Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
175-077
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1"aG-.S.2 V L..R�> JUL 0 2 20199 Ia. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ Well C SS e•w ^ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ 11 WAG 11 WDSPL ❑ No. of Completions: Zero 11b. DavelO. AM oATB9-1dh'J ❑ Service ❑ Stratigrephic Test ❑ 2. Operator Name: & Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 6/11/2019 175-077 • 318-194 & 319-147 3. Address: 7. Date Spudded 15, API Number P.O. Box 196612 Anchorage, AK 99519-6612 12/31/1975 50-029-20189-00-00 4a. Location of Well (Governmental Section): 8, Date TO Reached: 16. Well Name and Number. 1/28/1976 PBU 04-07 ' Surface: 90' FSL, 593' FEL, Sec.27, T11N, R15E, UM 9 Rat Elevations KB 51.00 17. Field/Pool(s): Top of Productive Interval. 1579' FNL, 1201' FEL, See. 34, T11N, R15E, UM GL 18.50 • BF Surface PRUDHOE BAY, PRUDHOE OIL Total Depth: 1759' FNL. 1448' FEL, Sec 34, Tl IN, RISE, UM 10. Plug Bad( Depth(MDr VD): 18. Property Designation: Surface / Surface ADL 028325 4b, 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number. Surface: x- 712235 • y- 5951946 Zone - ASP 4 • 9494'19036' 70-039 TPI: x- 711676 y- 5950260 Zone - ASP 4 12. SSSV Depth (MD/TVD): 40 Thickness of Permafrost MDrrVD: Total Depth: x- 711436 y- 5950073 Zone - ASP 4 None 1850'11850' 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21, Re-drill/Lateral Top Window Submit electronic and printed information per 20 AAC 25.050 MSL) WA (ft MSL) N/A 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma my, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary DIL, BHCS/GR, FDC, GR/ CCL, CBL/VOL, Gyro, GR/CNL/CCL 23. CASING, LINER AND CEMENTING RECORD GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM H40 33' 122' 33' 122' 32° 240 sx Andic Set MN -90 32' 2701' 32' 2701' 17-1/2" 3500 sx PF 11, 400 ax PF II FT-29# MN -e 0-95 30' 8342' 30' 8009' 12-1/4" 1000 sx Class'G', 125 sx PF I I 1a 80 8074' 9486' 7760' 9029' 8-1/2" 303 sx Claw'G' 24. Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes, list each interval open (MDrrVD of Top and Bottom; Perforation Size and Number, Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD/TV 5-1/2" 17# 13Cr80 8118' 8023'17713' x 4-1/2" 12.6# 13Cr80 A,t 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. D TE Was hydraulicfracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Dale Firs( Production: Not on Production Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested:'. Production for Test Penod y Oil -Bbl Gas -MCF: Water -Bbl: Choke,&Ve Gas -Oil Ratio Flow Tubing Press Casing Press: Calculated 24 Hour Rate �y Oil -Bbl: Gas -MCF. Water-9bl: Oil Gravity - API(com: Fomi 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMS�R4^'JUL 0 8 2019 ��� d IvIf ,/� 28. CORE DATA Conventional Cores) Yes ❑ No 0 Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed), Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 8877' 8500' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sadlerochit 8877' 8500' Base Sadlerochit -Kavik 9310' 8875' Formation at total depth: Kavik 9310' 8875' 31. List of Attachments: Summary of Daily Work, Suspended Inspection, Photo Documentation, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Laslufka, Joseph N Contact Name: Obngewitch, Beau Authorized Title: SIM S Mist Contact Email: BEAU.OBRIGEWITCH@bp.com Authorized Signature: e. �Contact Phone: +1 907 564 4854 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 All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are Conducted. Item 1a. 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 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations 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 15. 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 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. 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 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. 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 30. 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, Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only WELL NAME: 04-07 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 7962'- 7967' Tubing Punch 2390' 245 Bbls Class'G' 2250'-2260' Tubing & Casing Perforation 2095' Cut Tubing Surface 312 Bbls Class'G' Surface 145 Gal Arctic Set I Pulled well house, disconnected production and AL line with laterals (P&A). Transported 9/6/2018 production and AL line with laterals to wash bay for wash & toss. Staged well house on edge of pad. Tree platform left on well for access to valves. ***Job Complete*** 9/11/2018 Cost placehoder for foam balls for future P&A CTU #9 - 1.75" Coil x 0.156"wt Blue Coil Job Objective: Tubing Punch, Cement P&A MIRU CTU. MU & RIH w/ 2 7/8" GR/CCL carrier and 3.70" JSN drift nozzle. Tag TOC above Posiset plug @ 8988', begin swapping well over to KCL ....Job in Progress... 2/3/2019 2/3/2019 LRS Unit 72 - Assist Coiled Tubing: Heat Diesel Transport to 85*17 CTU #9 -1.75" Coil x 0.156"wt Blue Coil ***Continue from 2/3/19*** Job Objective: Tubing Punch, Cement P&A Log from 8200' up to 7700', paint WHITE & GREEN FLAG @ 7900'. POOH. Good data on log, +10' correction. MU & RIH w/ HES tubing punch. Punch 7962-7967', POOH. Make up WFT 1-trip retainer and RIH. Set at 7938' ME. Circ IA out w/ 1 % KCL, lead in with 70 bbls diesel, 70 bbls 9.8 brine, and begin pumping 15.8 ppg Class G cement. 2/4/2019 1 ...Job in Progress... CTU #9 - 1.75" Coil x 0.156"wt Blue Coil ***Continue from 2/4/19*** Job Objective: Tubing Punch, Cement P&A Complete Cement job with expect IA TOC at 2400' with 9.8 ppg brine from 2400-800' and then diesel from 800' to surface. Lost 28 bbls of cement into PC leak while circulating in. Unstung from retainer and laid in cement 1:1 in the tubing with a dressed cement top of 2400'. Tubing left with 9.8 brine from 2400-1200', and the surface FP with 1200' of diesel. Diesel circulated across parted tubing and out IA to ensure surface FP. Make up 3.5" JSN and jet tubing hanger, tree, and BOPS. Pump corrosion inhibitor and then blow down coil for pipe swap. 2/5/2019 (LRS Unit 70 - Pre-AOGCC CMIT-TxIA) Drive to location. Rig up to IA. Swab valve locked 2/12/2019 to wing valve. DSO unable to get key. Job Postponed T/1/0=13/17/170 CMIT TxIA (Pre AOGCC) CMIT TxIA PASSED To 2289/2314 psi (2500 Max, 2250 Target) Pumped 4 bbls Diesel down Tbg. to reach test pressure. Loss of 102/102 2/14/2019 psi 1st 15 min, Loss of 41/42 psi 2nd 15 Min. FWHP=0/0/171 SV,WV,SSV shut MV,IA,OA TWO = SSV/20/170. Temp = SI. WHPs (LTSI). Wellhouse, scaffold, and flowline disconnected. Unable to reach treecap. 2/26/2019 SSV = C. MV = O. IA, OA = OTG. 04:00 ***WELL S/I ON ARRIVAL*** (P&A) HES RELAY UNIT #46 STATE WITNESS CMIT-TxIA TO 2250 psi PASSED RAN 10'x 3-3/8" DUMMY GUN & 2.5" SAMPLE BAILER, TAG TOP OF CEMENT @ 2390' SLM, NO SAMPLE. TAGGED TOP OF CEMENT W/ 2.20" CENT & 1.75" SAMPLE BAILER Q 2390' SLM, SAMPLE RECOVERED. PERFORATED FROM 2250 - 2260' MD WITH BH HMX PERFORATING GUN, 7.9' CCL - TOP SHOT. CCL STOP @ 2242.1 '...GOOD COMMUNICATION WITH OA CUT TUBING WITH JET CUTTER 2095' MD 13.8' CCL - CUTTER. CCL STOP 2081.2' 3/17/2019 Daily Report of Well Operations 04-07 T/1/0=30/15/210 Temp=S/I (LRS Unit 70-Assist Digital Slickline: AOGCC CMIT-TxIA) Pre AOGCC CMIT-TxIA PASSED @ 2336/2358. Max applied=2500 psi. Target pressure= 2250 psi. Pressured up TBG/IA to 2475/2496 psi with 2.25 bbls diesel. 1st 15 min T/IA lost 96/96 psi. 2nd 15 min T/IA lost 43/42 for a total loss of 139/138 psi in 30 min. AOGCC CMIT-TxIA PASSED @ 2358/2381. Max applied=2500 psi. Target pressure= 2250 psi. Pressured up TBG/IA to 2480/2505 psi with 1.24 bbls diesel. 1st 15 min T/IA lost 87/87 psi. 2nd 15 min T/IA lost 35/37 for a total loss of 122/124 psi in 30 min. Bled back 1.2 bbls DSL. State witness: Lou Laubenstein Pumped 12 bbls DSL to confirm communication between TBG/IA/OA after perforation. SL in control of well upon departure. Hung tags on WV/IA AFE sign hung on MV ***FLUID 3/17/2019 PACKED WELL*** CV's OTG FWHP=50/50/313 T/I/O=SI/45/45 R/D existing IA valve on working side, installed integral and block valve. R/D blind, removed VR plug on non working side, installed integral and block valve, for upcoming 3/18/2019 cement job. FWP's SI/0/0 see log for details T/I/O = SSV/0/310. Temp = SI Bleed OAP to 0 psi (Pre Valve Shop). No AL, flowline, scaffold or well house. Rig scaffold installed. OA FL @ Near Surface. Bled OAP to BT from 310 psi to 0 psi in 1 hr (gas). Monitored for 30 min. OAP increased 8 psi. Bled back to O psi in <2 min. Held open bleed for 30 min. SI and monitored for 30 min. OAP increased to 2 psi. Bled OAP to 0 psi in <1 min and held open bleed. Monitored for 30 min. No increase in OAP. Final WHPs = SSV/0/0. 3/19/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:59 T/I/O=SSV/0/0. Pre Cement Squeeze. RD 3 1/8" CIW OA Valve and companion flange. RU integral flanges and block valves with 1502 caps on working and companion OA. Torqued to 3/20/2019 APIspecs. 401 FT/LBS.***JOB COMPLETE***. Se log for details. Final WHP's. SSV/0/0. T/l/O = SSV/vac/20 Temp = SI. FL & AL lines removed. No wellhouse. Job Scope: Cement Conrol & Balance lines to SSSV for Plug and Abandonment. Mixed 14.0 ppg SqueezeCrete and Injected 2 quart down Control Fine and pressured up to 2760 psi. perform passing 5 min test with 16 psi loss. Injected 1/2 gallon down the Balance line and pressured up to 3480 psi. performed passing 3/24/2019 5 min test with 10 psi loss. o red line required. ***Job Complete*** T/1/O=-13/-5/0 (LRS Unit 72 - Circ Out / Red Dye Test) Pump 5 bbls 60/40 down Txl, w/returns up OA, followed by 135 bbls 180* and 150 bbls 180* 9.8 brine. Soak for 1 hr. Pump 150 bbls 9.8 brine down Tbg/IA and out OA at max rate to flush arctic pack. Pump 154 bbls 180* surfactant down OA and up Tbg/FA. Pumped 10 bbls red dye down OA and up Tbg/IA. Flushed red dye w/ 121 bbls 9.8 brine at rate. Pumped 24 bbls 9.8 brine at 1 bpm while holding back pressure on Tbg/IA. 4/1/2019 ***Job Cont on 04-02-2019 WSR*** Daily Report of Well Operations 04-07 ***Job Cont from 04-01-2019 WSR*** (LRS Unit 72 - Circ Out / Red Dye Test) Continue to pump down the OA, up the TBG/IA 75 bbls (100 bbls total) 9.8 brine after red dye turned the corner at 1 bpm while holding 150 psi back pressure. Got red dye returns after 61 bbls and steadily increased darkness to 100 bbls. Pumped 5 bbls 9.8 brine down OA taking returns off IA only and got clean returns in 5 bbls. Pumped 144 bbls (300 bbls total) 9.8 brine down OA taking returns off Tbg only, got clean returns in 5 bbls off Tbg. Returns turned a dark pink. Pumped 25 bbls of 9.8 brine into the OA while taking IA returns. Returns were brown and then cleared up to a dark pink. Pumped 15 bbls of 60/40 Mach into the OA. U -Tubed TxIAxOA for 20 minutes. Freeze protected the surface equipment with 5 bbis of 60/40 Mach. All of the 1/4 turn valves and SSV are closed. MV is open. IA/OA CTG. DSO notifed of 4/2/2019 status upon departure. T/l/O = 50/50/60. Temp = SI. LTSI Wells. No wellhouse, AL or flowline. Drill scaffolding installed around wellhead. MV LTT = Passed. 4/4/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:30 T/1/0=0/0/0 (LRS -76 Assist SLB pumpers with cement) Rigged up to choke trailer. Pumped 8 bbls 60/40 to confirm flow path on surface lines and communication with TBGJA 4/21/2019 and OA. WSR continued on 04-22-2019. SLB Fullbore Pumping Crew Job Scope: Plug and Abandonment (surface TxlAxOA lateral Plug). Spot equipment, R/U, PT, wait on LRS and WSL to verify flowpaths. 4/21/2019 ***Continued on AWGRS 4/22/19*** ***Continued from AWGRS 4/21/19'** SLB Fullbore Pumping Crew Job Scope: Plug and Abandonment (surface TxIAxOA lateral Plug). Circulated the following down OA with T x IA returns to surface tank: 5 bbls freshwater. 312 bb s�15.8 PPG Class G Cement. *'"Job Complete*** Est. TOC in TBG x IA x OA @ 0' MD / 0' TVD 4/22/2019 Est. B Cin TB x x A 2,250' MD / 2 250' TVD **'WSR Continued from 04-21-2019*** Cement done. SSV would not close. MV closed per WSL Jerry Lau. Freeze protected and flushed all surface lines and dead legs to OT with 22 4/22/2019 bbls 60/40. ROMO. SLB in control of well upon LRS departure. T/1/0=0/0/0 Removed upper tree, installed tree cap bonnet on Master. Removed block valves from IA and OA, working and non working sides. installed caps with gauges. FWP's 5/13/2019 0/0/0 see log for details. T/I/O = SSV/0=/0=. Strap TOC (Pre wellhead cut). No wellhouse, flowline or AL. IA & OA previously bled. Removed 1502 caps and strapped the IA & OA cement at surface. Well 5/29/2019 condition left with SCE&R. T/I/O = SV/0/0. Temp = SI. AOGCC SU Inspection (Regulatory Compliance). State witnessed by Adam Earl. Pictures taken. 6/2/2019 SV = 9. IA, OA = OTG. 14:20 Cut & Remove Wellhead (P&A) Started cut @ 13:00 and completed @ 19:00. Cut wellhead t 66"below tundra grade. TBG IA & OA were fully cemented to the cut. Conductor by surface csg had 28" void to top of cement. 6/7/2019 '**Job In Progress*** Daily Report of Well Operations 04-07 Cut & Remove Wellhead (P&A). Completed Cement Top Job in conductor w/Arctic Set #1. Cement Inspected by AOGCC Matthew Herrera. Welded Marker Plate & inspected by AOGCC Matthew Herrera. Unable to remove shoring box & backfill due to weather. ***Job In Progress*** 6/11/2019 04-07 - P&A - Pulled Shoring Box & Backfilled excavtion hole with gravel (-120 yds), deliniated around excavation around hole footprint. 6/12/2019 —Job Complete** Suspended Well Inspection Report InspectNo: susAGE190618101436 Date Inspected: 6/2/2019 Inspector: Adam Earl Well Name: PRUDHOE BAY UNIT 04-07 Permit Number: 1750770 Suspension Approval: Sundry # 318-194 Suspension Date: 3/29/2016 Location Verified? 99 If Verified, How? Other (specify in comments) Offshore? ❑ Type of Inspection: Subsequent , Date AOGCC Notified: 6/1/2019 Operator: BP Exploration (Alaska) Inc. Operator Rep: Josh Prowant Wellbore Diagram Avail? O Photos Taken? ❑ Well Pressures (psi): Tubing: Fluid in Cellar? ❑ IA: BPV Installed? ❑ OA VR Plug(s) Installed? ❑ Wellhead Condition general area looked in good condition but work was ongoing to be permanently abandoned Condition of Cellar covered Surrounding Surface Condition work platforms, covering cellar area, lots going on Comments location verified by pad map Supervisor Comments Unnecessary call -out for inspection by BPXA r 0_(` 1 o Tuesday, August 13, 2019 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 04-07' Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1750770 API Number: 50-029-20189-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 3/29/2016 Surface Location: Section: 27 Twsp: 11N Range: 15E Nearest active pad or road: DS -04 Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: rad or location surface: Location cleanup needed: Pits condition: Surrounding area conditic Water/fluids on pad: Discoloration, Sheens on Samples taken: None xWO Access road condition: Good Photographs taken (# and description). Wellhead Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Clean Cellar description, condition, fluids: No Rat Hole: No Wellhouse or protective barriers: No Well identification sign: No Tubing Pressure (or casing if no tubing): N/A Annulus pressures: N/A Wellhead Photos taken (# and description): Yes Work Required: None Operator Rep (name and signature): Josh Prowant AOGCC Inspector: Adam Earl Otherbservers: Inspection Date: 6/2/2019 AOGCC Notice Date: 6/1/2019 Time of arrival: 12:00 AM Time of Departure: 12:00 AM Site access method: Access Road f i r_xj , r A ■ Q s TREE= MCEVOY WELLHEAD= FMC ACTUATOR= AXaSON KB. BA/ = 51' BF E -EV = SURFACE KOP= 4500' Mex Angie = 31' @ 9494' Datum MD= 9281' Datum WD= 88W SS 13-3/8' IG/ WIOA CMT 422/19) G & FC PUNCH, —� TPF (03/17/19) BG & A CMT 32/05/19) ""-J s414'- . D. D = 12.347—T--' TBG FULLY ABANDONED WELL IS CUT OFF 6'6" BELOW TUNDRA (06/07119) OF 7' LNR & CMT TBG, 12.69,13 -CR -80, ! bpf, ID = 3.958' IO/SOO-95, ID = 8.681' Minimum ID = 3.725" @ 8087' 4-1/2"PARKER SWN NO-GO NIP PERFORATION SUMMARY REF LOGBRCS ON 02/1652 ANGLE AT TOP PHiF: 31-@9066- 1"@9066'Note: Refer b Rroducbon OB for historical perf data Note: SIZE SPF INTERVAL OpNSgz DATE 3-318' 4 9066-9070 C 09/19/93 3-318' 4 9120-9130 C 03/09193 3-3/8' 4 9180-9190 C 05/16102 3-3/8' 4 9198-9226 C 05/16M 33/8' 4 9244 -9250 C 05/16/02 3318' 4 9318-9341 C 05/16/02 331W 4 9352-9369 C 05/16/02 9)=8.681" SAFETY NOTES: ""'USE EXTRBM E CAUTION WHEN ENTERING WELL.P & A TBG PARTED @ TBG HGR & FELL -10' OK CONTROL LINE BALLED O��O f UP AO -2 SLM.