8,5,00 0,00 350,0 0.00 PRODUCTION HEADER 7 02-08-92 0145 85,00 0,00 110,0 0,00 PRODUCTION HEADER 6 01-27-92 0030 90,00 0.00 840,0 0,00 PRODUCTION HEADER 5 01-14-92 201,5 90.00 0,00 30,5.0 0,00 PRODUCTION HEAl)ER 4 12-14-91 2000 96,00 0,00 1010,0 0,00 PRODUCTION HEADER 3 11-0.5-91 1700 98,00 0,00 900,0 0,00 PRODUCTION HEADER 2 10-06-91 1330 100,00 0,00 930,0 0,00 PRODUCTION HEAleR I 0'~-23-91 1200 810.0 0,00 PRODUCTION HEADER $$ -PTEI23~ 28S.7& L I~ZS. 57. i171~ 28_ ~ 157t mm L P515 ~. ~VQ, ~VG, RV~. 10:~:3:2~ HOk;:5 12-29-92 2 ' TIME B~KHARO 9 - DISPLAY PLOT FGq DS'HELL,LENGTH ENTERED ON LiNE Drill Site: 4 Well: K-VALVE DESIGN Thu Aug 20 18:38:23 1992 COMMENTS: This K-valve design should allow the well to flow at full choke. The K-valve must be bench tested. CC: / W.D. COOPER RB 24 T.C. COLLIER ATO 1582 J.C. SMART / M. ~. SHOEMAKE PRB 20 C.L. CLARK ! K.L. '~LACKBURN ENGINEERIN~ WELL FILE Drill Site: 4 Well: i ... " .- Thu Aug 20 18:37:50 1992 K-VALVE DESIGN SSSV DEPTH (MEAS): 2162 FTP @ CLOSE (PSIG): 155 PRESS ADJUSTMENT: 173 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: CK LGR FTP OIL %WTR ~OR 81 0 329 2217 84.2 5102 CONDITIONS AT CLOSURE: 81 0 155 2466 84.2 5102 WELL TEST TEMPERATURE @ SSSV: 166 PRESSURE @ SSSV: 618 SEP COML GLR LIQ PWF PI TEMP PRES DATE SEL 801 14110 2191 9.73 160 0 08/18/92 Y 801 15696 1955 9.73 160 0 @CLOSE 166 446 DOME SET PRESSURE: 270 PRIOR DESIGNS: DATE: 03/29/92 SET PRESSURE: 195 FTP @ CLOSURE: 183 TEMP: LINEAR 10/03/91 340 ssa 05/12/91 ..- "305 ..~ 195 NA ESC=EXIT; Fl=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SF8=RESTORE WELL TEST; CFg=CYCLE DATA; WPS C= . .67651e-2 N= 1. 000000 NEW C= . .66435e-2 ENTERED N= 1. 000000 AR~ Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-1-92 REFERENCE: ARCO CASED HOLE FINALS 1-4 3-24-92 Prod Profile 3-2 3-19-92 Prod Profile 3-10 3-20-92 InJ Profile* 3-17 3-21-92 Inj Profile 3-22 3-20-92 Prod Profile 3-24 3-22-92 Prod Profile 4-1 ?.- ~/; 3-23-92 Prod Profile - 3-23-92 Prod, Profile 9-6 3-20-92 . Prod Profile 11-4 3-30-92 Prod Profile 11-12 3-22-92 ~od ~o~e 11-24 3-23-92 *~od ~o~e 12-20 3-23-92 ~J ~o~e 18-16~-~/ 3-24-92 PITS Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco Run 1, 5' Camco R-- 1, 5" Camco Run 1. 5" Camco R~n 1, 5" CAI:IlCO Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco Please sign and return ~e attached copy as receipt of data. IVED BY_ .~__~ R ECE Have A Nice Day! Sonya Wallace ATO- 1529 · RECEIVED MAY 1 I 1992_ APPROVED Trans# 9209~ ...... Alaska'Oii & Gas Cons. Commissior~ Anchorage # CENTRAL FILES # CHEVRON D& M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO Drill Site: 4 Well: Sun Jan 26 08:23:45 1992 K-VALVE DES I GN DOME SET PRE~S~: 195 PSIG @ 60 DE~ F FTP @ CLO~E (PSIS): 183 PSI~ K-VALVE CLASS (A,B,C): C Well m~y have to be choked back to keep the K-valve open. However, since the last design 12-17-91, the PI has dropped, GOR has increased and water cut has declined, m~king a wide choke setting possible. J.C. SMART / M.~. SHOEMAKE C.L. CLARK / K.L. BLAOKBORN EN@INEERIN~ WELL FILE PRB 24 PRB 20 PRB 14 W.D. MOSTELLER ATO 1584 DESi~NED BY: A. W. Brooks RECEIVED FEB 0 <l 1992. Alaska Oil & Gas Cons. Commission Anchorage ~rill 8i~e: ¢ ~etl: ( (' Tue -Dec i7 -22:48:20 -1991 DONE 8E~ ~l;l:E8861~: 325 PS[g @ 60 DE(~ F ~ @ CT.,0~ (PS[I;): 279 P8[I.~ cc: c.P. ~~ / w.z~. ~' ~.c. ~ / M.e. C.L. ~ / K.~. PRB 24 PRB 20 ~ X4 Printing contents of current screen - wait for message to clear RECEIVED JAN ~0 1992 A/aska Oil & (~as Cons. Commission Anchorage Drill Site: 4 Well: 1 K-VALVE DESIGN DOME SET PRESSURE: 400 PSIG ~ 60 DEG F FTP @ CLOSE (PSIG): 515 PSIG K-VALVE CLASS (A,B,C): C (~ ~u Oct 05 0~:56:10 1~1 COMMENTS: K-VALVE WAS DESIGNED USING PH2. MECH MODEL AND PH2 HYDRAULICS AGREED. W~ MUST BE CHOKED TO MAINTAIN FTP ABOVE CLOSURE PRESSURE. NET RATE IMPACT = -15 BOPD. CC: C.F'. FARMER / W.D. COOPE~ K.M. KENNEDY / L.D. LASH C.L. CLARK / K.L. BLACKBURN ENGINEERING WELL FILE F'RB 24 W.D. MOSTELLER ATO 1584 PRB 20 F'RB i4 DESIGNED BY: A. W. BROOKS Printing content's of current screen - wait for message to clear ARCO ALASKA.. INC, F',O, BOX i00360 {~" ANCHORAGE, ALASKA1~,~5i0 DATE' REFERENCE: ~-0ooq.o i-J7 -o;i;-o 2-~2 ~. 0095-0 3-i6 ). ooq:l' 0 4-i ~-oo~'~-0 4-i2 ~4-,35 . o~'t-o (.4-35 . oa e"/- 0 t 6-i L~ ARCO CASED HOLE FINALS 7-i7-9i DSN RUN i , 9-"~0-9 t COLLAR-F'ERF RUN i 9-i 9-9i COLLAR-F'ERF RUN i , 9- i 3-9 i PERF RUN 9-23-9i COLLAR-F'ERF RUN i, 9-24-'-7i CBT RUN i , 9-24-9i CET RUN i , 9-20-9t CCL KUN i, PLEASE SIGN AND RETURN THE ATTACHED COPY AS F<E. CEIF'I OF' i)AIA. OCT 1 5 199 ..... 9 'Alaska Oit & Gas Cons. CommissWll D I 2 T'R I B U T I Q~ichorage CENTRAL FILES CHEVRON D&M EXTENSION EXPLORATION EXXON MARATHON HuBZL ¢ PHILLIPS F'B WELL FILES R & D '- BF'X .~, STATE OF ALASKA TEX~CU 5' 5' 5" 5" 5' HL$ A FLA2.' A FLA~,, Al'LAS $CH SCH A [LAS STATE OF ALASKA ALASKA( . AND GAS CONSERVATION IISSION REPORT OF SUNDRY WELL OPI ,HATIONS 1. Operations performed: Operation shutdown , Stimulate ~ Plugging ~-- Perforate X~ Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1327' FNL & 295' FEL, Sec. 34, T11N, R15E, UM At top of productive interval 1672' FSL & 1448' FWL, Sec. 35, T11N, R15E, UM At effective depth 1467' FSL & 1508' FWL, Sec. 35, T11N, R15E, UM At total depth 1449' FSL & 1513' FWL, Sec. 35, T11N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 9790 feet 9039 feet 5. Type of Well Deveiopme.t :X Expioratc~/ Stra~graphic Plugs(measured) None 6. Datum of elevation(DF or KB) 64' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-1 9. Permit number/approval number 70-42 10, APl number 50 - 029-20078 11. Field/Pool Prudhoe Bay Oil Pool feet Effective depth: measured true vertical Casing Length Structural 115' Conductor 1185' Surface 2686' Production 9749' Liner 9749 feet 9002 feet Junk(measured) Size Cemented 30" To Surface 20" 1030 sx 13-3/8" 2090 sx 9-5/8" 1060 sx None Measured depth True vertical depth 115' 115' 1185' 1185' 2686' 2686' 9749' 9002' Tubing (size, grade, and measured depth) 7"/5-1/2", L-80, tbg w/tail @ 9184' MD ~l/~/0/,a;;. CO/~/[]/~iO/i" Packers and SSSV (type and measured depth) Baker FB-1 packer @ 9063'MD; Camco SSSV @ 2162' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) N/A Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaae Production or Injection Dat~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 508 1766 2750 1489 247 Subsequent to operation 193 1463 10422 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1584 268 Service Signed (~~ej~ (~ t Form 10-404 Rev 06/15/88 Title Sr. Area Operations Engineer SUBMIT IN DUPLICATE SUN/nb DS 4-1 Perforating Operations: ARCO Alaska, Inc. perforated DS 4-1 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 9/13/91. The interval perforated was the following: 9430'-9458' MD (Reference Log: BHCS dated 12/27/70). Produced fluids were in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 9/13/91. RU perforating unit, pressure tested BOP's and lubricator to 3500 psi, okay. Perforated 9430°-9458' MD at 4 SPF (ref: BHCS of 12/27/70). SI well, POOH, and confirmed all shots fired. Rigged down and secured well. WDM: 9/18/91 Drill Site: 4 Well: 1 K-VALVE DESIGN Tue Jul 30 13:04:28 1991 COMMENTS: DOME SET PRESSURE: FTP @ CLOSE (PSIG): K-VALVE CLASS (A, B, C ): 175 PSIG @ 60 DEG F 205 PSIG C K-VALVE WAS DESIGNED WITH PH2 SINCE IT MATCHED THE MECHANISTIC MODEL'S RESULTS. IT MAY BE POSSIBLE TO DUMP WELL TO DEPRESSURED SEPARATOR TO TEST THE VALVE. · CC: C.P. FARMER / W.D. COOPER PRB 24 K.M. KENNEDY / L.D. LASH. '~ PRB 20 D.L. NICKERSON / B.R. ROBERTSON PRE 14 ENGINEERING WELL FILE W.D. MOSTELLER ATO 1584 STATE OF ALASKA (COVER) DESIGNED BY: R. J. REINTS ARCO ALASKA, INC. P.O. BOX iOOS60 i ANCHORAGE, ALASKA 99 DATE: 7-i2-9t REFERENCE: ARCO CASED HOLE FINALS i-i i 6-5-9i F'ROD F'ROFILE~" i-i i 6-5-?i GR-COLLAR -- t-2i 6-7-9i F'ROD PROFILEj 2-4 6-JO-DJ CCL-PERF/' 4-t 6-~-9~ GA~ LIFT~ ~4-J6 6-t 9-9i CBT~ q1~'~(4-56 6-t 9-~t CET~ k4-36 6-2i-9i PFC-GR (PACKER ~ETTING~ F4-37 6-2i -9i CBT~ ~~ ~. 4-37 6-2t -9i CET~ ~'.~4-37 6-24-9i PFC-GR (PACKER ~ETTING~ I'~JJ-3-- t 6-28-9 i GR-CCL~ ~/-8~ 5-35 6-38-9i SBL/GR/CCL- 7-t 5 6-38-9i CCL-PERF~ * 9-6 6-i6-9i _ LEAK DETECTIO~ 9-8 6-5-9i PERFORATION BREAKDOW~ 9-9 6-23-9i COLLAR-PERF~ ** 9-t~ 4-t7-9i INJ PROFILE~ 9-i 8 6-i 3-~i JEWELRY~ 9-33 6-i 4-9i LEAK DETECTIO~ ** t i-J 4-i7-9t LEAK DETECTION~ i i -22 7-i-9i P~K--t ~/GR/CCL-BORAX~ i2-t 2 6-i 6-9i LEAK DETECTION-- i 3-i5 6-i ?-9i INJ PROFILE- **** i3-i6 6-i?-9i INJ PROFILE-- i 6-i 6 6-i 3-9i INJECTION/F'RODUCTI O~ i 7-i 6-i 6-9i PRI~ i?-ti 5-8-9i LEAK DETECTIO~ RUN i, 5" CAMCO RUN t, 5" CAMCO RUN t, 5' CAMCO RUN i, 5" ATLAS RUN t, 5' CAMCO RUN t, 5" $CH RUN t, 5" $CH RUN t, 5' ATLAS RUN i, 2"&5' $CH RUN t, 2"&5" SCH RUN t, 5" ATLAS RUN t, 5" ATLAS RUN i, 5" Al'LAS RUN t, 5" ATLAS RUN t, 5' ATLAS RUN t, 5' Al'LAS RUN t, 2"&5" CAMCO RUN t, 5' CAMCO RUN t, 5" Al'LAS RUN t, 5" CAMCO RUN i, 5" CAMCO RUN t, 2" CAMCO RUN i, 5" CAMCO RUN t, 5' CAMCO RUN i, 5" CAMCO RUN t, 5" CAMCO RUN t, 5" ATLAS RUN t, 2"&5" CAMCO RUN i, 5" CAMCO RUN t, 5' CAHCO RUN i, 5' CAMCO RUN t, 5' ATLAS RUN i, 2'&5' CAMCO RECEIVED BY ' AF'F'ROVED TRANS~ 9i~'~- PHILLIPS F'B WELL FILES HAVE A'NICE DAY! $ONYA WALLACE ATO-i52~ DISTRIBUTION CENTRAL FILES CHEVRON EXTENSION EXPLORATION EXXON ' MARATHON MOBIL BPX STATE OF ALASKA TEXACO * CORRECTED LOG INTERVAL FOR 9-6 IS 6700-7788 ** REFERENCE MIX UP ON TRANSMITTAL 9ii59 - POSSIBLE DUPLICATE LOGS *** CORRECTED LOGGED INTERVAL FOR ?-48 IS iJ~5t-t425i **** CORRECTED API~ FOR t3-i6 IS 5Q-Q29-29823 STATE OF ALASKA REPORT F SUNDRY WELL OPERA' i. O~rat~ns ~do~: ~a~ ~ut~ sfimu~m Plu~g P~a~ x Pull tubing Alter casing ----. Repair well 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1327' FNL & 295' FEL, Sec. 34, T11N, R15E, UM At top of productive intewal 1672' FSL & 1448' FWL, Sec. 35, T11N, R15E, UM At effective depth 1467' FSL & 1508' FWL, Sec. 35, T11N, R15E, UM At total depth 1449' FSL & 1513' FWL, Sec. 35, T11N, R15E, UM 6. Datum of elevation ) X64' RKB/' feet 7. Unit or I~operty / Prudhoe B~Un.~ 8. Well humid/ 4-1 9. Permit nun~3~/approval number 50~- 029-20078 5. Type of Well Development l=xplorata7 Stra~graphic 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9790 feet true vertical 9039 feet Effective depth: measured 9749 feet true vertical 9002 feet Casing Length Size Structural 115' 30" Conductor 1185' 20" Surface 2686' 13-3/8" Production 9749' 9-5/8" Liner Plugs(measured) None Junk(measured) None Cemented Measured depth True vertical depth To Surface 115' 115' 1030 sx 1185' 1185' 2090 sx 2686' 2686' 1060 sx 9749' 9002' Perforation depth: measured 9405', 9418'-9447', 9682'-9729' true vertical 8699', 8710'-8736', 8943'-8985' Tubing (size, grade, and measured depth) 7"/5-1/2", L-80, tbg w/tail @ 9184' MD Packers and SSSV (type and measured depth) Baker FB-1 packer @ 9063'MD; Camco SSSV ~)~2162' MD 13. Stimulation or cement squeeze summary Intewals treated(measured) N/A ,. ::~:~,~,~. Treatment de,ription including volumes used and final pressure ~? .~ ,,, ~ 4. ~ms~ntativ, Daily ~wraa~ Produ~ion or Ini~ion Da~ ~0~ ' Casing OiI-Bbl Gas-M~ Water-Bbl Pressure /~u~~ssure Prior to well operation 792~ 2912 4587 1375 297 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 844 j 4430/ 4360 J 1740 224 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 ~~ (:7~- ,~J~:~-- Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 SUN/nb SUBMIT IN DUPLICATE ( .~IIX RETORT OF WELI. OPEl{ _IONS DS 4-1 Perforating Operations: ARCO Alaska, Inc. perforated DS 4-1 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 10/28/90. The intervals perforated were the following: 9405' and 9418'-9447' MD (Reference Log: BHCS dated 12/27/70). Produced fluids were in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 10/28/90. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. Perforated at 9405' with 1 shot, and 9418'-9447' MD at 2 SPF (ref: BHCS of 12/27/70). SI well, POOH, and confirmed all shots fired. Rigged down and secured well. WDM: 6/12/91 STATE OF ALASKA ALASKA( '_ AND GAS CONSERVATION C(~~ VIlSSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown .~. Stimulate Plugging ....-- Perforate X~ Pull tubing Alter casing Repair well Olher 2. Name of Operator ARCO Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1327' FNL & 295' FEL, Sec. 34, T11N, R15E, UM At top of productive interval 1672' FSL& 1448' FWL, Sec. 35, T11N, R15E, UM At effective depth 1467' FSL & 1508' FWL, Sec. 35, T11N, R15E, UM At total depth 1449' FSL & 1513' FWL, Sec. 35, T11N, R15E, UM 12. Present well condition summary Total depth: measured 9790 feet true vertical 9039 feet 5. Type of Well D~v~oprr.,nt :X S~graphic Plugs(measured) None Effective depth: measured 9749 feet true vertical 9002 feet Junk(measured) None 6. Datum of elevation(DF or KB) 64' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-1 9. Permit number/approval number 70-42/90-521 10. APl number 50 - 029-20078 11. Field/Pool Prudhoe Bay Oil Pool Casing Length Size Cemented Measured depth Structural 115' 30" To sudace 115' Conductor 1185' 20" 1030 sx 1185' Surface 2686' 13-3/8" 2090 sx 2686' Production 9749' 9-5/8" 1060 sx 9749' Liner True vertical depth 115' 1185' 2686' 9002' Perforation depth: measured 9682'-9729' true vertical 8943'-8985' Tubing (size, grade, and measured depth) 7"/5-1/2"; L-80 tubing w/tail @ 9184' MD Packers and SSSV (type and measured depth) Baker FB-1 packer @ 9063' MD; Camco SSSV @ 2162' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) N/A 14. Treatment description including volumes used and final pressure Reoresentative Daily Avera(~e Production or Iniection Data OiI-Bbl ~as-Mcf Water-Bbl Casing No perforations Prior to well operation open to produc~on ...... Subsequent to operation 745 ~ 2829 206 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1626 Service Form 10-404 Rev 06/15/88 276 Title Sr. Area Operations Engineer SUBMIT IN DUPLICATE SUN/nb AIIX ~RT OF WEI,I, OPEl( .~ONS DS 4-1 Perforating Operat/on~; ARCO Alaska, Inc. perforated DS 4-1 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 7/21/90. The intervals perforated were the following: 9682'-9729' MD (Reference Log: BHCS dated 12/27/70). Produced fluids were in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short snmmary of the work is given below: Began perforating operations on 7/21/90. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. Perforated 9682'-9696' at 1 SPF and 9696'-9729' at 4 SPF (ref: BHCS of 12/27/70). SI well, POOH, and confirmed all shots fired. Rigged down and secured well. WDM: 6/12/91 ARCO ALASKA, INC. F'.O. BOX i00;560 ANCHORAGE, ALASKA 995t8 DATE.' REFERENCE' ARCO CASED HOLE FINALS 2-2 4-t 2-9t COLLAR/F'ERF RUN t , - = '"1 ' 2-t;5 ;5-25-9t PRODUCTION RUN i, 5 · .5-5 4-2-9i TBG CUTTER RUN i, 5" 4-t ;5-"~')-~t~. . PROD PROFII. E/F'ITS RUN t, 2'&5'.. 4-6 ~-~4-9,. i TEMPERATURE RUN t, 5" 4-24 ~-24-'9t STATIC TEMF'ERATUF~E RUN i 4-35 3-':2t-9i F']:I'S I:~UN t, 5" ~g.~q~-.47 3-28-9t GAMMA/( ....L RUN t 5 ~-0~ 9-48 4-5-9t COLLAR/F'EF;~F R~N i~.':~--~"~.,... 4--t .-9t COLLAR/PERF ' · RUN i , 5" g.~2-~f ~-2t-9t INJECTION RUN t, 5" ~ 2-33 3-2t--9i INJECI'iON RUN i, ~ 3--~78 ~-2G--~? ~ FLUID I,D, ' RUN · ~ 4-~ 6 3-t 8--~7t F'RODUCI'ION F~'.UN i, t 5-~ 2-o . . ~7.-9t PITS RUN t 5-;5 o_ ,-~ 5" ~ ~8--~ PERF BREAKDOWN RUN t 6-6 4-t t ~9~ COLLAR/PERF RUN F:' i... E: A 5' E ,~ I G N A N D R E';' U R N 'F HI'-':: A T T A C H E D C 0 F:' Y A 5' R E C E I F:' i" 0 F:- D A T A. RFCEIVED BY _~/~____.~ I"IAVE A NICE DAY! SHARON WILSON Al'O- i 52~? A'FLA~' CAMCO A T L A 5' CAMCO CAM[;[) CAMCO C A M C 0 Al'LAS I"1R S' ~'rLAS' CAHCO CAMCO C A H C 0 HR,S' HR$ ~, I'LAS D I '~.t ' *'t ' · ~ l R .I. B U l' I [)N ~,E. NTRAI.. FILES '" C Fi IF. V R 0 N 11' D & M "" EXTENSION EXF'LC)RATION 'Ir · ~ EXXON HARATHON · ..'~ I'iOB ZL '~ F:' H I L L I F:'B W E I_ I. F' :!: I... E S R & D · '~- BF'X i" I_:i: X A C C) * I'HE .,OI'<I-<E'..CFED AF']:~$ F:'OR t 4-i 6 IS ':~:":'~'"'~Q--"~q,qF"~:) Drill Site: 4 Well: K-VALVE DESIGN Mon Apr ~8 16:~4:1a 1991 DOME SET PRESSURE: 3~5 PSIG FTP @ CI,OSE (PSIG ~: 195 PSIG K-VALVE CLASS (A,B,C COMMENTS: Based on flowing-pressure survey. Pressure adjustment to c].ose K-valve in we]] = 84 psi. CC: C.P, FARMER ,/vJ.D, Coo PE~ PRB 24 K.M. KENNEDY / W.S. WII,DER PRB 2~ C.L. CLARK / B.R. ROBERTSON PRB 14 ENGINEERING WEi, I, FILE W.D. MOSTELLER ATO 1584 STATE OF ALASKA (COVER] .DESIGNED BY'~/~~ RECEIVED APR, 19 1991 Alaska Oii& Gas Cons~ Commissior~ Anchora[m ARCO ALASKA, INC, ~' f F'.O. BOX t0,3360 ANCHORAGE, ALASKA 995i8 DATE' i i--9-9(-) REFERENCE' ARCO CASED HOLE FINALS i-8 iC~-i7-gc~ INJECTION F'ROFILE RUN i, 5 · 4-i i0-28-9(~ PERF RECORD RUN i, 5' 6-i6 ii-4-90 COLLAR/F'ERF RUN i, 5 · 6-24 i,3-i7-90 PITS RUN i i2-5 t0-i8-90 F'RODUCTION PROFILE RUN i, 5' i2-8B i0-25-9,'-5 LEAK DETECTION RUN i, 5' i,S-8 t 0-t 8-90 FM I'EMF' RUN i , i4-5i i0,-i7-9~ TEMP RUN i, 5' t5-2 i¢-i7-9~ F'RE-FRAC PITS RUN i, 5' i5-2 ii-i-g(~ CCL/PERF RUN i, S' t5-2i tr~-i6-9~ F'RE-FRAC SURVEY RUN t, "- '="'- ....UI-f AS RECEI F OF' DA'FA FI..EA,.~E SIGN AND RETURN THE AI'TACHED £ .... '"' F' HAVE A NICE DAY! SAL. L.Y HOFFECKER A'FO- i 529 · TRAN.S~, 9¢~'59 ' CAMCO SCH ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO Al'LAS CAMCO DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXF'LORATION EXXON MARATHON MOBIL F'HILLIF'S PB WELL. FILES R & D BF'X STATE OF ALASKA TEXACO RECEIVED · NOV 1 5 1990 Alaska Oil & Gas Cons. Commission Anchorage DATE' in~-i7-90 REFERENCE- ARCO CASED HOLE FZNAi_~£ i -25 9-8-90 4-! 9-.-i 4 -- 9,::} 4-2 9- J 4-96, 4-2 9-i 6- 9,:.':, · "; .... ~ 9-2i _.. c;, r.--, --'¢' -? : ~.. ,.a.- -~ .,:_ 9-24 .-c..,A ,i-.-- *,. ,-.z, 9- 2 i .... 9 ® 4 - 2 ¢ 9 .- 3 - 9 ;3 9- 4 i 9 ..-:2 .'3,- 90 i S.-- i 9 .... i 9- 9,>':o i =iii: --. i 49 .--. 2 '2 - 9 e F'WDW i '-2A 9-":.._:'0-9'.'") F'W;'.')W 1 -2A ";' -"'"'-, ' ,::...'. 9'":;,, TM!) F'RODUCTION F'ROFILE 6R ,~:U R V r:-" Y PRODUCTION PROFILE F:'ERF REC. OR i') F'RODtJC'.T ! ON PROFILE ;::' E R F:' =" ~:' r,,"', ~', ;"-, t% !... ~...- ~..:, t.. '% I:' iv ':' .... '~! SURVEY 'f'FZH F:' ,:?URVEY P c' r'l i~ H r" "f' T 0 b.J.' PROFILE 'f'.6:(':;' F::UNCHEF;: RECORf) (:.- R / fi: C L P t::' l:;..' F: R ~- r'- n ~', f., I:;.: U i'-...i *;. 5 ~ RUN i, "2 ~&5 ~ F;.:UNi, 5" k'..:Uf,! 'i , _; F;4UN i, 5 ' RUN i, 5" f;:.~ ~ N '~ 5" i;:. U r4 ~. , _,':"" RUN !: 't::" RUN i, 5" F.,'UNi, 5" RUN i, 5" RUN i, 5 ' ,-Lu..~--~.::.E ;s"rGN AND F:.:E'f'URN 'Ft-'I,E *. 'r ';" -'- r' i ' i: '., CUP A;s' Ui-:' ... ~.-~. , ~..: ,.., 4,_ ~ 'f' R E C iii .[ F:' 'f' D A 'f'A RE CE '.': VED BY HAVF A NTM~.,..,~. DAY~. ;S'AL: "" HOFF';::''r' F:. L. ~ .... ,.,KF AT0-!529 HLS CAMCO C A ,*.*. C 0 C'; A'.'~ C: 0 C A ~ C C) CA?JCC) C~CO ~:C~ D ]: .:?TR I BUT ]: ON :~ Ciii:N T F,' A i... F Ii_E;S' :il: C I.-i E V R C.i N D & M ~"¢ FXTFN>-.~ IOiH EXPLORA]"ZON · ~ EXXON HARATHON · I,': MOBIL · " F' t-t I L t_ 'r p 3' F'B WEL. L. F]:i...E,S' R & D :~ .BP'.': '~]'A'i'E OF ALA~S'I<A TEXACO THiE CORF:,'F:~C",rED API-JI: FOR F'WDWi-'2A I£ 5¢.~-09c)"-:)"')"="'""4-(~t .... ~. ~.. · .'..,2...- .,2'. ~. RECEIVED OCT 1 9 1990 Ala~l~a 011 & Oas Con,. Commission Anchora~le Drillslte-Well:I C°mments:li Previous Settings: PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET 4-01 RECEIVED OCT 1 6 1990 Alaska 011 & Q.s ~ons. P.,ommluion Ant, borage Date:l 9/30/90 I Initial k-valve after SSSV failed. / Designed with Mechanistic model since well has 7" tubing. Dome Pres. (PSIG} Closure ~P (PSIG) Date NA Production Data: ROR = 755 BOPD CFR = BOPD Swing Well (very high or Iow GOR): No Design Parameters: Deg choke Deg choke Choke Priority Well: No Basis (one only): Actual well test and date. Flowing-pressure survey and date. Rates used with hydraulics program Rates (if needed): Oil Rate 760 BOR3 Watercut 87 % Formation GOR 4036 SCF/STB 'Gas Lift Gas Rate 2000 MSCF/D Total GLR 893 SCF/STB ;lowing Tbg. Pressure 297 PSlG ;Iow. Wellhead Temp. 148 Deg F Choke Setting 90 Deg (one only): PH2 PRLDHYD MECMODEL Conditions at Valve: Temp. @ SSSV 1 57 Deg F Pres. @ SSSV 608 PSIG Pres. Adjustment ~ SSSV 192 PSIG Notice: This adjustment is at the valve, not surface. Calc. Dome Set Pres. 256.0 PSIG ~ 60 Deg F IActual Dome Set Pres. FTP at K-valve Closure K-valve Type 260 PSIG @ 60 Deg F 20 0 PSIG @ Surface Borderline B-C (Ar Bp or C) cc: Farmer/Vacant~..~ Wilder / Kennedy (2 copies) State of Alaska cc: D.S. Eng: D.W. Mosteller D.S. Supv: Clark/Robertson Prep. by: R.J. Reints ATO- 1584 PRB-14 PRB-24 PRUDHOE BAY FIELD K-VALVE DOME SE'ri'lNG PRESSURE DATA SHEET Drillsite-Well=I 4-01 I Date:l 9/30/90 ! Comments: Previous Settings: Initial k-valve after SSSV failed. Designed with Mechanistic model since well has 7" tubing. Dome Pres. (PSIG) Closure ~P (PSIG) Date NA Production Data: ROR= 755 BOPD @ 90 CFR= BOPD @ Swing Well (very high or Iow GOR): No Design Parameters: Deg choke Deg choke Choke Priority Well'No Basis (one only): Rates (if needed): Actual well test and date. Flowing-pressure survey and date. Rates used with hydraulics program Oil Rate 760 BOPD Watercut 87 % Formation GOR 4036 SCF/STB Gas Lift Gas Rate 2000 MSCF/D Total GLR 893 SCF/STB =lowing Tbg. Pressure 297 PSIG -'low. Wellhead Temp. 148 Deg F Choke Setting 90 Deg (one only): PH2 PRUDHYD MEC MODEL Conditions at Valve: Temp. @ SSSV 1 57 Deg F Pres. @ SSSV 608 PSIG Pres. Adjustment @ SSSV 1 92 PSIG Notice: This adjustment is at the valve, not surface. Calc. Dome Set Pres. 256.0 PSIG @ 60 Deg F Actual Dome Set Pres. FTP at K-valve Closure 260 PSIG@60Deg F 20 0 PSIG @ Surface K-valve Type Borderline B-C (A~ Br or C) 0.4' > o 'es: 're ^u T cc: Farmer/Vacant~(~' Wilder / Kennedy (2 copies) State of Alaska cc: D.S. Eng: D.W. Mosteller D.S. Supv: Clark/Robertson Prep. by: R.J. Reints ?~ '~'~ .... ~,?~'~'~ ATO- 1584 PRB-14 PRB-24 DRTE- 9-i2-9B REFERENCE' ARCO MAGNETIC TAPE(,~) WITH LI£'TING(~J) i-5 7-25-90 4-i 8-'i3-90 i 8-20 8-2'5-99 DUAL 8UR3T TDF-F', RUN i TDT-P, RUN i F'DK-'i (.~O/GR/CCL/BORAX CNL, RUN i CNL.. RUN i FI..E,-~, .... SiGN AND RETURN TF![..:. ATTACHED CC1PY AS' RECEiF'T .OF DATA,. RECEIVED BY HAVE A NJ:CE DAY! 5'AI...LY FtCIFFECI<ER ATO- i 52"..;' DISTRIBUTION CiENTRAL F:[LE&' (CH) CHEVRON D & M '['AMMA~-~' BROWN (CIH) EXXON MAF..'ATHON MOBIL "- F' H :[ t_ L I P .'i~ pB ~ELL F'ILE~7 · "' 'SPX 11' · ~- &"Y'A'I"E OF ALASKA TEXACO ARCO AL.A£'KA, liNC P.O. BOX i ANCHORAGE, ALA~'KA 995i DATE- 8-i7-90 REFERENCE' ARCO CASED HOLE FINALS 5-i4 'r-i 4 --'%-27 ,~ - '.~ 2 ....,, 0 .- 4~.~ --9-4,-'- ,~-4 i ~-23 ~ ~--- 7 j S---t 2 ~.i 7.--~ 8-~ ,:)-9~ PERF' RECORD 8-~-9¢' DUAL BUR.,T TDT-P 8-7-90 COLLAR/F'ERF '7-~ i-9~: DIAGNOSTIC FM 8-i~-9~ PERF' RECORD 8- i i -9':~ COLLAR/PERF 8-9-9~, CNL-GR/CCL '?-27-9~ INUECTION PROFILE 8- i t -9~ COLL. AR/PERF 7-28-9G INJECT'ION F'ROF iI_E 8-5-9(~ CBT 8- 9- 9,3 C N L.-G R/C C L 8- ~ 2--9~ COLI..AR/F'Et;~F 7-25-9,;:) F'RODUCT I ON PROF I L E 8- 5--9(~, PERF' RECORD 7-26-.9~ DIAGNOSTIC; FM 8-- 4.-9 ~, PERFr REC:ORD 7-~),t-o(:~ F'RODUCT!ON PROF'ILE 8.-'7-9¢, CCL F'LE'.ASE SIGN' AND F;:.E"['UF.:N THE ATTACI"tED COPY HAVE A NICE DA¥'~ AU G ? 2 1990 ;~ALL_Y HOF'F-FCK EF,' A T 0 .- t .5 2 9 N~ 011 :& G~s Gons. I';om~i~'~,°~ Anchor'4~ RUN RUN RUN RUN RUN RUN RUN RUN 'RUN RUN RUN i;,'U N RUN F.:UN RUN RUN RUN i:;:O N RUN RUN AS RECEIF'T OF:' DATA. A F' P R 0 V E D TRAN.?¢- 9,~B.$ 'i ' $CH ~'CH ATLAS CA~.CO SCH ATI_A'S A'[ LAZ CAMCO ATLA:; CAMCO ,S'CFt SCH ATLAiJ ATI_A:~' CAMCO ~CH CAMCO ,~CH CAMCO DISTRIBUTION CENTRAl_ FILE'~'~. C;HEVRON D & M EXTENSION EXPLORATION Ex,..ON MARATHON MOBIL -.- F'H ILL. IF'S' F'B WELL FIL. ES R & D ¢- BF'X ,, ~'TA'I'E OF ALASKA TEXACO * THE AP l~: FOR ti-23 IS 50-~29--2 ** THE CORRECTED AF'I~ FOR t3-7 STATE OF ALASKA 0 ALASK/~" 'L/r 'D GAS CONSERVATION C~' ,VI_( ..... ]ON APPLICA, 1 ,,4 FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. Abandon Suspend Operation shutdown ....-- Re-onter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Variance Perforate Other 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1327' FNL, 295' FEL, Sec. 34, T11N, R15E, UM At top of productive interval 1672' FSL, 1448' FWL, Sec. 35, T11N, R15E, UM At effective depth 1467' FSL, 1508' FWL, Sec. 35, T11 N, R15E, UM At total depth 1449' FSL, 1513' FwL, Sec. 35, T11 N, R15E, UM 5. Type of Well Development X__ Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-1 9. Permit number 70-42 10. APl number 50 - 029-20078 11. Field/Pool Prudhoe _B_ay__Oil Pool 12. Present well condition summary Total depth: measured 9790 feet Plugs(measured) RECEIVEU true vertical 9039 feet Effective depth: measured 9749 feet AU~ 2 0 ~0 true vertical 9002 feet Junk(measured) ~.0~ ~ ~ ~ ~ Casing Length Size Cemented ~ ~"~e~ot~ept h Structural 80' 30" Cmt to surface 115' Conductor 1155' 20" 750 sx Fondu Flyash & 1185' 280 sx Fondu Neat Surface feet True vertical depth 115' 1185' Production Perforation depth: 2656' 13-3/8" 975 SX Fondu Flyash, 2686' 485 sx Cl G & 100 sx Fondu 2686' 9722' 9-5/8" 960 sx CI 'G' & 100 sx Fondu 9747' measured 9682-9696'; 9696-9708'; 9708-9709'; 9709-9721 '; 9721-9729' true vertical 8943-8955'; 8955-8966'; 8966-8967'; 8967-8978'; 8978-8985' 9000' Tubing (size, grade, and measured depth) 7", 269, L-80, IPCT @ 3009' MD; 5-1/2", 17#, L-80, IPCT @ 9184' MD Packers and SSSV (type and measured depth) Baker FB-1 packer @ 9063' MD; 7" Camco Bal-0 SSSV @ 2162' MD 13. Attachments Description summary of proposal Detailed operations program 14. Estimated date for commencing operation ~ September 1990 ' 16. If proposal was verbally approved Oil ~ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ '~' ~ Title Sr. Area Operations Engineer FOR COMMISSION URF ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance. Mechanical Integrity Test Subsequent form required 10- ~- ORIGINAL SIGNED 8Y LONNIE C~ SMITH _Approved by order of the Commissioner Commissioner BOP sketch x Form 10-403 Rev 06/15/88 15. Status of well classification as: Gas ~ Suspended I Approval No- ~?~ _~"~) 484 GB c: J. Gruber, ATO-1478 SH Approved Copy Returned SUBMIT IN TRIPLICATE Drill Site 4-1 Zone 1 Hydraulic Fracture Treatment · . e = . , PRELIMINARY PROCEDURE Arco Alaska intends to pump a hydraulic fracture treatment on well 4-1 as outlined below: Pull gas lift valves and replace with dummy valves. Pressure test tubing / casing annulus. Rig up fracturing service company· Pump propped fracture treatment at 40 BPM, using a cross linked water system, with approximately 76,000 lbs of 16-20 proppant. The pump schedule is outlined as follows: A. 775 Bbl B. 3 Bbl C. 8 Bbl D. 1 1 Bbl E. 2 8 Bbl F. 5 7 Bbl G 7 0 Bbl H. 8 6 Bbl I. 4 7 Bbl cross-linked water pad @ 1 PPG proppant concentration @ 2 PPG proppant concentration @ 3 PPG proppant concentration @ 4 PPG proppant concentration @ 6 PPG proppant concentration @ 8 PPG proppant concentration @ 10 PPG proppant concentration @ 12 PPG proppant concentration If necessary, rig up CTU and cleanout to PBTD. Install gas lift valves. RECEIVED / JJt3 2 o 1990 ~mchorage Open well to flow gradually increasing the drawdown to allow proper fracture healing. ,5 4 2 C01LED 'I'UB]Nt3 UNIT BOP E0U ! PMENT 1. ~d:)00 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. ~d:)O0 PSI 4 1/6" SHEAR RAMS 5. ~)00 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX N]REL]NE BOP EoU]PHENT i i 1. 5000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELIN[ RAIaS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-Olrlr STATE OF ALASKA ALASK/¥ 'L(' '9 GAS CONSERVATION C~' MI(~ :ON ~ REPORT' F' UNDRY WELL OPERArlONS 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 1327' FNL, 295' FEL, Sec. 34, T11N, R15E, UM At top of productive interval 1672' FSL, 1448' FWL, Sec. 35, T11N, R15E, UM At effective depth 1467' FSL, 1508' FWL, Sec. 35, T11N, R15E, UM At total depth 1449' FSL, 1513' FWL, Sec. 35, T11N, R15E, UM 5. Type of Well Development Explorat~/ Stra~raphic 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-1 9. Permit number/approval number 70-420/90-065 10. APl number 50 - 029-20078 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9790 feet Plugs(measured) 9039 feet Effective depth: measured 9749 feet true vertical 9002 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Structural 80' 30" To sudace 115' 115' Conductor 1155' 20" 1030 sx Fondu 1185' 1185' Sudace 2656' 13-3/8" 1075 sx Fondu & 485 sx Cl 'G' 2686' 2686' Production 9724' 9-5/8" 960 sx Cl 'G'& 100 sx Fondu 9747' 9000' Perforation depth: measured 9682-9696'; 9696-9708'; 9708-9709'; 9709-9721 '; 9721-9729' 8967-. j8978,8978-8985' true vertical 8943-8955'; 8955-8966'; 8966-8967'; ' :~ " , Tubing (size, grade, and measured depth) 7", 26~, L-80, IPCT @ 3009' MD; 5-1/2", 17#, N-80, NPCT @ 9184' MD Packers and SSSV (type and measured depth) Baker FB-1 packer @ 9063' MD; 7" Camco Bal-0 $SSV @ 2162' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Reoresentative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Shut in. Tubing Pressure Subsequent to operation Shut in for pending rig workover. 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations _._ Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-~'~- ~'~' ~ Form 10-404 Rev 06/15/88 Service Title Sr. Area Operations Engineer Date SUBMIT IN DUPLICATE 486 DCR c: J. Gruber, ATO-1478 SH DS 4-01 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR WATER SHUT OFF 2/23/90 : MIRU CTU & Stimulation Equipment. PT equipment to 4000 psi. RIH w/CT & performed a fill cleanout. Jetted down to 9727' MD. Loaded wellbore w/206 bbls of seawater, then washed perforations at: 9480' - 9500' MD Ref. Log: BHCS 12/27/70. 9506' - 9542' MD 9557' - 9578' MD 9627' - 9647' MD 9654' - 9678' MD 9682' - 9721' MD Pumped: 61 bbls 12% HCI w/10% Xylene, followed by, 60 bbls 12-3% HCI-HF, followed by 59 bbls 12% HCI. Flushed w/Seawater & Meth-Water. POOH. Rigged down. 2/24/90 : A CTU Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4200 psi. RIH w/CT and fluid packed wellbore w/seawater. Pumped 91 bbls cement, squeezing perforations at: 9480'- 9500' MD Ref. Log: BHCS 12/27/70. 9506' - 9542' MD 9557' - 9578' MD 9627' - 9647' MD 9654' - 9678' MD 9682' - 9721' MD Placed 32 bbls of cement behind pipe at 3000 psi maximum squeeze pressure. Contaminated cement w/Biozan, and reversed out contaminated cement. POOH. 2/25/90 : RIH, & tagged bottom at 9730' MD. POOH. RD. RD. The well was not returned to production. A Rig Workover was performed during June/July 1990 to install a new 7" x 5-1/2" tubing completion, and GLV design (Apprvl # 90-355). This work has been reported under a separate Report Sundry. A Hydraulic Fracture Treatment is scheduled for October 1990 pending approval. ARCO ALASKA, iNC. F'. 0 . BOX i ,:-_'.,G¥60 ANF:HORAGE, ALA£KA 995t DATE' '7-50-90 REFERENCE' ARCO CASED HOLE FINALS' F'LUIi) RE£I£TIV'ZTY FLUID RESISTIVITY PERF-' REC:ORD F'EF:F F;.'.EC 0 RD (":B 'i- CE T C-R IN CASING F' F' F;,' F F;:ECORD C O i... L.. A R / F' E R F C:OI_LAR F' L. tJ l D R F £' I S T I V I T Y C I.-i R iF: S I S T I V I T Y F' L U I I) R E :';' I :':/T ]: V I T Y C.O LLAi';.:/F'ERF C E.' L. L. A R," P E RF RUN i; RLJN i, RUN R I f i'...~ .... s o..-' RUN F;,'UN i , 2 RUN i , RUN i , _, RLii'"-.! i , ~'-.,. F< I..I i"-.J, i , ':::_.'" F,' I_.,t ~,~ i , ':~.," F('.tJ N i: I;..'UNi, 5" F;.'.t tN i , ~'"" .... PLEASE ZI(.;.N AND RETURN 'Fl..liE ATTACHED COF'Y AZ RECF:IF'T OF' DATA., .., . HAVE A NiCE DAY! SALLY HOF'F:EC:KER A 'F 0 '- '~. ':~'..,- .-":' ':;', '::J C Pi '<,.,' ~'/_: £CH .£ :.':::: H ,y i...: SCH S C i-.i SC:H A 'i' i... A S A i' LA,S' ,S: C H S C i.-i ,.*:...' C I--I ATL. AS · Ia I i.,.IBLJTION L':FZN'¥R AL FILES CHEVRON D & M EXTFNSiON EXPLORATION EXXON MARAI'HON MOBIL P FI ! L L I F'S F'B WELL F'IL. ES R & D BPX STA'f'E OF' AL. ASKA TEXACO " ~- --O~LAND GAS CONSERVATION COMM I REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Stimulate __ Plugging __ Perforate Alter casing __ Repair well Pull tubing X Other__)~_ Workover 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc. Exploratory _ 64' Rt~I~ f~et 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1327' FNL, 295' FEL, Sec. 34, T11N, R15E, UM 4-1 At top of productive interval 9. Permit number/approval number 1672' FSL, 1448' FWL, Sec. 35, T11N, R15E, UM 70-42 / 90-355 At effective depth 10. APl number 1467' FSL, 1508' FWL, Sec. 35, T11N, R15E, UM 50-029-2007~ At total depth 11. Field/Pool Prudhoe Bay Field 1449' FSL~ 1513' FWL, Sec. 35, T11N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 9790' feet Plugs (measured) Squeezed: 9600'-700 sx Class G true vertical 9039' feet 9380'-200 sx Class G 9268'-100 sx Class G Effective depth: measured 9749' feet Junk (measured) None true vertical 9002' feet 0 fl ~ G ~ ~t~ , [d~e~ph~ Casing Length Size Cemented Measured depth True vertical t Structural 80' 30" Cmt to surface 1 1 5' 1 1 5' Conductor 11 55' 20" 750 sx Fondu Flyash & 1 1 85' 11 85' 280 SX Fondu Neat Surface 2656' 1 3-3/8" 975 sx Fondu Flyash, 2686' 2686' 485 sx Class G & 100 sx Fondu Production 9724' 9-5/8" 510 sx Class G, 9749' 9002' 100 sx Fondu Flyash & 450 sx Class G Perforation depth: measured None open to production true vertical None open to production Tubing (size, grade, and measured depth) 7" / 5-1/2", L-80, w/tail @ 9184' Packers and SSSV (type and measured depth) Baker 'FB-I' pkr ~ 9063', Camco 'BaI-O' sssv @ 2162' i3. Stimulation or cement squeeze summary . ~""~-,' .~ ~ N/A ~ ~'~' ~ ~': InterVals treated (measured) Treatment description including volumes used and final pressure ~ i4. N/A Recresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation , 15. Attachments *WORKOVER WELL HISTORY 16. Status of well classification as: Copies of Logs and Surveys run ~ Water Injector ~ Daily Report of Well Operations X* Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~:~ ~ ~/~ f~.Jt~/ Title Drillin~ Analyst Date Form 10-404~lev 05/17/89 SUBMIT IN DUPLICATE Well History - Initial Report- Dally lastnJctJoal: Prepare end lul~nlt the "lll~Jll I%IIN)IT' on the firm Wedneldly efte/ i well Ii I~Jddld or wmtq)ver opereUonl ill Itlrted. Delly work prior to IPuddlng Ihould be lummarized on the form giving Inclullve dlte~ only. Dtstrict ARCO ALASKA INC. Field PRUDHOE BAY NORTH SLOPE L,m o, unit ADL: 28324 TiUe WORKOVER State Auth. or W.O. no. AS2815 API: 50-029-20078 Dictator ARCO Spudded or W.O. begun ACCEPT 06/17/90 1600 IARCO W.I. 0. 0000 Prior Itmtus if I W.O. t)ele end depth es of 8:00 a.m. 06/18/90 ( TD: 0 PB: 9739 SUPV:HMP 06/19/90 ( TD: 0 PB: 9739 SUPV:HMP 06/20/90 ( TD: 0 PB: 9739 SUPV:HMP 06/21/90 ( TD: 0 PB: 9739 SUPV:ZR 06/22/90 ( TD: 0 PB: 9739 SUPV:ZR 06/23/90 ( TD: 0 PB: 9739 SUPV:ZR Gomplet .... d ~y NU BOP M~: 8.5 Seawater ACCEPTED RIG @ 1600 HRS, 6/17/90. MIRU NABORS 2ES. PULL BPV. CIRC SEAWATER TO KILL WELL. SET BPV. NU BOPS. DAILY:S91,135 CUM:$91,135 LD TUBING FINISH NU BOPE. TEST BOPE. SAME. POOH LD TBG. ETD:S91,135 EFC:$1,516,000 MW: 8.5 Seawater PULL HANGER TO FLOOR AND LD DAILY: $22,668 CUM: $113,803 ETD: $22,668 EFC: $1,607,135 LD SEAL ASSEMBLY MW: 8.5 Seawater LD 5-1/2" TUBING. MU OVERSHOT ON DP AND RIH. TAG JUNK ABOVE TUBING STUB AND WORK DOWN TO TUBING STUB @ 8990' MD. ENGAGE STUB AND JAR SEAL ASSEMBLY FREE FROM PKR. POOH, LD TUBING AND SEAL ASSEMBLY. DAILY: $24,670 CUM: $138,473 ETD: $138,423 EFC: $1,516,050 LD PKR ASSEMBLY MW: 8.5 Seawater RIH W/OVERSHOT F/SBR. ENGAGE SBR AND ROTATE TO RELEASE K-ANCHOR. POOH, LD SBR AND K-ANCHOR. RIH W/PKR MILL AND PRT. MILL PKR. CIRC OUT GAS. POOH, LD PKR ASSEMBLY. DAILY: $21,845 CUM: $160,318 ETD: $160,318 EFC: $1,516,000 *RIH W/CASING CUTTER MW: 8.5 Seawater POOH W/PKR ASSEMBLY. RU ATLAS. RIH W/8.29" GR/JB TO 9250'. RIH AND SET CIBP @ 9210'. RIH W/SBT/CCL/GR AND LOG FROM 6100' TO SURFACE. RD ATLAS. MU 9-5/8" RTTS W/FO CLOSING FINGERS AND RIH. TOOK 20000# TO GO THRU FO @ 1903'. SET RTTS @ 2437'. TEST 9-5/8" BELOW RTTS TO 3000 PSI F/30 MIN. PRESS TST 9-5/8" ABOVE RTTS TO 3000 PSI F/60 MIN. RELEASE RTTS AND POOH. PULL TBG HNGR SUPPORT BUSHING AND 9-5/8" PACKOFF. MU 9-5/8" MECHANICAL CASING CUTTER AND RIH. COULD NOT GET PAST FO @ 1903'. POOH, MU MULTI-STRING CSG CUTTER AND RIH. DAILY: $57,155 CUM: $217,473 ETD: $217,473 EFC: $1,516,000 POOH & LD 9-5/8' CSG MW: 8.5 Seawater LD MECH CSG CUTTER. PU & RIH W/ MULTI-STRING CSG CUTTER. DISP WELL TO OBM TO 2500'. CUT 9-5/8" e 2300'. POOH & PU & RIH W/ SPEAR. ENGAGE & PULL CSG. NO GO. POOH & RIH W/ MECH CUTTER. CUT CSG @ 1840'. POOH. RU & PULL 9-5/8" CSG · LD SAME. DAILY: ~21,768 CUM: $239,241 ETD:SO EFC: $1,755,241 The above Is correct Drilling, Pages 86 and 87. rumberall prepared for each well. as they are dally well history forms consecutively Page no. AR3B-459-1-D ARCO ..a .asCompany Daily Well History--Interim Instmclionl: This form ia used during drilling or workover operations. If tasting, coring or perforating, show formation name in desCribing work perforated. Number ail drill stem tests sequent ally. Attach descr ption of all cores. Work performed by Producing Section will be reported on "lnlerlal" sheets until final completion. Report official or representative test on "Final" term. t) Submit -Inllrlm" sheets when filled out but not less frequently than every 30 days, or on Wednesday of the week in which oil string is set. Submit weekly for workovere and following setting of oil string until completion. District ARCO A:~SKA INC. IC°unty °r Parish NORTH SLOPE Istate ~ Field pRLTD.OE ~},y IL ..... Unit DS 4-~ Iwelln°' I I as of 8~ a.m. 06/24/90 ( TD: 0 · B: 9739 SUPV:ZR 06/25/90 ( TD: 0 PB: 9739 SUPV:ZR 06/26/90 ( TD: 0 PB: 9739 SUPV:ZR 06/27/90 ( TD: 0 PB: 9739 SUPV:ZR 06/28/90 ( TD: 0 PB: 9739 SUPV:HMP 06/29/90 ( TD: 0 PB: 9739 SUPV:HMP 06/30/90 ( TD: 0 PB: 9739 SUPV:HMP The above is ~u,,ect ~ For form ~epar~tion and distribution 10) 11) 12) 13) MW: 8.5 OBM POOH W/ 9-5/8" CSG. C/O & TEST RAMS. RIH W/ 9-5/8" SPEAR. JAR CSG. NO GO. POOH WET. RIH W/ SPEAR & CUTTER. CUT CSG @ 2315'. COULD PULL LOOSE. PULL UP HOLE & RESET GRAPPLE/SPEAR. RIH W/ SPEAR & PACK-OFF. ATTEMPT TO CIRC THRU CUT CSG. SET SPEAR AND JAR. NO MOVEMENT. POOH & PU MECH CSG CTTR. RIH TO 1990' & CUT CSG AGAIN. POOH W/ CTR. DAILY:S21,779 CUM:$261,020 ETD:SO EFC:$1,777,020 MILL 9-5/8" CSG MW: 8.5 WBM CONT TO POOH W/ 9-5/8" CSG. RIH W/ SPEAR & ENGAGE CSG. JAR FREE & POOH. LD 9-5/8" STUB, FO,CSG PATCH, i JT & CSG STUB. RIH W/ GRAPPLE & SET @ 2000'. JAR. NO MOVEMENT. POOH & MU CSG MILL. RIH TO TOF @ +/-1990'. DISP TO SPUD MUD. MILL CSG F/ 1984' TO 1995'. MILLING @ +/- 20 FPH. DAILY:S27,957 CUM:$288,977 ETD:SO EFC:$1,839,322 RIH W/ OVERSHOT MW: 8.5 WBM MILL 9-5/8" CSG F/ 1995' TO 2105'. TWIST OFF DP. MU O-SHOT & ENGAGE FISH. POOH W/ DP & BHA. LEFT 14 DC & MILL IN HOLE. MU O-SHOT & TIH. DAILY:S46,391 CUM:$335,368 ETD:SO EFC:$1,885,713 MILL 9-5/8" CSG MW: 8.5 WBM MU O-SHOT & RIH. ENGAGE BHA FISH & POOH. LD BHA & INSPECT ALL CONNECTIONS. RIH W/ 48 JTS 5" CLASS G DP. TAG FILL @ 2075' & WASH/REAM TO 2104'. MILL CSG F/ 2104' TO 2180'. DAILY:S27,135 CUM:$362,503 ETD:SO EFC:$1,912,848 RIH W/ CSG MILL MW: 8.5 WBM MILL 9-5/8" CSG F/ 2180' TO 2324'. CBU. POOH & SLM. PU NEW MM MILL. RIH W/ SAME. DAILY:S28,816 CUM:$391,319 ETD:SO EFC:$1,941,664 MILLING CASING @ 2397' MW: 8.5 WBM RIH W/ MILL. COULD NOT EST CIRC. POOH WET. CLEAN OUT CMT & CTNGS F/ BHA. RIH. MILL CSG F/ 2324' TO 2392' DAILY:S28,846 CUM:$420,165 ETD:SO EFC:$1,970,510 POOH W/ BIT & SCRAPER MW: 8.5 WBM MILL CASING F/ 2397' TO 2425'. CBU. POOH & CO MILL. RIH. WASH & REAM TO TOP OF CSG. MILL SAME F/ 2425' TO 2445'. CBU. POOH. MU BIT & SCRAPER. RIH TO 2445. CIRC & COND MUD. POOH. HANG UP ON FO & CSG PATCH. DAILY:S28,847 CUM:$~44%0~- ETD:SO EFC:$1,999,357 .. J~.~ ~.~ J~it,e grJJJJng ~upt. see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B JNumber all daily well history forms consecutively no. as they are prepared for each well. I Daily Well History--Interim Inltmctloel: This form is used during drilling or workover operations. If testing, coring, or perforating, show formalion name in describing work perfom~eq. Number all drill stem tests sequentially. Attach description o! all cores. Wo~ performed by Producing Section will be regorted on "ln#rfm" sheets until final completion. Report official or representative test on "Fl~el" form. 1) Submit "latiUm" sheets when filled out but not less frequently than ever~ 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workowerS and following setting of oil string until completion. District ]County or Parish IState ARCO ALASKA INC. NORTH SLOPE AK Field ILease or Unit lwell no. PRUDHOE BAY DS 4-1 Date and depth Complete record for each day while drilling or workover in progress as of s:m a.m. NABORS 2ES 07/01/90 ( TD: 0 PB: 9739 SUPV:HMP 07/02/90 ( TD: 0 PB: 9739 SUPV:HMP 07/03/90 ( TD: 0 PB: 9739 SUPV:HMP 07/04/90 ( TD: 0 PB: 9739 SUPV:HMP 07/05/90 ( TD: 0 PB: 9739 SUPV:MDD 07/06/90 ( TD: 0 PB: 9739 SUPV:MDD 07/07/90 ( TD: 0 PB: 9739 SUPV: MDD Tho above is correct ~, For form ~epera~ion and distribution see Procedt~res Manual Section 10, Drilling, Pages 86 and 87 L4) L5) L6) ).7) 18) 19) 2O) MU 9-5/8" CSG SPEAR MW: 8.5 WBM POOH & LD BIT & SCRAPER. PU WASH PIPE & WASH OVER 9-5/8" STUB. CBU. CLOSE ANNULAR & PRS 13-3/8'. PUMP 2.5 BPM @ 690 PSI. POOH. MU TRI STATE BACK OFF TOOL & RIH W/ SAME. SET TOOL AND BREAK CSG CONN @ 2464'. POOH W/ BACK OFF TOOL. PU 9-5/8" CSG SPEAR. DAILY:S33,030 CUM:$482,042 ETD:SO EFC:$2,032,387 NU BOPS MW: 8.5 WBM RIH W/ CSG SPEAR. ENGAGE STUB AND BACK OUT SAME. POOH. LD STUB & FISHING TOOLS. RIH W/ FO CLOSING FINGERS & RUN THRU FO @ 1117'. CLOSE ANNULAR & EST INJ RATE THRU 13-3/8" SHOE. SET RTTS BELOW FO & CSG PATCH. TEST ABOVE TO 2000 PSI. POOH & LD BHA. MU STORM VALVE W/ RTTS. SET @ 24'. ND BOP. NU NEW CSG HEAD. TEST. NU BOPS & TEST SAME. DAILY:S28,548 CUM:$510,590 ETD:SO EFC:$2,060,935 ENGAGE 9-5/8" CSG PACKOFF MW: 8.5 OBM NU BOPS & TEST SAME. PULL & LD RTTS. CO RAMS. RUN 58 JTS 9-5/8" CSG. REV OBM INTO HOLE. ENGAGE & MU TSA TRIPLE CONN TO 9-5/8" CSG STUB. WORK TORQUE DN. PRESS TEST CSG TO 2000 PSI, THEN 3000 PSI F/ 30 MIN. OK. ND & LIFT STACK SET CSG SLIPS. DAILY:S155,375 CUM:$665,965 ETD:SO EFC:$2,216,310 MILL CIBP @ 9210 MW: 8.5 FSW CUT 9-5/8" CSG @ SURF. LIFT BOPS & INSTALL 9-5/8" PACK OFF. JACK UP RIG & INSTALL 11X 13-3/8 ADAPTER FLANGE. NU & TEST BOPS. MU MILL & BHA. RIH & MILL CIBP @ 9210. DAILY:S166,057 CUM:$832,022 ETD:SO EFC:$2,382,367 POOH MW: 8.5 FSW MILL ON JUNK AND EZSV. PUSH SAME TO 9739' MD. TEST CSG TO 1500 PSI (150 PSI LOSS). POOH SLM. DAILY:S47,294 CUM:$879,316 ETD:S913,661 EFC:$1,516,000 MU PACKER AND TAILPIPE ASS'Y MW: 8.5 FSW FINISH POOH. LD MILL AND PU SCRAPER. RIH TO 9739' MD. CIRC INHIBITED SEA- WATER AROUND. POOH. MU PACKER AND TAILPIPE ASS'Y. DAILY:S41,936 CUM:$921,252 ETD:S955,597 EFC:$1,516,000 RIH W/COMPLETION ASS'Y MW: 8.5 FSW RIH W/PACKER AND TAILPIPE ASS'Y. SET SAME AT 9050' MD. POOH LDDP. RIH W/5-1/2" BY 7" COMPLETION ASS'Y. I O'~ '~J..~ (~ ITitle Drilling Supt AR3B-459-2-B Number all daily well history forms IPage no. ,as they are prepared for each well. consecutively ARC~: ~i .d Gas Company (,./ally Well History-Final Report laetmalioal: Prepare and lubmlt the "Flail R~ell" ~ the fires Wednesday after allowable has been Illigned or well il Plugged, Abandoned, or ~old. "Filial RIilelT' should be lubmifted also when oPeretlons ere lUlpended for ~n indefinite or appreciable length of time. On work~vem when ~ official reit II m~ required upon completion, report completion end representative test date In blocks provided. The "Flail Rl~ell" form may be used for mpo~ting the Ifltif~ operation if apace is available. District ICounty or Pedsh ARCO ALASKA INC. I NORTH SLOPE I Field PRUDHOE BAY IL.se or uni~ ADL : 28324 I Auth. or W.O. nOAs2815 [Title WOR~OV~R A~I: 50-029-20078 Op. ro,or ARCO IA...Co. W.,. 0. 0000 I Spudded or W.O. begun IDem ACCEPT I 06/17/90 Date end depth Complete record for each dly reported as of 8.'00 a.m, ]~I~BO]:~.~ 2ES 07/08/90 ( TD= 0 PB: 9739 SUPV:MDD IAccounting State COlt center code Iotal number of wells (active or inactive) on this, cst center prior to plugging and / bendonment of this well I Prior status our 1600 I if · W.O. 1) RIG RELEASED M~: 8.5 FSW FINISH RIH W/5-1/2" X 7" COMPLETION ASS'Y. TEST TUBING F/30 MIN. OK. ATTEMPT TEST CSG/PACKER F/30 MIN. SOS SHEARED. DID NOT GET 30 MIN TEST. ND STACK. NU TREE. TEST TREE, ALL CONTROL LINES. OK. SET BPV. SECURE WELL. RELEASE RIG. ***RIG RELEASED 0030 HRS 7/8/90. NOTE: CAMCO 'BAL-O' SSSV @ 2162', BAKER 'FB-I' PKR @ 9063', & TT @ 9184' DAILY:S215,382 CUM:$1,180,525 ETD:S1,180,525 EFC:$1,516,000 Old TD Released rig INew TD I PB Depth Date IKind of rig Type completion (single, dual, etc.) Official reservoir name(s) Classifications (o11, gas, etc.) Producing method Potential test date Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Ga~ per day Pump size, SPM X length Choke Ilze T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct ' A ~*~ ~ I Sign.~~~~ Title For form ~paratl .... d distribution, ~ ' ['' s~ Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all dally well history forms I no. as they are prepared for each well. consecutively I Page Division of AtlentlcRicldleldComplny STATE OF ALASKA .~,~' ~ 0 ~. ALAS~~ OIL(" 'D GAS CONSERVATION( Mat ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon .~. Suspend Operation shutdown Re-enter suspended well Alter casing Repair well -.,.- Plugging Time extension Stimulate Change approved program Pull tubing Variance Perforate X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic 4. Location of well at surface Other 6. Datum of elevation(DF or KB) 64 feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1327' FNL & 295' FEL, Sec. 34, T11N, R15E, UM At top of productive interval 1672' FSL & 1448' FWL, Sec. 35, T11N, R15E, UM At effective depth 1467' FSL, 1508' FWL, Sec. 35, T11N, R15E, UM At total depth 1449' FSL, 1513' FWL, Sec. 35, T11N, R15E, UM 4-1 9. Permit number 70 -42 10. APl number 5O - O29-20O78 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9790 feet 9039 feet Plugs(measured) None Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 115' 1185' 2686' 9749 feet 9002 feet Junk(measured) Size Cemented 30" To sudace 20" 1030 sx 13-3/8" 2090 sx 9749' 9-5/8" 1060 sx measured All perforations squeezed. true vertical All pedorations squeezed. Tubing (size, grade, and measured depth) 7"/5-1/2"; L-80 tubing w/tail @ 9166 !'MD Measured depth True vertical depth 115' 115' 1185' 1185' 2686' 2686' 9749' 9002' JUL o 1990 "~ias~(a Oil & Gas Cons. C0mm[~ss~r~ ~ gnch'0ra~ Packers and SSSV (type and measured depth) Baker "SAB" packer @ 9050'MD; Camco SSSV @ 2200'MD 13. Attachments Description summary of proposal ... X Detailed operations program ... BOP sketch X 14. Estimated date for commencing operation ~ July 1990 16. If proposal was verbally approved Oil X Name of approver Date approved Service 17. t hereby certify that the foregoing is true and correct to the best of my knowledge. ..Signed ~ ~. '~"~ ,~ ~_e~v~ ~,.~ ~"'o#'//- Title Senior Area Engineer .. ~'//~/ FOR COMMISSION [J~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Approved by order of the Commissioner Form 10-403 Rev 06/15/88 15. Status of well classification as: Gas. Suspended Subsequent form required 10- ~¢c~ ORIGINAL $1GNE0 BY LONNIE C. SMITH Date WDM/SUN/nb I Approval No.p~)., ~-o~ / Commissioner Approved Copy FLetumed .~ ~ Date rT]/~)/q{~ SUBMIT IN TRIPLICATE ARCO Alaska, Inc. proposes to perforate DS 4-1 at selected intervals within the Sadlerochit formation. All previous perforations were squeezed for profile modification purposes, and the well has recently undergone a rig workover to repair a 9-5/8" casing leak. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Interval: 9682'- 9733' Ref: BHCS 12/27/70. WDM: 7/6/90 RECEIVE? J U L 0 ,,~ 1990 ~i~eska Oil & Gas Cons. Commiss/or~ Anchorag~ 4 3 2 1. $000 PS1?" WCLLHr,.AD CONN[C10R IrLANG[ 2. 5000 PS1WIR[LIN£ RA~$ (VARL~BLE $1ZI~) 3. 5000 PS14 1/6" LUBRICATOR 4. sooo Ps~4 ¥~" flow TUB[ PACK-orr Cons. Anchora~a TO: THRU: DATE: FILE NO: July 5, 1990 JT.HH. 75.5 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection AAI PBU DS 4-1 Permit No. 70-42 Pruhdoe Oil Pool FROM: Harold R. Hawkins /J~ -~ Petroleum Inspector J:i? ~z~/ Friday June 29, 1990: I went to AAI PBU DS 4-1 to inspect Nabors 1ES BOP equipmenti ~"6~hecked the rig from the floor to the cellar. Everything looked o.k. without a witnessed BOP test. Henry Peterson was the operator and Charlie Henley was the toolpusher. This well is on completion work. In sum~_ary, the BOP system and components looked satisfatory on Nabors I-ES without a witnessed BOP test by the State. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 P ~ 0., BC)X i 0,::.:,..'::;60-~r'~ A N C: H 0 R A F; E, A L. A ,5: K A 9~,- .., 1 0 DATE' 6/27/90 I:::EFERENCE' ARCO CASED HOL_E I::'INAL. S' .... i 6--2J -90S'EGMEN'¥'E:I) BCINDiGR/CCL. 4- i 6.-2 i -90 CCL i .... i 8 6-' 8- 90 F'E R F' .... A-..'~ ~ c,,c~ F:BT i2 .... i ,' ,. ,-.'"', .... 2 .... i 7 6-'2i --90 BRIi)[;i::: PL..U[: F;.'.LECOI4,'D 4-5. <:--i' 7-9e N. OI .-. <' l:.-x ....... J J: iq F:' ..,.':": .... ...,'z 6 '-" 2 i --' '";', ,':',.., (:; R /C C L.. ,:-..... .... a'~ 6-'" 2 i .- <;', ¢,.... P E R I:: R E C 0 R D 6 '.-' '-,23; 6 '.-- 20 - 90 C E: 'i"/G R 6'"-2::5 6'-'-':,:'0""9 e CBT 6 .... '2:3 6-'-'2':")-'-9,?) F' K R S E '1"'i" I N G R E C [.t R D F:'I...EASE SJ:C-'.N AND RE"f'LJRN Tt'iiE AT"I"ACHtE~:OPY' AS F;.:FZCE:[F:'i' O1::' DA'f'A. I I: '" . ............................ ~...,, ,,,,.,,, ,.,, .,, R E: C E: ]: v 1:. D B Y t..tAVFZ A N:I:CE DAY! ;ii: A L.. L.. Y 1"10 F F:' E C K E R A T 0 .... ! 5 2 9 RECEIVED d U L - 2 1990 Alaska Oil & Gas Cons. Commission Anchorage D I ;:: T R :[ B U '1' I 0 N '"' C': E N .... ' '" · ,,. 1 I",,-.l 1... I:r :!: 1.. E S · ,,.'"' C i"1 ti!: V R 0 N D & H · ,,.'"' iE .':.<. 'f' F.i: N S' I O. N E X P l... 0 R A 'f' I 0 N :~: E X X 0 N ?'t A R A 'T'H 0 N :~: H 0 B I I... :[: F:' Ft I I.. L.. :1: F:' 6.'.' F:' B W I:.".' L.. i... F:' :1: L.. L:L $ F;,' & D :,",: B F-'X S' TA T E: 0 F' A L.. A,S' K A 'f'E X A C 0 ATLAS A'i L. A S t.-t i..'":.; SC:H, :i.;' C t-.t ;5;' (:'; l--i ,? C; H .'.:.:: C J-.i ;::: C H ;!'.; C f..i ARCO ALASKA, F'.O. BOX ANCFiORAGE, ALASKA DATE' 6/22/90 ' ~.A~.ED HOLE FINALS REFERENCE ARCO R' ¢- t-5 6-5-9'0 F'RODLICi'ION F'ROFILE RUN i, 5' ~ · ,,,,r '"" ~"~ I i t ¢, 6-i'7-c--'A CULl_AR RUN t, 5 4-i 6-i5-96~ CCL. RUN t, 5' 4-i '::.:' 6-i i -"..'?0 iS./R £URVEY RUN ~'.-~'~ 6-i 6-90 COLLAR RUN i , _,~;" ._. ....' i 8 6-t 0-90 DUAL BUR$"i' 'T'DT=F' RUN i 5' 6---"~,'-'',~.. .. 6- i i --c~n, .. DitAL.. BUR~T TD T- F' RUN "" '~"$ 6-i 3-96' DUAL B~JRST 'l'D'l'-F' RUN i ':~ i 2-i 7 6-i 5-9(') COL. LAR RUN i i.S'-i2 5-~'~i-9e L. EAK DETE..I.