— B' - 18' 5.554' ISA LOCK X 4-1/2' TBG JT (DAL 18 2' GAS LFT MANDRELS ST MD I WD I DEV I TYPE VLV LATCH PORT DATE 1 3014 3014 1 G1-TGPD •DMY RK 0 63/16/16 2 5147 5114 24 CA-TGPD 'DMY RK 0 03/16/16 3 6340 6199 26 CA-TGPD "DMY TG 0 09/09/94 4 6928 6729 27 CA-TGPD "DMY TG 0 0222/92 5 7518 7254 26 CA-TGPD "DMY TG 0 0222/92 6 7851 7555 26 CA-TGPD 'DMY TG 0 0222/92 7 7924 7622 24 CA-TGPD "D" TGE 0 0222/92 'ALL STATIONS = COVERED BY CBA BFT I 8019' 119-5/8'X4-12'TWHBBPPMD=4.000' I F,rT, :: / m. r 15' 4-12' TUBING TAL, 1)=3.958' 9� EL D IT LOGGED 03101/92 MLLOUT WINDOW 9-518' @ 8342' - 8415' 7- LNR, 290,13 -CR, 0.0371 bpf, ID=6.184' DATE REV BY COMMENTS DATE REV BY COMMENTS 11115176 ORIGINAL COMPLETION 05/08/19 BO/AAD PBA 022292 SIDETRACK 06/11/19 BOIJMD FINAL APPROVAL TO PUBLISH 04/19/18 BO/JMD PRE -P&A t%MREI;TDNS 0625/19 JA/JMD FULLY ABANDONED 02/06/19 JWJMD CRC CMT & TBG PUNCH 0321/19 NXWUJ JET CUT TBG & TBGN1 PUNCH 05/02/19 JJUJMD TBG, IA, & OA CMT (0422179) 8884' 0 WITH H 1' OF 1-3/4' BG - 02104/93 PRUDHOE BAY UNIT WELL: 0407 PERMIT No: 1750770 AR No: 50-02920189-00 SED 27, T11 N, R1 5F 90' FSL & 593' FEL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �P�� �(IzDATE: 6/09/19 P. I. Supervisor / l FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector PBU 04-07 BPXA PTD 1750077; Sundry 319-147 6/09/19: 1 arrived on location and met up with Rob Liddelow with BPXA to inspect the cement and cut-off depth of the well casing after the wellhead had been removed. The pad is 6.2 ft deep from the top of the pad to ground level. The measurement from the bottom of the excavation to the top of the pad level was 13.4 ft'. The cut off casing is 2.2 ft tall at the bottom of the excavation. The casing cut was confirmed to be 5 ft below ground/tundra level. The cement in the conductor was 37.5 inches down from the top of the conductor. The rest of the casing strings were full to surface with cement. The tubing was almost completely full with just a small area that needed to be filled. I left location after instructing Mr. Liddelow to send in a request for witness to the AOGCC after they had completed the top job and were ready to weld on the identification plate. Attachments: Photos (4) 2019-0609_Surface Abandon PBU_04-07_gc.dox Page 1 of 3 I 1� 2019-0609—Surface Abandon _PBU_04-07_gc.dox Page 3 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg l�r� (, z ���I DATE: 6/10/19 P. I. Supervisor FROM: Matt Herrera SUBJECT: Surface Abandonment Petroleum Inspector PBU 04-07 BPXA PTD 1750077; Sundry 319-147 6/10/19: 1 traveled out to PBU 04-07 and met up with Company Rep Rob Liddelow. Previous inspection by AOGCC Inspector Guy Cook (6/9/2019) showed the well had a void in the surface casing by conductor annulus. Cement was used to fill the void before I arrived. Cement inside and around and outside of all casing strings was solid and showed correct cement top at surface. Depth of cutoff was previously determined as documented in Mr. Cook's report. I verified the marker plate information was correct and witnessed its installation. Attachments: Photo 2019-0610_Surface_Abandon_PBU_04-07 mb.dox Pagel of 2 Surface Abandonment — PBU 04-07 (PTD 1750770) Photos by AOGCC Inspector M. Herrera 6/10/2019 2019-0610_ Surface _Abandon _PBU_ 04-07_mh.dox Page 2 of 2 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Beau Obrigewitch Wells Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 04-07 Permit to Drill Number: 175-077 Sundry Number: 319-147 Dear Mr. Obrigewitch: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alcska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, DanieT Seamount, Jr. Confmissioner DATED thisZ2day of April, 2019. RBDMS.�-Ew APR 2 3 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25,280 MAR 2 6 2019 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ OperaAsh Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Pro grem Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4, Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number 175-077 3. Address: P.O. Box 196612 Anchorage, AK 6. 99519{i612 Stratigrephic ❑ Service ❑ API Number: 50-029-20189-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? H Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 04-07 9, Property Designation (Lease Number): 10. Field/Pools: ADL 028325 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total DepBr TVD(ft): Effective Depth MD: EffecBve Depth TVD: MPSP (psi): Plugs (MD): 2400, Junk (MD): 9494 9036 2400 2400 988,9016,9165,9278 9429 Casing Length Size MD TVD Buret Collapse Structural Conductor 89 20" 33-122 33-122 1530 470 Surface 2669 13-3/8" 32-2701 32-2701 5380 2670 Intermediate 1 8312 9-5/8" 30-8342 30-8009 6870 / 8150 4760/5080 Production Liner 1412 T 8074-9486 7760-9029 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grace: Tubing MD (ft): 1 None 5-1/2" 17# x 4-1/2" 12.8# 13Cr80 28-8118 Packers and SSSV Type: 4-1/2" TIW HBBP Packer Pacers and SSSV MD (ft) and TVD (ft): 6023 / 7712 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: April 15. 2019 15, Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Obrigewitch, Beau be deviated from without prior written approval. Contact Email: BEAU.OBRIGEWITCH@bp.com Authorized Name: Obrigewitch, Beau Contact Phone: +1 907 564 4854 Authorized Title: Well Integnty, Wgineer Authorized Signature: aill 4Z.11CDate: -31,Z& v 101 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness SundryNumber: (vAl Plug Integrity 11 BOP Test ❑ Mech(alnical Integrity Test El Location Clearance Q( \ 1 Other: l> ko �'O & 4O C- , vul S� r 3o..C-CC I o c-d-�t e.•�.� C { fl`+'O.' c e � G.� O+-C�-+� r Post Initial Injection MIT Req'd? Yes ❑ No ❑/ FiBDMS�� APR 2 3 2019 Spacing Exception Required? Yes El No 0 Subsequent Form Required: 10_407 � J� Approved by: f� COMMISSIONER COMMISSIONAPPROVED Date: Date: -1W4 a ��6gttk�tC\ ORIGINAL��, rw.gsavR� Form 10-403 Revised D4/2017 Approved application is valid for 12 months from the date of approval. � and Submit Form and Attachments in Duplicate 04-07 -Well Full Plug and Abandon Intervention Engineer Beau Obrigewitch (907) 564-4854 Production Engineer Bernhard Stechauner (907) 564-4594 Estimated Start Date September 15, 2018 History Greater Prudhoe Bay Well 04-07 was initially drilled and completed in 1976. There were two tubing swap RWOs and a Rig Sidetrack in 1992 is the current completion. Both the original and sidetrack were perforated into multiple zones and it was a producer for all its life. It produced approximately 1.1 MMbbl until being shut-in in 1997 for high water cut. It was made Not Operable in May 2015 due to IA repressurization. Responding to the IA repressurization, multiple attempts to secure the well by setting a mechanical plug in one of the Parker Nipples were unsuccessful due to failing pressure tests. In August 2015 a downhole camera showed the 5-'/" tubing had separated from the tubing hanger, leaving the top of the tubing — 10' downhole, and allowing direct Tubing x IA communication. Continued efforts to secure the well failed. A memory acoustic Leak Detect Log in December 2015 identified a Production Casing was landed in the backpressure va ve pro i e, with a 4-1/2" tubing tail extended into the top of the 5-1/2" tubing in March 2016 The well was Suspended under AOGCC Sundry 316-027 after setting a Posiset Plug at 9,016' and dumpbailing cement to 8,988' on 03/28/2016. Due to the known Production Casing leak and parted, tubing at surface, the plug and cement cap could not be tested. The current bottom -hole reserves being produced from this well have been accessed by another wellbore and the cost of repairing 04-07 !?y sidetracking and restoring the surface kit exceeds the cost of drilling a new well. Therefore, knog the ri s posed by the current conditions of this well the ✓ safest logical conclusion is to sus d it. I� Objective Place a cement plug from the packer to 2,400' in the IA and Tubing, cement the control and balance lines, and place a surface cement plug to —2,250' in the OA, IA and Tubing. Cut off all casings and wellhead —1' below pad level. The well will remain in suspended status until the final removal of the casings and welding of marker plate 3' below the original Tundra level. This wellwork is in conformance with eMOC 10439. Note: All text with a StFikethrough on the following pages is work that has been completed. Job Steps 4 G 2 € a. Drift and Tag TOG; Pressure Test as F;eeded; Requires AOGGG Witness NetifiGat'ei; b lei .. rt G 112" TL.. 3 € NS Pressure Test - 4 01. 6 d 9 S WOG 3 Days, PT GeRtFel and Balan 7 J a. Circ Arctic Pack and Surfactant wash OA, IA and Tbg b. Died Brine Injectivity Test down OA and up IA & Tb 8 J Surface Cement Plug OA, IA and Tb 9 J Cut off Wellhead; Install marker Plate; Requires AOGCC Witness Notification Procedural steps ■T_�iR.Ti 01. •_ • • _ oil EVE W -Wm •• •• ■ • _ MIR _ •• Revision 5: March 25, 2019 (BJO; Updated to full P&A: Cut wellhead 3' below original tundra and change status to Abandoned) Class G 16.8 ppq mixed on the fl m V. ' MCI Class G 16.8 ppq mixed on the fl m V. ' Revision 5: March 25, 2019 (13.10; Updated to full P&A: Cut wellhead 3' below original tundra and change status to Abandoned) 014D GFitprmg iR MITO Special Projects / Fullbore Note: In consideration of the Tubing x IA communication at surface, please rig up in a way such that the tubing, IA, and OA can all be accessed to both pump into and take returns from. 13. Clean Antic Pack out of OA; Surfactant wash OA, IA, and Tubing; Died brine injectivity test down OA and up IA and Tubing, per the following pump schedule: • Arctic Pack flush OA, pumping down tubing, taking returns from OA L 5 bbls methanol ii. 135 bbls 160°F heated diesel iii. 150 bbls 180°F heated 9.8 ppg brine (SD for one hour after —50 bbls of brine away to allow heated diesel to soak/break up Arctic Pack) — pump brine at max rate achievable once the soak period has passed. iv. 75 bbls of hot surfactant wash (180°F FW + 2 gal/mgal of F103 and 2 gal/mgal of U067) • Surfactant wash OA, IA, and Tubing L 75 bbls hot surfactant wash (180°F FW + 2 gal/m gal of F103 and 2 gal/m gal of U067) down OA, taking returns from IA and Tubing ii. 150 bbls 9.8 ppg brine down OA, taking returns from IA and Tubing • Died Brine Injectivity Test is pumped the same as the designed cement job, to test the potential that cement can be returned from the IA and Tubing very near the same time i. Pumping at 5 bpm, pump 10 bbls died, followed by 121 bbls clear 9.8 ppg brine down OA, taking returns from IA and Tubing. If mixing and dilution of the die is a concern, the died brine volume can be increased, but the total pumped at 5 bpm is 131 bbls. Revision 5: March 25, 2019 (BJO; Updated to full P&A: Cut wellhead 3' below original tundra and change status to Abandoned) 9 - - - - mw ... _., - i - IWIN 014D GFitprmg iR MITO Special Projects / Fullbore Note: In consideration of the Tubing x IA communication at surface, please rig up in a way such that the tubing, IA, and OA can all be accessed to both pump into and take returns from. 13. Clean Antic Pack out of OA; Surfactant wash OA, IA, and Tubing; Died brine injectivity test down OA and up IA and Tubing, per the following pump schedule: • Arctic Pack flush OA, pumping down tubing, taking returns from OA L 5 bbls methanol ii. 135 bbls 160°F heated diesel iii. 150 bbls 180°F heated 9.8 ppg brine (SD for one hour after —50 bbls of brine away to allow heated diesel to soak/break up Arctic Pack) — pump brine at max rate achievable once the soak period has passed. iv. 75 bbls of hot surfactant wash (180°F FW + 2 gal/mgal of F103 and 2 gal/mgal of U067) • Surfactant wash OA, IA, and Tubing L 75 bbls hot surfactant wash (180°F FW + 2 gal/m gal of F103 and 2 gal/m gal of U067) down OA, taking returns from IA and Tubing ii. 150 bbls 9.8 ppg brine down OA, taking returns from IA and Tubing • Died Brine Injectivity Test is pumped the same as the designed cement job, to test the potential that cement can be returned from the IA and Tubing very near the same time i. Pumping at 5 bpm, pump 10 bbls died, followed by 121 bbls clear 9.8 ppg brine down OA, taking returns from IA and Tubing. If mixing and dilution of the die is a concern, the died brine volume can be increased, but the total pumped at 5 bpm is 131 bbls. Revision 5: March 25, 2019 (BJO; Updated to full P&A: Cut wellhead 3' below original tundra and change status to Abandoned) 9 - - - - mw ... _., - i - 014D GFitprmg iR MITO Special Projects / Fullbore Note: In consideration of the Tubing x IA communication at surface, please rig up in a way such that the tubing, IA, and OA can all be accessed to both pump into and take returns from. 13. Clean Antic Pack out of OA; Surfactant wash OA, IA, and Tubing; Died brine injectivity test down OA and up IA and Tubing, per the following pump schedule: • Arctic Pack flush OA, pumping down tubing, taking returns from OA L 5 bbls methanol ii. 135 bbls 160°F heated diesel iii. 150 bbls 180°F heated 9.8 ppg brine (SD for one hour after —50 bbls of brine away to allow heated diesel to soak/break up Arctic Pack) — pump brine at max rate achievable once the soak period has passed. iv. 75 bbls of hot surfactant wash (180°F FW + 2 gal/mgal of F103 and 2 gal/mgal of U067) • Surfactant wash OA, IA, and Tubing L 75 bbls hot surfactant wash (180°F FW + 2 gal/m gal of F103 and 2 gal/m gal of U067) down OA, taking returns from IA and Tubing ii. 150 bbls 9.8 ppg brine down OA, taking returns from IA and Tubing • Died Brine Injectivity Test is pumped the same as the designed cement job, to test the potential that cement can be returned from the IA and Tubing very near the same time i. Pumping at 5 bpm, pump 10 bbls died, followed by 121 bbls clear 9.8 ppg brine down OA, taking returns from IA and Tubing. If mixing and dilution of the die is a concern, the died brine volume can be increased, but the total pumped at 5 bpm is 131 bbls. Revision 5: March 25, 2019 (BJO; Updated to full P&A: Cut wellhead 3' below original tundra and change status to Abandoned) ii. Reduce pump rate to 1 bpm, pump 151 bbis 9.8 ppg brine down OA, taking returns from IA and Tubing. If the IA and Tubing have equal/approximately equal flow rates, the died brine is expected to be at surface after a total of approximately 282 bbis are pumped. If it shows up early, it has "short circuted" either the Tubing or IA, and the program will be changed to address this. Hold Point: If the brine shows up early, do not proceed with pumping the cement. Contact Beau Obrigewitch at (907) 564-4854 (o) or (907) 952-6271 (c) for a plan forward. 