[ON SLIRYEY RUN i iS-SS 6-6-9.0 F'UMF'-IN TEMF' F'LOW RUN i, 5" CAMCO A'I'I_A:S' ATL. AJ¢ C A M C 0 A'FLA~! $CH $CH ~'CH CAMCO CAMCO F'I_EA;.?E SIGN AND I;:ETURN 'THE ATTACHED COPY AS RECEIF'T OF DATA. ;~AI...L.Y H JF F EUK ER A'i"O- t 529 JUN 2 T 1990 Alaska Oil & Gas Cons. Gommission Anchorage · AF'F'ROV ~ ED _ .- TRAN$~ DISTRIBUTION uEt.tR~L FILES 'ir '"'-.. CHEVRON D & M EXTENSION EXF'LORH~ION '~ EXXON MARATHON · ~ MOBIL PHILLIPS PB WELL F'ILES R & D BF'X STATE OF ALA£'I<A TEXACO "'.~ '' , ~ STATE OFALASKA ~ 0 ~ o. cous..vA ,o, cou .,,s o. APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing X Repair well _ Plugging _ Time extension _ Stimulate t Change approved program _ Pull tubing ..~ Variance _ Perforate _ Other :X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development .~. ARCO Alaska. Inc. Exploratory _ RKB t~4' feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1327' FNL, 295' FEL, Sec. 34, T11N, R15E, UM 4-1 At top of productive interval 9. Permit number 1672' FSL, 1448' FWL, Sec. 35, T11N, R15E, UM 70-42 At effective depth 10. APl number 1467' FSL, 1508' FWL, Sec. 35, T11N, R15E, UM 50-029-20078 At total depth 11. Field/Pool Prudhoe Bay Field 1449' FSLr 1513' FWLr Sec,. 35~ T11N~ R15Er UM Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 9790' feet Plugs (measured) Squeezed: 9600'-700 sx Class G true vertical 9039' feet 9380'-200 sx Class G Effective depth: measured 9749' feet Junk (measured) None 9268'-100 sx Class G true vertical 9002' feet CTU sqz all prod perfs Casing Length Size Cemented Measured depth True vertical depth Structural 80' 30" Cmt to surface 1 1 5' 11 5' Conductor 11 55' 20" 750 sx Fondu Flyash & 11 85' 11 85' 280 SX Fondu Neat Surface 2656' 1 3-3/8" 975 sx FondU Flyash, 2686' 2686' 485 sx Class G & 100 sx Fondu Production 9724' 9-5/8" 510 sx Class G, 9749' 9002' 100 sx Fondu Flyash & 450 sx Class G Perforation depth' measured None open to production RECEIVED true vertical None open to production 1 5 199,? Tubing (size, grade, and measured depth ' 5-1/2"/4-1/2", N-a0, w/tail @ 9204' Naska.0ll&GasC0ns. CmmlsSi0~0 Packers and SSSV (type and measured depth) "~,nch0ra~ Baker 'SAB' pkr. @. 9076', Otis 'RQY' sssv @ 2186' 13. Attachments Description summary of proposal .~ Detailed operation program ~ BOP sketch , , , 14. Estimated date for commencing oPeration 15. Status of well classification as: Mav 29, 1990 ..... Oil ..~ Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is 'true and correct to the best of'my knowledge. Signed ~(~/YIIM,.j' ~ Title Drilling] Analyst Date / '" 'FOR COMMISSION USE ONLY Conditions(~ approval: Notify Commission so rePresentative may witness IApproval No. Plug integrity _ BOP Test _ Location clearance__ I ~:~ ~'' Mechanical Integrity Test _ Subsequent_form re.qujre 10- '~ ~pprovea ~opy Returned Approved by, the order of the Commission . .... ~ -2~- ~:~C.~ Commissioner Date~'-~ ~.~ Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH SUBMIT IN TRIPLICATE OBJECTIVES: PRIOR TO RIG.UP: DS 4 - 1 WORKOVER PREUMINARY PROCEDURE · Pull the 5-1/2" completion and recover the SBR. · Mill and Retdeve the 9-5/8" Baker'SAB' permanent packer. · Set a 9-5/8" ddllable BP above the perfs at 9200'. · .Cut, Pull and Repair the 9-5/8" casing to +_2500'. · Drill the BP at 9200' and clean out to PBTD. · Run a new 7" X 5-1/2" completion with GLM's. A Pre-Rig CTU squeeze is expected to have been performed pdor to the workover. Coordinate with the wireline group and perform the following slickline and E-line work: · Pull the Otis SSSV at 2186'. · Jet cut the 5-1/2" tubing pup between the SBR and the K-Anchor at d:9085' MD. PROCEDURE: 1. MIRU Nabors 2ES. Kill and displace the well with 8.5 ppg seawater. 2. ND Tree. NU and test BOPE. 3. Pull and LD the 5-1/2" completion and SBR. 4. PU 3-1/2" DP and retrieve the 5-1/2" tubing pup stub and the K-Anchor. 5. Mill and retrieve the Baker 'SAB' permanent packer at 9090' MD. 6. RIH and set a drillable BP at 9200'. 7. RIH w/RTTS and isolate the 9-5/8" casing leak above 2500'. Test the 9-5/8" casing below the leak to 3000 psi. POH and LD the RTTS. 8. Cut, pull and replace the 9-5/8" casing below the DV at 2422'. 9. Drill the BP at 9200' and dean out to PBTD. Displace the hole to clean inhibited seawater. 10. Set a 9-5/8" permanent packer. POH and LDDP. 11. Run a 7" X 5-1/2" completion stdng with GLM's. 12. Freeze protect the permafrost interval with inhibited diesel. Land the tubing and pressure test the tubing and annulus. 13. ND BOPE. NU and test the Tree. BHP = 3735 psi at 8800' TVD (8.2 ppg equivalent) 13-5/8" 5000 PSI BOP STACK ANNULAR PREVENTER 7 I I ! ! PIPE RAMS 6 BLIND RAMS 5 DRILLING SPOOL PIPE RAMS 3 TUBING HEAD 2 1.13-3/8" CASING HEAD 2. 5000 PSI TUBING HEAD 3.13-5/8" - 5000 PSI PIPE RAMS 4. 5000 PSI DRILLING SPOOL 5, 13-5/8" - 5000 PSI BLIND RAMS 6.13-5/8" - 5000 PSI PIPE RAMS 7, 13-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TE,~T 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4, RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL IN WINTER OR SEAWATER DURING SUMMER MONTHS. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES, BLEED DOWNSTREAM PRESSURETO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOP TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY FOR DRILLING OPERATIONS. FOR COMPLETION/ WORKOVER OPERATIONS, PERFORM COMPLETE BOP TEST EVERY 21 DAYS AND FUNCTION TEST BOP WEEKLY. DAM 11/20/89 BOP SCH (FOR: NAB 2ES) ARCO Alaska, Inc(== Prudhoe B;~ ~-ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 31, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-1 Permit No. 70-420 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DCR/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 4-1)W1-3 RECEIVED (. Anch0rs(J~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA APPLICA 'ION FOR SUNDRY Al-, 1. Type of Request: Abandon Suspend Operation shutdown Alter casing Repair well Plugging Change approved program 2. Name of Operator ARCO Alaska, Inc. Pull tubing Variance 5. Type of Well Development X Exploratory Stratigraphic Service 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Re-enter suspended well Time extension Stimulate Perforate ,, X Other 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit ,, 8. Well number 4-1 9. Permit number 70-420 10. APl number 50 - 029-20078 11. Field/Pool Prudhoe Bay Oil Pool 4. Location of well at surface 1327' ENL, 295' FEL, Sec. 34, T11N, R15E, UM At top of productive interval 1672' FSL, 1448' FWL, Sec. 35, T11 N, R15E, UM At effective depth 1467' FSL, 1508' FWL, Sec. 35, T11 N, R15E, UM At total depth 1449' FSL, 1513' FWL, Sec. 35, T11N, R15E, UM feet 12. Present well condition summary ~ E C ~lV E D Total depth: measured 9790 feet Plugs(measured) true vertical 9039 feet Effective depth: measured 9749 feet true vertical 9002 feet Junk(measured) '.:... '~i:~ ~iJ ~ ~a$ Co,qS, r~'~'~'-'~ ~ '~ .... i~ch0 Casing Length Size Cemented ~~ureu~pth True ve~ical depth Structural 115' 30" To sudace ~~ ~0 115 115' Conductor 1185' 20" 1030 sx Fondu ~~'~' 1185' 1185' , Su dace 2622' 13-3/8" 2090 sx Fondu 2686' Perforation depth: measured 9480-9500'; 9506-9542'; 9557-9578'; 9627-9647'; 9654-9678'; 9682-9721' true vertical 8765-8782'; 8788-8819'; 8833-8851'; 8895-8912'; 8918-8940'; 8943-8978' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 9087' MD; 4-1/2", 12.6#, N-80, NPC tail @ 9204' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9076' MD; 5-1/2", Otis RQY SSSV @ 2186' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x~ 14. Estimated date for commencing operation I 15. Status of well classification as: February 1990 I 16. If proposal was verbally approved I Oil x..[_ Gas Suspended Name of approver Date approvedI Service 17. I hereby.qertify that the foregoing is true and correct to the best of my knowledge. .... Signed ~/?~,~~/~ Title Operations Engineering Manager Date FOR COMMI~RION URI= ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. Plug integrity BOP Test Location clearance Mechanical Integrity Test Subseeuent form reg.uJt'.ed~lD- 'f~ ~' ORIGINAL u~ S~iTH Approved by order of the Commissioner Form 10-403 Rev 06/15/88 300 D. C. Reem Returned Commissioner SUBMIT IN TRIPLICATE D.S. #4-1 CTU Cement Squeeze - WSO/PPM Preliminary Procedure W0rkover Objective: Acid wash all perforations, cement squeeze all perforations with high pressure squeeze, clean out wellbore, shut in for rig workover. 1. RU slickline. Tag fill, surge well, re-tag fill. RD slickline. 2. Production test well. 3. RU CTU. Clean out fill as necessary to 9735'. RU acidizing equipment. Acid wash all perforations. Production test well. 4. RU CTU and cementing equipment. Cement squeeze perforations to 3000 psi WHP. Volume of cement pumped will cover all perforations. The perforations to be squeezed are as follows: (Ref BHCS dated 12/27/70) Pre-Squeeze Perfs Z0n~ Comments d9480'-9500' 2(UV) Open - Channel up to Zone 3 9506'-9542' 2(LV) Open 9557'-9578' 2(T) Open 9627'-9647' 2(UR) Open 9654'-9678'// 1 (LR) Open 9682'-9721't/ 1 (LR) Open 5. Hold squeeze pressure for one hour. 6. Reverse out cement leaving seawater across reperf intervals. 7. Wait on cement one week. Complete rig workover operations. 8. Reperforate well as outlined below: (Ref BHCS dated 12/27/70) Curren$ P0rf~ Z0n0 Prot~osed Perf$ Density 9480'-9500' 2(UV) 9480'-9500' LSD 9506'-9~542' 2(LV) 9506'-9542' LSD 9557'-9578' 2(T) 9557'-9578' LSD 9627'-9647' 2(UR) 9627'-9647' LSD 9654'-9678' 1 (LR) 9654'-9678' LSD 9682'-9721' I(LR) 9683'-9696' LSD I(LR) 9696'-9721'~/ FSD I(LR) 9721'-9734' FSD Comments Reperfs Reperfs Reperfs Reperfs Reperfs Reperfs Reperfs Approved Addperfs 9. Return well to production on low choke setting until well stabilizes. Reservoir Conditions Estimated Reservoir Pressure= 3780 psi Estimated Reservoir Temperature= 190OF ,5 4 2 COILED TUBI~N{~ UNIT BOP E0U ! PMEN~' 1. 5000 PSI 7" WELLHEAD CONNECTOR FLAI~G[ 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYD~LIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 H]REL]NE BOP EQUIPMENT 1. 5000 PSI 7" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OIrF ARCO ALASKA, INC. F'.O. -BOX i ANCHORAGE, ALASKA 995t DATE' 9-27-89 REFERENCE' ARCO CASED HOLE FINALS ,~ ---4 9-t 8-89 COLLAR/PERF 3-2 9- t 5-89 COLLAR/PERF 4-~ 9-7-.89 NOISE 5-t t '7-8-89 SPINNER ~'URYEY 6-2~ ¢?-t 4-89 CNL-GAMMA 7-2';; 7-28-89 PERF RECORD ii-~O 7-24-89 PERF RECORD ~ ~-~ 2 7-2:$-89 PERF RECORD ~t-t7 9/~t-~2/89 COLLAR/PERF ~ 2-~ 3 9-~ 7-89 COLLAR/PERF ~ 4-3~ 9-t ~-89 COLLAR/PERF RUN RUN t, RUN RUN RUN RUN RUN ~ 5" RUN RUN RUN t~ 5" RUN ~ 5' PLEA.~E SIGN AND RETURN THE. ATTACHED COF'Y AS RECEIPT OF DATA~ ATLA~~ ATLAS ~'CH HL2, A'rLA3' HI_$ ATLAS AI'LA~' AI'LA~' ...l'?.,r.4, 2 IQI~ A T O- t S,. 9 Ateska Oil & Gas Cons. Anchorage DISTRIBUTION CENTRAL FILES ~ PHILLIPS CHEVRON F'B WELL FILES D & M R & D EXTENSION EXF'LORATION EXXON ~ $TAI'E OF ALASKA MARATHON $ TEXACO MOBIL ARCO ALASKA, iNC. P.O· BOX i(:)0S6£.~ ANCHORAGE, ALASKA 995i¢' DATE' 7-28-89 REFERENCE' ARCO F'RE3'ZURE DATA 3-~ 5 7-7-89 BHF'--$'i'ATIC GRADIENT HL. 5' ..3-22 7-9-89 BHP--$'i'AT !C GRADIENT fILS 4-~ 6-28-89 BHP--~'TATI C GRADIENT HL~' 4-26 7--t 2-89 BHP--;~TAT!C GRADIENT CA~CO 7-~6 6-3e-89 BHP--~'TA¢IC GRADIENT HL~ 9-6 7-5-89 BHP--;~"FA'FiC ~RADiIEN F HL.~' 9-'7 7-~-89 BHP--S'TAT IC GRRDIENT HL~ 9-9 7-6-89 BHP--3'TATiC GRADIENT HLZ 9-24 --~_~_oo, ~,. BHP--3:TATIC GRADIENT t 6-8 7-8-89 BHP--~'TAi'IC GRADiENF Hl.~ t 6-~ 2 7-9-89 BHF'--S'TATZC. GRADIENT HL&' ~ 6-2¢ 7-8-89 BHP--5'TATIC GRADIENT t 6-24 7-6-89 BHP--5'TATIC GRADIENT ...... HL5' ..... PWDW2-~ 7-9-89 BHP--5*TAFZC GRADIENT CAMCO PI_EASE: SIGN AND RETURN THE ATTACHED COPY AZ; RECEIPT OF DATA, RE.EIVED BY t"!" ~ ~ t'~,-' ' 'r~'~':'~''ll]~: I ~L. LY HOFFECKER ~..,.',~ ...... , .~ ~FFRUVED '~ ATO-t 529 .~'.~'"~ TRAN~ 89~3 DISTRIBUTION CENTRAL FZ~E$' ~~ CHEVRON .... D & M .~ ~:- EXTENSION EXPLORAI'ION EXXON" ' NARATHON MOBIL PH.[LLIP$' PB WELL FILES R & D BPX ,?ZI'ATE OF ALA~'KA TEXACO ARCO ALASKA, INC. F'~O, BOX J00360 ANCHORAGE ALASKA 99~ O DATE' 7-J ~-89 REFERENCE' ARCO CASED HOLE FINALS 4-~ 6--29-89 CNL RUN 7, 4-4 6-29-89 CNL RUN 6, it--i2 7-i-89 TEMF' RUN i, ii.-t2 '7-i-89 CNL RUN i, I:'I_E:AS'E ~;'IGN AND RETURN THE ATTACHED COPY A,~' RECFiI::'T OF DATA. REuEIYED BY t.-tAYE A NICE DAY!" ;,::ALLY HOFFECKER ATO.-.t 529 D I ,S' T R :i: B U T ]: 0 N CENTRAL F' .,.';' L.,E~ CHEYRON D&M EXTEN-~"ION' E. XF L. URAI I ON EXXON MARATHON ~ MOBIL ,-~ F' H :[ L t. :[ P ,~ PB WELL F']:LE:$' R & D ,,IL · .. BF'X .... ~"" ,S"I"ATE OF' ALA~'KA .' TEXACO ~Ci'-i ~,'t:;H ~'CH ;::;CH ARCO ALA$1<A, iNC. P ~ O. BOX ANCHORAGE, ALASKA 995t0 DATE' ?-i ,3-87 REFERENCE' ARCO CASED HOLE FINALS 2-i 6 6-S0-89 COLLAR/F'ERF S-~o 6-28-89 DIFF I'EMP 3-2S 6-28-89 CNL-GAMMA 4-i 6-28-89 TEHP StJRVEY 4-i a 6-S0-89 DIFF TEl'dF' 4- i ~. 6-S0-89 CNL-GAMMA 4-i 5 6-"'28-89 INJECI'ION PROFILE 4-.~0 6-30-89 DIFF 'rEMF' 4-._-40 6-30-89 CNL.-GAMMA 4-3t 6-28-89 DIFF TEMF' 4 Si 6-28-89 UNL-~AMMA t i -t 5-i 8-89 I'MD ii-i? ?-i-89 DIFF TEMP i i-i '7 '7-i-89 CNI_-GAMMA 18-25 6-23-89 CBT (TLC) RUN i , 5' RUN 'i, 5' RUN i, 5' RUN t, 5' RUN t , 5' RUN i, 5" RUN t , 5" RUN t , 5' RUN i , 5" RUN t, 5' RUN t, 5' F:UN t, 5" RUN t, . RUN i, 5" RUN i, ..,~'<" PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. A'FLA~ Al'LAS Al'LAS OTIS A'FLA$ A'I'LAS OTIS Al'LA~'~ ATLAS Al'LAS ATLAS HLS ATLAS Al'LAS $CH RECEIVED BY HAVE A NICE DAY! SALLY HOFF'ECKER A'i"O- i 529 'DISI'RIBUTION CENTRAL FILES CHEVRON D &.-.M · EXTENSION' EXF'LORATION. EXXON, MARATHON MOBILe' ~. .... . .;- PHILLIPS F'B WELL FILES R & D BF'X 'STATE OF ALASKA TEXACO ARCO ALASKA, INC. F'.O. BOX 1 (:~336¢, ANCHORAGE, ALASKA 995! DATE' 7-.i 0-89 REFERENCE' ARCO MAGNETIC TAPE(S') WITH L. IS'i'IN(;(.~i') 4-i 6-29-89 CNL, RUN 7 :JOB:~TS387 4.-4 6-29-"89 CNL'-A; RUN 6 ,..i0B-~'::'3S86 i i '-i 5-i 8-89 .... T'MD .JOP,~ i "~'=.~ i S5 F'L.E:A,S'E SIGN AND ""'" I-,.: E. T LJ R N i" I-t E A T i" A C H E. D C 0 F' Y A ~: R E C [:' I P 1" U F' D A i" A D I S' T R :!: B LJ T ]: 0 N CIENTRAL F'ILFZ,$ (CH) ~ F'HII_LJ:I::'.S' C::I.-ii::JVRON PB WELl.. FILE3' D & M R & D TAMMA,S' BROWN (OH) ~ BF'X tEXXON ~ $I'AI'IE OF ALASKA MARATHON TE:XACO HOBIL STATE OF ALASKA COM Mf,~olON A ([~KA OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ . Operation shutdown m Re-enter suspended well __ Alter casing __ Repair well ~ Pluggi,~.._ Time extension ~ Stimulate ~ Change approved program ~ Pull tubing __ Variance ~ Perforate __ Other ~ 2. Name of Operator / 5. Type of Well: 6. Datum elevation (DF or KB) A R C 0 A 1 a s k a, I n c ' l Development__v//' Exploratory ~ 64 3. Address Stratigraphic ~ 7. Unit or Property name P. 0. Box 100360, Anchorage, AK 99510 0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 1327' FNL, 295' FEL, Sec.34, T11N, R15 At top of productive interval 1672' FSL, 1448' At effective depth 1467' FSL, 1508' At total depth 1449' FSL, 1513' E, UN FWL, Sec. 35, T11N, R15E, UN FWL, 5ec.35, T11N, R15E, UM FWL, 5ec.35, T11N, R15E, UN feet 8. Well number DS 4-1 9. Permit number 70 -42 10. APl number 50-- 029-20078 11. Field/Pool Prudhoe Bay 0il Pool 12. Present well condition summary Total depth: measured true vertical 9790 ' 14 D feet Plugs (measured) 9039 ' TVD feet Effective depth: measured true vertical 9749 ' 14 D feet Junk (measured) 9002 'TVD feet Casing Length Structural I 1 5 ' Conductor 11 85 ' Surface 2686 ' Intermediate Production 9 749 ' Liner Perforation depth: measured Size Cemented Measured depth True vertical depth 30" To surface 115'MD 115'TVD 20" 1030 sx 1185'MD 1185'TVD 13-3/8" 2090 sx 2686'14D 2686'TVD 9-5/8" 1060 sx 9480'-9500', 9557'-9578' 9749 ' HD 9002 ' TVD RECEIVED true vertical 8771'-8788,, 8839'-8857' DEC l .5 1988 Tubing (size, grade, and measured depth) 5-1/2"; 17#, N-80 & 4-1/2" 12 6# N-80, (~ 9204'MD ~as~a Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) Baker "SAB" Packer (~ 9076'MD; Otis RQY $SSV ~ 2186'MD 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: 04-15-89 16. If proposal was verbally approved Oil ~ Gas __ Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~q ~ i¢-¢,~ T.p.{)o¢TI~I~,~ Title Regional Drilling Engineer Date ~<~/7/~.. FOR COMMISSION USE ONL~B E S ) S ^ 4 / 0 .~ 4 Conditions of approval: Notify Commission sQ. rCpresentative may witness i Approval No. Plug integrity __ BOP Test .z~, Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- OR~GI~,',~ q,~N~n BY l. Ol',JJ'-Jl~ f'; SMITH Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ~pn-r,,..,~d Copy Returned -"_/~ ~¢ __ Commissioner Date /,~, -.,,/;>',',~ ..?~(?) / SUBMIT IN TRIPLIGATFy 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) 11) 12) 13) 14) 15) PBU DS 4-1 PRELIMINARY WORKOVER PROCEDURE Pull the 5-1/2" tubing. Replace the 9-5/8" wellhead packoff. Retrieve the 9- 5/8" packer. Test the 9-5/8" casing. Run a new 7" X 5-1/2" completion. RU slickline unit and.set a pump-out tubing plug in the XN nipple at 9145' MD. Pressure test the tubing plug to 1000 psi. Punch a circulating hole in the tubing above the XA sleeve with a Kinley Perforator. MIRU WWl. Displace the well with 8.5 ppg seawater. Monitor the hole for stability and kill the well if required. ND tree. NU and test BOP's. Test the 9-5/8" packoff, energize the packoff with plastic if necessary. Pull the 5-1/2" tubing and the seal assembly. Replace and test the 9-5/8" wellhead packoff assembly. PU 3-1/2" DP and retrieve the slick stick, pup joint and K-Anchor at 9026'. RIH with packer milling tool on DP to 9000' MD. Pressure the DP and casing to shear the pump-out tubing plug. Kill the well, pump HEC pills to control fluid loss as required, If fluid loss is unmanageable, pump a Temblok pill. Mill over and retrieve the 9-5/8" packer at 9076' MD. RIH with an 8-1/2" bit and a 9-5/8" casing scraper and clean out to PBTD. Pump a 50 BBL HEC sweep. Displace the well w/inhibited seawater. RIH with a 9-5/8" RTTS to +/- 9100' MD and pressure test the 9-5/8" casing to 2500 psi. Run a 9-5/8" packer and a 7" X 5-1/2" tapered tubing string completion w/ GLM's. Set the packer and pressure test the tubing to 3000 psi and the' annulus to 2500 psi. Freeze protect the permafrost interval by circulating diesel down the 9-5/8" taking returns up the tubing via a circulating/check valve in the top GLM. ND BOP's. NU and test the tree. Release the rig. Turn the well over to Operations. RECEIVED Alaska Oil & G~s Cons. Cornrnissior~ Anchorage ANNULAR PREVENTER 6 PIPE RAHS 5 BLIND RAHS 4 TUBIN6 HEAD 1. 13-3/8" CASING HEAD 2. 9-5/8" CASING HEAD 3. 5000 PSI TUBING HEAD 4. I,'5-5/8" - 5000 PSI BLIND RAMS 5. 13-5/8" - 5000 PSI PIPE RAMS 6. 13-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TI[ST o , , . 10. 11. 1'2. 13. 14. , , , I. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING D E'C 1 ],988 BOP STACK TE~a oil & C~s cons. commissiorl Anchorage FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK. DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAHS AND RECOVER TEST PLUG. HAKE SURE HANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOHEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG NOVEMBER 21 , 1986 · "~" ' ]]NC A R C 0 A L.~,, K A, , F'.O, Box t~e~60 ,~ ~. ANCHORAGE, ALASKA ~5~.. ~ DATE' tt-S0-88 REFERE:NCE: ARCO MAGNETIC TAPES W/L. IST]:NG 2-'S ~t"S-88 CH: CN/Mg (S F'ASg) JOB'S'594 2-5 t0-24-88 CH: CN/M$ (6 PAS'S') JOB¢SS'72 . - d 0 B ,~ S .~ 90 -2-~? t 2-'t 8 t t S-88 CH ' CN/M~' (S F'AS',S') In'~,~."z~'o'~ 4-~ tt .... 5-88 CH' CN/M:~ (3 F'A~g) .JOB~:3597 ..~ 4-.-4 _ · 'PR ~-'~'?~ ~-29 .... ':~ .... "~ 5-t ~ t t'-'2-88 CH' CN/~,~ (:~ F:'AI~g) .JOB~:3'591 t 2-'"2 t ~.-9 t 0-'F---88 CH CN/M}; ~ 4 I:'A,~,~) JOE ~5.) ~4 ATLAS ATL. A.};' A'l' L. A ~'-:,' A'Et_Ab7 A'I'L..A~: Al'LA.':? A"f' L. A :i: A'T'I...AZ A'f' L..A,S' ATt_Ag I::'I_E:AS'E ,t-;IE;N AND RE::TURN TFIE ATTACHED COF'Y AS' RECEIPT OF DAI'A, .. I:;,' IE C'. E :!: ¥ E: D B Y ................................................................ HAVE: A NICE DAY! ]b I ;!;' T R I B ~J'T' I 0 N I... [:.,:, ( CI"I .~ :II: F:'H I !... !... I P 5' · ,-'"' C E: N '1' R A I... I:: I "'" . C H t!.:. V F;..' 0 N F' £'~ bJ I::' I.. L.. I::' I I... I.'] 5' D & i'4 i:;.'. & D , [ .... , · .......... ;,., . F' N ..,I" HE.E I I::.1,,~ ( fJH ) ;~.'AF'C: · "' EiXXON ~: ,S"f'A'I'E OF At...A,'.';'KA 'ir M A I;..' A 'l" i't 0 N "f' Ii!: X A C O t'.t0 B I L. ARCO Alaska, Inc. [ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 23, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Comission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 4-1 Approval Number: 8-743 Enclosed is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/BLS:sd Enclosures cc: Standard Alaska Production Company JoAnn Gruber, ATO 1478 File PI(DS4-1)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED NOV 2 9 Alaska 0il & Gas Cons. C0mmiss|O~rt ~nch0rage AR3B--6132-C A 'KA Oil AND GAS CONSERVATION COMM ' ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Operation shutdown Stimulate ~ Plugging Pull tubing ~ Alter Casing ~ Repair well Perforate Other 2. Name of Operator ARCO Alaska, INC. 3. Address P.O. Box 100360, Anchorage, AK 99510 . 12. 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 1327'FNL & 295'FEL, Sec. 34, T11N, R15E, UM At top of productive interval 1672'FSL & 1448'FWL, Sec. 35, T11N, R15E. UM At effective depth 1467'FSL & 1508'FWL, Sec. 35, T11N, R15E, UM At total depth 1449'FSL & 1513'FWL, Sec. 35, T11N, R15E, UM 6. Datum elevation (DF or KB) 64' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number 4-1 9. Permit/Aoproval Numbers 70-42/8-743 10. APl number 50-029-20078 11. Field/Pool Prudhoe Bay Oil Pool Present well condition summary: Total depth: measured 9790 feet Plugs (measured) true vertical 9039 feet Effective depth: measured 9749 feet Junk (measured) true vertical 9002 feet Casing Length Size Cemented Structural 115' 30" To surface Conductor 1185' 20" 1030 sx Surface 2686' 13-3/8" 2090 sx Measured depth 115' 1185' 2686' feet True vertical depth 115' 1185' 2686' P rod u ctio n 9749' 9-5/8" 1060ex Perforation depth: measured 9480-9500', 9506-9542', 9683-9721' true vertical 8771-8788', 8788-8820', 8944-8978' Tubing (size, grade, and measured depth) 5-1/2"; 17#, N-80 & 4-1/2", 12/6# N-80 @ 9204'MD Packers and SSSV (type and measured depth) Baker "SAB" Packer @ 9076'MD; Otis RQY SSSV @ 2186'MD 9557-9578', 8839-8857', 13. Stimulation or cement squeeze summary 9749' 9627-9647', 9654-9678', 8895-8912', 8918-8947', 9002' RECEIVED Intervals treated (measured) N/A Treatment description including volumes used and final pressure Alas .k,3.. Oil & Gas Cons, ', chorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 8.536 8414 10126 -- 8054 7904 10479 -- Tubing Pressure 273 271 15. Attachments 16. Status of well classification as: Copies of Logs and surveys run ~ Oil x Gas~ Suspended __ Daily Report of Well Operations ,.x 17. I hereby c.,ertify that t. be foj;egoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Service Oper. Engr. Manager Date /'~/~//'~'~ Title SUBMIT IN DUprlCATE--/ Summary of Operations DS 4-1 Began perforating operations on 28 September 1988. Rig up perforating unit, pressure test BOPS and lubricator to 3000 psi, okay. Shut-in well. RIH with gun //lA and #lB , tie-in. Open well to flow, shoot 9524', and 9536', pull up and shoot 9512', flow well 15 min. Shut-in well, POOH, all shots fired. Rig down and secure well. Ref. BHCS 12/27/70 ARCO ALASKA: I'NC, P,C,', BOX 1 ANCHriRAGE ALASKA °c'::' i '":" DATE h.:b.r::.R~'HUE' ARF:FI CASED i"tOL"- m--, -., -5-88 ,~.- c, i i CNL-6ArIMA · 2-4 i 6,-24-88 CCI_ · ">--* i i- _c,c, · = , 4 ,.,,., CNL-GAMMA ~ ;.3.'-i 8 'r '~, -S-P°...,,_, C NL'-f.;-AMM A.. · 4-i !¢-i4-88 PRODtJCi'iON PROFILE · 4-i i i --5-88 CNL-GAMMA ·-4-4 '; i -=.'.-oR .... ' _. ,_, .., t...,,'.L.- G A · 4.-i '3 i 0-i ;5-88 INJEC:TZON F'F;.:OFILE: · .4 - i 7 i ':'".~ - i 2 - 88 i N ._J E C "1" i 0 N F' R iii F' ]; L. E · 4'-29 i i -4-88 CNL'-C-AHHA · ....' ,., i i .... 2-88 CNt...'--'L, AMMA ~II g~. .... .,. ..;.'- i 5 i ~ '"' '-' ,.. --- ~ ::..:.: NL-F;.AMMA ,-..-,~...:, i i--5:.-b:L.~ "FibBING CUTi"EF;'. e;9.-J'.~; i ,:)-i 6--88 PRODUCTION F:'ROFIk_E-(.~RMidA · 1 :i?:..-. J i 0 -. i 4 --- 8 R P R 0 i) U C T I 0 N P R 0 F I L. F: · i 2-6 i ,:)-i S-88 PRODUC:T!ON PF;,'L~F'ZLE · i :::.::- i ,':",, i ('). -- i .,..:':'- ,., <::' 8 . eia-iS i¢, i'=.' ...... , - .., --~:¢ u l N J F C T l 0 N P R 0 F:' I i_ E · '~ 4 ...- :.:l 7, i (.) - ;*;,.. i -. R"',::. CBi".. · i 4-:3? i ,::;,-5 i -88 CE'f' ~- i 4-38 i (:,', -. ;'!; i -88 CBi" ~ 4- ;q';a i ,::).- S i'.-- Si: 8F:E T · i :~'.- 2':' ..,.-- ..;. t ,':'.-2(-)-"'8,, o CCi_-.[.;AMMA Iii 6 .- "/' I ':'-) '- 22 --- 8 ~::~, F' R 0 D Ij C i" I 0 N P R u F' :t: L. F · i 8 .- 2 i ,."!:, --- 2 J -' 8 :iii', C': C L F'WDWS-i t ,?,.. '.-. '~, :."~; ..- o'"'"'o GAMMA F;:. A Y F:'!... Iii: A S E ,~ l (:;. N A N I) R E 'T' U R N T H E A T T A C i..IE D C 0 P Y A S R i-':.: C E. Z P T RUN i, 5" F::UN i, 5" tkt_lN, i , ....."~" RUN i, 5' RUfi i , .5:" F.'.tJN i ...5" RUN i, _,.~'" F;.t(Jt'~ i, '~.'; ' R. UN i, 5" I:;.: U N. i , _.,='" R LIN i , 5" RUN i, 5" RUN i, 5" RUN i, ...,""' F..LJr,.i, D" R'l. jr~i , .., RUN i., 5" RUt'.4 i, 5" RUN i , 5" RUN i, 5 ' RLJN i , 5" RtjN i, 5' F.:UN i, "~'.," RUN i , 5:" [;..'(,IN i , 5" F;: U N i , "':..," DATA ... A f'L.q$ C A ri C (3 A'FLA~: A'i i_A2;' CAi~CO ATI_AC M I L.H,S C A M C 0 C A M C 0 ATLAS Al'LAS; A'TL. AS C A M C 0 CAMCO CAi'~CO CAMCO CAMCO SCH SCH ¢~'CH' CAMCO CAMCO CAMCO IR E C: F:: ! V IT. D B Y i..iAYE A NiC':E D-AYf ~ D l S T R :[ B i.j 'i' I 0 N '"' F' H I I.. l.. I F' $ -ir' F'~', WEt_L. F'!LiE/':: F.: & i) SAF'C ~'~"TA'T'E OF' r::'~i...F;,':.;'i<.,.';:'~ T E X A C 0 ARCO ALASKA, ]:NC, F',O, BOX i00S60 ANCHORAGE, ALASKA DATE- tt-4-88 REFERENCE: ARCO CASED HOLE FINALS "'""' t -2 i 0/t -2/88 FLUID DENSITY '~ 2-5 i 0-24-88 CNL-GAMMA ~S-i 5 i O-i 9-88 VERTILOG ~S-i7 ie/t-3/88 TEMP 2URVEY ~S-i 9 t ~-24-88 COLLAR ~3-t9 t~-2'7-88 CCL-PLUG 2ETTING ~ S-i 9 i ~-27-88 CET '~-t 9-~-88~R ' ' COLLAR/PERF' **~7-SS 9-i6/t7-88 COLLAR/F'ERF ~ 7-34 9-i 6-88 ~.ULL. Ai-:/F'ERF ~9-~ t'' = oo PRODUCTION F'ROF'ILE ~9-2(D t~,-3-88 INJECTION F'ROFILE ~9-22 9-22-88 INUECTiON F'ROFILE 9-~5 9-m6-°8 FRODUUTION PROFILE ~ ti-t t(.)-t-88 PRODLJCTION F'ROFILE ~ t n-'~ i ~-2~-88 .NL-eMMMH i 2-9 9-i 9-88 COLLAR/PERF ~ t 4-t 8 t ~)-7-88 GAMMA-COLLAR **~ i 5-i (~A i 0-9-88 GAMMA-CCL ~'i 5-i 9 i ~3--8-88 COLLAR. ~ i 5-2t 9-~,:)-88 PRODUC'FION PROF'ILE ~i '7-6 9- i 4-88 COLLAR/PERF t 8-i t (~-2-88 PIT2 t 8-t t i ,:).-2'~-88 COI_I_AR/~'E'RF PL. EASE 2tGN AND REI'URN i"~Z ATT~,CFtED COF'Y RUN 9 ~ ' RUN i, ~:..' RUN t, 5:" RtJN i , 5' RUN t , 5' RUN i ,_,s' RUN t, 5' RUN i, 5' RUN t , 5' RtJN t , 5' RUN i, 5' I:,:tJN i, 5' RUN t, 5" RUN S, 5' RUN t , 5' RUN t , 5' RUN i , 5' RUN t, 5' RUN t , 5' RtJN I, 5' RUN ~ , 5" RUN t , 5' RUN t , 5' RUN t , 5' AS' RECk:.iF'T OF' I)A'FA.,. I;.'iECE I VED BY HAVE A NICE DAY! SALLY HOFFECKER ATO- i 529 DISTRIBUTION CENTRAL FILES cHEvROn. EXTENSION EXF'LORAT ION EXXON MARATHON MOBIL '""..- PH!LLIP2 F'B WELL FILES ' SAF'C ~ 2'I'ATE OF ALASKA .,-'- TEXACO CAMCO A I'LA;~ Al'LA2 CAMCO ATL. A~-;' $CH $CH GEAR GEAR GEAR. C A M C 0 CAMCO CAMCO CAMCO CAMCO ATLA~ GEAR CAMCO CAMCO CAMCO CAMCO G E A R C A M C 0 A'f I_ A,"~' THE~E LOGS HAVE i 5-t (~A THE WRONG AF'I ' i"~" N d~. ON 50-(~'29-2 i 8':3'9 ':~ £) '- '-'.:,~ 2'-;"' '" 2 ¢J 50 i -0 i 'I"HEM . I'HE COI;;'.REC'i' NOS ARE' ARCO Alaska, Inc. [, Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager September 26, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Comission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 4-1 Permit Number: 70-42 Enclosed is the Application for Sundry Notice detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/BLS:sd Enclosures cc: Standard Alaska Production Company JoAnn Gruber, ATO 1478 File PI(DS4-1)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon~ Suspend Operation shutdown Alter casing Repair well Plugging Change approved program ~Pull tubing Re-enter suspended well Time extension Stimulate Variance Perforate x Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P.O. BOX 100360 Anch, AK 99510 5. Type of Well: Development _x_ Exploratory Stratigraphic Service Location of well at surface 1327'FNL & 295'FEL, Sec. 34, T11N, R15E, UM At top ot productive ~nterval 1672'FSL & 1448'FWL, Sec. 35, T11N, R15E, UM At effective del)th 1467'FSL & 1508'FWL, Sec. 35, T11N, R15E, UM At total depth 1449'FSL ~, 1513'FWL SE(~. 35. T11N, R15E. UM Present well condition summary: Total depth: measured 9790 feet Plugs (meal ~red) true vertical 9039 feet Effective depth: measured 9749 feet Junk (measured) true vertical 9002 feet Casing Length Size Cemented Structural 11 5' 30" To surface Conductor 1 185' 2 0" 1030 sx Surface 2686' 1 3-3/8" 2090 sx Intermediate Production 9749' 9- 5/8" 1060 sx Liner Perforation depth: 6. Datum elevation (DF or KB) 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 4-1 9. Permit number 70-42 10. APl number 50-029-20078 11. Field/Pool Prudhoe Bay Oil Pool. feet 12. Measured depth True vertical depth 115' 115' 1185' 1185' 2686' 2686' 9749' 9OO2' 9480-9500', 9506-9542', 9557-9578', 9627-9647', 9654-9678', measured 9683-9721' true vertical 8771-8788', 8788-8820', 8839-8857', 8895-8912', 8918-8947', 8944-8978' Tubing (size, grade, and measured depth) 5-1/2"; 17#, N-80 & 4-1/2", 12.6# N-80, @ 9204'MD Packers and SSSV (type and measured depth) Baker "SAB" Packer @ 9076'MD; Otis RQY SSSV @ 2186'MD 13. Attachments: Description summary of proposal Detailed operations program BOP sketch x 14. Estimated date for commencing operation September 27. 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas__ Suspended__ Service 17. I hereb, x certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY- CONDITIONS OF APPROVAL: Notify Commission so representative may witness IIAppr°val No. ~_ Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent forn~p[f~V~l'~(~o~j- ORIGINAL. SIGNED BY Approved by order of the Commissioner LONNIE C. SMITH · Form 10-403 Rev 06/15/88 Returned _ ~,ornmissioner SUBMIT IN TRIPLICATE I ! 1. ~>000 PSI ?" W[LLH[.AD CONNECTOR FLANGE 2. 5000 PSI WIR£LINE RAMS (VARIABL£ SIZE:) ,3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PS~ 4 ~/6" fLOw TUBE PACK-Orr H ! RE L ! NE BOP EOU ! PHE NT ARCO Alaska, Inc. proposes to add perforations in DS 4-1 at selective intervals within the Sadlerochit Sand of Pmdhoe Bay Unit (at 9506', 9518', and 9530' reft BHCS 12/27/70). Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP/BOP/Lubricator, tested to 1.2 _times the maximum expected surface pressure. The well is currently flowing. Produced fluids will be in the wellbore during perforating operations. The objective is to increase the shot density in the perforated interval 9500' to 9536' from 1 shot per 12 feet to 1 shot per 6 feet. These perforations are in the Lower Victor; the reservoir pressure here is approximately 3800 psi. ARCO ALASKA, INC. P.O. BOX tQQJ&O ANCHORAGE, ALASKA DATE: 9-9-88 REFERENCE: ARCO CASED HOLE FINAL ~'- 2-i 4 8-3i -88 '" 2- t 6 8-3 t -88 "--3-5 8-22-88 ~ 3- t 2 8-29-88 ~3-25 8-27-88 '~' 4-~ 8-3~-88 '~ 4-9 8- ~ 9-88 ~ 4- t t 8-22-88 ~5-i2 8-4-88 ~' 5- t 3 8-4-88 ~6-i2 8-i 7-88 ~7-8 8-t 7-88 ~7-i5 8-i 7-88 -~"7-33 9-7-88 ~ 9-i 3 8-i 8-88 ~i t-t 5 9-2-88 "~ i 3-i 8 8-2i -88 ~ t 4-J 8-26-88 ""-i 5-i 8-3i-88 ~,i 5-2 t 8-29-88 ~'"i 8-3 9-i -88 ~ i 8-i 7 9-1 -88 COMPLETION RECORD--GAMMA RAY PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION TEMP FLOWMETER--GAMMA RAY PITS INJECTION PROFILE TEMF' SURVEY INJECTION PROFILE CONTINUOU£ FLOW SURVEY CONTINUOU£ FLOW SURVEY PITS PRODUCTION PROFILE PRODUCTION PROFILE COLLAR COLLAR PFC INJECTION PROFILE TEMP SURVEY LEAK DETECTION PRODUCTION PROFILE CCL--GAMMA RAY COLI. AR/F'ERF~ F'~i~FORATiNG RECORD 'PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF' RUN t , RUN t , RUN i , RUN t , RUN i , RUN t, RUN i, RUN t, RUN i, RUN t, RUN i, RUN i, RUN i, RUN t , RUN i, RUN ~, RUN ~, RUN ~, RUN ~, RUN t, RUN ~, DATA. 5' 5" 2' 5' 5" 5' 5" 5' 5" 5' 5" 5' 5' 5" 5' 5' i'&5" 5' 5" 5' SCH CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO GEAR GEAR CAMCO CAMCO CAMCO ATLAS CAMCO' ATLAS CAMCO CAMCO CAMCO CAMCO ATLAS $CH RECEIVED BY HAVE A NICE DAY! £ALLY HOFFECKER ATO-i52~ TRAN$ ~88568 ~ APPROVED . DISTRIBUTION CENTRAL FILES CHEVRON' D & M EXTENSION EXF'LORA'FION EXXON MARATHON MOBIL, PHILLIPS F'B WELL FILES R & D SAF'C STATE OF ALASKA TEXACO A~'Rf') AI.AS.'I~A. TNf]. ~ F:'.Ft, Rf]W i ~.~,i,J~l..InF.('~r~F. ~1 -~J,l!~q c:-..)9=...'~ ,:'.':, RFFERFN~- ~R£D £A~FD HAl.l: l.F~k' 'R,.FTF:'ICTTflN !;,'! iN i .. %" I:nl l.r-",R. ~:~ND I:'FE'FllR~.qTTN.F, !.nc R!!N i, ~." F'TT2 RI)N t : 5" F'R'F1D! ICTTF!t'-..I F'!::DFTI F Rj. JhJ t : ~ m TD..IFFITTFlh. I F'I;.'ilI:I'I.F R'IJiNI i. .~." FtAII. AF;: f.",ND F'F'R'I--FIR;qTTN(.T, l..Of..', l;:l. lhJ i. r"T." 1::'!;.'F1i".':( IF:'lFTf]i'-J F:'F;:f'I-I:T! F" F~'llixl i · ~" I.-.,~.HFi,'~; F;:AY/:ZF'I'NN-Ft'~'/HY~)I:;.'F) lng t-i.'I.IN i: i} A "F,'-*; I::' F;.' ~q f': ,:' 'T !::' H F' F F;.' ~ T ! I F;.' F' I. f'l g l;: I ! Ni : E;" · 'I-F.'HF:'. /FI f'!LdMFTFF;.'/t !~,,'~!-,'. DI:TF-'t-:.'T 'F FIN R'! IN i . W," F:' T-r ,.:, F;.'I IN i F'FJ:F1T:,IIf".'TTFli',J F'F:.'RF'Ft F RI. IN i . ri" 'rj".J, ll::'F'."T!lf'ii',J F'l.~'f'tFl'! I::' I;.'I.!N t. F'I. !.-.- ,'h ."C F.-. S..'I'F.;N AND F;,'F'T'!II;:i"J 'T'H!: ~:,'T'TAEI-IFr',F:., F':F!F'Y A:.'C I:;.'FEF.-'.TlZ'T nD DA'T,A. F':~MCFI C ~ M F: fl [: A M Fl F, !--- ;~ F;: C g, M f".' Fi f".' t.~ M F: I'] lq,'-5 M P. FI Fi ~ M F': ','] i--I.P.,VF ~ w'rf".'F Dr.':.',Y~ I!:' t:~ f$ f'.; Y R t::' N N E T T AT£t .... t ~'".'o / :.% o . . Alaska 0ii & Gas Cons. Commission Anchorage .... :N "f' F:,' A f... F:' '[ ~ !::' .'::.' :",: f': H ET V F,.' f'i N '('., ,.t M :",: l::' ';~ 'T F.' hJ .':::; 'F FI i"-..I F' Y-: !::' ! f'l F;: ;:".', '1" T ('1 N :Il: FEY..' 'x' f'] N M A R ¢',"f'N AN · f,: H 0 R T I.. I;~F:~FERF:i'-Jr.:E:: AR.r;O F'RES,.~IlRF I'.')AI"A 5-4 7-~ 4 BI-'iF'-FI..131J ]' l'4F.; .F.?R'.¢~.1)'[ E:NT R I--I F'- ?,' T ~.~'T l' ft I;RAI) T E:N'IF F:'I. F:' ~,? E'.". .~;' T [; N ~ ~..J T) F;.' F:' 1'! ] R N T H !::' ~'T' 1' r.':', F; !--I F T) f; f,i P Y ¢', X' E'. F' F: F:' T P'T fl F' T) ~-~'T t~ .. FI ~ M F: Fi f':,.~ M f': I;'i - / Alaska 011 & (3as Cons. Commission Anchorage ARCO Alaska, Inc.I~ Prudhoe Bay~,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 20, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re- DS 4-1 Approval Number' 8-209 Enclosed is the Completion Report and Report of Sundry Well Operations detailing work completed on the above-mentioned well. Very truly yours, D. ~. Scheve DFS/BLS/sd Enclosures cc: Standard Alaska Production Company J. Gruber, ATO 1478 File: P1(DS4-1)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' A~Ul STATE OF ALASKA {~ "' ALASK L AND GAS CONSERVATION C~,,,v:MISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. ~ 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20078 4. Location of well at surface 9. Unit or Lease Name 1327'FNL, 295'FEL, Sec. 34, TllN, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1672'FSL, I~J+8'FWL, Sec. 35, TllN, R15E, UM 4-1 At Total Depth 11. Field and Pool 1449'FSL & 1513'FWL, Sec. 35, TllN, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 64' RKBI ADL 28324 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 11/27/70 12/27/70 01/10/71I N/A feet MSLI 1 17. Total DePth (MD+TVD) 18. Plug Back Depth (MD+I'VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9790'MD, 9039'TVD 9749'MD, 9002'TVD YES~ NO[]I 2186 feet MD 1850' (Approx.) 22. Type Electric or Other Logs Run GR/CBL/VDL, GR/CNL/CCL OIL, FDC, SNP, BHC-Sonic~ LL-3~ SS Gyro Survey~ CBL & Temp. , 23. CAS.lNG, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 157 B Surf. 115' 39" C~m~_nf' t.O S111~J~Rc~ -0- 20" 133 & 94 H & K Surf. 1185' 26" 1030 sx -0- 13-3/8" 72.~ N-80 Surf. 2686' 17~" 2090 ~x -0- 9-5/8" ...47.'43'5,~0 S & N Surf~ , '.'~9749' 12~" 1060 Sx -0- .... 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) 9480'-9500'MD 8771'-8788'TVD 1/2 spf 5%" qgn/,, 9076' 9506'-9542'MD 8788'-8820'TVD 1/12 spf 9557'-9578'MD 8839'-8857'TVD 1/2 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9627 '-9647 'MD 8895'-8912'TVD 4 spf DEPTH INTERVAL (MD) ,AMOUNT & KIND OF MATERIAL USED 9654'-9678'MD 8918'-8940'TVD 4 spf q~0O' 700 sX Class G Cement 9683'-9721'MD 8944'-8978'TVD 8 spf q~R~, 200 sx Class"G cement` 100 sx Class G cement 9268, 27. PRODUCTION TEST Date First Production Method o'f OperatiOn (Flowing,gas lift, e~tc.) June ' 77 I Flowin~ r Date°f'Tes( ' HOUrs Tested. PRODucTION F°R 01L, BBL GAS-MCF IWATER-BBL cHOKE SIZE IGAS~0iLRAT'O 4/2/88 8.0 TEST PERIOD I~ 3082 2747 . 1930 8?° I ~0 Flow Tubing CaSing Pressure cALCULATED. =~ OIL-ESL GAS-IVICF i wATER-DEL OIL GRAVITy-APl (corr) Press. 516 Positive 24-HOUR RATE a~' 9261 8242 5789 27.0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. " I ,, N/A i!.~!: .. ,. · Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE SUbmit in duplicate · , STATE OF ALASKA ALAS ..IL AND GAS CONSERVATION COMMI~ .ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of ARcO 3. Address Post 4. Location Operator Alaska, !nc. Office Box 100360. Anchorage. AK 9953,0 of well at surface 1327'FNL & 295'FEL, Sec. 34, T11N, R15E, UM At top of productive interval 1672'FSL & 1448'FWL, Sec. 35, T11N, R15E, UM At effective depth 1467'FSL & 1508'FWL, Sec. 35, T11N, R15E, UM At total depth 1449'F~;L & 1513'FWL. Sec. 35: TllN= Rl.~F. IIM 11. Present well condition summary Total depth: measured 9790 feet Plugs (measured) true vertical 9039 feet 9749 feet Junk (measured) Effective depth: measured 9002 feet true vertical Casing Length Size Cemented Structural 115' 30" To surface Conductor 1185' 20" 1030 Sx Surface 2686' 13-3/8" 2090 Sx Production 9749' 9-5/8" 1060 Sx 5. Datum elevation (DF or KB) 6~' RKB 6. Unit or Property name Feet 7. Well number DS 4-1 8. Approval number 8-209 9. APl number 50-- 029-20078 10. Pool Prudhoe Bay 0i] P0o] Measured depth True Vertical depth 115' 115' 1185' 1185' 2686' 2686' 9749' 9002' Perforation depth: measured. true vertical 9480-9500' 9506-9542' 9557-9578' 9627-9647' 9654-9678' 9683-9721' 8771-8788' 8788-8820' 8839-8857' 8895-8912' 8918-8947' 8944-8978' Tubing (size, grade and measured depth) 5½"; 17#, N-80 & 4½",12.6# N-80, @ 9204'MD Pa..ck.ers a.n.d SSSV (type and measured depth) Baker "SAB" Packer @ 9076'MD; Otis RQY SSSV @ 2186'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) 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 10182' 8900 5889 positive 9261 8242 5789 positive Tubing Pressure 519 516 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~//~'/'j.~~~'~-~- Tit,e Operations Engineering Manager Form 10-404 Rev. 12-1-85 Submit in Duplicate 4-1/STAT17 B. L. Surritt (263-4217) ..Summarj/of Operations 4-1 Began perforating operations on 25 March 1988. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi. SI well. RIH with gun #1, tied in opened well to fl ow 15 min. shot interval 9506' -9542' wi th 4 total shots (1 shot every 12 feet). Flow well 20 min. Shut-in well, POOH, all shots fired. Opened well, RD and secure well. Ref. BHCS 12/27/70 STAT17 :SN 4-29 RCO AI_A~KA, ~0~ BOX iNCHORAGE, ALASKA 99~ ~ G PATE' ~-tt-8~ ~ERFWCE' ARCO CA~EO HOI...E FTNAI... .~.-77 4_.-,-R,o, nnl t .X-?7 4-4-,qn nnt ! ~ .%- 75:.- ~,q r'..OI .! AR'/F'F-.F;'.FFIFJATTFIN 9 -5¢) ,:~.-'7.~'E: -R,o, C. NI -- ¢, r.;.' t '~' ""~ ..'~ -- '] ') .-.- ~] ~R f]lnl~ ! AR'/F'[r!-"¢I:'FIF,'AT T Fti',! ~ '7.-":' .':'~' -'~-~'-?-~::,~ F;l'il L. AF:/I:'FIr,'r,:RF<t-iT 'r, FiN t '7-~ a--Pg-R::~ r:f]l ! ,.:':,R/PFRFFIRATT · i R.-R 4-?c<.--R:q Cr~t ! /-~I;:/PFRI'"F!F,:AT'rRi'.J ~i ,q.--'! ,'S 4.--.A--I"-IP, pb. il'H.J?-4 Z',-9--F4';::I i~f"li I K'FP.F'r",!..F...'D RY ....... HAVE TRAN,.~ ~ APPROVED DI~TRI~tlTION ~ CENTRAl... F'.T.! r · ,. CHFVRON. '$ .F/Y, TDNI,DTON F'X'PI.. OI'~ATTRN ""'....F.. ¥'/rlN . MARATHON "-. HOBII... '"- PH T I...I...T. P,~ F'F~ W.F.I_ I...F.T.[ F".~ - R & D .. ~ TF.,XAC.,A K~ STATE OF ALASKA ALAS ,.)IL AND GAS CONSERVATION COM ~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ;- Suspend ~ Operation Shutdown F~ Re-enter suspended well ~ Alter casing ~ Time extension ~ Change approved program r~ Plugging ~ Stimulate ~ Pull tubing - Amend order - Perforate ~ Other 2. Name of Operator ARCO Alaska. ]:nc. 3. Address Post 4. Location 1327 Office Box 100360, Anchorage, AK 99510 of well at surface 'FNL & 295'FEL, Sec. 34, TllN, R15E, UM 5. Datum elevation (DF or KB) 64' -RKB feet 6. Unit or Property name Prudhoe Ba~, Unit 7. Well number DS 4-1 At top of productive interval 1672'FSL & 1448'FWL, Sec. 35, T11N, At effective depth 1467'FSL & 1508'FWL, Sec. 35, T11N, At total depth 1449'FSL & 1513'FWL, Sec. 35, T11N~ 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 115' Conductor 1185' Surface 2686' Production 9749' R15~,~, UM R15E, UM R15E ~ UM 8. Permit number 70-42 9. APl number 5o-- 020-20078 10. Pool Prudhoe Bay Oil Pool feet Plugs (measured) 9790 feet 9039 9749 feet Junk (measured) 9002 feet Size Cemented 30" To surface 20" 1030 Sx 13-3/8" 2090 Sx 9-5/8" 1060 Sx Measured depth True Vertical depth 115' 115' 1185' 1185' 2686' 2686' 9749' 9002' Perforation depth: measured true vertical 9480'-9500' 9557'-9578' 8771 '-8788' 8839 '-8857' Tubing (size, grade and measured depth) 5½"; 17#, N-80 & ~'" ~ ,12.6# N-80, @ 9204'MD Packers and SSSV (type and measured depth) Baker "SAB" Packer @ 9076'MD; Otis RQy sssv @ 2186'MD 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation March 15, 1988 14. If proposal was verbally appr°ve-d'~t~ Name of approver :Oa~ ~/O_-- r~,~,~ ._ .~._'~~ Date approved 15. I hereby, certify that the foregoing is true and correct to the best of my knowledge S i g n ed ~)~0~-)~. ~¢~..~. ,,~)~~ Title 0perations Engineering Manager Date Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. ~) __~-~, [] Plug integrity [] BOP Test [] Location clearanceI -~pproved Copy Returned~ ORIGINAL SIGNED BY Approved by LONNIE C. SMITH Commissioner Form 10-403 Rev 12ol-85 by order of t~/'-~ ~ the commission Datet:~"' 4-1/STAT17 B. L. Surritt (263-4217) Submit in triplicately/ ARCO Alaska, Inc. proposes to perforate DS 4-1 at selected intervals within the Sadlerochit Sand of Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Ref' BHCS 12/27/70 Proposed Perforation Interval- 9506' - 9542'MD Gas Cons. Commiss[o~ Anchorage STAT17'SN 4-29 ARCO Alaska, Inc~'.~' Prudhoe Ba~j" ,_,'tgineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 22, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re' DS 4-1 Permit Number' 70-42 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/BLS'sd Enclosures cc' Standard Alaska Production Co.. File P1(4-1)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-O APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon~. ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension ~ Change al313ro~ed program ~ Plugging ~ Stimulate ~ Pull tubing - Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Al~lska. Inc. 3. Address Post 4. Location 1327 Office Box 100360, Anchorage~ AK 99510 of well at surface 'FNL & 295'FEL, Sec. 34, T11N, R15E, UN At top of productive interval 1672'FSL & 1448'FWL, Sec. 35, T11N, R15~E., UN At effective depth 1467'FSL & 1508'FWL, Sec. 35, T11N, R15E, UN At total depth 1449'FSL & 1513'F~L, Sec. 35, T11N= R15E~ UH 1'1. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet ~'790 feet 9039 9749 feet 9002 feet Plugs (measured) Junk (measured) 5. Datum elevation (DF or KB) ~4' -RKI~ feet 8. unit or Property name Prudhoe Bay Unit 7. Well number DS 4-1 8. Permit number 70-42 9. APl number 50-- 029-20078 10. Pool Prudhoe Bay Oil Pool Casing Length Size Cemented Structural 115' 30" To surface Conductor 1185' 20" 1030 Sx Surface 2686' 13-3/8" 2090 Sx Production 9749' 9-5/8" 1060 Sx Measured depth True Vertical depth 115' 115' 1185' 1185' 2686' 2686' 9749' 9002' Perforation depth: measured true vertical Tubing (size, grade and measured depth) 9480'-9500' 9557'-9578' 8771' -8788' 8839 '-8857' 5{"; 17#, N-80 & 4½" 12 6# N-80 @ 9204'MD PaCkers and SSSV (type and measured depth) Baker "SAB" Packer @ 9076'MD; Otis RQY SSSV @ 2186'MD 12.Attachments Description summary of proposal ~, Detailed operations program .~, BOP sketch 13. Estimated date for commencing operation March 15, 1988 14. If proposal was verbally approved ........ Name of approver Da Date approved 15. I hereby, certify that the foregoing is true and correct to the best of my knowledge S i g n ed ~"J~.-~. ~~) ~~~ Title Operations Engineering Mana~ier Date Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test ~ Location clearanceI Approved Copy · Returned ~ ~ ORIGINAL SIGNED BY ,,Z/,~--'/ '- ~ '~ ApprOved by LONNIE C. SMITH Commissioner by order of the commission Form 10-403 Rev 12-1-85 4-1/STAT17 B. L. Surritt (263-4217) Submit in triplicate ARCO Alaska, Inc. proposes to perforate DS 4-1 at selected intervals within the Sadlerochit Sand of Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Ref- BHCS 12/27/70 Proposed Perforation Interval- 9506' - 9542'MD STAT17'SN 4-29 SUMMARY OF OPERATIONS - DS 4-1 Began Perforating operations on ~_/~_0/86. RU perforating unit, pressure tested equipment. RIH w/gun #1, shot intervals 9557'-9578'MD (4 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. RIH w/ gun #2 shot intervals 9480'-9500'MD (1 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. Secured well, RD. Depths referenced to BHCS 12/27/70. F'.O. Box t-00360 Anchorage, Ala_~k~ 995~ .0 DATE' 9-25-87 REFERENCE' ARCO Cased Hole Final 4-t 8-~6-87 F'roducfion F'rofi Le Run ~, 5" Camco i-8 8-22-87 Inject ion Profi Le Rt~n i, 5' Camco t-5 8-2~-87 Producfion Profi Le Run t, 5" Camco 4-5 8--2~-..87 Production F'rofi te Run ~, 5' Camco 4-2 8-24-87 Production Profi [e/Fl. uid Den.s., Run ~, 5" Camco ~4--~7 8-28-87 F'rodu. c~ion Profi[e Run ~, 5' Camco ~S-.6 9-~8-87 Injection Profi Le Run ~, 5" Camco ~S--28 9-~6-8'? Pump-In Tempera~ure Run ~, 5" Camco 5-5 9-9-87 F'roduction F'rofi [e Run ~, 5" Camco 5--~6 8-2S-87 CCL Run ~, 5' Camco ~S.-~ 9 .... '~-...87 Pump-In 'l'emperature Run ~, 5" Camc:o S.-28 8-..2S-87 Leak Detection R,an ~, 5" Camco NGI.--~2 9-~5-87 48 Arm Inspection Caliper Run ~, 2" Camco ~ '1 - ?~. S_ 9 .... t ~, '~ ..... '-- 8 7 F:"r' o d u. c 't i o n P r o f i t. e R ~ n ~ ..5" C a m c o S-.-- 9 8 ..- 2 9 -.-8'7 F' ~ T .S' R u 'n'~ ,5" C a m c o I::'l. ea~e .sig'n and return 'l:he a~:'l:achecl copy as' receipt of data. Received BY . ~-~..._/J_ ~ , , EP 987 C) A'l"O-~529 / /AAska Oil & Gas Cons. Commission -- ~~ ~ / ~ Anchorage TRANS' :l~8,498 ~ ~ Ap ~: t' oved ............. .~ .................................................. D I ~ 'i' R I L U T I 0 N · "'.,,. (";. e'n t r a t. 1::' i 1. e s ~I: !::' h i t. I. i I::' ~' · ,,.'"' C h e v ~' o n F:' ¥:-:.. W e !. I. F' i ..I e ,'i: D & M R & D · ,,."~ E x .I: e n :~' i n n Ii!: x p L ,'", ..... r a '1' i o n :II: ..?. A F:' r: ~ .E x x o n q: ~;' t.,:., + ~ o 1"' A L a .'.~' ~:..'~ H a r a 'l' h o n ~ T e x a c o ':~: f'iob i I. ARCO ALaska, Inc. ....... P ' 0 i" B6x" t ee36e '- Anchorage, ALaska DATE .... Au=JUSt REFERENCE t -29 8- t-3e 8-t 7-87 t-3t 8-t7-87 3-7 8-i 9-87 3-27 8-t 7-87 3-30 B-t e-87 4-t 8-i 6-87 4-3 8- t 8-87 9-i 8-i 3-87 Static Gradient Static Gradient Memory F'ress/Temp.(P.F.O.) FLowing Gradient Flowing Gradient Flowing Gradient Flowing Gradient FLowing Gradient Camco Camco Camco FJ-$ch Camco Camco Camco Camco Camco F' leaze .~i Rec e i red HAVE A NI i."(o~a nne P ATO- t 529 gn and return .~ZIi,t,Qct~Jpy a.s ~;~.ipt of data, ~ ~"//~' ~'~"' ' N~sk~ 0il & Gas Cons. O0~~ e~ - ~o~ .. TRAN$ ~87443 ~ App roved .............. '~D""' ............................................ D I ~: l' R I B lJ T I 0 N ARC(] Atm.s'ka, Inc. R.O, Bo× t.00~60 Anchorage, ALaska DATE' June t5, 1~87 REFERENCE- ARCO Magne$ic Tapes' w/iisfing 3-28 4-1 7-t-9 F'Lease s'ign arid Received By_._ HAVE A NICE DAY! Ros'anne Peek ATO-t 529F t1-t8-84 Magi'ape .-..074 CH CN/M$ Dress l l-lE~--8~t Plagfape t2075 CH CN/MS Pres~; t1-.12-84 Hag,ape ~2069 CH~),"e~ Ap p roved ...................................... DISTRIBUTION ~ CentraL Fi Le~ . ~ · Phi L.L i ps D & N R & D '" .$'oh io F', HcF'heet'er~ ~ · .-'"' Exxon ~',. ~aSe of Alaska Harm ~hon Texaco Mob i [ ARCO Alaska, Inc. F'.O. Box t00:~60 Anchorage, Alaska DATE' September 26, t986 REFERENCE: ARCO Casecl Hole Final ~ ~---t0 9-t 8-86 Step Rate Inj, F'rofi Le/GR Run t, 5' Camco ~4-'i 9-2t-86 F'roduct ion F'rofi [e Run t, 5' Camco ~4-..9 9-t 0-86 're,~p, Log/Iai, F'rof i I.e Run t, 5" Camco '~"4-9 9.-t 5-86 Inj, F'rofi Le Run t, 5' Camco · ~4-.t0 9--.t0--86 Temp,, log Run 'i, 5' Camco ~4-.t0 9-.t5-86 ]:nj, F'rofil. e Run t, 5" C,'~mco ~9'-.t2 9-.'it/1~,..-.~&' Spinner/Inj~ F'rofi Le Run 3, 5' Camco ~-t2 9-.tt/t2-86 Temp, I. og Run 3, 5" Ca~,~co ~9'-..t2 9-t5-86 'l"emp, Log Ru¥~ t, 5:' Camco ""'"'~?-t7 9'-~t-86 Inj. Profi[e Run t, 5" Camco ~9'-..t 7 9-t t .-.86 'l"eml:.~ ~ Log Run t , .5" Camco '~ 9'-20 9'.-t ''~ ' ,.-86 Inj. F'rofi le Run t, 5' Camco 9' - 25 9" - "~,.. 0 - 8 &I n j F' r o f i L e R u n t, .,:5,~ -.~'~ t -2 9'-i 4-86 ,.";'p inner/Ten~p ~ Survey Run t, II C 0 _ -'1t-t0 9'-20/2t -86 Spi¥~ner Log Run t, 5" Camco · - r.~ " C ,.3 t'~l C 0 ~"~-..tt °-t3/t4-86 Spi,'~ner/Production ProfiLe Run 2, ~t6.-.2 9'-t5:-86 'l"emp Log Lemk l)etectior~ Run t, . 5 ' C m m c o F' Lease m-Jgl-I arid i-e~,, tl'lE,~/~-acl'~d c_'opy.,~ rec:e jp.I., of data,, Rec e i red E y. ....... L~-~--:'C'... _,/.~/,,/_._/" _~~.,r- / "' SEP /O 1986 . HAVE A NICE~.,~-Y-L,/' ........ -'-"- ./~ /7~ ~8,Sk8 Oil & Gas. Oor~s. ~,ummisS{Oll Ro ~a or, e/~:'ee k /' ' ' ..... Anchorage ATO'-t 5~~~''~. TI:;:AN$ ~:86597 I) ISTRIBUTION · "' CentraL Fi Les 'Ir · "' Chevron 'ir ID 6, .M · "' Extens~ioo ExpLoration ~'"' Ex XOll Marathon · "' Mob i I. 'M' -..'"' F'hi LLips F'B WeLL Fi Les R & D · "'.,. Sohio · ,.'"' State of A l,aska ~~r TE.~ X a C 0 / Anchorage, DATE:-" ~epte~ber 8, t986 . REFERENCE: ARCO Cased Ho Le F ina L ~t-3;0 -- ' 6:-.30'~-86 Iml~, 4-J 7-t 0-86 4-9 7-9-86 t~-J7 6-29-86 11-18 6-29-86 ACBE/VDC/$IN/GR' Gamma Ray Log CNL/GR MuLti-Space ACBL/VDL/SIN/GR ACBL/VDL/$IN/GR Run t, Run Run 'i. 5' Run ~, 5' Run t, 5' Dress Dress Dress Dress Dress PLease sign and return the attached-copy as receipt-of-data-.- ..... ..Recei'Ved By 'HAVE A NICE DAY Linda HuLce ATO-~52~ : TRAN$ 1 5 198 Gas Co,,~. ~,,,,n~ion An~0~ge DISTRIBUTION Central Fi Les Chevron '. -- D&.H Extension, ExpLoration Ex xon: " Marathon Mob i [ .- PhiLLips F'B WeLL FiLes R&D Texaco ARCO Alaska, Inc.[ (' Post Office B,.,x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 15, 1986 Ms. Elaine Johnson Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Elaine: As per our phone conservation today, please find the Report of Well Operations amendments for these wells: DS 4-1 DS 4-4 DS 4-7 These amendments should satisfy the requirements for the "Subsequent" Sundry Notices and Completion Reports. If there are any questions concerning these documents, please notify me at 263-4217. Paul Lantero O/A Engineer PVL/IO:cb Enclosure cc: PI(DS 4-1)W1-3 PI(DS 4-4 )WI-3 PI(DS 4-7)W1-3 J. G. Ambrose J. Gruber ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ALASKA rLAND GAS CONSERVATION C ,wMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 70-42 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50' 029-20078 4. Location of well at surface 9. Unit or Lease Name 1327' FNL & 295' FEL, Sec. 34, TllN, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1672' FSL & 1448' FWL, Sec. 35, TllN, R15E, UM 4-1 At Total Depth 11. Field and Pool 1449' FSL & 1513' FWL, Sec. 35, TllN, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 64' RKBI ADL 28324 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore ] 16. No. of Completions 11/27/70 12/27/70 01/10/71 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9790'MD 9039'TVD 9749'MD 9002'TVD YES ~ NO [] 2186 feet MD 1850' (Approx.) -- 22. Type Electric or Other Logs Run GR/CI~L/VDL, GR/CNL/CCL DIL, FDC~ SNP, BHC-Sonic~ LL-3~ SS Gyro Survey, CBL & Temp. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 157 B Surf, 115' 39 Cement to Surface -0- 20" 133 & 9~ H & K Surf. 1185' 26" 1030 SX -0- 13-3/8" 72,~ N-80-:. i Surf',- 2686' 17~" .. 2090 iX -0- ,, 9-5/8" ~7,~3.5,b0 S & N Surly ,.r.8~49' 12k" 106.0 SX -0- 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) 9L*80'-9500'MD 8771'-8788'TVD ~ spf 5~" 920Z~' 9076' 9557'-9578'MD 8839'-8857'TVD ½ spf 9627 '-96~7 'MD 8895'-8912'TVD ~ spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 965z~'-9678'MD 8918'-89z~0'TVD z, spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9600i 700 ~x Crass G Cement 9683'-9721,MD 8944,-8978,TVD 8 spf 9380, 200 SX Class G Cement " 9268' 100 SX Class G Cement 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) June, 77I Flowing "Date of Test Hours Tested ;PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 7/12/86 6.2 TEST PERIOD ~ 2887 2063 509 50° 885 ...... Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 708 0 24-HOUR RATE ~ 9919 8780 1979 27.0 28. CORE DATA Brief description of iithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips, f ~/A c,. ~ 6'as Cor~. · , AOCbora,qe' Co~Tral~ion Form 10-407 Submit in duplicate Rev. 7ol-80 CONTINUED ON REVERSE SIDE REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Other [] Stimulate [] Plugging [] Perforate I~ Pull tubing [] 2. Na.m~,,of .Qpercttor ~KbU A~asKa, Inc. 3. Address vos~: Office Box ].00360, Anchorage, AK 99510 4. Location of well at surface 1327' FNL & 295' FEL, Sec. 34, T11N, R15E, UN At top of productive interval 1672' FSL & 1448' FWL, Sec. 35, T11N, R15E, UN At effective depth 1467' FSL & 1508' FWL, Sec. 35, T11N, R15E, UM At total depth 1449' FSL & 1513' FWL, Sec. 35~ T11N~ R15E~ UM 11. Present well condition summary Total depth: measured 9790 feet Plugs (measured) true vertical 9039 feet 5. Datum elevation (DF or KB) 64' RKB Feet 6. Unit or P,,rope[,ty na~e vruonoe uay Unit 7. Well number DS 4-1 8. Approval number 70-42 9. APl number 50- 029-20078 10. Pool Prudhoe Bay Oil Pool Effective depth: measured 9749 feet true vertical 9002 feet Casing Length Size Structural 115 ' 30" Conductor 1185' 20" Surface 2686' 13-3/8" Intermediate Production 9749' Liner Perforation depth: Junk (measured) Cemented Measured depth True Vertical depth To surface 115' 115' 1030 SX 1185' 1185' 2090 SX 2686' 2686' 9-5/8" 1060 SX measured 9480'-9500', 9557'-9578' true vertical 8771' -8788', 8839' -8857' Tubing (size, grade and measured depth) 5½" 17#, N-80 & 4½", 12.6# N-80, @ 9204'MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 9076'MD Otis ROY SSSV ~ 2186'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) 9749' 9002' Treatment description including volumes used and final pressure RECEIVED J U L ) 1 1986 Alaska 0il & Gas Cons. ColnrnissJ0n Anchorage 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 6547 6932 3360 0 9919 8780 1979 0 Tubing Pressure 551 7O8 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title 0pr. Engr. Manaqer Form 10-404 Rev. 12-1-85 JGA (,263-4361 Submit in Duplicate ARCO Alaskm, Inc P.O· Box t00360 Anchorage, Akmska oo=..i 0 ,..- ..' J ~DmTE' February it i° , ,86 HoLe Final %' o,S, S-S i m-mS--°q' Con+. inur, u-=; ~S~. ~m-i 7 i 2-26-85 Con*, inuou~ ~,- ~ DS 4-i i t -i -8=:~ Gamma ~S 4-S i 1'-S-85 Gamma Ray ~DS 4-24 i2-3i--85 Gamma Ray ~,S 4-27 i -4-" ' oo Gamma ir(ay = ~'-8 Gamma Ray ~ D~ 6-2 i O-i,~m..-8'5 CFI/ ~D S 9 - 2 8. . 9 - 2 ~" --8 = =~' Q a [,', m a R a y L-[ow ~urv;','.-'/gR R:~;'i 'i _:. . _ Flow $:,rvey l:.:;~n i 5' Log R,J'n i 5' !DA Log I;,'un i 5' DA Log. Run t 5" 'l"~" · Log Rur~ i .~=" Go Loc] R U.i'l t 5" DA F;..' u. n t ~'"~'" {;. o t ,.. o g .. _, iS, A Pi. ea.~:e :i.;'ign a'nd re't'utr;"~ ':.':he af.i'a,:::ned copy a/.-: receiF.;'~ of d.:'..'~'~'a., Received By FIAVE A NICE DAY! irma Ca;"l. in ATO-- i 429F .r.~-,,-.~ -.'ooi 7a ..... Ir.., ][ OUT i) I:~ t,", ~.,.~, ION C e n t' r a 1. t-'-' i 1. e s Chevron Ex*,en~io'n Expl. o;-a+, ir;;-,_ Exxon Marat-hon Mob i 1. Phi I. !. il=, :...';' F'B WeLl. Fi ;es R & D ~: Sol", i o · ~'= i'e x a c o P "'" P,c'., x '1 A'n c h o i" a ,-"j e., F:i I..:?~ .~: t< .:'-~ DATE]' . tai"~a'ry .,-....:., 'i '".~-'.' .~: ...... - . {;;,;.., . !:;: E F:' Iii: F;..' !ii: N E:: E ' ;:'-'~ F;..' C'. [3 C'. a :'..~.' e d I.-! ,::.', i. ,:..'..', F:' i 'n,.'..l I. ~]as~$ Oil ~ ~ ~ ~ ~" ~ ~- ~:' I"' d .:':',; 'i.' 4..'; ... ARCO Alaska, Inc.[ ( Prudhoe Bay%,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 13, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 4-1 DS 4-4 DS 4-12 DS 4-30 DS 4-31 DS 4-32 Permit No. 70-42 Permit No. 71-11 Permit No. 78-18 Permit No. 85-89 Permit No. 85-74 Permit No. 85-64 Enclosed are the "Intention" Sundry Notices detailing work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS:JGA:vh Enclosure CC: SOHIO Alaska Petroleum Co. File Pi(DS 4-1)Wl-3 P1 (DS 4-4)W1-3 PI(DS 4-12)W1-3 Pl (DS 4-30)W1-3 PI(DS 4-31)W1-3 P1 (DS 4-32)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany A(0 STATE OF ALASKA ALASK IL AND GAS CONSERVATION cOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [~X OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 Su~£~ue: 4. LocationofWell 1327'FNL & 295'FEL, Sec. 34 TllN, R15E, OM At Top Producing Interval: 1448'FWL & 1672'FSL, Sec.35, TllN, R15E, UM At Total Depth: 1513'FWL & 1449'FSL, Sec. 35, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 64' RKB 6. Lease Designation and Serial No. ADL 28324; ALK 2322 7. Permit No. 70-42 8. APl Number 5O-- 029-20078 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 4-1 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate r~X Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations to DS 4-1 at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and cleanup operation. Proposed Perforation Intervals: 9480-9500' MD 9506-9523' MD 9557-9578' MD 9721-9734' MD Ref: BHCS 12-27-70 RECEIVED JAN 2 0 1986 0il& Gas C0r~. ~mml~n Anchorage 14. I hereby c,e~ify that the foregoing is true and correct to the best of my knowledge. Signed ,~_ ~ ~~ Title Operations Eng'i :neering Mgr. The space below for Commission use Date Conditions of APproval, if any: Approved by. IIIIG. INAL SIGN.ED 'BT LONNIE C. SMI~ 8¥ Order of /- ~-, O- ~ (.,CD COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-~-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc(~ Prudhoe B~ _,,~lineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 6, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 4-1 DS 4-3 DS 11-4 DS 13-26 DS 15-10 DS 15-12 Permit No. 70-42 Permit No. 71-05 Permit No. 80-60 Permit No. 82-74 Permit No. 80-88 Permit No. 81-146 Enclosed are the "Subsequent" Sundry Notice detailing work completed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/JEB/vh Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 6-1)W1-3 RECEIVED alaska Oil & Gas Cons. Cornmisslor~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ('" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELTLxI-I OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 70-42 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Su.~ .l~ct~e: 1327' S & 295' W fr NE cr of Sec. 34, TllN, R15E, UN At Top Producing Interval: 1448'E & 1672' N fr SW cr of Sec. 35, TllN, R15E, UM At Total Depth: 1513' E & 1449' N fr SW cr of Sec. 35, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 64' RKB I ADL 28324 12. 8. APl Number 50-- 029-20078 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 4-1 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations E~Z Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began reperforating operation on 11-1-85. RU perforating unit and pressure tested equipment. RIH w/gun #1 to shoot 9701-9721' MD (4SPF). SI well, POOH, all shots fired. RIH w/gun #2 to shoot 9683-9701' MD (4SPF). SI well, POOH, all shots fired. Secured well, RD. Ref: BHCS 4-10-77 RECEIVED u~, ~ b~S Cons. Commissior~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_z~__~~~ Title Operations ~.ngineering Mgro The space below for Commission use Date Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in I~uplicate '!.=.'9"-' i ,"-', ,', ............... NC ' .-'-. '": ;" r", i:: i.-i 1'.'.., ...... (;; ,-':i .'iF (*:':., ,:; i-'i,.=, i. e !::' i 'n a L .~") , fl .q. 4 · _.... ,, ,:~ ~. .'i i .... 'i :.:.:.", .... ~ii', 4 Iii: .r.:, ! I ,:::, ,::~ M- .'. , . . .. ","; ,!i: ."~ .... :.i:~'~ i"i 'i'7 :ii~"' .... ., .: ..? ........ I::. F:' i i. ,:z, ,.'~.I .... ...~. i.':', :ii: '7""'7.,q ,-"- i i ..... ~ 6"" 8 4 ~:: ,', ~ i..,:::, ,::i · · ."- ,... I" .. ¥) 5: '7 ..... ~ ({::-"' i 'i i '":' "'"' "; '"'" , ...... · ... ...: ..... ,::-, .:.,. i:. l.: i !..:.-::~ ,'.5.I i)., :?., '7 ..... j ':? ~" 'ii .... ! :2 ...-',iii: 4 iii; p i L .::::, 9 i:.':' ,. ,S'., 5; ..... ..'::'--- i 'i ..... l ii!: .... ,..,":::' ...... '''~ ,..*::' i.:"' i i. ,:::, ,:.:.:.. )'_':, ... 5: ,. S:' ...... !. -"'"'- i i .... i i!i:...' i!i: 4 E i::: i i. ,::::,:;.,'. · ::1 ! i ,..1 I tlr :. ,.: ~. I ! ,;;.~ .::1 '. '..;:I :... ~ ":. · : :..., i.: 7 ..;' .::- i :.'.:' ,... ,.'.:: ! ~..' ~. , , . .................................................................................. iX, i",! P ~:~ ,,e i. i.'::...' H,:::i.-.:..'~'r' Land AlaSka Oil & Gas Cc,ns ; ....... ,,.. · .¢; T q,.. ..... i ':"' -'": '-:'"' ...... ~" "f' I:;:r. :: r,.'. ,.":. ., :',l: ({:, (-) 9 AC, r-q A[askm: Inc F'. O, Box i Anchormge: A[askm DATE' December 2~ , ~oo,~ REFERENCE' ARCO Cased Hole Fina ~.ease sign ii_~ ,.:,,~ , ¢,,,, , - o,-;. [,Fa / ~': p inner i--i -84 CF;?./~p inner i _~'...o~, I) iff Temp Loq ~-2--84 D i fi: Temp i --?--8,~ -' ~ ' ~' ' i -i ...o,~...,.~ CFS/Sp inner i --i o_.o~,,, ~.-¥ CN/HS/GR 2--i 2-84 Sp inner Log 'i-'-i°-r~m r';,I /~- xr'r', i '-i ,::,-o ~, ''~ -' 8 - 8 ~ ~ ' i -i °--8 ~ C~x., ma. ~ Gk 2-i 2-84 Sp inner Log 2-i()-.84 Spinner L. og 2--i(:,--84 Inj F:'rofi ~ · '""'nner 2-5-84 Spinner/Temp/In.j F'rofi ~e o _. 5 --84 ,~ ,.. ,- Spinner/Temp/Inj F:'rofi Le 2 -. 6 '-- 8 4 i n j F' r o f i L e/,? t::' i n n a r ,/T' e m p 2-6 ...o x, ,-. ,.,..,- ~:. p i n n e r L o 9 2 -. 6 ._,.,° .,-~' I n j P r o f i L e / ,? p i n n e r ' -r ... ~ -4"''°z~,., ,. CF:'S/~'' ' ,:. P I lhneT' ~i-'4 E'.'~ ..... ~ Diff 't"emF. t..o9 and 'r'et'u'r'n i'he ai'tac:hecl copy a~: recaiF, i' of Run i Ru'n i R u n i Ru.n I R u n . i Run t R u n i R u n i R u. ni R u n i R u n i R u n i R u n i Run i R u. nf Run i R u. ni d a .1: a., HAVE: A 'PY NE".W YEAR] i<eLl, y McFar La~u A'i" 0--i 429F' Oil & G~sL,,mo.'"'-' C0mlmssi0n TRAN,:? ,. ~--4 i 9 I) I 5.' 'T' R i E.-: U "," i 0 N Mob i [ Hr'~bi t. E & F" F:' h i [ [ip '.'i: F:'rudhc',e Bay We Ii. F.: 6: D ."';ohio ,?".fa ±.~:.-, oi'" A i.a:!.:l.:.'a I::' i I. e '.i.' ARCO Alaska, In~i Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 '4? June~14, 1984 Reference: ARCO Cased Hole Finals ~ D.S. 1-21 5-4-84 Epilog Run 2 5" DA J D.S. 1-25 5-26-84 Spinner Log Run 1 5" Camco .~D.S. 2-17 3-28-84 Spinner Log/Basket Flowmeter Run 2 5" Camco ~D.s. 3-13 5-21-84 CFS/Spinner Run 1 5" GO -.D.S. 3-27 5-18-84 ACBL/VDL/Signature/GR Run 1 5" DA ~.D,So 4-1 5-6-84 Epilog Run 2 5" DA ~D.S. 4'4 5-14-84 CH CNL Run 1 5" GO ~D.S. 5-8 ~-5-84 Epilog Run 1 5" DA ~D.S. 6-4 5-30-84 CP1/TDT-M w/listing 5" Sch ~D~S. 7-20 4-18-84 Spinner Run 1 5" Camco ~D.S. 12-16 5-20-84 PLS Run 1 5" DA ~D.S. 9-4 5-7-84 Epilog Run 1 5" DA ~D.S. 7-25 4-22-84 Spinner Run 1 5" Camco ~D.S. 7-22 4-20-84 Spinner Run 1 5" Camco .~D.S. 12-18 6-1-84 CPL/TDT.-M w/listing 5" Sch .~D.S. 12-23 5-19-84 ACBL/VDL/Signature/GR Run 1 5" DA ~D.S. 14-2 5-3-84 Epilog ~ Run 3 5" DA ~D,S. 14-25 5-18-84 CFS/Spinner Run 1 5" GO ~D.S. 14-32 5-20-84 CFS/Spinner Run 1 5" GO ~-D.S. 14-34 6-5-84 CPL/TDT-M w/listing 5" Sch ~.D.S. 17-1 5-24-84 Collar/Peri Log Run 1 5" GO ~e sign and return the attached copy as receipt of data. Don't Forget Dad on his day! Kelly McFar land ATO-1429F Trans. f~ 242 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob i 1 Mobil E & P Phillips Prudhoe Bay Well Files R&D Carolyn Smith SohiO State of Alaska ARCO'Alaska. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 6, 1984 Reference: ARCO Cased Hole Finals D.S. 1-26-" 5-17-84 D.S. 2-177/' 5-12-84 D.S. 4-1 5-6-84 D.S. 5-8-' 5-5-84 D.S. 6-18~ 5-22-84 D.S. 9-4'~/' 5-7-84 D.S. 9-6/ 5-7-84 D.S. 12-17~/ 5-~14-84 D.S. 12-23~ 5-16-84 D.S. 13-34/~ 5-17-84 D S 13 98'~/5- . . 16-84 D.S. 16 13/' 5-20-84 D.S. 17-7~"~ 5-25-84 D.S 17-10 ~'~' 5-18-84 D.S. 17-10~ 5-18-84 D.S. 18-3-- 5-14-84 Collar/Perf Log Run 1 Collar Log to set Casing Patch Run 1 CN/MSN/GR Run 2 CN/MSN/GR Run 1 CPL/TDT-M w/listing 5" Sch CN/MSN/GR Run 1 CH CNL Run 1 CPL/TDT-m w/listing 5" Sch X-Y Caliper Log w/Boreho Run 1 CPL/TDT-M w/listing CH DIL Collar/Perf Log Collar/Perf Log CET Log CCL/Perf Record Temperature Log 5", GO 5" GO 5" DA 5" DA 5" DA 5" GO le Volume 5" GO 5" Sch Run 12 5" Sch Run 1 5" GO Run 1 5" GO Run 1 5" Sch Run 1 5" Sch Run 1 5" GO se sign and return the attached Be PATRIOTIC! - Hang out your copy as receipt of data. flag on the 14th. Kelly McFarland ATO-1429F Trans. 9231 DISTRIBUTION ' 'Chevron D&M Drillin$ Exp. Services Ext. Exploration Exxon Getty Marathon Carolyn Smith Sohio -State 'of Alaska ARCO Alask~ Post O% Jox 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 24, 1984 Reference: ARCO Magnetic Tapes //D.S. 4-1 ~'~ 5-6-84 CN/MSN /~b. S. 6-8~'' 5-18-84 CH/CNS ,-D.S. 7-14~/ 5-22-84 CH/CNS / D.S. 7-13/ 5-22-84 CH/CN.S fD.S. 15-13~/ 5-23-84 CH/CNS /D.S. 7-19~' 5-18-84 CH/CNS /D.S. 5-12/ 5-23-84 CH/CNS /D.S. 9-26'' 4-18-84 OH #1946 ~/D. S. 3-27 ~ 5-15-84 OH #6923 /D.S. 12-21 ~4-29-84 OH #6918 '~,D.S. 13-34~, 4-21-84 TDT Edit /D.S. 12-17~/ 4-22-84 TDT Lis '- ~-.- S ~: -1-2--~t-7--ut'/-,--4-. '2 ~.'~8,4 ...... Answ.e~. .~/D.S. 7-11~''' 4-26-84 CH CNL '-/D.S. 12-21"" 4-29-84 RFT #691 1965 w/listing DA 281781 w/listing GO 281783 w/listing GO 281782 w/listing GO 252598 w/listing GO 281784 w/listing GO 281788 w/listing GO w/listing DA 4 w/listing Run 1 69198 w/listing Sch 8 w/listing Run 1 #69197 w/listing Sch #69164 w/listing Run 1 69165 w/listing Run 1 69179 w/listing Run 1 88 w/listing Run 1 Sch Sch 'Sch Sch Sch ' Sch tt I! I! t~ I/ Ii ARCO Alaska, Ir~ Post Offi~ , 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 17, 1984 Reference: ARCO Pressure Data D.S. 3-19f' D.S. 3-22/ . 3/ DS. 3-2 D.S. 4-1'' DoS. 6-4~ D.S. 6-7~' D.S. 6-18/ D.S. 6-23' D.S. 7-20f D.S. 7-21/ D.S. 7-22 / D.S. 7-24 D.S. 7-25/ D.S. 7-26' D.S. 12-7A/ -D.S. 12-15f D.S. 12-18 D.S. 13-13 D.S. 13-15 D.S. 13-16 D.S 13-33 D.S. 18-7 j 4-9-84 4-9-84 4-9-84 3-17-84 1-25-84 1-25-84 1-15-84 1-15-84 12-27-83 8-11-83 4-18-84 4-29-84 4~20-84 4-20-84 4-20-84 4-21-84 4-22-84 4-28-84 4-14-84 4-14-84 4-13-84 4-13-84 4-15-84 4-16-84 4-12-84 4,13-84 4-12-84 41-5-84 3-14-84 3-14-84 ~~Ple~se sign and return Static Static Static Static PBU Common Data Base Report PBU Common Data Base Report Horner Plots w/listing Horner Plots w/listing PBU PBU PBU Common Data Base Report PBU " Common Data Base Report PBU PBU PBU Common Data Base Report PBO Common Data Base Report PBU Common Data Base Report Static PBU Pressure Draw-Down Static PBU Common Data Base Report Camco Camco Camco Camco GO GO Sch Sch Camco DA Camco C amc o Camco DA Otis Camco Camco DA DA Camco DA DA the attached copy as receipt of data. Kelly McFarland · ATO-1429F Chevron D&M Trans. ~ 187 Drilling Exp. Have A Nice Day! ~ D .ISTRIBUTION Mobil '~L~_~ · · · ,~ ~ Mobil E & P .,~,,,. Phillips Services Prudhoe Bay Well Ext. Exploration R & D Exxon Carolyn Smith Getty Sohio Marathon State of Alaska ~ Bill Sheffield, Governor ALASKA OIL AND CAS CONSERVATION COMMISSION March 29, 1984 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501'--3192 TEL EPHONE (907) 279.-1433 A D M I N I S T R A T I V E A P P R O V A L NO. 192.1 Re: The application of ARCO Alaska, Inc. to substitute static bottomhole pressure surveys for transient pressure surveys in Prudhoe Bay Unit wells DS 3-10, DS 3-15, DS 3-18, ~DS 4-1, DS 4-5, DS 4-11, DS 9-1, DS 9-6, DS 9-10, DS 16-1 and DS 16-9. Mr. D. F. Scheve Regional Operations Engineer ARCO A!a~ka, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Dear Mr.. Scheve: Application for exceptions to Rule 6 of CO 165 was received March 23, 1984. Exception to CO 165 Rule 6(c) for PBU wells DS 4-5 and DS 9-6 and exception to CO 165 Rule 6(d) was requested for PBU wells DS 3-10, DS 3-15, DS 3-18, DS 4-1, DS 4-11, DS 9-1, DS 9-10, DS 16-1 and DS 16'9. ARCO Alaska, Inc.'s application requests substitution of static bottomhole pressure surveys for the transient surveys required in Rule 6(c) and (d) of CO 165. These static pressure measurements were taken during the scheduled FS2 shutdown (March 12-19) after a shut-in of approximately seven days. Pursuant to CO 188 and 192 it has been determined that static bottomhole pressure surveys serve the intent and purpose of Rule 6 of CO 165 and may be substituted for the tramsient survey. The Alaska Oil and Gas Conservation CommissiOn hereby authorizes substitution of static bottomhole pressure surveys for transient surveys in PBU wells DS 3-10, DS 3-15, DS 3-18, DS 4-1, DS 4-5, DS 4-11, DS 9-1, DS 9-6, DS 9-10, DS 16-1 and DS 16-9 pursuant to Rule 2 of CO 192. very ~r~f~, 'Lonnie C. Smith Commissioner BY ORDER OF THE COM}!ISSION lc ARCO Alaska, In( Prudhoe B~, ,-:ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 15, 1984 C. V. Chatterton STATE OF ALASKA Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: Prudhoe Bay Unit DS 3-10 DS 3-15 DS 3-18 ~ DS DS 4-5 DS 4-11 DS 9-1 DS 9-6 DS 9-10 DS 16-1 DS 16-9 Permit No. 79-21 Permit No. 79-92 Permit No. 79-103 Permit No. 70-42 Permit No. 71-25 Permit No. 78-6 Permit No. 75-76 Permit No. 76-48 Permit No. 76-82 Permit No. 80-136 Permit No. 81-19 Enclosed are Sundry Notices requesting permission to substitute static bottomhole pressure surveys in place of transient pressure test prescribed in Conservation Order 165, Rule 6, on key wells 4-5 and 9-6, and section wells 3-10, 3-15, 3-18, 4-1, 4-11, 9-1, 9-10, 16-1 and 16-9. The static pressure measurements on these eleven wells are part of a package being planned to obtain a baseline reservoir pressure in the FS2 waterflood area prior to the start of water injection. Each well will be shut-in for approximately seven days prior to its survey. We believe that these static pressure surveys will provide a better interpretation of reservoir pressure in the FS2 area than transient pressure surveys and will satisfy the intent of Conservation Order 165, Rules 6(c) and 6(d). If yOu have any questions concerning this request, please contact Dan Cavin at 263-4268. Very truly yours, D. F. Scheve DFS/DLL/STATE/lmh cc: SOHIO Petroleum Company File PI(DS)Wi-3 ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfieldCompany ' STATE OF ALASKA ALASK ..IL AND GAS CONSERVATION .vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 70-42 3. Address 8. APl Number P.O. BOX 100360, Anchorage, Alaska 99510 50- 029-20078 4. Location of Well 1327'S & 295'W fr NE cr of Sec. 34, TllN, R15E, UM (surf) 1448'E & 1672'N fr SW cr of Sec. 35, TllN, R15E, UM (top pr( 1513'E & 1449'N fr SW cr of Sec. 35, TllN, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 64' RKB 6. Lease Designation and Serial No. ADL 28324 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number .d) DS 4-1 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [-] Change Plans [] Repairs Made Pull Tubing [] Other [~[ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all .pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska Inc. requests permission to run a static bottomhole pressure survey on section well 4-1 in lieu of a pressure transient test for 1984. Conservation Order 165, Rule 6(d) requires an annual transient survey on one well in each governmental section producing. A static pressure survey will be run while the well is shut-in during the flow station shutdown (March 12-19) to fulfill the State's requirements. The static pressure survey should prOvide accurate reservoir pressure data. RECEIVED kdAR 2 3 1984 0il & Gas Cons. C0mmissl0rt Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of APproval~ if any: Approved by Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Tr plicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post OfficeFl~"x 360 Anchorage[~ ~ka 99510 Telephone 90/' 277 5637 March 19, 1984 Reference: ARCO Cased Hole Finals D.S. 4-1 12-5-83 D.S. 4-10 "- 12-9-83 D.S. 4-11-' 12-5-83 D.S. 4-13 ~/ 12-9-83 D.S. 5-2 ~ 1-13-84 · D.S. 6-8~" 12-9-83 D S 6-11// 12-21-83 D S 7-15 / 12-18-83 D.S. 9-7f, z 12-4-83 D S 9-16' 2-20-84 D.S. 9-17~ 12-4-83 D.S. 14-5 ~ 3-4-84 D.S. 16-1~z 3-9 -84 D.S. 16-11 -~'~ 3-10-84 D.S. 16-16-'~3-10-84 MS/CNL/GR EPL MS/CNL/GR CET Log Collar Log CH CNL CH CNL Perforating Record MS/CNL/GR Collar and Perforating Log MS/CNL/GR Collar & Perforating Log Collar & Perforating Log Collar & Perforating Log Collar & Perforating Log ign and return the attached copy as receipt of data. HAVE A NICE DAY Run 1 5" DA Run 1 5" Sch Run 3 5" DA Run 1 5" Sch Run 1 5" Camco Run 2 5" Sch Run 3 5" Sch Run 1 5" Sch Run 1 5" DA Run l&2 5" GO Run 1 5" DA Run 1 5" GO 5" GO Ru-n 1 5" GO Run 1 5" GO Kelly McFar land ATO-1429F Trans. # 101 DISTRIBUTION Chevron Mob i 1 D & M Mobil E & P Dallas Phillips Drilling Prudhoe Bay Well Files Ext. Exploration R&D Exxon Getty Marathon Carolyn Smith ARCO Alaska, Inc. Post Offic~ x 360 Anchorag~ .ska 99510 Telephone 907 277 5637 January 19, 1984 Reference: ARCO Magnetic Tapes w/Listings D.S. 2-10--~ 11-6-83 CN/MSN #1861 DA ..... ~_: S.~9 n~_~l 2.~L 83 ........ ~N~M~ N #1886 DA ~'I'5';~'~'I:'I2:84- ..... ~'C, NL #228638 wTristing D.S~' 1-11-84 CH C~ #228635 w/lzst[ng GO '~ ~_ -- ~.,-~ ~ ~ - ~. D.S. 7:14~ 1-12-84 CH C~ ~2'28636 ~/li~'~i~'~ ...................... GO D.S. ~22~~11Z~ CH CNL ~228633'w/listing GO ~VEz~I~':-~ I2-1-83 , TDT Edit #68838 9~listing ? ~-./~.~.~ .-zb~ ~.:.~-~.~f ,~- f~ :~ Run 1 Sch Run 1 Sch Run 1 Sch D.S. 6-11-'"' .12-21-83 CH CNL #68871 w/listing Run 3 Sch :~ l 9 :. ~,..:. ::- c ~, ..: :'r.V "-- ?i?.. !"" 'Z-- i :: ?-:: ............................... ~. , ~ :7 ' .-' .,, c ...' ;' c~t ~., ::,z ,' 7 .,, .~m:__.~':';-:~':;.~'~ ..... :.~.:,.__~.~.:.~o... .~{:..i:,~,~.:,.~o : ~ ~..~:? i-.~ j:~ ......... ~,.,..,..,. ',, Please sign and return the attached copy as receipt of data. Kelly McFar land ATO-1429F Trans. # 019 Chevron D & M Dallas Drilling Exxon,~ Getty Marathon Mobil DISTRIBUTION North Geolog7 :;:. '~:.t' .it Phillips Prudhoe Bay R& D Sohio ;~CO A~aSka. !nc. :~ a S~ d:ar,, of -' Hant~cR~egfie;~."3c": - Bill Sheffield, Governor ALASKA OIL AND OAS CONSERVATION COMMISSION November 21, 1983 3001 PORCUPINE DRIVE ANCHORAGE.ALASKA 99501 '-3192 TELEPHONE (907) 279.-1433 · . ADMINISTRATIVE APPROVAL NO. 165.6 Re: The application of ARCO Alaska, Inc., Eastern Area Operator, " ~ ~"~ ' ~ ~ 1 Prudhoe Bay Unit, to substitute ~!i~?~!~:,:~~: W~e ls 6-8 ~, and 1-10 for current key Wells 1-8, 4-13" and 7 - in the Gas-Oil-Contact (GOC) monitoring key well program. Mr. D. F. Scheve Operations Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Dear Mr. Scheve: The referenced application was received on November 9, 1983 and stated that wells 1-8, 4-13, and 5-7 would no longer be suitable for GOC monitoring. Wells 1-8 and 4-13 are scheduled for con- version to water injection and 5-7 has recently undergone mechan- ical changes rendering it unacceptable for GOC monitoring. Our studies indicate the selection of Wells 6-8, 4-1, and 1-10 as suitable for continued monitoring of gas-oil-contact move- ment. The well substitutions will not cause undue problems and appears to be a prudent action. The Alaska Oil and Gas Conservation Commission hereby authorizes the substitution of Prudhoe Bay Unit Wells 6-8, 4-1, and 1-10 for Prudhoe Bay Unit Wells 1-8, 4-13, and 5-7 in the Gas-Oil- Contact Monitoring program, pursuant to Rule 9(c) of Conservation Order No. 165. Yours very truly, Harry W. Kugle~ Commi s s ione r BY ORDER OF THE COMMISSION lc ARCO Alaska, lnct6 Post Office~ 360 Anchorage. Alaska 99510 Teie~ho.,"e £,~7 ~77 55~7 August.31, 1983 Re ference ' Arco Pressure Data D.S. 4-1 7-22-83 Pressure Build-up GO sign and return the attached copy as receipt of data., Kelly McFar land ATO-1429F Trans. # 498 Chevron D & M Dallas Drilling Exxon Getty Marathon Mob i DISTRIBUTION. Caroling Smith Sohio ARCO Alaska, Inc. Post Office-- 360 Anchorage.~'Alaska 99510 Telephone 907 277 5637 November 23, 1982 RE' ARCO Cased Hole Finals D.S. 1-8 f 10-24-82 CH CNL D.S. 1-22~ 11-6-82 CBL/VD D.S. 4-1~ 10-30-82 CH CNL D.S. 5-7f 10-26/5-14/10-22-82 CNL Gas Monitor Log D~S. 5-7~ 10-22/5~14-82 CNL Gas Monitor Log D.S. 5-7~ 10-22-82 O.S. 5-14J 10-30-82 D.S. 5-12~' 10-23-82 D.S. 6-23 J 10-21-82 D.S. 6-24~ 11-4-82 D.S. 13-5J 8-20/11-1-82 ~D.S. 13-15~ 10-21-82 D.S. 1~~10-3-82 v7-22-82 10-21-82 Run 5 SCH Run 1 SCH Run 6 SCH Run 3, lO, & 11 SCH Run 10 & 11 CH CNL Run ll CH CNL Run 3 CH CNL Run 7 ACBL Run 1 CBL/VD Run 1 CH CNL (CNL Monitor Overlay) Run I & 2 CBL/VD Run 1 ACBL Run 1 Spinner ACBL Run 1 SCH SCH SCH SCH D/A SCH SCH SCH D/A Camco D/A Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA- 403 Trans. #625 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON · CHEVRON EXXON MOBIL GETTY D&M STATE OF ALAS DALLAS ARCO Alaska, Inc. Post Office4~' ,< 360 Anchorage.~. ,ska 99510 Telephone 907 277 $537 November 8, 1982 RE' ARCO Magnetic Tapes with Listings ~- D.S. 5-14 10-30-82 Cased Hole CNL SCH Tape #ACC 66015 Cased Hole CNL Tape #ACC 66013 /D.S' 4-1 10-30-82 SCH Run 3 Run 6 ~' D.S. 9-15 10-31-82 Cased Hole CNL SCH Tape #ACC 66014 Run 1 D.S. 13-5 1 l- 1-82 Cased Hole CNL SCH Tape #ACC 66016 Run 3 ~,,- D.S. 3-10 10-29-82 CNL (6 passes) D/A Tape #ECC 1507 ,, D,S. 13-3 10-22-82 CNL/Multispace (2 passes) D/A Tape #ECC 1503 '"- D.S. 4-13 10-31-82 CNL TBI~e #ECC 1508 D/A ~,.. D.S. 1-21 10-15-82 Open Hole D/A Tape #ECC 1489 ,~-~ D.S. 13-4 10-23-82 CNL & CNL Repeat D/A Tape ~#ECC 1504 Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA-403 ~ ~ ~'. F:! V ~: ,. . Trans' #608 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M 'STATE OF'ALASKA' DALLAS NOV .~. ~.') '.'~,,',,,, Alaska Oil & {,~,~s Cc, ns. U~:~m~ ....... ARCO Oil and Gas t~ mpany North Alask;~...strict Post Off;ce Box 360 Anchorage, A!aska ~°9510 Telephone 907 277 5637 Jerry A. Rochon District Cpera(ions Engineer . January 4, 1982 Reference: ARCO PRESSURE DATA D.S.4-1 10/22/81 Pressure Survey ~e sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 853 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company ~5 a Division of At!a{H~cR~chlielc~Company JAN- 7' 982 Alaska 0il & Gas Cons. Commissior~ Anchorage ARCO Oil and Gas~~- mpany North Alask[~ ,strict Post Office Box 350 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer Septemb'mr 3, 1981 Reference: ARCO CASED HOLE FINALS 8/10/81 CNL Run 2 5" DS..4-4~- 8/10/81. CNL Run 2 5" D.S.5-14~ 1/22/81 TDT Run 1 5" D.S.6-7 w 8/7/81 CNL Run 2 5" D.S.9-3 ~' 8/9/81 CNL Run 1 5" D.S.17-6~/ 2/6/81 CBL/VDL Run 1 5" ~l~~~e~ sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #567 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG, MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY SOHIO MARATHON Alas~0il& GasC0ns. C0mmissi0~ CHEVRON Anch0mge ARCO Oil and Gas Company is a Division of AttanticRichfieldCompany ARCO Oil an~t;'Gas Company North Alask(' 'strict Post Office ~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer August 27, 1981 Reference: ARCO Magnetic Tapes & Lists D.S.i-16 8/8/81 Tape#62100 Run 2 Schlumberger ~~~~'~*:'~ '8/10/81 Tape#62111 Run 1 " D.S.6-7 8/7/81 Tape#62103 Run 2 " D.$.17-10 8/13/81 Tape#62077 Run 1 " P~~lease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #550 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO OH and Gas Company ~s a D~ws~on of AtlanlicRichlieldComl3any EXXON MOB I L GETTY PHI LLI PS SOHIO ARCO Oil and Gas Company North Aia~ ~3ist~ct Post Office-,.,ox 3o0 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer January 28, 1981 Reference: ARCO Pressure Data 12-08/09-80 D.S.4-6 12-06/07-80 Pressure Survey Pressure Survey /Please sign and return the attached copy as receipt of data. Mary Kellis North Engineering Transmittal #19 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG; MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON Oil & G~s Cons, Commissio~ Al~chorage ARCO Oil and Gas Company is a Division of AtlanticRicht'ieldCompany ARCO Od and Ga~r ','npany Nor{h Alask: district Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 'Jerry A. Rochon District Operations Engineer November 21, 1980 Reference: ARCO Pressure Data Pressure Survey 5/8/80' O.S. ~4-7 5/12/80 " " O.S. 4-6 5/10/80 " " o.s. 4-5 5/15/8o " " D.S. 4-5 9-7/8-80 " " CONFER: ~Please sign and return the attached copy as receipt of 'data. Mary Kellis North Engineering Transmittal #837 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON . .RECEIVED . Alaska 0il & Gas Cons. Commission Anchorage ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ARCO Oil and Gas mlpany AI3sk~ i,~.d rici Post Of[ice Bc.x %0 Anchorage. Ai:~sk~ 9:)510 Telephone 90'; 277 5~537 April 3, 1980 Reference: ARCO Pressure Surveys 9/2-3/79 Camco 11/7-8/79 " D.S, 4-9 9/18/79 Camco D.S. 1Z-3 3/1Z/80 Dresser Atlas jPlease sign and return the attached copy as receipt of data. 'K. J. Sahlstrom North Engineering TRANSMITTAL #254 DISTRIBL~FION North Geology R & D Drilling Eng. ~'~nager D & H Geology State of Alaska ~bbil Getty Phillips Sohio ~rathon ~ex~on Po3! OlS.q~' .330 Ancllora,.Se, ~laska .°,.9510 Tel~p',~one 907 277 5337 AprillG, 1979 . ~~!~ Enclosed are copies o£ the following Pressure ~D.S. ¢4-7 3-19-79 . Please sign and retu~ the attached Fopies of the transmittal as receipt of data.~/~~--~/~¢/F Very t~ly yours, R. A. Hamlin North Operations Engineering Transmittal #154 i,i, :; ,, ,r:::!;z DISTRIBUTION North Geology Drilling Eng. Manager R & D Geology State of Alaska D & M Exxoh Mobil Getty Sohio Marathon Phillips Chevron -ichfieldCompany No,H.h Amc;';/ ,-,c, ducir',g Norlh Alask J~._...~trict Post Office Box 360 Anchorage, A~aska 99510 Telephoj~e 907 277 5637 December 1, 1978 State of Alaska Attn: Mr. Hoyle Hamilton 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: In regards to your request for delinquent reservoir surveilance data, our records indicate the following: - Wells #3-3, 3~4, 3-6~-1~4-6, 4-9, 5-15, 5-16, and 9-44 per your dates~l~'{cate that they are Initial Static Surveys where they were shut-in for less than 12 hours and no stabilized flow rates are available. - Copies of surveys for D.S. #9-6 and #1-6 have been sent on ll-28-7~..and should reach your attention shortly. D.S;' #5-8~as sent out earlier this year and a copy will b~f~t with this letter for your information. If further information is needed, please do not hesitate to request it from us. Very truly yours, F J.~. A. Rochon District Engineer ral- JR HKVP A[lantic~ichfi~,'ldcompany North Americ~n Rej Producing Division AlaSkapost Office~ox 360 Anchorage, A~aska 99510 Telephone 907 277 5637 October 24, 1978 · · Reference: RECEIVED Division Enclosed are Transient Pressuro Surveys for the following dr~ll sites: .... o.s. #4-5 9/30- 10/1 8/25-27/78 1978 Please sign and return attached copy of transmittal as receipt of data. Very truly yours, R.A. Logue North Alaska Engineering Transmittal #524 AtlanticR[chfieldCompany North Amerig Producing Division North Alaskt~ .trict Post Office l~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 14, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject:~S 4-~~ Permit No. 70-42 Permit.No 70-63 DS 4-3 DS 4-4 DS 4-5 DS 4-6 DS 4-7 DS 4-8 DS 4-9 Permit NO. 71- 5 Permit No. 71-11 Permit No. 71-25 Permit No. 76-83 Permit No. 75-77 Permit No. 76-10 Permit No. 76-30 DS 4-10 Permit No. 76-42 Dear Sir: .... ~ Enclosed please find a Completion Reportf!for the above- mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer FMB: lr Attachments RECEIVED gOO 1 8 I978 SUBMIT IN ., CATE* STATE OF ALASKA ~ s~ oth~,,- sY tractions cfi OIL AND GAS CONSERVATION COMMITTEE re,,~,-.~ s~,~; WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELL WELL ~ DRY Other b. TYPE OF' COMPLETION: WELl. OVER [._3 EN ~ BACK RESVR. Other __ 5. AP1 NLr~L~ICAL CODE 50-029-20078 6. LEASE DESIGNATION A.ND SERIAL NO. ADL 28324 7. IF INDIAN, A_L,LO~ OR TRIBE NA~,LE 8. UNIT,FA1TM OR LEASE NAME Prudhoe Bay Unit 9. WE3.,L NO. DS #4-1 (23-35-11-15) t~ FiELd, A~qD PO~L, OR ~IJ~DC~%~ ~ruanoe ~a¥ ~'le£a Fruonoe Oil Fool 11. SEC., W., R., 1VI., (BOTTOM HOLE OBJECTIVE) Perforated 9. NA~,IE OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR ' P.O. Box 360; Anchorage~ Alaska 99510 4. LOC~TION OF WELL (Report location clearly and in accordance with any State requireme~ts)* At surface 1327'S & 295'W fr NE cr of Sec 34, TllN, R15E, At top prod. Interval reported below UM 1448'E & At total dep~ 1513'E & 1672'N fr SW cr of Sec. 35, 1449'N fr SW cr of Sec. 35, 13. DATE SPUDD~ [14: DATE T.D, R~CHED 11-27-70[ 12-27-70 }i~. ~x~ co,~(~i~ 1-I0-71 5-14-77) 18. TOTAL DEIaTH, ~LD & TVD[19. PLUG, B~CK MD & TVD~. IF N~JL'r ,~L-'LE COM~L., [ 21. 9790'MD, 9039'TVD [9050'MD,8384'TV]~ ~°~g~iel, 9.9~. PRODUCING !NT~iVAL(S), OF THIS COMPLETIOAI--TOP, BOTTOM, NAME (MD AND TIE))* Top Sadlerochit : 9 2 9 6 ' MD, 8 6 0 3 ' TVD Base Sadlerochit 9754 'MD, 9007'TVD ,Sec. 35, TllN, R15E,U~ TllN, R15E, U! TllN, R15E, U! i~.. P~amT NO. 70--42 ELEVATIONS (DF, RKB, RT, GR, ETC)* 17. ELEV. CASINGHEAD KB 64.0' INTERVALS DRILLED BY '[' CABLE TOOLS !~3. WAS DIRECTIONAL } SURVEY MADE Yes 24. TYPE ~.LF.C~i=~iIC A~O OTI~ LOGS RUN GR/CBL/VDL, DIL, FDC, SNP' BHC-SONIC, LL-3, CASING RECORD (Report all strings set in' ~'{'1')' ' .... 30'" : 157! B [ 115 39"[' 20" '~L33 &' 94~ IH ~ K! zi85 26" 1 ~3-3/8"" ' 22~ / N-e0] 2686 ~-~/2" 9-5/s" 7, 43'. 5a.4q~ s~I 9249. L2-1/4'' LI~ ~CO~' GR/CNL/CCL SS GYRO Survey, CBL & Temp. Survey, SIZE TOP (AID) BOTTOM (MD) SACKS CEMENT*: SC:iLEEN (RID) CEML..NTING REC O P~D SEE REVERSE SiDE II !! Il II II II !1 II !! i A O/IC~UNT PULLED --0-- --0-- -Q- 27. TUBING RE C,OP~D SIZE DEPTH SET (MD) ~ PACKER SET (MD) 28, PEI{FORAT1ONS OPW.~q TO (Interval, size and number) 'g705'-9721' 683'-9706' ~ 9666'-9678' ~ 9654'-9662' ~9627'-9647' shots foo~ 30. PRODUCTION 29. ACID, si!eT, FiiAC~'(IRE, CF2vIENT SQUEEZE, ETC. DEPTIi iNTF_.RVAL (MD) AA,I©UXF £~ND 1-21ND OF MATEPI~L USED 706 0 630 WATER--BBL. [ OIL GRAVIT¥-API (COiR/{.) I 0 J 27.0 .... J TEST WITNESSED BY Production Operations EE 33. I hereby certify that the foregoing and attached information is complete and correct as determined from all-available re'cords SIGNED ~~~_~ f~TITLE District Drlg Engineer WT~ _c~/~~._~ ..... ii ! I II *(See Instructions and Spaces [or Additional Data on Reverse Side) Reinjected 32. LIST OF ATTACHMENTS DA~FTI~~ [ PRODUCTIO:N MEI.[{O,D (Flowit~g, ga3 lifL pumping--size and type of pump) {V/ELL STATUS (Producing or June 1977 ~ Flowing Division et 0~{ a~ld Oas L~n~~cino ~~ T~,T~ 'lcnoxr size IP~OD'N FO,a m~L. ~.%~CF. { ~13/77 4.0 30° 69 4 ~' · ...... · , , ,, 5 I I o I [ I i:;,~n~,JcHicli:'ieldCompany North American Producing North Alasyt~;strict Po~t Olfice J .. :.?~ ~, ', Anchorage,~kiaska 99510 ,'~"xkL,'~ ., '.'.'~ ' , Telephone ~07277 5537 ~'-~:."~ ':' ~"" ~' ', t. ~ "' ~'2'X , . ." :.'~ O~e 29, 1978 Enclosed are copies of of the following Cased hole logs: Ganm~a-Ray Neutron Log D.S. #5-2 5"'( 1 Dresser Atlas - 1 Go Wireline) Compensated Neutron Log D.S. #4-15 2" a 5" Cement Bond Log 2" a 5" Neutron Log D.S. #1-4 5" Casing Collar Log & Perforating Record D.S. #1-13 5" Continuous Flow Survey · -D.S. #5-8 5" D.S. #1-4 5" Please sign and return copy of trm~smittal as receipt of data. Very truly yours, North Operations Engineering Transmittal #373 RECEIVED ,'-," "19'.78' ]:l'()~tt ' .......... J. A. Rochon/R. A. Lo. gue Name: n:.:~;~i [.lc:c! herev.-Zt.h are the foil. ow.lng for t];c s',:bjcct well' No. Scale Xerox .......... Acid or Fracture Treatment Log . ........ B!IP Buildup ~ Flow' .Profile Su~,ey },mono]e Geometry Log _,_..-Carbon ~)'gen Lo~ . Casing Collar Log ...... Cement Bond Log -.~ ..... Compensatecl Neutron LOg -- Cased Ilole Core Analysis - Interval Core .... :. Core ])escriptio~ (SMO)- ...... Core Description (Com~.) - Core ....... ])irectional gurv~y- Gyro - Single S~j6t .... ...... ' .']ln2ineerin2 Production-Log Fluid Analysis ...... .Fluid Density ....... Gamma' Ray ].,ocation Plat ....... B~onthly lfell Test Data Nud Lo~ ..... t'erforat~2 Record State Reservoir Pressure Bepo~t .... · Surveillance Reports Temperature Log ....... TVD Logs - Duel Induction Laterolog - Compensated Formation D;.ns.tt). I,oa - Compensated Neutron-Fox, ration Density Log - BorM~ole Compensated Sonic Log - Porosity I.og ~se Re't'~,rn Rece:tpt 7'0' Atlantic Rich'field P. O. Box 360 Anc]~orage, A~as~ Sep.:~.a 'BL Lit REC!:: vE.n "*"-"/} i978 PMsion o~ Oil and Gas ~;ons~mation ])ate- North Alaska DistrictEngin,, _f~ ...... :tg TRAN SM I TTA L ' From: J. A. Rochon/R. A. Logue ansmitted here~vith are the follo~dng for the subject n No. Scale Xerox Sepia BL Line Acid or Fracture Treatment Log · BlIP Buildup ~ Flm~ Profile Survey Borehole Geometry Log 'Carbon Oxygen Log ___ Casing Collar Log ~ Cement Bond Log Compensated Neutron Log - Cased Hole Core Analysis - Interval Core No. __~ Core Description (S~.IC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro - Single Shot - Multishot __~_ Engineering Production Log __. Fluid Analysis , Fluid Density .... 'Gamma Ray Location Plat .... Monthly Well Test Data MUd Log perforating Record State Reservoir Pressure Report · _ _ Surveillance Reports __ Temperature Log .... Transient Pressure Surveys TV]) Logs - Duel Induction Laterolog - Compensated Formation Density Log - Compensated Neutron-Formation Density Log - Borehole Compensated Sonic Log - Porosity Log ~ase Return Receipt To' Ms. R. A. Logue Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 O: K. G~lhveth, Jr Febzuary 9, 1978 D~ Test Surface Safety Valves (SSV), Subsurfac~ Safety Valves (SSSV), L~w Pressure Pilots and Annular Pressures cn ARCO's Drill Sites %1, %4 Subject test involved two separate trips to Prudhoe Bay, ~ first c~ January 16, 1978, and the second c~ January 22, 1978, with eight cumlla- rive days spent testing. Part of the second trip was utilized retest- lng cer~_~-~n wells on drill site %1 after guide lines were agreed upon at a n~et/ng between agency and ARCO productio~ personnel c~ January 20~. L.P. Pilot Initial Actuated F l~ing .@ .PS! _ Pressu te . SSV SSV SSSV SSSV 9 5/8" Tested Test' Tes%ed Test Annulas 1-1 1-2 1-3 1-4 1-5 1-6 1-7 1-8 1-9 .l-10 4-4 4-5 4-6 4-7 4-8 4-9 4-10 720 70O 700 660 700 7OO 700 700 700 780 680 775 670 700 700 700 650 65O 1550 1270 790 1020 900 1550 1140. 1140 1600 1400 2075 1300 1450 1560 1300 1500 1350 960 1450 640 OK 825 OK 25 675 OK 720 OK 0 620 OK 660 Failed 0 680 OK 700 CK{ 0 740 .. OK 700 OK 90 800 OK 810 CK 0 695 OK 650 .Failed 60 740 OK 750 Failed 0 970 Failed 1000 Failed 0 * ** Inoperable 700 OK 700 OK 0 * *** Failed 0 750 OK 750 OK, 0 750 OK 750 OK 0 700 OK 890 OK 0 * *** Failed 100 775 OK 700 OK 0 700 OK 760 Failed 0 660 OK 650 CK~ 100 700 CK~ *** Failed 50 * Not tested ** SSSV inoperable. Being~pulled. *** SSSSV would not close. 13 3/8" k~ulas PSI 0 0 0 100 0 50 0 0 100 0 250 0 0 0 0 0 0 0 ~ D.S. 91, '%4 Fe~ 9, 1978 Of the twenty sssv, s tested, n/ne, or 45%, ~ inoperable or failed. F~ SSV's tested successfully and cne failed. Three SSV's %~re not tested after it was found the SSSV's /n the wells %Duld not test. These Field ~ reports were prepared and copies ma~41_ed to A1 Brown, prcd~cn super/n~dent, and Den Franks, assistant production su~tendent. Originals of the field iruspectic~ reports are attached to this report. Drlg. Permit No.~_ Operator__m~?~ A1 _.<a Oil and Gas Conservation Committee Field Inspec~tj~on Report ~'~o-J Wel 1 / P:l~i:~I~ Sec T R~,_. _M Represented by~'~.N~,.~ Name & Number /L).~' ~-J' . Satisfactory Type Inspection Yes No Item ( ) Location ,General ( ) ( ) 1. Well Sign ( ) ( ) 2. General Housekeeping ( ) ( ) ~. Reserve Pit-( )open( )filled () () 4. Riq (~2/~'Safety Valve Tests ,,-- (l~)" ( ) 5. Surface-No. Wells / (~ ( ) 6. Subsurface-No. Wells ~, ... ( ) Well Test Data ( ) ( ) 7. Well Nos. , , , ( ) ( ) 8. Hrs. obser , , , ( ) ( ) 9. BS&W ,--,--, ( ) ( ) 10. Gr. Bbls., , , ( ) Final Abandonment ( ) (). 11. P&A Marker Satisfactory Type Inspection Yes No Item ( ) BOPE Tests 15. "Casing set @ 16. TesL fluid-( )wtr.---~ )mud ( ) oil 17. Master Hyd. Control Sys.- psig 18. N2 btls. ,__,__, psig 19. Remote Controls 20. Drilling spool- "outlets 21. Kill Line-( ) Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No. valvs flas 24. Chokes-( )Remote( )Pos.(-}-~-dj 25. Test Plua-( )Wellhd( )csg( )none 26. Annular Preventer, psiQ 27. Blind Rams, ... psi~ 28. Pipe Rams ~psiq () () () () () () () () () () () () () () () () () () () () () () () () () () () () ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) ( ) ( ) 13. Clean-up ( ) ( ) ( ) ( ) 14. Pad leveled ( ) ( ) Total inspection observation time~hrs/d~ Total number leaks and/or equip, failures Remarks 29. Kelly & Kelly-cock psig 30. Lower Kelly valve psio 31 Safety Floor valves--E-(-~BV ( )Dart cc' .~E.~_-~:~,,~ Notify in days or when ready To' North Alaska District Engineering:'... '.. '. · ',, ',(.~' ...., -; '.,.'&...-.:~,:~. T RANSM I TTAL "&' ,, · , From: · _ x..:}~3t;' A. Rochon/D. R. Jackson Date: January 9,1978 Well Name: D.S. 4-1 .'- .. . . Transmitted here~Jith are the following for the subject well' Run No. Scale Xerox Sepia BL Line BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - InterVal Core No. Core Description (SWC) - Interval Core Description (Cony,) - Core No. Directional Survey - Gyro Single Shot Multishot Drill Stem Test - Test No. Dual Induction Laterolog ~' Formation Density Log Formation Density Log/Gamma Ray Gan~na Ray/CCL Laterolog Location Plat ~[[crolaterolog Microlog b~dlog- Interval Sample Log (A.R. C6.) - Interval Synergetic Log TVD-DIL TgD-Porosity Log Initia! Transient.Pressure Sumrey:Oct 3~_/77 Receipt Ackmowledged For' Date' Please return receipt to' ...... Attn: ~@. Donovan Jackson Atlantic Richfield Company North Alaska Engineering P. O. Box 360 Anchorage, Alaska 99510 #744 :ompany. &'ell Sorough DATE TIME Individual Well Data Sheet ATLANTIC RICHFIELD COMPANY Location NORTH SLOPE Field Formation__ SADLEROCHIT DRILL SITE ~4 -~tate_. ,Date.,, 30-31 OCTOBER 1977 CHRONOLOGICAL DATA ELAPSED TBG ' TIME PRESS HR. MIN. PSIG GAUGE GAUGE GAUGE 41007 HP 39402 BHP@ BHP@ TEMP F R.D.. R.D.' & DATUM 9604MD. 9598M.D. 9592M.D. -8812 -8806 -8800 o 1100 1310 1345 1708 '1712 1718 1724 1730 1736 1742 1748 1754 1800 1806 1812 1818 1824 1830 1836 1842 1848 1854 1900 1906 1912 1918 1924 1930 1936 1942 1948 1954 2000 2006 2012 10-30-77 RIG UP LUBRICATOR TEST LUBRICATOR SIH W/INSTS. MAKING STOPS AR R.D. 9592M. D. -8800 WELL FLOWING I! I! 1! !! II !1 I! !1 II !1 !! !! !! !! !! !1 ;, !1 !1 !! 00 :'00 00: 0'6 00:12 00:18 .00:24 00:30 00:36 00: 42 00: 48 00: 54 01 :'00 01: 06 01:12 01:18 01:24 01:30 01:36 01: 42 01:48 01:54 02: 00 02:06 02:12 02:18 02: 24 02:30 02:36 02:42 02: 48 02: 54 03: 00 986.7 186.0 3365 3367.5 3366. 9 3366.7 3366.7 3366.7 3366.1 '3365.4 3364.2 3363.3 3362.5 3361.7 3360.9 3360.4 .3395.2 3358.2 3357.8 3357.4 3357.4 3356.7 3357.6 3357.7 3358.2 3359.1 3358.9 3359.6 3360.0 3360.3 3361.3 3360.7 3360.7 3361.9 3361.5 mpany. ATLANTIC-RICHFIELD QDMPANY ;11 ~l~ ' Field rough NO ,.I~H SLOPE Individual Well Data Sheet Location · 'Formation, SADLEROCHIT C ~ ~0 N 0 T. 0 G Z C ~ 'r. D ~ T ~ D ~R._~r_~ S~ #4 Rtate__ Date 30-31 O .CTOBER .1977 ~ATE 'IME REMARKS ELAPSED TBG TIME PRESS HR. MIN. PS IG GAUGE GAUGE GAUGE 41007 BP 39402 BHP@' BHP@ . TEMP F R.D. . R.D. & DATUM 9604MD. 9598M.D. 9592M.D. -8812 -8806 -8800 018' WELL FLOWING CON'T 020 " 020' 021 022 023 024 025 026 027 028 029 030 031 032 933 934 935 936 937 938 939 940 941 942 343 344 ]45 346 347 ]48 ]49 ]50 )51 ]52 BUILD UP I! · · 03:06 03: 08 00:00 00:01 00:02 00:03 00:-04 00:05 .00:06 00:07 00:08 00:09 00:10 00:11 .00:12 00:13 00:14 00:15 00:16 00:17 00:18 00:19 00:20 00:21 00:22 00:23 00:24 00:25 00:26 00:27 00:28 00:29 00:30 00:31 00:32 3361.5 186.0 3358 3361.5 186.0 186.1 186.1 186.1 186.1 186.1 186.0 186.0 186.0 186.0 186.0 185.9 185.9 185'9 185.9 185.9 185.9 185.9 185.9 185.8 185.8 185.8 185.8 185.7 185.7 185.7 185.7 185.7 185.7 185.7 185.7 185.7 185.7 3361.5 3481.9 3 608.0 3713.9 3797.8 3859.6 3903.9 3934.3 3955.1 3970.0 3981.0 3989.8 3996.7 4002.3 4007.1 4011.4 4015.0 4018.1 4020.9 4023.4 4025.7 4027'.8 4029.6 4031.5 4032.9 4034.8 4035.9 4037'2 4038.5 4039.7 4040.9 4041.7 4042.8 Individual Well Data Sheet ,mpany. ATLANTIC RIOIFIELD C. OMPANY' ell ~1 FielH ,rough NORTH .SLOPE Location Formation SADLEROCHIT C H R O'N 0 L 0 G I C.A L D A T..A )ATE :IME REMARKS ELAPSED TBG TIME PRESS HR. MIN. PSIG DRILL SITE ~ #4 -C, tat_-_ _a T.~?_ FA Date 30-31 OCTOBER 1977 GAUGE GAUGE GAUGE 41007 HP 39402 B~@ BHP@ TEMP F R.D.. R.D. & DATUM 9604MD. 9598M.D. 9592M.D. -8812 -8806 -8800 · . D53 · D54 )55 )56 L02 L08 L14 L20 L26 L32 L38 .44 .50 .56 ~02 120 ,26 32 38 44 5O 56 02 10 20 3O 40 50 O0 [0 ~0 ~0 [0 50 BUILD UP CON'T I! I! I! II II I! I! I! I! I! I! II I! I! II II I! I! I! II l! · I! I! 10-31-77 1! . I! 00:33 00:34 00:35 00:36 00:42 00:48 00:54 01:0'0 01: 06 01:12 01:18 01:24 01:30 01:36 01': 42 01: 48 01: 54 .02: O0 02:06 02:12 02:18 02:24 02:30 02:36 02: 42 02: 50 03: 00 03:10 03:20 03:30 03: 40 03:50 04:00 04:10 04:20 04:30 185.7 185.7 185.7 185.7 185.6 185.6 185.6 185.6 185.6 185.5 185.5 185.5 185.5 185.5 185.5 185.5 185.5 185.5' 185.5 185.5 · 185.3 185.3 185.3 185.3 185.3 185.3 185.3 185.3 185.2 185.2 185.2 185.1 185.1 185.1 185.1 185.1 4043.6 4044.6 4045.4 4045.8 4050.2 4053.0 4055.9 4058.3 4060.6 4062.2 4063.5 4065.3 4067.0 4068.5 4069.5 4070.4 4071.4 4072.4 4073.3 4074.1 4074.7 4075.5 4076.1 4076.8 4077.5 4078.1 4079.0 4079.8 4080.7 4081.3 4082.1 4082.9 4083.6 4083.7 4084.6 4085.2 ~pany. I , ~ugh Individual Well Data Sheet NORTH SLOPE ,,, Location Field ~m~'3~ ~v Formation SADLEROCHIT CH RO'NOLOG I CAL DATA ELAPSED TBG TIME PRESS HR. MIN. PSIG DRILL SITE #4 State_ _~ T.___~.cK% Date 30-31 OCTOBER 1977 GAUGE GAUGE GAUGE 41007 HP 39402 BHP@ BHP@ TEMP F R.D.. R.D. & DATUM 9604MD. 9598M.D. 9592M.D. -8812 -8806 -8800 )0 )0 )0 )0 )0 )0 )0 )0 )0 lO ~0 ~0 ~0 ~0 ~0 ~0 0 ,0 0 BUILD UP CON'T II !l II !l !! SOI-:I W/INSTS I~.KING STOPS 04:40 05:40 06:40 07:40 08:40 09:40 10:40 11:40 12:40 13:40 14:40 15:40 16:40 17:40 18:40 19:40 20:40 21:40. 22:40 23:40 24:00 185.1 185.1 185.1 185.1 185.1 185.1 185~O 184.9 184,9 184.9 184.8 184.8 184.8 184.8 184.8 184.8 184.7 184.7 184.7 184.7 184.7 4109 4085.8 4089.1 4091.8 4093.9 4095.6 4097.4 4099~2 4100.2 4101.9 4103'.1 4103.7 4104.9 4105.9 4107.0 4107.8 4108.9 4109.6 4110.3 4110.7 4111.4 4111.6 MILE 4. NORTH RD. BOX 3453 KENAI. ALASKA 996ll PH. 1907! 283-4403 Company Well Location #1 Field ~]0RTH SLOPE Formation , 1000 ~..001~'ressure 3000 'Location PRUDHOE BAY D~TT.T. ~Tq~. ~ TEMP 4000 Fo P.O. BOX 4o155! ANCHORAGE. ALASKA 99501) TELEPHONE i907! 276-3525 TLX 0902-6481 State ALASKA , Date ~n-31 c~q~n~ lq77 .' .... '7 41007 lip M.D. "sLgc.Press Press 9721 -8912 -' 4111.1 9681 -8874 4110.7 9665 -8865 4110.9 9653 -8854 4111~0' 9650 -8851:. .i 4111.2 9620 -883t_.~.? 4111.0 184.7 ..... 173.. 6 8693 ,9592 -8800_4109 4111.6 125.5 5246 89.5 . 2Q64 --0-- Gmdim PSI/F': -8000 3848 3.850.2..' .32.~ -5000 2841 2842,7 -2000 17~6 1787.4 .35; -64 !434 143~,.8' .18; Well Information Elev. -64 Datum -8800 Csg. to Tbg~ to Perfs. Zero Pt. K.B. · tO Pkr Oil Level Well status PBTD ,, Csg Press ,, H20 Level ~ Prod rate Date last test Status of well last test Prod. rate last test Press. last test Press. this test Press. change Element Nos. 41007 Calib. No. Remarks MILE 4. NORTH RD. BOX 3453 KENAI. ALASKA 996ll PH. 1907) 283-4403 P.O. BOX 4-lg5! ANCHORAGE, ALASKA TELEPHONIr I907) 276-3525 TLX 0902-648! Company Well Location ATLANTIC RICHFIELD COMPANY Location #1 1000 Field .... PRUDHOE BAY Formation .q ADT.W.~cx"WT'P 2000Pressure 3000 DRILL SITE ~4 , . State ALASKA Date 30-31 OCTOBER 1977 TEMP 41007 H. P. FO M.D. S.S. PRESS. PRESS. GRADIEE '-0- -64 980 986.7 146.9 1990 ~1926 1397 1399.4 .222 ~47.2 2090 -2026 1416. 1419.9 .205 149.8 2290 -2226 1465 1467.7' .235 ~50.6 2390 -2326 1495 1497.3 .29E 163.2 4128 -4000 '1921 1923.7 .255 176.4 6401 -6000 2485 2487.9 .282 184.4 8693 -8000 3100 3102.7 .307 186.0 9592 -8800 3365 3367.5 .331 Well Information Eiev. -64 Datum -8800 Zero Pt.~ K-B-, Csg.9, .5/~ to 9749 , ...... to ........ Tbg. 5~ to 9223 to Peds. 9667 - 7921 Pkr. -9090 PBTD 9739 Csg Press' Oil Level H20 Level Well status Prod rate Date last test Status of well last test Prod. rate last test :, Pre~s. last test Press. this test Press. change Element Nos. 41007 Calib. No. Remarks Temp. Element Nos.