14. Circulate cement down the OA and up the IA and Tubing, cementing all 3 strings from 2,250' to surface, per the following pump schedule: • 5 bbls freshwater spacer, taking returns from IA and Tubing • Pumping at 5 bpm, pump 131 bbls cement down OA, taking returns from IA and Tubing • Reduce pump rate to 1 bpm, pump remaining cement down OA, taking returns from IA and Tubing until —10 bbls clean cement is returned to surface • At WSL discretion, inject a small amout of N2 across the wellhead in an attempt to remove some cement, increasing the chance of opening the valves and providing a monitorable space to check for pressure prior to cutting the wellhead off. Note: With the Tubing x IA communication at surface, the intent of this cement procedure is to fill the IA and Tubing simultaneously through the perforations at 2,250'. Consider the possibility that cement will be returned from either the IA or the Tubing before the other. Keeping track of the cement volumes pumped vs. the cement fiilup volumes is critical. Contingency Considerations for IA and Tubing Fillup: I. Two cases were considered: a) Reducing pump rate down the OA once cement reaches perforations reduces annular friction losses in both the IA and Tubing, allowing them to fill up together. This is expected to occur after —282 bbls of cement pumped. If this happens, continue pumping the remaining 10 bbls of cement down the OA, taking returns from IA and Tubing, ensuring clean cement througout. b) Cement is returned to surface from the IA or Tubing before pumping 282 bbls of cement. In this case, it is unknown what path the cement has taken, and immediate action must be taken to retain access to the well. i. Cement to surface between 183 bbls and 273 bbis of cement pumped: 1. The assumption in this case is that the tubing has filled to surface and the IA has filled to within 200 feet of surface. ii. Cement to surface between 230 bbls and 277 bbls of cement pumped: 1. The assumption in this case is that the IA has filled to surface and the tubing has filled to within 200 feet of surface. II. Because it is not possible to know which string (IA or Tubing) the cement is returned from if it returns to surface between 183 bbls and 230 bbis pumped, the remediation action is the same: a) Swap to pump down tubing and take returns from the OA, shut in IA, and pump 52 bbis diesel down tubing, taking returns from the OA. This should ensure that the tubing cement is at or near the perforations at 2,250'. Cement Calculations — Cement Plua #2 (Fulibore OA. IA_ and Tubinal 13-3/8" x 9-5/8" volume from 2,250' MD to surface 0.0581 b 131 bbls 9-5/8" x 5-1/2" volume from 2,250' MD to surface 0.0438 b 99 bbls 5-1/2" volume from 2,250' MD to surface 0.0232 b 52 bbls Total Cement to Pum 10 bbls excess 292 bbls Revision 5: March 25, 2019 (13JO; Updated to full P&A: Cut wellhead 3' below original tundra and change status to Abandoned) Class G 15.8 ppg mixed on the fly Cement Type / Weight Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 800 to 110° F Revision 5: March 25, 2019 (13JO; Updated to full P&A: Cut wellhead 3' below original tundra and change status to Abandoned) Fluid Loss 40-200cc (20-100 cc/ 30 min) Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 4 hours Cement thickening time: Mix on the fiv Activity Time hours Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination 0 Safety 3 Minimum required thickening time: 6 Cement Ramp for Blend Time Volume Pumped bbls Temperature °F Pressure Si 0:00 0 100 0 0:30 135 90 1150 1:00 165 80 900 2:00 225 70 600 3:00 1 285 1 60 300 4:00 292 50 1 0 5:00 292 50 0 6:00 292 50 0 Special Projects 15. Cut off all tubulars and wellhead -I' belowpadat least 3' below original tundra level and top off cement in all tubulars. lastall Weld marker cap ort to outermost casing string. Provide a minimum of 24 hours notice to AOGCC Inspector of the timing of the cut. Photo document t e condition of the tubular stub immediately after cutting the wellhead, after topping off with cement (if necessary), and after installing the marker plate. a) Marker Plate to meet requirements in SOP: Through -Tubing Abandoment, Section 5.8 and 20 AAC 25.120: i. Minimum %" Thick ii. neo..;..,, rn IR" D- F:;meteF Does not extend beyond the outermost casing string Bead weld to the marker plate the following information: BP Exploration Alaska, Inc PTD: 175-0770 Well: PBU 04-07 API: 50-029-20189-00 Note: Revision 5 changes the program to a full P&A in accordance with 20 AAC 25.120 (marker plate) and 20 AAC 25.170 (3' below original tundra level). Revision 5: March 25, 2019 (BJO; Updated to full P&A: Cut wellhead 3' below original tundra and change status to Abandoned) TREE= MCEVOY W9IHEAD= FMC ACTIATOR= AXELSON KS. ELEV = 51' JET cuT'rBG BF. B -EV = 7 (03117/19) KOP=00' TBG & A RNC M4K Angie = 31'.0;04' (03/17119) Dab#n RV= 9281' TBG&KCmT DWvnTVD= aa00'SS 9180-9190 (02105119) 73-318' CSG, 72#, W&0. D- 12347' LNR D = 3.956' Minimum ID = 3.725" @ 8087' 442"PARKER SWN NO-GO NIP P9RFORATION SLAWRY Rff LOG SHCSONWJIB/92 ANGLEATTOPPERF: 31' @9068' Note : Refer to Production CB for hstoncal pert dela WE SPF INTERVAL OprdSW DATE 3-38' 4 9066 - 9070 C 0911993 3-3/8' 4 9120 - 9130 C 03,09199 3-318' 4 9180-9190 C 05/16!02 3-38• 4 9198-9226 C 0511802 3-3/8' 4 9244-9250 C 05116+02 3-W 4 9318-9341 C 05116102 3-318" 4 9352-9369 C 05116112 SAFETY NOTES: —OSE FXTNENE CAUTION WI@I FELL 04-07 BC OR CONTNTROLLNEBALLEDUP0 OO PARTED @ TOG �M.— ST MDIWDIOEVI 11Ma" OBGINAL COMPLETION 04/19/18 SOIJAD PREPGA CORREENONS TYLE VLV LATCH PORT DATE 1 3014 3014 1 CJ1-TGPD -DWJRKo 03116/16 2 5147 5114 24 GA-TOPD 'I7W03/16/16 3 8340 8199 26 CA-TC�FD 'DWDOOM 4 8928 8729 ZI CA-TGPD 'DW0222/625 7518 7251 28 CA-TGFD 'OW02221826 7851 7556 26 CA-TGPD '17WO/22192 7 7924 7622 20 CA -TOED -DNN0222/92 -ALL STATIONS = COVERED BY CHIN ENT 7953' H4V2• PARKER SWS NP, D=3813' 8115' I-i4-12•TUBNGTAL.D-3958• 8888'EMD TT LOGGED 03001/92 WLLOUT WINDOW 9- In D = 6.164' ELSTmm''. DATE REV BY I OckfANIS DATE I RBI BY OOMBdTS 11Ma" OBGINAL COMPLETION 04/19/18 SOIJAD PREPGA CORREENONS 0222/92 SIDETRACK 02/06119 JWJMD CRC CWr&TBG PUNCH 06115+01 RVP CORRECTIONS 0321119 JM1 JET CUT TOG &1BGIIA FLINCH 10115115 RYJAD ADM SAFETY NOTE 0311all 8 C A01D GLV 00 - TBG HGR - WBS EDITS 03/30/16 LACIAU SET PLCIG&C7ITCAP (327-28116 D=4000' D= 3.725' NOZZLE WITH 1.OF 1-314' OOL® TBG - 02RN83 PRIDHOE BAY fl8f NAL: 04-07 PEFW ND: 1750770 AR N1: 50-029-2018500 T11N Rt15E 90 FSL & 593' FEL SP Exploration (Alma ka) Revision 5: March 25, 2019 (BJO; Updated to full P&A: Cut wellhead 3' below original tundra and change status to Abandoned) TRW= LIIYOV V1BLFfAD= FIC ACRYIIOR= AX9.SON T03. E"= 51' BE FLLV- 7 low= 4500' Mn Argb- 3109491- DhhrnLD- 9281' DMUNTVD= 8800'Ss rt Tbg to - 2.250' Cut Tbg 100' in Tubing IA - 2,400' 1 A' - ') ftri'A' Packer - 7,998' 4-12' TBG, 12.. 13-C17.80, 8115 0.0152 hpf, 0=73 158' =E?�_Yti 04-07 Suspended Minknum ID = 3.726' @ 8087' PZ3 4-IW'PARKER SWN NO-GO NIP ,884' to TD FERRO ATION SU.MIARY Fill LOQ BFiS ON 02116182 ANGLE AT TOP Pte: 91.0 6OW NYA: Fifer Io Production DA for hWorr� pert data sim SPF Nn3TVAL Opn/W DATE 3-38• 4 9066 - 9070 c 09'19/93 3,347' 4 9120-9130 c 03709/63 3-7/8 4 9180-9190 c 05/18102 3-38• 4 9196-9226 c 05/18102 3-38• 4 9244 - 9250 c 05116m 3-38• 4 9318-9341 c 0511812 3-38• 4 9352-9369 c 0511802 D=9.681' 1 892' SAFETY NOTES: ••NEE EXTRENECAUIION VNBN ENT@eNO WELL. TBG PARTED ® TOO HOR 4 PELL -10' @L CONTROL LINE BALLED UP 0 -Y SLY.••• GAS LFT NANDRE-S T MD TVD f7(V TYPE VLV LATD4 PORT DATE 1 3014 3014 1 G-TGPD DA4Y R( 0 OY16116 2 5147 511{ 24 G-TTfD OAA' TM 0 03116176 3 6340F!991 M G-TGPD OW TG 0 09109194 4 T� 8729 27 G-TGPD MY TG 0 02//712 5 7518 7254 26 G-iDFo 0A4f TG 0 025/17192 6 7851 7555 26 G-TGPD OAA' TG 0 022202 7 7924 7622 24 G-TCYO DAB' TGE 0 02ZJ92 7963' 412'PARKF3N SVW FP D-3.813• Annular TOC est. @ - 6,547' 8019• 8-518•X4-ln•TBVFBBP R02 D=4.000• BOa7' 4-112• PARXT3NSW8 PP. D=3.817• —4 aloe 4-12• PARKER W M NO-GO Fp, D= 9.725 -� 8115 4-115/ TL8NC TAL,D=3.958' 8099' ELLO TT LOGGED 0110//92 kLLOur WN30W 9.5/8• a 8342 -8415 D - 6.184' DATE REV BY ODWANTS DATE 8437 BY COMMENTS 111m; ORKWAL COMPLETION 70/75x15 RYJkO ADDTDSAFTTY NOTE 022282 SDETMCK 03118x16 GMYO GLV d0 - TBG MR - WBS FDTTs 061501 RWTP coRlEanom 03Mx16 LA SET FLUG&CAR CAPt327-26716 05130108 DIM VWELLISADOORFwn6m 19MB BORMD PRI&FILACOF8BUTIOiS 0811602 CVWS ( STT � 0311508 FDIRic t^KE&LOCJLTIONCOTaB:RD F'r4Y•31 VWM V OF 1-314• PRLU DEBAY UFR WELL 04-07 {EENT No: 1750770 AN Nr 50-0252018900 BP Tiplora9nn (AFaskaj Revision 5: March 25, 2019 (BJO; Updated to full P&A: Cut wellhead 3' below original tundra and change status to Abandoned) 10,000,000 1,000,000 BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT 04-07 (175-077) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates LL V O N m 10,000 m _ t7 O w O MY f7 d LL o 1,000 u a v v m 100 0 O t F 10 1 Jan -1975 10,000,000 m d 1,000,000 N O O 100,000 am 3 O 3 w 10,000 S O 1 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 n Produced Gas (MCFM) . GOR Produced Water (BOPM)-- Produced Oil (BOPM) SPREADSH EET_Prod-I nject_Curves_W ell_V119_1750770_PBU_04-07_20190327.xIsx 3/27/2019 MEMORANDUM Founded on State of Alaska De th To MW Above Alaska Oil and Gas Conservation Commission TO: Jim Regg lel 0q(11 q (l1 8019 ft MD " DATE: March 18, 2019 6.9 ppg P.I. Supervisor 71 SUBJECT: Well Bore Plug & Abandonment PBU 04-07 - FROM: Lou Laubenstein BP Exploration Petroleum Inspector PTD 175-077; Sundry 318-194 Section: 27 Township: 11N Range: 15E - Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 9494 ft MD Lease No.: ADL 028325 Operator Rep: Gerald Boyles Suspend: P&A: yes - Casing/Tubing Data (depths are MD): Casing Removal: Conductor: 20" O.D. Shoe@ 122 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2701 Feet Csg Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 8342 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: 7 O.D. Shoe@9486 —Feet Csg Cut@ Feet Tubing: 5 1/2" x 4 1/2""O. D. Tail@ 8118 Feet Tbg Cut@ Feet Plugging Data: Test Data: Tvpe Pluq Founded on De th Btm De th To MW Above Verified Fullbore Retainer 8019 ft MD " 2390 ft MD_ 6.9 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2480 2393 2358 IA 2505 2418 2381 P OA 208 210 210 Remarks: On 3/18/09 1 witnessed a successful tag and pressure test on the cement plug for the P&A on well PBU 04-07. The tag was performed using slick line with a tool string having 600 Ib of weight and a bailer attached. I witnessed a sample of good solid cement after the tool was brought to surface. The pressure test of the plug was completed using a Little Red Service pump truck; this was a passing test. Attachments: none rev. 11-28-18 2019-0318_Plug_Verification_PBU_04-07_11 i *\���)j/j..4. THE STATE Alaska Oil and G!,as Lt.-,!,) ---- --‘1N� � Of/� T AsK /� Conservation Commission .f333 West Seventh Avenue 1, ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-372 �'� ^'"� Main: 907.279.11433 F ALAS Fax: 907.276.7p42 www.aogcc.alaska.gov Beau Obrigewitch 1. Well Integrity Engineer scow c w JUN 0 7'?ii,ti BP Exploration(Alaska), Inc. P.O Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 04-07 Permit to Drill Number: 175-077 Sundry Number: 318-194 Dear Mr. Obrigewitch: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, tAl&ct_ Hollis S. French 41 Chair DATED this'5 day of June,2018. RBDMS JUN 0 6 2018 VE, STATE OF ALASKA 1I • ALASKA OIL AND GAS CEAT APPLICATION FORONSSUNDRYRVION APPRCOM LS ION o 1 S 5/5/// / '2S 20 AAC 25.280 MA( fl 7 2018 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend p ' Perforate 0 Other Stimulate 0 Pull Tubing 0 Chang ro r Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other Additional Suspend II 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 175-077 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p 99519-6612 Stratigraphic 0 Service ID6. API Number 50-029-20189-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No p PBU 04-07 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028325 • PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9494 • 9036 • 8988 8596 8988,9016,9165,9278 9429 Casing Length Size MD ND Burst Collapse Structural Conductor 86 20" 33-122 33-122 1530 520 Surface 2670 13-3/8" 32-2701 32-2701 5380 2670 Intermediate 8312 9-5/8" / 30-8342 30-8009 6870/8150 4760/5080 Production Liner 1412 7" 8074-9486 7760-9029 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9066-9369 8664-8927 5-1/2"17#x 4-1/2"12.6# 13Cr80 28-8118 Packers and SSSV Type: 4-1/2"TIW HBBP Packer Packers and SSSV MD(ft)and ND(ft): 8023/7712 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary El Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory 0 Stratigraphic 0 Development p Service ❑'i: 14.Estimated Date for Commencing Operations: September,15,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended p ' 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Obrigewitch,Beau be deviated from without prior written approval. Contact Email: BEAU.OBRIGEWITCHl bp.com Authorized Name: Obrigewitch,Beau Contact Phone: +1 907 564 4854 Authorized Title: Well Integrity E gineer Authorized Signature: % '�' i4 4- Date: c>6 / 08/2o is COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3'Z ^ ^ Plug Integrity V BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: ' Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No Subsequent Form Required: /d — 17 d-7 APPROVED BYTHE / f c �,� Approved by: COMMISSIONER COMMISSION Date: b 7 V'T1 x///18 4`„s-36 AA fr RBDM JUN 0 6 2018 ORIGINAL 726 '-' ‘,,s7./t Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate bp • i 0 04-07 Reservoir Abandonment/ Surface Plug / Suspend Well Intervention Engineer Beau Obrigewitch (907) 564-4854 Production Engineer Bernhard Stechauner (907) 564-4594 Estimated Start Date September 15, 2018 History Greater Prudhoe Bay Well 04-07 was initially drilled and completed in 1976. There were two tubing swap RWOs and a Rig Sidetrack in 1992 is the current completion. Both the original and sidetrack were perforated into multiple zones and it was a producer for all its life. It produced approximately 1.1 MMbbl until being shut-in in 1997 for high water cut. It was made Not Operable in May 2015 due to IA repressurization. Responding to the IA repressurization, multiple attempts to secure the well by setting a mechanical plug in one of the Parker Nipples were unsuccessful due to failing pressure tests. In August 2015 a downhole camera showed the 5-W tubing had separated from the tubing hanger, leaving the top of the tubing - 10' downhole, and allowing direct Tubing x IA communication. Continued efforts to secure the well failed. A memory acoustic Leak Detect Log in December 2015 identified a Production Casing anomaly at 6,100' and a likely leak at 6, 983'. To provide future wellbore access, an integral ISA lock was landed in the backpressure valve profile, with a 4-1/2" tubing tail extended into the top of the 5-1/2" tubing in March 2016 The well was Suspended under AOGCC Sundry 316-027 after setting a Posiset Plug at 9,016' and dumpbailing cement to 8,988' on 03/28/2016. Due to the known Production Casing leak and parted tubing at surface, the plug and cement cap could not be tested. The current bottom-hole reserves being produced from this well have been accessed by another wellbore and the cost of repairing 04-07 by sidetracking and restoring the surface kit exceeds the cost of drilling a new well. Therefore, knowing the risks posed by the current conditions of this well the safest logical conclusion is to suspend it. Objective Place a cement plug from the packer to -2,400' in the IA and Tubing, cement the control and balance lines, and place a surface cement plug to -2,250' in the OA, IA and Tubing. Cut off all casings and wellhead -1' below pad level. The well will remain in suspended status until the final removal of the casings and welding of marker plate 3' below the original Tundra level. • • Job Steps 1 C Drift and Tag TOC; Circ Tbg; Tubing Punch; Cement IA and Tubing 2 E a. Drift and Tag TOC; Pressure Test as needed; Requires AOGCC Witness Notification b. Jet cut 5-1/2" Tbg c. Perforate 5-1/2" Tbg and 9-5/8" PC 3 F A/SL: Pressure Test 4 V Drop OA gate valve and install integral 5 0 Cement Control and Balance Lines 6 D WOC 3 Days, PT Control and Balance Lines 7 0 a. Circ Arctic Pack and Surfactant wash OA, IA and Tbg b. Died Brine Injectivity Test down OA and up IA & Tbg 8 0 Surface Cement Plug OA, IA and Tbg 9 SP Cut off Wellhead; Install marker Plate; Requires AOGCC Witness Notification Procedural steps Coiled Tubing 1. Rig up to drift and tag TOC @ 8,988' with nozzle (size at WSL discretion) and GR/CCL. GR/CCL log is needed for depth control during tubing punch. Circ tubing to 9.8 ppg brine. It is suspected that hydrocarbon fluids are present in the tubing from surface to the cement at 8,988'. An attempt to remove these fluids must be made. If unable to drift to cement or otherwise fail to circ out the tubing, call Beau Obrigewitch at (907) 564-4854 (o) or (907) 952-6271 (c) for a plan forward. Note: Even if the flowline is still connected to the well, it is blinded and unavailable for a flowpath. 