- 39402 Safety Valve @ 2190 M.D.. DRILL SITE #4-1 PERFORATE ~N~) CLE~N~JP RECORD ~y 7-8, 1977 D.S. #4-1 was drilled to a bottom hole location in the southwest corner of Section 35, TllN, R15E, Prudhoe Bay Field. Depths of interest are: Measured Depth Subsea Depth Zon~ Top of Sadlerochit Gas/Oil Contact Perforations Base of Sadlerochit Junk Left in Hole 9297' 8550' 9330' 8580' 9627-9647' 8831-8849' 9654-9662' 8866-8876' 9666-9678' 8855-8862' 9682-9721' 8880-8914' 9753' 8942' None LBS SMB SMB SMB On the first gun run, fill was detected to 9722' M.D. As no shale breaks were present up to the next set of perforations, the first gunwas fired one foot off bottom at 9705' to 9721', 11' high. The well was flowed on a 1/2" choke at 1500 BPD and 50 psi tubing pressure for 7 minutes, rFhe choke was opened to 3/4" resulting in a stable rate of 2600 BPD and no tubing pressure. The well was shut in after a total of 18 bbls. and 13 minutes flow. The shut-in wellhead pressure built up to 810 psi. The second gun was shot from 9705' to 9682' while flowing on a 1/2" choke. The stable flow rate increased from 2600 BPD to 3300 BPD and tubing pressure from 200 psi to 300 psi. The choke was opened to 3/4", resulting in 4200 BPD and 125 psi tubing pressure. The flow rate increased to 6000+ BPD in 30 minutes and 270 psi tubing pressure. The chOke was returned to 1/2!' for the remainder of the flow, 3750 BPD and 350 psi. After a total of 180 bbls., gas reached the surface and the turbine meter wag bypassed. Shake-outs indicated the calcium chloride water came out in a slug, as much as 88% water was recorded. Very high amounts of solid were present, as much a 25% was found near the end of the calcium chloride slug (looked like drilling mud). The well was flowed an hour longer than normal in order to reduce the solids content to .2%. The final flowing tubing pressure was 1100 psi. The well was shut in after a total flow of 509 bbls. at an average rate of 3600 BPD. Shut-in tubing pressure was 1450 psi. The oil-AP1 gravity was 27.8©. The maximum flowing wellhead temperature was 45°F. A gradiomanometer was run showing the calci~n chloride water cleaned out to 9698' M.D. (8894' ss), leaving the bottom 23' of perforations covered with calcium chloride water. Fill was found at 9722' M.D. The well was flowing at 1025 psi tubing pressure on a 3/4" choke when 9654-9662' was shot. In two minutes the flowing pressure was 1050 psi when 9666-9678' was Drill Site #4-1 Perforate and Cleanup Record Page 2 shot. Five minutes later the flowing tubing pressure was 1060 psi when the well was shut-in. Shut-in pressure built up to 1425 psi. With the well flowing on a 3/4" choke and 1125 psi tubing pressure, 9627-9647' was shot. Final flowing pressure 5 minutes later was 1225 psi. The shut-in tubing pressure 24 hours later was 1510 psi (1512 psi by Amerada). An Amerada pressure bomb was used to obtain the 8800' ss static pressure, 4413 psi. The well was then flowed for ~vo hours and two minutes on a 1/2" choke. After 15 minutes flow, the tubing pressure was 1310 psi at 25°F. Final flowing pressure was 1460 psi at 42°F. The volume produced was 200 bbls. The Amerada showed a maximum drawdmm (just prior to shut-in) of 130 psi. This results in an approximate productivity index of 18 STB/psi. The maximum reading thermometer recorded a temperature of 186°F. Final shut-in tubing pressure was 1590 psi.~ The total estimated volumes of oil and gas produced during the perforating operations were 780 bbls. oil and 585 MCF ga~. JRM 6/14/77 (Aorth Alaska District Engineer~i:g TRANSMITTAl, To' ~_aT~ 05' &?_. ~,~ From' ])ate' _ August_ 15,1977 . _ J. A. Rochon/D. R. Jackson '~ Well Nmne' D.S. 4-1 Transmitted herewith are the following for the subject well' Run No. Scale . . Xerox Sepia BL. Line 1 BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gan~na Ray Log Caliper/CCL Cement Bond LOg/VDL Compensated Formation Density Log Compensated Neutron- Fot~nat ion Dens ity Compensated Neutron Log Core Analysis - Inter~al Core No, Core Description (SWC) - Interval Core Description (Cony.) - Core No. DireCtional Survey - Gyro Single Shot Multishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/~amma Ray G ~amma Ray/CCL Laterolog LOcation Plat Microlaterolog Microlog Mudlog- Interval Sample Log (A.R. Co.-~ - Interval Synergetic Log 'i~13- DI L TVD-Porosity Log .1 Borehole .~epmetry Lo_~ $-" __J__ Perforat in~ Record 5" R ECtZ[ D _ _ ea ~ Iea _ ! ea Division of Oil & G~s Con~e, rvallon _ lea "-i'ea ! ea - ! ea Receipt Acknowledged For: Date' ~/7~T ~7 Please return receipt to: Atlantic Richfield Company North Alaska Engineering ~t~nager P, O. Box 360 Anchorage, Alaska 99510 #548 IJate: 'July 28, 1977 North Alaska Dlstrict En],~ineering T RAN S M I T TA L ~TO~' l?ell Name: J. A. Rochon/D. R. Jackson DiS. ://'4-1 Transmitted herewith are the follmd.ng for the subject well' Run No. " Scale Xerox 'Sepia BL Line BHC Son'c/Caliper Log . BHC Sonic/Caliper-- Gamma Ray Log BHC Sonic/Gamma Ray Log' .., Calip&r/CCL Cement Bond Log/VDL "' Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Intmwal Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. D.i. redtional Survey- Gyro .. Single gl{°t b~ultishot · F~ill Stem Test - Test No. . Dual Induction Lat. erolog . Formation Density Log Fomation Density Log/Gamma R.ay Gamma Ray/CCL ...... Laterolog Location Plat ......... . Mlcrolaterolog .......... Microlog ~'~a. dlog- Interval Sample Log (A.R. C6.) - Interval ........... Synergetic Log TVD- l)I L TVD-Porosity Log .... ! _ _E_n~ineered Production Loggj_ng ],ecoa.pt Acknowledged For' pi.case return receipt to' 'Arian lb. chfie].d Company North' Alaska Engineerihg Manager P. O. Box 360 AnO~orage., ~.aska 99510 ~534 iiorth Alaska District Engineeri~]g TRANSMITTAL 'Date' ~y 31, 1977 Well Nmne' J. A:'Roc~,n/D? ~. Jackson D.S. C4_ Transmitted herewith are the follo~ving for the subject well' Run No. Scale BHC Sonic/Caliper Log BHC Sonic/Caliper - Gmnma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (~fC) - Interval 'Core Description (Cony.) - Core No. Directional Survey - Gyro Single Shot b~ltishot Drill Stem Test - Test No. Dual Induction Laterolog Fo~ation Density Log Formation Density Log/Gam~a Ray 'Ganma Ray/CCL Laterolog Location Plat b2crolaterolog ~crolog ~k~dlog - Interval Sanple Log (A.R. Co.) - Interval Synergetic Log %rD-DIL ~D-Porosity Log Xerox Sepia BL Line · Receipt Acknowledged For' Date'. Please retuxn~ receipt to: P. O. Box 360 Anchorage, Alaska 995.10 #431 AtlanticRichfieldCompany North Ame~ n Producing Division North Alas[ istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 26, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division. of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject4_2 '123-35-11-15) 13-26-11-15) DS 4-3 (23-34-11-15) DS 4-4 (14-36-11-15) DS 4-5 (23-27-11-15) DS 4-6 (22-03-10'15) Permit No. ~70-42 Permit No. 70-63 Permit No. 71-5 Permit No. 71-11 Permit No. 71-25 Permit No. 76-83 Dear Sir- Enclosed please find our Sundry NOtiCes of SUbsequent report detailing the work done on the above-mentioned Wells. Very truly yours, Frank M. Brown District Drilling Engineer /kb Enclosures 'JUH - 6 t977 D!vis{0~ of Oil and Form 10-403 REV. 1-10-73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) O,L ~ GAS F"l WELLI...JJ WELL OTHER 2, NAME OF OPERATOR P. 0. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 1327' S & 295' W of NE cr Sec. 34, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 64' RKB 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20078 6. LEASE DESIGNATION AND SERIAL NO. ADL 28324 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. Drill Site 4-1 (23-35-11-15) 10, FIELD AND POOL, OR WILDCAT ,Prudhoe Bay Fi el d-Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 151~'E-& 1449'N of SW cr Sec. 35; TllN, R15E, UM 12. PERMIT NO. 70-42 )ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF L-..-- FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF; WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Perforate (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work, Began perf operations on 5/6/77 Tstd tree, cs§, tbg & wireline BOP's. P:ulled dummy valve. Perf'd int rvals 9705'-9721' 9683'-9706' 9666'-9678' 9654'-9662', 9627'-9647' w/4 shots per ft. Ran Amerada l~ombs. Flowed well. Ran & set ball valve @ 2190'. Tstd balance & control lines to 5000 psi OK. Bled press above ball valve to 0 psi, held OK. Installed & tstd tree cap to 5000 psi. Released well to Production Department on 5/14/77. RECEIVED JUi'.t -- 6 977 16. I hereby certify that the foregoing is true and correct TITLE District Drilling Fnoin~e~ DATE- (This space for State office use) APPROVED BY .... CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side 02~01B STATE of ALASKA TO: j-- FROM: DATE : May 26, 1977 SUBJECT: Witness Tests cm Subsurface Safety Valve and Surface Control F~nfety Val~ for Arco DS 4-1 ,_ ~13,_!977 - I was picked up at DS-9 where I was staying at Arco's at 7:00 AM by Minoe Heb~, supervisor for Aroo. We w~nt to DS 4-1. Tubing pressure was 160~ psi. The surface cum~rol safety valve was closed and pressure above SCSV was bled to 200 psi. There was no buildup of pressure. I ob~er~ this fc~ 15 min~. The SCSV was close~ with SSSV open. ~he SSSV was n~ closed and p=es~ abo~ SSSV of 1600 psi was bled down 800 psi. ~ SSSV was set at 219,0 feet. There was no build up of p~uz~, ~ n~t leak. I observed this pressure for 15 Attar Drlg. Permit No. Operator ..~ ~, ~. ~ A ~a Oil and Gas Conservation Comm Field Inspection Report Wel 1/Platfm Sec T R Represented,.,.~:~'"~',:~,,,~,,~..>?. ..... ,?.,',/.~,~_~,, ~' Name & Number /,. Satisfactory ~ Type Inspection Yes No Item ( ) Location,General () () () () () () () () ~) () () () () () () () () () () () 1. Well Sign 2. General Housekeeping 3. Reserve Pit-( )open( )filled 4. Ri§~ (~)~ Safety Valv~ ~sts 5. Surface-No. Wells 6. Subsurface-No. Wells_~/ ( ) Well Test Data 7. Well NoS. , , , 8. Hrs. obser , , , .... 9. BS&W , , , 10. Gr. Bbls. ( )Final Abandonment ll. P&A Marker SatisFactory Type Inspection Yes No Item ( ) BOPE Tests () () () () () () () () () () () () () () () () () () () () () () () () () () () () 15. "Casing set @ 16. Test fluid-( )wtr.-~ )mud ( ) oil 17. Master Hyd. Con~.rol Sys.- _psig 18. N? btls. ,__,__,__psig 19 R~mote Controls 20. Drilling spool- "outlets 21. Kill Line-( ) Check valve 22. Choke Flowline ( ) HCR valve 23. Choke M~nifold No. valvs fl~s 24. Chokes-( )Remote( )Pos.(-}-A-dj. 25. Test Plug-( )Wellhd( )cs9( )none 26. Annular Preventer,__psi~ 27. B1 ind Rams ,__]~si g 28. Pipe Rams psig ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock psi.q ( ) ( ) ~13. Clean-up ( ) ( ) 30. Lower Kelly valve psi9 ( ) ( ) 14. Pad leveled ( ) ( ) 31. Safety Floor valves'( )BV ( )Dart Total inspection obServatiOn time__ ,s Total number leaks and/or equip, failures ~/~:y~m:' Remarks ,/~;' ~? ~' days or when ready Inspected by/,~/:,,~,~//i~/~/~,~" Date~ AtlanticRichfieldCompany North Ame~c~,n Producing Division North Alas( strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 16, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject 35-11-15) Permit No. 26-11-15) Permit No. DS 4-3 (23-34-11-15) Permit No. DS 1-2 (32-7-10-15) Permit No. 70-42 70-63 71-5 69-119 Dear Sir' Enclosed please find copies of the gyroscopic directional survey for your files on each of the above-mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer /jw Enclosures RECEIVED 1 ? !977 Divis!on ~ O!~ & ~ G~.n~rv~tion AD~hor~ To' DISTRIBUTED TO=. T RAN $ ~l I T T A L STATE OF ALAS~ 'DIVISION-OF OIL 8c · · ...... .,- . From: .o J. A. Rochon! p. Hellstrom. Date: Y=_y' 1%1977 . 1%11 ~cL %.;ell: TransPired here+,5~h are the fol!o-:~ng for ~he subj~ ~ · . Run No. . ., : Scale o BHC S6nic/C~35per Log- ':" BHC Sonic/Caliper D G~:~'~a Ray JL. og · . ' <- "'- ]~HC Sonic/g~-~ Ray. Log . . . Caliph=r/COL. . -- . Cement Bona Log/VDL- ' - · ~' - - ° - - o . ' Co~ ~ys~ - I~te~ ' .. "-' . . Ooze No.' ' . "~ Core ~es~igtio~ [Co~.) - ...... ' - ~- ~rec~on~ Su~=y -. ~o ....... ,. .. _ ' - .. 8~gle ~b6t " :'. .. - -;" ~ D3~! InSuc~on Late~olog ., . - =- F~~on De~i~ Log , .... "' - ~~on De~i~ Lo~G~{ Ray .. '"- :-..-. G~ ~yl~ .. ... ..:---'~' gaterolog ~. - ... ........ -- }Emlog . }~og - ~te~al ' ' - S~le Log (A.R.C0~--In~e~)' ' ~ - ' $~erge~c Log -- -~-Porosi~ Log Receipt Acknowledged For: Date. ' return receipt to' Atlantic Richfield Co.,.-~. any North Alaska Engineering P. O. Box 350 #326 , Atlant~cRichfieldCompany North Ame~n Producing Division North Alas{ istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 3, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: D.S. 4-1 (23-35-11-15) Permit No. Dear Mr. Hamilton- Enclosed pleaSe find our Sundry Notice'of SUbsequent Report detaili.ng the work done on the above-mentioned well. Very truly yoUrs, Frank M. Brown District Drilling Engineer /Vp Enclosure RECEIVED 1977 Form 10-403 REV. 1-10~73 Sul~ml t "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS ,(Do not use this form for proposals to ~lrlll or to ¢Jeepen Use "APPLICATION FOR PERMIT--" for sach proposals.) OiL !:1 GAS F'] WELLI.~.I WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 5. APl NUMERICAL CODE 50-029-20078 6. LEASE DESIGNATION AND SERIAL NO. ADL 28324 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 360, Anchorage, AK 99510 DS 4-1 (23-35-11-15) 4. LOCATION OF WELL At surface 1327'S & 295'W fr NE cr of Sec. 34,T11N,R15E,UM Bottom hol e: 1513'E & 1449'N fr. SW cr of Sec 35, T11N,R15E,UM 13. ELEVATIONS ('Show whether DF, RT, GR, etc.) Check Appropriate Box To Indicate Nature of Notice, Re 14. 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVES) Sec. 35, T11N, R15E, UM 12. PERMIT NO. 70-42 )ort, or Other Data NOTICE OF INTENTION TO-' TEST WATER SHUT-OFF L-~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEG~UENT REPORT OF-' WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTEs Report results of multiple completion on Well ¢omplet:lon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly ~tate all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Please see attached. RECEIVED 16. I herel~y certify that the foregoing is true and correct T,TLEDistrict Drilling Engipeer DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side DRILL SITE 4-1 SUBSEQUENT SUNDRY REPORT API 50-029-20078, PERMIT NO. 70-42 Accepted rig @ 0200 hrs 3/19/77. NU & tstd BOPE. Circ & CO ice from 43' to 60'. Circ warm diesel. PU 8½" bit & 6¼" Drl clrs. Bit stopped @ 1002'~, Ran Cal& CCL logs' Cal showed bad 9-5/8" csg from 980'-1010'. Ran 7½' swage. Cut 9-5/8" csg @ 1020'. Fish out 9-5/8" csg. RIH w/12¼" bit. Stopped @ 1001'. Swaged 13-3/8" csg from 1001'-1012'. Ran CBL from 2500'- 1020'. Top of cmt @ 2020'. RIH w/9-5/8" csg ctr. Cut pipe @ 1940' Trip for spear, no cut on pipe. Made cut @ 1943'. Trip for spear w/pko~f. Engage fish, unable to circ. Jarred· & worked fish up to 1730' POH LD fish. RIH w/8½" bit to 1942' Circ & warm hole. POH. Ran C~I log in 13-. 3/8" csg from 1943'-surf. RI~ w/12" swage. Swage from 1002'-1146'. Ran 10- 5/8" bit to 1942'. Circ & cond mud to 10.3 ppg. ND BOP & NU & tstd 20" Hydril. Ran 13-3/8" csg ctr to 1160'. Cut csg @ 1114'. Unable to pull fish. Made 2nd cut @899'. LD 21 its & piece of 13-3/8" csg fish. McEvoy 18~" OD TC hgr hung up in tight spot in 20" csg, approx 20' below ground. Latched fish w/spear & lowered to hgr ring in 20". @ t~90' leaving top of 13- 3/8" casing fish @ 833'. 20" is partially collapsed to 15" ID. Ran 18" OD swage from 37' to 54'. Heated mud. PU spear. Engaged fish @ 833' & rec all of 13-3/8" csg fish. RIH w/13-3/8" csg ctr. Cut 13-3/8" @ 990' Latched into fish & rec 13-3/8" csg. Top of 13-3/8" stub @ 990'. Rill w/spear. Engaged & jarred fish (csg cut @ 1114'). Fish would not come free. PU 16" OD wash pipe. Washed over 13-3/8" csg from 990'-1142' (cont to steam @ 80' in 20" x 30" anul). POH w/washpipe. Ran spear & engaged 13-3/8" fish @ 990'. Fish would not come free. -POH. Ran csg ctr. Cut 13-3/8" csg @ 1118'. Ran spear. Fished out 1.3-3/8" csg leaving stub @ 1118'. Ran 12¼" bit to 1943', top of 9'-5/8" stub. POH. Ran 4-arm caliper tool to top of 9- 5/8" stub @ 1943'. RIH w/16" wash pipe. Wash over 13-3/8" stub from 1118'- 1158'. 13-3/8" csg. Cut 13-3/8" csg @ 1140'. POH & LD fish. RIH w/dressing tool. Ran & tstd dummy patch to 700 psi OK. Ran 13-3/8" csg patch & FO asbly. Set patch then tstd to 1000 psi OK. ND BOP. Installed & tstd 13- 3/8" pkoff & spead head to 2000 psi. NU & tstd BOP. Opened & closed FO @ 1117'. Tstd RTTS, opened FO. Set RTTS @ 1100'. Circ 13-3/8" x 20" anul. Arctic packed anul. Closed FO. Super Pack 20" x 30." anul to 80'. Washed from 1859'-1968'. Dressed 9-5/8" csg stub @ 1943. Ran csg patch & FO asbly. Set patch then tstd w/3000 psi. Installed & tstd 9-5/8" csg pkoff to 5000 psi OK. Arctic packed 13-3/8" x 9-5/8" ~anul. Closed FO & tstd to 3000 psi. Displ oil. base mud w/11.0 ppg wtr base. CO cmt' to 9648'. Tstd old squeeze perfs w/2000 psi held OK. Ran GR/CBL/VDL from 9620'-5000'. Ran gyro from 9600'-surf. Displ wtr base mud w/10.4 ppg CaC19 wtr. Tstd csg to 2000 psi. Circ hole clean. RU & ran 5½" tbg completion ~/shear sub @ 9204', ND BOP. Installed tree. Pulled dummy valve. Dropped ball to set pkr. Unable to pump through control or balance line. ND tree. NU BOP. POH & LD 5½" tbg asbly. Drld to 9739'. Press tstd csg to 2000 psi OK. Ran gauge ring to 9200'. Reran 5½" 17# N-80 A-B Mod tbg completion asbly w/shear sub @ 9223', Baker pkr @ 9090', Otis RQY nipple @ 2190'. ND BOP. NU & tstd Xmas tree to 5000 psi. Displ CaC19 wtr to pkr inside tbg w/211 bbls diesel. Dropped ball & set pkr. Pulled dummy valve. Ran GR/CNL/CCL from 9726'- 8500'. Set dummy valve. Tstd balance & control lines to 5000 psi. Started 48 hr pkr leakage tst. Released rig @ 1200 hrs. 4/27/77. RECEiVLD ~,^Y I 2 1~77 Eastman/ ~ Whipstock A PETFIOLANE COM~ REPORT of SUB-SURFACE DIREC TIONA L SURVEY Atlantic Rich£ield COMPANY D. S. 4-1 WELL NAME Prudhoe - North Slope JOB NUMBER A477 G0326 LOCATI ON / SURVEY BY Shyam Talwar OFFICE Alaska DATE 4-29-77 · COMPLETION REPORT APRXL 27~ [977 ATLANTIC RICHFIELD COM~-ANY WELL NO. DS GYROSCOPIC METHOD OF --~-D-i-US-OF CURVATURE ~fE-T-~OD OF C-O'~-~OT~,-TTON~$ L/ --~-OM-PbTED FOR EASTMAN WHIPSTOCR INC. BY F. M. LI-~-D-~'EY' AND A.S$O--C-X-~'TES RECORD OF SURVEY --~EXs. DRIFT V~-RTICAL SI-lB b-RTF-t DEPTH ANGLE DE~TH S E A--bTR-ETC TD-'r~ L D M DEG, c L 0 $ U'R--E $ D !'~-I'-A--~-C-~ 'ANG-G-G~ E I~ M s D-O-G- --L-E-G DEG/iOOF'F D[STA~ICE 49.9'0 E /+9.90 E /+9 o~9-0 E 5-O~O-f E ' 50,12 E 2~o.0'0 $' 12 0 0 E 2-4-0-,-oU S 12 0--0 E-- 2~-OTO-O' S 12 O----O--E 2 40T5-7' s 12 0.000 222.99 o.ooo 0 ,-0-0-0 222 · 99 0,25b 223,21 O-e-O-8-O-- --500 0 25 ? 00 0 15 6 g 9.99-- 63'5-,-99---NTd;-O~O-E 2 ~ 6.-5~- $~ 800 0 10 799.99 ?'3~-9 N85.00E--236.~2 S 900 0 15 899,99 83'5~-9;9 S61. O-O"E--236. ~9 .... 1300 0 35 1299,~7 123-5~7 ..... $2~.00E-- 1400 0 30 1399,97 1335,97--5-'-5, OOE-- ~500 0 15 1499,9J 1435 ,~J' S~9,00W 1600 0 15 1599,97 1535,97 N72,00W 17QO 0 10 1699,97 16~5,97 4,9.91 E -- 5-0-'-2-? E ~0-T'6-'2 E 51.02 238,07 ~" ' 5~-~-:[3 239,01 S 5-2,53 -- 239,9/+ .% 52,7~ 2~0,~2 $ 52.50 E 2/+0.61 S 52.10 E 2/+0,83 $ 51,93 E 1800 0 10 1799.97 1735,97 S42,00W 1900 0 15 1899,~ 1835,97 N18,00E-- 2000 0 15 1999,96 1935,96 N29,OOE 51.92 E 2/+0.97 S 51.69 E 2~0.57 $ 51,87 E 2~+-0T99 --$--1~i--5-7 --Z8 -- E " 0~-26-0-- O'~-'fS-O 0./+35 0.080 O, 0-90 0.160 o 0.062 0.090 0,250 2/+6.18 $ 12 13 3 E 2/+6.37 S 12 246.63 S 12 9 l/+ E 0.2/+6 0.080 0,0~8 2/+6.46 S 12 6 31 E --2-2-3;-8-5---~' 2'2/+-,~ ' 22~+, 8~ " 226.05 228.v0 229.08 z-fg-.%-o 229-. 17 2100 0 30 2099.96 2035.96 $8/+,00E ..... 2'2'0'0- 0 ~+0 2199.96 21-3~5-.-96 S79.00E 2300 0 30 2299.95 2235.95 S80.OOE 2/+0,29 S 52./+2 E 21~5.94 S 12 18 23 E 0.250 21~0,4/+ S 53.43 E 2/+6.3-:L' S 12 31' /+2 E 0,1'70 240,63.S 54,43 E 2/+6,71 S 12 44 /+8 E 0.170 229,00 230,40 ' 2~+00 O. 30 2399,95 2335,95 SSO,OOE 2/+0,99 S 55,21 E 2/+7,2/+ S 12 5/+ 17 E 0,259 231,13 r RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER DOG LEG MEAS, DRIFT VERTICAL SUB C~R'TF-T DEPTH ANGLE DEPTH SEA D I RE~- D M DEG. T~'TAL COORDINATES CLOSURES SEVERITY SECTION DEG-/fO-O-F-T--D ! STANCE 25-0-0--0--~-5 .... 2-Kg-9-~-9-4----~$~--g-~S-6-2~EO-E 2-41--~60 $' 56.1i E 2~~--~~35 E-~ 2600 0 50 2599,93' ' 28~'0 3 -~0--2-79g~8-0--273 -320'O--['O~-5~-~-g6-JS-O--3I'32%~O~-4-6"OOE - 274~60--S~99-,-8-9--E ' 2-92TZ0--~-'~-9-59--25.'E~ 3400- 1~ ~-0- 3-3~-2%-2'l--3-$2~-j21~45~-OO~30-~l-6--S--l-30V22--E' ' 3-30~87--S--2-3--10 3'7~ 0¥250 0-;0'90 2-33~--I '1~3-4'0' 2 2 ;3~1 26 '1~0' 3'0-2%-73 2~6-71 3 2 2~-9~ ~8~-, 8 2 .'~7'~ ~'~6~-~ 3-9-0'0---2%---1-5'-----3-8-5-9"7' 2-8--3-79'5-;-2'8-- 5Z+-4',- 00'E---'4:2'9 %-3'6--5---25- 3-;-B- 8--E ' 4. O0 0--2-6--1-5----3-9~-8-~-97 ~388-~-J97---S Z¢-~-~- 0 0 E~z+-61-J1-7--$-----~-8-4.-~-60--E ..... 5-4.1%-9 41'00 26---0 ~+0 38' .,~--3-9-7'-Z+-;-7-5 54.~-*-0 4~2~.~-2-6-s---4-1-Z8--~-6~--4~6W-~6~--5-4-3-~5~E---5-2~5-6-~-3-t~-5-~-5-5-E~ 6-2-8'~-1-5--$--3-3--22--2'8--E " 430-0-~26 30 42-1-8-~-2-5---4-~-5-4-~-25-~+.4~E-55~6-~-5-6-~-3~6-~-~-~--E.--67~-~77-~--3~4--3-~-?-E- ~400 26 0 ~307,94 42/,3~9/+ 542'-*-00E 588,91 5 'Z+-0-6-i'35 E 715,4.9 5 3/+ ~ 50 0-'-2'6--5 4. 3 ~)'? ,-;-7-8----'4-3-3-3-~- ? 8--$7+-f,-50E----6-Z1-,-6'7--S--4-3-5--,', 5-8--E ..... 7-5-9-;-08--S--3'5--1--%--E~ /+600 26 0 ~.x+8-?',63 4. t+23-~-63 ..q4.-~i-,50E~6-5-4-'-5-5 S 4.674';-'68---E 802%72 S 3.5 22'--1-7--E 4700--26 0 ~577,5! /+5-1-3-'-51 5'4-1--'-50E 687,38 S z+93--*-72 E 8-46-;-32--5--35 4.1---1-8--E .... 4. 8 00 26 -0----4-6--6-7~. 3-9-----4~-O-3%-~9~'~-2%-O'~E~7'2-O~O-9--$~~2~9-1~E .... 8-89 /4.-9-00--2-6 O---4-7-5-?-J2-7----4-69-3-J2'7 $2+2-'-0'0-E "7"5-~-6-7 5 5-5-2-;-2-5--E 9'3-3;'-5-3--5-3'6--1'6 .... ~5-0-0-0-2'6---i-5 t+8~'?'-.-0-5~'78-3-;-05' ~42-,-OO[----78-5¥3-9.S------5'8-1-;-?-l--E~9"??-,-3-6--S--3-6--3'1--34--E .... --5i-00'--27 0 ~9-3-6.45 ~-8'Z2-~-4-5 542.00E 8-i-8-~-6-9--S--6-1-'f~-7-O---EI' '10-2-i-.-9-8 S 36 4.5 5200 29 55 50274-,35 -4-9-60-J3'5 5~+1.50E 8.5-4-J25--S 643,43 E--1069-.46 S 36 59--1-5-E-- 530-0--3-0--~-5 '5-1--~-0-.-87--5-0-4-6-.-87$41%0:0E--8-9'1-;-92+--$--677(;,-.-4.9 E--i';I.i-9-.4.0 ,5 3-7--1'0 49-8 -;-8-0 --5--3 '0--35--4.-4-- E ...... 2 -;-0-8 '0 Z+-9-8-JOT-m 0%-0-00' '5~ o. 2'5-0' 0-"6'3-1 7 i 5. 0 · 0 9'0 8-02 0-' 0-0'0 s ~' S 0.219 8-89.22 0-;0-0-0 932':5-9---~ 0:2 50 e 7 o. 7-5'o ~. 2,933 073%-4 1'1'1-7-.-4 0 RECORD OF SURVEY ALL CALCULATIONS PERFORM-~D BY I B M ELECTRONIC CO~-P-0-T-ER, 'TRUE DOG LEG C L 0 S ,U R E $ SEVERITY TOTAL COORDINATES HEASo DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA --DIREC DIS?~A-N-CE ANGLE D M D'E-G. SECTION --DEG/IOOFT D rs-T-AN C E 5400 30 10 5197.29 313:3,29 $41~-0~-E~~9-~92 $'' '7-0-9-~5--0 --5500 30 20 .5283,67 5219067 S~-O~-O-O-E 968023 S, 742,22 5600 30 15 5~70.01 5306,01 $39,50E 5700 30 0 5456'51 5392-'~'51 S38,00E 1046,15 5800 30. 10 5'543.03 5900 30 15 5629,45 5565,45 $37,5'~----i-~-2-5,44 $ 6000 30 0 5715.95 5651,95 S36,00E .1%65~69 S --6100 30 0 ~802,55 5538,55 774,48 E 805.89 E 836075 E ~-6-T, 56 E-- 897,59 E 926,98 E 6200 29 45 5889,26 5825,26 S36,50E 1246,27 S__956.4~ g 1169~-6~-~--FT--Z-O--~-~--E ' 0--0-8-0 --1219,98 $ 37 28 22 E 0,307 --127'0-,-~9 $ 37 33 48 E 0,156 --1320,57 $ 37 36 30 E 0,451 1370,70 $ 37 37 22 E 1421,01 $ 37--~7 38 E --1471,1'9 S 37'3.5 50 E --1521,18 S 37 32 41E 0,170 0,150 0,4.51 0,000 --1570,97 $ 37 30 13 E 0,279 i-1-6-7'. 31 1 l f6-7-. ~ 0 131-7o49 1367.48 i41~7',67 146-7-, 79 1-517,75 1567,51 --63'00--2-9 45 5976,08 59-i-2-0-08 S'36,00E 1286.29 S 985,77 E 6400 30 15 . 6062068 5998,68 $3-6-e-0-~E 1326.74 S lOlSml6 E --6500 31 30 6148,51 6084.51 S36.00E 1368e26 S 1045,32 E --6600 32 30 6233,31 6169,31 $35,50E 1411,26. S 1076.28 E 6700 32 55 6317,45 6253,45 535'-,bOE 1455,-4'0 S ~67%%-7~ 6800 32 30 640~5-~6~-37~,59 S'35i0~'~-4-9V;~-~S--i-~3~ E 6~.00 31 ~0 6~86~3~ 6~22,3% 53-~*~-0E--%5%-3~'~~-~6-8~~ E-- 7000-31 O, 6~71~73 6507,'~'3 S3~,00E--~5-8~%~6 S ~197,6~ E ~00 30 0 6657,89 6593,89 S3-3%-5-OE--~-6-2~-6 ~ ~2~-~8~ E 7200--2~ 15 67~4,8~ 6680,8~ S3-3%bO'E: ~670,~0 S ~252,9~ E 73-00 28 30 6832.38 6768,38 ~3~3'*00E 1710,60 S ~279,2~ E 7400 28 0 6920,.47 6856,47 S33,00E 1750,29 S lSb-5~~--~F3,26 s 36 ~2 29 'E~ 7500 28 0 7008,77 6944,77 S32,50E 1789,78 S 1330,42 E 2230e09 $ 36 37 30 E --1620,58 S 37 27 55--E 0,248 --f6-7-0,57 $ 37 2.5 17 E 00500 --1721.~-7---S---~-7' 22 4.5 E 1,250 1774.84 S 37 19 50 5 1.010 18-28,85 $ 37 16 8 E 0,45.5 --1-882 · 85 $ ~-7--:1.-2-"1%--E o V'4-~ o 1-9-3-5-,-91 S 3-7'. 7 ~7 5--0.879 1-9-8-7 · 84. S 37 2 5-2--E 0-.-6-70 --20 ~-8-%~-~--S--3-6---g7--.5-7-'E 1 · 008 --2-0-8-7084 $ 36 52 ~-O--E 0-;75-9 2'136.02 S 36 47 25 E 0,750 0.23.5 1617.08 1-6~-7-. 04 1771,27 fg2-5,30-- 1879.33 1932.44 ~-9-8-4-e44 --21'32'91 Z£8-0.24 2227.18 7600 28 15 7096,96 7032,96 S3-3~-OUE i-8-~-9~042 $ 1355.92 7700 28 30 7184094 7120094 $3~'-0-0E 1869028 S 1381,80 --7800 28 40 7272,75 '7-2-0-~-~-7"5---S3~"-00E'"i-9-09041 S 1407,86 --7900 28 30 7360,56 7296.56 533.00E 1949,53 S 1433,92 E 2277,13 S 36 32 4-1--E 2324,56 $ 36 2%--2-(~ E~ ~372.32'S 36 24 8 E 2420.08 S 36 20 6 E 0,250 0.1-7-0 0,170 2321,84 2369~,68 24 8000 28 35 7448,41 7384041 S34,00E 1989,38 S 1460,29 E --2467,81S 36 16 49 E 0.246 2465,31 8100 28 15 7536.36 74-72,36 Sg*3-~-ObE 2029,07 .S 1486.56 E 2515.35 S 36 13 39 E .0.407 8200 27 50 7624,61 7560,61 S3-2'-~-0'0E 2068,72 S 1511082 E 2562,27 S 36 9 2~12.90 2559,90 ,! RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY ! B M ELECTRON!C COMPUTER MEAS. DRIFT VERTI'CAL SUB --DEPTH--ANGLE ,DEPTH SEA DR ! FT DI R~E-¢ TOTAL: cOOR-I~'INATE$ c L 0 $ U R--E-$ DTSTA~CE ANGLE ' DEGT:L-0-OF'T SEC¥ !'ON ' 'D I"$TANCE-i 8-300 27 30---77X-~-8--~-64-g-;1;'8----S3].-~O-OE----Z%O-8~-3I--S---'Z53-6,--09 E "2-6-0-8~5:~--3'6---4--35--E 84'0 0 .... 27 -0---T8-0-2%-0-8--7 7 3 8',0 8 S30'-'-OOE---21-~7~-7-6--S--I559~3-2--E-----265-4%-l-3--$ 35-58--4 - 85-0-0--2~--E0---~-89"1-;-3'"1----7827.31--$2-9-~00'E---2-1-8Tg'0-5--S--l~5-81-g'5~ E Z&-9-8';'99--S--3'5--5-2--20-E 0%-3-8-7 -8'600 2~--30---~9'80-,-T4--7'93.6-'-7'~---$28-e-OO~2-2-6-e-38--5~'l-602-~-gZ--E 2T4-3 ~-~3-7--5-- 35- 45---8-- E 8'700 25--3~-8`~7~;-62-8~6~62-_S27~-5~E~22~5-i-~J~8-$---%623-~32-E~T8H~79-$ 35 37 3-6--15 1%-0'04 --8"800--2'5'30--8"].-60-.-87---8096-.-87----S2Te-OOE----Z3'O3-~-4;5--S~l.-6-~-3-~-O'3--E ' 2-8-Z9%-39--$--35-'29--59-15 ....... 8900-26 ....... O- 82'50-;-94----818 6 ,-94 .... S2'-6"~-00E--23-4;2'~33--$ .... 9'000-2 7--0 8-3-4-O-.-4-4--8-276-'-4-4--525-*-OOE'--23-8-Z~-60--S----'I-681-~-6Z--E ;'9-1-6~-27--5--3 5--3.-2 51--g l~O-2-Z 9 T O0 --2-?--2-0--8 -4-2-9-,--4-0--83-65%%'0-- S2-4-~-0-0 E-~2-4-2-4%~-5--5-'-1--700~ 5-6-- E-'--2-9-6'].TZ-5--5--35-- -2-- 59- g " 0%-4-0-0 92'00-'2 7 .... 50 ..... 8'5~-8-*-0-~3--8-45~-;-03--52 3-~-0UE----24-6-6-,-62--S--~-71-9%-0-3--E 3-0-0'6-~5-4--S-3-~--52 2'3--E 9 300-2 8--30---8-60-6-~Z-8--B-542:~-l-87---522-~-O 0 E---25I-0~24--S IT3T~og--E-----3-O52T67--S--3'4--4 l' -0--E~0-~-69~8- 9-40 O--2-8--[-5--8-Eg-~-~7--~63'OTl- 7--S20-~OrOE---2-55-6--~ 60--S---~-75-4-~Z'- E ' 3-O-9-8-&8-6--5--3-4--ZS--31-- E 0~5~-3 95 00-28 0--8'T8'2-;-3-6---87'1-8-'-3-6 S l'9'",-O-OE--25"99',-O-4--S---iT'69-;-8-6--E----3~-4-4-;"4-3--S--3-4--]..5--1-2 E'-----0'~-~:33 _.~9600 2'8 0 8B-7-0-;-6-6--880-6~,-66- 5"!-8~-OOE-'-26~4-3-;~-56--S--:I.-78'4-~-75--E 3-1-8'9-~-6-3--S 3-4--'-1--__28-E 0-~-/+-69- --T D-"D A T A--E×T R-A- P-OI~ATED 2'60-6-~-3T---~, 26'5'2-~ L~ Z69 7~ ,--qj 2 7-4-1-.- 6I' 2'7 8'5--2"1 28-2'T.-99 287 r.-og~F? 2'9T5';-25 ~:. Z9-6-0-,-3-3---4 :! , 3005-'-9'[ 3-09-8-~-5-8---~,; BOTT'DN HOLE CLOSURE 325-2~-2-5--FEE-T--AT $ 33 41 '5[ E ~ A-S U RED-DE P_T H -AN D_(1TJ-J ER_ D AT AL_ F_OR__ EVER.Y_EVEN-IoO~~_OF' SUB_&EA_DEP_T_Ifl_. : TRUE MEASURED -DEP-T-H- VERTICAL ,SUB MD-TVD VERTICAL DEP-TFf--SE A--D-I-F FER-EN-CE:------CO R RE~T iON " 'F ! 6-4 Lr6-4. I-O-O 0 0 2-~-4 ,--76--$ 4-9~-90-E' 264. 200 364 664 764 864 1-1-64 i-264 'I-36 ~ 1-4.%% 1564 166z~- 186'4 i9 6'4 ~2-06~4 216~ 226%- 2~6~ 256~ --2'96~ 306-5 3371 364.--300 46'~ · 4-00 5-6-4:. 50'0' 6 64, 6 O0 76-4. --700-- 9-6-4 · 90 0 1-064%-----I'00 0-- 1'1-6-4%--'1-100-- i-2-6"4~%--- 12 00' 1-3-6-4-; i3 O' 0 I564-, ...... 1500 1-6'64-'J~16-00 1"7'6-4%--17 00-- 1-8%-~ · 18 O0 2-0-6-4-J----200 O' ' 21-6z~-;---21 O0 2-2-6-4-'---2-2 00 2-3-6-4-.~2300-- 2-4-6-4 ,-- 2-40'0 2564. ,, 2-.500 2%%-4" 2%-00 2'7%~. 27 00 2864. 2~8-0'0-- 29-6-4.% ..... 2900-- 3-1%-4, 3 i-00-- 3 2 6 4 .--3 2'00--4. -- 33'64.% 3'300 3~5'6-4%--35 0'0 ~- 5 0 0 0 0 0 0 0-- 0 0 0 0 0 0 0-- 0 0 0 O' -0 0 0 -0 0 0 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, M E-A-S-O'RE-D V E-R-TYCA-L---$'OB -~'DUTg-D VERTTCAL DEP 'T H DE-PTR'~'SE A--O-'~-F F ER-ENCE CORR-E-C T-'I I'-OT-A L ...... C O-O~-rN-A-TE-5 3686 '? 3795 8 39O5- 1-~ 4-,:[-2-8 4239 ~-351 12 11 44.62 457g 4685 4907 5019 5-131 5246 5593 5709 5824 59~0 _ ~. 6055 6171 6286 6401 6518 6636 6755 68-74 6991 7"1-0-7 7222 7336 '/449 7563 3 6 6 4, 3-~ 0-0 2 2 3764, 3700--30 38'6-4-~ ..... 3800 39'6-4-, ....390 0 .... 5-3 4-0~6'~-,--4000 .... 6-4 /+ 1-6'4., /+ 1 O0 -75 42'6~ e-- 420~ 87 ~ 64 ,--4 300~9-8 4464e ~-~00 110 486~ e--~800-- 15~ 496 ~. 49 506g. 5000 ......... 5'36~-'--53 O0 ........... 2 29 5~6~, 5~ o0 5-5-~4%~5~ 500~26~ 566~, 5600 .... 2?'6 586~e · 5800 307 596~.~5900 322 606~, 6000 337 616/+. 6100 354 __ 6264. 6200 372 6364, 6300 391 6464, 6400 410 6564, 6500 427 6664, 6600 443 6764. 6700 458 6864, 6800 ~472 6964, 6900 485 7064, 7000 498 12 '~ 1 1-1 11 i3 1-6 T~ ].% 1'5 1-6 1-6 15 15 17 18 19 19 15 14 13 13 36-'r~0~ 5 193 3-9-7-;~-7' S 2-2~';-Tg--E 4-3-0-;-9-5- 5 4-6-6-,-5-0--~ ...... 289%-7"4--E 50-~ ,--7'0--$ ..... 3-2'3-JT-O--E '53-7-;-1-0--~ " 3-57'i~-3-2--E 5-73~0-0~5 '" 39-1-~-77--E 6-0-9-;-2~--S 4-2~-~ 4/+ E' 646e09 S 4~5-6,82 E' 6-8-2~%-6- 5--489 · 11 E 75-4-;-95--5 ' 5'.5-~, 30 E' ?-91,62 ~~587,32 E '87-1T5-2--~--65 8 9'59',-3-5--$ .... 73"4 ,~ ~--E 1-004%-4-Z--5 .... 772-,-0'8--E Z-04-9-;-5-6--~ ' 8-08-'-55'--E-- i-1-4-1%-5-4--5 .'" 87 9-~-6-0--E 1-1-87-,-9'0--& 1-2-37+ ,--TO--$--9 fZ8-0%-8-0--5--981 · 5 ~ E 1015.4.6 E 1050,65--E 11-24,56 E-- 1532,00 S 1582,70 S 163i.69 S 1679e07 S-- 1724,94 S 1-7-69,64 5 1814,68 S 1160,80 E 1195,04 E 12'27,74 E 1258,77 E 128-8-,-5-5 E 1317.46 E 1346,17 E _MEA,,%URED_DEI:LT_~I~tD__Q_TJ-JEi. IR_OAI_A_IF~__R__E_V_E_RY E_V_EE!i__~OO_FEET OF SUB SEA DEPTH_~ T flUE MEASURED DEPTH V E R T I ~-A~-, S U B M D-~-T-gD V E-R-T~ A L: D-E-P-T 'H-~SEA--, D-~-FF E' R'ENCE ......... C-O-~~ R-EC- TTON " T-O-T A L- ..... CO-ORD-I-N A-TE-& ! 7790 7264. 7200 '5-26 lt+' 9139 ~ _ 9252 9'3-& 6 959-2 9'7O-6 7364, 7-~0 539 7'5-6-4-. ~66-4~--~T600 .... 580 77-6'~ ........ 7700 .... 593 7'~6-~%~~'8-0-0~'05 · 0-~-~,~8 O0 0--~62 9 B~5-6-4%- 85 '00--%- '8~-6-4~ ...... 8800 '13 '13 i-2 I2 I2 11 · ~NTERPOLAY-E-~CU~$ FOR EVE~' FEET OF MEASURED DEPTH. , TRUE MEASURED V E R T'i-~-~ L SUB DEPTH DEPTH SEA TO'TA--~----CO~RD[NA~E-$ 1000 999, 935. 236.81 S 51.02 2000 1999, 1935. 2~0.57 S 51.87 3000 2999. 2~'~. 2~~--S 77.22 6000 39/+8. 388~+. 5000 /+8z+7. /+783. 6000 57i-5, 56-51.'. 7~000 8000 461.17 S 284.60 785.39 $ 581.71 1~1-65-'7 8 $ i-586 · 56 -i98 9-'-38-- S i~60-,-29 9000 83/+0. 8276. 2382.60 S 1681.62 E ...................................................... VERTIC A'E-SECTION ...... i ~CALE I"= I000': .'_- . '~_'i~ :.__- ......... ? -- ATLANTIC RICHFIELD-COMPANY ......... . ; 'DRILL SITE . _. '--. :~i'_' _ '~Z"'~i'_-i--~_-_~_i.~I~'-_. _--.~ '_. '..RADIUS OF CURVATURE .... { ..................... ~ ..... ! ...... GYROSCOPIC SURVEY 4801: . . ...................................................... _HORIZONTAL _.VIEW._ - - ATLANTIC RICHFIELD COMPANY .... )' ....... DRI't~L SITE 4-! ........ ........ , ...... *---_-. ....... ~ .~*-~ RA[~I-O~' -o~-CU~/~TURE .... I ............. { ....... .................. ,. - - GYROSCOPIC SURVEY ! ........... ~ ....................... ~ ....... ~'- _ _ _ . .............. ~ ................. ,. ......... ; ............. ~ ..... ~ .............. ~ .......... : .......... ~ ...... { ........ , ............... ~ .......................................... .......................................... ! ................. 2800 ..... 3200 360~ . . · ..~eoo_ .............. ~__',__i 5200 5600; 6800 ................... ~ ...... ': ....... ?200 .......... AtlanticRichfieldCompany North Ame~'''-,ri Producing Division North Alaslk strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 14, 1977 Mr. Hoyl e Hamil ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 4-1 (23-35-11-15) Permit No. 70-42 Dear Sir: Enclosed please find a Monthly Report of Drilling and Workover Operations for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /jw Enclosure ~m N'o. P--4 1~. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMI~EE SUBMIT IN 13UPLICA'I'~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHmE 2. NAME OF OP~A. TOR Atlantic Richfiel d..Company P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WEJ~L At Surface: 1327'S & 295'W of NE cr Sec 34, TllN, R15E, U At TD' 1513'E & 1449'N of SW cr Sec 35, TllN, R15E, UM -5. APl NU~ERICAL CODE 50-029-20078 6 LEASE DESIGNATION AND SERIAL NO. ADL 28324 T. IF INDIA)~,, ALOT£EE OR TRIBE 8. L.~IT,F.Z~2Vl OR LEASE NAME Prudhoe Bay 9. WELL DS 4-1 (23-35-11-15) ! "iO. FL~.~.,~ AND POOL. OR WILDCAT Prudhoe Bay - Sadlerochit Pool 11. SEC., T., R., M., (BO'I~I'OM HOI.,E ommc-rn~ Sec 35, TllN, R15E, UM -- 12. PERMIT NO. 70-42 "13. REPORT TOTAL DEPTH AT END OF MONTH, CI-I.A~NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLU'MI~ USED, PERFOHATIONS, TESTS AND HESULTS. FISHING JOBS. JU'NK IN HOLE A.ND SIDE-TRACKED HOLE A~TD ANY OTIKER SIGNIFICANT CHANGES IN HOI.~ CONDITIONS. Commenced rig operations @ 0200 hrs 3/19/77. NU & tst BOPE. RIH open end DP. Circ & CO ice from 43' to 60'. Cant in hole to 2600'. Circ warm diesel. Trip. Picked up 8½" bit & 6-¼" Drl clrs. Bit stopped @ 1002' POH. Ran Cal& CCL logs. Cal showed bad 9-5/8" cs_.g~.,[c~~lOlO'. Ran 7½"' swage. Cut 9-5/8" csg @ 1020'. -'~i~t 9L5-/8'"-"C-sg. RIH~w/~T~.~topped~@ lOOl '. SWaged 13-3/8" csg from lOOl' - 1012'. Ran CBL from 2500' - 1020' Top of cmt @ 2020' RIH w/9-5/8 csg ctr. Cut pipe @ 1940' Trip for spear, no cut on pipe. Made cut @ 1943'. Trip for spear w/pkOff. Engage ~ish, unable to circ. Jarred & worked fish up to 1730' POH LD fish. RIH w/8-1/2" bit to 1942'. Circ & warm hole. POH. Ran Cal log in 13_-3_/~2' csg from 1943' - surf. RIH w/12" swage. S~wa_~qe from 1002"- 1146'r Ran 10-5/8" bit to 1942'. Circ & cond mud to 10.3 ppg. ND BOP & NU & tst 20" Hydril. Ran 13-3/8" csg ctr to 1160' Cut cs_~ @ 1114'. Unable to pull fish· ~de~n~.,£.!~ ~ ~9'. LD 21 jts & piece of '~13-3/8" csg ~'Sh. ~ McEvoy 18¼" OD TC hg~' D~"~[~'~i'n 20~_QZL"~, _a_p~ 20' below ground, Latched fish w/spear & lowered to hgr ring in 20" ~ 8'9--O~-~ving~b=~'-6T-13~z%~8",casing fish @ 833'. 20" is. Rartiall~ collapsed to 15" ~ID.:. Ran 18I' OD swage from 37 to 54'. Heated mud. PU ~] .......... ~'n~6~a-'fi~E @ ~:~3~& rec all of 13-'3/8" csg fish. RIH w/13-3/8" csg ctr. Cut 13-3/8" @ 990'. Latched into fish & rec 13-3/8" csg. Top of 13-3/8" stub @ 990'. RIH w/spear. Engaged & jarred fish (csg cut @ 1114'). Fish Would not come free. PU 16" OD wash pipe. Washed over 13-3/8" csg from 990' -1142' (cant to steam @ 80' in 20" x 30" anul). POH w/washpipe. Run.spear & engage 133/8" fish @ 990'. Fish would not come free. POH. Ran csg ctr. Cut 13-3/8~C_~,.~@~.,1~8~,~ Ran spear. Fished out 13-3/8" csg leaving stub-@ lll8'i ......... TffYO~"~6~(i'~ ............ ~R~n 12¼" b~ to 1943', top of 9-5/8" stub. POH. Ran Schlumberger 4-arm caliper tool to top of 9-5/8" stub @ 1943'. RIH w/16" wash pipe. Wash over 13-3/8" stub from 1118' - 1158'. As of March 31, 1977, prep to cut c g. RECEIVED APR 1 5 1977 S~G~ =~ Di stri C~ Dri 11 i Dq Enqi nee~ ) NOTE ~Report on this form i, required for .each calendGr ~th~ regardless of [he *totus of operations, Grid must ~ filed in duplicate with the oil and gas coneervat;on oommiflee bythe 15~ of the suec~ding mon~, ~le~ Otherwise directed. AtlanticRichfieldCompany · North A~,--ica. Producing Division NorthA[. ~ District Post Office Box 360 Anchorage, Alaskn 99510 Telephone 907 277 5637 March 25, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject:~ril~Site-4-_~~-~ (23-35-11-15) Permit No. 70-42 Drill Site 4-2 (13-26-11-15) Permit No. 70-63 Drill Site 4-3 (23-34-11-15) Permit No. 71- 5 Drill Site 4-4 (14-36-11-15) Permit No. 71-11 Drill Site 4-5 (23-27-11-15) Permit No. 71-25 Drill Site 4-6 (22-03-10-15) Permit No. 76-83 Drill Site 4-7 (31-34-11-15) Permit No. 75-77 Drill Site 4-8 (33-26-11-15) Permit No. 76-10 Drill Site 4-9 (33-35-11-15) Permit No. 76-30 Drill Site 4-10 (33-27-11-15) Permit No. 76-42 Dear Sir: Enclosed please find a Sundry Notice outlining our plans for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure Form 10-403 REV. 1-10-73 Submit "1 ntentlons' in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELL L--J OTHER NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL At su trace 1327' S & 295' W of NE cr Sec. 34, T 11 N, R 15 E, UM 13. ELEVATIONS (Show whether DF, RT, GRt etc.) 64' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re ;5. APl NUMERICAL CODE 50 - 029 - 20078 i6. LEASE DESIGNATION AND SERIAL NO. ADL 28324 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudh0e Bay 9. WELL NO. Drill Site 4-1 (23-35-11-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay- Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 1513' E & 1449' N of SW cr Sec. 35, T 11 N, R 15 E, UM 12. PERMIT NO. 70- 42 )orr, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING L._=J MULTIPLE COMPLETE ABANDON* CHANGE PLANS Perforate .... WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) REPAI RING WELL ALTERING CASING ABANDONMENT* (NOTE= Report results of multiple completion on Well Coml31et!on Or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state' all 13ertlnent details, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working, pressure, will be utilized with all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. Well will be flowed to a surge tank to recover load fluids and any produced well fluids. All. recovered liquids will be retained in the surge tank, then trucked to the oily waste disposal facilities for disposal. Any' produced gas will be vented to the atmosphere during perforating operations.' The down hole safety valve will be installed and tested upo'n conclusion of Estimated start date- May 1, 1977 MAR 2 9 197'7 16. ' I ~'emeby certify that the foregoing Is true and correct {~h~si:space for State office use) Division of Oil and Gas Conservation T,TLEDistrict Drillin§ En.qine~r_ DATE. ,, , ..... Aa~.,OVED BY ~-~- '~-~~ T,TLEPetroIeum Engineer '"'~I~D:I'TIONS OF APPROVAL. IF ANYJ See Instructions On Reverse Side DATE ~3'30-77 ~Pproved Copy Returned AtlantilbRichfieldCompany North Amerilr ' Producing Division South Alask~ ~trict Anchorage, Alaska 99510 Telephone 907 277 5637 · February 10, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 4-1 (23-35-11-15) Dear Sir: Enclosed please find a Sundry Notice outlining our plans for the above-mentioned wel 1. Very truly yours, District Drilling Engineer /jw Enclosure RECEIVED FEB 1 6 1977 Form 10-403 Subml t "I ntentlonS" In Triplicate · REV. 1410-73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-029-20078 6. LEASE DESIGNATION AND SERIAL NO. ADL 28324 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay 3, ADDRBS OF OPERATOR 9. WELL NO. P. O. Box 4144, Anchorage, AK 99510 DS 4-1(23-35-11-15-) 4o LOCATION OF WELL At surface 1327'S & 295'W fr NE cr of Sec 34, TllN, R15E, UM Bottom hol e' 1513'E & 1449'N fr. SW.cr of Sec 35, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Sadlerochit Pool 1L' SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 35, TllN, R15E, UM 12. PERMIT NO. 70-42 ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other} - See B'el ow SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of .~tarting any proposed work. Proposed operations for this well consists of repairing the 13-3/8" & 9-5/8" casing, displacing all freezable fluids from the cased annuli with Arctic Pack & running a single 5-1/2" tubing completion. This is to be completed in the Sadlerochit, however will be suspended in an unperforated condition at this time. During the workover & completion operation a 20' Hydril 2000 psi W.P. will be installed if the 13-3/8" casing requires repair, the remainder of the time the BOP stack will consist of 2 13-5/8" pipe rams, 1 13- 5/8" blind rams, and 1 annular preventer all rated at 5000 psi W.P. to be functionally tested daily and pressure tested weekly. RECEIVED 1 1 77 D!visi0n ef 0il and Gas f~ns~rv~ti0n .. A~.her~_~ 16. I hereby certify that the foregoing is true and correct ('l'hts space for Stat~/~f~.e use) CONDITIONS Ofj4PPROVAL, IF ANY: See Instructions On Reverse Side APProved '~ ~efl~me ~ .. /~tlantic~ichfield~ompany North se~ '~ Am ' Producing Division North Ala ,strict Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277 5637 December 16, 1971 State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Homer Burrell RE: Drill Site No. 4, Well No. 1 (3~-35-11-15) Dear Sir: Attached is State of Alaska form P-3 Subsequent Notice of pulling the tubing from the above mentioned well. Very truly yours, ~. ,~, B. T. Loudermilk Dist. Drlg. Supervisor Enclosure C ON FI DENT A[. DEC 2, 0 1971 DIVISION OF OIL~,-,."ND' GAS Form .P~ REV. 9-30--6 9 Stabrntt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITIEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use "APPLICATION 'FOR [~'FA-li~IT~." 'for such 'p~oi~osal$.) · i, WELL WELL OTHER 2. NA.'~IE OF OPERATOR Atlantic Richfield Company 3, ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 1327'S & 295'W fr NE er Sec 34, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, OR, etc. 64' KB Check Appropriate I~x To Indicate Nml'ure of NOtice, Re 5. AP1 NIIMER~CAL CODE 50-029-20078 6. Ld?~%SE DESIGNATION AND SEI~IAL NO. ADL 28324 7. IF INDIAN, ALLO'A'r~-'~- OR TRiBE NA/VLE 8. UNIT, FAB.M OR LEASE NA/VIE Prudhoe Bay 9. WELL NO. Drill Site #4-1 (23-35-11-15) 10. ~'~2L,I) AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 35, TllN, R15E, UM 12. PERlVHT NO. 70-42 ~rt, or Other D~ta ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT 0R ACIDIZE REPAIR WELL . PULL OB ALTER CASINO MULTIPLE COM PI,RTE ABANDONs CHANOE PLAN8 ~Other) SUBSEQUENT REPORT OF: WAileR SHUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING 8HOOTING OR ACIDIZINO ABANDONMEKT* (Other) ng tubing (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) !5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertlneut details, and give pertinent dates, including estimated date of starting an}' proposed work. Moved rig over hole and began operations on 12-7-71. Nipple down tree and nipple up BOPE. Pulled and laid down 2-3/8" tubing. W/2-3/8" tubing at 2651' circ 240 bbls diesel down through tubing. At 130' pumped in 30 bbls diesel. Clean diesel to surface. Finished pulling tubing. Set out BOP. Made up xmas tree. Released Rig 1:30 AM 12-8-71. C0NF DEN A 16. I hereby certify tha~ the foKegoinl is true, and correct SIGNED .~ _ . ~ TITLE Dist. Drlg. Supervisor DATE 12-16-71 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See I:nstrudions On Reverse Side AtlanticRichfieldCompany North Am~~£ Producing Division North Ala.,~. uistrict Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277 5637 December 7, 1971 State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 ATTENTION: Mr. Homer Burrell RE: Drill Site No. 4, Well~ No. 1 (34'35'11-15) Dear Sir: Attached is a P-3 Intention to pull the tubing from the above mentioned well. Very truly yours, ./"~ ,.,~ , ..... .--), /L. N. Bell Sr. Dist. Drlg. Supervisor~ ~/WTJ/mm Enclosure: c. G~o~ c. ~j----- / 1 ENG_~ ' cN.'G j,, . I ~ / DRAFTI F)-I_-~Z-'-~-'-'-- DEC 71971 Di¥1SION OF OIL AND GAS Form P--3 RE~, 9-30-6 9 Smbmtt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE (}F ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FOR ~'E~MIT-L.'' 'for such 'p~o~mosal~.) . . 1. WELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage} Alaska ~510 4.LOCATION OF WELL At surface 1327' S & 295' W fr NE er Sec 34, TllN, R15E, UM 13. ELEVA'FIONS (Show whether DF, RT, GR, etc. 14. ~. AP1 NUMEP,/CAL CODE 50-02g-20078 6. LEASE DESIGNATION A_ND SERIAL NO. ADL 28324 ?. IF INDIAN, A.I.J~O~ OR TiTIBE NA1VI.E 8. UNIT, FAd~V~ OR LEASE NAN~E Prud~oe Bay ~. WELL NO. Dr~ s~te #4-] (_23-35-11-15) 10. F!I~.LI"~ ~Nrl2} POOL, OR WILDCAT ' Prudhoe Ra~ - 2~.~tleroehJf. 11. SEC., T., R., M.,~(BOTTOiVf HOLE OBJECTIVE) Sec 35~ TllN~ R15E~ UM 12. PERd~IT ~O. 70-42 Check Af)propriate Box To I, nd~cate Niature of N~)tice, Re: ~or~, or Other D~ta ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ] I PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE I J ABANDONS REPAIR WELL CHANO~ PLA~S ~ Other) Pull tubing EUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING Oil ACIDIZINO ~ ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Cornpletion or Recompletion Report and Log form.) I5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. Move rig over hole and begin operations on 12-7-71. Nipple down tree and nipple up BOPE. Pull and lay down 2-3/8" tubing (hung off at 9525')' to 2500' diesel oil. Finish pulling and laying down tubing. Nipple down BOPE and nipple up tree. and reverse in 175 bbls of OEC 71971 DIVISION OF OiL AND OAS TITLE Sr. Dist. Drlg Superv~ mo~ DATE / Z ~ ~ - 7 / Approved Copy Returned ~ Instru~ions On Reverse Side CONDITIONS O~I~PROVAL, IF Ai~f: TITLE AtlanticRichfieldCompany NORTH ALASKA DISTRICT ARCTIC SLOPE SAMPLE TRANSMITTAL SHIPPED TO' WELL N,aCqE' Div. of Oil & Gam ~ Po~-"eD.pine: Drive~ ~or~, ~~ 995~ _~RO0 DATE' J~v ~-.~9"~ SEC ':~JD SAMPLE INTERVAL TWP II RGE 1~ ]3; ~ FROM NUMBER OF ~(BOXES) TYPE OF SAMPLES' ( ) WET CARRIERS' TO ~ DRY ( ) CORES ( ) OTHER PLEASE SIGN THIS AND PASS IT ON WITH THE SAMPLES AIR CARRIER ARCO EXPEDITER CARRIER (FAIRBANKS TO ANCHORAGE) ARCO ANCHORAGE REPRESENTATIVE REPRESENTATIVE' WHEN YOU HAVE RECEIVED THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL THIS FORM TO: DISTRICT GEOLOGIST ATLANTICRICHFIELD COMPANY P. O. BOX 360 ~CHORAGE, ALASKA 99501 SHIPMENT INITIATED BY: ~L.~ (ARCO REPRESENTATIVE) TITLE' ~ ~ T~ MEMO April 13, 1971 TO: F I LES FROM: John A. Levorsen/1~~ Petroleum Geologi sf Drill Site No. 4-1 Drill Site No. 4-2 Per telephone conversation 4/13/71 with Bill Jones, ARCO well samples and core chips from Drill Site Iil4-2, in which cores were taken, will be supplied in lieu of those required from Drill Site #4-1, which had no cores taken. ~lantiqRichfieldCompany / / North Am_e,~ '~ Producing Division South Ail ,strict Post OffiCe ~ux 360 Anchorage, Alaska 99501 Telephone 907 277 5637 February 3, 1971 State o£ Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, AK 99'504 ATTENTION: Mr. Homer Burrell Gentlemen: RE: Drill Site #4-1 (23-35-11-15) Permit #70-42 Enclosed please find a Well Completion Report form P-7, for the above subject well. Included with the report is the well history and directional survey. The required electric logs will be sent to you as soon as they are completed by our supplier. Very truly yours, DRAFT SEC CONFER: FILE: C. R. Knowles Senior Drilling Engineer CRK/ms ~.nclosures: SUBMIT IN . ~ E* STATE OF ALASKA , ',.~rherin- st ructions on OIL AND GAS CONSERVATION COMMITTEE reverse side) I WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* W ELI. w ELL DR ¥ Other b. TYPE OF COMPLETION: NEW ~-~ WORK ~1 DEEP- ~ PLrG ~ DIFF. ~ WELL OVER EN BACK gESVR. Other Sus_endedo 2. NA~,XE OF OPERATOR Atqan%ic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360 Anchorage, Alaska 99501 LOC^TION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 1327'S & 295' W fr NE cr of Sec 34, TllN, R15E, UM At top prod. interval reported below 1448'E & 1672N fr SW er of Sec 35, TllN, R15E, UM At total depth · 1513'E & 1449'N fr SW 'er of Sec 35, TllN, R15E, UM 13. DATE SPUDDF_J3 ' !14. DATE T.D. REA, CHED {15. DATE 'COMP S,USP 0/% ABAND. ' [16.' ELEVATIONS (DF, RKB, 11-2,7-7o] 12-27-70[ 1-10-71 ] lib 64.0' la, TOTAL DEPTH, [ViD a TVD[19. PLUG. BA, CK MD a TVD[20, IF MULTI]PLE COiVLPL.. ! 2I. ! I-IOW MANY* I ROTARY TOOLS 9790,,.~ 9039 TVD ! 9050 m~ 8384 ~VD | 0-9790 22. PRODUCING INTERVAL(S). OF TH. IS CO.iViPLETION--TO~, BOTTOM. NAME (MD ANDTVD)- None 5. API N~CAL CODE 50-029-20078 LF~E DI~::~IGNATION AND SERIAL NO. ADL 28324 7. IF INDIA.N, ALLOTTEE OR TRIBE NAME 8. UNIT,FA/LM OR LEASE NAME Pru~oe Bay 9. W~) DS ( 23-35-11-15 ) I0. FI[rI~J'A~D POOL, OR WII-,DC'A.T 'rudhoe Bay Sadlerochit Pc 11. SEC., T., R., M., (BOTTOM HO,I.~. OBJECTIVE) Sec 35, TllN, R15E UM 12. PER~IT NO. 70-42 aT, GR, ~I'C)*]17. ~:1.~.'~". CASI~,qEAD I ~INTERYALS~ " __ DRILLED BY ' I CABLE TOOLS 23. WAS D!R~C~ONAL ~ SURVEY MADE ~ Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL, FDC, SNP, BHC-SONIC, LL~.3, SS GYRO Survey, CBL & Temp. Survey 25. CASING RECORD (Report all strings set in well) ' ..... ' ' ' I , ~o" [~ ~ 9~ / ~ ~ ri ~8~ ' ]" " " [ 72~ .J ~-80 [ 2686 [ ~7 ,/2" " " " [~7,~3,.5~o~ s~ [ 97~9 , ~2 ~I~" 13 3/8"., 9 518" SIZE I - LINER EEC OI-LD TO1~ (AID) BOTTOM (MD) ~ SAC. KS CEME~T* 2fi. P~RFOtRATIONS OPW.-LN TO PRODUC~TION' p~t~'a~iz~aT ,1 ,! SIZE 2 3/8" ,, TUBING RE C. OF~D SCi%EEN (~ffD) iA~/IOUNT puLLED'' --0-- --0-- --0-- --0-- DEPTH SET (MD) i PACIfiER SET (MD) 8968 ' i N°nei 29, ACID, Si/CT F;IAC'I O'RE, Cw.'>,IENT SQUEEZE, ETC. DF~PTIi IN'i'ElqV.~J., (MD~ ] AMOUN£ Z~ND I-i!ND OF MAtIE?~IAL USED SEE EI'V]3RSE SIDE [ None FEB 5- ~'?I Dl,¥1$1Ol'q 01;: 0i[ AND I % i~l I I I i ~ ~--- · '' '~ l Suspenaea DaTZ OF T~ST, ~O~-"EST~b' ' ICI1OXE SiZE IPEOD'i~ FO'~ OI~EDL. Gz~A~CF. %VATE~--BBL. ! GAS-OIL ILYTIO } I t ", ~*BING JCASLNG P~SSURE [CALC~ OI~BBL. GA~M~. WA~--BBL. [OIL GRAVITY-~I (CO~.) 31 DISPOSIIlONOr GaS ~8old used ]or luel vented, etc )- TEST W ITNESS~D 32. LIST OF ATTACHMENTS Well His%o~, Directional S~veys 33. I hereby certify that the foregoing and attached tnformathm is complete and correct as determined from all-available records ~(S~ Instructions ~na S~ce~ [or Additional D~to on R~v~rse Side) /,'* '* ;7 /" INSTIIUCTION$: Prepare and submit the INITIAl., ~EPOHT on the first Wednesday after a -ell is spudded or ,orkover operations are started. Daily ,ork prior to spudding should be summarized on the form giving inclusive dates only. DALLY WELL HISTORY-INITIAL REPORT District North Alaska -County or Parish North Sloue State Alm.~km -__ Field Prudhoe Bay n Auth. or W.O. No. 18-9138 Title Lease or Unit Drill Site #4 Well _ Development 0il Well Well No.L__ Operator ARC6 Spudded or W.O. Begu~.ll-27-70 Date R E"C [ VE'D ' .TARCO' S W.I. 50% FEB 5- 971 Prior. Status Hour6'O0 AM if a W. O. DIVISION OF OtL AND OAS' ANCHO~AOI Date & Depth as of 8:00 A.M. 11-11-70 ii-i2-Td 11-13-70 11-16-70 11-17-70 11-18-70 DS #4-i 11-19-70 11-20-70 ].1-23-70 11-24-70 :!].--25~70 Complete Record for each Day Reported (23-35-11-15) North Slope -API- 50-029-20078. Remvg Wind Walls. Mvg Rowan Rig #34 to DS #4. (23-35-11-15) North Slope -API 50-029-20078. Remvd wind walls frm Derrick floor and mvd mud tanks and mud mxg house to DS #4. · (23-35-11-15) North Slope -API 50-029-20078. Remvd rig and substructure wind walls. Remvd drawworks house and doghouse and mvd to DS #4. (23-35-11-15) North Slope -API 50-029-20078. Mvd rotary and shaft wrks, lowered derrick, mvd pmps and pmp shed, SD boilers and drained steam systems. Loaded out and movd power train, drawworks and prep to mvd power train cradle and rig base. .Movd derrick, A-frame and substructure and strtd RU on DS #4-1. Have po~er train set in. , .... (23-35-11-15) North Slope_- API 50ff~29-20078. Finished mvg camp and power plant. ~-- ~4~')~:~C~i?i/-?'