2. Run 5' Tubing Puncher and punch across collar at 8,008' (top of first pup above packer). If there is concern of debris in the IA at this location, the tubing can be punched across the collar at 7,965' at WSL discretion. 3. Cement IA and Tubing as Follows: • Make up and run in with Weatherford One-Trip squeeze packer to -10' above tubing punch. Set packer. • Diesel and 9.8 ppg brine, pumped in volumes sufficient to freeze protect near surface (but not deeper than 1,200') and leave 9.8 ppg brine from the base of diesel to the top of cement. Diesel for surface freeze protect is at WSL discretion, depending on ambient temperatures. • 2 bbl freshwater spacer. It is understood the final location of this spacer is in the permafrost, but it is acceptable since it is low volume, and will likely be mixed into the brine as the cement is circulated into the IA. • Class G Cement as needed (-295 bbls) through tubing punch and up IA, taking and monitoring returns from the IA until the cement top in the IA is at 2,400'. • Unsting from packer and pump 90 bbls class G cement while pulling out of hole, laying cement in tubing to 2,400', taking one-for-one returns from the CT x Tubing annulus. • 5 bbl freshwater spacer • Diesel and 9.8 ppg brine, pumped in volumes sufficient to freeze protect near surface (but not deeper than 1,200') and leave 9.8 ppg brine from the base of diesel to the top of cement. Diesel for surface freeze protect is at WSL discretion, depending on ambient temperatures. 4. RDMO Coil. Note: These cement volumes are calculated from the desired tubing punch depth of 8,008', and desired TOC in IA and Tbg of 2,400'. The suspected PC Leak at -6,980' is likely to drink a few barrels, so have extra cement available to fill the IA as needed to 2,400'. It is important that the cement in both strings be sufficiently below 2,250' to allow placement of the surface cement plug from 2,250' to surface. 2 • • Cement Calculations - Cement Plug #1 (Deep Tubing/IA Plug) 9-5/8" x 4-1/2" volume from 8,008' MD to 3,002' MD (0.0535 bpf) 268 bbls 9-5/8" x 5-1/2" volume from 3,002' MD to 2,400' MD (0.0438 bpf) 27 bbls 4-1/2" volume from 8,008' MD to 3,002' MD (0.0152 bpf) 76 bbls 5-1/2" volume from 3,200' MD to 2,400' MD (0.0232 bpf) 14 bbls Total Cement to Pump (no excess) 393 bbls Cement Type/Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/-0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc (20-100 cc/30 min) Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 9 hours Cement thickening time: Mix on the fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 6 Cement contamination 1 Safety 2 Minimum required thickening time: 9 Cement Ramp for Blend Volume Pumped Temperature Pressure Time (bbls) (°F) (psi) 0:00 0 100 0 0:30 30 170 0:45 45 170 1:00 60 160 2:00 120 130 3:00 180 110 4:00 240 80 5:00 300 60 5:30* 330 40 6:00 360 6:30 390 7:00 393 8:00 393 9:00 393 *Note: At -330 bbl cement away, the IA cement will be in place. This is the cement design point, as the remaining cement mixed on the fly will be laid in the tubing. Eline & Fullbore 5. Drift and tag TOC with sample bailer. Notify AOGCC Inspector of the timing of the Cement plug tag and pressure test (24 hour minimum notice). 6. CMIT-TxIA (with diesel) to 2,500 psi. If fails, attempt to get LLR, RDMO. 7. Perforate through 5-1/2" Tubing and 9-5/8" PC into OA at 2,250' • Schlumberger to provide perf gun specifications 3 • i 8. Jet cut tubing at 2,100'. Note ISA Lock in tree is 3.833" ID, so a 4-1/2" Jet Cutter will be needed. • The intent of this step is to establish injectivity down the control and balance lines. Success has been achieved in the past by holding pressure on the Control and Balance Lines during the firing of the Jet Cutter. If the line(s) are severed, the pressure will drop, providing immediate evidence of success in cutting. Note: If the CMIT-TxIA fails, call Beau Obrigewitch at (907) 564-4854 (o) or (907) 952-6271 (c) for a plan forward. Valve Shop 9. Drop OA Gate Valve and install integral Valve. Special Projects 10. Injectivity test down control and balance lines with hydraulic oil. If there is no injectivity, there is no need to attempt to cement the lines. 11. Cement control and balance line w/ 1.2 gals of squeezecrete or finecem (1,300'). Reference small volume cement RP. If pump pressures allow (<5,000 psi), pump the entire line volume of cement (Lines are 1,060ft/gal; total displacement to 2,100' MD is 2 gallons per line). Note: The design of this program is to jet cut the control and balance lines at 2,100' to establish injectivity for cementing. As long as injectivity is attained, the depth will be unknown. For this reason, the full volume of 2 gallons of cement will be pumped into each line, provided pump pressure is not exceeded. DHD 12. Wait on cement 3 days and pressure test control and balance lines to 2,500 psi per Small Volume MIT criteria in MIT RP. Special Projects / Fullbore Note: In consideration of the Tubing x IA communication at surface, please rig up in a way such that the tubing, IA, and OA can all be accessed to both pump into and take returns from. 13. Clean Artic Pack out of OA; Surfactant wash OA, IA, and Tubing; Died brine injectivity test down OA and up IA and Tubing, per the following pump schedule: • Arctic Pack flush OA, pumping down tubing, taking returns from OA i. 5 bbls methanol ii. 135 bbls 160°F heated diesel iii. 150 bbls 180°F heated 9.8 ppg brine (SD for one hour after -50 bbls of brine away to allow heated diesel to soak/break up Arctic Pack) — pump brine at max rate achievable once the soak period has passed. iv. 75 bbls of hot surfactant wash (180°F FW + 2 gal/mgal of F103 and 2 gal/mgal of U067) • Surfactant wash OA, IA, and Tubing i. 75 bbls hot surfactant wash (180°F FW + 2 gal/m gal of F103 and 2 gal/m gal of U067) down OA, taking returns from IA and Tubing ii. 150 bbls 9.8 ppg brine down OA, taking returns from IA and Tubing • Died Brine Injectivity Test is pumped the same as the designed cement job, to test the potential that cement can be returned from the IA and Tubing very near the same time i. Pumping at 5 bpm, pump 10 bbls died, followed by 121 bbls clear 9.8 ppg brine down OA, taking returns from IA and Tubing. If mixing and dilution of the die is a concern, the died brine volume can be increased, but the total pumped at 5 bpm is 131 bbls. ii. Reduce pump rate to 1 bpm, pump 151 bbls 9.8 ppg brine down OA, taking returns from IA and Tubing. If the IA and Tubing have equal/approximately equal flow rates, the died brine is expected to be at surface after a total of approximately 282 bbls are pumped. If it shows up early, it has "short circuted" either the Tubing or IA, and the program will be changed to address this. 4 . • Hold Point: If the brine shows up early, do not proceed with pumping the cement. Contact Beau Obrigewitch at (907) 564-4854 (o) or (907) 952-6271 (c) for a plan forward. 14. Circulate cement down the OA and up the IA and Tubing, cementing all 3 strings from 2,250' to surface, per the following pump schedule: • 5 bbls freshwater spacer, taking returns from IA and Tubing • Pumping at 5 bpm, pump 131 bbls cement down OA, taking returns from IA and Tubing • Reduce pump rate to 1 bpm, pump remaining cement down OA, taking returns from IA and Tubing until —10 bbls clean cement is returned to surface Note: With the Tubing x IA communication at surface, the intent of this cement procedure is to fill the IA and Tubing simultaneously through the perforations at 2,250'. Consider the possibility that cement will be returned from either the IA or the Tubing before the other. Keeping track of the cement volumes pumped vs. the cement fillup volumes is critical. Contingency Considerations for IA and Tubing Fillup: I. Two cases were considered: a) Reducing pump rate down the OA once cement reaches perforations reduces annular friction losses in both the IA and Tubing, allowing them to fill up together. This is expected to occur after -282 bbls of cement pumped. If this happens, continue pumping the remaining 10 bbls of cement down the OA, taking returns from IA and Tubing, ensuring clean cement througout. b) Cement is returned to surface from the IA or Tubing before pumping 282 bbls of cement. In this case, it is unknown what path the cement has taken, and immediate action must be taken to retain access to the well. i. Cement to surface between 183 bbls and 273 bbls of cement pumped: 1. The assumption in this case is that the tubing has filled to surface and the IA has filled to within 200 feet of surface. ii. Cement to surface between 230 bbls and 277 bbls of cement pumped: 1. The assumption in this case is that the IA has filled to surface and the tubing has filled to within 200 feet of surface. II. Because it is not possible to know which string (IA or Tubing) the cement is returned from if it returns to surface between 183 bbls and 230 bbls pumped, the remediation action is the same: a) Swap to pump down tubing and take returns from the OA, shut in IA, and pump 52 bbls diesel down tubing, taking returns from the OA. This should ensure that the tubing cement is at or near the perforations at 2,250'. Cement Calculations —Cement Plug #2 (Fullbore OA, IA, and Tubing) 13-3/8" x 9-5/8" volume from 2,250' MD to surface (0.0581 bpf) 131 bbls 9-5/8" x 5-1/2" volume from 2,250' MD to surface (0.0438 bpf) 99 bbls 5-1/2" volume from 2,250' MD to surface (0.0232 bpf) 52 bbls Total Cement to Pump (10 bbls excess) 292 bbls Cement Type/Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/-0.1 ppg Slurry Temperature 80°to 110° F Fluid Loss 40-200cc (20-100 cc/30 min) Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 4 hours 5 • • Cement thickening time: Mix on the fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination 0 Safety 3 Minimum required thickening time: 6 Cement Ramp for Blend Volume Pumped Temperature Pressure Time (bbls) (°F) (psi) 0:00 0 100 0 0:30 135 90 1150 1:00 165 80 900 2:00 225 70 600 3:00 285 60 300 4:00 292 50 0 5:00 292 50 0 6:00 292 50 0 Special Projects 15. Cut off all tubulars and wellhead —1' below pad level and top off cement in all tubulars. Install marker cap on outermost casing string. Provide a minimum of 24 hours notice to AOGCC Inspector of the timing of the cut. Photo document the condition of the tubular stub immediately after cutting the wellhead, after topping off with cement (if necessary), and after installing the marker plate. • Marker Plate to meet requirements in SOP: Through-Tubing Abandoment, Section 5.8: i. Minimum %4" Thick ii. Minimum 18" Diameter • Bead weld to the marker plate the following information: BP Exploration Alaska, Inc PTD: 175-0770 Well: PBU 04-07 API: 50-029-20189-00 Note: The well will remain in suspended status until excavation, casing removal to 3' below original Tundra level, and marker plate welding occur at final pad remediation. 6 • • Pre Job Schematic: TREE= MCEVOY SAFETY NOTES:"'USE EXTREME CAUTION WHEN "ki_` `° PON ACTUATOR= AXELSON 0 4 0ENTERING ENTERING WEl L. TBG PARTED P.HGR FELL '10'l7Fi.CONTROL LINE BALLED UP k4-2`SUM."' KB REV= 51' BF.ELEV- 7 / 4-*------- 0'-18' J-/5.554'ISA LOCK X 4-1/2"TBG JT(©AL 18.2') KOP= 4500' Mex Angle• 31 r.,9494' 2203' H5-12"CAM BAL-O SSSV NP,ID=4.562' Datura 110. 9281' lj I 0 DirilunTVD= 8800'SS , 3007 5-1/2 X 4-1/2'XO,D=3.805" 113-318•CSG,721,M14-80,D=12-347• H 2701' GAS LFT 1•14I4)RELS ST k0 TVD DEV TYPE VLV LATCH R)RT DATE 111 5-1/2"TBG,Ill,1301,0.0232 bpf,D=4.892' 3002' 1 3014 3014 1 CA-TGPD OARI RJC 0 03x16116 TOP OF 4-1/2'TBG H 3007 2 5147 5114 24 C4-TG(4J DMI RK 0 03/16/16 3 6340 6199 26 CA-TGR) 01W TG 0 09109/94 4 6928 6729 27 CA-TGT DM' TG 0 02/22/92 Minimum ID =$.726" 8 87' 5 7518 7254 26 CA-TGR) WY TG 0 02/22/92 6 7851 7555 26 CA-TGPD MY TG 0 02/22/92 4-1/2"PARKER SWN NO-GO NIP 7 7924 7622 24 CA-TGR) DMY TGE 0 02/22/92. ' 7963' H4-12'PARKER SWS NP,D=3.813' I 8019' H9-5f8'X 4-112"TIW HBBP PKR,D=4.000' TOP OF 7-LNR H 8074' J . I 6087' —4-12'PARKER SWS NP,D=3.813- 8102' 4-1R'PARKER SWN NO-GO NP,D=3.725' 1 4-12'TBG,12.64,13-CR-80, 8115' I 8116' H4-1/2"TUBING TA L,ID=3,958' 1 0.0152bpf,ID=3.958' r 8098' —I ELIAD TT LOGGEEI03101192 9-5/8-CSG,47*,MIN-80/S00-95,D=8.681' ,- 8342' ,--. nMIL m10(0 W1IDW O 9-518-@ 8342'-8415' -898& HCMTCAP(0328/16) I '011 iris .114, .A1,1Iii• 9016' -T 5LB F SISET PLUG(0327/16) 1►11% -1.0��s/' 1414♦ y,"1� 4.1110 0P /0►1011 PERFORATIONStM4 R1 ♦111111 11NN1• 9166' —BP(05/t610z) REF LOG: BI-05 ON 02/16/92 41101►4 M11111• / 4004111 ANGLE AT TOP PERF. 31°Q 9066' 0•14.41. 1111014 Note.Refer to Production DS for historical pert data 111111!' SIZE SPP INTERVAL DATE i 11101044440041 9278' CMT CAPON SAND PLUG 4.0441 3-3/8' 4 9066-9070 �C� 09/19/93 11441141441444 �iis 3-3/8'" 4 9120-9130 C 03109193 J 1!1111111111!1 ��i�!" 0444144• ... 3-3/8' 4 9180-9190 C 05/16/02 1►10144 e.'� � MR WLM 3 1/2'CTU 11.111!• •w�f'�//// 3-3/8' 4 9198-9226 C 05116/02 111011! NOZZLE WITH 1'OF 1-314' .....1/445.111►!11 � 3-318" 4 9244-9250 C 05/16/02 ////// eft..1! oDFL@TBG-02I04193 3-343" 4 9318-9341 C 05116/ 2 111.111•.4 � % 3-3/8' 4 9352-9369 C 05/16/02 040400. 1100004 1111101 !1011.4 1104114 44411141110144 1111001 0110414. 011141-,14111!1 1:111`+11!1141 440441101 111• 1 !4.41014!1 r LNR,294,13-CR, — 9488' s11►4144414141 0.0371 bpi,D=6_184' 01111101440144 9-5/8"CSG,474,MPL80,D=8.681• -1 9373' DATE REV BY COMPANTS DATE REV BY COM U'1TS PRUDHOE BAY LUT 11115/76 ORIGINAL COMPLETION 10/15/15 P4JM) ADOI)SAFETYNOTE WELL: 04-07 02/22/92 SIDETRACK 03/18+16 CJMJM)GLV CJO-TBG HGR-WBS EEGS PERIM'No' 1750770 06/15/01 RCP CORFECTIDNS 03/30/16'LACJJM)SET PLUG&COAT CAP(327-28/16) API Ib: 50-029-20189-00 05/30/06 DTM WELL- AD CORFECTIONS SEC 27, T11N,R15E,90'FSL&593'FEL 05/16/02 C WS/KK SET BP 03/15/08 REIPJC NA1E S LOCATION CORFECTIONS BP Exploration(Alaska) . . %Q� �p 0 • Post Job Schematic: ti TREE= MCEVOY SAFETY NOTES:"'USE EXTREME CAUTION WHEN BLFEAD FSC A 04-07 Suspended ENTERING WELL TUG PARTED @ TUG HGR&FELL CIURTOR= A�SON Pert Tbg to -70'014.CONTROL LINE BALLED UP(d_?-2'SLM.`” Ia9,IE3�r_ 5f OA - 2,250' BF RA/ ? { Q'-18' ,-15.554"ISA LOCK X 4-1/2"MG 3T(OAL 18 2') KOP= Max Angles= 31 9494' � '' ' -» 2203' —15-1)2"CAM BAL-0SSSV NP,D=4.562' DWunMD= 9281' Jet Cut Tbg ,, oaalmlvo= eat"SS _ 2,100' 6...so■msIP k- GAS UFT MANDRELS TOC in Tubing ! r MD TVD DEV TYPE VLV LATCH FORT DATE and IA 2,400' ]l 3 3014 3014 1 CA-TGPD DRAY RK 0 03116/16 ` ' 2 5147 5114 24 CA-TGRD DAY RK 0 03/16/16 3 6340 6199 26 cA-TGPD DMY TG 0 09109194 Original OA Cmt 2,414' -2,653' 4 6928 6729 27 CA-TGFD DMY TG 0 02/22192 13-318'CSG,72*,MN-80,D=12.347' 2701' -- 5 7518 7254 26 CA-TGR) DMY TG 0 02/22/92 6 7851 7555 26 CA-TGPD DMY TG 0 02122/92 15-1/2"TBG,17a,13-CR,0.0232 bpf,ID=4.892- i1--16H 3002' t7 7924 7622 24 CA-TGPD DMY TGE 0 02/22/92, [TOP OF 4-1/2'TBG I-#.-....3002' •- . 7963' I—I4-1,.2•PARKER SVVS NIP,D-3.813" iJ Squeeze Packer -- 7,998' Annular TO. -- 6,547' Tubing Punch 8,008' sham 8019' H9-518'X4-112"TAN HBBPPKR,0=4.000' TOP OF 7-LM 8074' ' IV /� ii 8087' —4-112'PARKER SWS NIP,0=3.813' ' f > 7"Liner TOC a, 8,074' I 810 4-112'PARKER SWN NO-G0110..0-3 725' l L4-112"TBG,12-6#,13-GR-80, —{ 8115' ^- - ..„,, 8115' --I4-1/2”TUBINGTAt,0=3.958' l 0,0152 bpf,ID=3.958' o-'i 8096' -ELM TT LOGGED 03/01/92 3 19-5/W CSG 47*,1149-80/S00-95 ID 8.681" N 8342' D 1 % MLLOUT WINDOW 9-518'a 8342'-8415' 3.. J Minimum ID =3.725" @ 8087' cA 1 ( � CywtfCAP(03/28116)� n��' �`GS¢� 4-112"PARKER SWN NO-GO NIP -._ .,. .►► \ 4144►. .i+/s� tt c T 111 iii ail 9016' 7•SLB x�sr;F 1 r�Lx;(o3/z7n6) *►*0000►►►1 Y FERFORATION SUtvMARY 404►►►►►►►►►1 ►►►►►►►►►►4. N 9165' 0p(0511610'2) G' REF LOB-E ON02116192 001100 ' N►4#44 ANGLE AT TOP P 31"i§90613' 400044• Nate_Refer to Production DB for historical pert data 0004404000444. 4004041 \ 9278' —ICMTCAP ONSAND RLUG SIZE SPF INTERVAL 0pn/Sqz DATE 144444• #0444►► 3-3/8" 4 9066-9070 ' C 09/19/93 40►4►0►►►►444ii► 4►1444. deli" 3-318" 4 9120-9130 C 03/09/93 4►►4►►►►►►044 rlaNi ` 3-3/8' 4 9180-9190 C 06/16/02 0►0►040000►�. vf% RSH WLM 3 112'GTU 4 444►►11 NOZZLE VIATH 1'OF 1-3/4" 3 318' 4 9198 9226 C 05/6/02 0000►4 4►►►►44 3-318" 4 9244-9250 C 05/16102 0.1.0444@ G00. 78G-02104P93 3-318' d 9318-9341 C 05116102 41141010404 •.moi.- 3-3/8" 4 9352 9369 C 05/16102 444444444444. f 4044►►►►►►04 400000►►►►►4. 4►►►►►►►4#4. 41►4►4►►►►44 4000444. 44444►►44141 4;4;5;►�;1;► 7'LNR 29;4,13-CR, 9486' ►0►4►►►►►►1v 0.0371 bpf,ID-6.184' [9-5/8-CSG,47*,NIN-80,0=8 681' 1�X73• .4►4►►►►1►►144 DATE REV BY COMMENTS DATE i REV BY CONSENTS RRUCHOE BAY CHIT 11115/76 OF8GMEAL COMPLETION 10/15/15 FR'JISO ADO®SAFETY NDTE WTIL 04 07 02/22/92 SIDETRACK 03/18f16 CJN'Jh0 GLV C70-TBG HGR-WBS®FTS FERNT No 1750770 06/15/01 I8 9V CORFECT1ONS 03/30(16 LAC/.943 SET RUG&CWF CAP(3/27-28/16) ART N3' 50-029-20189 00 05130/06 DTM VYELLFEAD CORRECTIONS ;04/19118 BO/.M) PRE-P&A CORRECTIONS SEC 27, 111N,R15E,90'FSL&593'FU 05/16102 CWS/KK SET T3P 03/15)08 RC/PJC NOME&LOCATION C ORFITIDNS BP Exploration(Alaska) 8 STATE OF ALASKA y •ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATI�S 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other:Suspended Inspect Rpt m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 175-077 3. Address: P.O.Box 196612 Anchorage, Development II Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20189-00-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PBU 04-07 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED I1R`a�R�♦S E D Total Depth: measured 9494 feet Plugs measured See Attachment feet true vertical 9036 feet Junk measured 9429 feet SEP 2 2 2016 Effective Depth: measured 8988 feet Packer measured 8084 feet P� true vertical 8596 feet Packer true vertical 7769.05 feet >�q1..r�,C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 86 20"94#H-40 33-120 33-120 1530 520 Surface 2670 13-3/8"72#MN-80 32-2702 32-2702 5380 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1412 7"29#13Cr80 8077-9489 7762-9032 8160 7020 Perforation Depth: Measured depth: 9066-9070 feet feet 9120-9130 feet 9180-9184 feet 9184-9190 feet 9198-9226 feet 9244-9250 feet 9318-9341 feet 9352-9369 feet True vertical depth: 8664-8667 feet feet 8710-8719 feet 8762-8766 feet 8766-8771 feet 8778-8802 feet 8818-8823 feet 8882-8902 feet 8912-8927 feet Tubing(size,grade,measured and true vertical depth) See Attachment S,eq, ,.. WBai...,r.m—rtn.See•Afleehwnent Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): pNNE® 2t 1 Treatment descriptions including volumes used and final pressure: % � �c ' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 106 7217 15407 1622 367 Subsequent to operation: Susoended Well 14.Attachments:(required per 20 MC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development RI Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 2j Phone +1 907 564 4424 Date 9/21/16 Form 10-404 Revised 5/2015 rri f°/11)1C, RBDMS L" SEP 2 6 2016 Submit Original Only At /447.44 • • Plugs Attachment PBU 04-07 SW Name Date MD Description 04-07 03/28/2016 8988 Cement Cap on Posiset Plug 04-07 03/27/2016 9016 7"SLB Posiset Plug 04-07 05/16/2002 9165 7" IBP 04-07 02/04/1993 9278 Cement Cap on Sand Plug S Ca Q.000000000 la (NI N- CO CO CO N CO O CD In CO f- O N- CD N LC) LO p N d U V r- CO n ti U 0 0 0 0 0 0 0 0 0 co co 1` to N- CO 'Cr CO CO LO CO CO c- CO m c- tf) CO CO CO 00 N- CO 00 O N CO c-- N N U) O N to d' CO CO O CO O " N- M CO CA O C) CO N N I- CO O) CO I� H COLO N O to "CrCO CO CO O CO CO CO CO CO 1� N N O N N- I` M (1) O N CA LC) CO O U) N O to I,- CO O CO N- CO O1 CO O d- CV N 1� O) 0) CO CO a 1 1 1 4.1 Q O LO LC) CO N O to 100 00 O )14' c!) M C'M CVO O N N CO c 0 • W F— Q. O O O O CO 000 Z O o U J U a) OZ0co .N N 4 N N N 4 N CD 17Z2 ,' OD CA U 0 M in c N N O to L +' O0) COO N 1.- N CO N- N 00 CO c- 1�- CO x- C CO CO CO to Nt O c- J N N to r c- N LC) W W W Q Q Q N0ULIJ 000 U O a u Q f a Z Z Z zWWWWmmm ODi— rHz » D • • Packers and SSV's Attachment PBU 04-07 SW Name Type I MD TVD Depscription I04-07 TBG PACKER I 8022.02 7711.88 4-1/2"TIW HBBP Packer 04-07 PACKER 8084.05 7769.05 7" Liner Top Packer • •• Suspended)Well Site Inspection Form Initial inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT 04-07 Field/Pool: Prudhoe Bay I Prudhoe Oil Permit#(PTD): 175-077 API Number 50-029-20189-00-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended 3/29/2016 Surface Location: Section: 27 Twsp: 11N Range 15E Nearest active pad or road DS-04 Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good, clean Pad or location surface: graded gravel Location cleanup needed: None Pits condition: full of rain water, snow melt Surrounding area condition: clean, good Water/fluids on pad: rain water Discoloration, Sheens on pad, pits or water: none Samples taken: none Access road condition: good, gravel road Photographs taken(#and description). 3, well sign, well house, FLs/pits Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: FMC Gent, McEvoy tree,AL spool dropped/blinded, FL connected wing locked, all casing valves open to gauges, condition good Cellar description, condition, fluids: dry gravel Rat Hole: N/A Wellhouse or protective barriers. Yes.well house Well identification sign' Yes, correct Tubing Pressure(or casing if no tubing): 660 psi-tubing cut Annulus pressures: IA=660 psi OA=160 psi Wellhead Photos taken (#and description) 3, wellhead, tree, S Riser Work Required: None Operator Rep(name and signature): Ryan Hayes AOGCC Inspector: Bob Noble Other Observers Inspection Date: 8/21/2016 AOGCC Notice Date: 8/19/2016 Time of arrival: 14:05 Time of Departure: 14:15 Site access method: P/U Truck 0 • . § . . \ Igo iii ƒ 44C- 73 0 k ir- \ \ I . . §\ !§ qrj Cil .22 \ ^�� $ c �z\( V "- lei _ \ lij .w$ .0 / « 447 °sr a v \o %ff\\ ! . ti % ¥ 9 a %� � $� , a.} . ®$ sv \ 2 ' $ a / �\ \ �a 0 cn { \ g z c ~ "0 2 / - ;/ . . I ( ƒ = m . z = » -`---- 2 = £ _ > s \ / / f / « . �\ - \ ' ' - / \ \ CD ? { > ~ ? , / \ E ~ 2 \ S [ . / F. . .. . . „ . '..f'•.'.',• .,, .„. , .., • •' 1 I „. . t ,.., li „. .. „ . ,., ,:. .„. ..,. . ..,,. r .. . .. , .q. .... .1 . ,, . , . .., . _,........„,.„,;, _,. 7 4 74 4tit .• ,,. .g'„,04.'i,' :' „ ..,.. ..- ,... 11 , . , • I .. . .,.. ‘.. .„. \ ..,. ., .i.. ..„ . .. -,,, \. c...'4t,o' . ,•.:1",.* 1.41.,' ' ., it:41,•,., *..4.'"'''',I'''''',.'''''' `, 1:"'!'1,4''''.":::'''' 4 . ' -3 ,,,' :::%:: .,.,.,.,,,,i.,,,,, 4,i,,.,,i,:, il ..,,-.-..,,0•,-•.,:-i,'.''..*,•%s,...•,4#1,0...,,1„••r),.,.14-.!:.t0..t.",,--,-,:-"::: ,.,•,,,• ';'''‘. '-:,4.,4--'-'-',#:.., ,?r.•. , 1 r;.,.. - i f-7 I ' ''''•' '''''.%.ii''''... ,.'4'''' ' .Ili.,,.(,1'.''‘; . ' 'f.•• '''' '. ,!,',1.'.,,,,,,4,,,.. - '' ,,,,, .•'' i --..,', ,... .... . ......., - - . .....,,,, .., 710 T !..I..! ...;... s..: '.. .1,„.-,. .,,,.. ,,,,,. '',:i'•;;01 #Iff,'' ,.„, 4 • • :,":4 1: t,. -: ..... ,,•,"2/0. „..),1,4,,,•,#,, „:,•,•, ,, 14 1+11, •;••••• .,,,, ‘... • ..,....4.., ,-.7.,.:,..',,. .....,',...'0',r.'.......... ,': , . ..„,... , ..........„,.......; , . ....., .,.....,.... . . .. _ ,. ,,.....qw . . ,... .... , i ..., , -- . •-•,..i.'''.''''' '.'',.11., ‘,:'....,..,..4. , -4)Iiit -,..0„;.....:. ':„..!... ,..,,,,,' _ . ....... . ,,,„, Ni . , ...., ... . ,. . ' ,' ' .. . ..., .. , .. ..„„,.. „......" . ..._ „,,, ,...., ,... ..• , , .4,... ,„. ...„ , , , f...,. i 7 411Si .) • ty.kih,41 ••-•e'il . .., , . , • „01 . . .. s • . .... .,„ It ' i "I' 3 _ „ .R..T' .^`"fit a E t ,, t f l I f ViatAit) -i ', - " z. v° 1.: it.(, „ k ! 3, •, , < i r, ,..::.'1,...,:::::,-;..„,c„,',.:-, z^3 ai .", ,- c y r'• — k- . --'s ' .. ,* ... .,., , - „, „; 0,1 ' '-' -.., --J;. yy A :. Yom" 10110 41, • j fid'.'s' _. ` M44 `d w I k wt � w ' 4.s'k;r-,',' �' � ,, r^ I VVVIlkiiis‘t%, Illk NI, '''',,, • �*41i1r ',...+,,<,. .,, ,‘: .. M '7 gi: ittt‘i•,k'.,,\•..t ,.. 'r-- ,, fr :a } a r i ..,,, ..... .5. ,. - T 1.•-' 4. -'-'-' " - • 1' . ' '' .'1 ' . ' : ' ; : , ': ,i'''. -,c ,Cil; ' '' . ' , . I • . -; -'!'.*t r: ,I ! ' . •' r 1 , ,,- • ""4.,!!; „ 2.:,i', ' •---;.'t 1." , t ',-,'''' , I.. . ' - . i ' •!, ''' . i '.(' •:' ' P;.'.''•..ii!''''.,, ''' ' ,.7 i ' .. ."', . ' • .:1 ,, „1 ' .4 ' -, ', — , s, • , '.'• , ,' ' ',,....,:-:' ..1 -.*- ,,..„.7. , ,:-,%.... !' ,,.. •,-?...,,,,,c,,,- , -.:. ,., -, ,,,, .,„, , - :,t,..:.,. ,, r.i,-....,,,,,f- :,,, ,,,,,, „ . y. . ..., ,, , . ,,,. 1 .,...... ..,..,- ,....1..,5,1. .. ., , ....it..,,„.,,,,, ,,,..,...,01,, .,., .,5 .,... : ... ,........,,,, , .. , ., . ,.. . . . . , ,,.:, . , ; .„. .. _ . .,. ,., . . • ...... 1 - .„.,,....„.. , ..,..,,.. . . , 5 .. ., . . . . . . . . , • . . .,. ,, , ... ............_. . . ...,. :i' : /.1. ‘; ..,, r ... . it . . r, I- •• ' ' •I -II: •• - ' .: ' ' , . ' I r ,' , , • • , - , ,,„, • , - . . • i ' •• . . ...• •. . ” •. • . ' , .C. :"P'q':4... ' '.. ' '' •:. .. ' 4 -- ' ' t . • , . . • . • , • . , . . . ' I - f '•' : 1 • ' • ' t. - . • i•-i,' . . , . . . 5,,,, ...„ .... . 5, . _ . . , , . , , * • -. • ,,, . , . . .. , .. . . ,, • , • . t, ' 4 ,,,:•.6',F,. K• ,. !, ."°Y;t- ' I II . . • .. , ;!...,:! :‘,•'' ' - I •-.' ;:l‘ey-lii:•;';',--1,,,k1AtAlki,t .; - ' ' . . ' • 4... . . ,. . . .A.- . ,.:: .. .. . V';' ` .•;-••!, `-' 74*.t..);•*-",i,' ..-',.. ' . ' '''',- ',1*,--'t----t;;;;;431..- 1-„"cri,'.,••,/'5,',,;:l,‘1:' ' 4- ' 1.,:;•!):1-41 • v t. ..,•.; ' ", ..,:.,.4',.A....1f.,..t'..1,',1'.e.45..1.114),4;: '? ' ' , I: 1 • ': ":., ".,,h,t.=.1; •, ,,-,'. ' . , . , •, 0 _ .' --,F: .': ' . •' .': ,1i1,4.!, ,., ;.- i: ..4fli:)%:,:;-:,', .'''''.1)4,:l''''',1.:•?,i'-',ii,' :!'..-,,. ' 11.''',:f ' ''':,,: . ',.,-'. • -,',. ,.-,f -,,,,t1tit';,.,4-',1',44.,,,,tli-.1.',--,'-ci-1.-;.ir':,,,-,-.';'''1,t 41..41,%('.1,44',', '" , . ' ' -1.1_t• ,--,--:,;,i1,,,,,,i4Y3',,,...7,,,,f,„ji,„,,i 11,,A,)1,.,,i,-,,, .,..k..i.N,; ;. :;,!..41.,:" i....,..,..kz t':44114)1I4-°..9.10.:2;1,t- ;,•.';'',,i;i.1""r;;(.."i- .:"' { V.'.11,•4'.'f3,41•1';'':41;-!... ' ,,,r-,1 !.MHe•fl!.: . - -' , /.. : • '' c' -t''''I ,-.... ,',:,,,:'-;. ''',..;t, 1:•;,:t.,1,,,-„!•;;;• .4,!•-•!/-iitt,,f,!,fitki'i.1,41-, ,',...;'-itt'' ..(411.!;."4:7k.';iiif •AVI',-- .11',.: - ''''''' • • • • (:- t'I'' rit--1Xt-,:., .:,.1.,-t 41*..!-,-/1.1 ' -.- 2-1.*".'.e.'elf ','`Al.' ' ' . ,`,.' ,,* ,,e ,. t •,r , • - , - '',. ' ''.,'''' ... '•':-..41,34:ii‘.: 4,.,''',•-t*ritl'ili...'''All..,,,'..'.,D.4',,' 1.• :, ' °', 5 .- ,' ''..5',..'. ; <, : c . • .-: ° - ,:,° ,i;„ ';:',5 -ikf'"i,i,..;101ti,-..,,,4'ottiy,', 1',4' it.,*:,,4,iiztor•A;... ' . •'' ' ' .;;;.:••'-•t*.•4, .• `,;; ; • .' ' . 4' ' re- - •;•••-yiy,p..";,..t.,•••.;,,.;-..=;,. ,•:. °.!- r"..;!: e,. ,fp;-,,,•• • -.i •• ;-foii.,-.f'‘ .. -';' i ;;4.4•1'.'..r-1 t.T.ist"..1... ..•i.:-4',.-,,'-,1:.•t,i' ), '...; .1til.,5,,,,,1",e'-• . '' ';)V' •• t .1-r.;"5';°'!'e',;.:4 f:'-, .' ' •• . '; A '•,5 14 ' ..-5- 1144'-'-f:'‘0,4i6.11's:-;:t:itb =, i . ''',' ---'';. ,. . ,' ,, ', - 1 , , „r , - - , ,. • --....,' ,1 , , ,,,,,,,,. 0,.° , t.1,--t5,0 -..,..., por 5,,,,, .1.: ., , , ,k. • , . . : . ...t .. ,:‘•• 1 t Z,,. ' i''' ,..-'.'•:',,,:.1;t'.1•4'',s,' fz.'14,1:V•101`.A.,...05'-''., .',,.,..-4., ,; , , , : . . ...,...,;4:,.. 4, . . . ...,-,*,,i-•,,fo,,4,:;:-",,,,,‘, ;... yt.: ..(i' ' -..-.',.....,..4„ -,it.f...tiov/-7 ' . :kg.0..• 40 fr, ...„., ' ' ' i'-;k:-. .I.1., ,, , ,°•... ; :•1,::',)01,5, ., ,?..,#,:,: - 1 ',j''.11;' . • ' C J',•3•;'-';5:•-•1"...5...It'..''' 1;."1:5N f*:i... ,,,,;‘,4 ',-,..,::';,...t.i:k %,: '.;. ./i . t , ,'`.','.-."4 ''4'• • - °. .°- - . - - ,;-:.° i ;; 1, ''''-'•''''' ';,,,,,.,,-A," ,iltri',N5. '''',01,,'.' ` '. ';'„".,°.-'-:it.° ' ' (. • ', (4•, .• : 't ° ' . 5.15-;;,-, 1 • 1 ' 1 1 , — .° ,;4 •'• ' , ° ' ' • -I°' I ,,. ; ., ,.;s•";/ 5 °, ... i . i,..,'.1 .1/4...t I' ..5., 5.5.— ' "t„;°- . 5 .i'' !.';‘,. . ,,.c,...1°,'5.4,,..°0-J.;; 5;5.f.it,;"",i 4,f;V\ 4-4 •. .5'"*.•••.1.•tr''-; .:•1' : i v ''4.,"i. : 0':',M ''74':'''..3-'5')' i C.',..''f't 445;0 01 f' ,1'. .*.'.....15.'A . ' • • I . ? '- . S. -, ;',:•,'1•7'.'•t"..., t,10,"•.f'',.."'',Ii.".S' .; c • . 5. i 0 ' ••*5• 5'411,‘0.5j' •.•:,*'44;'' 4.:•;1'•47-'44.6,1 . . 4,11'• -,;,51.;°, itkii",* °I . ' ' •t . . . , ,.,. ; t •,...,f;4°.. ',01111f, ,.. , 4. S. ‘ ,' '•' . , , ; it,, ,,,`,1°./.'„,,5 0t ,.!: i,;1,°;,T It-.-1.,..1, '.?‘;11 . . , ° -,.' ''' 401 - • ..,,, " , ' if • ' '.''.';..i.114,'•. 5,' -...-•;*•11-,5, ' _ Ss L , ' ..,',":0,4-.• , „.5'7", 1 . . • '.. ; ,,......T• " •,1,•:.;..cl, t51';574•„,,„?4,4 't t "'•-- , • 5 =-4•1 I •5*,v.*cf.' C*4„fiti * '5,' , . ., . ,.....10c• '"' . 1 ca, i.0, 41117'i t... `,"0 •• '- : 5, — ' , Tk -w..• ,-..-•• ; 4 ,5.';—.?' , 4 ,.„.r,-- . ,,,,,. ,...,- ',, t ,. , it kr tr ; .. .----,4, ,. .,.., r - Aolimil , . , .. , . . ., , . . . i;''...4!If .,„ . • • .' •• , • . •. `,, . ., ' '. ,,, " • , • ,..., .., ,1,' :: . • ., , , ' .' - ik,, '.... .,,,,,; : . . . . , . i 1 ' t , . .,. !.,... ., , 1 , -i:f ,:.' ..-ii;',V.I‘,„ ,',0, _.•.' , , . ,, • ' , , '. :,,,,.,,,'..,,",-. , . .,' .,'' . ' . ,.'. '''',,'. . , .. , .. . . , . . . .. . , . . .. . , :,‘.• • , , . t' \ ' =`,''-'4.....,;,... r,-.,„,i.,‘. .,v,1,•-,.'?„, ' . ..' ' : .. '' I, > '.. • :.:', :','. .., ,'. • , ,.. • . . . . . . . . ,. - . i . . „. .. 11 II I' .. , . 4',,••. ,, , .,....),,,,,,,,..,..,,.:,:.,.:,;, .7,,,,,t.:.%,T;'.•..'3, :' . • , • „ '' . • • ,,,:,,:.,p Y4.;4- It , fl ''' I i -7•;;11, .1: : l• ••• ••-,',• ' • ..C.,-.01.,•' • ,•• :;',1c.••,',.• - , , , ,:,, . • . • ',',•• .. • ,,. ... • .,.., .l' •, ,••i pi' ig,!.„.!,,,I11:1..,;,'.,1,-; , ' ,, .. , ,. .,... . ,, ,,,, i : . ,,, ..,. , r ,, . ,. , . _., ., ., .1 Ic•- ' .,:4*.1.••• • ', 1 • . • '•• :' :1'''.. ': • , • • • • '''• • ' •. • •-::', : " ,„;..,..-• , ..:',.•,•1•,,:i..1,-: ,, , ' • • : . : , 1 . • .. • . 1 : : '.. .1 ' '. ' • — • .. ' ' ' ' 1 ' ; .1 : 1 , ' , ,•:,•,:0,,";f4:••',",.. ' ' • ,• • . ''' • . , • • , .• • . ••,, , • .•,. •:• ' :- ;,'„,...s., • • , ,-,• . . ' 1'. I 1', , ''111:''' ' ..:. : ' • ' •• ' •• • • : • 1 • ,. :, ':.• '':-': — ..' !.'... ...,.1. LI „. i i ' ' ' '. ' -.'‘,•.-.1,:- ' •: .,• . '' • ''' ' - i : .. •. ', .":, ,,, ',‘ . ,. .". - - - t ,,,,',.. i .-- • , , ,,,, ,. , , . . 1 . . , • , - .r .,., ... . . . . . ., . - •-",, .:„ 1,, . 1 ' ' ,:',-,•', .': ..,.'..••• •,,,`,,.' ''• ' ' ,. • • , ' :• .. . ' . ' :41' i II,- ' ri t ,1','/ : i:, '••• ' • '. ..,:' '-. •-•' * • • '• . '• ' ' ;, t., ,4". :: I': I. '1, t" -1 •!;,',-,•":1,, , ' ,.' ,• ,,' ': ,4 ',:, • "," •:',," ,I . ',,•,, , • 1' • • .. ,' • '7 t. n I -:..::,...' ' ,,,,... ,...,,..