~-~ ,,?:i:_- . - (23-35-11-15) North Slope - A?I 50-029-20078. RU drawworks and motors, pmps and motors. RU pmp shed. RU £reeze boxes on power train and freeze boxes frm power train to rig. (23-35-11-15) North Slope -API 50-029-20078. RU skid rails f/mud system and RU mud houses. RU, winterizing and movd truck. · (23-35-11-15) North Slope -API 50-029-20078. Rigging electrical system, strung lines in crown. (23-35-11-15) North Slope -API 50-029-20078. ~ised. mast and fin setting mud houses and electric lines to same. Instlg wind walls and bldg storage racks. RU instld wind wall and winterizing. (23-35-11-15) North Slope -API 50-029-20078. RU wind walls, floor and elec lines to floor. (23-35-11-15) North Slope -API 50-029-20078. Instld wind walls, set pipe racks, RU steam lines and electrical lines. CONFIDENTIAL The Above is Correct: / ..,4.. Mt':'_ ' ' ' "-. I ," ' Y : 'f" '/~'~" o-,,--', s l Gb~AI'UIU,: .,. / DATE / . / / / Ngzth..A. '1, !bt. ii(! D?-_[:.I_:I_ J._n_.g._5_u_pgL, y::[,?~_ _ T 1 TI,I':: ~.' ~ ~r,i:, :,~ '-{, I,,\{~ '~ ~l. l t II~',i.~ld t~mM:, i~L"~:-,I.:!:iI'{'IVI,:I.¥ AS TilI'.¥ Alii': I'ItEPAilI,:I'{ I,'Ol! EACll WEIA,. ) INSTRUCTIONS: This form is used during drilling or vorkover operations. If testing, coring., or perforating, show formation ~ame in describing work performed. Number all drill stem tests ~sequentially. Attach description of nil cores. Work per- formed 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 act. Submit weekly for workovers and following setting of oil string until completion. DAILY WELL HISTORY - IHTERIM District North Alaska County or Parish North Slope S~a teAlaska Field Lease or Unit DS 4-1 Well No.___ Date & Depth at 8:00 A.M. 11-27-70 #4-1 11-30-70 DS #4-1 12-1-70 DS #4-1 12-2-70 DS #4-1 12-3-70 DS #4-1 12-4-70 DS #4-1 Complete Record for each Day While Drilling or Workover in Progress (23-35-11-15) - NORTH SLOPE -API 50-029-20078 RU. Instld 30" Rockwell head. RU floor lights and heaters. Hauled wtr, Repaired seals in mud tanks. Mxd mud. PU 17-1/2" bit. ~7~ (23-35-11-15) - NORTH SLO?E - AP]: 50-029-20078 985' (985') - Drlg - MW 80#, Vis' 200 Spudded @ 6:00 AM 11-27-70. Drld 8-1/2" hole to 985'. Dn/~-~~rs. Low on wtr. Waiting on weather. Survey'.. 900' 1-1/4 Degrees. (23-35-11-15) - NORTH SLOPE - AP1 50-029-20078 1228' (243') - MW 79#, Vis 195, WL 18.4 Drld 8-1/2" hole 985-1228'. Made wiper run.. Cond hole. Ran Schlu Dil, FDC gamma ray and sonic gamma ray frm 1223'. Sonic log poor quality due to enlarged hole. (23-35-11-15) NORTH SLOPE API 50-029-20078 1250' (22') - MW 74#, Vis 195, WL 12.5 0pnd 8-1/2" hole to 17-1/2" 256-1228' and drld 17-1/2" hole 1228-1250'. (23-'35-11-15) North Slope -API 50-029-20078 1250' (0') - prep to run csg - MW 73#, Vis 200. Opnd 17-1/2" hole to 26" 87-1250'. Circ 3-1/2 hrs. POH. Reran 26" bit. CO 28' fill. Circ 2-1/2 hrs. POH. RU to run 20" csg. (23-35-11-15) NORTH SLOPE -API 50-029-20078 1250 (0') - MW 73#, Vis 200. Ran 8 its 20" 133# K-55 Vetco csg 'on 17 its 20" 94# H-40 Vetco csg w/3 ea 94# Regan slip its. 20" csg landed on 30" hd w/shoe @ 1185'. Top of EC landing clr 892', slip its @ 470', 350' and 230'. Landed @ 7:00 PM. Rn§ time 10-1/2 hr. Bkd out landing it. Ran cmtg stinger on 5" Reed extra wt DP. Stbd into shoe; circ 1-1/2 hr. Prep to circ pkr fluid when rig pmps failed. Wrkd on rig circ pmps 5 hrs. CO.N Fi DENT! AI.: %, , The Above is Correct: <' ' DATE ,.-,:,/ .:_?,,', , :,..,, .,, T i 'ri, E 2 , P^GE NO ................ {NIIMHEI! AI.I. DAII.Y WEI.I. IIISTOII¥ FOllM$ ¢:ON.gF.I.IIT1VI,:I.¥ AS TIIE¥ ^lie PIIEI~AllEI) FOIl I,:A¢:I! ~EI.I.. ) IffSTflUCTIONS: This lorn is used during drilling or workover operations, If testing, coring., or perforating, show formation name ~n desc'ribing work performed. Number all drill stem testa:sequentially. Ac~ach description of nil cores. Work per- formed 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 completien. DAILY WELL HISTORY - II~TERII4 District North Alaska Alaska .... State County or Parisb North Slope Field Lease or Unit DS #4-1 Well No.__ Date & Depth at 8:00 A.M. 12-7-70 DS #4-1 (23-35-11-1.~ 12-8-70 DS #4-1 (23-35-11-15 12-9-70 DS #4-1 (23-35-11-15 Complete Record for each Day While Drilling or Workover in Progress ) NORTH SLOPE -API 50-029-20078 (20" @ 1185') 2750' (1500')'- MW 74#, Vis 400, WL 18.5 Pmpd in 450 bbls 68# Ken-Pac in 4 hrs. 1st 35 bbls and last 18 bbls not trtd w/Ken-ox. Had 50 bbls clean Ken-pac rets. ~Cmtd 20" csg @ l~85'- Mxd 750 sX (750 cu.ft) of 1:1 Fondu Flyash cmt (111#) followed w/280 sx (325 cu ft.)'Fondu neat cmt (119#). Mxg time 50 min. Displ thru HWDP w/8 bbls mud. CIP @ 12:55 PM 12-4-70. Dry cmt 10 degrees, wtr 75 degrees, slurry 48 degrees. Had good circ throughout. Remvd 30" riser. Instld 20" permafrost hd. Ran D-A temp log @ 6:30 PM (0-70~ 3=8 degrees - 51 degrees, 100-350' 51 degrees - 49 degrees, 350-600' 49 degrees - 52 degrees, 600-750' §0-1/2 degrees. 750-950' 50-1/2 degrees -59 degrees and 950-1170' 59 degrees - 84 degrees). Ran CBL log rrm 807'. Top,of cmt @-765'. Instld kill manifold. Tst Hydril w/1000 psi OK. Purged choke manifold w/die oil, tstd manifold w/3500 psi OK. Tst csg w/750 psi OK, chkd 20" shoe @ 1185', Tstd 20" shoe and fm w/80 psi OK. CO to 1250'. No cmt 1195-1250'. Circ 1 hr, POH. Reran D-A CBL 1180-30'. Top of bonding @ 1174'. Drld 8-1/2" hole 1250-2750'. Spotted gel pill. Ran Schlu FDC in progress. NORTH SLOPE -API 50-029-20078 (20" @ 1185') 2750' (0') - MW 75#, Vis 200, WL 18. Ran Schlum FDC, DIL & BHC gamma ray 2750-1185'. Opnd 8-1/2" hole to 17" rrm 1250-2587'. North Slope -API 50-029-20078 (20" @ 1185') 2750' (0') - MW 75#, Vis 195, WL 18. Opnd 8-1/2" hole to 17-1/2" frm 2587-2750'. Measured out of hole OK. RI to 2750' circ' pld up to 1900' Bit dragged. RI to 2750'. Cond hole. PO OK. Made up and ran 13-3/8" csg, in progress. Ol¥1$10N OF OiL AND GAS ANCHORAG~ PAGE NO. 3 HtINTEI) IN IJ.$.A. The Above is Correct: D^TE SI GNA'rlII'E /'7 :.. . ........... TI TI,l;: ' ~ ~ (NI'I,tllI.:II Al.l. DAllY I~l-;|.l, illS'FOllY FOIIM,'-i (;ONSI,i(:tFI'IVI,;I.Y AS TllEY ARE i'IIEI'AllEI) FOIl EACil WF.i.I,. ) 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 per- formed by Producing Section will be reported on "INTEBIM" sheets until final completion. Heport 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. DALLY WELL HISTORY - INTERIM District North Alaska County or Paris'h North Slope Alaska State Field Lease or Unit DS #4-1 Well No. . Date & Depth at 8:00 A.M. 12-10-70 DS #4-1 (23-35-11-15) 12-11-70 Ds #4-1 (23-35-11-15) 12-14-70 DS #4-1 (23-35-11-15) 12-15-70 DS #4-1 (23-35-11-15) 12-16-70 DS # 4-1 (23-35-11-16) Complete Record for each Day While Drilling or Workover in Progress North Slope -API 50-029-20078 (13-3/8" @ 2686') 2750' (0~) - MW 75#, Vis 195, WL 18. 13-3/8" cmtd @ 2686'. Ran 2717' (72 its) 13-3/8" 72# N-80 butt csg to 2686' w/ Larkin flt shoe and ltl clr (2605'), Baker stg clr@ 1251', Rockwell EC hngr @ 892'. PI 175 bbls~d. Mxd 975 sx (975 cu. ft) 1:1 Fondu Flyash cmt ~llowed w/485 sx (558 cu.ft.) Class "G" cmt pre-mxd w/l% TIC (cmt -12 degrees, wtr 80 degrees, slurry 58 degrees). Displ w/215 bbls mud. · Press incr to 1900 psi. Hydrauliced csg 2' up hole. Had rets of oil contaminated mud. CIP @ 2:30 PM 12-9-70. Csg drpd 1' when pmps shut off. Opnd stg clr w/500 psi, circ and cond mud (rets o__ff 75% SF-100off s_~tg clr). PI g circ SF-100 pkr fluid. 2nd st~[ Mxd ~0 mx (380 cu ~--.~ .... Fondu cmt. Displ w/185 bbls mud. Closed stg clr w/1200 psi. CIP @ 2:00 AM 12-10-70. Tstd stg clr w/1500 psi OK. WOC. Landing csg. North Slope API 50-029-20078 (13-3/8" @ 2686') 2750' (0') - MW#, Vis 195, WL 18. Ran 13-3/8" slip assy, very tite. PO & reran 2nd slip assy, very tite.. Instld seal assy, very tite. Instld Rockwell speed hd. Took wt of BOP stack to force over csg stub. No visual evidence of why fitting ti~e. Possible oversized 13-3/8" jt. CO =! E N ~orth Slope - A?~ - 50-029-20078 (13-3/8" @ 2686') . .. 2800' (50') - M~ 68#, Vls 55. ~nstld.ne~ Nydril rubber, Tstd CSO pipe rams and c~oke manifold w/5000 psi OK. Tstd Hydril w/3000 psi OK. Ran 12-1/4" bit. CO cmt 1229-1244'. Tstd stg clr w/1500 psi OK. RI to 2085'. Drld out firm cmt 2085-2685'. CO to 2695'. Tstd csg shoe w/405 psi OK. Drld 12-1/4" hole 2750-2800i. Ran SS gyro survey 2686-0'. Ran D-A CBL & temp sur~e~. North Slope - A?T - 50-029-20078 (13-3/8'* @ 2686') 3892' (1092') Drlg MW 72#, Vis 48, WL 15 4 .... PU limber BHA & GIH. Drlg And bldg angle. POH and was tzte 3850-2700'. PU sqr stabs and reamed to btm. BHA - bit #10, 2 Drilco 12-1/16" sqr stabs - sub - monel DC - Servco 11-3/4" stab - 3 steel DC - LOR 12-1/4" stab - x over - bmpr sub - 39 its (1239.89') of HWDP. North Slope -API - 50-029-20078 (13-3/8" @ 2686') 4859' (967') - Drlg - MW 76#, Vis 42, WL 10.4. Drld 12-1/4" hole 3892-4859'. Survey: 4765' 26 degrees 00' TVD4628.69 S42E S733.56 E589.86. The Above is Correct: .... =__~_~..=:~-.:' /-.-/ SIGNATUIIE DATE .,.,.,.: -= ......... PAGE Nl~ ............. {NIiMIII,:il AI.I. I)AII,Y WEI,I. IIISTORY FI)I[MS C{)N~I,:I:II'I'IVEI.Y AS TilEY AIIE I ltEIAilED FOil EACII WEI.I.. ) PlIIN'I'I,:D IN II.,%.A. 3B~459-2 17,~;7 INSTBUCTIONS: This form is used during drilling or workover operations. If testing, coring., or perforating, show fornation ~ame' in'den-'~ribing work performed. Numbera Il drill stem tests sequentially. Attach description of all cores. Work per- formed by Producing Section will be reported on "INTEItlM" sheets until final completion. Heport official or representative test on "FINAl." form. (1) Submit "INTEHIM" 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, DAILY WELL HISTORY - INTERIM District North Alaska County or Parish North Slope State Field Lease or Unit DS #4-1 Alaska Well No.__ Date & Depth at 8:00 A.M. 12-17-70 . DS #4-1 (23-35-11-15) 12-18-70 DS #4-1 (23-35-11-15) 12-21-70 DS #4-1 (23-35-11-15) 12-22-70 DS #4-1 (23-35-11-15) 12-23-70 DS #4-1 (23-35-11-15) 12-24-70 DS #4-1 (23-35-11-15) Complete Record for each Day While Drilling or Workover in Progress North Slope -API - 50-029-20078 (13-3/8" @ 2686') 5720' (861') - Drlg - MW 76#, Vis 41, WL 8.4. Dir drld 12-1/4" hole 4859-5720'. Survey: 5658' 30 degrees 15' ~.VD5410.22 S40E S1068.72 E872.51. ' North Slope -API - 50-029-20078 (13-3/8" @ 2686') 6412' (692') - Drlg - MW 76#, Vis 52, WL 7.2. Dir drld 12-1/4" hole 5720-6412'. Survey: 6412' 30 degmees 00' TVD6063.19 S36E S1368.85 El100.56. North Slope -API - 50-029-20078 (13-3/8" @ 2686') 8230' (1818') - MW 85#, Vis 42, WL 4.4, Oil 2%. Dir drld 12-1/4" hole 6412-7700'. Tstd Hydril w/3000 psi OK. Tstd blind ram, pipe rams and choke manifold w/5000 psi OK. Dir drld 12-1/4" hole 7700-8230'. Survey: 8230' 28 degrees 00' TVD7646.97 S31E S2110.96 E1595.78. North Slope -API 50-029-20078 (13-3/8" @ 2686') 8707' (477') - Drlg - MW 85.5#, Vis 50, WL 3.2, Oil 4%. Dir drld 12-1/4" hole 8230-8707'. Survey: 8472' 27 degrees 00' TVD7862.59 S31E S2205.14 E1652.37. North Slope -API - 50-029-20078 (13-3/8" @ 2686') 8877' (170') - Drlg - MW 85#, Vis 52, WL 3, Oil 4%. Dir drld 12-1/4" hole 8707-8877'.. While GIH w/sharp bit had partial displ @ 4000'. Broke circ and rets OK. Survey: 8800' 25 degrees 15' TVD8185.31 S23E S2332.54 E1714.71. North Slope -API 50-029-20078 (13-3/8" @ 2686') 9250' (373') - MW 86.5#, Vis 45, WL 3.8, Oil 4%. Dir drld 12-1/4" hole 8877-9250'. Had mud gas cut to 83#. Circ out cuttings gas and mud returned to 87#. Survey: 9250' 28 degrees 00' TVD8557.37 S19E S2525.83 E1790.99. CONFIDEN DIVISI©N OV O1[ AND GAS ANCHORAGB The Above is Correct: PIIINI'I':D IN IJ..~.A. :llt-450-2 t: INSTIIUCTIONS: This fore is used during drilling or workover operations. If testing, coring., or perforating, show formation hame'in 'describing ,ork performed. Number all drill stem tests aequentlally. Attach description of all cores. Work per- formed by Producing Section viii be. reported on "INTEHIM" 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. DALLY WELL HISTORY - INTERIM District North Alaska County or Paris,h North Slope State Alaska Field Lease or Unit DS #4-1 Well No. Date & Depth at 8:00 A.M. 12-28-70 DS #4-1 (23-35-11-15) 12-29-70 DS #4-1 (23-35-11-15 12-30-70 DS #4-1 (23-35-11-11 Complete Record for each Day While Drilling or Workover in Progress North Slope.- AP1 - 50-029-20078 (13-3/8" @ 2686') 9790'TD (540') - MW 88#, Vis 42, WL 4.1, Oil 5%. Dir drld 12-1/4" hole 9250-9790'. Made 15 std wiper run, no fill, Schlu DIL. density gamma ray logs 9767-2686', sonic SNP & LL3 logs. Strung 10 lines, ran 12-1/4" bit to 9790'. Broke circ w/700 psi. Circ 10 minutes and lost rets. Plg DP. - Survey: 9790' 27-3/4 degrees TVDg032.80 S15E S2794.61 E1871.56. North Slope - AP1 - 50-029-20078 (13-3/8" @ 2686') 9790' TD - MW 86#, Vis 40,.WL 4.0, Oil 5%. POH to 5687' & wrkd pipe. Broke circ w/250 psi w/3/4 BPM. Incr to 2 BPM g 400 psi. WIH to 7700' and circ w/400 psi @ 2 BPM. Found brdg @ 8600' and circ w/400 psi @ 2 BPM. CO brdg and WIH to TD @ 9790' and circ hole f/csg. Lost 50-55 bbl mud and gained 35-40 bbl bk before reaching TD. Mud was quiescent in hole f/approx 40 hrs. Circ up several slugs @ 200+ sec vis and 90#/cu ft. mud. Circ frm TD w/12 BPM w/2000 psi. North Slope -API 50-029-20078 (9-5/8" @ 9749') 9790' TD MW 86#, Vis 40, WL 4, Oil 5%. POH. Chngd to 9-5/8" csg rams. Pld bowl protector. 9-5/8" csg @ 9749'. Ran 1495' (33 its) 9-5/8" 47# S00-95 butt includes Larkin opn guide shoe and diff clr on 2707' (65 jts) 9-5/8" 43.5# S00-95 butt on 3528' (80 jts)9-5/8" 40# S00-95 on 1988' (44 its) 9-5/8" 47# N-80 butt, on 9-5/8" x 12" Rockwell.hngr. Landed csg in speed hd @ 24' KB (270000# wt). Shoe @ 9749~ diff clr@ 9656', Baker stg clrs @ 5966' and 2420'. Lost rets while GIH @ 7300'. Landed csg w/csg full and annulus 3' dm. PI 30 bbls mud w/no rets. Pld 520000# gross pull and PI away 20 bbls mud, no rets, csg would not move. Drpd opng bomb and opnd stg clr@ 5966' w/900 psi, broke circ @ 3 BPM rate w/40% rets @ 500 psi. Slowed pmp to 400 psi and have full rets. Circ. CON Fi DFFITIAL.' The Above is Correct: INSTRUCTIONS: This form is used during drilling or workover operations. If testing, coring., or perforating, sho. formation nsme in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work per- formed by Producing Section .ill 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 leas frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit .eekly for ,orkovers and folio*lng setting of oil' string until completion. DAILY ~/ELL HISTORY - INTERIM District North Alaska County or Paris~ North Slope State Alaska Field Lease or Unit DS #4-1 Well No. Date & Depth at 8:00 A.M. 12-31-70 DS #4-1 (23-35-11-15) 1-4-71 DS #4-1 (23-35-11-15) Complete Record for each Day While Drilling or Workover in Progress North Slope -API 50-029-20078 (9-5/8" @ 9749') 9790' TD - MW 86#, Vis 40, WL 4. Circ thru stg clr@ 596~' 3 hfs w/full rets,.had 89# 165 vis mud frm stg clr. Cmtd thru stg clr @ 5965' w/430 sx(860 cuft) Class "G" cmt premxd w/10% gel, 0.2% D-13 g 1% Tic (98# slurry) followed w/80 sx (95 cuft) Class "G" cmt premxd w/0.2% D-13 & 1% TIC (118#, 56 Degrees F slurry) (mxg wtr 76 degrees) mxg time 35 min. Disp1 w/450 bbl mud (444 calc) in 30 min. Bmpd plug & closed stg clr w/1500 psi. CIP @'12:lS'PM 12-30-70. Had bleed bk. Held 800 psi on csg while mxg SF-100 annulus fluid. While mxg neat cmt Dowell's pmp truck pmp engine froze up (out o~ oil) to end mxg job. Discharge vlv was ~ vibrating closed giving false indication of displ press. Continued to mx SF-100 & Gel-tone into residual oil. With high vis air would be contained in fluid going thru jet mxr & pmps would lose suction. Diluted mx w/30% die oil - vis 250 sec @ 80 degrees F. Atmpt to mx barites to bring mixture to 72# & again pmps would los~ suction. Drpd bomb & opnd stg clr@ 2420'. PI 20 bbls w/wt material in 2 hrs. PI 3~0 bbls unweighted annulus fluid and had 25 bbls rets of annulus SF-100 fluid. (Mxg conditioDs -38 degrees 12 knot wind.) North Slope -API 50-029-20078 (9'5/8" @ 9749') 9790'TD - MW 86#, Vis 45, WL 4.3. Pmpd total 390 bbls SF-100 annulus fluid (10-30% diesel), had 73 bbls rets of SF-100. Cmt thru stg clr @ 2420' w/100 sx Fondu Flyash (1:1) cmt. Drpd closing plug and displ cmt w/177 bbls mud. Bmpd plug and closed ~tg clr @~ 2420' w/2000 psi, held OK. ~$P 10:15 AM 12-31-70. Instld 9-5/8" csg pk off. Tstd w/5000 psi OK. Indtld 5" rams. Strung 8 lines, stood cmtd 16 hrs. Ran 8-1/2" bit, DO stg clr@ 2420'. Tst w/1500 psi OK, DO stg clr@ 5965', could not tst. Fluid pmpd away w/500 psi (thru shoe?). RI to 9656', circ& cond hole. Pld' 10 stds, closed DP rams, tstd csg, pmpd away 4 bbls w/700 psi @ 3 BPM rate, POH. Ran 9-5/8" RTTS cmtr on 5" DP, circ 1/2 hr @ 9648'. Set RTTS @ 9643' tstd csg and stg clr@ 5965' w/1500 psi on annulus OK. Pmpd thru DP @ 5-1/2 BPM rate w/1200 psi. Opnd RTTS. PI 10 bbls Wtr & 5 bbls wtr treated w/5 gal .Free Flo, mxd 450 sx (515 CF 118#) Class G cmt treated w/l% TIC & 0.2% D-13. Displ slurry to tools, set RTTS, displ cmt to 9686' , fin press 1800 psi. CIP @ 6:30 AM 1-2-71. Flt did not hold. SI w/750 psi. Stood 4 hrs, released press OK. Released RTTS, backscuttled hole clean, POH. Had soft cmt ring in recess @ tool jt box only f/btm 17 stds. Circ out OK. Odometer on D-A sleeve erratic in -50 degrees F temp (D-A 9606 = DIL 9580). MIH w/8-1/2" bit and 9-5/8" csg scraper. CO firm cmt 9608-9648', circ & cond hole, POH. Ran DA G-R, CBL-CCL log frm 9639-8000'. Log shows top of cm-c @ 8750'. Shot 4 1/2" hole @ 9600' (Dim)..~ ~ ~ .... ~ [ ~ .L ~ [~ ~ CON FI DENT IAL' 101V$S~ON OF OiL A?~D GAN ANCHOP, AG~ The Above i.~ Correct: :-; 1 ~;NATURE / DATE TI TI,E .(~slff, lt~t I~ ~11, I)A~I ~ ~,1:1.1, IIISTOIIY F()R~, t:t)~:-,I~t~lVl.~LY AS TIIEY ARE PllEPA~EI) FOIl EACll WEI,I..) INSTBUCTION~: This form is used during drilling or workover operations. If testing, coring., or perforating, show formation ~ame in describing work performed. Number all drill stem teats sequentially. Attach description of all cores. Work per- formed by Producing Section will be reported on "INTEItIM" sheets until final completion. Beport official or representative test on "FINAL" form. (1) Submit "INTEI{IM' 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. DistrictNorth Alaska DALLY WELL HISTORY - INTERIM County or Paris~ North Slope Field Lease or Unit DS #4-1 Well No ...... .State :: Alaska Date & Depth at 8:00 A.M. 1-5-71 DS #4- (23-35-11-15) 1-6-71 DS #4-1 (23-35-11-15) 1-7-71 DS 4-1 (23-35-ll-15) Complete Record for each Day While Drilling or Work@vet in Progress NORTH SLOPE -API 50-029-20078 (9-5/8" @ 9749') 9790' TD - MW 86#, Vis 45. Ran 9-5/8" Howco RTTS on 5" 19.5# DP and circ 1/2 hr @ 9509' and set to tst csg. Tstd annulus of DP-csg w/1500 psi f/15 min OK. Tstd cmt prop and lines w/4500 psi OK. Pmpd in 4 bbl wtr @ 2 BPM w/2200 psi brk dn. SI press stable @ 1500 psi. Open RTTS @ 1:50 PM 1-4-71. Pmp in 10 bbl wtr trtd w/10 gal Shur-Flo. Mx and pmp 100 sx (115 CF) "G" w/1.0% TIC ¢ 0.2% D-13. Displ w/10 bbl wtr and 109 bbl mud. Closed tool and displ w/total of 171 bbl w/1800 psi to 2500 psi @ 1-3/4 BPM decr to 1 BPM. Stg sqz 2 cu. ft. @ 5 min intervals f/30 min w/press max of 2800 psi falling to 1800 psi. Did not get sqz. Cleared perf w/10 bbl wtr and 4 bbl mud. CIP 4:00 PM 1-4-71. SI hd 2-1/2 hr after strt of mix f/1 hr. 0pn bleed port @ '5"00 PM w/no press and reversed out DP. Rec 1 bbl contiminated mud and 50# of cmt chip. Reset RTTS @ 9609' and pmp into fm w/5 bbl @ 3 BPM w/1800 psi. Opn tool and pmp 10 bbl of wtr w/10 gal Shur-Flo followed w/100 sx (115 CF) "G" w/0.2% D-13 and 1.0% TIC. Mix time 10 min strtd @ 7:40 PM. Displ w/10 bbl wtr and 109 bbl mud. Closed RTTS and displ w/additional 52 bbl mud w/2 to 1 BPM rate @ 1500-2100 psi. Stg sqz 6 cu. ft. @ 5 min intervals w/1700 psi to 2800 psi and failed to get sqz. Cleared perf and closed hd w/1500 psi. CIP 10:40 PM 1-4-71. Held press 1 hr. Reversed DP clean and POH to chk DP. Found last 1600' had cmt ring. RTTS had slight buildup. Strt in hole. NORTH SLOPE'- API 50-029-20078 (9-5/8" @ 9749') 9790'TD - Ran 9-5/8" RTTS pkr to 9509'. Tstd surf lines w/3500 psi OK. Set pkr. Broke shot holes dn @ 9600' w/1750 psi. Opnd by-pass. PI 10 gal free flow mxd in 10 bbls wtr, mxd 300 sx Class G cmt premxd w/l% TIC and 0.2% D-13. Displ cmt to tools w/79 bbls wtr and mud, closed tools, sqzd cmt to fm w/max 2750 psi @ 1/8 bbl per min rate. Fm broke dn @ 2700'. Pmpd last 7 bbls to fm @ 1700 psi. Cleared perfs. Held SI f/2 hr. Reversed DP clean. Had 3 bbls contaminated mud. Reset Rtts @ 9417', broke shot holes dn w/2250 psi. PI 10 gal free flow in 10 bbls wtr. Mxd 200 sx (41 bbls) Class G cmt premxd w/0.2% D-13. Displ cmt to tools w/98 bbls wtr and mud. Stgd cmtd shot holes at 9600' w/31 bbls cmt. Fin press 2500 psi. Held 15 min. CIP 3:00 AM 1-6-71. Reversed DP clean. Recovd 2-1/2 bbls contaminated mud. POH. NORTH SLOPE - API 50-029-20078 (9-5/8" @ 9749') NO REPORT. (Sqzd shot holes @ 9380' w/170 sx cmt. Fin press 2500 psi. Details to follow). ~: ~: C ~ ~%/ ,r ~ CONFIDENTIAL 9~\a, 51C,~4 OF OiL A~'-!D GA~ 8 PAGE NO The Above is Correct: 7 ':? // ~, :' _..~':¥~? ... ,..~..; . .... · I'ITI.E (NUMIIMI Al.I, I)AII,Y WELl, IIlSTOHY FOIIMS CONSF. CUTIYEI,Y AS TIIE¥ AIIE PllEI'AilED FOI{ EACI! WEI.L. ) IN:4TBUCTIONS: This form ia used during drilling or workover operations. If testing, coring-, or perforating, show formation ~-/~-.m-~--~ in-~escribing .ork performed. · Number all drill stem tests sequentially. Attach description of all cores. Work per- formed by Producing Section will be reported on "INTERIM" sheets until final completion. Report official or representative teat 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 workovera and following setting of oil string until completion. District North Alaska DALLY WELL HISTORY - INTERIM County or Parish North Slope Field Lease or Unit DS #4-1 Well No .... .State Alaska Date & Depth at 8:00 A.M. 1-8-71 DS #4-1 (23-35-11-15) 1-11-71 DS #4-1 (23~35-11-15) Complete Record for each Day While Drilling or Workover in Progress NORTH SLOPE -API 50-029-20078 (9-5/8" @ 9749') 9790' TD 964~' PBD. 1-7-71 - Pld RTTS, drug 30000# f/25' then free. Had cmt on tool and 15' contaminated mud in b~m jt DP, no cmt inside DP. Ran 8-1/2" bit and 9-5/8" csg scraper, top cmt @ 9472' . PU to 9450', cond mud. Shot 4 1/2" holes @ 9380' (DIL) Ran 9-5/8" RTTS tool to 9265' se~ tool closed rams,'tstd 9-5/8" csg abv pkr w/1500 psi OK. Tstd surf lines w/3500 psi OK. Broke dn shot holes @ 9380' w/2250 psi. PI @ 1.2 B/M rate w/2300 psi. Mxd 10 gal Free Flo in 10 bbts wtr. Mxd 200 sx Class "G" cmt premxd w/0.2% D-13. Disp1 cmt w/10 bbls wtr and 85 bbls mud. Closed tools, sqzd shot holes @ 9380' w/i67 sx to fm in 4 stgs. Fin press 2500 psi. Held 10 min OK. CIP @ 7:45 AM 1-7-71. 1-8-71 - Reverse circ DP clean. Record 30 bbls contaminated mud w/ slight trace of cmt. Ran D-A csg gun, stpd @ 9272'. Shot 4 1/2" holes @ 9268'. Ran 9-5/8" E-Z drl retainer and set retainer @ 9160'. Tstd annulus w/1500 psi. Had slow bleed off. Tightened 9-5/8" csg seal assy. Tst surf lines w/3500 psi OK. Pressd shot holes @ 9268' w/2500 psi, held 5 min. Released press to chng over to diesel oil in surf lines (atmos. -38 degrees F). While chng over, pressd w/rig pmp to 2500, bled to 1600 psi. Could not find any surf leaks. RU Dowell, pressd to 4000 psi and held 5 min. Bled off and repressd and holes brk dn w/2400 psi. PI @ 1/4 B/M rate @ 2500 psi. Mxd 10 gal Free Flo in 10 bbls wtr. PI hole and mxd 100 sx Class G cmt premxd w/0.2% D-13. Displ cmt to tools w/10 bbls wtr and 111 bbls mud. Closed tools and sqz 70 sx cmt to fm in 4 stgs. Fin press 2500 psi. CIP @ 4:45 AM 1-8-71. Pld DP out of retainer, reversed DP clean. NORTH SLOPE -API 50-029-20078 (9-5/8" @ 9749') 9790'TD 9648'PBD - Plugged 9169-9050'e. Spotted 50 sx Class G cmt premxd w/0.2% D-13 @ 9160-9050'+. PU to 897~'., reversed DP clean and circ hole clean. POH, LD DP to 248--9'. Flush out mud in 9-5/8" csg seal assy and plastic packed seal assy. Tat seal assy w/1000 psi f/15 min OK. Reversed mud w/diesel oil rrm 2489', POH, LD DP. Ran 8948' (287 jts) 2-3/8" 4.5# N-80 butt tbg, landed @ 8968'. Completed filling annulus and tbg w/200 gal diesel. Remvd BORE. Landed well hd, did not seat. PU well hd. Unlanded tbg, dressed lip off tbg hngr. relanded tbg, instld well hd. Tstd w/5000 psi OK. RR 5:00 AM 1-10-71. CONFIDENTIAL DiV~S~ON OF O~L AND GAS ANCHO~G~ The Above is Correct: ~ 1 GNA'I'UI'E ~~~, DATE . .,.-:---? . ,'-- .,.., :. 'I'1 TI.E ,,, '~ (NUMBER .~I.I D~II.Y ~EI.I. IIIS'I'O}~Y FORMS (X)NSi.'(;lJ'I'IVEI.Y AS TIIEY AIIE PIH']~AllED FOR EACI! WEI.I.. ) '1~ iN IN';TttUCTIONS: Prepare and submit the FINAL REPORT on the first Wednesday after s hie has been assigned or well is Ab.,,do.ed, or Sold. FINAL REPORT should be submitted also when operations are suspended for an indefinite or appreciable ~,~r~'t:th o~ tJ~e, On workovers ~hen an official test ia not required upon completion, report completion and representative data in blocks provided. The FINAL REPORT form may be used for reporting the entire operation if space is DALLY WELL HISTORY - FINAL REPORT District North Alaska FielR...Prudhoe BAv Auth. or W.O. No.~18-9138 County or Parish North Slope Lease or Unit Drill Site ~4 State Alaska Well No. 1 - · Title Development Oil Well Operator,, ARCo Spudded or W.O. Begun 11-27-70 Date _ TARCO's W.I. 50% Prior Status ,Hour 6:00 AM if a W.O. Date & Depth as of 8:00 A.M. 1-11-71 DS #4-1 (23-35-11-15) Complete Record for EaCh Day Reported NORTH SLOPE -API - 50-029-20078 (9-5/8" @ 9749') - 9790'TD 9648'PBD - Plugged 9169-9050' +. Spotted 50 sx Class G cmt premxd w/0.2% D-13 @ 9160-9050'+. PU to 8975' , reversed DP clean and circ hole clean. POH, LD DP to 248--9'. Flush out mud in 9-5/8" csg seal assy and plastic packed seal assy. Tst seal assy w/1000 psi f/15 min OK. Reversed mud w/diesel oil frm 2489', POH, LD DP. Ran 8948' (287 its) 2-3/8" 4.5# N-80 butt tbg, landed @ 8968'. Completed filling annulus and tbg w/200 gal diesel. Remvd BOPE. Landed well hd, did not seat. PU well hd. Unlanded tbg, dressed lip off tbg hngr. Relanded tbg, instld well hd. Tstd w/5000 psi OK. RR 5:00 AM 1-10-71 : . Old TD New TD 9,793 PB Depth 9050 Released Rig 5:00AM Date 1-10-71 Classifications (Oil., Gas, etc.) Oil Well (Suspended) Producing Method , Kind of Rig Rotary Type Completion (Single, Dual, etc.) Official Reservoir Name(s) Sadlerochit Potential '[est Data: ' ~ OiL OR TEST TIME PRODUCTION WELL NO. DATE RESERVOIR PRODUCING INTERVAL GAS OIL ON TEST GAS PER DAY ,, ' PUMP SIZE SPM X LENGTH CHOKE SIZE T. P. C. P. WATER ~ COB ~'RAVITYALLOWABLE EFFECTIVE DATE , CORRECTED l)i~t, ribution: The Above zs Correct: Orig.: Drilling Section - Dallas cc:- District Office Engineering Division - (720) Co-Owner(s) As Appropriate ll,~ional Office, Well Record File North Ala~ Drilling Supcrvis, or TITLE ~:,, ........... (NIIMBI.:i~ Al I. I,^fI.Y WEI.I. IllS'tonY roams CONSECUTIVELY AS THEY ABE pIIEPARED FOlt'EACll SYMBOL. OF SERVICE CO T REPORT of SUB-SURFACE DIRECTIONAL SURVEY NY r~lll RITF 42 ~,23T35,11-15) NORTH S.I_OP~E,~. ALASKA JOe NUMBER AM 121670 TYPE OF 'SURVEY DATE SINGLE SHOT DEC. 1970 ANCHORAGE ~.. 0 I R E C T I O'N a' L' $'U ~ ¥ E ¥ PAGE TAH~ENTIAL METHOD ATLANTXC RiCHFiELD CO OCS.-* MELL 2:3-35-11.-L5 PREPARED BY SCS !2/30/70 DEPTH ANGLE DIRECTION TVO SUB :SEA LATITUDE DEPARTURE DISTANCE ANGLE SEVERITY DISTANCE !00 0 ~5' S 20E 200 0 ~5' S 21E 400 0 30* S 8E 500 0 15~ S 700 0 35~ 5.31# 800 0 35' S 342 ~00o ! 5, S 60E 1100 0 55' S 73E 1~00 i 10' S 1600 ~ ~Oe $ 66E ~700 ~ 35' S TV~ = O.OOe LaT!TUOE.~~ _DEPARTURE 35.99 234,415 §0.14E 239o7! S 12.07E 0.000 135.99 23~.815 50o30E ~0.~ S ~2o09E 0.004 223.00 ~35.99 236.095 50.5~E 2~1.~ $ 12.06E 0.257 635.9e 2~8.27S ~9.gSE 243.45 S 11.84E 0,265 225.68 735.97 239,1~$ ,~,3aE 244.Z6 S Ll.66E 0,030 226.06 935.95 2~[.0T$ ~,ZSE 246.44 S ~.98E 0,847 228'68 L035.9~ 24L,535 5~.71E 2~T.22 S ~2,31E 0,280 229.92 242.385 ST.82E 249.~8 S !3o41E 0.319 233.48 2~3.5~$ 61.84E 25t.28 $ I~..2*E 0.326 236.68 2~5.175 64.07E 253.41 $ ~4.64E 0.50~ Z39.28 399.99 699,98 799.97 --laO0 ........... X--~O' __S_.__~tT_E !?qge'7T__ [73s.T7 2000 2 tO' S 26E 1999,65 19~5.65 2300 3 40' $ 59E 2299.30 2235.30 2500 4 25' S 56E 2498.69 ~434.69 ~....~600 4 35~ S 58E 2~98.~7 2534,37 3090 7 15' $ 60E 3'~29 t4 30' S 50E 3,085.88 3021.88 ~____ 3!T4-28 TANGENTIAL NETHOD D [ ~ E C T [ ~'N A,L $' U R V E Y ATLANTZC RICHFIELD CO D.So-4 NELL 23-3§-/[-[5 PREPARED BY SCS [2/30/70 PAC .~ASUREO -O E ...V I..A .T ....... t..O. N .............................. TQTAL~.CQO.RDINATES CLx. Q_5 U. R_.E. S ~ OGGL DEPTH ANGLE OIRECTION TVD SUB SEA LAT[TUDE DEPARTURE DISTANCE ANGLE SEVER[ T 3.583 3737 3892 4765 5074- 52t3 5382 ~807 ,1.20 64L2 6563 6715 6805- 7119 7~88 edit 82~o 6723 9086 9250 9&75 .a790 1,8 30 ' 22 26 26- 15 ' 26 26 26 30 30 30 ' 30 15 * 30 30 30 32 32 45* 30 [5* 27 45 ' 28 30 t 28 28 0 27 0 25 45 25 t5 28 0 S $ $ S $ $ S S S S S S $ S 49E 3562,'I~6_..3~9_8,_~6 ..... 375..205 S 47E 3705,25 3641.25 4L~,55S S 45E 3844,56 3780,56 462,5gS S 43E 4352,78 4288.78 643,4tS S 42E 4628,7[ 4564,71 743.435 S ~[E 5026,22 4962.22 897,445 41E 51,71.83 5107,83 962.18S 40E 5610~25 534b.25 ..... I068.69S 38E 5539,29 5475.29 1127.40$ 38E 5810.36 5746,36 1250.72S 36E 6063.2~ 5999-o2~ ..... 13.68,815 36E 619~,29 6L27,29 I~33,57S 35E 6319,[3 6255,13 1500,93S 34E 63-9~,fl2 ~6330~82 ..... L5_~1,29S 34E 6666,07 6602,07 1672,~3$ 32E 6992,63 6928,63 1818.14S 35E 7266,82 7202,fl2 ............ 194.0~9S 34E 7~52,69 7388.69 2022,89S 31E 76~6,05 7582,05 7861,68 .... 2797,68 ....... 8087,75 8023.75 2302.355 8157,39 8093.39 2332.58$ S 27E S 23E S 23E 28 0 * S 16E 2.8 ~30' $ L6E 27 45 ' S 15E 238.065 444...35 .S 32o39E 2,.603 280.25E 500.39 S 34.06E 2.316 ~28,30E 567.25 S 35,36E 2,633 499.67E 814.65 S 37.83E 0.166 589.726 9~8.93 S 38.~25 0,142 681.17E !085.36 S .38.87E 0,080 7a6.77E 1t5~.81 S 39.00E 2.718 783,04E 1240.54 S 39.13E 0.295 872.~1E 1379.57 S 39,~E 0,204 10t4.63E 1610.52 $ 39.05E 0.000 1.100.~5E 1756.33 S 38.79E 0,342 1147.48E 1836.26 S 38,67E 1.32~ LZ2L,STE 196.6~87 S 38.,.IOE 0,601 1310.33E 212'.62 S 38.07E 0,796 1401,37E 2295,5~ $ 37,62E 0,726 Ii86,76E 21_14,~6 $ 37,16~ 0,512 1542.61E 2543.96 S 37.32E 0.254 1595,56E 2&~6,17 S 37,08E 0.655 1652.1SE 2755.4~ _S 36,84E 1701.65~ 2862.91 $ 36.46E 0.865 1714.4~E 2894.90 $ 36.31E 2,328 3022.48. S 35.,.7~E 0.699. 3096.29 S 35.33~ 1.219 ~196.15 $ 31.70E 0.625 3276,26 .S 31,23.E 0,282 / 3336.qq S 33.87E 0,641 8556,46 8492.46 2525.92S 1790,72E 8755.12 8691.12 2627o46S 1819,84E 89_10.67. 88~6.~7 ......... 270.8..6§S 1813.1.2E 9032,80 8968.80 / 2770.71$ 1859.75E CLOSURE 3336.9q S 33- 52' E O ][ R E C T I 0 N A- L* S U R V E Y PAGE ATLANTIC RICHFIELO CO 0,S.-4 ldELL 23-35-]L]L-t5 PREPAREO 8Y SCS [2/30/70 TANGENTIAL I~ETHOD MEASURED DEPTH TVD 164 164.00 264 264°00 464 '464.00 ~64 564.00 TOTAL COORO!NaTES MD-TVO VERTICAL SUB SEA LATITUDE OEPARTURE DIFFERENCE CORRECT[ON lOOoO0 -234.67$ 200.00 -235,08S ~._._~.~sS;TSiS_ _ _ 400.00 -236.375 500.00 -237.08S 50.54E O 50,SOE 0 764 764.00 700,00 -238,81S 86* 864.00 800,00 -259.76S · -~-L064 1064.00 lOOO.O0 -24L.$6S 1164 1164.00 LLOO.O0 -241.87S ~ .............. ~26d~00 ......... 120~- - -242~045 1364 1364.00 1300.00 -242.25S 1464 1464.00 1400,00 -242,60S 1664 L664.00 1600.00 -244.59S Z764 1764.00 1700.00 --1864 ................1.~64.00 .... ~I~ 1964 1264.00 1900,00 2064 ~064.00 2000.0'0 2265 2264,00 2200.00 2365 2364.00 2300.00 2~66 2564,00 2500.00 2666 2664~00 2600.00 2867 2864.00 2800.,00 2267 2264.00 2~00o00 --306e ............... ~__ 3000~00_ '2S4.44S -260.685 49.58E 0 0 4~,48~ 0 O ~Z.LGE 0 0 53.68E 0 0 57.10E 0 59,20E 0 63.27E 0 65.44E 0 67~&LE O 69.~6E 0 7i,59E 0 78,34E X 97.83E 2 i04.0iE 2 111,84~ Z 120.16E ~ 129.32E ~ 0 0 0 0 J~ 0 0 ! 0 L F? D [ R E C T ]: O N A-L S U R V E Y PAGE 2 ATLANTIC RICHFIELO CO DES.-4 NELL 23-35-11-15 PREPARED BY SCS 12/30/70 TANGENTIAL METHOD MEASURED DEPTH TVD TOTAL COORDINATES t~D-TVD VERTICAL SUB SEA LATITUOE DEPARTURE DIFFERENCE CORRECT[ON 3169 3164.00 3100.00 3272 3264.00 3479 3464.00 3400.00 3585 3964.00 3500.00 3802 3764.00 3700.00 3914 3864.00 3800.00 .~,,..4~37 4064.00 4000.00 4248 4164.00 4100.00 1 3 12 4470 4364,00 4300.00 4581 4464.00 4400.00 4804 4664000 4600.00 4916 47~4000 4700,00 -647.~8S 503,33E !06 -75&°36S &Ol,37E I~0 I1 5141 4964,00 4900.00 -870.3~S T03.ZOE 177 5257 50&4.00 SO00,O0 -9!4.24S 741.37~ 193 54a9 S2a*.O0 ~200.00 -~O0~.3SS e~?.sme 2~s 5&05 5364°00 5300.00 -lO~e,02$ 855.07E 241 58~6 5~64,00 5500,00 -1138,64S ~27.0&E 272 D ! R E C T ! O'~N A '!~ $ 'U R ¥ E Y PAGE 3 ATLANTIC RICHFIELD CO 9.S.-4 ~ELL 23-95-11-15 PREPARE9 8Y SCS [2/30/7D TANGENTIAL ~ETHOD NEASURED TOTAL,. COORDINATES HO-TVD vERTi DEPTH TVD $U8 SEA LATITUDE DEPARTURE DIFFERENCE CORRECTION 6885 6464,00 6~00,00 -~7~,T~$ ~Z~.~E ~ !7 700Z 6564.00 6~00.00 -Z623,08S ZZTT,O4E 437 7~43 6664.00 6800.00 -1760.7~S :X~6~.~E 47~ 7064.00 7000.00 - 84g.e $ 7683 7X64.00 TtO0.O0 -~894,36S ~454;,T4E 5~g Tgxo 7364.00 7~00.00 -~83.3~S .i~l~.g6E ~4~ 8024 7464.00 7400.00 '2028.04S 1545.7~E g60 82~0 7664.00 7600.00 -2XXO.aSS X60O,27E ~8~ 8362 7764.00 7700.00 -~6Z.53S 16~6.gZE ~9e 8~8~ 796~.00 7gO0.O0 -Z2~,Z~S Z674, g~E 622 8697 8064.00 8000.00 -2292.14S X696.45E 6~ 8gZO 8~64.0Q 8200.00 -2363.~ZS ~7~.g4E 6~6 903~ 8364.0Q 8300.00 -2430.S~S XT~6..GTE 668 Z2 g~7Z 8664.00 8600.00 -Z580,89S XSO6*48E 708 9S99 8864.00 8~00.00 -Z684.29S ~8~6.Z3G 7~ 971Z 8964.00 8900,00 -~7;35.7~S 18~0.38E 748 PAGE ! ATLANTIC RICHFIELD CO O.$.-* NELL 23-3S-!1-15 PREPARED BY SCS 12/30/70 TANGENTIAL METHOD ~EASUREO DEPTH 1000 2000 *000 5000 6OOO 7000 8000 TOTAL COORDiNaTES MO~TVO VERTICAL TVD SUB SEA LA'TITUOE OEPARTURE DIFFERENCE CORRECTION Lg99o65 1935.65 -Z52.68S 70o05E 0 0 3941..2 3877.~2 -496.95$ 361.4eE 58 55 *839.47 4775.47 -8Z0.67S &$9.27E 160 102 5?06.63 56~2.~3_ ...... ~~$ ........ g2_T~ ................ 2.9~ .............. 1.33 6563.27 6~99,Z7 -L622.73S i276.80E ~36 143 7**3.00 73'7g,00 -20~8.57S ~539.?0E $56 ~20 TANGENT[AL HETI.40O DIRECT !NTERP~LaTEO ATLANTIC RICHFIELD ['O N A'L $ U R V E Y PAGE CO D.S~,-4 HELL 23-35-11-[5 PREPAREO BY $CS 12/30/70 [I3 HARKER -TOS HEASURED DEPTH TYD SUB SEA 9296 ~97t07 9310 8609.~3 9312 $611.20 g~4.._ a&!2-g6 ~SS4a.g& . 9~16 8614.73 8~S0.73 9~22 8620,03 8556.03 9324 8621.79 g~28 8~25,33 8~61,33 9330 8627.09 8563.09 ~334 8630.62 8566o62 9336 8632.39 8568.39 g34Q 86~5.92 8~T.1,92 9342 8637.69 8573.69 9346 864Z.22 8577,22 9348 8642,98 8578.98 9352 8646.52 8~82,52 9354 8640.28 8584.28 9358 86~t.8t 8587.81 9360 86~,58 8$89,~8 9364 8697.11 9366 8658,88 0594.88 ¸4' TOTAL COORDINATES LATITUDE DEPARTURE -2554.gi.S -2555oTtS 1798.49E i798,75E 1799,2bE 1799.52E leO0.04E ISOO.~OE -2561,125 1800,82E -2562.038 teOI.OTE -2563.835 1801.sgE -2564.735 teOI..e~E -2566,54$ 1802.37E -2567.44$ 1802,6~E -2570,15$ -ZSTt,VS$ -2572.865 -2574°665 -Z576.56$ -~S76.478 -2578.27$ 1803.40E 1803.62E 1804,18E ~44~ t804-96~ ~805,73E O [ R E C T I'O N A*'L 'SURVEY PAGE RADIUS OF CURVATURE METHOD ATLANTIC RICHFIELD CO 0.$.-4 i~ELL 23-35-11-15 PREPARED BY SCS [2,/30/70 i, IEASUREO O E V I A T ! 0 N OEPTH ANGLE DIRECTION TVD SUB SEA TOTAL COORDINATES LATITUDE OEPARTURE C L O $ U R E S DOG LEG SECT[ON DISTANCE ANGLE SEVERITY DISTANCE ORIGIN LOCATED AT MD I00 0 15° S 20E ~00 0 30° S 8E 600 700 0 ,,,,900 0 35° S 9E lO00 I 5° $ 60E 1200 0 55' $ TiE 0.00, TVO - O.OOt 99.99 299.99 235.99 399.99 335,99 ~99~99 899,97 999.96 935,96 1199.93 1135.9~ LATiTUOE- -234,00, DEPARTURE - $O.O0 2~5o22S 50,4~E 2~O.S? S 12. lOG 0.01~ 222,95 2~7.17$ $O.~.E 2~2,~8 S 12.CIE 0.250 224.58 238,0&$ 50.21E 243.30 S ll.gOE 0,265 225,16 2~t.0~$ 50.8~E ~4&.32 $ il,geE 0,847 227.96 24.2.2!S 53,94E 248.14 $ I2.$~E O,OSl 230,69 241.9~S 55.51E ~8.22 S 12.g2E 0.3i8 251.~5 1500 1 1600 I lO° $ 66E - [ 700 .......... L-35: 1800 i 40' S 4TE tgOO t 45' $ 46E 2,!00 2 $' $ 41E 2ZOO Z 15' $ 37E 2~00 4 ~Oo $ 59E ~500 4 29' $ 56E 2686 4 ~' $ SSE 2936 5 15' $ 65E 3~4S lO ~0° S SSE 3429 14 30° S 5OE ~- ~~8~ ._- 1799.79 1735.79 1899.T4 18~5.74 2099,62 ~035.62 2199.55 2135.35 2399.15 2335.15 2498.65 2434.85~ 2664,30 2620,30 2933.46 2869.46 s08~,34 .. _~022.34 3239.67 3!75,67 3419.27 3355,27 243.05$ 61,42E 250.69 $ 14.18E 0.326 235,S9 2.~6.0~$ 65,66E 254.67 S 14.g4E O.Zl5 240.46 248.10S 6T,$4E 257.21 $ 15,2~E 0.086 243.38 Z53,g~$ ~6.875 263.975 268.1~$ 276.,0tS 286,L6S 29~.90S 306.75S ~30.~8$ 71.88E 263.91 $ 15.80E 0,560 250.47 74.26E 267.39 $ 16.[2E 0.224 254.24 ~__B.OTE _~7!.76 S 16.69E 84,17E 277,07 $ 17*68E 0,833 265.68 ge.?3E 283,08 $ !6,69E 0,24'7 272,82 ' I02.73E 294,51S 20.41E 0.638 286.06 120.32E 3.10.43 S 22.80E 0.56T 304.34 155.34E 343,8~ S 26.8SE 2.153 341,04 166.92E 380.11. $ 29.45E 2.250 378.83 D I R E C T [*0 N A*L S U R V E Y PAGE 2 RADIUS OF CURVATURE METHOD ATLANTIC RICHFIELD CO D,S.-4 I~ELL 23-35-11-I~ PREPAREO BY SCS 12/3~/70 MEASURED D E V ! A T ! 0 N DEPTH ANGLE DIRECTION TOTAL COORDINATES C L 0 $ U R E S. DOG LEG SECTION TVD SUB SEA LATITUDE DEPARTURE O]STANCE ANGLE SEVERITY O[STA. NCE 3737 22 O* S 47E 5713 30 O' $ '~-~658 30 XSe S 40E 5807 30 O' s 38E 6412 30 0° 4087.26 4023,26 4914.46 4850,46 5037.03 4973.03 5550°00 5486.00 S 36E 6073,95 6009,95 S 36E 6203.37 6139,37 3~g,388 220.~?E 618.218 478o11E 818,545 660.08E 867.6~S 703o49E 421,46 S 31,49E 2,603 42i.00 472.80 S 33,32E 2.316 472.75 648.04 S 36.~2E 0. i94 647.50 ?ei.52 S S?.?IE 0.I66 780.02 I~51.53 $ 38.88E 0.080 1047.~7 1037.985 849.98E 1~41.S9 S 3g,31E 0.204 1336.19 lO~6.LOS 8~7.04E 141~.~7 S 39.29E 0,694 1410.70 .1336,018 1081.25E 1718.73 $ 38.98E 0,342 i7i2.67 13;8,938 l126.g6E 17~6,40 $ 38.85E 1,324 1790,40 6805 32 71!9 30 15' S 34E --7-488 ......27_48~ ..... S_32E 7800 28 30" S 35E 8011 28 15' S 34E 8472 27 O' $ 31E 8723 29 45, S 27E -aaoo- ...... 25_1_5, ~_S_23E 9086 27 92S0 28 O' S 19E 9652 Z8 ~0' S 16E 9790 27 6407.44 6675.15 7273.0! 7458,66 7&~1.80 7866°46 8091.35 8~Z?.~ 8562.6~ 8917.20 9038.91 6611.15 1641,328 1293-53E 2089.77 $ 38.246 __ 69~3.86 1791.33S~ X3~E ~g6_$ 7209,01 1913.96$ 1472,12E 2414,62 S 37,56E 7394.66 1996.60S 1528o92E 2514.76 $ 37o44E 0,601 1920o'45~ 0,796 2084.50~ 0,512 2410,~8 0,254 2510o65i 7887.80 7802,46 80~7.35 8498.62 8697.28 8974.91 2179.44S 164X.93E 2728,72 $ 36.ggE 0.413 2725.41 i 2276.948 1695,98E 2839.16 S 36.68E 0.86S 2836.43 24~3.418 1759.41E 2994.7~ $ 35o97E 0.699 2993.2*' 2494039S 1786,65G 3068,24 S 35,6~E L,21g 3067.27 2675..65$ i841.SOE 3248,12 $ ~4.~3E 0,282 3248.05 2738.]48 1858o89E 3309,68 S 34.i7E 0,64! 3309.68 CLOSURE 3309.68 S 34- ]LO' E O ! R E C T ! g N A. L $ U R V E Y PAGE RADIUS OF CURVATURE METHOD ATLANTIC RICHFIELO CO D,$--4 HELL 23-3S-][1-15 PREPARED BY $C$ t2!30/10 t4EASUREO TOTAL COORO!NaTES MO-TVO VERTICAL DEPTH TVD SUB SE~ LATITUDE OEPaRTURE DIFFERENCE CORRECT[ON t64.00 264.00 464 464.00 400.00 -236,285 564 564.00 500.00 -236,93$ 764 764.00 700.00 -238,6tS 864 864.00 800.00 -Z39,525 106~ 1064.00 1000.00 -241,465 1164 1164,00 1100,00 1264 126~-.G0 ........... 1364 1364.00 l~O0.O0 1464 t464.00 1400.00 1664 1664.0Q 1600,00 -243,B25 1764 lT64,00 t700.O0 -245.40$ t96~ t964,00 1900,O0 -24~,.87$ 206~ 2064,00 2000,00 -252,8~S 2265 2264.00 2200.00 -259,09$ 2~65 2~64,00 2300.00 -262,685 2565 2564.00 2500.00 -270,94$ 2666 2664000 2600.00 -275.[65 2866 2~64.00 2800.00 -283.335 2967 2964,00 2900.00 -Z87.71$ D ! R E C T I (5 N A'k 'S U R ¥ E Y PAGE~ RADIUS OF CURVATURE METHOD ATLANTIC RICHFIELD CO D.$,-4 MELL 23-3S-ILl-ILS PREPARED BY SCS 12/3'0/70 HEASURED DEPTH TVD SUB SEA 3168 316~.00 3100.00 3270 3.264.00 3200.00 3476 3464,00 3400,00 3580 3564.00 3795 3764,00 3TOO,OO 3904 386, e00 3800,00 TOTAL COOROINATE$ MD-TVO VERT ;CAL LAT[TUOE OEPARTURE DIFFERENCE CORRECTION -300.,0S 1,5.38E , -310.03S 15~.62~ 6 2 -339.58S 197.00E 12 -358.82S 21~.52E 16 -41!-31$ 276,64E 31 -~2,69S 308,92E *0 ~'~4127 4064,00 4000.00 -512,655 377.67E &3 I1 4238 ~164.00 4100,00 -548.09S 411.57E 74 Il 4795 4664.00 4600.00 -727.25S ~906 4764,00 ~700,00 -763.70S 5130 4964,00 4900,00 -838,37S 524~ 5064.00 5000,00 -679.48S 5476 ~64,.00 5200,00 -967 4461 ~364.00 4300,00 -61g.,25S 479,07£ 4572 4464,00 4400,,00 -655,21S $I2,,,02E 577.886 61o.7oe 677,&2E 790.17E 828.23E 902.01E 5592 5~64.00 5300.00 5823 5564.00 5500.00 5939 5664.00 5600.00 -1147o96$ 6170 586, o00 5800,00 6285 5964.00 5900.00 -L285.32S 97 166 228 11 11 11 1.2 INTERPOLAT~_~ V~LILjE$ RADIUS OF CURVATURE HETHOD ATLANTIC RICHFIELD CO D.S.-4 HELL 23-35-11-[5 PAGE 3 PREPARED BY SCS HEASURED DEPTH TVO SUB SEA TOTAL COORDINATES i~O-,TVO LATITUDE DEPARTURE OIFFERENCE CORRECT!DN 6635 6264.00 asea 722! 6764.00 7335 6864.00 7&~g 6e64~ -- ~---7~6~ 7064.00 7676 7164.00 7g03 7364.00 80Z7 7464.OO 8E44 766~.00 8~57 7764.00 8~8X 7964,00 8693 8064.00 9Z52 8~64.00 9~65 8664.00 9S9Z 8e64,00 970~ 8g64.00 6~00.00 6ZO0.OO 6300.00 6S00.00 ~oO~PO 6700.00 6800.00 7000.00 7100.00 7300.00 7400.0O 7~O0~OO~ 7600.00 7700.00 7gOO.Q0 ~OOO.O0 0200.00 ~300.00 8500.00 8600.00 8800.00 6gOO.O0 '1584.855 -168Z,6ZS ~lTZg. ios '1820,8lS -1865.375 -1999.00S -2089.10$ -2221.73S -226S.095: 407 617 6.6 ~ 7~! 16 18 !4 ~ ID ! IR E C T ! 13 N A'L $ U R V E Y PAGE ~ RADXU$ OF CURVATURE METHCfD ATLANTZC RICHFiE:LD CO D.$o-4 NELL 23-15-!1-15 PREPARED BY SCS 12/30/76 ~IE ASUR ED TOT AL CGGRD XNAT ES lqO' TVD YER T X CAL DEPTH TVD SUB SEA LAT ~. TUDE DEPARTURE DZFFEREHCE COR~ECT~ON 0 I R E C T ] 0 N A- L: S U R V E Y PAGE ]. ~-C~LA~LE O__V_ALUES__~R_NON_ S URVEY__PQ.!N.1:S ................................................................................. ... .................... L~. RAD[US OF CURVATURE METHOD ATLANTIC RICHFIELD CCI 0.S.-4 WELL 23-35-11-I. 5 PREPAREO 8Y SCS ].2/30/T0 HEASURED TOTAL COORDINATES ~ HARKER DEPTH TVO SUB SEA LATITUDE DEPARTURE g3LO 86X5.60 931Z 8617,36 8553036 -2522oI~S 1795.40E 9316 8~Z0,90 8~.90 -25Z~,9~S ~795,97E ................... 9320 .... ~A3__~_856.0.43__ 9322 8626.19 8562.!g -2926.625 XT96.82E 9324 8627,96 856~.96 -2527.525 1797oi06 .-~ 9330 8633.26 9334 8636.T9 8572.79 -2532.005 17~8.51E g336 8638,55 8574.55 -253Z.895 1798,79E 9340 8642,09 8578.09 -2534.685 1799.36E 9342 8643.85 8579.85 -2535.585 1799.6~E ............... ~ ~_ 9346 8647.38 8583.38 -2537.375 ~800.20E 9348 8649.15 8585.15 -2538.265 ZSOO,49E 9352 8652,68 8588.68 -25~0.0&$ 9358 8657,98 8593.98 -25~2.745 1801.90E ~ 9360 8659.74 8595074 -2543.64S 1802018E g364 e663.z8 esg~.28 -254s.43$ t802,74G ~ ~366 8665.04 8601.04 -2546.$2S ~003.03E D ! A E C T I C) N A. L 'S 'U R V E Y PAGE I.I~.TE RP_.~LA TED-.~/ALUES..~EQR ~_.I~ON. SURVEY .P OI~N TS ........ TANGENT[AL METHOD ATLANTIC RICHFIELD CO D.S.-~ ~ELL 23-35-I].-15 PREPAREO BY SCS 12/30/70 MEASURED TOTAL COORDINATES .... HARKER OEPTH TVO SUB SEA LATITUDE' OEPARTURE 9370 8662.~1 85'98o41 -2580.08S 1806,25E 9372 8664.18 8600.18 -2580.98S 1806,51E 9376 8667.7! 8603.?~ -2582.79S ~ 9378 8669.47 8605.47 -2583.69S ~i, ~382 8673,00 8609.00 9384 8674.77 86L0.77 -2586.40S 1808,06E ..... 9388 8678.30 86~.30 -2588,20S 'LSOS.S6E q390 8680.07 86~6.07 -2589,~0S BOS 9754 g000.94 _8936.94 ...... ! R E C T ! 0 N A'L' 'S U R V E Y PAGE · ATLANTIC RIC;HF!ELD CID 0,~S.,-4, ~LL'-23-~~--!~5- PR~.PARE~, BY · DEPTH T¥O 9~74 9376 86.73.87 9~8~ ~79.17 9~84 9388 8684.47 TOTAl,. COORe INATES LATITUDE DEPARTURE -2546.606 ~804..16E -ZSSO.aOS !80~.~4E 86!~,64 -255~.70$ ~804,T2E 8616.94 -Z554.3eS ~805.57E 86~0.47 -2S56.~7S ~O6.X3E 8622.~] -~5S7.OTS iS06.~XE l t LOCATED IN THE APPENDIX [~ WFL [~ IPR LOG · UI CALIPER SURVEY [~ VOLAN ~-CURVE DATA [ZI STRATIGRAPHIC HIGH RESOLUTION DIPMETER [~ OTHER: AtlanticRi.chfieldCom'pan~ North Amerig~'~broducing Division · . Alaska Di( Post Offic~ ~ox 360 Anchorage,,Alaska 99501 Telephone 907 277 5637 January 12, 1971 State of Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Attn: Mr. Homer Burrell Subj: Drill Site No. 4-1 (23-35-11-15) Sec. 35, TllN, R15E, UM Dear Sir: Enclosed please find the P-4 report for the subject well on our December operations. Very truly yours, R. D. ~o~nstone Dist. ~lg. Supvr. RDJ:ll Enclosures ~ ~o. ~,-4 STATE/~-r ALASKA RL"v*. OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WKLL W~LI, SUBMIT IN DUPLICATE S A~! N%r~Em~AL ~ODE 2, NAME OF OP~G~,,ATOR Atlantic Richfield Company 3. ADDRESS 0~ OP~TOR ' ' P. 0. Box.. 360~ Anchorage, Alaska 99501 LOCATION OF WEI.L 1327' S & 295' W fr NE cr of Sec. 35, TllN, R15E, UM 50-029-20078 LEASE DESIGNATION AND SERIAL NO. ADL 28324 ? IF INDIA~ ALOTT*E~ OR TRIBE NAME 8. L~IT F.a~R~{ OR LEASE NAME " lOr~d hoe B~y 9 xv~..,L NO 10. ¥~ A_ND POOL, OR. WILDCAT Prudho e Ba,y-Sadlerochit I1. SEC., T., H., M.. (Bo'FroM HOLE oamc-rrv~ Sec. 35, TllN, R15E, UM 12. PE~IT NO. 70-42 REPORT TOTAL DEPTH AT F.2qD OF MONT/-I, CPL~NaES IN ]HOLE SIZE[ CAS{NG AIN-D C~A~E/~TING JOBS INCLUDING DEPTH SET AND VOL~ USED, PER~ORATIONS, TESTS AND RESULTS. FISHING JOB$. JUNK IN HOLE AND SIDE-T1R. ACKED HOLE ~WD ~wY OTm~R SIGNIFICA~ C'aA-W~mS IN HOL~ CONDiTiONS. Spudde. d ~ 6:00 AM 11-27-.7~0. Drld 8-1/2" hole 0' to 1228'. Ran DIL, FDC gamma ray & sonic gamma ray from 1223'. Opened 8-1/2" hole to 17-1/2" from 256-1228' & drld 17-1/2" hole 1228-1250'. Opened 17-1/2" hole to 26" 87-1250', Ran 8 jts 20" 133# K-55 csg on 17 jts 20" 94# H-40 csg w/3 94# slip its. 20" csg landed on 30" head w/shoe ~ 1185'. Top of EC landing collar ~ 892', slip joints ~ 470', 350' &r230'. Ran cementing stinger on 5" drill pipe. Pumped in 450 bbls 68# Ken-Pac. Had 50 bbls clean Ken-Pac returns. Cemented ..2:0" csg ~. 1185'. Mixed 750 sx i:l'Fondu FlyAsh. cmt followed w/280 sx Fondu Neat cement. CIP ~ 12:55-P~-12-4-7Qr Removed 30"~ riser. Installed 20" permafrost head. Ran D-A temperature log & CBL. Installed kill manifold.. Tested Hydril w/1000 psi-OK. Purged choke manifold w/diesel oil, tested manifold w/3500' psi-OK. Tested csg w/750 psi-OK. Tested 20" shoe & formation w/80 psi-OE. Drld 8-1/2" hole 1250-2750'. Ran FDC, DIL & BHC gamma-ray 2750-1185'. Opened 8~1/2" hole to 17-1/2" from 1250-2750'. 13-3/8" csg cemented ~ 2686' Ran 72 jts 13-3/8" 72# N-80 buttress csg to 2686' w/float shoe & fl-oat collar ~ 2605'~,~-stage collar ~ 1251', EC hanger ~ 892'. Pumped in 175 bbls SF-100 packer fluid. Mixed 975 sx 1:1 Fondu. FlyAsh cmt followed w/485 sx Class "G" cmt premixed w/l% TIC. CIP ~ 2:30 PM 12-~-7..q. Opened stage collar @ 1251', circulated SF-100 packer fluid. Second stage cmtd w/300 sx Fondu cmt. C/P ~ 2:00 AM 12-10-70. Tested CSO pipe rams & choke manifold w/5000 psi-Oil. Tested Hydril w/30'0'0'Psi.OK. Tested csg & shoe w/405 psi-OK. Drld 12-1/4" hole 2750-2800'. Ran SS gyro survey 2686-0'. Ran D-A CBL & temperature survey. Drld 12-1/4" hole 2800-7700'. TeSted Hydril w/3000 psi-oK, Tested blind rams & choke manifold w/5000 psi-OK. Drld 12-1/4" hole 7700'9790'. Ran DIL density gamma ray logs 9767-2686', sonic SNP & LL-3 logs. 9-5/8" c~sg ~, 97~_9'.. Ran 33 jts 9-5/8" 47# S00-95 buttress w/open guide shoe & differential collar o'n 65 Jts 9-5/8" 43'5# So0~95 buttress on 80 jts 9-5/8" 40# S00-95 on 44 jts 9-5/8" 47# N-80 buttress on 9-5/8" x 12 hanger. Landed csg in speed head @ 24' KB. Shoe @ 9749', diff collar ~ 9656', stage collars @ 5~66' & 2420'. , Could not break circulation through csg shoe. Dropped bomb & opened stage collar ~ 5966 w/900 psi. C_mtd through stage collar ~..5965' w/430 sx Class "G" cmt premixed w/0.2% D-13 & 1% TIC. Bumped plug & closed stage collar-w/1500 psi. CIP ~ 12:15 PM 12-30-70. Dropped bomb & opened stage c.oll~~~ 2420F ii~g~me~oT2i31~.L ................ 141 ! hereby certify that t .~g~l~tru~ld - - - r~m~ . -~-~...~ N. Dist. Drlg. Supvr. ~AT~ _/--/,2--, - 7/ oil and g~floervatiofl commi~ee ~ythe tom otthe suQc~difl0 monm,~ien otherwime directed. ' ~" * ~ ~Y D~VI$1ON OF OiL AND OAS Atlantic~ ,chfieldCompany North Amer!~-=.', Producing Division Alaska Dist~ Post Offic9 Box 360 Anchorage, Alaska 99501 Telephone 907 277 5637 December 2, 1970 State of Alaska Department of Natural Resources 0il and Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 ATTENTION: Mr. Homer Burrell: Dear Mr. Burrell: Attached please find a P-4 form for Well #1 at Drill Site #4 (23-35-11-15). Very truly yours, C. R. Knowles Senior Drilling Engineer C~/mm Enclosure: Form No. P--4 REV. 9-30-67 STATE OF ALASKA O~L AND GAS CONSERVATION COMMITTEE SCBMIT L~~ DEPLICATE A~IONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS OIL ~ GA8 ~ W£LL~-~ ~ W£LL 0Tfl ER 2. NAME OF OPJ~R~A. TOR Atlantic Richfield Company ~. *~Ess oF OVE~AZOR P. O. Box 360, Anchorage, Alaska 99501 4. LOCATION OF WELL 1327' S & 295' W fr NE cr of Sec. 35, TllN, R15E, UM ~API NL'AiERICA_L CODE 50-029-20078 6 LE.~SE DESiGNA¥ION AND SEEIAL ~'O ADL 28324 7. IF INDIAN, .%~OTTEE C'E TRIBE 8. L~'IT,F.~M OR LEASE N.&ME Prudhoe Bay 9. WELL NO Drill Site #4-1 10. FIELD A-\'D POOL. Oil WILDCA? _Prudhoe Bav-Sadlerochit 11. SEC., T., R., M.. (BO/'TOM HOLE oBJectIVE ~ ~Sec. 35, TllN, R15E, UM 12. PJDRMIT iN~O. 70-42 'i3/REPO~T TOTAL DEq:'/"I-I AT END OF MONTH, CHA~GES IN HOLE SIC. E, CASING A_ND CE/ViENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS. TESTS A/XrD RESULTS. FISHING JOBS, JUNK IN HOLE AND SIDE-T/~ACKED HOLE AlXIDANY OTHER SIGNIFICANT CIiA~GF_.S IN HOL~ CONT)ITIONS. S~udded ~ 6:00 A.M. 11-27-70 Drilled 8-1/2" hole 0' to 895' hereby certify that the foregoi~g'~s true/wand correct ' ' · f I Il NOI£--~e~on o//$ ~o~ i~ ~e~uired for each calen~a~ ~onth, with the Division of ~nes & Minerals by the 15th of the ~.cc~odina mnnth .nl -~ r'h~ ,'~ " · ' August 18, 1~70 ~r. R, 0. Jol~mstone Olstrlct t)rllltag Supervisor Atlantic Richfield :~en¥ Aachorage, Alaska ])~Z~l Dear Sir: P rudhoe # ¥* I In reference to the subject drilling~ location, the Alaska Oepart~nt of Fish .and ~e 'requests Inforn~tlon as to the exact location in regard to the Sagavan 1 rktok R i ver. August I $, 1 Re: ~ Giy DS t4-! (~3-3S-11-1S) Atlint~¢ Richfield Co., Operi~r Dtstrtct i)rt I!~' ~tsor A~lintlc Rt~teld ~ ~irlge, Alas~ 99601 ~r $1r: ~11 mp.Iu and ~. ,alps tn PEq~h~d. A dl:~ectloaal survey ts Xany :rt.~ tn Alaska and their dr~tnage s~~ have ~ clustfied as t~ ~ ~ ~tq ~ it~tt~ ef ~d~s fish. E.a~b elec~t¢ .~ fil~ porsuant to AS 3iI,06,~ and ~e , ~11 ~ call~:tJ.~ file a~ ~ In ~ ~t ,of suspensto~ or atmuWmmt please net~f~ thts off'ice ~'teJy ~n ldvlnce so, that ~e ia~ have a wtt~s present. . . ./ cc': ~t of Fish and Game AtlanticRichfieldCompany North Ame~[, ~ Producing Division Alaska District Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 August 3, 1970 State of Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, Alaska 99S04 I c. C~[~OL 2 CONFER: FILE: _ Attn' Mr. Homer Burrell Gentlemen' Subject' Drill Site #4-1 (23-35-11-15) We are enclosing the Application for Permit to Drill, location plat, and $100 filing fee in connection with the above subject well. Very truly yours, C. R. Knowles, Jr. Senior Drilling Engineer CRK: cs Porto BEV, ~-30-~ SUBMIT IN'FRLI~ AT~ STATE OF ALASKA API 50-029-20078 !970 o~ ,ND ~AS CONS~VA~OU CO~~~ APPLICATION FOR PERMIT TO DRILL~ DEEPE,, N~'b~':'~:JlI~,i~Ci~ ' J~, ~J O~ ~OJ~ DRILL ~ DEEPEN ~ PLUG BA~ ~ ~. T~P~ O~ W~LL W~LL W~LL ~H~ ZONg ZONE 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS O~ OI:rl~L~R "' Box .