‘ .,, , ,... ...,...,.. ,-,...:.-., ....;-, 1" "- , •',,;,.••\ •.I , ' '•,'• •.; '• 1 ,1 t . , • •,, • • . • vv. $ It ,. , •I i „.1 l' 1 ., • .: •:;•••••••,' i• , ',••.:', : '';' ' ., • , '; • ,1 1 : • ' - • ': ' . j (i• '', . ' . . .., . 4', ' '. .' ‘,• ' • . ' .. 't s ', ,: . ''. . .'f*,',%.,..i',— .;. , . ;,, , 4. ' ,'''. '''' . ., 1 t• .. :, ,,: t,,. , , , . , 't ' --,- "' I , •, IllipPrk t ' ' ' ..,-.,- .,.....-..„. . ..._ ... . ,..... 4.+.--,..; ._ ..„ . . tj .. ,, ..i.' 01. 1,,.};•A'..;;;,,, ,V,Ag ; , '''',, c ; AAA".""; , ..,,,.;.:•'4‘"' ,., .' ' .•,sofiV1''''''''' /0"..",17-- , 1,, . , • r,..,, ,, •. \ 1 4 .....,, ..,. , . , ........•, , . . „. „.,...° \ ' - 1111 . , . , A ^ A A ...It . c . ,',,..,,','' -- \ , ......,i-, , II i e •' -,,. ''''''''' ,• . . i...''''''. ..'. „----i,•, 4 i ., I It ... , „.. . — -------,-- . . ii..4A lit' ..—: - , .. -,,--,-, . . • . -2, ',, ''''''' , ' ,, ' -• \ ,',, , 11..16 _ . : 11,11 4 f ' . i ',' ' ....; '--.1. '.. ,. .' 1 ........41,, \ ,.,,..11'' ,,,..., - +0.11111Flf • .,, 4,1•44.4- ''7,!, .4. .._ , • s . . , \ i `• . ° ''' ''' 4 it,..,,A,,,, , ''' 1*-"-- -- •- ' ''- 11” I,. II., . , ,,. •• .0., ... , . \ - ,,,',,,,,,Tot,-,,,,-,,„_.1„4,„-i , ,,.. „. ..°°IL --_,-,7.. .°..:°°°. -° °, . ' • q . 4 ,°0 .4 .. 11 „, .. :, '''itk- •''4' .4' . ---; - ' .; 4' • , ,....42 4.,:.. .74;;;VA; -'4111111ZIMI . . . .. .. ....41,14,4, .4.4 :„.,.. 4,44. ... ____ 1111 ,.....„-„.•_., '',... - . . „ , • , ., . . , ,••.,,. ,. •. .,• .. ... . . . , ....,,, . . . . ..4,.. • .....,,,,,,,,, -• ' 'l 4.1C^:,%riir'rr'Y • - -7,1i* i , ..,--..4.--. .41.4„,,,, (7 .l'ii.",;;14 Al " .., ,,..- , - ,.,... . „„..,.. , . ...,, .._- •' -.-.. ;;,..' ., . . .. 4 \\. , . '''' • rr,r, -_ , , . ., -.. „:;,..1....4.•,,,,S.,,,..0,,, -•,. - , - , . , ---• , ,• .• •1 , - •, • ••, • „, ,,,t ''I.N R4,,,°.4..,,,,:i0;;,,,,,:. .„ ,..„,s4,,,,, . ., .,* - '''N..'''''''''..; ''' '- siA, 's., *•- -',- . - ..„,,..:4:::;01- ''•,,,,V.. ,'„;,..S.-; . • - - . ''. .°N*°,..\,\W\EN,„\4,\*•.‘\:‘\\k`ki444".4.,\ * ' . ,•', ..; ' ' .f 6 ,, , :- ' ' i'444fik' il ,' .,\ . '''''' ' le'''''' - _ . .. - ; :.,..,,, irwor J' ♦ as r •r* ' 4 r �. .G ...,,...... . _ _______ ,,,_..._,__.. ._ ,. . - z o o — /` ox c:=, _17;7 o mz o (13 • '� Q O U.sr- O Q� "� ,Q�W S w 4 W r i Q 2 �Z� W O O Q Cn Q ..r..,,,;. h a 4 ..4. . . .. ,,_ .,frw Y'' '' at ' t`s^SMrpa az S r j 34 ," 'x. Or " 'g ' ` ,. r .+ 4. 4.kfix,' , s , a 4> *7P x *^ roti , P. wo � + TREE= M 1/OY i SA NOTES:"`USE EXTREME CAUTION WHEN = FMC ACTUATOR= 04-07 0 7 ENTERING WELL. TBG PARTED @ TBG HGR&FELL �1CFUATOR= AXELSON -10'OH.CONTROL LINE BALLED UP @-2'SUM.'"' KB.ELEV= 51' BF.ELEV= KOP= 4500' J -�( ---- 0'-18' 5.554'ISA LOCK X 4 " JT(OAL 18.2') —. -1/2TBG— Max Angle= 31 @9494' 2203' H 5-112"CAM BAL-O SSSV NP,D=4.562" Datum MD= 9281' L Datum TVD= 8800 SS , 3002' H5-1/2"X 4-1/2"XO,D=3.805" 13-3/8"CSG,72#,MN-80,D=12.347" -{ 2701' GAS LFT MANDRELS I ST MD TVD DEV TYPE VLV LATCH FORT DATE 5-1/2"TBG,17#,13-CR,0.0232 bpf,D=4.892" -I 3002' 1, © 1 3014 3014 1 CA-TGPD DMY RK 0 03/16/16 [TOP OF 4-1/2"TBG 1H3002` 2 5147 5114 24 CA-TGPD DMY RK 0 03/16/16 3 6340 6199 26 CA-TGR) DMY TG 0 09/09/94 4 6928 6729 27 CA-TGPD DMY TG 0 02/22/92 Minimum ID =3"725" @ 8087' 5 7518 7254 26 CA-TGR) MAY TG 0 02/22/92 6 7851 7555 26 CA-TGPD DMY TG 0 02/22/92 4-112"PARKER SWN NO-GO NIP 7 7924 7622 24 CA-TGFD DMY TGE 0 02/22/92 7953' H4-1/2"PARKER SWS NP,D=3.813" ><- 8019' H9-5/8"X 4-1/2"T1W HBBP PKR,0=4.000" TOP OF 7"LM H 8074' 1. Ci '- 8087' 4-112-PARKER SWSNIP,D=3.813" I ' 8102' H4-1/2"PARKER SWN NO-GO NP,0=3.725" 4-1/2'TBG,12.6#,13-CR-80, -{ 8115' / % we-1_14-yr TUBING TAIL,D=3.958' 0.0152 bpf,D=3.958' SQ98' H E LMD TT LOGGED 03/01/92 9-5/8'CSG,47#,MN-80/SO0-95,D=8.681" H 8342' MILOUT WINDOW 9-5/8'@ 8342'-8415' ' -8988' H CMT CAP(03/28/16) 1�1�11\ salook 1111 .ii�n�s , 9016' {7"SIB POSISEi PLUG(03!27/16) 1111♦ •:�iiyi 11111♦ -, 1111111111111 ��� Fff7FORATION SI)J,jaRY1111111111111 , 9165' IBP(05/16/02) REF LOG: BHCS ON 02/16/92 11111111111114 1111111 ANGLE AT TOP PERF: 31°@ 9066' 1111111 1111111 Note:Refer to Production DB for historical pert data 1111111 SIZE SPF EIfiT32VAL Opn/Sqz DATE 0111111111111� 9278' HCMT CAP ON SAND PLUG 1111111 3-3/8" 4 9066-9070 C 09/19/93 1111111'♦111111 ifori1N1111' (likfr nni�3-3/8" 4 9120-9130 C 03/09/93 1111111 rar 1111114' si 3-3/8" 4 9180-9190 C 05/16/02 1111111 •��� � 1111114' woo," , 9429° -FISH WLM 3 1/2"Citi 3-3/8" 4 9198-9226 C 05!16/02 1111111111111 NOZZLE WfTH V OF 1-3/4" 3-3/8" 4 9244-9250 C 05!16!02 1111111 ,1111111111114 COPED TBG-02/04!93 3-3/8" 4 9318-9341 C 05/16/02 ••11111. /%; �`� 3-3/8' 4 9352-9369 C 05/16/02 11111111111114 � 1.1.1.1.1.1.1• ,111111111111• 1111111111111 011111111111 11111111 1111111111111 1111111 1111111 11111111111111 7'LNR,29#,13-CR, --I 9486' 11111111111114 0.0371 bpf,D=6.184' 9-5/8"CSG,47#,MN-80,D=8,681' 9373' 0.4.4.4.4.4.4:4t DATE REV BY QTS DATE REV BY COMMENTS FRUDHOE BAY UNT 11/15/76 ORIGINAL COMPLETION 10/15/15 AVJMD ADDED SAFETY NOTE WELL: 04-07 02/22/92 SIDETRACK 03/18/16 CALM)GLV GO-TBG HGR-WBS EDITS PERMIT No: 1750770 06/15/01 RWTP CORRECTIONS 03/30/16 LAC/JM)SET PLUG&CMT CAP(3/27-28/16) API No: 50-029-20189-00 05/30/06 DTM WELLHEAD T1DNS SEC 27,T11 N,R15E,90'FSL&593'FEL 05/16/02 CWS/KK SET BP 03/15/08 RGPJC NAME&LOCATION CORRECTIONS BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/21/16 Inspector: Bob Noble Operator: BP Exploration Alaska Well Name: PBU 04-07 Oper.Rep: Ryan Hayes PTD No.: 1750770 Oper.Phone: (907)659-5766 Location Verified? Yes Oper.Email: If Verified,How? Other(specify in comments) - Onshore/Offshore: Onshore Suspension Date: 03/29/16 Date AOGCC Notified: 08/18/16 Sundry No.: 316-027 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 660 Photos Taken? Yes IA 660 OA 160 Condition of Wellhead: Tubing is cut so tubing and IA pressures track.Flowline is still in place.AL spool piece is removed.All are blinded with gauges installed.No signs of any leaks or spills in the well house.SSV was closed. Condition of Surrounding Surface Location: Well protected with the use of a wellhouse.Good clean gravel with no sign of spills.Correct wellhouse sign. - Follow Up Actions Needed: none Comments: Location was verified with a pad map. - Attachments: 4 Photos SCANNED o1 t n (t 61 REVIEWED BY: Insp.Supry J6!\ 10)2—llais Comm PLB 12/2015 2016-0821_Suspend_PBU_04-07_bn.xlsx • • Suspended Well Inspection—PBU 04-07 PTD 1750770 Photos by AOGCC Inspector B. Noble 8/21/2016 04- 07 A OWNER: PRUDHOE BAY UNIT OPERATOR: BP EXPLORATION (ALASKA) INC. API#: 50-029-20189-00*' Well sign SURFACE LOCATION: NE 1/4, SEC. 34, T11N, R15E PERMIT #: 1750770 • •+#' vial` : 4 Tubing-casing annulus flanged with } gauge • 2016-0821_Suspend_PBU_04-07_photos_bn.docx Page 1 of 2 II r r t �� ,A ;fr.,: a) cn alt � . . �. o '''''''Q' O v ti 4-1 o b 0 oO N 0 4. � O N aQ o iokq , p;14-,-rt.';''''' ' N N a: F ,_, ... .. • T { ..1...,..„,i, 1 ' �.. s d i.,- • � f rlit . ‘r,-.1,.. o , ., ., .- * . „... .. ...: ...._....F‘' I,.-.. is ..ru.� ,. iPA -vat f � �y ,. o . 1 ....-;.;;,..'17--.77::;:°.: 7 °w x'"" "TM's xSuaY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM.N 8 2016 WEL OMPLETION OR RECOMPLETION REPAND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG 0 Other ❑ Abandoned ❑ Suspended ❑ - 1b.Well Class: )GC's 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Zero - Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 3/29/2016 _ 175-077 - 316-027 3. Address: 7. Date Spudded: 75' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 12/31/1975 50-029-20189-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 1/28/1976 PBU 04-07 Surface: 90'FSL,593'FEL,Sec.27,T11N,R15E,UM + 9 KB Ref Elevations 17. Field/Pool(s): 51 Top of Productive Interval: 1579'FNL,1201'FEL,Sec.34,T11N,R15E,UM GL 18.5 BF 18.71 PRUDHOE BAY,PRUDHOE OIL - Total Depth: 1759'FNL,1448'FEL,Sec.34,T11N,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 8992'/8600' ADL 028325 - 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 712235 - y- 5951946 - Zone - ASP 4 - 9494'/9036' - 70-039 TPI: x- 711676 y- 5950260 Zone - ASP 4 12. SSSV Depth(MD/TVD): PO Thickness of Permafrost MDTTVD: Total Depth:x- 711436 y- 5950073 Zone - ASP 4 None 1850'/1850' 5. Directional or Inclination Survey: Yes 0 (attached) No t1 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary DIL,BHCS/GR,FDC,GR/CCL,CBL/VD,Gyro,GR/CNL/CCL 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT FT. CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 94# H-40 33' 122' 33' 122' 32" 240 sx AS 13-3/8" 72# MN-80 32' 2701' 32' 2701' 17-1/2" 3500 sx PF II,400 sx PF II 9-5/8" 47# MN-80 30' s 8335' 30' 8003' 12-1/4" 1000 sx Class'G',125 sx PF II 7" P9# 13Cr80 8074' 9486 7760' 9029' 8-1/2" 303 sx Class'G' 24. Open to production or injection? Yes ❑ No IZI 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 5-1/2"17#x 8118' 8023'/7712' 4-1/2"12.6#13Cr80 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. SCANNED 4NED JUN 2 2016 Was hydraulic fracturing used during completion? Yes ❑ No El �,/���7�r 4 U Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 9016' Set Posiset Plug 8992' 38.7 Gallons Cement 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period 1 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate �T Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only i RBDMS 0- APR 1 1 2016 s �' /�. 28. , CORE DATA • Conventional Core(s) Yes LI No 2 •• Sidewall Cores Yes ❑ No Q • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes ❑ No RI Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 8877' 8500' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit 8877' 8500' Base of Sadlerochit 9310' 8875' Formation at total depth: 31. List of Attachments: Summary of Daily Work,Well Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bronga,Jaime Email: Jaime.Bronga@bp.com Printed Name: Joe Lastufka Title: Drilling Technologist r 1VSignature: )\\Jt11 �.� Phone: +1 9075644091 Date:JJ 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. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item is. 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 lb.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations 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 15.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 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.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 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.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 30.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. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • 04-07 Well History . TIVITYDATE �"!`''!tviy' ,.a T/I/O = 250/280/180. N/D tree cap assembly. N/U 6-3/8"x 7-1/16" P-Sub. N/U 20' Spool w/ASV#27 &temp#22. Change out w/night BPV crew. See log for details. ***Job In 3/14/2016 Progress*** FWHP's =SI/280/180. T/I/O= SI/290/180 Relieved Day shift; Installed 4 30' chains to top of Doniker/riser& bound them down to top of Well House corner picking eyes, Torqued P-Sub, ASV, Crown valve to Tree &to Doniker/riser to API Spec..; PT 300 psi-low& 5000 psi-high (passed); 3/14/2016 FWP=SI/290/180 RDMO ***See Log for details***Job complete*** ***WELL S/I ON ARRIVAL***(Plug &abandon) TAG BPV PROFILE AT 0' SLM W/5.10" CENTRALIZER(Flagged wire). SET MODIFIED 5.554" ISA LOCK(Min id = 3.833"), 4-1/2"x 15'TUBING W/MULE SHOE IN BPV PROFILE. SET 4-1/2"WHIDDON CATCHER SUB AT 8,076' SLM /8,102' MD. CURRENTLY RIH W/4-1/2" OM-1, 1-5/8"JDS TO PULL TG-OGLV FROM ST#2 (5,147' MD). 3/15/2016 ***JOB IN PROGRESS, CONTINUED ON 3/16/16 WSR*** ***CONTINUED FROM 3/15/16 WSR***(Plug &abandon) PULL TG-OGLV FROM ST#2 (5,147' MD) &TG-LGLV FROM ST#1 (3,014' MD). SET RK-DGLV'S AT ST#1 (3,014' MD) &ST#2 (5,147' MD). PULL EMPTY 4-1/2"WHIDDON CATCHER SUB FROM 8,076' SLM/8,102' MD. TAG BAKER IBP AT 9,133' SLM (9,165' MD)W/3.50" BARBELL(No issues). ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** MODIFIED ISA LOCK (Min id = 3.833"), 4-1/2"x 15'TUBING W/MULE SHOE LEFT IN 3/16/2016 BPV PROFILE. T/I/0=1400/500/200. R/D Temp. ASV#27, HWO Temp#22, 20' Riser, and P-sub. Installed 3/21/2016 tree cap bonnet. FWP's 1400/500/200 see log for details. T/I/O = 480/480/150. Temp =SI. TBG & IA FL (Eline request)AL spool dropped. TBG FL @ 600' (14 bbls). IA FL @ 680' (30 bbls). 3/25/2016 SV, SSV =C. WV = LOTO. MV= 0. IA, OA = OTG. 16:30 ***WELL SI ON ARRIVAL.***(ELINE JEWELRY LOG/PLUG/CEMENT DUMP) PAD OP CONTACTED ON ARRIVAL. T/I/O = 600/480/260 RIGGING UP. 3/26/2016 ***JOB IN PROGRESS. CONTINUED ON 3/27/2016*** ***JOB CONTINUED FROM 26-MARCH-2016***(ELINE JEWELRY LOG / POSI PLUG/ DUMP CEMENT) JEWELRY LOG RUN: LOGGED PASS FROM 9143'TO 7766' PLUG RUN: RIH WITH HEAD/CCL/MPBT WITH PLUG. CCL TO TE = 23.33/CCL STOP DEPTH = 8992.51 /TOP OF POSISET PLUG @ 9016'; SURFACE CONFIRMATION OF PLUG SET. CEMENT RUN 1: RIH WITH HEAD/CCL/ DUMP BAILER, TAG PLUG @ 9016'. DUMPED 4.8 GAL CEMENT. TOC @ 9012.9' CEMENT RUN 2: RIH WITH HEAD/CCL/ DUMP BAILER. DUMPED 4.8 GAL CEMENT. TOC © 9009.8' BEGIN RIH WITH CEMENT RUN 3 ALL LOGS CORRELATED TO CAMCO JEWELRY LOG DATED 01-MAR-92 3/27/2016 ***JOB CONTINUED 28-MARCH-2016*** • 110 04-07 Well History ***CONTINUED FROM 3-27-2016 WSR***(JEWELRY LOG/ POSI PLUG/CEMENT DUMP) CEMENT RUN 3: RIH WITH 4.8 GAL CEMENT/3.1'. TOC © 9006.7' CEMENT RUN 4: RIH WITH HEAD/CCL/ DUMP BAILER. DUMPED 4.8 GAL CEMENT. TOC @ 9003.6' CEMENT RUN 5: RIH WITH HEAD/CCL/ DUMP BAILER. DUMPED 4.8 GAL CEMENT. TOC © 9000.5' CEMENT RUN 6: RIH WITH HEAD/CCL/ DUMP BAILER. DUMPED 4.8 GAL CEMENT. TOC @ 8997.4' CEMENT RUN 7: RIH WITH HEAD/CCL/DUMP BAILER. DUMPED 4.8 GAL CEMENT. TOC @ 8994.3' CEMENT RUN 8: RIH WITH HEAD/CCL/ DUMP BAILER. DUMPED 4.8 GAL CEMENT. TOC @ 8991.2' CEMENT RUN 9: RIH WITH HEAD/CCL/DUMP BAILER. DUMPED 4.8 GAL CEMENT. TOC @ 8988.1' *38.7 GALLONS CEMENT TOTAL* RDMO 3/28/2016 FINAL T/I/O =400/480/260 PSI ***WELL S/I ON ARRIVAL*** (D&T) TAGGED TOC @ 8,975' SLM + 7' CORR=8982' ELMD w/2.25" CENT& 1.75"S-BLR. 3/29/2016 ***JOB COMPLETE, WELL LEFT S/I*** ***WELL S/I ON ARRIVAL***(D&T) TAGGED TOC @ 8,975' SLM w/2.25"CENT& 1.75" S-BLR. 3/29/2016 ***JOB COMPLETE, WELL LEFT S/I*** TREE_ , MCEV OY • W3LHEAD- Rot SA4110 NOTES:"*USE EXTREME CAUTION WHEN ENTERING WELL. PARTED @ TBG GR& FELL ACTUATOR= AXELSON 04-07 -10'DH.CONTROL LINE BALLED UP@ N2'SM.'" KB.ELEV= 51' O ELEV= K / ----,----,BOP= 4500'' 0'-18' -15.554"ISA LOCK x a-vz"TBG JT(OAL 18-2') Max Angle= 31 @ 9494' 2203• H5-1/2'CAM BAL-O SSSV NP,D=4,562" Datum MD= 9281' 1 0 Datum TVD= 8800 SS 3002' —5-1/2"X 4-1/2"XO,D=3.805" 13-3/8"CSG,72#,MN-80,D=12.347' H 2701' ! CAS UFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5-112"TBG, 17#, 13 C F�0.0232 bpf,D=4.892" H 3002' 1 3014 3014 1 CA-TGPD DMY RK 0 03/16/16 [TOP 1/2 TBG I J� 3002 ® 2 5147 5114 24 CA-TGPD DMY RK 0 03/16/16 --_------_-- 3 6340 6199 26 CA-TGPD DMY TG 0 09/09/94 4 6928 6729 27 CA-TGPD DMY TG 0 02/22/92 5 7518 7254 26 CA-TGPD DMY TG 0 02/22/92 Minimum ID =3.725" ( 8087' 6 7851 7555 26 CA-TGF) DMY TG 0 02/22/92 4-112"PARKER SWN NO-GO NIP 7 7924 7622 24 CA-TGPD DMY TGE 0 02/22/92 I I 7953' 4-1/2"PARKER SWS NIP,D=3.813" >< >< 8019' H9-5/8"X 4-1/2"11W HBBP PKR,D=4.000" TOP OF 7"LNR H 8074' • t o I ' r 8087' —14-1/2"PARKER SVVS NP,D=3.813" { 8102' —14-1/2"PARKER SWN NO-GO TAP,D=3.725" 4-1/2"TBG,12.6#,13-CR-80, — 8115' / \ 8115 '—F-1/2"TUBING TAIL,D=3.958" 0.0152 bpf,D=3.958' 8098' —{EUu1D TT LOGGED 03/01/92 9-5/8'CSG 47#,MPl-80/SOO-95,10=8.681" li_ 8342' 1 11 MLLOUT WINDOW 9-5/8"@ 8342'-8415' —8988' ---1CMT CAP(03/28/16) .�1�11` ,i:i, N11 ,doom. 9016' —7"SLB PosISEr PLUG(03/27/16) '1111♦ viii •111111 tiv 111111 PERFORATION SUMMARY 11111111111111, 9165' IHIBP(05/16/02) B REF LOGH(S ON 02/16/92 0 . 