%0, ~chorage, Alaska 99501 4. LOCATION OF WELL At surface 1327' S & 295'W fr NE cr of Sec 34, TllN, RISE, UM At proposed prod. zone 1320' N ~ 1320' E fr SW cr of Sec 35, TllN, RISE, UM 13, DISTANCE IN MILES AND DIRECT:ON F.'{OM NEAREST TOWN OR POST OFFICE* 360 mi north of Fairbanks 6. LF-.A~E DESIGNATION AND S~tlAL NO. ADL 2 8324 ?. IF INDIAN. A~LOTTEE OR TRIBE NAME 8. UNIT~FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. DS #4-1 (23-35-11-15) 10. FIELD AND POOL, OR WILDCAT ?rudhoe Bay-Sadlerochit Pool I1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 35, TllN..~ RISE, UM 12. 14. BOND INFOIt2VIATION: TYPE Statewide Surety and/or No. Federal Insurance Co. 15. DISTANCE FROM PROPOSED* i16. NO. OF ACRES IN LEA:SE LOCATION TO NEAREST 1 PROPERTY OR LEASE LINE, FT. (Also tO nearest drig, unit, if any) 1320 ' 2560 i , · 18. DISTANCE FROM PROPOSED LOCATION* il9, PROPOSED DEPTH TO NEAREST WELL DRILLING, COMPLETED, ! OR APPLIED FOR, FT. 9498' 1981s, MD C9049' VD) ~o..~ $100,000 NO. ACRES ASSIGNED TO THiS WELL 640 ROTARY OR cABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, GR, etc.} ~. APPROX. DATE WORK WILL START* 74 ' KB 23. P~OPOSED CASING' AND CEMEI~TING PROGRAM SIZE OF HOLE SIZE OF CASrN~ WEIGHT PER FOO~ GRAD~ SETTING DEPTH qL'ANTIT! OF 36" 30" 157.5 B' 11~"' KB Circ 'FOndu rd' surface ~. 26,' 20" 94 & 133 H ~ K 1200' KB'' 280Sx--Ybndu Neat ~ 7S0sx ~o~~ .N'_ ~n~ ..... ~ .......... h 17-1/2" 13-3/8i' "72 ..... 2700"" KB' 1st stage' 625sx ~'onau biyas ~:OII~ , ,,,, ,,,, , , ,, ,,,, , ' i ,. , · · ' "- ~ · '~ " -; I ' 365Sx Class " ~. j ~. .~ ~"., ,~ r~., * :;" } ./.~ 2i ~ 'stage:' "i00SX Fondu Nea~- ri;,,, ,:] , , , -. ' ,.7.~43~5,4~t.~O01~6 J9'~15tii Ktli Itl~ ~.stage: 590~ "G" w/10% gel foli ./~ ,wed ~ 59OSX "G" Neat ~ '~'?~:;" by 2nd stage 340sx "G" w/10% gel 13-3/8" 5000 psi Hydril & Cameron gates w/CSO & DP ramston 13-3/8" csg 20" csg will be fitted w/$ slip its. @ 230', 330', ~ 470'. Well will be directionally drilled below 13-3/8" csg. 20", 2000 psi Hydril on 20" csg Logs ~ TD, DIL & Density GR, TD to surface csg, BHS & GR, LL-3, MLL, SNP & GR run TD to 8950'. No cores.;~ mud log fr surf to TD; cuttings: 10' to Permafrost Top, 30' to 4125', 20' to 640~'~'~gm~r ~o, os~ ~~: z~ ~ ~ ,o dee~n o~ plug ~, give ~ on present p~u~ive zo~ ~d pro~ ~w produ~ive ~. If pro~l is W drill or d~n d~e~ :o~lly,, give pert~ent ~ on ~bsu~a~ ~at~ ~d meas~d ~d ~ue ve~ical dept. Give blo~ut preventer p~gram. 24. I hereby certify that the Forage an& Correct ~Thts space for S~te of/i~ (~/ CONDI~ONS OF ~V~, IF A~: ~ m ~o . See lransmi ttal letter .. .... a.~o~,v- ~. Chai man *~ I..mu~o., ~ Reve~ Side August 13, 1970 RECEIVED gU~ ?' 1970 IDIVI$1ON OF OiL AND GAS WELL Z :(Control Pt) LAT. 70° [6' 0~.~6" LON~. 146° 16' 51.88" X = T 12, 546 ELEV. 25.00 O~iflol G~nd 27 ~ 34 $70: . IIII 26 SCALE: I": 400' CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me 'or under my supervision, and that all dimensions and other details are correct. 'Date SURVEYOR 0 0 N FI D E L' DRILL SITE N-° 4 Located in ; Surveyed for AtlanticRichfieldCompany Surveyed by F.M. LINDSEY I~ ASSOC. LAND 6 HYDROGRAPHIC SURvEYo'RS 2502 West Northern Lights Boulevard Box 4-081 Anchorage Alaska CHECK LIST FOR NEW WELL PERMITS Company 'Lease & Well No..z:),m. Yes NO Remarks · Is well to be located in a defined pool ................. 2. Do statewide rules apply ........................ - !3 Is a registered survey plat attached * ~- · · · · · · · · · · · · · · · 4. Is well located proper distance from property line ........... 5.'~..[ th r we1 is '. s well located proper distance from o e ........... . 6. Is sufficient undedjcated acreage available tn this pool . ....... 7. Is well to be de a~'. ....... '. ': ~ 8 Is ope ator the on affec e a ":" '- ' g. Can pemtt be approv~ before ten-day wat~-~::~-::'~:-.:~:. .......... 10. Does operator have a bond tn force . ."~*.:. '.":;~ :-;~';':--:;-'~":-,::~ ,' 11. Is conductor strtng p~vtded ...... .... , , .~ Is enough cement us~ to circulate on conductor and surface , . . . '~ill cement tie in surface and tnte~ediate or pr°duction strtngs 14.N111 cement cover all possible productive horizOns '',".-- 15.N111 surface castng cover all fresh water zones . . . , ......... 16.Will surface csg. in~rnal burst equal .5 psi/ft· to next string 17.~11 all casing g~ve adequate safety in collapse and tension . ..... 18.Does BOPE have sufficient pressure rating ............... Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this · nature is accumulated at the end of the file under APPENDIXi .. No 'special*effort has been made to chronologically organize this category of information. Company LIBRARY TAPE CURVE SPECIFICATIONS ARCO Alaska. Inc. Well D.S. 4-1 ~ ECC,~ 2075 Field Prudhoe Bay Counuy, S:aue Noruh Slope, A!~ska Date 11/18/84 DELIVERY DATE 6/15/87 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale .' '' Fi!es~ 1-3 t " CN - Mui:is=ace , CCL Casing Collar Locator -*--' I: " t CN Compensated Neutron ~ ' 60 - 0 , SSN Shorn Soace " 50 - 550 LSN Long Space I " 0 - 200 GR Gamma Ray- " 0 - 100, 100 - 200 File 4 .I I '' ~ I CNAV Average CN t ". 1 6o-o .: I I. I .! l * REEL MERCER ** EEL N:iNE : ~ :E : ...... · RIGIN : FSYS ~RV z:cE ' N~-~ :' ...... EEL CONTiNU~TZOk NUMBER: 01 ~:EVIOuS EEL NAME - OMMENTS: DRESSER ATLAS LIS CUSTOMER T~: --- CREATED BY SDS PROGRAM R 2.0 APE N&ME : qlGIN : FSYS ~PE CONTINUATION NUMSER: 01 DNMENTS: FILE HE~,DER # 1 ** ~RVICE NAME' ITE: 85II!/20 [LE TYPE: LO MNEM CONTEN'TS UNITS :~ ~i~'i~ i: ~:~: ~f ~::~:~: :~:~i::~::~:: ~::~:~: :~: ::::::::::::::::::::::: i: ::~i:~::~ ::~: i:~::i:~ !::: ~:~:7:~f::~::~::f~:::~ ~::~: :~::~ ~::: :~:: ::::~::::: :::~:: ::::::::: ~::: :::~:: :;;: ~ ~: ::~:~:~::~:~ :~:~::~ ~::~:~::~:f:~: APZN : 50029~0078 W N : D. S, 4 - 1 COUN · N SLOPE LCC : 150.00 ~ FORMAT ,i~ 8 60. u F RAthE SrACTN~ 1 4~ MAXZMUN FRA~S/RECORD -0.500 LEVEL SP~:CING ,TUN SPECIFICATION ~L'3CKS '~!.1;: , COZ=_'' !I!: 'S ~ r,,' ,c t ;2 SN ;. :- .4 I ~ 68 4 I ~ kFORN&T ** ~PE EN~qv ~ ~PTiON , . .... .~q~ 4 1 2~PTHS 9 .1tN ;RA~ SPACING UNITS 0 TERMINATOR iME CODE SiZE SAMPLE UNITS ~ N 68 4- 1 C ,~ S ] 6 8 4 ,5 8 4 :PTH 9735.000 ;N 60.994 FT ,t ~4,4'z7 :i~ :~::~:~:~:>~::~:: ;i~;;;!~;:¢!:~¢:~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::: ::*.!;:~: :::::::::::::::::::::: ::::::::::::::::::::::: [PTH 9~00.000 ~T 2926.0856 N ~:~,:~f~ :~?~ ~::~.~2:~::~`~?~.~::~:~::`~::?~:~:~::~:~:~:~:::4~:~:~:::::~.~:~:~:~:~::::~:~.:~:::~::~:`~1::J~:::f~;~:~::~::~:.~::::~:::;~::~:~:~:`::~:~:~:~:~::::~:~:~::.:~:~::f:J~:~:~:~:~:~:::~:~:~::~::~:::~::~::~:::~.::::~J~::~::~:~::~?:~:~?;?~:~?:2;~T:;?~?2?2~J::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:~:~FJ:;:;:L:~::~:;:;:~F:??:;.~?~:~?x:~:~:4? 24~ 557 SSN 4~6 302 GR ~7,69'g CCL -2u4~.000 t 9.51 2 ~ ;;~ ~:::~ ~ ¢;: ~: ~ ~¢ ~¢~ ~ ~ 1 :;~ :~; ~ ::i: i :~ :~::: ;~ ~: :::~; ~: ~: ~ ~;; :; :~ :¢::;: ~: ?~;:: ~ :~ :~:¢:~ ::~: ~::::.: ::¢:~:; ~: ~: ~:~; ;:: ~ ~ :;(:;-~; ~ ~:~;: ~ ~::~: ;:i:: ! %: ::;~:: ~ :~::; :~:; ~:~ :;~:~;¢ :~;~ .;::~¢::;; ~;~::~ :~:::% :;~:; ~::;;: :: ~:: :;~:¢::~; :~:: ~ ~: :~ ~ :~ ~ .(:;:~: ~ ~ :,:~ :~: ?::~;':~::~: :~::::~: :: :: ~: :: .: ::'~ :7:: ~:: :.~ :::: ::~ :;?;~: ~::~::: ; '~: ~::~¢::::~: ~:::~:¢:;:::~::;;¢ ~ ~ :~ ¢:~::E~;~: ~ ~ 'PTH 940~.0~0 FT 2865.126C M ~::: ~:~ ~8:~ ~¢~;;~;~¢~;~:~:~¢~::~;~;~:~:~;:~:~;~;;:~:~.~::;~:¢:~::::~:~:~:~;¢~::~:~:~.~;~::;~;~:~:~::~:~::~::~.~:¢~:~::~:::~:~:::~::::~:::~;~¢~:~::~::~;~::~;~::~:~.~:~:¢:~t:~::::~:~::::~::;:~:~:~:::~:::~::::;~:..:::::¢:::~:::::::::~:~.:;~::~;:~: ::;:::~::: ::~:: ::::~ :::::::::::::::::::::::::::::::::::::::: N 364 546 ~SN ~06 x.:~7 ~¢R 25 3~ COL -2 8.000 ~!!~:~ ~'::: ?;~: ~;::¢;:~¢:~:~: :~;:~¢~;~:~;:!~¢;:~:~::~:~::~:~:~:~i:¢~:~:~::J:~::;:'¢~::~ ~:~;:!;~:;~::~'~::~:~:~::: ::~: ::~: :~:~ ~:¢~: :¢:~::: ::::::::::::::::::::::::: :~:: ::::::~ ::: ::::: ::~; ::;~:::~t: ::: ;'~:::; :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :~:: ::::::::::::::::::::: , 9.0 6 4 E P T ~, 9' Z S 7. :.5 O C N 1 C:. 1 ~6 T'&R ~.N~ D.:PTh : 9735.000 FT 2.,6, 43 N *: FiLE TRAILER ** iLE NAME: P~SS 1.001 _ ¢"~-- , ~': ~ - ERVi~_ N~ME, ERSiON ~ : ! ~TE: 8~/11 / &XiMUM LENST~,: 1.,324 [LE TYP:: :Lc EXT FiL: NA~E: ILE NAME: PASS 2.001 =RSION ~ : I &X RECORD LENGTH' 1024 BYTES REVIOUS FILE NA~E: * iNFORMATICN RECORDS CN : ARCO ALAS FN : PRUOHOE STAT : ALAS:K~ ENTRY BLOCKS ENTRY DESCRIPTION I OEPTHS DECREASE .lIN FRAPE SPACING UNITS TERMINATOR ~'~:~:~:t'~: f~:~:~ ¢::~::~ ~::;~:~Y~ f~:~:?:~:::¢:~:~:::'~:¢::~¢ ~:~ ~:~:f~::~:;¢:::~:~:~: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :: :::~:;~:: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::: I 6 8 4 I ENTRY 7LOCKS CDE ENTRY DESCRIPTION iii 4 I CEPTHS DECREASE 8 6~.0 ~APE S:~CiNG 9 .lIN FR~E SP~CING-UNITS 11 42 ~XiMUM F~AMES/~ECOR~ TE, RMIN~,TOR - -m'~. 50P~ L~VEL_ So&CINc~ -~, ITUM SoECIF!C~TICN ~LCCKS JRVE ~[~R CPS ;L 68 4 I DIM ~1 31.6,88 iPTH 9700.C00 ~N 52.027 -5 00,¢ I 45 .C'43 !PTH 9500,000 FT 2895.606C M J:~::i~:~:~:~:~:;~:~::~:~::~:~:~ ~:~:~:~:~T~:~'~::~:~ ::~:: ;:;:::¢:;~:::~::~::~::: :: %:.:::;::::(:::; ::::::::::::::::::::::::::::::::: ::;':::~: ;N 58.691 SSN 217.529 GR 19.732 CCL -5.000 !9.696 PTH 9300.000 FT 2834.646C M ~:~:~:¢:~;~:~ !~:~:~ ~ ~¢~::~i?f:::i;~:¢;~:~:¢;':~:~i~%:¢~::~::~::!;~:::~::~¢;::::~::;:;:7~ ~:~::~ ;~:¢ :::; ~¢ ~¢~::; ::; ~;::~::~;::~:; :::~ ::~ :::::::::::::::::::::::::: ::~: ~:::~::; :::::::::::::::::::::: ;~;::~::: N 64.520 SSN 219.152 GR 78.679 ARTZNG DEPT~ = 9712,000 FT 2960.2240 M FiLE TRAILER ZLE NAME: R$SS E'RVICE ERS~CN. ~ : I ~TE: 85/11t ,~:XIMUM LENGTH: 1024 iLE TYPE: LC EXT PILE N~YE: FILE ~E~.DER ~:L'E N A M E: ""P:~'~S S' 3':-:00'1 =RVICE NA~E: .RSION 1 ~TE: 85/11 R ECO .,O [LE TYPE: LC MNEM CONTENTS UNITS APlN : 5002920C78 WN : D.S. 4-1 COUN : N SLCm.E LCC : 150.0 8 6~.0 ~:R~ME SPACING 1 /,2 ~v~ ,~, X ~ M UI'4 FR~MES/RECORiD ~i,~::J!i!:Ji:i:ii::.;!::::!:,,~: ::::!::::~:J:~: :~J ~::~::~:J: ::.~ ~ ~:,.~J~,~:J:~:::~:~;~~cF~:~E~:~J:~:~ ::J::~::J ~,~ ~'~:~:~J~J:~::,~E:~J::?:.:~:~:,J:J~:JJ?J:~i~::,~ ::~:~:%~J~!(:J~: J.~::J::?:J ::3 ::~:_ ~:~:,~J:~.~:::~:::~:.~:~: ~Z:;~:J~..::]~:~::~ :J~::;~;J ~:;J:: :?,, :::~:::~:J~,::J:~ ::.?~?:J:J;~:~:::?::~:~?:J: ~J :~J~:(::~ :i ::~: ~::::~:?~::J~::J~:~:~:E ~ :::~ ~ ::~:::~::::~ :~(:::.~:J~ ?:J::J: ~:::~J:;~::~:~:~:J:~J:(:~ :J:~J;~J;; ::~,~:::~:J:~: ::::::::::::::::::::::::::: :~(::;~:::J~::J:~::J :J; ~::J~::~::J: ::::::::::::::::::::::: ~;J:::;~:? :?JJ~J:,:::J ?:?J:~?J~J:.C:: :~ ::~::::::~::~2 :~: :J:::.)?:~::~::;::JZz::J:::J~::~:J:~:J;.:,J':J:J~:E:E:~::: -O.cO0 LEVEL SP~CiNG ,TUM SPECIF!C~TiON BLOCKS ~RV; ~E'PR ~;N~:~:~: ~:~:~:E~ ~$ ~:~:~;~:~:~:~:~:::$:~::~ ~:~:~!:$~:~:~ ~::~: :~:: ~:~:~$: :~i :~:~:~::~::~:~ ::: :~:~ ~:~ ~:?,~ N 68 4 1 CPS L 6 8 4 I g, I M T C K mN. RY g~LO S ~f:~E~?:~:~:E~:~:~::~:~.~ ~;~:~;~::~:~:~E~::~:~:::~ ~:~;: ::~::::E:::~::~: :::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~:~:~:: ~:: ~::}:~: :~:~ ::::::::::::::::::::::::::::::: ::~:~::~::: ::~:: E:::~:::: ::::::::::::::::::::::::::: :~:~:: ~:Y::~::~: ~:::4E::~: :~ :::~:~:::~::: ~:::~:~: :;~:: ::~:'~::~: :::::::::::::::::::::: :~:::~::~: :;~ ::~::~:~: :::::::::::::::::::::::::::: :::~:~::~:: ::~: :~: ::: ::~: ::~:~: ?:} :::~ ::: :~::~ :::: ::~:: :: E:~}: :~::~:: :~::: :: ::: ::: :::~:~ ::: ~: ~:: :::::::::::::::::::::::::::::::::::: ~::~: :;~:~:f:~:~:~E~Ef;~:-~: PE ENTRY BESCRIPTZON SN 6 8 ~ -' I C P S 5._L ................ _5_8 ....4___ ~ 1': ': OZM :PTH 9713.C03 FT 2',~03.528t3 M ~N 67,993 SSN 19t.981 GR 35.624 CCL -5.000 34.3!9 :PTH 9600.C00 FT ~926.C~)6C M 50 :PTkl 9400.G00 ~T 129.352; SSN ?92.499 GR 25,129 CCL -4,000 33.359 ~PTH 928t . 500 FT 28Z9. 007C ~4 :~:~; ;~:,:~ :~: ~ ¢~ ~:~ :~: ~¢~ ~' ~ ~ ~;~ :;(~ ;~; ~: ~ :~ ~:: ~; ¢~ ;::{: ~ ;: ~ :~ ;: ? ~: ~ :: ~:;:; ~;:: ~: :¢; :~ Y { :~ ::: ¢' ~::~ ::;~ t:: :~:;; :: ::: t:, :¢: :~: :: ~ :~ ~;:: :~:: ~:~: :~: ;:: ;: :~ Y ~ ~: ': ::;: ;; ::~. :: ;~ :~: :¢:; ::;: );; ::~ ::; :: f:;:: :: ;:: ~:: ~ :~: ~ ::~:: ~: ~ :: ~: :: :J~ :~: :: ;:: :;:~: ~:: ::: ::.: :: ~:: :~ :~ ::: ;:: ~; :: ~ :: ;~ :: ~':;:: ~: ~:: ;; :: ~ :; :( :~:: :~: :: ~ :: ~ :~ ;::;:: ~; :~:: ~ :~: ~;: ~ :~: (: :: ~:: ~: ::; :: ~;: :~: ~: :~: :~:: ~ ~ ::;:: ;:.~: :: ~:: ~:, :~:: :; :~: ::: ~:: :~: :: :: ~:~: ::: ::; ::~:::; :: ~::: :~:: ::,; ::~ ::;:;:: :: ~:::;; :: :~¢ ::;: :: ::: ~: ::: ;: :: ;: ::: :( :; ;?: ~ :~ ;::; :: ~ :: :: ::: ::: :~: ~ :~ :;~ ~ :~ :~:: ¢.:; :: :4 ::::: :; :: ¢:: ~;:::: ::;~ :~ ::;t;;: Y: ~ :~ :: ~ :: ~: 'N 6, a 8n5 SSN >17 127 GR ~4 59C CCL -~ 000 L~ NAME: P~S~.~ ~., '~ 00! RSION '~ ~' : 1 XIMUM LENGTH,' 1024 XT FILE NAu!~: , I'L~-. NA~4':-: PASt.. 4 . ..,n"~l~, ERSiCN ~ : t ~,TE: 85/11/20 AX RECO~c~ L=NST~: 1024 SYTES ILE TYPE: LC REVIOUS =iL~ NA~=: . * iNFORMaTION RECORDS ** --. CONTENTS '- UNITS CN : ARCO ALASKA IN" , ·: . :~;: .: : :;.,- .... FN : PPUDHOE BAY STAT : ALASKA ENTRY BLOCKS fPE ENTRY CESCRiPTION 4 I DEPTH 9 .lIN FRAME 0 T E R N I 1ME CODE S'IZE SAMPLE UNITS ~ :::~: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::~:: :i~::: ::::::::::::::::::::::::~::::~:~:~::i: ::~: ::i'::~:: ::'::~i?:;:::: :: ~ :; ::::i:;:;::: :i; :L ;:~:dJ :::::::::::::::::::::::::::::: ;N 68 4 I CPS ~ ~ )~: ~ ~ )~i :)~ ~ 4::~:: ~ ~:: ~: ~: ~: ~: ~: ~: ~ ~:~ ~ :: ~ ~: ~ ~ ~ :~: ~ :~ ~ ~ ~ :)~ ~ ~ ~:~: ~.~ ~ ~ ~ ~ ~: ~ ~: ~ ~ :~ ~:~:: ~::~:~: ~ :~ ~} ~: ~: ~:: ~ ~ S:~t ~:~ :~ ? :: ~::}~ ~: ~ ~)~:~):~: ~: ~:~%f~: ~: ~:: ~ ~ ~: ::: ~ :~: :~ :¢ ~ ~ :: ~ '~ :~: ~i S:: ~: ):: :~: :: :~: !: ~::: ~}~:: ~: :~':: '::: !: :~ :: ~:: ~: :f' :: ~: ~:: '~: }~: ?: ~::: }: ~: :~ :: '.: ~:: ~: ::!:: t::: :::'~:: ~: ~'}: :~ :: ~:: ::~: ~: ~:: ~ ::~: :::: :: ~ :: :~: ::!~:~:~: ::~:: :~: ~ ::~ ::~: ~: :: ~:: ~: ~: ~: ::~ :~ ?:~: ::: ~ :: ~ :~ ::~:: :::::: ': ~:: T: ::: :: .:::: ~ :::~: ~ :: }:: :~:: ~:: :::, :~: :~ :?::: ~:::: ::: :~: :::: ~' :% :: :: :: '~:: ~:::: ~ ~:~:: ~:: :~ ::': :: ::: :~ :)~: ::~: :: ~'::: ~:: :? ~:~: :t:::: :',: ~:: ~.:: :~}: ~,: ::~:: :~ :~ ~ ~ FORH~T ~.v FRAF~ SPhCZNG -Li.~C:L;.. LEVE~,. ..<PhriNG TUM SPE,ZIFZCAT~ON EL©CKS it;,: V E R E ? q N 58 4 1 * DATA ** ~'PTM 9714 .,~uO *'T 2900.8230 N 2~.229 ',t 4.4 1~ ~PTb 9500.C~0 ~N 82,~76 ~T 2~ ''''' '~ ..... Y ...... 606C M SSN 215.526 22 488 CCL 5 ~ 15,834 :PTh 9300,0130 ~N .x, ~ 9 6 4 FT -4,0O0 FILE TR~.ILE~ RViCE NAME :~¢~:: TE: 85/1 LE TYP5: LO :;:~:b:,.~:;;2~b ,,~.~47 ~;~: XT TAP~ REEL TRalLEm ** =EL N'~M=' --RViCE NAV.!E: 51TLiS ~iGIN 0= C~T&: FSYS ~EL CONTINU/~TION # : 01 =XT R;'-EL N~,~E: )MMENTS. DRESSER ATLAS CI'S CUSTOMER TAP~ CREATED BY SDS PROGRAM R 2.0 z~ .L HE~DE~ - I [LE ~E~CE-~ - ~;-FORMATION - 4 ................... :)RMZ~T - ~SLE SUup - ~P~ TRAILER - 1 Company Well LIBRARY TAPE CURVE SPECIFICATIONS ARCO ALASKA, INC. D.S. # 4-1 S.O. # 25271 ECC # 1965 R ECEI VED ~not~orage Field PRUDHOE BAY County, State NORTH SLOPE, ALASKA Date 5/6/84 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale CN1 COMPENSATED NEUTRON PASS 1 LSN1 LONG SPACED NEUTRON " SSN1 SHORT SPACED NEUTRON " GR1 GAMMA RAY " CCL1 CASING COLLOR LOCATOR " CN2 COMPENSATED NEUTRON PASS 2 LSN2 LONG SPACED NEUTRON SSN2 SHORT SPACED NEUTRON " " GR2 GAMMA RAY " " CCL2 CASING COLLAR LOCATOR " " CN/MSN 1! 60 - 0 0 - 200 70 - 570 0-100, 100-200 0 - -30 60 - 0 0 - 200 70 - 570 0-100, 100-200 0 - -30 CNAV ,~ COMPENSATED NEUTRON AVERAGE 60 - 0 -'i, .~ CurVES ,lB CN~V NORTa SLOD~ ~LASK& (Ot4 ,c1~,8.0C TO ~72~'.00 3.t,.T E: 5 / 1~ / :.,:,, TIME' ,~,..'"~, ALAqK~. :_NC, t.S. ~,-1 PRLJ~Oz E~Y :~ C ~ T JA~.L:- TO LOG ~'P T H GR1 GR2 LSN1 LSN2 SSNt SSN2 CN1 CN2, CNAV ~ 9199 0 t~7 !3 S' 2& 3 O O I.~=¢ ~ 0 O $1 2 ~0 5' i · · · · · · · ' · i ~ .... S5.3 ~7 5 9203. C'. 1 ..' · 9205. O. 159. 0.3 2,~,.0 C.C 140.2 0.0 7~.3 36.1 ~' ........c :~:::~:~:~:~:~:~:~::~:~:~::~:. ......... ~?p..~:~:~!. :::::::::::::::::::::::::::::::::::::::::::: ::%:: ~:~:~. ~:~::~,~'.~ ~z~:~;~5.. ~,~c~'~ ~ '~{~j ~' ~?'.:~;~ ..:~i. 9207, O. 133· 0.0 30,1 O.O 150.3 0.0 62.6 36.4 9209. 0. 123. 0.0 ~6.5 0.0 1~~.~.1 ,3 O. 7~.~ 36.5 9211, O. 91, O,O 32,6 0,~ 171,9 0,0 ?0,~ 79,6 · ....... ........... ,921~, O, 1~, 0,0 2~,5 0,0 150,1 0,0 65,9 31.8 9215, O. 130, 0,0 27,& 0.0 144,6 0.0 70,9 28,9 9217 9219' 9221. O. 114. 9223· O. !0;?. ~225 0 t 04 :~227. 0. 1t9. O.0 24.6 0.0 t35.1 0.0 77.5 38.2 ~229. 0. 151. 0.0 25.0 0.0 135.5 O.0 75.7 33.0 9231. O, 147. O,O 25,3 O,O 135.7 0.0 '73.~ 35.4 9233 n 134 0 O ~'~ 1 0 O 142 5 0 n 5~ 2 33 ~235. 3. 139. 0.~ 25.3 O,O t38.8 3,0 77.~ 3~.1 9237 O 130 0.0 ~5.t 0 3 130 5 0 0 6~ 4 ~ 0 ~9"'~ ....... 'i'~: 9'~' ~¥ '.:?.' '~~:~:~.~ ............ ~; ~ ~aa~ ~;~;~;~~;~ ~:~:~ ~a~:;~;~:,:~ ~ ~ ~;~.~ :~zs~ ~ ~,~.~:~:.~:~ ~:~z~:~ ~ ~;~ ~:~ ':::'.:.:,: '.~.'..... '..~'..? .' .', .'.' ,.' .' ". .............. '.: 9239, O, 117· 0,0 27,0 0,0 14~,3 0,0 55,9 41,2 ~[~1, O, 16~. .~,.~ ~,1 O,u 1~.~ ~.,-~ o~,v ~,~ 9243, O, 135, ~,0 2'~,0 0,0 146,7 0,0 64,3 39,3 9245, O, l~P, 0 3 P3 5 O,O t32,~ O,~ ' . _ ...... ,~ 8t.o 4o PRUDdO= ~Y 9:~1:27 4-1 ~UN .3N 5-4-34 ~'1;1. 9. 177. 3.:'''~ '~.* ~* ;" 14':, .... .... ,,~..., · ~-.'~::. :~,. ::~: ~<:: /BtCj~:?*: : i, ;U' ======================================================== ::i .~'::~::~:~:::*//¢~:¢~:~'t¢4 ~' ::ES~~ .t?t~:~;~: ~:~:..~a '~2*~ * 115. 3 0 l'~ ;S ~ n 143 * " , , .., .... , .... ,.., .... ..... ~.0 5:~.~ 37.0 9255. O. 132. 3.0 Z3.9 0.0 134.~ O.O 82.e 38,6 ~::~;: ::::::::::::::::::::: ;:: ~: ~:::.:::: ~;:::t::~: :~:~:::;~::?~:~; ~::::~:;;:S::::~;:::';:~:~8::::~,~ :~:~:~::~:~;~::~;~ ~ 9a5~ '~ 147 3 O :'4 7 ~" . ....... _ . :,~.0 13¢.,¢ 0.0 7:~.5 37.4 925~. O. 135. 9.9 ~4,_ .7 0 . O 135 . ~, ~ n~. ~, 77 .9 ¢~3.0 ,~261. O. !51. O.O 76.0 0~,131.4 0.0 6~.0 34.6 ~263. O. 171. 0.0 75.3 :3,0 !35.7 O.O 73.6 50.0 9267. O. 152. ~27t, O, 139. 9273. O. 144, ':9175. O. 117. 0.0 £'7.5 0.0 145.7 0.0 71.S 9279. 11!. 118. 25,5 28.5 142.8 144.5 63.1 6.4.1 65.5 }281. !12. toa. 25.s 28.3 141.5 140.7 70,5 ~2a, 3 113 t08 27 7 '2'~ '~ 141 0 141 I 54 7 63 ~285. 9~.. 's2.. 25.6 .~7 . c,,~!47 .6 !4:*. 4~, ,****,. c, 72' . '~. **,**. 4 ~87. !1!. 101. 23.~ ZT.S 1~!.~ 14~.5100.0 ..... ~. ~{~ .,.,. ~,~!m~?~m~,~-~,,~ ~ ~ ~ ~ m~,~ .............. ...... ~E89. 110 '~. ~3.4 ~7.1 1~ :5 135.~ '~ I 6 )291. !05. 107. 23.5 25.3 132,5 !35.'? 82.9 57.0 67.9 ~l~~ 96 t~0. 2:~ I :~6. ~ "~ u ,~. :. ~ t35 ~ t~ .~ 67.7 SS,, t 65 6 ~EPTM GR1 GR2 LSN1 L$N2 S$N! SSN2 CN! CN2 2NAV 9295, 10~. c, 2. '27.0 92~~-~, 95, ':'5, 35,! 51,! 1S?,? 23t.! '=,7,1 '4~,5 35.4 ~301 ~'7 53 ~7.7 5'~ 9 202 1 2-35 ::,::.::::: ~:t: :: ::,~:::: ::::::::::::::::::::::::: ~:~'.~;~~$~X::~:~;~ ~303, 35. 50. 07,2 ~:3.5 222,3 223,.5 37.! 35,~ 34,0 9305 52 55. 5~ ~ ~o & 217.9 21~ 9307 51 40 ~4 4 :~' ~ ~7 7 ...... ~, 5 :~73 4 243 · ~ ~, i i '.~ ~ m ~_ I ,9~99. 3S 41. 8~.0 7C,.~ ='~4n.¢~ '*~31.~ 28.3 ~.'~.¢~ 27,_, 9 . ~ I . ~ ,~, I ~ . m 9311· 4~. :36. ¢~.5 ~¢.} '23~¢.7 247.'2 26.1 ~6.3 24.~ 9313, 33. 32, 931 5. 9317. 43. 44. 9319. 41. 34. 932! .......... . .... _ ,~.~4 :3 ~'6 I ?? 4 :~ , ~... .. .~..~.~'~:i'..'~T~'~:~Z~?~3~*~i~ · ~.. .... ~ .............. ~ ............. ~.~ ~325. 2S. 33. ~;~2.~ 75.5 27.3.9 221.3 27.~ 2~.3 2'~.0 / 93~7, 39, 33, 7~.4 77,2 72¢,9 2'34,.5 30,1 ,'~9,4 29,3 932~, 2'. 25, 81.7 5'~,8 229.3 22!,5 -~6.5 31,2 29,0 ..... · .... ~ ....... :~ ~m~ ......... ~s~m..~:$r$~% .~m~ ..~ ..... ~::...~ ..... -:.~ ..... ~,31.,,.,, ~,~,,~. ,.~,.. 73.~,. 70.1 ,~1_ .7 .~13.~,. =~. .n~ 30.5 35. :;". .... ~,,..X,. :~%!~!i~':~;;~;~;¥¢$;(.. ~,; '$:;~$~:~,. ;~. ;~!~(;~' .,~lji ~ ~$ ................ ~'¢~'¢ ............... ¢ '~335. 54. 56. 5~.4 4~.~ tgZ.Z !:~0.~ '37.4 37.o ~. ¢~ ~,:~ .... ¢~¢ $~., ..... ...... ~ '~i~:. .. ~.. . .<.~:~:~ ~335. 4~.,. 37. .,,~5.5 ~..9 ~PC5.t ~09.3,_ 39.~. -,.~.6 ~337. 2~. 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'711 33 30, 54,6 57,a 19~ 2 202,1 x~.~ 2 '~ ~:~ :~::~:~;~:~~:~:~:~::~::`~`~:~5~:~:~:~:~~ ..... ~ ~ .~.. ~ ~ ................ ~ ¢713, 33, 30, 54,;~ 57,9 202,8 200,7 39,0 35,4 37,2 ..... .....¢~ ......... .:~ ........ ;~ ...... ......,. ~~$~,,. ..............~.~,:. . ................ .-,.. ....... .~~ ....... ..¢¢~ ......... ~, '¢715, 33, 30, 55,1 55,~ ~05.1 200.0 35,X 35,1 35,7 ~717 3~ ~0 r7 .~ 58 3 199 5 20'~ n-45 1 35 1 ~5 1 ;719. 33, O. 57.9 O.C 20t,3 O.O ;5.5 ,3,0 17,8 ~721, 33, O, 58.0 O,O 201,0 O,O 35,4 O,O 17,7 .................................................................. . ~72'~.~ 3x.,. O. ,5~,0,~ O,O 201,~ 0,0 55,4 0.0 !7.7 LI-= :x>-.r.Y Cs--party ARCO ALASKA, INC. D.S. # 4-1 Field PRUDHOE BAY State NORTH SLOPE, ALASKA S. O. # 90312 ECC # 1888 PAGE 1 of 2 PAGES e6c£1V£O 12-5-83 THIS TAPE CONTAINS 2 FILES CN4 NOT USED TO COMPUTE CN AVERAGE I LSN1 I LONG SPACED DETECTOR PASS 1 CN:MSN 0 - 200 I SSN1 i SHORT SPACED DETECTOR PASS 1 t CN:MSN t 50 - 550 , I N:M N t - 0 i LSN2 i LONG SPACED DETECTOR PASS 2 CN:MSN 0 - 200 I SSN2 [ SHORT SPACED DETECTOR PASS 2 CN:MSN 50 - 550 t CN2 t CONPENSATED NEUTRON PASS 2 CN:MSN I 60 - 0 CN:MSN I -30 - 0 , . , CN:MSN I 0 - 200 I CCL2 ] CASING COLLAR LOCATOR PASS 2 CN3 GR3 CCL3 LSN4 SSN4 CN4 CN:MSN [ 50 - 550 COMPENSATED NEUTRON GAMMA RAY CASING COLLAR LOCATOR LONG SPACED DETECTOR PASS 3 I PASS 3 i SHORT SPACED DETECTOR PASS 3 I PASS 4 i CN:MSN t 60 - 0 CN:MSN I 0-100, 100-200 PASS 4 I CN:MNS -30 - 0 CN:MSN [ 0 - 200 CN:MSN I 50 - 550 COMPENSATED NEUTRON PASS 4 CN:MSN I 60 - 0 S.O. ~; 90312 ECC f/ 1888 PAGE 2 of 2 PAGES ARCO ALASKA, INC. PRUDHOE BAY State NORTH SLOPE, ALASKA Date 12-5-83 THIS TAPE CONTAINS 2 FILES CN4 NOT USED TO COMPUTE CN AVERAGE ('~-ev. .) .ct~n~-rf~ ~= Cu.--ye Ka~e Lo~$ l~ed_ Scale ~ GR~ G~ RAY PASS ~ C~:HS~ 0-100, 100-200 CCL4 iCASING COLLAR LOCATOR PASS 4 CN:MSN -30 - 0 CNAV 60 - 0 iCOMPENSATED NEUTRON AVERAGE / :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::8:: ~:~ i: !~1!: :~{: ~: ::!~/: ~ 1i[~ ii ~I ~ ~ ~ ~?~ ~:~t i iii~i:~{ ~Y~i :: ~i::;~ i;~:: ~ :~: ~ ~ y ~i~j{ ~ ~ ~ :i: ~ ~( :~: ~ ~ ~ :ii~ 7 ~ ~i f:~i~: ~t, ::~{, :{~ ~: ~; ~: f~; ?~: ~ i ~$~, ~'i i~ :~:~: ~ ~: i; ~ ;:: ~: ~ ~, ~:: ~ ~;~ ~: ~ :~t ?~: ?i iI~:~ i~: ~i)~: ~ :: ~: t~: ~: ~ :~ ~ ~: ~ :i ~.~i~:: ~ ~ ~ :: i~ :: :~i ~i~ ~ ~: ?Pi: i(: :i;~: :Y ::~' :~:: ~,: ~: ~ ::'~ t~ ~ :~: ~I ~ :~iY: ~ :i :: ::~$: ~:::~ :~ ~ ~: ~ :: :~: } :: ~ ~ :~ ~: 1~: :i~::;~: ~ $ :~::~ ::: (~: :~;;:~ ~ ::: ~: ~: ~:: ~: z,~ ::: ~ :: ~::: i:: ~:~:: ~ ::{J~ :: ~:~ ::: ~: ~: t: ~ ~ ¥: :~ :~ ~i~: t~ ;~: ~:: ~: ~ :¥ 4t~ ~ t;( ~ ~ ~: ~??~ i i ~: ~: :p:: :: ~ ~:: :~ :: ~; :: ~: y:: ~:: ~ :: ~: :(:: ~:: '~: i: ~b: :~: :$ ~: ~: ~:: ~ · :. :~ ,., ,..,:....,., .., ...., .., .:...........~. ~, .:....: .,. .. . .,. ,. ,..:x~..,.~.~., .......... ,,.,, ......~ .~...~. ,.~.,..,...~ .....: ....:....~.,...~.... ,,...: .. ~ .~.......... :... ,....:...,......,..,..,. ,.. .,.....,.... , :.., ~..., .,~,... ,. ~, .s~: ,: .,, ,,., ~.,. ~ ,., .~,..,: .,.,,., ,..:......~.: .x ..-..., ,.-.. · · .,t~... ,..: :..~.:... ~ ~ ~?~:X:S{S::S~: S:::S~'~eX $~5~::~a~: ~X~:~:~:s:}~: s~::~,:::.s:s~X:~::~:~ ~:S :~:: :x~,a::~: X: :~:$~:~:~8::~::X:~:::t: ===================================================== :::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~::: ::: ¥:~:}:: :::: ~,:'~{}51~'~ ::~::~:~}::7 ~i::~: :~ :r: ~" ~?~} :~:~:: :B7~'!:::¢~~: :}:~:!: :-'~7 :~: ~:~:"~:~:~::! ::3~: :~:~ ~:!.?i:~:~2 87~'~:~7:::7}}~:?~:~ :~1::'~ :i~i~}~B:'~5~:!:}~: ~ :7 :g~5ii: i::~!~:i ~::'~:~¢7!:~:~ ~?:~7::~: :~:;::=' r~:::~} ?~: 3:}i~ ~:~ ~::I :~}: ?~ :} ::~+i~ :77~;i~:~i :?i~ :~:~;i:}:~ ~: ):: ;:';?? ::~:" ::~::~: ~i :¢~ ::~f ? i :;: i: 7 ii :~: :~: :~:i: :~:~:7~: ~ :; ~: :~ 7. ~ :~: :7 ;'~ :~: :' :: ~:::~:~ :-~ :'~:::: :~' ~ :;: :'~: }~ :~ ~': ? 7 :.~ :~: ii: ~.:~: :::::::::::::::::::::: i i~ :i~ ~'~: ;7'' ¢~ :~' :i :~i::~} ~g:~ }}i:: '~: :}ii:'~ i ;:~ ~:: ::}~:~ ~: :~ :~ :~ :: :~ ~: ~ ::: ~: '~;: ::~:: ~ ~:~:~: :~: :: '~ :~ :: ~: ~: :::: :: ~:: ~ ~: ~ :X~: :: J~ :~:: ~ ~ ~::~ :: ~: :~ ::::~ :t~;~.:: :i :~ :: ::i~:~: :: ~: ~: :~: :: ~:: ~: :; ~ ~ :: ~ :~ ~: :~ :;~ ~: :: ~: :~: ~ ~ :i ~;: ~: }~;:~: ~ ~.~: ~ ~ ::~ :~ :~;: ~::~ ~ :: ~ :~:~:X~ ~ ~:~:~ ,~,;~:: ¥.:~: '~; ;~::~:: ~ :~:: :~/:~ ¥~ ~:!~ ~:~ ~ {~: ~.: ¥:: :: :~;~: ~: :~, :~ ~:~: :~ ~ ~::~: :: '~: ':~ :~i~ !~: ~:?~::;~ ~:: i: ~, ~ ~ :: ~ :;:: ~qi ~ :~ :: ¥: ~: ~: :~: ~ '~:: ~ :~:: :{:: ::~ ~: ::~: ~ ~, ~, ::::.:::::: ~:;~?: :: ~ ~;~: '~: ~: ',: ~?: :.:::" ::: :: ~. ;;~:: ~ :?: ':: ~:: :i~ :: :~: ::~: :: :: :~ :: ~: :~: ':~::: ~:::~:: ~:~ ::::::?::~' :~: ~:: ~::: ::;~::~ :: ~ ~::3:::: ? ::: ~ :~:: ~ :~:: :: :i:: :<:::': ~:: :::: ~ :: ~:: ~::: i .. ............................ vt: ::. ,::~ 7 37 9.4 * ALASKA COMPUTING CENTER . ****************************** . ............................ ....... SCHLUMBERGER * ****************************** RECEIVED FEB 041999 Alaska 0il & Oas Cons. Commission Aaohor~ COMPANY NAME : ARCO ALASKA, INC. WELL NAME : DS 4-01 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292007800 REFERENCE NO : 99036 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: **** REEL HEADER **** SERVICE NAFIE : EDIT DATE : 99/01/28 ORIGIN : FLIC REEL NAME : 99036 CONTINUATION # : PREVIOUS REEL : COMF1ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-01, API# 50-029-20078-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/01/28 ORIGIN : FLIC TAPE NAME : 99036 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-01, API# 50-029-20078-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 4-01 API NUMBER: 500292007800 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 28~JAN-99 JOB NUMBER: 99036 LOGGING ENGINEER: VETROMILE OPERATOR WITNESS: C. SHUMWAY SURFACE LOCATION SECTION: 34 TOWNSHIP: 1 IN RANGE: 15E FNL: 1327 FSL: FEL: 295 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 64. O0 DERRICK FLOOR: 63. O0 GROUND LEVEL: 25. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 12. 500 9. 625 9747.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 30-NOV-70 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 88887.0 88887.0 9556.0 9555.0 9554.0 9553.0 9552.5 9553.0 9547.5 9546.5 9546.5 9545.5 9544.0 9544.0 9503.0 9504.0 9504.0 9406.5 9405.5 9405.5 9394.5 9394.0 9394.0 9379.5 9379.5 9379.5 9363.5 9363.0 9363.0 9355.0 9355.0 9355.0 9331.0 9331.0 9331.0 9323.5 9324.0 9324.0 9317.0 9317.0 9317.0 9299.0 9299.5 9299.5 9287.5 9287.0 9287.0 9282.0 9281.0 9281.0 100.0 99.0 99.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG REMARKS: CONTAINED HEREIN IS THE CNTG DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 4-01 ON I3-NOV-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTG PASS #1 GRCH TO THE BASELINE GAMMA RAY PROVIDED BY THE CLIENT (GR.BCS); AND CNTG PASS #1NPHI TO GR.BCS. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : OOICO1 DATE : 99/01/28 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. LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: PASS NUMBER: 1 DEPTH INC~: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9563.0 9268.0 CNTG 9574.0 9268.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT I1 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: ** SET TYPE - CHAN ** ....................................................................................... NAM1E SERV UNIT SERVICE API API API API FILE NUF1B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELE~ CODE (HEX) O0 000 O0 0 1 1 1 4 68 0000000000 DEPT FT 1224665 NPHI CNTG PU-S 1224665 O0 000 O0 0 1 1 1 4 68 ENPH CNTG PU-S 1224665 O0 000 O0 0 1 1 1 4 68 CPHI CNG PU-S 1224665 O0 000 O0 0 1 1 1 4 68 NRAT CNTG 1224665 O0 000 O0 0 1 1 1 4 68 CRATCNTG 1224665 O0 000 O0 0 1 1 1 4 68 ENRA CNTG 1224665 O0 000 O0 0 1 1 1 4 68 NCNT CNTG CPS 1224665 O0 000 O0 0 1 1 1 4 68 FCNT CNTG CPS 1224665 O0 000 O0 0 1 1 1 4 68 CNTC CNTG CPS 1224665 O0 000 O0 0 1 1 1 4 68 CFTC CNTG CPS 1224665 O0 000 O0 0 1 1 1 4 68 CNEC CNTG CPS 1224665 O0 000 O0 0 1 1 1 4 68 CFEC CNTG CPS 1224665 O0 000 O0 0 1 1 1 4 68 GRCH CNTG GAPI 1224665 O0 000 O0 0 1 1 1 4 68 TENS CNTG LB 1224665 O0 000 O0 0 1 1 1 4 68 CCL CNTG V 1224665 O0 000 O0 0 1 I 1 4 68 GR BCS GAPI 1224665 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 9740.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG -999.250 CCL.CNTG GR.BCS 83.861 DEPT. 9204.000 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG GR.BCS 195.493 -999.250 CPHI. CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: **** FILE HEADER **** FILE NAF1E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE . 99/01/28 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: O . 5000 FILE SUFmLARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9563.0 9276.0 CNTG 9574.0 9276.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9563.5 9559.5 9555.5 9548.0 9543.5 9540.0 9534.5 9530.5 9519.0 9512.5 9506.5 9500.5 9500.0 9482.5 9472.0 9462.0 9456.0 9448.5 9446.0 9435.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88887.0 88888.0 9558.5 9547.0 9543.0 9539.0 9530.0 9501.0 9483.0 9472.5 9462.0 9446.0 9434.5 9563.5 9558.5 9555.0 9542.0 9534.0 9520.0 9514.0 9507.5 9501.5 9456.0 9448.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 9434.5 9434.5 9424.5 9424.0 9406.0 9405.5 9405.0 9394.0 9394.0 9394.0 9379.5 9379.5 9380.0 9376.0 9375.5 9366.5 9366.5 9361.0 9360.5 9355.5 9355.5 9353.0 9353.5 9344.5 9345.0 9338.0 9337.5 9334.0 9334.5 9331.0 9331.5 9328.0 9328.0 9323.5 9324.0 9315.5 9315.5 9310.0 9310.0 9307.5 9308.0 9299.5 9300.0 9297 . 0 9297.5 9286.0 9287.5 100.0 100.5 101.5 $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH; AND PASS #2 NPHI TO PASS #1 NPHI. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 I 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE N73M~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1224665 O0 000 O0 0 2 1 1 4 68 NPHI CNTG PU-S 1224665 O0 000 O0 0 2 1 1 4 68 ENPH CNTG PU-S 1224665 O0 000 O0 0 2 1 1 4 68 CPHI CNTG PU-S 1224665 O0 000 O0 0 2 1 1 4 68 NRAT CNTG 1224665 O0 000 O0 0 2 1 1 4 68 CRAT CNTG 1224665 O0 000 O0 0 2 1 1 4 68 ENRA CNTG 1224665 O0 000 O0 0 2 1 1 4 68 NCNTCNTG CPS 1224665 O0 000 O0 0 2 1 1 4 68 FCNT CNTG CPS 1224665 O0 000 O0 0 2 1 1 4 68 CNTC CNTG CPS 1224665 O0 000 O0 0 2 1 i 4 68 CFTC CNTG CPS 1224665 O0 000 O0 0 2 1 1 4 68 CNEC CNTG CPS 1224665 O0 000 O0 0 2 1 1 4 68 CFEC CNTG CPS 1224665 O0 000 O0 0 2 1 1 4 68 GRCH CNTG GAPI 1224665 O0 000 O0 0 2 1 1 4 68 TENS CNTG LB 1224665 O0 000 O0 0 2 1 1 4 68 CCL CNTG V 1224665 O0 000 O0 0 2 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 9574.000 NPHI. CNTG 38.485 ENPH. CNTG 38.017 CPHI.CNTG NRAT. CNTG 3.724 CRAT. CNTG 3.514 ENRA.CNTG 5.439 NCNT. CNTG FCNT. CNTG 512.899 CNTC. CNTG 1768.503 CFTC. CNTG 516.484 CNEC. CNTG CFEC. CNTG 458.609 GRCH. CNTG -999.250 TENS. CNTG 3268.000 CCL.CNTG DEPT. 9276.500 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 94.107 TENS. CNTG -999.250 CCL.CNTG 35.281 1838.188 24 94.561 O. 013 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: **** FILE TRAILER **** FILE NAFIE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUMFL~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9563.0 9296.0 CNTG 9574.0 9296.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9564.0 9559.0 9556.5 9552.0 9546.0 9538.5 9534.5 9530.5 9524.5 9522.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88887.5 88887.5 9563.5 9558.5 9555.5 9551.5 9544.5 9537.5 9533.5 9530.0 9525.5 9521.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 9521.5 9522.0 9506.5 9507.5 9504.5 9505.5 9500.0 9501.0 9482.0 9483.0 9472.5 9473.0 9472.0 9472.5 9462.0 9462.5 9455.5 9455.5 9448.5 9448.5 9446.0 9446.0 9444.0 9444.0 9440.0 9439.5 9436.5 9434.5 9434.5 9434.5 9431.5 9431.0 9429.0 9429.0 9424.5 9424.0 9424.0 9423.5 9417.0 9416.5 9406.0 9405.0 9399.5 9399.0 9394.5 9394.0 9394.0 9392.0 9392.0 9379.5 9379.5 9378.0 9378.0 9366.5 9367.0 9361.0 9361.0 9353.0 9353.0 9352.5 9353.0 9338.0 9337.5 9337.5 9337.5 9331.0 9331.5 9331.0 9326.0 9328.0 9324.0 9324.5 9323.5 9323.5 9321.5 9322.5 9315.5 9315.5 9312.5 9312.5 9307.5 9308.0 9302.0 9302.0 9300.0 9301.0 9299.0 9299.5 100.0 100.5 101.0 $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #3 GRCH TO PASS #1 GRCH; AND PASS #3 NPHI TO PASS #I NPHI. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 16 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 1224665 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1224665 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1224665 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1224665 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1224665 O0 000 O0 0 3 i 1 4 68 0000000000 CRAT CNTG 1224665 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1224665 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1224665 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 1224665 O0 000 O0 0 3 1 i 4 68 0000000000 CNTC CNTG CPS 1224665 O0 000 O0 0 3 1 I 4 68 0000000000 CFTC CNTG CPS 1224665 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1224665 O0 000 O0 0 3 I 1 4 68 0000000000 CFEC CNTG CPS 1224665 O0 000 O0 0 3 1 I 4 68 0000000000 GRCH CNTG GAPI 1224665 O0 000 O0 0 3 1 I 4 68 0000000000 TENS CNTG LB 1224665 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1224665 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 11 DEPT. 9573. 500 NPHI. CNTG 34. 766 ENPH. CNTG NRA T . CNTG 3 . 439 CRA T . CNTG 3. 310 ENRA . CNTG FCNT. CNTG 547.747 CNTC. CNTG 1751.807 CFTC. CNTG CFEC. CNTG 463.166 GRCH. CNTG -999.250 TENS. CNTG DEPT. 9296.500 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 E1VRA. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 80.571 TENS. CNTG 39.081 CPHI.CNTG 5.536 NCNT. CNTG 545.713 CNEC. CNTG 3347.000 CCL. CNTG -999.250 CPHI. CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG 31.884 1800.377 2564.089 0.022 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, CNTG REMARKS: THE ARITH~ETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 12 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 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 1224665 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU~S 1224665 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1224665 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1224665 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1224665 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1224665 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1224665 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1224665 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1224665 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1224665 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1224665 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1224665 O0 000 O0 0 4 I 1 4 68 0000000000 CFEC CNAV CPS 1224665 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1224665 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9573.000 NPHI.CNAV 37.093 NRAT. CNAV 3.578 CPHI.CNAV CRAT. CNAV 3.437 ENPH. CNAV 40.615 ENRA.CNAV 5.672 NCNT. CNAV FCNT. CNA V 51 O . 270 CNTC. CNA V 1783. 740 CFTC. CNA V 53 O . 215 CNEC. CNA V CFEC. CNAV 458. 154 GRCH. CNTG -999. 250 34. 402 1874.468 2598. 582 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 13 DEPT. 9267.000 NPHI.CNAV -999.250 NRAT. CNAV -999.250 CPHI.CNAV -999.250 CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA.CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV -999.250 CFEC. CNAV -999.250 GRCH. CNTG 117.651 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : OOICO1 DATE : 99/01/28 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 NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~VARY VENDOR TOOL CODE START DEPTH CNTG 9593.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH 9267.0 13-NOV-98 8C1-205 1000 13-NOV-98 9586.0 9578.0 9300.0 9578.0 1800.O LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 14 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY CNTG COMP. NEUTRON $ TOOL NUM~ER SG T - L CNT-G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. LOGGERS CASING DEPTH (FT) : 12.500 9747.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDS TONE 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): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 6500 TOOL STANDOFF (IN): REMARKS: LOG TIED INTO DRESSER ATLAS GR DATED lO-JUL-86. PUMPED 430 BBL TO KNOCK WELL DOWN @ 5 BPM PUMPED 84 BBL DURING LOGGING @ 1 BPM PUMPED 10 BBL DIESEL TO CLEAN LINES OUT TAGGED TD AT 9578'. ESTIMATED FIELD GOC PICK AT 9450'. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 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 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1224665 O0 000 O0 0 5 I 1 4 68 0000000000 ENPH PS1 PU 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1224665 O0 000 O0 0 5 I 1 4 68 0000000000 TNRA PS1 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA PS1 1224665 O0 000 O0 0 5 I 1 4 68 0000000000 CFBC PS1 CPS 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PSi CPS 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 RCEN PSI CPS 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 1224665 O0 000 O0 0 5 i 1 4 68 0000000000 GR PS1 GAPI 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1224665 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 16 DEPT. 9593.500 NPHI.PS1 TNRA.PS1 4.792 RTNR.PS1 CNEC. PS1 2695.696 RCEF. PS1 RCFT. PS1 379.790 CNTC. PS1 GR.PS1 39.685 TENS.PSI DEPT. 9266.500 NPHI.PS1 TNRA.PS1 4.037 RTNR.PS1 CNEC. PS1 2444.033 RCEF. PS1 RCFT. PS1 347.445 CNTC. PS1 GR.PS1 110.439 TENS. PSi 61.780 ENPH. PS1 5.000 ENRA.PS1 507.209 RCEN. PS1 1834.553 CFTC.PSI 2213.000 CCL.PS1 48.028 ENPH. PS1 4.568 ENRA.PS1 400.873 RCEN. PS1 1479.847 CFTC. PSi 3159.000 CCL.PS1 36.575 TNPH. PS1 5.306 CFEC. PS1 2463.278 RCNT. PS1 390.718 NPOR. PS1 O. 014 44.648 TNPH. PS1 6.018 CFEC. PS1 2181.840 RCNT. PS1 369.312 NPOR.PS1 -999.250 65.189 508.036 1932.865 65.189 45.007 406.113 1552.869 45.210 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUFk~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG 9589.0 9274.5 $ LOG HEADER DATA DATE LOGGED: 13-NOV-98 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 17 SOFTWARE VERSION: TIFIE 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): 8C1-205 1000 13 -NOV-98 9586.0 9578.0 9300.0 9578.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~IA RAY CNTG COMP. NEUTRON $ TOOL NUMBER ........... SGT-L CNT-G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. LOGGERS CASING DEPTH (FT): 12.500 9747.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 6500 TOOL STANDOFF (IN): REMARKS: LOG TIED INTO DRESSER ATLAS GR DATED lO-JUL-86. PUMPED 430 BBL TO KNOCK WELL DOWN @ 5 BPM PUMPED 84 BBL DURING LOGGING @ 1 BPM PUMPED 10 BBL DIESEL TO CLEAN LINES OUT TAGGED TD AT 9578'. LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 18 ESTIMATED FIELD GOC PICK AT 9450 '. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NME SERV UNIT SERVICE API API API API FILE _Nr.~B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1224665 O0 000 O0 0 6 1 I 4 68 0000000000 NPHI PS2 PU 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1224665 O0 000 O0 0 6 1 I 4 68 0000000000 TNPH PS2 PU 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1224665 O0 000 O0 0 6 I 1 4 68 0000000000 ENRA PS2 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 RCEN PS2 CPS 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 19 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) TENS PS2 LB 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1224665 O0 000 O0 0 6 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 9589.000 NPHI.PS2 23.346 ENPH. PS2 33.562 TNPH. PS2 TNRA.PS2 2.683 RTNR.PS2 2.800 ENRA.PS2 5.018 CFEC. PS2 CNEC. PS2 2529.452 RCEF. PS2 503.221 RCEN. PS2 2311.367 RCNT. PS2 RCFT. PS2 630.040 CNTC. PS2 1696.012 CFTC. PS2 648.169 NPOR.PS2 GR.PS2 22.500 TENS. PS2 2000.000 CCL.PS2 0.014 DEPT. 9274.000 NPHI.PS2 43.627 ENPH. PS2 42.588 TNPH. PS2 TNRA.PS2 3.796 RTNR.PS2 3.837 ENRA.PS2 5.844 CFEC. PS2 CNEC. PS2 2558.634 RCEF. PS2 448.526 RCEN. PS2 2403.061 RCNT. PS2 RCFT. PS2 360.929 CNTC. PS2 1561.868 CFTC.PS2 397.141 NPOR.PS2 GR.PS2 95.645 TENS.PS2 3244.000 CCL.PS2 -999.250 22.931 504.042 1786.899 22.931 43.729 437.816 1636.485 44.001 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 20 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH 9589.5 CNTG LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY CNTG COMP. NEUTRON $ BORENOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9293.0 13-NOV-98 8Cl-205 1000 13-NOV-98 9586.0 9578.0 9300.0 9578.0 1800.0 NO TOOL NUMBER SGT-L CNT-G 12.500 9747.0 CRUDE 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 21 FAR COUNT RATE HIGH SCALE (CPS): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 6500 TOOL STANDOFF (IN): REMARKS: LOG TIED INTO DRESSER ATLAS GR DATED lO-JUL-86. PUMPED 430 BBL TO KNOCK WELL DOWN ® 5 BPM PUMPED 84 BBL DURING LOGGING @ I BPM PUMPED 10 BBL DIESEL TO CLEAN LINES OUT TAGGED TD AT 9578'. ESTIMATED FIELD GOC PICK AT 9450'. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 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 1224665 O0 000 O0 0 7 t 1 4 68 0000000000 NPHI PS3 PU 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS3 PU 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA PS3 1224665 O0 000 O0 0 7 1 I 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 22 NAME SERV UNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... CFEC PS3 CPS 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 RCENPS3 CPS 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 RCNTPS3 CPS 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1224665 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9589.500 NPHI.PS3 35.575 ENPH. PS3 58.716 TNPH. PS3 TNRA.PS3 3.354 RTNR.PS3 3.500 ENRA.PS3 7.086 CFEC. PS3 CNEC.PS3 2695.696 RCEF. PS3 379.790 RCEN. PS3 2463.278 RCNT. PS3 RCFT. PS3 507.209 CNTC. PS3 1709.651 CFTC. PS3 521.803 NPOR.PS3 GR.PS3 56.693 TENS.PS3 2067.000 CCL.PS3 0.024 DEPT. 9292.500 NPHI.PS3 46.327 ENPH. PS3 43.571 TNPH. PS3 TNRA.PS3 3.944 RTNR.PS3 3.980 ENRA.PS3 5.928 CFEC.PS3 CNEC. PS3 2565.765 RCEF. PS3 411.125 RCEN. PS3 2346.712 RCNT. PS3 RCFT. PS3 377.401 CNTC. PS3 1611.241 CFTC. PS3 405.231 NPOR.PS3 GR.PS3 71.466 TENS. PS3 3206.000 CCL.PS3 -999.250 32. 927 380. 410 1801. 269 32. 927 44.474 432.837 1756.957 42.791 ** EiVD OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : OOICO1 DATE : 99/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1999 11:43 PAGE: 23 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/01/28 ORIGIN : FLIC TAPE NAFIE : 99036 CONTINUATION # : 1 PREVIOUS TAPE : COMFiEITT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-01, API# 50-029-20078-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/01/28 ORIGIN : FLIC REEL NAME : 99036 CONTINUATION # : PREVIOUS REEL : COF~ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-01, API# 50-029-20078-00 * ALASKA COMPUTING CENTER * ****************************** * ............................ ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 4 - 1 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-20078-00 REFERENCE NO : 98132 * ALASKA COMPUTING CENTER * * * * ....... SCHLUMBERGER ....... * COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 4 - 1 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-20078-00 REFERENCE NO : 98132 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: **** RRRL HEADER **** SERVICE NAME : EDIT DATE : 98/03/16 ORIGIN : FLIC RRRL NAME : 98132 CONTINUATION # : PREVIOUS RRRL : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-1, API# 50-029-20078-00 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE : 98/03/16 ORIGIN : FLIC TAPE NAME : 98132 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-1, API# 50-029-20078-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 4 - 1 API NUMBER: 500292007800 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 16-MAR-98 JOB NUMBER: 98132 LOGGING ENGINEER: BAILEY OPERATOR WITNESS: SARBER SURFACE LOCATION SECTION: 34 TOWNSHIP: liN RANGE: 1SE FNL: FSL: 1327 FEL: FWL: 295 ELEVATION(FT FROM MSL O) KELLY BUSHING: 64.00 DERRICK FLOOR: GROUND LEVEL: 25.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) .............................................. 1ST STRING 13.375 2686.0 72. O0 2ND STRING 9. 625 9747.0 47. O0 3RD STRING 7. 000 3009.0 26. O0 PRODUCTION STRING 5. 500 9184.0 17. O0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUM~ : 1 PASS ~ER : 1 DATE LOGGED: 30-NOV-70 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 9557.5 9551.0 9543.5 9510.5 9502.0 9387.0 9372.5 9363.5 9348.5 9334.5 9330.0 9315.5 9305.0 9302.5 9297.5 9292.0 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88891.0 9560.5 9552.5 9544.0 9511.0 9503.5 9394.0 9379.5 9371.5 9355.0 9341 5 9338 0 9323 5 9312 0 9310 5 9304 5 9300.0 108.0 P~C~RKS: THIS IS THE DATA FROM THE CNTG LOGGED 31-0CT~97. THE DEPTH SHIFTS ARE PASS 1 GRCH TO BCS GR. ALL OTHER CNTG CURVES WERE CARRIED WITH THE GRCH SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 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 NUFfBER: 1 DEPTH INCREMENT: 0.5000 FiLE SOT4FL~RY LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9562.0 9279.0 CNTG 9574 . 0 9279.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG REMARKS: THIS IS THE PASS #1 DATA. NO PASS TO PASS SHIFTS WERE MADE 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 64 4 66 I 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PA GE: ** SET TYPE - CHAN ** NAME SERV UNIT SERViCE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... O0 000 O0 0 1 1 1 4 68 0000000000 DEPT FT 1173643 NPHI ~ PU-S 1173643 O0 000 O0 0 1 1 1 4 68 ENPH CNTG PU-S 1173643 O0 000 O0 0 1 1 1 4 68 CPHI CNTG PU-S 1173643 O0 000 O0 0 1 1 1 4 68 NRAT CNTG 1173643 O0 000 O0 0 1 1 1 4 68 CRAT CNTG 1173643 O0 000 O0 0 1 1 1 4 68 ENRA CNTG 1173643 O0 000 O0 0 1 1 1 4 68 NCNT CNTG CPS 1173643 O0 000 O0 0 1 1 1 4 68 FCNT CNTG CPS 1173643 O0 000 O0 0 1 1 1 4 68 CNTC CNTG CPS 1173643 O0 000 O0 0 1 1 1 4 68 CFTC CNTG CPS 1173643 O0 000 O0 0 1 1 I 4 68 CNEC CNTG CPS 1173643 O0 000 O0 0 1 1 1 4 68 CFEC CNTG CPS 1173643 O0 000 O0 0 1 1 1 4 68 GRCH CNTG GAPI 1173643 O0 000 O0 0 1 1 1 4 68 TENS CNTG LB 1173643 O0 000 O0 0 1 1 1 4 68 GR BCS GAPI 1173643 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 9600.000 NPHI. CNTG -999.250 ENPH. CNTG -999.250 CPHI. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA. CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCM. CNTG -999.250 TENS. CNTG -999.250 GR.BCS DEPT. 9500.000 NPHI. CNTG 37.677 ENPH. CNTG 31.082 CPHI. CNTG NRAT. CNTG 3.673 CRAT. CNTG 3.469 ENRA.CNTG 4.771 NCNT. CNTG FCNT. CNTG 535.383 CNTC. CNTG 1906.375 CFTC. CNTG 552.000 CNEC. CNTG CFEC. CNTG 602.313 GRCH. CNTG 56.875 TENS. CNTG 1395.000 GR.BCS DEPT. 9400.000 NPHI.CNTG 16.901 ENPH. CNTG 18.728 CPHI. CNTG NRAT. CNTG 2.298 CRAT. CNTG 2.275 ENRA. CNTG 3.394 NCNT. CNTG FCNT. CNTG 1175.656 CNTC. CNTG 2739.125 CFTC. CNTG 1203.258 CNEC. CNTG CFEC. CNTG 987.750 GRCH. CNTG 22.339 TENS. CNTG 1391.984 GR.BCS DEPT. 9300.000 NPHI. CNTG 28.270 ENPH. CNTG 24.734 CPHI. CNTG NRAT. CNTG 2.899 CRAT. CNTG 2.953 ENRA. CNTG 4.096 NCNT. CNTG FCNT. CNTG 750.735 CNTC. CNTG 2251.555 CFTC. CNTG 796.404 CNEC. CNTG CFEC. CNTG 731.888 GRCH. CNTG 43.844 TENS. CNTG 1390.000 GR.BCS DEPT. 9275.000 NPHI. CNTG -999.250 ENPH. CNTG -999.250 CPHI. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA. CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 GR.BCS -999.250 -999.250 -999.250 87.105 30.902 1919.625 2873.535 43.815 14.056 2909.000 3352.813 33.819 21.531 2365.744 2997.936 57.094 -999.250 -999.250 -999.250 159.101 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 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 SUF~IARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9562.0 9294.0 CNTG 9574.0 9294.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTG ............................ 88888.0 88882.5 9562.0 9556.5 9559.0 9552.5 9557.5 9551.0 9551.0 9544.0 9522.5 9515.5 9506.5 9500.5 9499.5 9494.0 9492.5 9487.5 9487.5 9483.5 9483.0 9478.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 9475.0 9471.0 9469.5 9466.0 9459.5 9456.5 9442.0 9439.5 9439.5 9437.0 9435.0 9432.5 9426.5 9425.0 9419.0 9417.5 9404.0 9402.0 9394.5 9394.5 9385.5 9385.5 9379.5 9379.5 9370 . 5 9371 . 5 9367.5 9367.0 9361.0 9360.0 9355.0 9355.0 9353.0 9352.0 9337.5 9338.0 9323.0 9323.5 9312.0 9312.0 9299.5 9300.0 100.0 100.5 $ Ri~D~RKS: This file contains CNTG Pass #2. The depth shifts shown above relect GRCH pass #2 to GRCH pass #1 and NPHI pass #2 to NPHI pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: TYPE REPR CODE VALUE 0 66 1 .............................. ** SET TYPE - CHAN ** NAMIE SERV UNIT SERVICE API API API API FILE NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) DEPT FT 1173643 NPHI CNTG PU-S 1173643 ENPH CNTG PU-S 1173643 CPHI CNTG PU-S 1173643 NRAT CNTG 1173643 CRAT CNTG 1173643 ENRA CNTG 1173643 NCNT CNTG CPS 1173643 FCNT CNTG CPS 1173643 CNTC CNTG CPS 1173643 CFTC CNTG CPS 1173643 CNEC CNTG CPS 1173643 CFEC CNTG CPS 1173643 GRCH CNTG GAPI 1173643 TENS CNTG LB 1173643 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 I 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9568.500 NPHI. CNTG 35.282 ENPH. CNTG 38.883 CPHI.CNTG NRAT. CNTG 3.286 CRAT. CNTG 3.338 ENRA.CNTG 5.518 NCNT. CNTG FCNT. CNTG 581.257 CNTC. CNTG 1893.381 CFTC. CNTG 580.702 CNEC. CNTG CFEC. CNTG 467.006 GRCH. CNTG -999.250 TENS. CNTG 1385.000 DEPT. 9500.000 NPHI. CNTG 34.906 ENPH. CNTG 34.140 CPHI. CNTG NRAT. CNTG 3.283 CRAT. CNTG 3.318 ENRA. CNTG 5.075 NCNT. CNTG FCNT. CNTG 546.000 CNTC. CNTG 1827.078 CFTC. CNTG 585.113 CNEC. CNTG CFEC. CNTG 580.125 GRCH. CNTG 50.938 TENS. CNTG 1405.383 DEPT. 9400.000 NPHI. CNTG 15.902 ENPH. CNTG 18.077 CPHI. CNTG NRAT. CNTG 2.071 CRAT. CNTG 2.205 ENRA. CNTG 3.315 NCNT. CNTG FCNT. CNTG 1182.016 CNTC. CNTG 2711.563 CFTC. CNTG 1234.375 CNEC. CNTG CFEC. CNTG 969.875 GRCH. CNTG 30.953 TENS. CNTG 1385.000 DEPT. 9300.000 NPHI. CNTG 24.720 ENPH. CNTG 26.341 CPHI.CNTG NRAT. CNTG 2.798 CRAT. CNTG 2.759 ENRA. CNTG 4.273 NCNT. CNTG FCNT. CNTG 762.739 CNTC. CNTG 2222.938 CFTC. CNTG 803.529 CNEC. CNTG CFEC. CNTG 703.958 GRCH. CNTG 40.531 TENS. CNTG 1385.000 DEPT. 9294.500 NPHI. CNTG 39.703 ENPH. CNTG 42.901 CPHI.CNTG NRAT. CNTG 3.692 CRAT. CNTG 3.581 ENRA. CNTG 5.871 NCNT. CNTG FCNT. CNTG 466.286 CNTC. CNTG 1599.634 CFTC. CNTG 433.873 CNEC. CNTG CFEC. CNTG 432.204 GRCH. CNTG 94.938 TENS. CNTG 1380.000 33.020 1991.923 2576.999 30.863 1904.500 2943.875 17.303 2855.594 3214.688 25.459 2432.490 3008.214 39.924 1707.546 2537.424 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01COi DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUF~W~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9558.0 9276.0 CNTG 9570.0 9276.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 9544.0 9535.5 9533.0 9528.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG .............. 88855.5 9511.5 9503.5 9501.5 9497.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE 9525.0 9494.0 9518.5 9488.0 9513.0 9483.0 9508.5 9478.5 9498.5 9469.0 9489.0 9459.5 9485.5 9456.5 9465.5 9437.0 9453.5 9426.0 9445.0 9417.5 9438.0 9411.5 9420.0 9394.0 9410.0 9384.0 9409.0 9382.5 9396.5 9371.0 9394.0 9367.5 9391.0 9362.0 9387.5 9359.5 9382.0 9355.0 9379.5 9352.0 9369.5 9342.5 9363.5 9338.0 9357.0 9331.0 9339.0 9312.0 9337.0 9310.5 9334.0 9308.0 100.0 74.0 $ REMARKS: This file contains CNTG Pass #3. The depth shifts shown above relect GRCH Pass #3 to GRCH pass #1 and NPHI Pass #3 to NPHI pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 O.5 9 65 FT 11 66 17 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 10 TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUb~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 FCNTCNTG CPS 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 CNECCNTG CPS 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1173643 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9537.500 NPHI.CNTG 21.356 ENPH. CNTG 26.694 CPHI.CNTG NRAT. CNTG 2.325 CRAT. CNTG 2.570 ENRA.CNTG 4.312 NCNT. CNTG FCNT. CNTG 828.980 CNTC. CNTG 2158.661 CFTC. CNTG 823.800 CNEC. CNTG CFEC. CNTG 657.152 GRCH. CNTG -999.250 TENS. CNTG 1395.000 DEPT. 9500.000 NPHI.CNTG 40.218 ENPH. CNTG 32.559 CPHI.CNTG NRAT. CNTG 4.037 CRAT. CNTG 3.609 ENRA.CNTG 4.920 NCNT. CNTG FCNT. CNTG 500.887 CNTC. CNTG 1839.531 CFTC. CNTG 519.946 CNEC. CNTG CFEC. CNTG 572.904 GRCH. CNTG 65.813 TENS. CNTG 1405.000 DEPT. 9400.000 NPHI.CNTG 16.485 ENPH. CNTG 19.067 CPHI. CNTG NRAT. CNTG 2.329 CRAT. CNTG 2.246 ENRA. C~G 3.436 NCNT. CNTG FCNT. CNTG 1203.750 CNTC. CNTG 2713.188 CFTC. CNTG 1228.188 CNEC. CNTG CFEC. CNTG 983.609 GRCH. CNTG 24.680 TENS. CNTG 1403.125 DEPT. 9300. 000 NPHI. CNTG 26. 260 ENPH. CNTG 27.215 CPHI. CNTG NRA T. CNTG 3.082 CRA T . CNTG 2.843 ENRA . CNTG 4.368 N CNT . CNTG FCNT. CNTG 753.746 CNTC. CNTG 2167.252 CFTC. CNTG 763.584 CNEC. CNTG CFEC. CNTG 685.198 GRCH. CNTG 28.578 TENS. CNTG 1375.000 23.311 2351.856 2833.411 37. 471 1799. 829 2818. 493 17.470 2795.750 3379.000 26.530 2323.232 2992.847 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 11 DEPT. 9274.500 NPHI.CNTG 51.036 ENPH. CNTG 43.363 CPHI.CNTG NRAT. CNTG 4.098 CRAT. CNTG 4.202 ENRA.CNTG 5.910 NCNT. CNTG FCNT. CNTG 342.113 CNTC. CNTG 1531.519 CFTC. CNTG 374.907 CNEC. CNTG CFEC. CNTG 429.068 GRCH. CNTG 124.688 TENS. CNTG 1370.000 46. 699 1634. 619 2535. 870 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREmENT: 0.5000 FILE SUM~3~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9562.0 9278.0 CNTG 9574.0 9278.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG .............. LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 12 88888.0 88884.5 9558.0 9554.5 9546.5 9541.5 9539.0 9533.5 9529.5 9524.5 9523.0 9518.0 9501.0 9496.5 9498.0 9494.0 9491.0 9487.5 9486.0 9483.5 9481.0 9478.5 9471.5 9469.0 9461.5 9459.5 9447.0 9446.0 9421.5 9421.0 9417.5 9417.5 9393.0 9394.0 9378.5 9379.5 9369.5 9371.0 9362.0 9361.0 9354.5 9355.0 9352.0 9352.0 9341.5 9341.5 9340.0 9340.5 9336.5 9338.0 9330.5 9331.5 9322.0 9323.5 9311.5 9312.0 9309.0 9310.5 100.0 101.5 $ REMARKS: This file contains CNTG Pass #4. The depth shifts shown above relect GRCH Pass #4 to GRCH pass #1 and NPHI Pass #4 to NPHI pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 13 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 17 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 NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1173643 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNTG PU-S 1173643 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNTG PU-S 1173643 O0 000 O0 0 4 1 I 4 68 0000000000 CPHI CNTG PU-S 1173643 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNTG 1173643 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNTG 1173643 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNTG 1173643 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNTG CPS 1173643 O0 000 O0 0 4 1 1 4 68 0000000000 FCNTCNTG CPS 1173643 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNTG CPS 1173643 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNTG CPS 1173643 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNTG CPS 1173643 O0 000 O0 0 4 1 i 4 68 0000000000 CFEC CNTG CPS 1173643 O0 000 O0 0 4 1 i 4 68 0000000000 GRCH CNTG GAPI 1173643 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTG LB 1173643 O0 000 O0 0 4 1 I 4 68 0000000000 ** DATA ** DEPT. 9570.500 NPHI. CNTG 36.668 ENPH. CNTG 42.800 CPHI. CNTG NRAT. CNTG 3.378 CRAT. CNTG 3.414 ENRA. CNTG 5.862 NCNT. CNTG FCNT. CNTG 529.444 CNTC. CNTG 1728.831 CFTC. CNTG 527.631 CNEC. CNTG CFEC. CNTG 412.068 GRCH. CNTG -999.250 TENS. CNTG 1405.000 DEPT. 9500.000 NPHI.CNTG 35.083 ENPH. CNTG 31.601 CPHI.CNTG NRAT. CNTG 3.410 CRAT. CNTG 3.327 ENRA. CNTG 4.824 NCNT. CNTG FCNT. CNTG 549.813 CNTC. CNTG 1860.125 CFTC. CNTG 563.375 CNEC. CNTG CFEC. CNTG 595.500 GRCH. CNTG 54.094 TENS. CNTG 1390.000 DEPT. 9400.000 NPHI.CNTG 16.863 ENPH. CNTG 17.997 CPHI. CNTG NRAT. CNTG 2.348 CRAT. CNTG 2.272 ENRA.CNTG 3.305 NCNT. CNTG FCNT. CNTG 1191.938 CNTC. CNTG 2681.125 CFTC. CNTG 1214.188 CNEC. CNTG CFEC. CNTG 1006.813 GRCH. CNTG 22.056 TENS. CNTG 1380.188 33.274 1793. 784 2415. 648 33.694 1925.875 2872.063 17. 460 2759. 688 3327. 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 14 DEPT. 9300.000 NPHI. CNTG 25.708 ENPH. CNTG NRAT. CNTG 2.969 CRAT. CNTG 2.813 ENRA.CNTG FCNT. CNTG 860.168 CNTC. CNTG 2357.676 CFTC. CNTG CFEC. CNTG 773.711 GRCH. CNTG 41.750 TENS. CNTG 24.550 CPHI. CNTG 4.076 NCNT. CNTG 849.310 CNEC. CNTG 1395.000 DEPT. 9279.500 NPHI. CNTG 45.017 ENPH. CNTG 40.150 CPHI.CNTG NRAT. CNTG 3.933 CRAT. CNTG 3.872 ENRA.CNTG 5.632 NCNT. CNTG FCNT. CNTG 421.513 CNTC. CNTG 1621.814 CFTC. CNTG 429.342 CNEC. CNTG CFEC. CNTG 462.331 GRCH. CNTG 110.813 TENS. CNTG 1385.000 25. 601 2504.520 3153.265 41.436 1708.868 2603.662 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3, 4, CNTG REMARKS: The arithmetic average of passes 1,2,3 & 4 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 18 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) ....................................................................................... O0 000 O0 0 5 1 1 4 68 0000000000 DEPT FT 1173643 NPHI CNAV PU-S 1173643 O0 000 O0 0 5 1 1 4 68 0000000000 NRAT CNAV 1173643 O0 000 O0 0 5 1 1 4 68 0000000000 CPHI CNAV PU-S 1173643 O0 000 O0 0 5 1 1 4 68 0000000000 CRAT CNAV 1173643 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH CNAV PU-S 1173643 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA CNAV 1173643 O0 000 O0 0 5 1 1 4 68 0000000000 NCNT CNAV CPS 1173643 O0 000 O0 0 5 1 1 4 68 0000000000 FCNT CNAV CPS 1173643 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC CNAV CPS 1173643 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC CNAV CPS 1173643 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC CNAV CPS 1173643 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC CNAV CPS 1173643 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH CNTG GAPI 1173643 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9568.500 NPHI. CNAV -999.250 NRAT. CNAV -999.250 CPHI. CNAV CRAT. CNAV -999 . 250 ENPH. CNAV -999 . 250 ENRA. CNAV -999 . 250 NCNT. CNAV FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV CFEC. CNAV -999. 250 GRCH. CNTG -999. 250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 16 DEPT. 9500. 000 NPHI. CNAV 36. 971 NRAT. CNAV CRAT. CNAV 3 . 431 ENPH. CNAV 32 . 346 ENRA. CNAV FCNT. CNAV 533. 021 CNTC. CNAV 1858. 277 CFTC. CNAV CFEC. CNAV 587.710 GRCH. CNTG 56. 875 DEPT. 9400. 000 NPHI. CNAV 16. 537 NRAT. CNAV CRAT. CNAV 2.249 EN-PH. CNAV 18.467 ENRA. CNAV FCNT. CNAV 1188.340 CNTC. CNAV 2711.250 CFTC. CNAV CFEC. CNAV 987. 012 GRCH. CNTG 22. 339 DEPT. 9300. 000 NPHI. CNAV 26. 239 NRAT. CNAV CRAT. CNAV 2. 842 ENPH. CNAV 25.710 ENRA. CNAV FCNT. CNAV 781. 847 CNTC. CNAV 2249. 855 CFTC. CNAV CFEC. CNAV 723. 689 GRCH. CNTG 43 . 844 DEPT. 9279 . 500 NPHI. CNAV - 999. 250 NRAT. CNAV CRAT. CNAV -999. 250 ENPH. CNAV -999. 250 ENRA. CNAV FCNT. CNAV -999. 250 CNTC. CNAV -999. 250 CFTC. CNAV CFEC. CNAV -999. 250 GRCH. CNTG - 999. 250 3.601 CPHI.CNAV 4.897 NCNT. CNAV 555.109 CNEC. CNAV 2.261 CPHI. CNAV 3. 362 NCNT. CNA V 1220 . 002 CNEC. CNAV 2.937 CPHI. CNAV 4. 203 NCNT. CNA V 803. 207 CNEC. CNAV -999.250 CPHI. CNAV -999.250 NCNT. CNAV -999.250 CNEC. CNAV 33.233 1887.457 2876.992 16.573 2830. 008 3318. 375 24.780 2406.497 3038.065 -999.250 -999.250 -999.250 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCRE~F2FF: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 17 FILE SUF~4ARY VENDOR TOOL CODE START DEPTH ........................... LOG HEADER DATA DATE LOGGED: 9574.0 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 .......... 9279.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CNTG DUAL NEUT. GR GAM~A RAY $ 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~PERATURE (DEGF) : BOTTOM HOLE T~PERATURE (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) : 31-0CT-97 44.2 1330 31-0CT-97 9591.0 9580.0 9300.0 9575.0 1800.0 NO TOOL NUMBER ........... CNC-GA-125 SGC-SA 2686.0 CRUDE 10.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 EPITHERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 18 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED IN TO SWS BHC DATED 12/27/70. THE PURPOSE OF THIS LOG WAS TO MONITOR GAS MOVEMENT. VOLUMES PUMPED: CRUDE=606 BBLS, DIESEL=lO BBLS. APPROXIMATE CURRENT GOC--9423 '. ***THIS IS THE PASS #1 RAW DATA******* $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 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 1173643 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS1 PU 1173643 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS1 PU 1173643 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS1 PU 1173643 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS1 1173643 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS1 1173643 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS1 1173643 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS1 CPS 1173643 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS1 CPS 1173643 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 19 NAME SERV UNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS1 CPS 1173643 RCEN PS1 CPS 1173643 RCNT PS1 CPS 1173643 RCFT PS1 CPS 1173643 CNTC PS1 CPS 1173643 CFTC PS1 CPS 1173643 NPOR PS1 PU 1173643 GR PS1 GAPI 1173643 TENS PS1 LB 1173643 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9582.000 NPHI. PS1 35.950 ENPH. PS1 36.696 TNPH. PS1 TNRA.PS1 3.375 RTNR.PS1 3.446 ENRA.PS1 5.317 CFEC. PS1 CNEC. PS1 2467.855 RCEF. PS1 464.102 RCEN. PS1 2312.888 RCNT. PS1 RCFT. PS1 604.409 CNTC. PS1 2024.188 CFTC. PSi 611.937 NPOR.PS1 GR.PS1 46.406 TENS.PSi 1025.000 DEPT. 9500.000 NPHI.PS1 22.800 ENPH. PS1 29.815 TNPH. PS1 TNRA.PS1 2.653 RTNR.PS1 2.452 ENRA.PS1 4.642 CFEC. PS1 CNEC.PS1 2876.304 RCEF. PS1 644.939 RCEN. PS1 2782.722 RCNT. PS1 RCFT. PS1 706.437 CNTC. PS1 1975.447 CFTC. PSI 735.940 NPOR.PS1 GR.PS1 45.063 TENS.PSi 1385.000 DEPT. 9400.000 NPHI.PS1 22.150 ENPH. PS1 25.257 TNPH. PS1 TNRA.PS1 2.618 RTNR.PS1 2.779 ENRA.PS1 4.154 CFEC. PS1 CNEC. PS1 3131.609 RCEF. PS1 751.125 RCEN. PS1 2972.525 RCNT. PS1 RCFT. PS1 819.608 CNTC. PS1 2333.156 CFTC. PSi 879.687 NPOR.PS1 GR.PS1 31.859 TENS.PSI 1365.000 DEPT. 9300.000 NPHI.PS1 20.112 ENPH. PS1 21.442 TNPH.PS1 TNRA.PS1 2.491 RTNR.PS1 2.651 ENRA.PS1 3.719 CFEC. PS1 CNEC.PS1 3051.400 RCEF. PS1 776.880 RCEN. PS1 2854.832 RCNT. PS1 RCFT. PS1 1064.469 CNTC. PS1 2511.660 CFTC. PSI 1035.805 NPOR.PS1 GR.PS1 39.031 TENS.PSi 1375.000 DEPT. 9265.500 NPHI.PS1 45.699 ENPH. PS1 47.611 TNPH. PS1 TNRA.PS1 3.909 RTNR.PS1 3.957 ENRA.PS1 6.260 CFEC. PS1 CNEC. PS1 2524.320 RCEF. PS1 404.220 RCEN. PS1 2300.426 RCNT. PS1 RCFT. PS1 386.518 CNTC. PS1 1549.940 CFTC.PSi 395.024 NPOR.PS1 GR.PS1 116.188 TENS. PSI 1390.000 28. 624 464.104 2118. 568 28. 624 19.527 619. 643 2234.196 17.336 19.084 753.838 2324.105 20.538 16.005 820.390 2707.530 15.238 43. 914 403.258 1634. 619 43.540 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 2O **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS AKIMBER: 2 DEPTH INCREMENT: 0.5000 FILE SO?4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 9574.0 9294.0 CNTG LOG HEADER DATA DATE LOGGED: 31-0CT-97 SOFTWARE VERSION: 44.2 TIME LOGGER ON BOTTOM: 1330 31-0CT-97 TD DRILLER (FT) : 9591.0 TD LOGGER (FT): 9580.0 TOP LOG INTERVAL (FT) : 9300.0 BOTTOM LOG INTERVAL (FT) : 9575.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CNTG DUAL NEUT. GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER ........... CNC-GA-125 SGC-SA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 21 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 2686.0 BORE~OLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE T~PERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE 10.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I 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): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): 1.0 REFIARKS: TIED IN TO SWS BHC DATED 12/27/70. THE PURPOSE OF THIS LOG WAS TO MONITOR GAS MOVEMENT. VOLUMES PUMPED: CRUDE=606 BBLS, DIESEL=lO BBLS. APPROXIMATE CURRENT GOC=9423'. ***THIS IS THE PASS #2 RAW DATA******* $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 22 TYPE REPR CODE VALUE .............................. 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 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 EL~ CODE (HEX) ....................................................................................... DEPT FT 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS2 PU 1173643 O0 000 O0 0 7 1 I 4 68 0000000000 ENPH PS2 PU 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS2 PU 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS2 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS2 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA PS2 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS2 CPS 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS2 CPS 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS2 CPS 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 RCENPS2 CPS 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 RCNTPS2 CPS 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS2 CPS 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS2 CPS 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS2 CPS 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS2 PU 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS2 LB 1173643 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9590.000 NPHI.PS2 40.001 ENPH. PS2 31.699 TNPH. PS2 TNRA.PS2 3.597 RTNR.PS2 3.673 ENRA.PS2 4.834 CFEC. PS2 CNEC. PS2 2432.464 RCEF. PS2 503.221 RCEN. PS2 2279.719 RCNT. PS2 RCFT. PS2 523.484 CNTC. PS2 1866.990 CFTC. PS2 530.004 NPOR.PS2 GR.PS2 40.688 TENS. PS2 970.000 37.221 503.223 1954.040 37.221 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 23 DEPT. 9500.000 NPHI.PS2 TNRA.PS2 3.173 RTNR.PS2 CNEC. PS2 2824.034 RCEF. PS2 RCFT. PS2 717.449 CNTC. PS2 GR.PS2 939.000 TENS.PS2 DEPT. 9400.000 NPHI.PS2 TNRA.PS2 2.391 RTNR.PS2 CNEC. PS2 3338.659 RCEF. PS2 RCFT. PS2 1173.688 CNTC. PS2 GR.PS2 22.219 TENS.PS2 DEPT. 9300.000 NPHI.PS2 TNRA.PS2 2.715 RTNR.PS2 CNEC. PS2 2998.516 RCEF. PS2 RCFT. PS2 860.063 CNTC. PS2 GR.PS2 44.094 TENS.PS2 DEPT. 9293.000 NPHI.PS2 TNRA.PS2 3.938 RTNR.PS2 CNEC. PS2 2550.674 RCEF. PS2 RCFT. PS2 401.620 CNTC. PS2 GR.PS2 94.500 TENS. PS2 32.271 ENPH. PS2 3.237 ENRA.PS2 578.747 RCEN. PS2 2135.197 CFTC. PS2 1375.000 18.600 ENPH. PS2 2.539 ENRA.PS2 988.804 RCEN. PS2 2743.085 CFTC. PS2 1385.000 23.916 ENPH. PS2 2.710 ENRA.PS2 684.049 RCEN. PS2 2261.722 CFTC. PS2 1395.000 46.218 ENPH. PS2 4.535 ENRA.PS2 423.334 RCEN. PS2 1626.616 CFTC. PS2 1395.000 31.386 TNPH. PS2 4.802 CFEC. PS2 2601.548 RCNT. PS2 705.797 NPOR.PS2 18.532 TNPH. PS2 3.371 CFEC. PS2 3153.845 RCNT. PS2 1203.270 NPOR.PS2 26.110 TNPH. PS2 4.248 CFEC. PS2 2868.157 RCNT. PS2 839.954 NPOR.PS2 44.592 TNPH. PS2 6.013 CFEC. PS2 2330.924 RCNT. PS2 406.510 NPOR.PS2 29.362 588.055 2205.853 29.849 18.451 990.526 2795.936 19.209 24.369 705.844 2283.069 25.586 45.249 424.166 1700.475 45.307 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 24 PASS NUMBER: 3 DEPTH INCREMENT: 0. 5000 FILE SUMMARY VENDOR TOOL CODE START DBPTH CNTG 9570.0 $ 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): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTG DUAL NEUT. GR GAMbL~ RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH .......... 9276.0 31-0CT-97 44.2 1330 31-0CT-97 9591.0 9580.0 9300.0 9575.0 1800.0 NO TOOL NUM~ER ........... CNC-GA-125 SGC-SA 2686.0 CRUDE 10.0 EP I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 25 FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): 1.0 ~S: TIED IN TO SWS BHC DATED 12/27/70. THE PURPOSE OF THIS LOG WAS TO MONITOR GAS MOVEMENT. VOLUMES PUMPED: CRUDE=606 BBLS, DIESEL=lO BBLS. APPROXIMATE CURRENT GOC=9423 '. ***THIS IS THE PASS #3 RAW DATA******* $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 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 bT]FIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 NPHI PS3 PU 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 ENPH PS3 PU 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 TNPH PS3 PU 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 TNRA PS3 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 RTNR PS3 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 26 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ~.nR~ CODE (HEX) ENRAPS3 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 CFEC PS3 CPS 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 CNEC PS3 CPS 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 RCEF PS3 CPS 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 RCENPS3 CPS 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 RCNTPS3 CPS 1173643 00 000 O0 0 8 1 1 4 68 0000000000 RCFTPS3 CPS 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 CNTC PS3 CPS 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 CFTC PS3 CPS 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 NPOR PS3 PU 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 1173643 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 9601.500 NPHI.PS3 25.113 ENPH. PS3 31.691 TNPH. PS3 TNRA.PS3 2.780 RTNR.PS3 2.839 ENRA.PS3 4.833 CFEC. PS3 CNEC. PS3 2729.450 RCEF. PS3 564.754 RCEN. PS3 2558.057 RCNT. PS3 RCFT. PS3 880.911 CNTC. PS3 2433.946 CFTC. PS3 891.883 NPOR.PS3 GR.PS3 69.500 TENS.PS3 1285.000 DEPT. 9600.000 NPHI.PS3 25.113 ENPH. PS3 31.691 TNPH. PS3 TNRA.PS3 2.780 RTNR.PS3 2.839 ENRA.PS3 4.833 CFEC. PS3 CNEC.PS3 2729.450 RCEF. PS3 564.754 RCEN. PS3 2558.057 RCNT. PS3 RCFT. PS3 880.911 CNTC. PS3 2433.946 CFTC. PS3 891.883 NPOR.PS3 GR.PS3 69.500 TENS.PS3 1360.000 DEPT. 9500.000 NPHI.PS3 37.602 ENPH. PS3 34.848 TNPH. PS3 TNRA.PS3 3.465 RTNR.PS3 3.500 ENRA.PS3 5.143 CFEC. PS3 CNEC. PS3 2719.044 RCEF. PS3 538.245 RCEN. PS3 2553.980 RCNT. PS3 RCFT. PS3 537.621 CNTC. PS3 1890.304 CFTC.PS3 551.068 NPOR.PS3 GR.PS3 478.250 TENS. PS3 1410.000 DEPT. 9400.000 NPHI.PS3 31.451 ENPH. PS3 32.016 TNPH. PS3 TNRA.PS3 3.128 RTNR.PS3 3.226 ENRA.PS3 4.866 CFEC. PS3 CNEC. PS3 2831.249 RCEF. PS3 538.245 RCEN. PS3 2642.093 RCNT. PS3 RCFT. PS3 603.708 CNTC. PS3 1847.840 CFTC. PS3 592.063 NPOR.PS3 GR.PS3 20.828 TENS. PS3 1375.000 DEPT. 9300.500 NPHI.PS3 51.036 ENPH. PS3 43.363 TNPH. PS3 TNRA.PS3 4.202 RTNR.PS3 4.098 ENRA.PS3 5.910 CFEC. PS3 CNEC.PS3 2535.870 RCEF. PS3 435.595 RCEN. PS3 2394.935 RCNT. PS3 RCFT. PS3 342.113 CNTC. PS3 1531.519 CFTC. PS3 374.907 NPOR.PS3 GR.PS3 124.688 TENS.PS3 1370.000 24.905 564.757 2547.432 24.905 24. 905 564. 757 2547. 432 24. 905 35. 726 528. 714 1913.206 37.170 30. 839 581. 897 1920. 582 31.107 46.699 429.068 1634.619 45.699 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 27 **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SU~F~RY VENDOR TOOL CODE START DEPTH ........................... CNTG 9574.0 $ 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): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CNTG DUAL NEUT. GR GA~VA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): STOP DEPTH .......... 9278.0 31-0CT-97 44.2 1330 31-0CT-97 9591.0 9580.0 9300.0 9575.0 1800.0 NO TOOL NUMBER ........... CNC-GA-125 SGC-SA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE 28 DRILL,S CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 2686.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE T~4PERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE 10.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EP I 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): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED IN TO SWS BHC DATED 12/27/70. THE PURPOSE OF THIS LOG WAS TO MONITOR GAS MOVEMENT. VOLUMES PUMPED: CRUDE=606 BBLS, DIESEL=lO BBLS. APPROXIMATE CURRENT GOC=9423 '. ***THIS IS THE PASS #4 RAW DATA******* $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 29 TYPE REPR CODE VALUE .............................. 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 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 1173643 O0 000 O0 0 9 1 1 4 68 NPHI PS4 PU 1173643 O0 000 O0 0 9 1 1 4 68 ENPH PS4 PU 1173643 O0 000 O0 0 9 1 1 4 68 TNPH PS4 PU 1173643 O0 000 O0 0 9 1 I 4 68 TNRA PS4 1173643 O0 000 O0 0 9 1 1 4 68 RTNR PS4 1173643 O0 000 O0 0 9 1 1 4 68 ENRA PS4 1173643 O0 000 O0 0 9 1 1 4 68 CFEC PS4 CPS 1173643 O0 000 O0 0 9 1 1 4 68 CNEC PS4 CPS 1173643 O0 000 O0 0 9 1 1 4 68 RCEF PS4 CPS 1173643 O0 000 O0 0 9 1 1 4 68 RCEN PS4 CPS 1173643 O0 000 O0 0 9 1 1 4 68 RCNT PS4 CPS 1173643 O0 000 O0 0 9 1 1 4 68 RCFT PS4 CPS 1173643 O0 000 O0 0 9 1 1 4 68 CNTC PS4 CPS 1173643 O0 000 O0 0 9 1 1 4 68 CFTC PS4 CPS 1173643 O0 000 O0 0 9 1 1 4 68 NPOR PS4 PU 1173643 O0 000 O0 0 9 1 1 4 68 GR PS4 GAPI 1173643 O0 000 O0 0 9 1 1 4 68 TENS PS4 LB 1173643 O0 000 O0 0 9 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 9591.500 NPHI.PS4 36.386 ENPH. PS4 48.256 TNPH. PS4 TNRA.PS4 3.399 RTNR.PS4 3.471 ENRA.PS4 6.311 CFEC.PS4 CNEC. PS4 2409.966 RCEF. PS4 381.857 RCEN. PS4 2258.634 RCNT. PS4 RCFT. PS4 513.351 CNTC. PS4 1727.223 CFTC. PS4 519.745 NPOR.PS4 GR.PS4 49.094 TENS.PS4 1030.000 34. 013 381. 859 1807. 757 34. 013 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 30 DEPT. 9500.000 NPHI.PS4 TNRA.PS4 3.242 RTNR.PS4 CNEC. PS4 2779.494 RCEF. PS4 RCFT. PS4 647.724 CNTC. PS4 GR.PS4 966.000 TENS.PS4 DEPT. 9400.000 NPHI.PS4 TNRA.PS4 2.201 RTNR.PS4 CNEC. PS4 3269.872 RCEF. PS4 RCFT. PS4 1172.414 CNTC. PS4 GR.PS4 23.766 TENS. PS4 DEPT. 9300.000 NPHI.PS4 TNRA.PS4 2.808 RTNR.PS4 CNEC. PS4 3216.457 RCEF. PS4 RCFT. PS4 847.142 CNTC. PS4 GR.PS4 46.844 TENS.PS4 DEPT. 9277.000 NPHI.PS4 TNRA.PS4 3.861 RTNR.PS4 CNEC. PS4 2568.191 RCEF. PS4 RCFT. PS4 425.838 CNTC. PS4 GR.PS4 103.688 TENS.PS4 33.526 ENPH. PS4 3.342 ENRA.PS4 569.738 RCEN. PS4 2050.313 CFTC.PS4 1375.000 15.848 ENPH. PS4 2.290 ENRA.PS4 983.346 RCEN. PS4 2661.381 CFTC. PS4 1370.000 25.612 ENPH. PS4 2.694 ENRA.PS4 830.628 RCEN. PS4 2450.665 CFTC. PS4 1370.000 44.809 ENPH. PS4 4.060 ENRA.PS4 481.797 RCEN. PS4 1615.862 CFTC. PS4 1375.000 31.853 TNPH. PS4 4.849 CFEC. PS4 2578.737 RCNT. PS4 667.723 NPOR.PS4 19.091 TNPH. PS4 3.439 CFEC. PS4 3132.309 RCNT. PS4 1197.604 NPOR.PS4 23.420 TNPH. PS4 3.948 CFEC. PS4 3117.311 RCNT. PS4 916.412 NPOR.PS4 39.718 TNPH. PS4 5.593 CFEC. PS4 2441.977 RCNT. PS4 429.393 NPOR.PS4 30. 059 573.182 2093. 923 30. 996 17.652 950.878 2808.094 17.429 24. 098 814. 712 2671.195 22. 783 41.196 459.166 1701.176 40.921 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/03/16 ORIGIN : FLIC TAPE NAME : 98132 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-1, API# 50-029-20078-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1998 09:46 PAGE: 31 **** REEL TRAJLER **** SERVICE NAME : EDIT DATE : 98/03/16 ORIGIN : FLIC RRRL NAME : 98132 CONTINUATION # : PREVIOUS R~Rr, : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-1, API# 50-029-20078-00 COMPANY NAME I ARCO ALASKA. INC' ~E~ NAME FIEbDNAMg BOROUGH ~ NO~TH SbOPE STATE ~ ALASKA API NUMBER ~ 50-029-200?8-00 REFERENCE NO ~ 934.53 RECEIVED DEC 0 1 199~ 011 & aa~ Oon~. Commle~ion Anchorage ~IS Tar~e Ve~Itlcat~on Ltsttnq $Ch[umbeTqer Alaska Computtnq Cen~e.r PAGE~ DATE : 93/11/16 ORIGIN : rbtc REEL NAME : 93453 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., D.S. 04-01, PR~!>HOE, 50-029-20075-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE' : 93/11/16 ORIGIN : FLIC TAPE NAME : 93453 CONTINUATIO..~ # : 1 PREVIOUS TAPE COMMENT : ARCO ALASKA !NC., D.S, 04-01; PR~;pHOE, 50-029-20078-00 P~UDHOE BAY WELL NAME{ D.S'~ 4'01 API NUMBERI 5002920078()%ii OPERAToRI ARCO ALASKA' OPERATOR WITNESS: M, SANT SURFACE LOCATION SECTION: 34 TOWNSHIP: 11N RANGE: 15E FNb: 1327 FSL: FEL: 295 FWb: ELEVATION(MT FROM ESL O) KELLY BUSHING: 64,00 DERRICK FLOOR: 63,00 GROUND bEVEL~ 25'00 WELL CASING RECORD ~ST STRING 2ND STRING 3RD STRING PRODUCTION STRING INC. OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN), DEPTH (FT) WEIGHT (LB/FT) 9,625 2464,0 47,00 9,625 9747,0 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) bis Tape verification Listing Schlumperger Alaska CompUting Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURYE CODE: GR RUN NUMBER: PASS NUMBER: I DATE LOGGED: LOGGING COMPANY: SCHLUMBERGER BASELINE DEPTH 88888 0 9334 0 9]02 5 9285 5 lO0 0 16'NOV-lEg3 !~:3g ---EOUIVASENT UNSHIFTED DEPTH---=------ GRCH 88883,5 9~29 THE DEPTH, ADJUSTMENTS SHOWN ABOVE REFLECT OR_CH OF PASS ~ TO THE OPEN'HOL~ BCS/GR~. ALL OTHER CNTD CURVES OF ASS 1 WERE CARRIED WITH.HAT SHIFT. $ **** FILE HEADER **** FILE NAME : EDIT SERVICE : FLIC VERSION : 001C01 DATE : 93/11/!6 MAX REC SiZE : t024 FIDE TYPE : LO LAST FILE PAGEl DEPTH INCREMENT: # FILE SUMNARY LDWG TOOL CODE GRCH CNTD FILE HEADER FILE NUMBER: ! EDITED CURVES Depth sh~.fted: and cliPPed curves ~Or each pass in separate ~lies, PASS NUMBER 1 0.5000 START DEPTH 9686,0 9698.0 STOP DEPTH 9274~0 9274,0 CURVE SHIFT DATA ' PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR~SHIFTS bDWG CURVE CODE~ GR PASS NUMBER~ '''''"----EQUIVALENT UNSHIFTED DEPTH---------. BASELINE DEPTH GRCH CNTD hiS~ TaPe Verification Listing Schlumberoer Alaska Computing Center i6~N0¥-~993 i5~39 REMARKS: THIS FI.LE CONTAINS THE FIRST PASS OF THE CNTD, AND NO PASS TO PASS SHIFTS WERE APPbIED TO THIS DATA, THE GR,OPN IS CONTAINED: IN THIS PASS' $ LIS FORMAT DATA PAGE~ DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *~ ...--......................... TYPE ~PR CODE VALUEi ! 66 0 2 66 0 3 73 44 4 66 ! 5 66 6 73 7 65 8 68 0,5 9 65 11 66 23 12 68 13 66 0 14 65 15 66 68 16 66 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API AP! AP1 APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 440743 NPHI CNTD PU 440743 NCNT CNTD CPS 440743 FCNT CNTD CPS 440743 CRAT CNTD 440743 NRAT CNTD 440743 CNTC CNTD CPS 440743 CFTC CNTD CPS 440743 GRCH CNTD GAPI 440743 TENS CNTD LB 440743 GR OPN GAPI 440743 00 000 00 0 1 1 I 4 68 0000o00000 00 000 O0 0 I 1 I 4 68 0000o00000 00 OO0 O0 0 I I 1 4 68 0000o00000 00 000 00 0 1 I 1 4 68 0000¢)00000 00 000 00 0 I 1 1 4 68 0000n00000 O0 000 O0 0 1 I i 4 68 0000o00000 00 000 OD 0 I 1 1 4 68 0000o00000 00 000 00 0 1 1 I 4 68 0000(>00000 00 000 00 0 1 1 I 4 68 0000000000 00 000 00 0 1 1 1 4 68 0000000000 00 000 O0 0 I I I 4 68 0000000000 LIS TaPe Verification SChlumberger Alaska Comput ~ Center ** DATA DEPT. 9760,~00 CRAT'CNTD '999, '50 GRCH'CNTD -999,250 16'NOv'1993 15:39 DEPT CR AT ,' CNTD GRCH ,CNTD 9200,000 -999,2§0 -999,250 END OF DATA NPHI,CNTD -999,250 SCNT.C?~TD NRATiCNTD -999,250 CMTC.C,~TD TENS'CNTD '999,250 GR,OP,~ NPHI,CNTD -999.250 NCNT,CNTD MRAT'CNTD -999 !~50 CNTC~CNTD TEN$,CNTD -999:50 GR,OPN -999.250 FC[~T. C!~TD =999.250 CFTC.C~TD -9999.000 999.250 I~ ..NT C~.~TD ~999.250 CFTC,CNTD 178,400 PAGE~ 999 250 '999.250 '999,250 **** FILE TRAILER FILE NAME { EDIT ,OOl SE..VICE : FDIC VERSION : O0lCOI DATE : 93/!!/16 ~AX REC sIZ~ : !024 FlUE TYPE : bO LAST FILE **** FILE HEADER FILE NAME : EDIT ,002 S~RVICE : FDIC VERSION I O0!COl DATE : 93/11/16 ~AX REC SIZE : 1024 FILE TYPE : DO LAST FILE DEPTH INCREMENT: FILE SUMMARY LDWG TOOL CODE GRCH CNTD $ FIL~ HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and cliPPed curves for eac~ pass ~n separate f~les,. PASS NUMBER: 2 - 0,5000 START DEPTH 9688,0 9698,0 STOP DEPTH 92 ,0 ~BRVE SHIFT DATA ' PASS TO PASS(MEASURED DEPTH) BASELINE CURVE: FOR SHIFTS LDWG CURVE CODE: GR PASS NUf~BERI 1 bis TaPe Verification bistXng SChlumberger Al, asEa CompUtlnq Center BASELINE DEPTH 88888 o 9678 5 9675 5 9670 0 9669 0 9658 0 9650 5 9649 0 9647 5 9632 0 9605 0 9593 5 958! 5 9571 5 9550 0 9545 5 9528 0 9510 0 95OO .5 9479 5 9475 5 9458 5 9407 0 9400 0 9398 0 9383 0 9365 0 9355 5 9350 0 9348 5 9335 5 ,5 315.:5 9302'0 9299.0 9298'5 loo ''--'-''-'EQUIVALENT UNSMIFTED DEPTH-''-'-'-'' 88884,0 9666.0 CNTD 88884.0 9674~5 9671,0 9665.0 9654.0 9646.5 9645.0 9644,0 9628 ~ 96o : 9588,5 9577,0 9567 5 9546 5 954! $ 9524 .0 9506 0 9496 0 9475 5 947! 0 9454 5 9403 0 9396 5 9393 5 9380 0 9361 0 9352 0 9348 0 9345.5 933~.0 9322,5 93!1,0 9297.0 9294.5 9~94,5 9281.0 97,0 96,0 9329.5 · ~EMARKS: THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT PASS 2 GRCH, TO PASS 1 GRCH, AND PAS~ 2 NPHI TO PASS ! NPHI WITH ALL OTHER CNTD CURVES C~RRIED WITH THE NpHI SN~FTS, $ LIS FGR~AT DATA bis Ta~e Yerification Listing $ChlUm erger al.a$~a CompUting Center 16-NOV-1993 15:39 PAG~ ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE -64EB ** TYPE REPR CODE VALU~ ! 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 ll 66 25 ~3 66 0 14 65 ~T 15 66 68 16 66 ! 0 66 1 ** SET TYPE - CHAN * NAME SERV UNIT SERVICE API ID DEPT NPH! CNTD PU NCNT CNTD CPS FCNT CNTD CPS CRAT CNTD NRAT CNTD CNTC CNTD CPS CFTC CNTD CPS GRCH CNTD GAPI TENS CNTD LB ORDER # bOG FT 440743 O0 , m~m~mmm~~N~!mmmmmmmmm~#~m~mmmmmm~mmmmm#mmmmMmm~N~! API AP! API FILE NUMB NUMB SiZE REPR PROCESS TYPE CLASS MOD NUMB S~MP EbEM CODE (HEX) 000 O0 0 2 1 1 4 ~8 O0000OO000 440743 O0 000 O0 0 2 1 I 4 68 0000000000 440743 O0 000 O0 0 2 1 I 4 68 0000000000 440743 O0 000 O0 0 2 1 1 4 68 0000000000 440743 O0 000 O0 0 2 I i 4 68 0000000000 440743 O0 000 O0 0 2 I ! ~ 68 0000000000 440743 O0 000 O0 0 2 ~ I 4 68 0000000000 440743 O0 000 O0 0 2 1 1 4 68 0000000000 440743 O0 000 O0 0 2 1 1 4 68 0000000000 440743 O0 000 O0 0 ~ I 1 4 68 0000000000 ~mmm~mm~mmmmwm~M~N~!m~mmmmmm~m~mm~m#~mmmm#mmm~mmmmm#mmmm~#m#mm ** DATA DEPT' 9690.000 C~A?~CNTD 4.650 GRCH,CNTD -999,250 DEPT' 9274,500 C~AT~CNTD 6'417 G~CH'CNTD -999,:250 NPHI,CNTD NRAT~CNTD TENS'CNTD NPHI,CNTD NRAT,CNTD TENs. CNTD 2~'~26 NCNT,CNTD 3203 20~ '0!1 CNTC'CMTD 3219'379 ~265.000 ' ' 48.7~1 NCNT,CNTD 2546 938 7'~77 CNTC,CNTD 2408:820 1210.000 FCNT.CNTD CFTC.CNTD FCNT.CNTD CFTC.CNTD 641 282 576:107 38~.770 34 .085 END O? D~TA LiS TaPe~ Verification Listfng SChlumbergerA. las~a Computing Center ~6-NOV-~993 PAGEI **** FILE TRAILER **** FILE: NAM. E : EDIT ,002 SERVICE : FLIC VERSIOM I 001C0! DATE I 93/!1/I6 MAX EEC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE }{EADER **** FILE NAME : EDIT ,003 SERVICE I FblC VERSION : 001C01 DATE : 93/11/!6 MAX EEC SIZE : 1024 FIL~ TYPE I 50 LASTFILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES DePth shifted and clipped curves ~or each pass in separate files, PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 IL.E SU~MA. RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9694,0 9275,~ CNTD 9697,0 9275, $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LD~G CURVE CODE: GR PASS MUMBER{ ! BASELINE DEPTH 88888,0 9680,0 9666,5 9658 5 9655 0 9649 5 9646 5 9628'0 9623'5 9602.0 9586,0 ----------EQUIVALENT UNSHIFTED DEPTH---------- GRCH CNTD 88887,5 88887,5 9679'5 9665',5 9658,5 9654'0 9649,0 9646'5 9627,5 9622.5 9601'5 9584.5 bis ?ave: Verification Listing SChlumberger Alaska ComputlnQ Center !6-NOv-1993 ~5)39 56O .9554 9552 9550 9546 9544 9542 9520 9506 9472 9462 9461 9458 9455 944!, 9437, 9425, 9396, 9393 9385 9364 9355 9330 9330 9312 9307 9296 9295 9288 9281 5 0 5 5 5 5 5 5 5 5 0 5 5 0 0 5 0 0 5 5 5 0 9460.5 9458,0 9454 ~ 9441:, 9 5i! 9424 9396 9393,0 9384.5 9363,0 9354.5 9329,5 9329.5 9311.0 9306'0 9296~0 9294.5 9289,0 9283.0 !01.5 100,5 g582 0 559 5 9553 .5 9546 5 9544 0 9541 5 9520 5 9506 0 947~ 0 946 0 THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT PASS 3 GRCH, TO PASS ! GRCH, AND PASS 3 NPH! TO PASS I NPHI. WITH AbL OTHER CNTD'CURVES CARRIED WITH THE NPHI SHIFTS, # bis FORMAT DATA PAOEI ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EM ** TYP~ REPR CODE VA~UE ! 66 0 2 66 0 3 73 40 4 66 1 5 66 SChlUmbergerAlaska CompUtlnO Center TYPE REPR CODE VAbUE~ 6 73 7 65 8 68 0,5 9 65 FT 1~ 66 25 13 66 0 14 65 FT 15 66 6~ 16 66 1 0 66 *.* SET TYPE - CHAN * NAM~ SERV UNIT SERVICE ID ORDER # DEPT FT 4407 NPH! CNTD PU 4407 NCNT CNTD CPS 4407 FCNT CNTD CPS 4407 CRAT CNTD 4407 NRAT CNTD 4407 CNTC CNTD CPS 4407 CFTC CNTD CPS 4407 GRCH CNTD GAPI 4407 TENS CNTD LB 4407 43 O0 000 O0 0 43 O0 000 O0 0 43 O0 000 O0 0 43 O0 000 O0 0 43 O0 000 O0 0 43 O0 000 O0 0 43 O0 000 O0 0 43 O0 000 O0 0 43 O0 000 O0 0 43 O0 000 O0 0 API APl APl API FILE NUMB NUMB SIZE REPR PROCESS LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) 3 ! 1 4 68 0000000000 3 1 1 4 68 0000000000 3 ! I 4 68 0000000000 3 1 I 4 6~ 0000000000 I 1 4 68 0000000000 ~ 1 i 4 68 0000000000 3 1 ! 4 68 0000000000 3 t 1 4 68 0000000000 3 1 I 4 68 0000000000 3 I I 4 68 0000000000 m~mmmm~mmmmmm~mmmm~,~mmmmm~mmM#mm~mmmm~~ DATA DgPT,: CRATjCNTD GRCH'CNTD DEPT': CRAT.CNTD GRCH'CNTD · ,500 g69~,895 276.750 NPHIeCNTD NRAT,CNTD TENS. CNTD 55,599 NCNT.CNTD 2353 422 .'851 CNTC'CNTD 2279'199 !210'000 ~ ' 9275.500 NPHI.CNTD 53.544 7.455 NRAT.CNTD 7.~30 -999,250 TENS,CNTD 1215,000 NCNT,CNTD CNTC'CN'rD 2454 277 2414:870 FCNT.CNT~ CFTC,CNT{~ FCNT.CN]~i) CFTC.CNTD 309 33 339.441 317.656 END OF DATA SChlumberger~.!as~a ComPut/nq Center **** FILM TRAILER *~** FILE NAME : EDIT ,003 SERVICE : FbIC VERSION : O01COI DATE : 93/11/!6 MAX REC SIZE : 10~4 FILE TYPE : LO LAST FILE : **** FI5~ HEADER FILE NAME ~ EDIT ,004 SERVICE : FLIC VERSION : O01COl DATE : 93/!I/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE 16-NOV-1993 15:139 10 FIbE~HEADER FILE NUMBERI 4 AVERAGED CURVES ~mpensated Neutron: Arithmetic average of edited Passes for all curves, -... !sed Neutron: Unaveraged edited Pass i Gam~a Ray"and baC~round 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 CNTD 1,2, 3, $ REMARKS; TME.~RITMMETIC AVERAGE OF ~A$$~$ I 2 & 3 WAS COMPUTED ' AFTER. ALL DEPTH ADJUSTM~NT~ WERE A~PLIED.~ ' LIS FORMAT ~ATA ** DATA ¥OR~AT SPECIFICATION RECORO ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE t 66 0 2 66 0 3 73 40 4 66 1 5 $6 SehlUml~eroer Ala$!<a ComPuting Center 16-NOV-1993 15~39 PAGE~ !1 TYPE .EPR CODE VALUE 7 65 8 68 0 5 9 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 I ~* SET TYPE - CHAN * NAME SERV [INIT SERVICE API ID ORDER # LOG DEPT FT 440743 O0 NPH! CNA¥ PU 440743 O0 NRAT CNAV 440743 O0 CRAT CNA¥ 440743 00 NCNT CNAV CPS 440743 00 FCNT CNAV CPS 440743 00 NTC CNAV CPS 440743 O0 FTC CNAV CPS 440743 O0 GRCH CNAV GAP! 440743 O0 TENS CNAV LB 440743 00 AP1 AP1 AP1 FILE TYPE CLASS MOD NUMB 000 O0 0 4 1 000 O0 0 4 1 000 O0 0 4 000 O0 0 4 000 O0 0 4 1 000 O0 0 4 1 000 O0 0 4 000 O0 0 4 000 O0 0 4 000 O0 0 4 NUMB NUMB SIZE REPR PROCESS SAMP ELE~ CODE (HEX) ! 4 68 0000000000 I 4 68 0000000000 0 ! 4 68 0000000000000 I 4 68 000000 I 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 i 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 mm~mmmm#mmmmmmmmmmmmmmmmmmmmmm~#~m ** DATA ** DEPT,~ 968~ 500 NPHI.CNAV NCNT.CNAV 307 ~313~ FCNT.C~AV GRC,'CNAV 288.305 TEN$.CNA¥ DEPT,i 92~-000 NPHI.C~AV NCNT'C~AV -9 ,250 FCNT.CNAV GRCH,CMAV -999,250 TENS..CMAV 33,555 591.433 1243,209 '999,250 2999.2~o 999'.250 NRAT,,CNAV CNTC,CNAV NRAT,CNA¥ CNTC,CNAV 5.466 296t.319 -999,250 -999,250 CRAT'CNAV CFTCiCNAV CRAT.CNAV CFTC.CNAV 5:,207 547'035 -999.250 -999,250 END OF DATA TaPe Ver~lcatfon Llstin Schlumberger A~$ka computin~ Center 15:39 **** FiLE TRAILER FILE NAME : EDIT ,004 SERVICE : FLIC VERSION : O01CO1 DATE : 93/11/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST' FILE **** F!LF HEADER **** FILE NAME = EDIT ,005 SERVICE : FLIC VERSION : 001C0! DATE :93/11/16 MAX REC SIZE : 1024 FILE TYPE : 50 LAST FILE : FILE HEADER F~L~ NUMBER 5 RAW CURVES CUrves and log-header data for each pass in separate PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TO0~ CODE START DEPTH CNTD 9708,5 LOG HEADER DATA DATE LOGGED~ SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD' LOGGER(FT)~ TOP LOG INTERVAL (FT): BOTTO~ LOG INTERVAL (FT)~ bOGGING SPEED (FP'HR.): . DEPTH CONTROL USED (YES/NO): STOP DEPTH 9277,5 TOOL STRING~ (TOP TO BOTTOM) " VENDOR TOOL"CODE TOOt TYPE $ ~OREHOLE AND CASING DATA files; raw background pass In last 23'SEP-93 CP 38.2 I030 23"SEP-93 9700,0 9700;0 9280'0 9697'0 !800.0 NO TOOL NUMBER OB CNC DA 146 Tape veri~:!c~tion bisti g Chlumberger Alas~a Computing center OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT)~ LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY . G):~EGF):CD SURFACE TEMPER~LB/ BOTTOM HOLE TEMPERATURE FLUID SALINITY FLUID LEVEL CFT)~ FLUID RATE AT WELLHEAD WATER CUTS (PCT)~ GAS/OIIJ RATIO: CHOKE NEUTRON TOOL TOOL TYPE (EPITHERMAb OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 2464,0 NEITHER SANDSTONE 2.65 BbUELINE COUNT RATE NORMALIZATION IN OiL ZONE TOP NORMALIZING wINDOW eFT): BASE NORMAL!ZING~ WINDOW (FT): # BLUEbINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE [,OW SCALE~(CP$): 0 ~EAR COUNT RATE HIG~ SCALE'(CPS): 2~000 TOOL STANDOFF (IN): REMARKS: TIE-IN SWS BHCS DATED 11-30-70 WELL WAS FLOWING IMMEDIATELY PRIOR T© LOGGING PU~PED ~INTO WELL WITH~490 BBLS C~UDE TOTAL PUMPED AT 0.75 BP~ WHILE 50GOING FOUND GOC AT APPROX 9426' RAN 2,5" CNL ON SANDSTONE MATriX $ · IS FORMAT ~ATA ** DATA FORMAT SPECIFICATION RECO~D ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 ~ 66 0 Schlumberger Alaslca ComPutlnq Center [6~NOV-1993 !5139 PAOB:I, 14 TYP~ REPR COD~ YAbU~ 44 1 3 73 4 66 5 66 6 73 ? 65 I1 66 23 t2 68 [3 66 0 [4 65 FT t5 66 68 0 66 1 NAME SERV [)NIT SERVICE API AP1 AP') APl FILE NUMB ID ORDER # bOG TYPE CLASS MOD NUMB SAMP NUMB SIZE REPR PROCESS EbEM CODE (HEX) mmmNmmmmmm~mmN~mmmmm~mmm~m~ 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 O0 4 68 00000000000 4 68 0000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ** DATA ** GR P'Sl 246'000 TENS~P$! 1020,.00 CCh'PSi 0~00 DEPT, 9 ~. 0 NPHI,P$! 48.556 7.5 0 TNRA PSi GR.PS1 79 ~94 RCFT.PSI 6,531 CNTCeP$! 2387.4~9 CFTC.PSi 387. 9 ** END OF DATA SChlumbergerAtaska Computinq Center [6.,NOV,.1993 15=]9 FILE NAME : EDIT ,005 V~RSION ~ 00)~0~ DATE . 93 1.16 MAX REC SiZE : 1024 FILE TYPE : LO ~AST FILE : **** FIL~ HEADER FILE NA~E : EDIT ,006 SERVICE ~ FLIC VERSION : 001C01 DATE ~ 93/!!/!6 MAX REC SIZE : F!LK T~PK : ~0 L~$T FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate PASS NUMBER: 2 D~PTH INCRE~ENT~ 0,5000 F~LE SUMMARY VENDOR TOOL CODE START DEPTH CNTD 9707.5 $ LOG HEADER DATA STOP DEPTH 9278,5 DATE LOGGED: 8OFTWARE VERSION~ TINE LOGGER ON BOTTOM: TD DRILLER eFT): TD LOGGER(FT): TOP LOG INTERVAL eFT): BOTTOM LOG. INTERVAL( LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) V~NDOR TOOL CODE TOOL,TYPE CNTD CASING COLLAR LOG CNTD TELEMETRY CARTRIDGE/OR CNTD COMPENSATED NEUTRON $ ~O~EHOLE .AND CASING DATA files; raw background pass in last 23-8EP-93 CP 1030 23-SEP-93: 9700,0 9700,0 9280'0 !800 TOOL NUMBER CAL UB ATC CB 1152 CRC DA 146 LIS TaPe Verification Listing chlu. mberger AlasKa CompUting Center OPEN HOLE BiT SIZE DRILLERS CASING DEPTH LOGGERS CASING DEPTH (FT): # ~OREHObE - N ~O, DITIONS FLUID FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY FLUIDTLEVEL (FT): FLUID RA E AT WELLHEAD WATER CUTS (PCT): GAS/OIL RAT!O: CHOKE NEUTRON TO05 TOOL TYPE CEPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION ('IN): BLUELINE COUNT RATE NORMALIZATION IN O!L~ ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZ!NG WINDOW BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER 0 4O0O 0 22000 FAR COUNT RATE LOW SCALE~(CP$): AR COUNT RATE HIGH SCALE NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS)~ TOoL STANDOFF (IN): # REMARKS: 2464,0 NEITHER SANDSTONE 2,65 TIE'IN SWS BHCS DATED 11'30'70 WEbb WAS FLOWING IMMEDIATELY PRIOR TO bOGGING PUMPED INTO WELL WITH 490 BBLS CRUDE TOTAL PUMPED AT 0.75 BPS WHILE LOGGIN~ FOUND GOC AT APPROX 9426' RAN 2,5" CML ON SANDSTONE MATRIX $ LIS FORMhT DATA 16 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 ~ 66 0 bis Tape veriflcation Blsting SChlumberger AlasKa Computing Center 16-NOV-'!993 15:39 PAOEI TYPE REPR CODE VALUE 44 1 3 73 4 66 5 66 6 73 7 65 9 65 il 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl APl AP1 API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 440743 O0 000 O0 0 6 I I 4 68 0000000000 NPM! PS2 PU 440743 O0 000 00 0 6 I I 4 68 0000000000 ~NR PS2 440743 O0 000 O0 0 6 I 1 4 68 0000000000 RA PS~ 44074~ 00 000 00 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 440743 O0 000 O0 0 6 i 1 4 68 0000000000 ~c~ ~s~ c~ ~4o~ oo ooo oo o ~ ~ ~ 4 ~ oooooo~§§o CNTC P$2 CPS 440743 00 000 O0 0 6 1 I 4 68 000000 0 CfTC PS2 CPS 440743 O0 000 O0 0 6 ! 1 4 68 0000000000 GR P$2 GAPI 440743 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 440743 O0 000 O0 0 6 I I 4 68 0000000000 oo ooo oo o oooooooooo ** DATA ** D~ 9707,500 ~PHI,PS2 45i~51 RTNR,P$2 6,476 TNRA,PS2 R !P$2 276i,421 RCFT..PS2 426' 96 CNTC.PS2 2684,015 CFTC.PS2 GR.~S~ 267.250 TEN$,.PS2 985 000 CCL,PS2 0.000 RCN ~PS2 2546,938 RCFT.PS2 3~4.7' ' CNTC.PS2 2408 820 CFT PS2 GR,PS2 82.563 TENS.PS2 12.0.000 CCh,PS2 0 000 6.769 396,529 34~, END OF DATA LiS Tape. Verification Listing SChlUmberger AlasKa Computing Center ~ FIhf TRAILER FiLE NA~E ~ EDIT ,006 VERSION ~ 00!C01 DATE { 93/11/16 MAX REC SIZE : 1024 FILE TYPE ~ LO b~ST FILE **** FILE HEADER **** FILE NAME : EDIT ,007 SERVICE : FLIC VERSION : O01CO! DATE ~ 93/ll/16 MAX REC SIZE { 1024 FILE TYPE : bO LAST FILE : 16-NOV-1993 15139 PAGE{ 18 !LE HEADER RaW CURVES Curves a~d log header data for each pass in separate PASS NUMBER. ' DEPTH INCREMENTI 0~5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTD 97!3,5 $ ~OG HEADER DATA DATE LOGGED: SOFTWARE VERSlON~ TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT)~ TOP LOG INTERVAL (FT)~T BOTTOM LOG INTERVAL CF..,)~ LOGGING SPEED (FPHR)~ DEPTH CONTROL USED (YES/N~): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTD CNTD CNTD $ CASING COLLAR LOG TELEMETRY CARTRIDGE/OR COMPENSATED NEUTRON BOREBOLE &ND CASING DATA files; raw bacKqround pass in last 23-SEP-93 CP 38,2 1030 23-SEP-93 9700.0 9700~0 928010 9697'0 1~0o.o TO0b NUMBER CAL UB ATC CB ~ !52 CNC DA !46 ~!$ Tape Verification .tlstin SChlUmberger AlasKa Computin~ center 16-NOV-1993 15139 DEPTH (FT DRILLERS CASING LOGGERS CASING: DEPTH (FT)~ BOREHOLE CONDITIONS FLUID TYPE~ FLUID DENSITY SURFACE TEMPERATURE, [DEGF)~ BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY FLUID bEVEL FLUID RATE AT WELLHEAD WATER CUTS GAS/OIL RATIO: CHOKE NEUTRON TOOL -'TOOL. TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN)I BLUELINE COUNT RATE NORMALIZATION IN Otb ZONE BASE NORMALIZING WINDOW (FT): BLUEL!NE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 4OO0 0 22000 FAR COUNT RATE HIGH SCALE '(CPS): NEAR COUNT RATE LOW SCALE (CP~)~ NEAR COUNT RATE HIGH SCAL~; (CPS)~ TOOL STANDOFF (IN): 2464,0 NEITHER SANDSTONE 2.65 TIE-IN SWS BHCS DATED 1!-30-70 WELL WAS FLOWING IMMEDIATELY PRIOR TO LOGGING PUMPED INTO WELL WITH 490' 8BI~S CRUDE'TOTAL PUMPED AT 0.75 BPM WHILE LOGGING FOUND GOC AT APPROX 9426' RAN 2.5" CNL ON SANDSTONE MATRIX $ L~S FORMAT DATA PAGE! 19 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR..CODE VALUE I 66 0 2 66 0 Sc~lu.mVerger ~l~s~: CompUting Center !6-NOV-lg93 15:39 TYPE REPR CODE .AbUE 3 73 44 4 66 ! 5 66 6 73 7 65 9 65 I1 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API APl APl AP! FILE NUMB NUMB SIZE REPR PROCES~ ID ORDER # bOG TYPE CbA$S MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 440743 O0 000 00 0 7 ! I 4 68 0000000000 -- 0000000000 NPH! PS3 RTNR PS3 TNRA PS] RCNT PS3 RCFT PS3 CNTC PS3 CFTC PS3 TENS PS3 .~,~o~4~ oo ooo oo o 7 ~ , ~ ~s 440743 O0 000 O0 0 7 1 1 4 68 0000000000 440743 O0 000 O0 0 7 ! ~ 4 6B 0000000000 CPS 440743 O0 000 O0 0 7 I 1 4 68 0000000000 CPS 440743 O0 000 O0 0 7 , I 4 65 0000000000 CPB 440743 O0 000 O0 0 7 I 1 4 68 0000000000 CPS 440743 O0 000 O0 0 7 ! 1 4 68 0000000000 GAPI 440743 O0 000 O0 0 7 I ' 4 68 0000000000 5B 440743 O0 000 O0 0 7 ' I 4 68 0000000000 o~ o~ o 7 ~ ! ~ ~. oooooooooo V 44074] O0 mwmmmmmmmmmmmmmmmmmmmm ** DATA DEPT..~ RCNT'PS3 GRIPS3 DEPT, RCNTgPS3 GRIPS3 971~.500 NPRi.PS3 45*783 RTNR.PS3 6.545 TNRA.PS3 285 ,56! RCFT'PS] 436,725 CNTC'PS3 2778.432 CFTCeP$3 296.500 TENS.,P$ 965.000 CCh,PS3 0.000 9275,000 NPHI.PS3 53.544 RTNR.P$3 7,455 TNRA.PS3 24~4.277 RCFT4PS3 339.441 CNTC.PS3 241~2870 CFTC,PS3 8~.688 T~S.PS3 12ts;ooo cc~.Ps3 "~. ooo 40~ 's41 ,134 ? 0 END OF DATA ** SchlumbergerA. iaska CompuCtnq Center 16-NOV-t993 15~39 2! $~RVICE ~ FbIC VERSION : 001~C01 DATE : 93/11/t6 MAX AEC' SIZE : 1024 FILE TYPE : LO bAST FILE **** TAPE TRAILER SERVICE NAME : EDIT DATE i ORIGIN t FDIC TAPB NAME , 93453 P E, I US TAPE COMMENT I ARCO ALASKA INC.. D.S, 04-0~. PRUDHOE. 50-029-20078-00 **** REEL TRAILER **** .SERVICE NA~E : EDIT DATE : 93/11/t6 ORIGIN I rbIC REEL NAME ,~ 93453 CONTINUATION # t PREVIOUS REEb ~ COHMENT ) ARCO ALASKA INC., D.S. O4-0i. PRUDNOE, 50-029-20078-00 *------- SCHLUmBERGeR COMPANY ~A~E : ARC© ALASKA INC. wELL NAME : D.S. 4-! FIELD NAME : PRUOHOE kAY BOROUGH : NORTH SLOPE STATE : ALASKA API N[~MBER ~ 50-029-20078-00 REFERENCE NO : 74019 **** REEL HEADER **** SERVICE NA~!M : EDIT DATE : 90/08/24 O~I~IN : F'L~C ~EEL NAME : 74019 CO~,~INUATION PREVIOUS ~EEL CO~EN'~ : a~CO ALASKA INC.,PRUD~{OE ~AY,D.8. 4-1,50-0~9-20078-00 **** TAPE HEADER **** SERVICE NA~E : EDIT })ATE : o0/08/~4 ORIGIN : F'LIC TAPE NAME : 74019 CONTINUATION # : 1 PREVIOUS TAPE : CO~ENT : ARC() ALASKA INC.,PRUDHOE BAY,D.S. 4-1,5o-029-20078-00 **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O0!A04 DATE : ~AX REC SIZE : 1096 F~LE TYPE : LAST FILM : ******************************************************************************* ******************************************************************************* ** ** SCHLUMBERGER wE£,L SERVICES ** ** ******************************************************************************* ******************************************************************************* COMPANY NAME: ARCO ALASKA INC.. WELL: D.S. 4-1 ~7ELD: PRUDHOE BAY ~OROUGH: NORTH SLOPE STATE: ALASKA AP1 NUMBER: 50-029-20078-00 LOCATION: !3~7' S & 295' W NE CRN SECTION: RANGE: 15E PER~ANENT DATUM: ESL MEASURED FROM RKB 64 ELEVATION: 0 ABOVE PERMANENT DATU9 ~ch!uro.lerqer ~,la ~a Computlnq Center E!:EVATIOM$ KS: 64 DF: DATE bOGGED: 13-AUG-90 RUN NUMBER~ O~E TD DRIbLER~ 9739 TD L~GGE~: ~676 BIT SIZE 1: !2.~5 BIT SIZE 2: TUBING BIT SIZE 3: T~FING TYPE FLUID IN MOLE: P~©DUCED FLUIDS TIME LOGGER ON BOTTOm: ~0~41 LOGGING DISTRICT~ P~UDHOE BAY LOGCING ENGINEER: SCHWARTZ WITNESS~ WHIODON /~EINT$ CAL~ 206 ATC CB 433 TND P 90 TNG PB 90 TNC P 90 ATE AA 277 FIELD REd, ARKS: TIED INTO DA GR/CCL LOG DATED 7-~0-86, [~CO~:TSC~/TSCF=RATI0 bCO~ImT$CN/TSCF:RATIO LCOlmTSCN/TSCF=RATIO DATE JOB STARTED: 24-AUG-90 JOB REFERENCE MO: 740~9 LDP/AMA~ ~. SI~ES ARCO ALASKA INC. PRUDHOE BAY PASS ONE - FRO~ FIELD FILE !O DATA SAMPLED EVERY -.5000 FEET DATA INCbU!)~D - center , * TODi, E×TE~8ION TOOL * TYPE USED NAME * * TDT-P ,PS~ THERMAL DECAY TOOb , TYPE : CONS TI.I~ VALU DEFI N ARCO ALASKA INC,. Company Name ~N P~UDHOE BAY Field Name · WN ~ 4-1 Well Name APIN ou-U29-20078.O0 AP! Serial Number FL i327' S & 295' W NE CR~ F~eld Location SECT 34 Section TOWN lin Township RANG 15E Range COUN NORTH SLOPE County STAT ALASKA State 0r province NAT! USA Nation bhT! Latitude LONG Longitude WITN WHIDDON /REINTS witness' Name SON 391432 Service Order Number PDAT ~Sb Permanent datum PD F~ 0 .~F ...... R~B Log ~easured From APO FT 64, EK~ mT EDF FT · 9~9,25 EGL PT 25 TDD FT 97~9. BLI FT 9669, Bottom Loq Interval TLI FT 9220' Top boq Interval TLAB 10:41 Time Logger At Bottom STF~ DEGF 0, TYPE : CURV DEFI DFPT De th Cha~nel Name $IG~ $1~.ma" (Neutron Capture Cross section). STDT Status of TOT TPH~ TOT Porosity !SH~~ TOT Shunt Cqrrent S~FD St~ma formatio~ ~ far detector (TDTP) SFND Silica ~oTmation near detector ........ - in~ Center SiGma borebole - far detector (TDTP) Sigma borehole - near detector (TDTP) Far TDTM Count Rate gear TDTM Count Rate Amplitude formation -- far detector' (~DTP) ~mplltud~ borehole -- Far detector (TDTP) Amplitude formatio~ - near detector (TDTP) amplitude Borehole -- near detector (~DTP) SIGM Correction Borehole s~gma (corrected) -- TDTP ginitron ~ode monitor ratio CTDTP) TDT Ratio Standard deviation of Sigma-for~ation (TDTP) Backoround, Near Gates Far Bac~oroun4 Total counts analyzed - near detector (TDTP) Total, counts analyzed - far detector (TDTP) Total, counts - near detector (TDTP) Total counts - far detector (TDTP) Selected ~ates count rate - near detector (TDTP) Selected 9ares count rate - far detector (TDTP) Inelastic counting rate -near detector (TDTP) Inelastic counting rate -far detector (TDTP) Raw Near 1st Gate Raw ~ear 2nd Gate Raw Near 3rd Gate Raw Near 4th Gate ~aw ~ear 5th Gate Raw gear 6th Gate ~aw Near 7tn Gate Raw ~ear 8t~ Gate Raw ~ear 9th Gate Raw Near 10th Gate Raw ~ear l~th Gate ~aw ~ear l~th Gate Raw Near ~3th Gate Raw Near 14th Gate Raw Near 15th Gate Raw gear 16th Gate Raw ~ar 1st Gate ~aw Far 2nd Gate Raw Far 3rd Gate Raw Far 4th Gate Raw Far 5th Gate Raw Far 6th Gate Raw Far 7t~ Gate Raw Far ~tb Gate Raw Far 9th Gate ~aw Far lOt~ Gate Raw Far l~th Gate ~aw Far 12tn Gate Raw Far ~]tb Gate Raw Far !4t~ Gate $~hlUKiberqer AlasKa Comput,~;~ Center DEFI RF!5 Raw Far 15tt~ Gate RF16 Raw Far l~tn Gate AVEO Averaqe OutD%It 0 AVE~ AveraGe Output ~ GR Gamma Ray TMMS Tension CCh CCL Amplitude ** D~TA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EBb** TYPE R~PR CODE VALUE 1 66 2 66 0 3 73 268 4 66 5 66 7 65 8 68 0,5 9 65 FT l! 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 ** SET TYPE - CHAM ** NA~E SERV U~!T SERVICE API API API AP1 FIhE NUMB NUMB SIZE REPR PROCESS ID ORDEP ~ LOG TYPE CLASS MOD NUMB SAMP EbE~ CODE (HEX) DEPT FT SIG~ P$~ CU STDT TPMI PS! PU ISHU P$~ V SMFD PS1 CU SFND PSI CU SBWF PSi CU S~H~ PSi CU 391432 00 000 00 0 I ! 1 4 68 0000000000 3914~2 51 400 01 0 ! 1 ! 4 68 0000000000 ~91432 51 390 00 0 1 I ! 4 68 0000000000 391432 51 890 O1 0 1 I 1 4 68 0000000000 ]91432 51 000 00 0 ~ ~ ! 4 68 0000000000 391432 51 400 02 0 ! t I 4 68 0000000000 391432 51 400 02 0 I ! I 4 68 0000000000 391432 51 400 01 0 1 1 ~ 4 68 0000000000 391432 51 400 0! 0 I ! 1 4 68 0000000000 51 000 00 0 1 I 1 4 68 0000000000 51 000 00 0 I ! 1 4 68 0000000000 51 391 00 0 i i 1 4 68 0000000000 FTDT PS1 CPS 391432 NTDT PSl CPS ~91432 AFFD PS! CPS 391432 $~lumberge:r . ,.as .a ~ompu~inb Center NAME SERV UNIT SERVICE AP1 AP1 API AP1 FI!j~ NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ABFD PS1 CPS 39!4~2 51 AFND PSI CPS 391432 51 ABND PS1 CPS 39J43~ 5! SIGC PS1 CU 39143~ 5I SIEM PS1 CU 391432 51 ~OF P$1 391432 51 T~AT PS1 39143~ 51 SDSI PSi C!! ]9~432 5{ BAC~ PSi CPS 391432 5~ FBAC PS1 CPS 3~!432 5! TCAN PSI 39143~ 51 TCAF PS1 39143~ 51 TCND P$1 CPS ]9~432 51 TCFD PS! CPS 3914~2 51 TSCN PS1 CPS 39~43~ 5~ TSCF PSi CPS ~9t43~ 51 INND PSI CPS 39!43~ 51 !NFO PSi CPS ]9143~ 51 RNI PS! CPS 391432 51 RN2 PS1 CPS ~9~432 5~ RN3 PS! CPS 391432 5~ RN4 PS! CPS 39143~ 51 RN5 PS! CPS ]91432 51 ~u6 PS{ CPS ]91432 RN7 PS! CPS 39~432 51 RN8 PS1 CPS 391432 51 RN9 PSi CPS 39~432 5! RNI0 PSI CPS 391432 51 ~NIi PSI CPS 391432 RNi~ PSi CPS 391432 5~ RN'13 PSl CPS 391432 51 RN!4 PSl CPS ~9~432 5! RNI5 PS! CPS 39~43~ RN!6 PS{, CPS 39~43~ 51 RFi PS1 CPS 391432 51 ~F2 PSI CPS 39~432 5~ RF3 PS! CPS 39143~ 51 ~F4 PS1 CPS 391432 51 ~F5 PSI CPS 391432 5t RF6 PS~, CPS 391432 5! RF7 PS1 CPS ~9~43~ 51 RF8 PS1 CPS 391432 51 RF9 PS1 CPS 39~43~ RFIO PS! CPS ]91432 5~ ~F!1 PS! CPS 39!~3~ 5{ ~FI~ PSi CPS 3914~2 51 RF!3 PS~ CPS 39143~ 51. RF14 PS1 C~S 39143~ 51 RF15 PS1 CPS 391432 51 ~F!6 PS1 CPS 3914]~ 51 AvE0 PS1 391432 51 391 O0 0 i i 1 4 68 0000000000 390 O0 0 i I I 4 68 0000000000 390 O0 0 I ~ 1 4 68 0000000000 400 O1 0 ! I I 4 68 0000000000 400 01 0 i 1 1 4 68 0000000000 000 O0 0 I 1 ! 4 68 0000000000 000 O0 0 I I 1 4 68 0000000000 000 O0 0 i 1 1 4 68 0000000000 390 17 0 I 1 ! 4 68 0000000000 391 17 0 t t 1 4 68 0000000000 000 O0 0 i I 1 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 i I 1 4 68 0000000000 000 O0 0 ~. ! I 4 68 0000000000 000 O0 0 ! I I 4 68 0000000000 000 O0 0 1 1 I 4 68 0000000000 000 O0 0 I 1 I 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 390 O1 0 1 1 1 4 68 0000000000 390 02 0 ! 1 1 4 68 0000000000 390 03 0 I 1 1 4 68 0000000000 390 04 0 1 1 1 4 68 0000000000 390 05 0 1 I I 4 68 0000000000 390 06 0 I I 1 4 68 0000000000 390 07 0 ! 1 ! 4 68 0000000000 390 08 0 1 1 1 4 68 0000000000 390 09 0 I I 1 4 68 0000000000 390 I0 0 I 1 1 4 68 0000000000 390 1! 0 1 1 i 4 68 0000000000 390 12 0 I 1 1 4 68 0000000000 390 13 0 i I I 4 68 0000000000 ~90 14 0 I I 1 4 68 0000000000 390 15 0 ! 1 1 4 68 0000000000 390 16 0 1 1 1 4 68 0000000000 ~91 Ol 0 i ! 1 4 68 0000000000 39t 02 0 I I 1 4 68 0000000000 391 03 0 1 ! i 4 68 0000000000 391 04 0 i ! i 4 68 0000000000 ~91 oS 0 1 1 1 4 68 0000000000 391 06 0 1 I 1 4 68 0000000000 391 07 0 ! ! 1 4 68 0000000000 301 08 0 i I t 4 68 0000000000 391 09 0 I 1 I 4 68 0000000000 391 !0 0 I 1 1 4 68 0000000000 39I I1 0 l 1 1 4 68 0000000000 391 1~ 0 i 1 1 4 68 0000000000 391 13 0 i '1 I 4 68 0000000000 391 14 0 I ! 1 4 6~ 0000000000 391 t5 0 i 1 ! 4 68 0000000000 ]91 16 0 1 1 I 4 68 0000000000 000 O0 0 1 1 I 4 68 0000000000 Schl r~.er Alas Corn u .ng C nter NAME SERV [)~ T SER. !CE'" AP1- AP:.I A I FILE ...... NUMB NUMB !ZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SA~P ELEa CODE (HEX) AYE! PS! 39143~ 5! 000 O0 0 i t I 4 68 0000000000 GR PSI GAPI 39i43~ 51 3!0 Ot 0 I I 1 4 68 0000000000 TEN~ Pal LB 39143~ 51 635 21 0 1 ! 1 4 6B 0000000000 COb PS1 V 391432 51 150 O1 0 i 1 i 4 68 0000000000 DEDT ISHU PSi SBHN PS 1 AEFD PS ! SlBH PSI BACK , PS 1 TCfJD. PS! IN~:D.PS 1 ~7,PS1 ~NI 5.' PSI ~F3*PSi ~FT,PS! "aR,psi I')KPT, ABFD.PSl SIBN,PS1 B~C~'PS1 TC~D~Ps! ~N3,PS! RNll PSI ~15 PS1 RF3 PS1 ~F7,PS! RF!5 PSl DEPT. ISHU,P$1 SB~5~,PS1 ABFD,PSI SIB~.P$1 BACK,PS~ 96~6,0.00 2,969 1~4,915 79,141 !32.484 !39 759 -!600 063 -4 751 961 174 1250 000 29~7 1903409 492,424 !041.667 i008.523 564.000 9600.000 37 719 51 O52 116 945 51 356 58 16930 594 2109 205 991 667 691,667 ~160,4!7 310,750 279,167 214583 722:9~7 03,333 45,031 9500,000 34,719 42,630 114,222 8'550 128,764 $IGM.PS! SFFD,PS1 FTDT,PSI FND.PS1EOF,Psi FBAC.P$! TCFD,p$! INFO.PS! RN4.PS! RNS,PSI RNI2,PSI RN16 PSI RF4iPS! RF8,PS1 RF12,PSl RFI6.PS1 TENS.PSi $IGM,PS1 SFFD.PS! FTDT.PSi AFND*PS~ BAC.PS1 CFD'ps1 INFO,PSI RN4,PS! RN8 PSI RN12:PS1 RM16,PS1 RF4.PSI RF8 PSI RF16.PSI TENS.PSi SIG~.PS! SFFD,PSI FTDT;PS! AFND,PS1 MMOF,PS1 FaAC,PS! 2 725 0:000 . 8 -1 16 90 56 890 ~3251 478 ]~l !107 954 672 348 1110 000 35.583 36,~13 42~ '002 ,334 1,2!7 14 745 4963,526 362,636 1350,000 887,500 i93g~583 204,167 391';667 297 9!7 621500 554 !67 14i5 000 15 50O 401422 562 !.217 164'770 STDT,PSI SFND.PSl NTDT,P$1 ABND PSI TRAT:P$1 TCAN,P$! T$CN,PS! RNI,PSI RN5.PSI RN9.PSI RN!3,PS1 RFI,PS1 RF5.PSI RFO,PS1 RF13,PS1 AVE0,PS1 CCL.PS! STDT,P$1 SFND,PSI NTDT.,PS1 ABND,PS! TRAT,PS1 TCA. N,PS1 TSCN,PS1 RN1,PSI RNL,PSl RNO,PSI RMI~ PSi PS RF5,PS1 RFO.PSI RF~],PS1 AVEO,PS1 CCh'PSI STDT,PS! SFND,PSI NTDT.PS! AB.ND,PSi TRAT,PSI TCAN,PS1 66.000 22.725 0.000 2~i"26000 0000 0,000 875 947 1519:886 265 151 454 545 66 591 122~ 879 0 000 0 000 66.000 38'541 18,863 582 40047'734 2224.:375 787'500 1385"417 1735~ 17 1470'~33 256,250 429,167 572.917 441.667 0o000 0.000 66,000 19.~10 30. 37 420755 2i373 683975O0 TPHI,P$1 SBHF,PSI AFFD,P$1 $IGC P$1 SDSI:PS! TCAF,PS1 TSCF,PS! RN2*PS1 R~6,PS1 RNIO,P$1 RN14,P~I RFR.PS1 RF6,P$1 RFIO,PSI RF14,PS iVEl,PS1 TPHI.P$1 SBHF,PS1 AFFD,P$1 SIGC,PS1 SDSI,PSl TCAF.PS1 TSCF.PS1 RN2.PS1 RN6,PSI RN ,PS1 RF2.PSl RF6.PS1 RF!O.PS1 R~14.PS1 AVE!.PS1 TPHI.PSl SBHF,PS1 AFFD,PS SIGC,PSI SDSI,PS1 TCAF,PS1 0 000 0 O0 o 0 00~ 0 000 ,½ t ,20 545 21 134 .60 634 748 106 1188 447 0 000 44 4~7 44 19 103 ~22 I 705 0 85t 12770 176 741042 2 O83 0 000 25 496 3642 o 28819 238 TCND.PS! 25075,078 TCFD I~ND,'' PS1 21t6,t57 INFD,PSi'' N3, PS1 94!,667 RN4,PSl N7~PSI 1133,333 RNS,PSl RNll'PSI 2770,833 RN12.PS1 R~'PS1 !602,0~3 RN16.PS! ~,p~l 304.167 RF4,P$1 RF7,PS1 485.417 RF8,PS1 15,PS! !029'167 G~,PS1 872.000 TENS.PSl DEPT 9400,000 $IGE PS1 ISHU:PS! ' 45.125 SFFD:PS1 S_~N,PS1 46.0!5 WTD~.PS1 ABFD,PSI 149,7!7 AFND.PS1 S!BH.P$1 43,925 M~OF.PS! BACK PS1 97,967 FBAC'PS! TCND:PS~ 2667~,676 TCFD,PS1 IN~PS1 2288.29~ iNFD.PS~ RN P$~ 1119,792 RN8.PS1 RNI~,P$~ 2838,542 RN12.P$! RN15.PS~ i348,157 RN16.P$1 RF~,PS1 366 667 RF4.PSI RF7,PS1 383:333 RF8.P$1 RFll,PS! ~037.500 RF12.P$1 ~F35,P$t 727'083 RF16.PS1 ~,P$i ~6,344 TEN&.PS! DEPT g]o0,000 SIGN.PS1 ,PS! 40,313 SFFD.PSi SB~N PS! 46,4~5 FTDT.PSI ~D:PS! 129.459 AFND.PS1 STBM,P$1 44'357 ~MoF,PsI B~C~,PS} 109,294 FBAC.PS1 TeRn.psi ~2276 445 TCFD,PSl i~i~'P$1 2143:~44 iNFD'PS! RN],PS1 99~.667 RN4,PS! RN7,P$! !058.333 RN8,PS1 R~II,PS1 2747 917 RN12.PS! RN~S.PS! 1250:00(3 R~16'P$1 PSI 295,833 RF4,P$1 RFi~..PS1 941 667 RF!2,PS1 RF15.PS~ 495~833 RF16.PSI G~,PSI 30,250 T~N$,PSi D~PT, 9200,000 $iGM.PS1 ISHU,PSi 39,469 SFFD,PS1 ~HN PS1 47.923 ~TDT.PS1 FD:PSi 104'098 .AFND.pSl SIBN,PSI 46.349 M~OF.P$1 BACK.PS1 119.742 TCND.PS1 15694']14 TCFD,PSI 8402 904 388 ~7~ i329 167 883 333 3041 667 789 583 4!2 500 318 750 I095 833 754 167 1405 000 I 77 484 128 1 51 18 960 961 43~ 020 i486 378 907 452 2956 730 693 109 452 083 352 083 i143 750 306 250 i430 000 17,375 22.497 9 977 404 669 1 81 7282 815 372 529 1339 583 877 083 2877 0~3 610 41~ 402 08~ 306 250 987.500 193.750 1390,000 37,~91 38. ~5 5 364 406:946 a '~98 TSCN,PS1 RNI-,PS1 RN5,PSI RN9.PS1 RNI3.PS1 RFI,P$1 RF5.PSI RFg,PS! RF13,PS! AVE0,PSI CCD.PS1 STDT PS1 SFND:PSt NTDT'PSI ABNO,P$I TRAT,PSi TCAN'PS~ TSCN.PSI RN1,PS1 RN5PS1 RN9:PS1 RN13,PS! RFI,PSI RFD,PSi RF9,PS1 RF13,P$1 AVEO*PS1 CCD,PSI STDT,P~I SFND.P$I NTDT.PSt ABND.P$1 TRAT,PS1 TCAN,PS1 TSCN,PS1 RNI,PS1 'RN5.P$1 RN9.PS1 RNI3,PS1 RFI,PS1 ~F5,PS! RFg.PS1 RF13,P$! AVE0,PS1 CCh,PSi STDT,PS1 SFND,P$1 NTDT,PSI ABND,P$1 TRAT PS1 TCAM:P$1 TSCN,P$1 7029 145 791:667 1414 583 3039,~83 270' 33 483.333 681.250 1254.167 0'o00 0,600 66,000 18,548 29.979 466.230 -2't56 70979'609 7346-208 831'330 1576'522 1973,157 2934,695 291"667 485 417 737i500 1195 833 000 §:ooo 66,000 25.6 5 419i 7 2 459 48~84 750 4~55 1387 500 1872!917 2693 750 277.083 464.583 683.333 977083 0!000 0 000 66 000 39 928 748 3 181 37977 438 20!2 129 TSCF,P$1 RN2.P$1 RN6.P$1 RNI0,PSX RNI4,P$1 RF2,P$1 RF6.P$1 RF10,PS1 RF14 AVEJ:P$1 TPHI.PS1 SBHF'P$i AFFD,P$i $IGC,P$1 SD$I,PSl TCAF,PSl TSCF,P$1 RN2.P$1 RN6.P$! RNIO.P$1 RNI4,P$1 RF2,P$1 RF6,P$1 RF{O.P$1 RF14 PSI AVEI~P$1 TPHI PS AFFD,P$1 SXGC,PSX SDSI,'PS1 TCAF.,PS1 TSCF,P$1 RN2,P$! RN6 PSi RNIO!PSX RN14 RF2.PS1 RF6 PS1 RFIO:P$1 RF14.P$1 AVE1,P$! TPHI PS1 SBHF.:P$1 AFFD PS s c:Psl SDSI PS1 TCAF:PS! T$CF,P$1 2961725 96 750 247 917 13~ 109 616 667 664 5~ 112847 2 866 0,303 32917 328 3406 9 696 715 005 208 552 083 752 083 246 105 4 2 98 6{9 40 552 19597 184 870' 487,$00 616,667 000 .0 8 ,543 chlugggrger Alaska ComDutino Ce.to.r PS ~ ~927,2B3 INFO,PSI R~N7 ,- . . . 1.1,PS1 2i14.583 RN12.PSi R~15,PS1 483,333 RN16'PSl RF3.PSI 258,333 RF4:Pgl gF7.PS~ ~29.167 RES.PS1 RE1 PSi ~4~,667 RF~6,P$~ GP'PSi 1~8.375 TENS.PS! DEPT. 9i95.000 SIGM.PS! ISH!.!.PSI 42,094 SFFD,PS1 SBHN.PSI 49.4!1 FTDT.PS! BAC~,PSi 115.376 FBAC.PS TCND.PS~ 16695'887 TCFD.PSi NND,PS! ~855'~48 INFD PSi IpN3.PsI '885.41.7 RN4:PS! ~N7'P$~ 7~0,417 RNS.PS1 Rbll..PS1 20~2'500 RN12.P$1 RN15,PS1 477'083 RN16,P8~ RFB,PS1 252*404 RF4.PS RET,PSi 228,365 RES,PS! RFI~,PS1 689'103 RF12.PS! RFIL,PS~ 162.260 ~F16,PS1 GP.PS! 110,250 .EMS.PSI ** END OF DATA **** FILE TRAIBEP **** FILE NA~E I EDIT ,001 SERVICE ~ Fl, lC VERSION : O01A04 DATE : 90/08/24 MAX REC SIZE : 1096 FILE TYPE : bO bAST FILE **** FILE HEADER **** FILE NAME : EDIT .O02 SERVICE ~ FLIC VERSION : O01A04 DAT~i ~ 90/08/~4 MAX REC SIZE ~ 1096 FIL~ TYPE ~ LO LAST FILE : 345 979 1.243 750 4~5 356 250 304.~67 554,167 ~6,667 1405.000 33 403 33:608 6 208 367~385 ~,173 31 143 4838 225 350 687 1220 833 827 083 1845.833 466, 7 282.452 616'987 110,176 1395,000 RM!,PSI RNL,PS1 RN9,PSi RN13.PSI RF1,PS! RF5,PS1 RFg.PSI RF~3,PS1 AVEO.PS1 CCh. PSi STDT,PS1 SFND.PSI NTDT'PSI ABND,P$! TRAT,PS~. TCAN,PS1 TSCN~PS1 RNI,PS! RN5,PS1 RN9.PS1 RN~3,PS! RFI,PS! RF5,PS! RF9 RF13.~PS! ~VEO,P$I CCL.PS1 777,083 1316,667 .083 5:000 504 !67 454:167 0.000 0.000 66 000 33 403 19263 373 717 3 122 25732 262 2621.020 779 ~67 1264583 1650 000 3 .580 530849 4741760 0 000 0 O00 RN2 PS1 RN6:PSI RNIO,PS1 RN14,P$1 RF2,PSI RF6,P$1 RFIO,PSX RF14,PS1 AVEI,PSI TPHI.PSX SBHF,P$1 AFFD,P$1 SIGC,PSI SDSI.P$1 TCAF PS! TSCF:P$1 RN2 PSi RN6:P$1 PSI RN1 RF2,PS! RF6,PS! RFtO,PSI RFi4,PS! AVEI,PSI 112,783 1266,667 i643,750 797 917 30 960 391 667 525 000 0 0 48 456 43253 96,810 0 000 1 456 IIi 23 127 008 802 ~ 3 3 36~ 586 52 843 29~ 465 0 000 Alaska ~o~ n. center FILE - EDIT,O0~ ARCO ALASKA INC. PRUDHOE BAY D.~. 4-1 50 029-20078-00 PASS TWO - FROM FIELD FILE 12 DATA SAMPLED E¥.sRY 5000 FEET TOOL EXTEMSIOM TYPE USED TDT-P , .PS2 T 0 0 L THER~AL DECA~ TOOL ****************************************************************************** TABLE TYPE ~ CONS TUNI VALU DEFI CM ARCO ALASKA INC, Company Name FN PRUDHOE BAY Field Name ADIN 5v~29.20078.00 APl Serial Number FI., 1327' S & 295' W ME CPM Field Location SECT 34 Section TOWN llN Township ~ANC 15E Range COUN NORTH SLOPE County STAT ALASKA State or Province NAT7 USA Nation !.~ATI Latitude LONG 5ongltude WIT~ WHIDDON /REINTS Witness' Name $0~ 391432 Service Order Number PDAT MSL Permanent datum EPD FT 0, L~M RKB Log MeasUred From APt) FT 64, ~DF FT ' 9,25 E~L FT 25 8TF~ DEGF 0 $chlUmberqer Alaska Com.uting Center TABLE TYPE : CURV S!G~ STDT TPHI ISM!! SFFD FTDT MTDT ABFD AFND ABND STSC TRAT SDS! BAC~ FBAC TCA~ TCAF TCND TCFD TSCM TSCF INMD IMFD ~2 ~6 RM9 RMiO RNII R~12 RN14 RNa5 Depth Channel Name Sigma (Neutron Capture Cross section) Status o~ TnT TnT Porosity TnT Shunt Current St~ma formation - far detector (TPTP) Sigma ~ormatlon m near detector (TDTP) Sidma borehole - far detector (TDTP) St~ma Dorehole - near detector (TDTP) Far TDTN Count Rate Near TDTM Count Rate Amplitude formation [- far detector (TOTP) Amplitude bore~ole - Mar detector (TDTP) Amplitude for~ation - near detector (TDT~) AmDlitUde Borehole -- near detector (TDTP) SIGN Correct,on Boreno!e siqma (corrected) -- TDTP ~initron mode monitor ratio (TDTP) TDT Ratio Standard deviation o~ sia~a-for~atlon (TDTP) Backaround, Near Gates Far Back,round Total co~lnts analyzed - near detector (TDTP) Total counts analyzed m far detector (TDTP) Total counts - ~ear detector (TDTP) Total counts - iar detector (TDTP) Selected ~ates count rate - near detector (TDTP) Selected Qates count rate - far detector (TDTP) Inelastic countin~ rate - near detector (TDTP) Inelastic countln6 rate - far detector (TDTP) Raw Near ~$t Gate Raw Near ~nd Gate Raw Meat ]rd Gate Raw Near 4th Gate Raw Near 5th Gate Raw Near 6t~ Gate Raw Near 7tm Gate Raw Near 8th Gate Raw Near 9th Gate Raw Hear 10th Gate Raw Meat 1lth Gate Raw ~ear 12th Gate Raw Meat !3th Gate Raw Near 14th Gate Raw Meat 15tb Gate Raw Near ~6tn Gate Raw Far Ist Gate Raw Far 2nd Gate cb. lumberoer asKa Comp, ino Center DEFI RF~ Raw Far 3rd Gate RF4 Raw Far 4tt~ Gate RF5 Raw Far 5th Gate RF6 Raw Far 6th Gate RF7 Raw Far 7th ~ate RF~ Raw Far 8th Gate RF9 Raw Far 9th Gate RFIO Raw Far 1Otb Gate RFI1 Raw Far 11tn Gate ~Fi2 Raw ~ar l~th Gate RF13 Raw Far 13th Gate RF14 Raw war 14th Gate RF15 Raw Far 15th Gate PW~6 Raw Far 16t~ Gate AVEO Averaoe Output 0 AVE~ Average OutPut 1 GR ~amma Ray T~NS Tension ~ CCL CCL AmDl~tude ** DATA FORMAT SPECIFICATION PECORD ** ** SET TYPE - 64EB ** TYP~ REPR CODE VALUE ~ 66 0 2 66 0 3 73 268 4 66 ! 5 66 6 73 7 65 8 68 0,5 9 65 {{ 66 4 12 68 13 66 0 1~ 65 FT ~5 66 68 16 66 0 66 Schlum.,eroer . as~a Co~uutin~ Center ** SET TYPE - CHAM ** NA~E SER¥ {3~{IT SERVICE AP1 APl AP1 aPI FILE NUmB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NU~ SAMP ELE~ CODE (HEX) DEPT ET 391432 O0 000 00 0 2 1 1 4 68 0000000000 ISHU PS2 V SFFD PS~ CU SFHD PS2 CU SBHF PS2 CU SBH~ PS2 CU 391432 5! 391432 391432 391432 5!, 39~432 51 39143~ 391432 51 391432 51 FTDT PS2 CPS 3¢1432 5I NTDT P$2 CPS 391432 51 AFFD P$2 CPS 39~432 51 ABFD PS2 CPS 391432 51 AFND PS~ CPS 391432 5~. ABND PS~ CPS 391432 51 SIGC PS~ CU 391432 5~ ST}~H PS2 C{! 391432 51 TRaT PS2 391432 5! SDSI PS2 CU 391432 51 B~CK PS2 CPS 391432 5! FBAC PS2 CPS 391.432 51 TCAN PS2 3914~2 51 TCAF PS2 391432 51 TCHD PS2 CPS 39~432 51 TCFD PS2 CPS 391432 51 TSCF PS2 CPS 391432 51 INND PS~ CPS 391432 51 iMFD PS2 CPS 391432 51 R~I P$2 CPS 3914~2 51 ~2 PS~ CPS 391432 51 RN4 PS2 CPS 391432 51 RN5 PS2 CPS 391432 51 RN6 PS2 CPS 391432 51 ~7 PS2 CPS 39~432 5! RN8 PS2 CPS 391432 51. R~0 P$2 CPS 391432 51 R~IO PS2 CPS 391432 a~ll PS2 CPS 391432 51 ~12 PS~ CPS 391432 51 ~13 PS2 CPS 3914~ 51. R~14 PS2 CPS 391432 51 ~Ni5 PS2 CPS 391432 51 RN!6 PS2 CPS 391432 51 ~FI PS2 CPS 391432 51 RF2 PS2 CPS 391432 51 RF3 PS2 CPS 391432 51 R~4 PS2 CPS 391432 51 400 O1 0 2 ! 1 4 68 0000000000 390 O0 0 2 I I 4 68 0000000000 890 O! 0 2 ~ I 4 68 0000000000 000 O0 0 2 I I 4 68 0000000000 400 02 0 2 1 ! 4 68 0000000000 400 O~ 0 2 1 1 4 68 0000000000 400 O1 0 2 1 1 4 68 0000000000 400 Ol 0 2 1 1 4 68 0000000000 000 O0 0 ~ 1 1 4 68 0000000000 000 O0 0 2 1 I 4 68 0000000000 391 O0 0 2 1 I 4 6~ 0000000000 391 O0 0 2 1 1 4 68 0000000000 390 O0 0 2 ! I 4 68 0000000000 390 O0 0 2 1 1 4 68 0000000000 400 OI 0 2 1 1 4 68 0000000000 400 Ol 0 2 1 1 4 68 0000000000 000 O0 0 2 I i 4 68 0000000000 000 O0 0 2 I 1 4 68 0000000000 000 O0 0 2 1 1 4 68 0000000000 390 !7 0 2 1 t 4 68 0000000000 391 17 0 2 ! 1 4 68 0000000000 000 O0 0 2 1 1 4 68 000000000 0 000 O0 0 2 I ! 4 68 0000000000 000 O0 0 2 1 I 4 68 0000000000 000 O0 0 2 1 1 4 68 0000000000 000 O0 0 2 1 ! 4 68 0000000000 000 O0 0 2 1 1 4 68 000000 000 O0 0 2 t 1 4 68 O00000u 000 O0 0 2 I 1 4 68 0000000000 390 O1 0 2 I 1 4 68 0000000000 390 02 0 2 1 ! 4 68 0000000000 390 03 0 2 I 1 4 68 0000000000 390 04 0 2 I i 4 68 0000000000 390 05 0 2 1 1 4 68 0000000000 390 06 0 2 i 1 4 68 0000000000 390 07 0 2 1 I 4 68 0000000000 390 O~ 0 2 I I 4 68 0000000000 390 09 0 2 1 ! 4 68 0000000000 390 !0 0 2 1 ! 4 68 0000000000 300 1i 0 2 I I 4 68 0000000000 390 1~ 0 2 I I 4 68 0000000000 390 13 0 2 I 1 4 68 0000000000 390 !4 0 2 I I 4 68 0000000000 390 15 0 2 I I 4 68 0000000000 390 16 0 2 1 ! 4 68 0000000000 391 O1 0 2 i i 4 68 0000000000 39! 02 0 2 I 1 4 68 0000000000 391 03 0 2 1 1 4 68 0000000000 391 04 0 2 1 1 4 68 0000000000 ~lumber,;jer Alaska Computing Center NAME SERV UNIT SERVICE API API API API FIbE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPR CLASS MOD NUMB SAMP EbEM CODE (HEX} RF5 PS2 CPS 391432 5i 391 05 0 2 I I 4 68 0000000000 Rw6 PS2 CPS 391432 51 391 06 0 2 1 1 4 68 0000000000 RF7 PS2 CPS 391432 51 39! 07 0 2 1 ! 4 68 0000000000 RrB PS2 CPS 391432 51 391 05 0 2 I 1 4 68 0000000000 RF9 PS2 CPS 391432 51 391 09 0 2 I I 4 68 0000000000 RF10 PS2 CPS 301432 51 ]91 10 0 2 I 1 4 68 0000000000 RF1! P$2 CPS 391432 5! 391 11 0 2 I I 4 68 0000000000 RF!P PS2 CPS 391432 51 391 12 0 2 1 I 4 68 0000000000 Rrl.~ PS2 CPS 391432 51 391 13 0 2 1 I 4 68 0000000000 RF14 PS2 CPS 391432 51 391 14 0 2 1 1 4 68 0000000000 RF15 PS2 CPS 391432 51 391 15 0 2 I I 4 6B 0000000000 Rw16 PS2 CPS 391432 51 391 16 0 12 1 i.. 4 68 0000000000 AVEO PS~ 391432 51 000 O0 0 2 1 1 4 68 0000000000 AVE! PS2 391432 51 000 O0 0 2 I 1 4 68 0000000000 ¢.. PS2 GAPI 3 1432 51 310 01 0 2 1 I 4 68 0000000000 TENS PS2 LB 391432 51 6]5 21 0 2 I ! 4 68 0000000000 CCL PS2 V 391432 51 150 01 0 2 1 1 4 68 0000000000 DATA DEPT 9684 500 SIGM,PS2 !SH!):P$2 Sl~i88 SFFD,PS2 SBHM PS2 47'491 FTDT.DS2 ABFD'PS2. 1{0.760 AFNO,PS2 $IBH PS2 45 658 MMOF.PS2 8~CK:~S2 1!2:069 · CND,PS2 i5682,664 TCF PS2 !MMV.PS2 2t13,703 INFO,PS2 RN].PS2 946,970 RN4,PS2 PMT,PS~ !~74,242 RMB.DS2 RMll PS2 2765,151 RM]2.PS2 RN!5:PS2 ~083,333 RN~6,PS2 PF3,PS2 269,~86 RF4 PS2 R~'?,PS2 501'894 RFS:PS2 R~!i.PS2 1008,52~ RF12,PS2 RFI5.PS2 i022,727 RFt6.PS2 GR.PS2 342,750 TENS'PS2 39 087 40:724 5 ~27 3 2o74 29 734 4~49 91 340 ~54 1259 469 819 129 3096 591 i084 280 416 1093,750 809;65 ~o9o'oo~ STDT.PS2 66.000 SFND,PS2 39,087 NTDT.PS2 17,02~ ABND,PS2 383,61 TRAT,PS2 ]'460 TCAN.PS2 37030'813 TSCN,PS2 1979.515 RNI.PS2 785.985 RM5,PS2 1429'924 RNg,PS2 1818,182 RN13 PS2 3191,288 Rtl:PS2 30~,030 RF5,PS2 45~:545 RF9.PS2 63 470 RFI3'PS2 1202 651 AVEO.P$2 OiO00 CCL,PS2 0 O00 ?PH! PS2 SBHF PS2 AFFDPSps) TCAF PS2 PS TSCF R.2 RN6 P$2 RN10 RNI~,PS~ RF ,P$2 RF6,PS2 RF10,P$2 RF14,P$2 AVE1,PS2 DE'PT, 9600,000 SIGM,PS2 I~HI.!.P$2 43,813 SFFO,PS2 SBH~.D$2 52,448 FTDTiPS2 ABFD.PS2 113,267 AFND.P~2 SIBH.PS2 53.589 ~MOF.PS2 BACK,PS2 111.237 FBAC.PS2 TCND PS~ !6697.703 TCFD.PS2 I~ND.iP$2 2053.374 iMFD'PS2 RN] PS2 957,532 RN4,PS2 RH7.PS2 743,{g9 RNB.PS2 R~!I,PS2 2239,583 RN12,P82 38 706 38:727 5 877 4~5:340 2~ 237 4834 398 372 187 !324'1~8 863 31 STDT,PS2 SFND*PS2 NTDT,PS2 ABND.PS2 TCAN'P , TSC~ PS2 RNI:PS2 RN5,PS2 RNg,P$2 RN13,PS2 38 06 19 149 393 562 3 260 42950 383 ,272 I336,138 1738.782 1472.356 TPHI,PS2 SBHF,PS2 AFFD,PS2 SIGC,P$2 SDSI,PS~ TCAF.PS T$CF.PS2 RN2,PS2 RN6,PS2 RN1 PS2 10A 474 ooo 58 '°I°t o 1647 727 1789 772 64 1183 712 0 000 54 756 46 022 109 966 0 000 689 72 97,30] I 84 054 857,372 "~3.,PS2 300,926 RF4,P'S2 RFT'PS2 221,836 RFS,PS2 RW'ii'Ps2 696,373 RFI2.P$2 RF~5,PS2 1!.9.599 RF16.PS2 GR.PS2 61.156 TENS,PS2 DEPT. ISH!J,PS2 SBHN,DS~ ABFD PS2 B~C~.PS2 TCND,PS2 N"'D PS2 ~N~PS2 ~N7,PS2 RN~.~$2 RN!5.PS2 RF3.~2 RF~5,PS~ GR.PS DEpT. ISH~? ...... ,PS2 SBbN,P52 ASFD,PS~ SIB~.PS~ B~CK TCND PS2 INND PS~ RN3 PS~ R~? PS2 RN!~.PS2 RN!5.P$2 RF3 PS2 ~F7 PS2 ~F!~ PS2 RF~5 PS2 G~ PS2 DEPT "~'Ps2 ISHL.. SBHN PS2 ~BFD:PS2 S!BH,PS2 BACK,PS2 TCND'pS~ ~ND'PS !R~3.pS2 R~7,P$2 RN15,P$2 9500,000 4~.969 40 481 118 925 35 410 166 932 24685 2057 087 943 510 ~183 ~94 2758 413 1688 702 2~3 333 479 !67 1o12:5oo 1075'000 808,000 9400,000 44,25o 46,578 135,19~ 44.693 139'542 25477.559 2179'7~7 993~590 I137,820 2806,490 1548.478 312.500 389.5.~3 ~.041.667 770 83;3 9300,000 44 45 755 122 055 43 250 146 564 22268 242 2020.631 951.5~2 !1~1.779 2740.384 1350,160 SIG~.P$2 SFFD.PS2 FTDT.P$2 AFND,PS2 i~OF,PS2 FBAC TCFO:PS2 INFD"PS2 RN4,PS2 RN8,P$2 12.PS2 RN16 PS2 RF4:PS2 RF8 PS2 RF!2:PS2 RF! PS2 SIGM.P$2 SFFD,P$2 FTDT,PS2 AFND,PS2 FBAC.PS2 TCFD'PS2 INFD,P$2 RN4iPS2 RNI2:P$2 Rgb6 PS2 RF4~Ps2 RF8-PS2 ~F!2.P$2 RF!6.PS2 TENS,PS2 SIGM.PS2 SFFD,P$2 FTDT,P$2 AF~]D P$2 ~MOF:PS2 FBAC.PS2 TCFD.PS2 INFD'PS2 RN4.PS2 RNS.PS2 R~12.Ps2 RNI6,PS2 432 692 RF1,PS2 3761157 RF5'PS2 30~ 784 RFg.PS2 57.. 846 RF13,P$2 96 45~ AYEO,PS2 !420:000 CCh. PS2 5i141 7 581. il !46 400,265 I 209 816~ 711 308 · 3 94 979 567 27 ~33 $3 i~29,i67 793.750 1460.000 12 99 i1'4 8 466 254 2~ 240 476 91.08 650 407 708 1380 208 873 397 288 2 435 4t7 337.500 I106.~50 352 083 I465:000 18,480 22.696 9 968 402:634 1,2i9 380 436 1384 215 881 410 2806 490 71! 138 STDT,PS2 SFND,'PS2 ~TDT.PS2 ABND,PS2 TRAT,P$2 TCAN PS2 TSCN:PS2 RNI P82 RN5~PS2 RNg,Ps2 RNI. 3.P$2 RFI'PS2 RFS'P$2 RF9,PS2 RF13'PS2 AVE0,PS2 CCS~PS2 STDT,PS2 SFND'PS2 MTDT,PS2 ABND,PS2 TRAT'PS2 TCAM,PS2 T$C~,P$2 RNI,PS2 RN5,PS2 RNg,PS2 RN13.PS2 RFI"P$2 RF5,PS2 RFg,P$2 RF13.P$2 AVE0,P$2 CCL.P$2 STDT,PS2 SFND.PS2 MTDT,PS2 ABND,PS2 TRAT.PG2 TCAN,PS2 TSCN.PS2 RNI.P$2 RN5.P$2 RN9,P$2 RNI3,PS2 RF1.PS2 60.417 RF2.PS2 93.518 RF6.PS2 555.556 RFI0.PS2 443.673 RF14.P$2 0..000 AVEI.P$2 0..000 415 2 68703 6998 791 1412 66 .O00 TPHI.PS2 757 $BHF,P$2 420 AFFD,P$2 425 SIGC.PS2 429 938 TCAF,P$2 074 TSCF.P$2 266 RN2 P$2 260 RN6~PS2 1806 891 RN10,P$2 2992 788 RN14,PS2 264 583 RF2'P$2 441 667 RF6,PS2 643 750 RF10.PS2 1247 917 RF14.PS2 . 000 AVEI,P$2 :000 66'000 TPHI,PS2 18.579 SBHF,PS~ 429.171 AFFD,P$ 175 SDSI,P$2 70076.~19 TCAF.P$2 68 7135 793 1470 ~897 2876 264 468 TSCF P$2 ]69 R~2iPS2 53 RN6 PS2 035 RNIO 603 RN14:PS2 583 RF2'PS2 750 RF6,P$2 677 083 RF10,PS2 1150 000 RF14'P$2 0,O00 AVE1 ,PS2 0,000 66.000 TPHI.PS2 25.676 SBHF.P$2 28.293 AFFD, PS2 41~.484 $IGC.P$2 .509 49876.195 TCAF PS2 5008'276 T$CF 819' 1 RN2 P$2 1454.1~7 R~6 PS2 1842,948 RNIO P$2 2776.442 RNI4 280.449 RF2,PS2 372' 557,484 000 25 250 35 842 100 015 2 551 0 554 28289 289 288! 502 148 166 1614 583 581 250 i 06, 0 0o000 20,952 ' 45 3 054 0 3862 6 0 16 8 27 500 000 10 667 0,000 27 176 42 460 98 375 4 079 0 568 19877 949 1996 028 2i73 8 21 285 $ChlU~-berqer Alaska Compd InO Center RFT:PS2 350 RFll.PS2 989 RF~.5.PS2 504 G~.PS2 45 DFPT. 9200 IS}iII'Ps2 48 ABFD*PS2 SiBH,PS2 47 BAC~,PS2 CND,PS~ 16024 I~ND,Ps2 2015 ~i3.PS2 94! RN7,PS2 769 RUI~,PS~ 2~55 RN15'.PS2 568 RF3.PS2 248 ~F7.PS2 2!8 RFI~,PS2 637 RFIS..PS2 ~36 iSM!i,PS2 49 ABFD,P$2 ~00 SIBM,PS~ 47 ~C~;~s2 15o TCND;PS2 16024 INND'PS2 2016 ~%~'PS2 941 ~,i7, PS2 769 RN!!.,.P$~ 2155 R~IS.PS~ 568 ~F3,PS2 248 RFT.PS2 218 RFll..PS~ 637 RFI5'PS~ I36 G,.PS2 134 .478 RF4.PS2 .561 RFS,P$2 ,583 RFI2.P$2 .808 RF16.PS2 .875 TENS, PS~ ,000 SIG~,PS2 ,156 SFFD,PS2 · 356 FTDT,PS2 ,564 AFMD,P$2 · 042 ~MOF.PS2 .96~ FBAC.PS~ ,758 TCFU.PS2 ,875 INFD.PS2 ,506 RM4,PS2 .23]. RNS,P$2 · 449 ~N12.P$2 ,910 RN16"P$2 ,397 RF4.PS2 ,349 RFS,PS2 .0lq RFI2-PS2 ,218 RF16'P$2 .250 TENS.PS2 .500 SIG~.PS2 .031 SFFD.PS2 356 FTDT*PS2 :562 AFND, Ps2 ,042 g~OF.P$2 ,96~ FBAC"PS2 ,855 TCFD.P$2 .048 INFD.PS2 506 RN4.PS2 23~ RNS.PS2 449 R~I2.PS2 910 RN16.PS2 397 RF4.PS2 349 RFS.P$2 019 RF~ PS2 215 RFI6.~PS2 125 TENS.PS2 396.635 ~F5 PS2 ~98,478 RFg:PS2 949.5]~9 RF13,PS2 214.343 AVE0.PS2 !435,000 CCS,PS2 37.416 'ST~T,PS2 39,528 SFS~D.PS2 5 340 NTDT.PS2 !,116 TRAT,PS2 37,483 TCAN,PS2 4386.808 T$CN,PS2 360.588 RNI,PS2 1310 ~96 RN5,PS2 865; 85 R~giP$2 i895.032 RN13,P$2 562,~01 RFI,P$2 348. 5~ RF5,PS2 298.47 RF9,PS2 1425,000 CC~.PS2 37 414 39~518 5,340 430,879 ]16 4386'8i4 360,591 !3~0.096 865.3~5 1895 032 562 901 348 558 298 478 570 9i3 122 196 1425 000 STDT.PS2 SFND,P$2 NTDT,P$2 ABND.PS2 TRAT PS2 TCAg:P$2 TSC~'PS2 RN1,PS2 RN5.PS2 RN9,PS~ R~!3,PS2 RFI,PS2 RF5,P$2 RFg. Ps~ RF!3,PS2 AVE0,PS2 CCL.PS2 424, 693' 935, o°. . 66. 40' 17' 392. 9 1.34~ 1388 272 354 426. o: O, 66 40 17 392 38797 1979 799 1348 1662 1388 272 354 538 679 109 497 000 0o0 000 993 858 959 16 970 270 157 660 55? 862 000 000 000 993 858 993 224 078 972 279 157 660 22! 436 567 862 683 000 200 RF6,PS2 RF10.PS2 RFt4.P$2 AVE1.PS2 TPHI.PS2 SBHF.PS2 ' AFFD P$2 sz~c:Ps2 SDS! PS2 TCAF:PS2 TSCF.PS2 RN2,P$2 RN6,P$2 RNIO.P$2 RN14,PS2 RF2,PS2 RF6,PS2 ~FIO,PS2 RFJ4 P82 AV i:PS TPHX.PS2 SBHF,PS2 AFFD.PS2 SIGC.PS2 SD$I,P$2 TCAF.P$2 TSCF,PS2 RN2,P$2 RN~O.P$2 RN~4.PS2 RF2,P$2 RF6,P$~ RF10,P$ RF!4 PS2 AVE1. :PS2 524.840 683,093 ~ 000 43 51 43 ~54 I 020 11609 566 614 143 190 1334 135 1594 55i 268 429 0 000 43,949 43 654 10~ 532 104 1 20 116 0 ~68 614 09 143 190 1334 135 1594 551 867388 34 830 386 ~19 516 27 268,429 o*o00 ~8~liS~r,: r .. ~s a' ~ompu~zJna, Center F?LE NAP.~ : EDIT ,002 SERVICE ~ FLIC VERSION : 001A04 DATF : 90!08/24 ~AX REC SIZE ~ ~096 FILM TYPE : LO LAST FILE : **** FILE MEAD.ER **** FILE NA~E : EDIT SFRVICM : FLIC VERSION : 00lA04 DATE : 90/08/24 ~AX REC SIZE : 1096 FIL~ TYPE : LO LAST FILE ****************************************************************************** , * FILE - EDIT,003 , * ARCO ALASKA INC. * PRUDHOE BAY * D $ * 5~-629-20078-00 , , , , * , ****************************************************************************** PASS THREE ' FROM FIELD FILE 12 DATA SAMPLED EVERY '.5000 FEET DATA INCLUDED TOOL ~XTENSIOM TOOL TYPE USED MA~E TDT-P ,PS3 THERMAL D~CAY TOOL TABLE TYPM : CONS TUNI VALU DEFI C~ ARCO ALASKA !NC, Compan Name FN PRUDHoE BAY Field ~ame ..umberger Alaska Co~i. u lng Center. 4-1 1327' $ & 295' W NE CRN ~4 NORTH SbOPE ALASKA USA APIN SECT TOWN RANG COUN STAT NATI WITN SON PDAT EPD LMF APO TOD STE~ WHIDDON /R~INTS ~91432 FT FT 64, FT 25 D- E, GF 0, well Name AP1 Serial Number Field bocation Section Township RanQe County State or Province Nat~on hat rude bonqitude Witness' Name Service Order Number Permanent datum hOg Measured FrOm TABLE TYPE : CUPV DEFI DEpT SlG~ STDT TPHI SFFD SFND SBH~ FTDT NTDT AFFD ABFD AFND SIGC S!B~ TPAT SDS! FBAC TCA~~ TCAF Depth Channel Name Stqma (Neutron Capture Cross SeCtion) Status of TDT TDT Porosity TDT Shunt Current Sigma formation - ~ar detector (TDTP) Sl~%am formation - near detector (TDTP) S~qma borehole = far detector S~qma borehole near detector (~.' T Far TDT~ Count Rate Near TDT~ Count Rate Amplitude formation -- far detector (TDTP) AmDli. tl~)de borehole -- Far detector {TDTP) AmSlitude formation - near detector (TDTP) Amplitude Borehole -- near detector (TDTP) SIG~ Correction Borehole sigma (corrected) -- TDTP ~lnitron mode ~onitor ratio (TDTP) TDT Ratio Standard deviatlo~ of Sl~ma-format~o~ (TDTP) Back,round, Near Gates Far Background Total counts analVzed - near detector (TDTP) Total counts analyzed - ~ar detector (TDTP~ a' m Inq Center DEFI TCMD Total counts.- near detector (TDTP) TCFD TOtal counts - far detector (TDTP) TSCN Selected qates count rate - near detector ~TDTP) TSCF Selected ~ates count rate - far detector INND Inelastic count~n~ rate - near detector (TDTP) INFD Inelastic count~D~ rate - far detector (TDTP) RN~ Raw Near ~st' Gate RN2 Raw Near 2nd Gate RN3 Raw Near 3rd Gate RN4 Raw Near 4th Gate RN5 Raw Near 5t~ Gate RN6 Raw Near 6th Gate RN7 Raw Near 7th Gate RM8 Raw Near 8th Gate RNQ Raw Near 9th Gate RN!0 Raw Near loth Gate RNI~, Raw Near llth Gate RM~,~ Raw Near !2th Gate RNa3 Raw Meat ~3th Gate RN14 ~aw Meat 14th ~Gate RN15 Raw ~ear ~5th Gate R~6 Raw Near ~6tb Gate RF1 Raw Far /st Gate RF2 Raw Far 2nd Gate RF3 Raw Far 3rd Gate RF4 Raw Far 4th Gate ~F5 Raw Far 5th Gate RF6 Raw Far Sth Gate RF7 Raw Far 7th Gate RF8 Raw Far 8th Gate RF9 Raw Far 9th Gate RF10 Raw Far 10th Gate RFi! Raw Far llth Gate RF ~ Raw Far 12th Gate RF13 Raw Far 13tn Gate RFI4 Raw Far ~4th Gate RFI5 Raw Far 15th Gate RF.6] Raw Far 16th Gate AVEO Average Output 0 Av~I Averaqe Output ~ GR GammaRav TFN$ Tension CCL CC5 Amplitude chlumberoe ~ laska ComDu nc , nter ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE ~EPR CODE VALUE I 66 0 ~ 66 O 3 73 268 4 66 5 66 6 73 7 65 9 65 · 1! 66 4 !~ 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API aPI API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG.TYPE CLASS MOD ~UMB SA~P ELEM CODE (HEX) DEPT FT SIG~ PS3 CU STDT PS3 TPMI PS3 PU ISHU PS3 V SFFD PS3 CU SEND PS3 CU SB~{~ P83 CU 39!4~2 oo 391.432 51. 391432 5! 391432 51 391432 51 391432 51 391432 51 39!43...~ 51 391432 5! FTDT PS3 CPS 391432 51 NTDT PS3 CPS 391432 51 AVFD PS3 CPS 391432 51 ABED PS3 CPS 391432 51 AFND PS3 CPS 391439 51 A~ND PS3 CPS 39t. 432 51 SIGC P$3 CU 391432 51 SIBH P$3 CU 391432 51 ~MOF PS3 391432 5i TRAT PS3 391432 51 SDSt PS3 CU 391432 51 BACK PS3 CPS 391432 51 FBAC PS3 CPS 391432 51 TCAN PS3 391432 TCAF PS3 391432 51 TCND PS3 CPS 39143~ 51 TCFD PS3 CPS 391~32 51 000 00 0 3 1 1 4 68 0000000000 400 01 0 3 1 1 4 68 0000000000 390 00 0 3 I I 4 68 0000000000 890 0! 0 3 1 1 4 68 0000000000 000 00 0 3 1 I 4 68 0000000000 400 02 0 3 I 1 4 68 0000000000 400 02 0 3 1 1 4 68 0000000000 400 O1 0 3 I 1 4 68 0000000000 400 O1 0 3 1 1 4 68 0000000000 000 00 0 3 ! 1 4 68 0000000000 000 00 0 3 1 ! 4 68 0000000000 391 00 0 3 I 1 4 68 0000000000 39! 00 0 3 1 ! 4 68 0000000000 390 O0 0 3 I 1 4 68 0000000000 300 O0 0 3 t 1 4 68 0000000000 400 O1 0 3 I I 4 68 0000000000 400 O1 0 3 1 1 4 68 0000000000 000 00 0 3 ! 1 4 68 0000000000 000 00 0 3 I 1 4 68 0000000000 000 00 0 3 1 I 4 68 0000000000 390 17 0 3 I 1 4 68 0000000000 391 1.7 0 3 I I 4 68 0000000000 000 00 0 3 1 t 4 68 0000000000 000 O0 0 3 i I 4 68 0000000000 000 00 0 3 t 1 4 68 0000000000 go0 O0 0 3 ! 1 4 68 0000000000 ~chlumberqer ....... A.i Com~ino· Center. N~ME SERV UNIT ID SERVICE API API AP! ORDER ~ LOG TYPE CLASS TSCN PS3 CPS 391432 T~CW PS3 CPS 3g~432 INND PS3 CPS 391432 INFD PS3 CPS 39~432 R~!i PS3 CPS 391432 RN2 PS3 CPS 391432 RN3 PS3 CPS 391432 RN4 PS3 CPS 39143~ RN5 PS3 CPS 391432 RE6 PS3 CPS 391432 R~7 PS3 CPS 391432 RN8 PS3 CPS 391432 RN9 PS3 CPS 391432 RN!0 PS3 CPS 391432 RMI1 PS3 CPS 39143~ RNI~ PS3 CPS 391432 RN13 PS3 CPS 391432 R~!4 PS3 CPS 391432 RNI5 PS3 CPS 391432 RE16 PS3 CPS 391432 RF1 PS3 CPS 391432 RF~ PS3 CPS 391432 RF3 PS3 CPS 39143~ RF4 PS3 CPS 391432 RF5 PS~ CPS 391432 RF6 PS3 CPS 391432 RF7 PS3 CPS 391432 RF8 PS3 CPS 391432 RF9 PS3 CPS 391432 RF!O PS3 CPS 391432 RFI1 PS3 CPS 391432 RF12 PS3 CPS 391432 RF!3 PS3 CPS 391432 RF~4 PS3 CPS 391432 FI5 P$3 CPS 391432 .FI6 PS3 CPS 391432 AVEO PS3 391432 AVM~ PS3 391432 GR PS3 GAP/ 391432 TFN~ PS3 LB 391432 CCL PS3 V 391,432 5I 000 O0 51 000 O0 Si 000 O0 51 000 O0 5~ 390 O1 51 390 O2 5! 300 03 51 390 04 51 390 05 51 390 o6 51 390 07 51 390 08 5! 390 09 5l 390 5! 390 51 390 I2 51 390 13 51 390 14 51 390 15 51 390 16 5! 391 51 391 2 51 391 03 51 391 04 51 391 05 51 391 06 51 391 07 51 391 08 51 391 09 51 391. 10 51 391 !1 51 391 12 5! 391 13 51 391 14 51 391 15 51 39! t. 6 5t 000 O0 51 000 00 5! 31o 01 51 635 21 51 150 O1 DATA ** DEPT 9684,500 SIGN.PS3 ISHU:Ps3 46.438 sFFD~Ps3 SBHN,PS3 48.356 FTDT,PS3 ABFD.PS3 100,562 AFND,p$3 ~H,P~3 47~042 MMOF.P~ AP1 MOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 FILE NUMB NUMB SIZE REPR PROCESS NUMB SAMP EhEM CODE CHEX) 3 I ! 4 68 0000000000 3 I 1 4 68 0000000000 3 I 1 4 68 0000000000 3 I 1 4 68 0000000000 3 1 1. 4 68 0000000000 3 I 1 4 68 0000000000 3 ! 1 4 68 0000000000 3 1 1 4 68 0000000000 3 1 I 4 68 0000000000 3 I I 4 68 0000000000 3 I 1 4 68 0000000000 3 I i 4 68 0000000000 3 1 1 4 68 0000000000 3 I 1 4 68 0000000000 3 ! 1 4 68 0000000000 3 1 1 4 68 0000000000 3 1 1 4 68 0000000000 3 1 I 4 68 0000000000 3 I 1 4 68 0000000000 3 I ! 4 68 0000000000 3 I 1 4 68 0000000000 3 ! ! 4 68 0000000000 3 I 1 4 68 0000000000 3 1 I 4 68 0000000000 3 1 I 4 68 0000 000000 oooooooo o 3 I 1 4 68 0000000000 3 1 1 4 68 0000000000 3 1 ! 4 68 0000000000 3 1 I 4 68 0000000000 3 1 1 4 68 0000000000 3 1 I 4 68 0000000000 3 1 1 4 68 0000000000 3 I I 4 68 0000000000 3 ! 1 4 68 0000000000 3 1 ! 4 68 0000000000 3 1 1 4 68 0000000000 3 ! I 4 68 0000000000 3 ! I 4 68 0000000000 3 I ! 4 68 0000000000 3 ! ! 4 68 0000000000 37.414 39,5!8 5 340 430:879 1,116 S~DT,PS3 66.000 TPHI,PS3 Sf'ND,PS3 40 993 SBHF.PS3 NTDT,PS3 17i858 AFFD.PS] ABND,PS] 392 993 SIGC.PS3 TRAT,P$3 3,224 SD$I.PS3 43 949 43 654 103 532 2 104 1 020 -mberqeT Alaske CompUtlnq CenteT PN7 PS] RNI~ PS3 RNIS.PS3 PFR,PS3 RF7.ps3 RF~!.,PS3 GP,P$3 DEPT. ISM!! PS3 SBHM ABFD PS3 SIBH P$3 B~C~ PSt TC~D RNV;PS3 R~! [ ! [ PS3 RM15.P83 RF3,PS3 gFT.PS3 RFil'PS3 RF!S'PS3 GP,PS3 D~PT. I$~U..PS3 A~FD'P§3 ~C~'PS3 INND.pS3 ~N3.PS3 NI!..P$3 N15.PS3 ~F3,PS3 ~F7 PS3 ~F~5.PS3 G~,PS3 ISHU'PS3 ABFD.PS3 SIB~.PS3 150,96~ 16024,B55 2016.048 973.958 1302,083 2932.292 1,875 520.833 ~036.458 11~9.,792 403,750 9600.000 37 313 S :7o2 395 !4~.526 1669 :~40 1002,083 808,333 2258.333 568.750 30~.083 ,417 133,333 72,875 9500.000 37,3t.3 41,354 I]4'747 6.724 191,008 24811,164 2030,999 947,917 !193.750 2764.,583 ~772.9~7 272.917 543.750 1016,667 t027,083 867.000 9410.O00 7'313 46'027 136 350 153,010 FBAC.PM3 TCFD.PS3 INFD'P$3 RMS~PS3 RN16.P$3 RF4,PS3 RFS,P$3 RF12.P$3 RF16.PS3 TENS. pS3 SFFD.PS3 FTDT.P$3 AFNO.PS] ~OV~PS3 FBi'.Ps3 TCFD.PS3 INFD*_o3 RN4.P$3 RNS~P$3 RM12.P$3 RM16.P$3 RF4,PS3 RF8 PS3 ~FI2:P$3 EFI6.P$3 SIG~.PS3 SFFD'PS3 FTDT'P$3 AFND PS3 FBAC,P$3 TCFD.PS3 IMFD.PS3 RN4.P83 RNS.P$3 RNI~.PS3 RN~6.PS3 RF4.PS3 RF8.P$3 RF12.PS3 RF16.P$3 TENS.PS3 SIGM.PS~ SFFD.P$3 FTDT.PS3 AFND PS3 37,483 43~6.814 3 0,591 1369,792 916.667 3!30 ~08 1307 ~92 458 3~3 338 542 1125 00o 796 875 1055:000 36 99 6 056 9~ 2 5 375. 39 1408.133 827.083 2031250 51:583 4o . so 32 833 63~ 333 !0 67 i44~ 10 00 15 249 17!851 11 42O 399 266 I 212 382 189 134~ 667 870 833 2979 167 995 833 425 000 306-250 1!27:0~3 764 58 2 884 11 . 4a8 661 30 438 TCAW.PS3 TSCN,PS3 RMI,PS3 RN5,PS3 RMg,PS3 .RM13,PS3 RFI,PS3 RFS,PS3 RF9,P$3 RF13,P$3 AVE0,PS3 CCh,PS3 STDT,PS3 SFND,PS3 NTDT,PS3 BND*P$3 RAT,PS3 TCAN,PS3 TSC~,PS3 RN1,P$3 RN5,P$3 RNg*P$3 RNI3,P83 RFI,PS3 RF5,PS3 RFg,P83 RF13iPS3 AVE0,P$3 CCh,PS3 STDT,PS3 SFNO,P$3 NTDT,PS3 TRA PS3 ?CAN~PS3 T$CM:PS3 RNt.*P$3 RNS,P$3 RN9-P$3 ~F~,PS3 RF5,P$3 RFg,PS3 RF13,P$3 AVE0,PS3 CCL'PS3 STDT,P$3 $FND.PS3 NTDT PS3 TRAT.PS3 TCAN,PS~ 797 38979! 1817 !520' 1791. 3343..' 265~ 489' 645, 1223' 30. 0. 66. 39 18 404 2 39689 2155 783 1358 1650 1491 266 4OO 581 485 37 0 66° 3oi 420 2 66200 6956 79! 1454 1839' 2989, 264' 466' 654' 208- 66 18 29 444 2 70511, 078 972 708 833 667 750 625 583 833 958 89t 000 000 14 73~ 166 000 667 667 000 250 125 000 000 039 672 05 '906 477 667 167 58~ 583 667 67 000 0o0 387 713 1~78 89 109 TCAF.P$3 T$CF,P$3 RN2*PS3 RN6,P$3 RNIO,P$3 RN14,PS3 RF2,P$3 RF6,PS~ RFII.P$3 RF1 .PS3 AVEI.P${ TPHI,PS3 SBHF,PS3 AFFD.PS3 SIGC. PS3 susz:Ps3 TCAF.PS3 T$CF,P$3 RN2,P$3 RN6,P$3 RNa0 P$3 RN14:P$3 RF2.PS3 RF6,P$3 RF10,P$ RFi4,P$1 AVEI,P$3 TPHI,P$3 SBHF P$3 AFFDiPS3 $IGC PS3 SDSI,PS3 TCAF,P$3 TSCF,PS3 RN2,P$3 RN6'P$3 RNIO,P$3 RNi4,PS{ RF2.P$3 RF6,P$~ RFIO P83 RF14iP$3 AVEJ,P$3 TPHI,P$3 SBHF.P$3 AFFD PS3 s cclPs3 SDSI,PS3 TCAF,P$3 11610.768 206, 1723'958 2046,87S 3005.208 159;960 614'583 43,194 45,5846 7 Io I13989 320 94~ 667 26 537 389 583 550 000 277 083 0 496 24 637 I8~6 694 54! 27670 5 9 2907 616 1897 9! 2593 132 686 6!2 500 654 7 0 253 r 21.150 39,905 111.375 32215,3 5 '273 S~hlu~hero. er AlasKa ~om~{ing Center TCND,PS3 26!64.4t4 INND PS3 2143,407 RN3~P$3 !045,833 RN7,PS3 1170.833 R~!ll.PS3 2858,333 RN.15,PS3 !681,250 F~,PS~ 325,000 , FT,PS3 406,250 RF~,PS3 1033,333 RFtS,PS~ 785,417 GR,PS3 45,406 DEPT SBHN PS3 ABFD,PS3 SIBH.PS3 BACK,PS3 TCMD,PS3 IMND,PS3 ~Ng,PS3 ~F3oPS3 ~F7,PS3 ~FI1 PS3 PT SBHN,PS3 ABFD,PS3 SIBH,PS3 B~CK.PS3 TCND P$3 INMD P$3 ~3 PS3 RN!5'PS3 ~F3,PS3 RFT,PS3 Rf'!!"PS3 RF15,PS3 GR.PS3 SBHN,PS3 ABFD,PS3 BAC~'PS3 TCND,PS3 9300,000 42,563 45,703 !30.018 43,250 !60,492 22289 !84 ~954 345 976 562 586 1286 892 310,4~7 325,000 97~,917 512.5oo 56,750 9200 000 43:~44 49'873 104.0~.5 49'470 153,74t 16103,582 t~53'411 57,031 66,059 2~28,906 ~8,490 269,097 221'354 6~4 531 136,500 9187,500 47,719 49,874 104.0~0 49,470 t53'741 16103,697 TCFD.PS3 INFD,PS3 RN4.PS3 RN8,PS3 RNI2 PS3 R~16:PS3 RF4.PS3 RFS,PS3 RFI2.P$3 RF16,PS3 TENS.PS3 $IG~.PS3 SFFD.P$3 FTDT,PS3 AFND,PS3 ~MOF.PS3 FBAC.PS3 TCFD,PS3 I~FD.PS3 RN4 PS3 PS3 R~12,PS3 R~tT,PS3 RF4, P$3 RFS:PS3 RFI2,P$3 RF16,PS3 TENS,PS] SIG~,PS3 SFFD,PS3 FTDT,PS3 AFND,PS3 FBAC.PS3 TCFD,P$3 IMFD.PS3 RN4'P$3 RNS,P$3 RN12.P$3 RglT,PS3 RF4,PS3 RFS.PS3 RF12 P$3 TEMS.P$3 SIGM.'PS3 SFFD,PS3 FTDT.PS3 AFND,P63 MMOFP$3 FBA~iP$3 YCFD,P$~ 9312.518 419.160 1450.000 879,!67 3035.417 925,000 454,167 5OO 337, . 1!31.~50 381.250 1445,000 22 S~ 10 168 415 269 7422 895 I~9 139 .! :146 861 545 2~5 521 726 996 406 250 308 333 954 ~67 212.500 1415,000 40 290 401301 5,473 422o8~5 442 2 ~39 _4 1905 353 733 303 ~9 579 427 12~ 038 ~420.000 40 245 401301 5 3 .1 2~8 35:82 4427'931 TSCN,PS3 R~t.PS3 RNS,PS3 RNg,P$3 RN13,PS3 RF1,PS3 RF5,PS3 RF9,P$3 RF13,PS3 AVE0.PS3 CCL,P$3 STDT.PS3 SFND,P$3 NTDT,P$3 ABND'p$3 TRAT,P$3 TCAM'P$3 TSCN,PS3 RNa;PS3 RNS,PS~ RMg,P~3 R~_-.13,P 3 RFI,PS3 F5.PS3 Fg,PS3 RF13,PS3 AVE0.P$] CCL,P$3 STDT.PS3 SFND,PS3 NTDT,PS3 ABND,PS3 TRAT,P$3 TCAN,PS3 TSCN.PS3 PN!,P$3 RN5,PS3 RN9,PS3 RN13'PS3 RFS,PS3 RFg,Ps3 RFI3,PS3 AVEO'PS3 CCh,PS3 STDT,PS3 SFND,PS3 NTDT.PS3 ABND,PS3 TRAT'PS3 TCAN,PS3 TSCN,P83 7344.871 847.917 1.514.583 189t,667 3097.917 277.083 481.250 702'083 1210.417 12.836 o'ooo 66.,000 26,113 28.671 426.305 46970 8 4990 321 802 951 1471 354 1840 278 2775.607 279,167 437'500 681.250 981'250 922 g:ooo 66,000 40'340 18.706 386.862 3'415 37610.047 ~9~ 1336 805 1668 837 46 1434 07~ 256 368 92.4 544 705 429 687 0.000 66,000 40.340 18'706 86.'848 3.415 37602'422 2!07,579 TSCF.PS3 RN2.PS3 RNS,P$3 RNIO,P$3 RN14,PS3 RF2,P$3 RF6eP$3 RFIO.P$3 RFI4 PS3 AVE1 :PS3 TPHI,PS] SBHF.P$3 AFFD.PS3 SIGC.P$3 SDSI,PS3 TCAF,P$3 TSCF,P$] RN2,P$3 RN6,P$3 RN10-,P$i RNI4,P$ RF2,PS3 RF6.,P$3 RF10.P$3 RF14,P$3 AVE1,P$3 TPHI,PS; SBHF,P$ AFFD P$3 SIGC PS3 $D$I PS3 TCAF PS3 TSCF PS RN2 PSi RN6'PS3 RNIO.PS3 RN14,PS3 RF2.PS3 RF6,PS3 RFIO,PS3 RF14,P$3 AVEI*P$3 TPHI,PS3 5BHF.PS3 AFFD P$3 sz¢clPs3 SD$I.P$i TCAF.PS T$CF,P$3 3355 74t i39 320 1658 333 1968 750 2602083 30 960 708 1095 833 0 205 99 9 2 4 416 0 565 19175 656 2037 274 159 223 1566 840 !879 340 96 ~75 000 685 417 83~.500 262 °o :11o 87O 33 171 351 562 5O3 472 249 566 0 441 45, 74 6~7,209 Chl~m ,er ~er Alaska CO~DU~:. ln~ Center INND,PS3 1853,588 INFD,PS3 RN3,PS3 957,031 RN4,P$3 PN7,PS3 766.059 RNS,PS3 RNII'PS3 2128.906 RN12.PS3 aNtE,PS3 6!8,4o0 RN16,PS3 RF3,PS3 269,0~7 RE4.PS3 RF7 PS3 221,354 aFB.PS3 RFII~PS3 644.53l RF12.PS3 RE15 PS] 145,399 RE16. PS3 GP:PS3 ~0,000 TENS:PS3 368,530 1278.212 839.844 1905,382 635 851 353 933 303 819 579 427 t28 038 1420 000 RNI,PS3 aND,PS3 RN9,PS3 R~!3,PS3 RFI,PS3 RED'PS3 RFg*.PS3 RFIE.P$] AVE0,PS3 CCL,PS3 807 292 RN2,PS3 1336:805 RN6.PS3 1668,837 RN10.PS3 1434.462 RN~4.PS3 256.076 RF2.PS3 368'924 RF6.P$3 544.705 RF~0.P$3 429,687 RF14,PS3 .000 AVE1.PS3 .000 145 954 1,360 677 1569 0t0 870 226 0 000 **** FILE TRAILER **** FILM NAME : EDIT .O03 SERVICE : FLIC VERSION ~ O0~A04 DAT~ ~ 90/08/~4 MAX RFC SIZE : 1096 FILE TYPE LAST FI[,E **** FILE HEADE~ **** FILE MA~E t EDIT .004 SERVICE ~ FLIC VERSION I 001A04 DATE ~ 90/08/24 MaX RFC SIZE I ~096 FiLE TYPE ~ LO LIST FILE ******************************************************************************* FILE - ED!T,004 ARCO ALASKA INC. PRUDHOE BAY P $ 4-1 ~ASE GAMMA RAY & HODGES LEHMAN AVERAGED CURVES DATA SAMPLED EVERY -.5000 FEET DATA INChUDED- 8chl etqer aska ComDutiDg Center , * TOOL * TYPE USED , * TDT-P * SIGN .HLA * SIPH ,HLA * TPH~ ,H[,A * TOOL BASE RU~ GAMMA RAY (FILE 9) FORMATION SIGMA MODGES-LEH~dAN AVERAGE (FILE BOREHOLE SIGMA HODGES-LEH~4AN AVERAGE (FILE POROSITY HODGES~LEH~AN AVERAGE (FILE ****************************************************************************** TABLE TYPE :CONS TUNI vAbu DEFI ARCO ALASKA INC, Company Name Field Name PRUDHOE BAY 2oo, .oo 1327' S & 295' W NE CRN 34 NORTH sLOPE ALASEA USA CN WN TOWM RA~ STAT ~ATI LATI SON PDAT APD EDF EGL TDD STE~ ~HIDDON /REINTS 391432 MSL FT O, FT 64, FT ~4. FT ~999,25 FT 25, FT 9739. o, Well Name APl Serial Number Field Location Section~ TownsbiD Range County Sta~e or Province Nation Latitude Lonoitu~e witness Name Service Order Number Permanent datum bog Measured From TABLE TYPE ~ CURV DEFI DEPT De~th Channel Name GR Gamma Ra CCL CCL AmplYtud~ SIGN S1Nma (Neutron Capture Cross Section) TPHI TDT Porosl~y S/BM Borebo!e s oma (~orrected) -- TDTP GR Gamma Ray DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ~* TYPE REP~ CODE VALUE ! 66 0 2 66 0 3 73 32 4 66 ~ 5 66 6 73 7 65 8 68 0,5 9 65 FT ~ 66 34 ~2 68 13 66 0 ~4 65 FT 15 66 68 ~6 66 ~ 0 66 1 ** SET TYPE - CHAN ** NAiF SERV UNIT SERVICE API API API AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB ~A~P ELEM CODE (HEX) DEPT FT 391432 O0 GR BGR GAPI 391432 51 CCL BGR V 39~432 51 SIGN HhA CU 391432 51 TPHI HLA PU 39~432 51 SIBH HbA CU 391432 5! GR HLA GAPi 39~432 51 CCL HLA V 391432 51 000 O0 0 4 I ! 4 68 3!0 01 0 4 ! I 4 68 150 01 0 4 ! 1 4 6~ 150 O! 0 4 ! 1 4 68 150 Oi O- 4 I 1 4 68 150 Ol 0 4 1 ! 4 68 310 O1 0 4 I 1 4 68 150 O! 0 4 1 I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** D~DT, 9686,500 GR BGP, -999 250 CCL.BGR -999.250 SIGN HbA TPHI,HbA 40,7~.3 $IBH:HbA 36:969 GR,HbA 228.000 CCb:HLA 'o Center D~PT. 9600 O0o DEPT, 9500,000 TPNI,HLA 25,146 DEPT. 9400,000 TPHIo~I.~A 20.752 DEPT, 9300,000 TDHI,HLA 25,684 DEPT. 920(3. 000 · TP[{I. }~LA 46,826 DEPT. 9100,000 TPHI,HLA -999,250 DEiPT, 9000,000 TPH!.~LA '999"250 DEPT,. 8900,000 TPH!.MLA -999,~50 DEPT,' ~848,500 TPN!'}!LA 999,250 END 0~ DATA GR.BGR ~999.250 CCL,BGR -999 250 $IBH.HbA 5~.406 GR,HbA 451031. GR.BG~ -999 250 CCL,BGR -999.250 SI8~.HLA 36~844 GR,~LA 872.000 GR BGR 60 938 CCb,BGR 0 000 S!8H:HLA 44:094 GR.HLA 16:344 GR.BGR 82,375 CCLoBGR 0 000 SIBH,HLA 43,500 GR,HL~ 30:250 GR BGR I19.6~8 CCL,BGR 0,000 SlBH~I[,A 47,469 GR.~!,A 118,375 GR.BGR 90 563 CCL,BGR 0.000 SIBH.HLA -999:250 GR.HLA -999,250 Si CC .S a 0 0o0 SIB,:HbA -999~2 0 ¢a.HhA '999:250 GR.BGR 54,938 CCb,BGa 0.000 $IBH.HLA ~990,250 GR,MLA -999,250 GR.BGR 62 094 CCL,BGR 0 000 SIDH,HLA -999:250 'GR,HLA -999:250 SlGM,HLA CCL,HLA SIGM,HLA CCL,HLA CCL,HLA $IGH,HLA CCL,HLA $IGM,HbA CCL,HLA S!GM,HLA CCb,HbA $IGM,HLA CCL,MLA CCL,HbA SIGM.HbA CCL.HLA ,656 3~,000 15,281 0.000 1~,859 ,000 18.078 0.000 -999,250 -999,250 0 :9 . '999,250 '999.250 .999, o -999,250 **** FILE TRAILER **** FILE NA~E I EDIT ,004 SERVICE ~ FL!C V~RSION : O01. g04 DATE I 90/08/24 ~AX REC SIZE : 1096 FILE TYPE I LO baST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE ~ 90/08/24 ORIGIN : FLIC TAP~ NA~E : 74019 CONTINUATION ~ ~ 1 PRE~IOUS ~APE : CO~ENT : ARCO ALASKA !NC.,PRUDMOE BA¥,D.S, 4-1,50-029-20078-00 $Cbl~' ~be~ger a, ske. Co~U~ .: ina Center SERVICE NA~ : EDIT DATE : 90/08/24 ORIGIN ~ FLIC R~EL NA~E : 74019 CONTINUATION # : PREVIOUS REEL ~ CO~ENT : ,A~CG A~,ASKA I~JC,,PRUDHOE BA¥,D,S, 4-!,50-029-20078-00 F~L'E ~{'A~E I EDiT ,001 ..... : FEL ~m PAGet NA~ SERV O.~T SgR¥~Cg APl: AP! APl AP! FILg NUmB NUMB SiZE REPR PROCESS 4 8 OOOO0 O00000OO00 0000000000 PS 1 (:Cb, 478 RCNT, 4ss: o cc[ ~0.904 TNRA 9'20078"00 : PROGRAM: LISCAN REVISION: 5.1 PART NUMBER: W5790-PE32 Start of execut±on: Tue 21 NOV 88 7:38a **** REEL HEADER **** LIS 88/11105 ATLAS 01 LIS CUSTOMER mORMAT TAPE **** TAPE HEADER **** LIS 88/11/05 3597 01 3 PASS CN/MS, GAMMA RAY PASS TAKEN FROM PASS 3. FILE # 1 PASS 1.001 **** FILE HEADER **** 1024 CN : ARCO ALASKA INCORPORATED WN D.$. 4-1 : PRUDHOE BAY FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH DER FRAME TAPE DEPTH UNIT : FT 12 CURVES : NAME CODE SAMPLE# UNIT BYTES 1 GR 68 I API 4 2 TTEN 68 1 LB 4 3 TEN 68 I LB 4 4 SPD 68 1 F/MM 4 5 CCL1 68 1 VOLT 6 CCL 68 1 VOLT 7 SSN 68 1 CTS g CSSN 68 I CTS 9 LSN 68 I CTS 10 CLSN 68 1 CTS 11 CN 58 1 PCT 12 CNC 68 1 PCT * DATA RECORD DEPTH CCL1 CLSN 97?0.000 3.000000 10.24898 9670.000 6.000000 9.180777 9620,000 3.000000 9.479250 9570.000 3.000000 16.08847 9520,000 5.000000 13.57093 9470.000 3.000000 12.27933 9420.000 3.000000 17.94839 9370.000 5.000000 18.35345 9320.000 3.000000 23.28998 9270.000 3.000000 8.571251 (TYPE# 0) GR CCL CN 514,2344 3.000000 15.00000 1444.048 6.000000 33.22198 58g.1753 3,000000 39.16246 62.56813 3.000000 27.75809 t92.4363 5,000000 30.49425 191,2181 3,000000 31.70534 119,1687 3.000000 24.62065 102.8241 5.000000 23.18178 80. 63565 3.000000 20.52443 155.7696 3.000000 42.60829 994 6YTES * TEN SN NC 1549.245 126.9873 19,00000 1767.087 142.0028 .37.22198 1759,541 148.6032 43.16246 1755.930 183.6859 31.75809 1720,592 181,2581 34.49425 1729,481 159.1455 35,70534 1716,211 248.4404 28.62065 1701 .540 187,7398 27,18178 1707.555 223,1429 24.52443 1700,496 140.9778 46.60829 TEN CSSN 262.2730 126,9873 127.2161 132.8860 22.54958 150.9192 0.3294015 207.0767 -17.11934 184.5531 -6.793879 172.7810 -8,174614 213,6728 -13.91837 208.3388 -6.419029 243.3959 11 .79893 143.4401 SPD LSN 15.99840 40.99591 24.81000 39.83951 25.22881 33.80182 25.41489 56.05560 25.10031 54.84563 25.47719 44.82840 25.72971 98,49451 75.84770 51.82089 25.49379 78.60222 25.63359 30,75819 TOTAL DATA RECORDS STARTING TAPE DEPTH FILE TRAILER **** 53 9720.00 ENDING TAPE DEPTH = 9224.00 FILE # 2 PASS 2.002 **** FILE HEADER **** 1024 FORMAT RECORD (TYPE# 04) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 12 CURVES : NAME 1 GR 2 TTEN 3 TEN 4 SPD 5 CCL1 5 CCL 7 SSN 8 CSSN 9 LSN 10 CLSN 11 CN t2 CNC CODE SAMPLE~ UNIT 68 I API 68 I LB 08 1 LB 68 1 F/MM 68 1 VOLT 68 1 VOLT 68 I CTS 68 1 CTS 68 1 CTS 68 1 CTS 68 1 PCT 68 I PCT BY 4 4 4 4 4 4 4 4 4 4 4 4 TES * DATA RECORD DEPTH CCL1 CLSN 9724.000 3.000000 10.24898 9674.000 6.000000 9.463001 9624.000 4.000000 8.457874 9574.000 3.000000 11.92860 9524.000 4.000000 12.94553 9474.000 3.000000 10.2522'7 9424.000 3.000000 (TYPE# O) GR CCL CN 523.4172 3.000000 15.00000 1548.004 6.00OOO0 34.20259 713.4985 4.000000 46.02184 90. 29643 3.000000 31.21983 180,1772 4.000000 31,18864 194.4758 3.000000 32.60831 94.50435 3,000000 994 BYTES * TTEN SSN CNC 1549.245 129.9870 19.00000 1781.093 146.4922 38.20259 1775.223 161.8158 50.02184 1754.665 199.6841 35.21983 174!.26~ 188,2306 35.18864 1729.761 163.8084 36.60831 1733.176 228.0246 TEN CSSN 271.4229 129.9870 103.4301 139.0675 I 5.01 027 148.9760 -13,23365 165.4341 -13.83054 179.8980 -6.573058 146.3067 -10.32059 250.3485 SPD LSN 15.99840 40.99591 23.17401 45.62361 23.67761 41.16481 23.36151 64.59300 23.30110 55.48430 24.19102 48.27271 24.14459 77.87411 23. 50838 21 · 16478 9374.000 111 .9416 451,0000 451 ,0'300 15,50817 30,45580 9324.000 59,:.59181 4.000000 4.000000 23.32417 20.12003 9274.000 174.4214 3,000000 3,000000 8.091 87~ 4(~.43539 25.164 1729.6 217.01 34.455 1724.7 236.44 24.120 1709.1 150.72 53.435 78 40 61 80 71 29 03 43 49 3Q 2.251511 211 .1225 -10.47!87 242.2956 -12.57820 147.7825 24.08771 72.17351 24.40370 87.95383 24.36142 33.21591 TOTAL DATA RECORDS : STARTING TAPE DEPTH = mILE TRAILER **** 53 9724.00 ENDING TAPE DEPTH = 9228.00 FILE # 3 PASS 3.003 **** FILE HEADER **** 1024 FORMAT ONE DEP TAPE DE RECORD (TYPE# 64) TH PER FRAME PTH UNIT : FT 12 CURVES : NAME ! GR 2 TTEN 3 TEN 4 SPD 5 CCL1 6 CCL 7 SSN 8 CSSN 9 LSN 10 CLSN 11 CN 12 CNC ODE SAMPLE# UNIT 68 I AP1 68 1 LB 68 1 LB 68 1 F/MM 68 1 VOLT 68 1 VOLT 68 1 CTS 68 1 CTS 68 I CTS 68 1 CTS 68 1 PCT 68 1 PCT BYTES 4 4 4 4 4 4 4 4 4 4 4 4 * DATA RECORD DEPTH CCL1 CLSN 9724.000 65527.00 16357.37 (TYPE# O) GR CCL CN 149121.1 65527.00 15.00000 994 BYTES * TTEN SSN CNC 1512.649 65204,48 19.00000 TEN CSSN 210.4290 65204,48 SPD LSN 19.99799 65429.46 6 '? ~,. 0 U 0 I 4 '~ '~. Z 71 1 'r 'r~.B. '~ 91 6. 000000 6. 000000 1 42.3 807 9.448874 34. 26706 38.2670~ 624. 000 757.6&99 1769.21 6 2. 000007 2. 0000~ 157. ~1 61 9.2o4201 41.51 527 45.51 527 574 . 009 101 . 7772 I 75~9.41 3 3 · 000000 3. 000000 I 97. 0901 I ?. 51240 31 · 36681 35.36681 524. 000 164 . 3065 1752. 528 3.000000 3.000000 I 87.01 81 I 3.8 3658 27. ,¢54 ~ 29 31 . $4929 q. 74. 000 285.1 438 1 742.1 08 000000 4. 000000 1 82.1 81 1 53420 32 · 60345 36.60345 424.000 9,5. 02931 1738. 461 3. 000000 3. 000000 217.2154 21 · 59995 23. 13573 27. 13573 374. 000 108. 3850 1 739. 759 3 · 000000 3. 000000 219 · 71 50 1 5. 6531 8 29. 54329 33. 54329 3 24. 000 73. 00104 1 71 9.1 84 3 · 000000 3. 000000 249. 9840 25 . 20233 1 8. I 9475 22 · 19475 274.000 161 .6907 1715.901 3 · 000000 3 · 000000 I 47.9363 7. 242425 67.00126 71 .09126 99.'['6094 140.6512 10.21171 153.9068 -9.865837 174.0246 -8.301493 177.1047 -9.601707 164.3338 -5.787375 245.0541 0.2372898 208.9864 -8.657427 244.3201 -7.528620 152.5194 22.40631 42.94699 22.64790 39.05551 22.85710 65.58531 22.83540 55.29172 23.59140 52.29123 23.44441 75.26332 23.50070 71.57280 23.79752 97.67981 23.37411 31.81610 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 53 9724.00 ENDING TAPE DEPTH = 9228.00 **** TAPE LIS 88/11/05 3597 01 TRAILER **** TOTAL RECORDS IN THIS LOGICAL TAPE : 172 **** REEL TR,&ILER LIS 88111105 ATLAS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 173 TOTAL RECORDS IN THIS PHYSICAL REEL: 173 End of execution: Tue 21 NOV 88 7:39a Elapsed execut±on t£me = 56.00 seconds. SYSTEM RETURN CODE = 0 R~CEIYEI) NOV ! 0 ]982 Alaska Oil & Gas Cons. Commission Anchorage S~RVlCE · : ~: ,~ .c:- :~-: :-' -~:. ,~...'. :~ .'~ -..:,~:.~. .'..'~'~r:'~".::"L...:..:~.~:,u~:'.~,::a: :~'.~.-' ~.'.:, -':~.a~::-.:~-.:-~:;~r ~ -..:.~- - ~::...: ORIGIN CON? ~ ...... i'0'i ' ~R VIC ~' CO N Ti N D~'T"I O'N .... · :~;: L:':~ ~ :~< VZRSlON' ~ .......: .......... · '~-': .~ "~ :~': ;.?~J~.::~:: ::::. FN : PR'UDHO'E '"'~A'~ ...................................................................... - ......... .................... :~ ..... 000 000 012 065 "TO'~N{ I1N .... " ...... 065 COUN~ NORTH SLOPE '""- ...... '~' .................. ' ........ "" :" ..... 065 · *' "COMMENTS" i :.. -- ": ': CODE RUN, ~6, DA~'B.:"LOGGEDi 30'"0'~'T'-"~'~2 '"'~'-: .... '-' '.~ ~ PA6E CODE 68 68 68 68 I 68 68 ! 68 68 68 *# DAtA ** DEPT NRAT 0 8 68 -999 2500 2500 2500 2428 2500 2500 2500 :-2 oo 2500 ,2500 3,4480 28,2227 691.5000 29 9805 606 5000 2.8?83 DEP NRAT GR 2.6337 ' 16 2598 i299," 0'000 o O0 O0 · 4:801 3-6379 2, 2126 9 5703 2230 0000 :2(~ -5416 21:$t 0000 8605 :26 7090 ,~16 5000 3,32~4 1 o'7102 -9805 ~0000 ,5957 ,0000 2.3057 2'8839 '999.2500 '9:99.2500 '999.2500 -999.2500 NOV 1 o ]982 Alaska Oil & ~as Cons. Anchorage *----$CHSU~BERGER .... · LIS TAPE VERIFICATION 5ISTING LVP 009.H03 VERIFICATION LISTING PAGE ~* REEL HEADER SERVICE NA~E :SERVIC DATE :81/08/17 ORIGIN : REEL ~AME :REEL ID CONTINUATION # PREVIOUS REEL : COMMENTS :REEL COMMENTS ** TAPE HEADER SERVICE NAM~ :SERVIC DATE :81/08/I7 ORIGIN :FSIA TAP~ NAME CONTINUATION # PREVIOUS TAPE : CO~ME~YS :TAPE COMMENTS EOF ** FILE HEADER FILE HA~E :SERVIC.00! ~SERVICE NAME VERSION # DAT~ : MAXIMUg LENGTH : 1024 FILE TYPE PREVIOUS FILE INFORMATION RECORDS MNE~ CONTENTS CN : ATLANTIC R~HFIELD COMPANY FN : PRUDHOE BAY RANG: RANGE TOWN: TOWNSHIP S · ECT. SECTION COUN: NORTH SLOPE STAT: ALASKA CTRY: USA MNE~ CONTENTS PRES: FDN001F RECORO~''~'YPE 047 RECORD TYPE 047 ** UNIT TYPE CATE SIZE CODE 000 000 026 065 000 000 028 065 000 000 0~2 065 OO0 000 005 065 000 000 008 065 O00 000 007 065 000 000 012 065 O00 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 007 065 bVP 009.H03 VERIFICATION LISTING PAGE RECORD TYPE 047 ** DATA FORMAT ENTRY BLOCKS RECORD ** TYPE SIZE REPR CODE 8 4 73 9 4 65 0 ! 66 DATUM SPECIFICATION MNE~ SERVICE SERVICE ID ORDER ~ DEPT NPHi C~b RNRA CNL FCNL CML NCNb CNb GR CbL BLOCKS UNIT APl API APl API FILE bOG TYPE CLASS MOD NO. 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