1111111111111 t '1111111 Se ANGLE AT TOP PERF: 31°@ 9066' 1111111'1111111 Note:Refer to Production DB for historical rf data 1111111' 11111111111111 ` 9278' i1 CAPON SA O PLUG SIZE SPF MHRVAL Opn/Sgz DATE ...... , 3 318" 4 9066-9070 C 09/19/93 111111111/111 .�1111111. n.13-3/8" 4 9120-9130 C 03/09/93 '1111111 /// 11111.1 3-3/8" 4 9180-9190 C 05/16/02 11111111111111 g�ii� , 9429' —FISH WLM 3-112"CTU 3-3/8" 4 9198-9226 C 05/16/02 11111111111111 ir," NOZZLE WITH 1'OF 1-3/4" 3-3/8" 4 9244-9250 C 05/16/02 1111111111111 COILED TBG-02/04/93 '1111111 „ 3-3/8" 4 9318-9341 C 05/16/02 .1111111111111 3-3/8" 4 9352-9369 C 05/16/02 X1111111111114 1111111 '1111111• 1111111 '1111111 1111111' '1111111 N11111' 11111111111111 1111111111111 '1111111 1111111' 11111111111111 7"LNR,29#,13-CR, H 9486' 111111111111 0.0371 bpf,ID=6.184" 9-5/8"CSG,47#,MN-80,D=8.681" 9373' 11111111111111 DATE REV BY_ COP W4TS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/15/76 ORIGINAL COMPLETION 10/15/15 PF/JMD ADDED SAFETY NOTE WELL: 04-07 02/22/92 SIDETRACK 03/18/16 CJNVJMD GLV C/O-TBG HGR-WBS EDITS PERMIT No: 1750770 06/15/01 RP CORRECTIONS ^ N/T03/30/16 LAC/JM)SET RUG&CMT CAP(3/27-28/16) AR No: 50-029-20189-00 05/30/06 DTM WELLHEAD CORRECTIONS SEC 27,T11 N,R15E 90'FSL&593'FEL 05/16/02 CWS/KK SET BP 03/15/08 RC/PJC NAME&LOCATION CORRECTIONS BP Exploration(Alaska) OF T • • 0w.`„�y �,,SA THE STATE Alaska Oil and Gas - 7 ®A AS Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 QP.ALAS 6 f �l i Fax: 907.276.7542 0�" d www.aogcc.alaska.gov Jaime Bronga 071 Well Interventions Engineer11S— BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04-07 Permit to Drill Number: 175-077 Sundry Number: 316-027 Dear Mr. Bronga: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this 2/day of January, 2016. RBDMS LA- JAN 2 5 2016 STATE OF ALASKA .LASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend RI• Perforate ❑ Other Stimulate 0 Pull Tabing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: . 5. Permit to Drill Number 175-077 - 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p 99519-6612 Stratigraphic 0 Service 1:16. API Number: 50-029-20189-00-00 - 7. If perforating. 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No IO PBU 04-07• RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: I^AI 2096 ADL 028325 • PRUDHOE BAY,PRUDHOE OIL . I)TS / L` /, 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): AJOfi/��°°JJ�� kc 9494 9036 9165 8749 9165.9278'(TOC) 9429' Casing Length Size MD TVD Burst Collapse Structural ' Conductor 89 20"94#H-40 33-122 33-122 1530 520 Surface 2669 13-3/8"72#MN-80 32-2701 32-2701 5380 2670 Intermediate 8305 9-5/8"47#MN-80 30-8335 30-8003 6870 4760 Production Liner 1412 7"29#13CR80 8074-9486 7760-9029 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9066-9369 8664-8927 5-1/2",17#x 4-1/2"12.6# 13Cr80 28-8118 Packers and SSSV Type: 4-1/2"TIW HBBP Packer Packers and SSSV MD(ft)and TVD(ft): 8023/7712 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary lI Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development l Service 0 14.Estimated Date for Commencing Operations: February 1,2016 15. Well Status after proposed work: Oil 11 WINJ 0 WDSPL 0 Suspended p • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Bronga,Jaime be deviated from without prior written approval. Email Jaime.Bronga@bp.com Printed Name Bronga,Jaime Title Well Interventions Engineer Signature /1.-\____` �` Phone +1 907 564 4151 Date // /1/�l 9-Oka COMMISSION USE ONLY 999 Conditions of approval:Notify Commission so that a representative may witness Sundry Number: alt—o2Z Plug Integrity V BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other / Post Initial Injection MIT Req'd? Yes 0 No 1°If Spacing Exception Required? Yes❑ No LN' Subsequent Form Required: /0_467. APPROVED BYTHE Approved by: / /Y v��l COMMISSIONER COMMISSION Date: // VTI. /I,za/ib Y� ORIGINAL RBDMS t L, JAN 2 c Intibmit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. A a is in Duplicate • bp • • • 04-07 Reservoir Abandonment Intervention Engineer Jaime Bronga 907-564-4151 Production Engineer Patti Phillips 907-564-5662 History Well 04-07 has been shut in for over twenty years. The well's shut in surface pressure trend builds to -2000 psi over time. A 2015 video log confirmed this well's tubing hasparted right below the tubing hanger and has moved close to 10 feet downhole. In addition, a recent LDL, run on 12/13/2015, located a leak near 6000 feet in the production casing. This well resides near the top of the list for non-operable well risk. Objective This intervention is to effectively secure this non operable well and mitigate risk by completing the first stage reservoir abandonment by placing a posiset plug and 25' of dump bailed cement over the perforations in compliance with 20 AAC 25.112 (1) (E): if the perforations are isolated from open hole below, a mechanical bridge plug set no more than 50 feet above the top of the perforated interval, and either a minimum of 75 feet of cement placed on top of the plug by the displacement method or a minimum of 25 feet of cement placed on top of the plug with a dump bailer; Expected Start Date: February 1, 2016 Procedural steps Slickline 1. Install straddle into BPV profile. 2. Dummy GLVs E-Line 3. Set posiset plug at 9016'MD. 4. Dump bail 25' of cement onto the posiset plug. Slickline 5. Drift and tag TOC. ,1I'0 fi fl °6 e G '"/' fi`''r S S Fullbore 6. CMIT-TxIA to 2500psi. Expected to fail (PC leak). Establish LLR. TREE= MCEVOY • SAF IOTES:"**USEEXTREMECAUTIONWHEN WELLHEAD= P> ACTUATOR'= AXELSON 04-07 ENTERING WELL. TBG PARTED @TBG HGR&FELL -10'DH.CONTROL LINE BALLED UP @-2'SLM.*** KB,ELEV= 51' BF.ELEV= ? KOP 4500' 2203' -I5-112"CAM BAL-O SSSV NIP,ID=4.562" Max Angle= 31 @ 9494' Al O GAS LIFT MANDRELS Datum MD= 9281' ST MD5147 TVD5114 DEV24 TG TYPECA-TGPD VLV LATCH FORT DATE Datum TVD= v�8800'SS 1 3014 3014 1 CA-TGPD TG 2 13-3/8"CSG,72#,MN 80,ID=12.347" H 2701' 3 6340 6199 26 CA-TGPD TG Minimum ID =3.725" 8087' I 4 6928 6729 27 CA-TGPD TG v 5 7518 7254 26 CA-TGPD TG 4-1/2"PARKER SWN NO-GO NIP 6 7851 7555 26 CA-TGED TG 7 7924 7622 24 CA-TGPD TGE 5-1/2"TBG, 17#,13-CR,0.0232 bpf,ID=4.892" - 3002' / - 3002' -15-1/2"X 4-1/2"XO,ID=3.805" TOP OF 4-1/2"TBG H 3002' I I 7953' H4-1/2"PARKER SWS NP,ID=3.813" f><.. 8019' HI9-5/8"X 4-1/2"TW HBBP PKR,O=4.000" TOP OF 7"LNR H 8074' (--r I ■ - 8087' H4-1/2"PARKER SWS NP,ID=3.813" I I 8102' -14-1/2"PARKER SWN NO-GO NIP,ID=3.725" 4-1/2"TBG,12.6#,13-CR-80, - 8114' 0.0152 bpf,ID=3.958" 8115' H4-112"TUBING TAIL,ID=3.958" 8098' H ELMD TT LOGGED 03/01/92 9-5/8"CSG,47#,MN-80/SOO-95,ID=8.681" H 8342' FA , MILLOUT WINDOW 9-5/8" @ 8342'-8415' 1* PERFORATION SUMMARY 40 1111111\ , REF LOG: BHCS ON 02/16/92 0111h , 11111♦ ANGLE AT TOP PERF: 31 @9066' ��1�1.1.1�1�1/ 9165' H IBP(05/16/02) Note:Refer to Production DB for historical perf data 1111111 X111111/ , SIZE SPF AYTERVAL Opn/Sqz DATE 1111111 3-3/8" 4 9066-9070 0 09/19/93 1111111111111, 411111/ 3-3/8" 4 9120 9130 0 03/09/93 1111111' , 9278' -I cur CAP ON SAND PLUG 1111111 3-3/8" 4 9180-9190 C 05/16/02 111111111111/ 3-3/8" 4 9198-9226 C 05/16/02 111111111111/ ,riiiA 3-3/8" 4 9244-9250 C 05/16/02 '1111111111111 �����,� 1111111 !!iiia , 3-3/8" 4 9318-9341 C 05/16/02 4111111 ��� 9429' -FISH: WLM 3-1/2"CTU 1111111' 3-3/8" 4 9352-9369 C 05/16/02 411111111111 NOZZLE WITH 1'OF 1-3/4" 1111111 � 1111111111111 COILED TBG-02/04/93 411111111111/ �j� 1111111 % i X1111111 4111111111111 11111111111111 11111111111, '111111111114 z 4444444. 4***X11111111114 �1�1�1�1�1�1�/ 7"LNR,29#,13-CR, H 9486' •11111111111 0.0371 bpf,ID=6.184" 4 _ 111111 9-5/8"CSG,47#,NXV-80,ID=8.681" 9373' 6vA1a1A1e1a1A1i DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/15/76 ORIGINAL COMPLETION 10/15/15 PP/JMD ADDED SAFETY NOTE WELL: 04-07 02/22/92 SIDETRACK F1] MIT No: 1750770 06/15/01 RN/TP CORRECTIONS API No: 50-029-20189-00 05/30/06 DTM WELLHEAD CORRECTIONS SEC 27,T11 N,R15E,90'FSL&593'FEL 05/16/02 CWS/KK SET IBP 03/15/08 RC/PJC NAME&LOCATION CORRECTIONS BP Exploration(Alaska) TREE410- S G WELL f EAD= . )Q�=7 MCEVOY ` SAI-ti Y NOTES:""'USE EXTREME CAUTION WHEN ACTUATOR= AXELSON 04-07 ) DH CONTROL LMEENTERING WELL. TBG TBG HGRB FELL KB.ELEV= 51' - @-2'SLM.'*' BF.ELEV= ? KOP= 4500' 2203' —15-112'CAM BAL-O SSSV NJ,D=4.562" Max Angle= 31 9494' ,, ST MD TVD GAS LIFT MAPDRB S Datum MD= 9281' DEV VLV CN Datum ND= 8800 SS 1 3014 3014 1 CA-TGFD TG 2 5147 5114 24 CA-TORO TO 13-3/8'CSG,72#,MN-80,D--12.347' — 2701' 3 6340 6199 26 CA-TGPD TG Minimum ID=3.726" @ 808T L 4 6928 6729 27 CA-TORO TG 5 7518 7254 26 CA-TOFU TG 4-1/2"PARKER SWN NO-GO NIP 6 7851 7555 26 CA-TGPD TG 7 7924 7622 24 CA-TOFU TGE 5-1/2'TBG,17#,13-CR,0.0232 bpf,D=4-892" 3002' j 3002' —5-1/2"X 4-1/2"XO,D=3-805" TOP OF 4-1/2"TBG I— 3002' J - c i i I I 7953' —4-1/2"PARKER SWS NIP,D=3.813" 8019' —19-5/8"X 4-1/2"TIW FBBP PKR,D=4.000" ITOP OF 7"LNR H 8074' ><11 1 8087" —I 4-1/2-PARKER SWS NIP,D=3-813" 8102' -4-1/2"PARKER SWN NO-GO NP,D=3.725" 4-1/2"TBG,12.6#,13-CR-80, — 8114' / \ 8115' —14-112"TUBING TAIL,D=3.958" 0-0152 bpf,D=3-958" 8098' —IELMO TT LOGGED 03/01/92 9-5/8"CSG,47#,MN-80,D=8.681" —i 8342' 1-4 \, Posiset Plug @ 9016'MD i;4 M TOC @8991' D MLLOUT WNDOW 9-5/8" @8335'-8415' PEORATION SUMMARY1111 .REF LOG: BHCS ON 02/16/9211NN1♦1ANGLEATTOPFELE: 31 @9066' 11♦111111♦ 9165' —IBP(05/16/02) 44444 Note:Refer to Production DB for ltistorical perf data 44044 ,SIZE SPF MBVAL Opn/Sqz DATE13-3/8" 4 9066-9070 O 09/19/9311i1tiI I _11 �3-3/8' 4 9120-9130 O 03/09/9311 9278' I�"`CAPON SAND I3UG 3-3/8" 4 9180-9190 C 05/16/0211/ A1' 004)3-3/8' 4 9198-9226 C 05/16/0211 min/�3-3/8" 4 9244-9250 C 05/16/02 1 �arr�rni •1111111111, .swoon- ', 3-3/8" 4 9318-9341 C 05/16/02 X1111111111111 a i 9429' —FISH Wi M 3-1/2"CTU 3-3/8" 4 9352-9369 C 05/16/02 111111.11111' NOZZLE WITH 1'OF 1-3/4" 111111/1/111+ COILED TBG-02/04/93 111/11/111111 ��%/� •1/111111/140.4004 " *4 *444, '1111111 *1111111111 X11/111111111 011/11111/1 .111/11/111114 1111111, 4111111111111 7"LNR,29#,13-CISIICZEI .111111111111• 0.0371 bpf,ID=6.184' 4440004041111 9-5/8"CSG,47#,MN-80,D=8.681" 9373' "41,4•A" DATE REV BY CONVENTS DATE REV BY COMtuENTS PRUDHOE BAY UNIT 11115176 ORDINAL COMPLETION 10/15/15 PP/JMD ADDED SAFETY NOTE WELL: 04-07 02/22/92 SIDETRACK PEWIT No: 1750770 06/15/01 RNrIP CORRECTIONS AR No: 50-029-20189-00 05/30/06 DTM WELLHEAD CORRECTIONS SEC 27,T11N,R15E,90'FSL&593'FEL. 05/16/02 CWS/KK SET BP 03/15/08 RCJPJC NAME&LOCATION CORRECTIONS BP Exploration(Alaska) 3 011 111 2J 3'3 WELL LOG TRANSMITTAL 4 PRoAcTivE DiAgNosTic SERVICES, INC. To: AOGCC Makana Bender 333 W. 7th Ave DATA LOGGED Suite 100 y i' mice. Anchorage, Alaska 99501 K.BENDER (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2-1 900 Benson Blvd. Anchorage, AK 99508 gancpdc(c bp.com SCANNED and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 12-Dec-15 04-07 BL/CD 50-029-20189-00 2) Signed : t����.,e-/) � Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. 0. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 5, 2009 Cathy Foerster, Commissioner Alaska Oil and Gas Commission 333 W. 7th Avenue, suite 100 Anchorage, AK 99501-3539 Re : Information Request - Status of Oil and Gas Wells In your June 22, 2009 letter, you requested information regarding a list of oil and gas wells operated by BP Exploration (Alaska), Inc. (BPXA) which the Commission shows to have been shut in for 5 years or longer. The request included the following for each well: verification that the Commission's information is correct, future plans, and if the information is not correct, the current status of each with documentation. The list included 98 wells operated by BPXA. The information contained in the list is correct in that each well has been shut in for approximately 5 years or more. All but six wells are shut in producers on active pads and may have potential future utility. Of the six wells, two wells are classified as service wells on active pads and may have future utility (water supply well MPU TER B-01 and water injector Niakuk NK -17). The remaining four wells are on the Badami and Milne Point D pads. The Badami development is shut in for evaluation pending the results of drilling activities. Badami B 1-25 and B 1-28 may have utility as part of any future development activities. Milne Point D pad is inactive with two shut in wells (MPU KR D-01 and D -02A). These wells will likely be suspended or plugged and abandoned within the next three years. Please call me at 564-4194 if you have any questions about the enclosed information. Sincerely, Harold Engel Alaska Drilling and Wells Well Integrity Team Lead cc: Steve Rossberg Tom Marshall David Szabo Tim Verseput Scott Digert Frank Paskvan Steve Robinson Alan Mitchell Dube / Roshinger John Cyr BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Ll L% ALASEL'A OIL AND GAS CONSERVATION COMUSSION June 22, 2009 f SARAH PALIN, GOVERNOR r` 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Harry Engel BP Exploration Alaska Inc. PO Box 196612 SCANNEr Anchorage AK 99519-6612 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Engel: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by BP Exploration Alaska Inc. have been inactive for five years or longer. If, for any listed well, BP Exploration Alaska Inc. believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, BP Exploration Alaska Inc. agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve BP Exploration Alaska Inc. of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertDa Sincerely, Cathy . Foerster Com issioner Enclosure Operator Permit No. Well Name BPXA 198-153 Badami Unit B 1-25 _ _ BPXA 198-130 Badami Unit B1-28 BPXA 188-145 Duck Is Unit MPI 2-42/P13 BPXA 194-049 _ Duck Is Unit SDI 3-19/R28 BPXA 185-062 Milne Pt Unit KR B-07 BPXA 185-093 Milne Pt Unit KR B-13 BPXA 189-016 _ Milne Pt Unit KR B-23 BPXA 189-015 Milne Pt Unit KR C-20 BPXA 181-144 _ Milne Pt Unit KR D-01 _ BPXA 183-040 Milne Pt Unit KR D -02A BPXA 194-118 Milne Pt Unit KR J-12 BPXA 194-169 Milne Pt Unit KR L-17 BPXA 198-115 Milne Pt Unit SB E-21 BPXA 198-128 Milne Pt Unit SB E-33 BPXA 197-119 Milne Pt Unit SB G-11 BPXA 197-142 Milne Pt Unit SB G-12 BPXA 190-086 _ Milne Pt Unit SB H-01 BPXA 190-088 Milne Pt Unit SB H-03 BPXA 190-090 Milne Pt Unit SB I-01 BPXA 191-097 Milne Pt Unit SB J-07 BPXA 198-056 Milne Pt Unit SB L -37A BPXA 198-169 Milne Pt Unit SB L-45 BPXA 196-016 Milne Pt Unit SR C-23 _ BPXA 180-075 Milne Pt Unit TER B-01 BPXA 190-087 Milne Pt Unit UGNU H-02 BPXA 200-162 Prudhoe Bay Un Bore Z-101 BPXA 185-140 Prudhoe Bay Un Lis L1-14 BPXA 188-025 Prudhoe Bay Un Lis L1-28 BPXA 190-018 Prudhoe Bay Un Lis L1-30 BPXA 187-097 Prudhoe Bay Un Lis L2-16 BPXA 185-134 Prudhoe Bay Un Lis L2-20 BPXA 186-006 Prudhoe Bay Un Lis L2-25 BPXA 185-104 Prudhoe Bay Un Lis L2-26 BPXA 185-009 Prudhoe Bay Un Lis L2-30 BPXA 187-137 Prudhoe Bay Un Lis L2-32 BPXA 183-143 Prudhoe Bay Un Lis L3-08 BPXA 186-034 Prudhoe Bay Un Lis L3-31 BPXA 188-084 Prudhoe Bay Un Lis 1,4-11 BPXA 191-106 Prudhoe Bay Un Lis L4-32 BPXA 189-009 _ Prudhoe Bay Un Lis 1,5-01 BPXA 190-110 Prudhoe Bay Un Lis L5-26 BPXA 188-013 Prudhoe Bay Un Lis LGI-04 BPXA 186-057 Prudhoe Bay Un Lis LGI-08 BPXA 186-054 Prudhoe Bay Un Lis LGI-12 BPXA 196-165 Prudhoe Bay Un Nia NK -17 _ _ BPXA 198-140 Prudhoe Bay Un PBU L2 -08A BPXA 198-106 Prudhoe Bay Un PBU L2 -18A BPXA 197-239 Prudhoe Bay Un Pol S-200 BPXA 193-103 Prudhoe Bay Un PTM P2-06 BPXA 182-203 Prudhoe Bay Unit 01-25 BPXA 186-111 Prudhoe Bay Unit 01-30 _ BPXA 175-077 Prudhoe Bay Unit 04-07 _ BPXA _ _ 186-035 Prudhoe Bay Unit 04-33 BPXA 191-077 Prudhoe Bay Unit 04-39 BPXA 194-003 _ Prudhoe Bay Unit 04-47 _ BPXA 179-073 _ Prudhoe Bay Unit 06-09 BPXA 199-007 Prudhoe Bay Unit 09-42A BPXA 194-081 Prudhoe Bay Unit 11-23A BPXA 181-073 Prudhoe Bay Unit 12-11 BPXA 181-103 Prudhoe Bay Unit 13-05 BPXA 181-129 Prudhoe Bay Unit 13-07 BPXA 182-074 _ Prudhoe Bay Unit 13-26 BPXA 196-121 Prudhoe Bay Unit 13-27A BPXA 183-060 Prudhoe Bay Unit 13-28 BPXA 182-106 Prudhoe Bay Unit 13-33 BPXA 188-103 Prudhoe Bay Unit 14-38 BPXA 188-138 Prudhoe Bay Unit 14-39 BPXA 182-030 Prudhoe Bay Unit 15-03 BPXA 188-085 Prudhoe Bay Unit 15-10A BPXA 191-128 Prudhoe Bay Unit 15-24 BPXA 195-174 _ Prudhoe Bay Unit 15-47 BPXA 192-075 Prudhoe Bay Unit 16-31 BPXA 186-094 Prudhoe Bay Unit 18-19 BPXA 197-098 Prudhoe Bay Unit 18-25A BPXA 195-074 Prudhoe Bay Unit 18-28 BPXA 192-107 Prudhoe Bay Unit A -18A BPXA 194-158 Prudhoe Bay Unit A-41 BPXA 178-069 Prudhoe Bay Unit B-11 BPXA 182-140 Prudhoe Bay Unit B-24 BPXA 186-066 Prudhoe Bay Unit C-38 BPXA 197-070 Prudhoe Bay Unit G -03A BPXA 189-044 Prudhoe Bay Unit H-28 BPXA 187-101 Prudhoe Bay Unit K-13 BPXA 193-086 Prudhoe Bay Unit M -27A BPXA 170-062 Prudhoe Bay Unit N-03 _ _ BPXA 193-121 Prudhoe Bay Unit P-22 BPXA 178-099 Prudhoe Bay Unit R-01 _ BPXA 192-058 Prudhoe Bay Unit R-28 BPXA 182-135 Prudhoe Bay Unit S-13 BPXA 190-127 Prudhoe Bay Unit S-23 BPXA 190-066 Prudhoe Bay Unit S-30 BP Exploration (Alaska), Inc. 198-239 Prudhoe Bay Unit U -02A BP Exploration (Alaska), Inc. 198-202 Prudhoe Bay Unit U -08A BP Exploration (Alaska), Inc. 188-056 _ Prudhoe Bay Unit Y -08A BP Exploration (Alaska), Inc. 180-119 Prudhoe Bay Unit Y-12 BP Exploration (Alaska), Inc. 201-179 Prudhoe Bay Unit Y -17B BP Exploration (Alaska), Inc. 191-065 Prudhoe Bay Unit Y-28 BP Exploration (Alaska), Inc.: 195-046 _ Prudhoe Bay Unit Y-38 ,,. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ SET IBP Pull tubing _ Alter casing _ Repair well _ Other_X SET IBP 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 5189' FNL, 593' FEL, Sec. 27, T11N, R15E, UM At top of productive interval 1709' FNL, 1375' FEL, Sec. 34, T11N, R15E, UM At effective depth 1745' FNL, 1423' FEL, Sec. 34, T11N, R15E, UM At total depth 1759' FNL, 1444' FEL, Sec. 34, T11N, R15E, UM 5. Type of Well: Development __X Explorato~__ Stratigraphic_ Service__ (asp's 712235, 5951946) (asp's 711507, 5950125) (asp°s 711564, 5950172) (asp's 711435, 5950073) 6. Datum elevation (DF or KB feet) RKB 51 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 04-07 9. Permitnumber/approvalnumber 175-077 10. APInumber 50-029-20189-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9494 feet Plugs (measured) 9036 feet 9165 feet Junk (measured) 8750 feet Set IBP @ 9165' (05-16-2002) Tagged TD @ 9269' (04-12-2002) Cement Cap @ 9278' Casing Length Conductor 54' Surface 2671' Intermediate 9353' Liner 1390' Size Cemented Measured Depth 20" 24 sx AS 84' 13-3/8" 3900 sx PF 2701' 9-5/8" 1125 sx Class 'G' 9373' 7" 303 sx Class 'G' 8074' - 8335' True Vertical Depth 84' 2701' 8931' 7760'-80O3' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) Open Perfs 9066'-9070', 9120'-9130', Open PerfsbelowlBP 9180'-9190', 9198'-9226', 9244'-9250' Below Cement Cap 9318'-9341', 9352'-9369'. Open Perfs 8664'-8668', 8711'-8720', Open Perfs below IBP 8763'-8772', 8779'-8803', 8819'-8824' Below Cement Cap 8883'-8903', 8913'-8927' 5-1/2", 17#, 13 CR-80, TBG @ 3002' MD; 5-1/2" x 4-1/2" XO @ 3002'; 4-1/2", 12.6#, 13 CR-80 Tubing @ 8115' MD. 9-5/8" x 4-1/2" TIW HBBP PKR @ 8019'. 5-1/2" Camco BaI-O SSSV Nipple @ 2203' 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 Shut-In Subsequent to operation Shut-In Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 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 foregoin.~ is t,~ue and correct to the best of my knowledge. ~~"'~,~J~~"/' Title: Technical Assistant DeWayne R. Schnorr Date. September 26, 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 04-07 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04112/2002 INJECTION CONVERSION: DRIFT/TAG 05/15/2002 ANNCOMM 05/16/2002 PACKERS/BRIDGE PLUGS/POGLMS: INFLATABLE BRIDGE PLUG 09/26/2002 WELL SHUT-IN/WAITING FOR ADDITIONAL MI TO BE INJECTED EVENT SUMMARY 04/12/02 DRIFTED TUBING AND TAGGED PBTD AT 9269' ELMD CORRECTED WITH A 3.5" DUMMY GUN. WELL LEFT SHUT IN-NOTIFY DSO OF WELL STATUS. (PRE 05/15/O2 T/I/O = 2480/380/300. FLs for wireline. Tubing FL @ 7924'- sta#7 (145 BBLs). IA FL @ 4990' - 150' above sta#2 (218 BBLs). 05/16/O2 RIH WITH BAKER 3 3/8" IBP, TIE IN AND SET PLUG AT 9165', TAGGED PLUG AFTER SET, POOH, RDMO ELINE. LEFT WELL SHUT-IN. 09/26/02 WELL IS SHUT-IN, WAITING FOR ADDITIONAL MI TO BE INJECTED BEFORE RESTARTING PRODUCTION IN THIS WELL. Fluids Pumped BBLS 1 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 1 TEST) 60/40 METHANOL WATER 1% KCL WATER 1% EXTRA SLICK KCL WATER 2# BIOZAN ;TOTAL Page I STATE OF ALASKA ALASKA J~._ AND GAS CONSERVATION COI~i..,!SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate Plugging ~ Perforate ~ Pull tubing Alter casing ~ Repair well Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 90' NSL & 593' WEL, Sec. 27, T11 N, R15E, UM. At top of productive interval 1709' SNL & 1375' WEL, Sec. 34, T11N, R15E, UM. At effective depth 1745' SNL & 1423' WEL, ,Sec 34, T11N, R15E, UM. At total depth 1759' SNL & 1444' WEL, Sec 34, T11N, R15E, UM. 5. Type of Well Development Exploratory Stratigraphic Service X 6. Datum of elevation(DF or KB) 51' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-07 ST1 9. Permit number/approval number 75-77 10. APl number 50 - 029-20189 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9494 feet 9036 feet Plugs(measured) Fill @ 9273' (7/19/96); Cmt Cap @ 9322' MD. Effective depth: measured 9273 feet true vertical 8839 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 54' 20" 24 Sx AS 84' 84' Sudace 2671' 13-3/8" 3900 Sx PF 2701' 2701' Production 9353' 9-5/8" 1125 Sx Class G 9373' 8931' Liner 1390' 7" 303 Sx Class G 8074 - 9464' 7760 - 9010' RECEIVED Perforation depth: measured 9066 - 9070'; 9120 - 9130'; 9180 - 9190'; 9198 - 9226'; 9244 - 9250' true vertical 8663 - 8667'; 8710 - 8719'; 8762 - 8770'; 8777 - 8801'; 8817 - 88~IG '~ (~ 199{~ Tubing (size, grade, and measured depth) 5-1/2", 17#, 130R Tbg @ 3002' MD; 4-1/2", 12.6~, Packers and SSSV (type and measured depth) TIW HBBP Packer @ 8019' MD; Camco BaI-O SSSV @ 2203' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached 14. ORIGINAL, Treatment description including volumes used and final pressure Representative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut In ........ Subsequent to operation Shut In 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 Rev 06/15/88 CC: JWP. Date ~-- / SUBMIT IN DUPLICATE.~. 4-7 ST1 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/1 9/96: RIH & tagged PBTD at 9273' MD. 7/21/96: MIRU & PT equipment. Added perforations: 9198 - 9226' MD (Z2) Shot 4 spf at underbalanced pressure. RIH w/perforating gun & shot 28' of add perforations: Ref. Log: BHCS 2/16/92. POOH w/perf gun. Rigged down. Obtained welltests, then shut in the well due to high watercuts & gas production.. A future rig workover is currently being evaluated. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 Al-tN: Sherrie Well D.S. -1022-A-. D.S. 4-7 ST1 D.S. 4-7 ST1 D.S. 7-3A D.S. 11-18 D.S. 11-31 D.S. 13-05 D.S. 15-35 Log Description DUAL BURST TDT-P RST CNTD NO. 97O9 Company: PERF RECORD PROD PROFILE PROD PROFILE PERF RECORD DUAL BURST TDT-P Field: Date BL Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 950823 1 950808 I 950809 950807 950807 950809 950807 950806 Prudhoe Bay Floppy RF Sepia DIR MWD Disk 9/8/95 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED , EP 0,8 - ods b, uiI,.5. ' Anchorage GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9697 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 9/6/95 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 4-7 ST1 95292 CNTD '>7 '~- 6~7 ~7 . [_~ ~ I ~ 950809 1 D.S. 9-4A 95302 C~G ~ ~6~ ~' H 950819 1 D.S. 11-25 95286 CNT9 ~~.~ (~ ~ 950811 I SIGNED: ~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATI'N: Sherrie NO. 9575 Company: 7/14/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Well Job # Log Description D.S. 1-5 ST D.S. 4-7 ST D.S. 6-16 D.S. 9-9 D.S. 11-22 D.S. 15-40 D.S. 5-6A D.S. 5-6A PROD PROFIL~= IN-N-~-~~RIDGE PLUG PROD PROFILE ~ PROD PROFILE ~ ~DUAL~ INDUCTION LO~RT-J ILD/SN_)_ CBT SONIC (OPEN H---0-~ Date 950610 950627 950624 950628 950627 950624 950626 950626 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Prudhoe Bay Floppy RF Sepia DIR MWD Disk AUG 1 1995 DA-i~ska 0ii & Gas Coris. Commission STATE OF ALASKA ALAS[:, OIL AND GAS CONSERVATION ,MMISSION REPOR" OF SUNDRY WELL OPFRATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging Perforate X 2. Name of Operator Pull tubing Alter casing Repair well Other ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 4. Location of well at surface 99510-0360 5. Type of Well Development X Exploratory Stratigraphic ,, , Service 90' NSL, 593' WEL, Sec. 27, T11N, R15E, UM At top of productive interval 1709' SNL, 1375' WEL, Sec. 34, T11N, R15E, UM At effective depth 1745' SNL, 1423' WEL, Sec. 34, T11N, R15E, UM At total depth 1759' SNL, 1444' WEL, Sec. 34, T11N, R15E, UM RECEIVED FEB 2 8 995 A.~s~ D~t & Gas Cons. Commission 12. Present well condition summary Total depth' measured true vertical 6. Datum of elevation(DF or KB) 51' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-07ST1 9. Permit number/approval number 75-77 10. APl number 50 - 029-20189-00 11. Field/Pool Prudhoe Bay Oil Pool 9494 feet 9036 feet Plugs(measured) Fill @ 9244' MD (12/29/94) on top of Cmt Plug @ 9322' MD Effective depth: measured 9244 feet true vertical 8816 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 84' 20" 240 sx AS 84' 84' Surface 2671' 13-3/8" 3900 sx PF II 2701' 2701' Production 9353' 9-5/8" 1000 sx CL G & 125 sx PF II 8342' 8009' Liner 1390' 7" 303 sx CL G 8074-9464' 7760-9010' Perforation depth: measured 9066-9070; 9120-9130'; 9180-9190'; 9244-9250' [isolated: 9318-9341'; 9352-9369'] true vertical 8663-8667'; 8708-8716'; 8761-8770'; 8816-8821' [isolated: 8878-8897'; 8907-8922'] Tubing (size, grade, and measured depth) 5-1/2", 17#, 13CR, Tbg @ 3002' MD; 4-1/2", 12.6#, 13CR-80, Tbg @ 8114' MD Packers and SSSV (type and measured depth) 9-5/8" TIW HBBP pkr @ 8019' MD; 5-1/2" Camco BaI-O SSSV @ 2203' MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) See Attached Treatment description including volumes used and final pressure Representative Daily Average Production or Iniection Data OiI-Bbl Prior to well operation 1402 Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15229 14326 44-6 Subsequent to operation 1344 14440 14597 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. Service 484 Signed Form 10-404 Rev 06/15/88 CC' KZ, JWP Title Engineering Supervisor Date SUBMIT IN DUPLICATE ~" 4-7 ST1 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 12/29/94. RIH & tagged PBTD at 9244' MD. 12/30/94- MIRU & PT equipment. Reperforated: RIH w/perforating gun & shot 4' of reperforations as follows: 9066 - 9070' MD (Z2) Ref. Log: BHCS 2/16/92. Used a 3-3/8" carrier & shot 2 spf at 180 degree phasing. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED FEB 2 8 1995 &~ska Oil & Gas Cons. Commissio~ Anchor~:, GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie F_.. C rO RECEIVED ~¢o~%~ ~' Oil & ~as Cons. Commission - Anchorage NO. 9211 Company: 1/23/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description BL RR Sepia RF Sepia Mylar x '7C 'o D.S. 1-3 POGLM SETrmNG RECORD (12-23-94) ~/'1 -~'1 D.S. 1-3 POGLM RECORD (1-3-9S) wl vl ]D.S. 1-25 LEAK DETECTION (1-3-95) v-1 ~'1 D.S. 3-27 BAKER IBP RECORD (12-31-94) ~ D.S. 4-7 ST 1 PERF RECORD (12-30-94) ~1 D.S. 4-22A PROD PROFILE (12-26-94) ~'1 v,' 1 D.S. 6-4 PERF RECORD (12-25-94) .,,1 D.S. 6-14A PERF RECORD (12-26-94) ,,'1 ,,'1 D.S. 9-4A PERF RECORD (12 23-94) ~ D.S. 9-30 ST PERF RECORD (1-2-95) ~/1 D.S. 9-32 PERF RECORD (12-25-94) v,1 D.S. 11-16 ST I LEAK DETECTION (12-31-94) ,--1 D.S. 11-23A PERF RECORD (12-21-94) ~ D.S. 13-15 SBHPS & INJEC PROFILE (12-29-94) .,-r D.S. 13-33 LEAK DETECTION (12-30-94) 1 1 D.S. 13-33 BAKER INFLAT BRIDGE PLUG RECORD (1-3-95) -1 .D.S. 14-21 SBHPS & INJEC PROFILE (12-23-94) .-1 '"'1 D.S. 15-7A DUAL BURST TDT-P (12-27-94) v,1 ,~1 .D.S. 15-30 LEAK DETECTION (12-27-94) ~ ,--'1 D.S. 15-30 DUAL BURST TDT-P (CT/E-LINE) (12-30-94) -.-1 ,"1 D.S. 18-9A DUAL BURST TDT-P (12-22-94) ~1 ,/1 D.S. 18-27 DUAL BURST TDT-P (CT/E-LINE) (12-29-94) -vl SIGNED' DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQueet ~ W, International A~porl Road Anohoroge, Al( 99618-1199 ATTN: Sherrie NO. 8882 Company: ! Alaska 011 & Gas Cone Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 8/24/94 Field: Prudhoe Bay · " Well Log Deecription BL RR Sepia RF Sepia Mylar ~ D.S. 4-4 PERF RECORD (8/2/94) 1 1 "?~'- '~Z D.S. 4-7 ST#1 PROD PROFILE (8/7/94) 1 1 ~ - ! E,~ D.S. 9-40 STATIC PRESSURE SURVEY (8/2/94) 1 1 ~'c/- ~'c> D.S. 11-33 PERF RECORD (8/3/94) 1 1 ~ D.S. 11-33 JEWELRY LOG (8/3/94) 1 1 ? ?- ~ ,~ D.S. 12-02 INJEO PROFILE (8/4/94) 1 1 ~ ~/'~'~? 'D.S. 12-04A PROD PROFILE (8/4/94) 1 ' 1 ~c/~- G..~ D.S. 15-34 STATIC PRESSURE SURVEY (8/1/94) 1 1 -"?V'- ~'3 D.S. 15-34 j JEWELRY LOG (7/30/94) 1 1 ~%,'- ¢ ~ D.S. 15-34 JPERF RECORD (7/30/94) 1 1 ~!D.S. 15-35 STATIC PRESSURE SURVEY (8/1/94) 1 1 --~V~ ~7 D.S. 15-37 PERF RECORD (8/1/94) 1 1 ~ D.S. 15-37 JEWELRY LOG (8/1/94) 1 1 Please sign and return one copy of this transmittal to Sherrle at the above address. Thank you. STATE OF ALASKA '" ALASK' "ILAND GAS CONSERVATION C IMISSION REPOR'I'" OF SUNDRY WFLL OP:RATIONS 1. Operations performed' Operation shutdown Stimulate __ Plugging Perlorate X 2. Name of Operator Pull tubing -- Alter casing Repair well Other i ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 90' NSL, 593' WEL, Sec. 27, T11 N, R15E, UM At top of productive interval 1709' SNL, 1375' WEL, Sec. 34, T11N, R15E, UM At effective depth 1745' SNL, 1423' WEL, Sec. 34, T11N, R15E, UM At total depth 1759' SNL, 1444' WEL, Sec. 34, T11N, R15E, UM 12. Present well condition summary 5. Type of Well Development Exploratory Stratigraphic Service RECEIVED AUG 1 5 'i99~ ,~iaska. 0il & Gas Cons. C0mmissior' Anchor~L.: ~. 6. Datum of elevation(DF or KB) 51' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-07 ST1 9. Permit number/approval number 75-77 10. APl number 50 - 029-20189-00 11. Field/Pool Prudhoe Bay Oil Pool Total depth: measured 9494 feet true vertical 9036 feet Effective depth: measured 9284 feet # ,r"'*', i: i;~i, i; true vertical 8849 feet Junk(measured) i' iI~f lt i~: '''~17,:!~i Casing Length Size Cemented Measured depth Conductor 84' 20" 240 sx AS 84' Surface 2671' 13-3/8" 3900 sx PF II 2701' Production 9353' 9-5/8" 1000 sx CL G & 125 sx PF II 8342' Liner 1390' 7" 303 sx CL G 8074-9464' Plugs(measured) Fill @ 9284' MD (7/8/94) on top of Cmt Plug @ 9322' MD True vertical depth 84' 2701' 8009' 7760-901 O' Perforation depth: measured 9066-9070'; 9120-9130'; 9180-9190'; 9244-9250'; 9318-9341'; 9352-9369' true vertical 8663-8667'; 8708-8716'; 8761-8770'; 8816-8821 '; 8878-8897'; 8907-8922' Tubing (size, grade, and measured depth) 5-1/2", 17#, 13 CR, Tbg @ 3002' MD; 4-1/2", 12.6#, 13CR80, Tbg @ 8114' MD Packers and SSSV (type and measured depth) 9-5/8" TIW HB-BP pkr @ 8019' MD; 5-1/2" Camco BaI-O SSSV @ 2203' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure .Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Prior to well operation 1346 11304 Subsequent to operation 1499 ' 14196 15. Attachments Copies of Logs and Surveys run _ Water-Bbl Casing Pressure Tubing Pressure 9958 -- 368 13903 -- 416 16. Status of well classification as: 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. Service Form 10-404 I~,~v 06/15/88 1183/13 cc: KZ, JWP Title Sr. CA Engineer SUBMIT IN DUPLICATE 4-07 ST1 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 5/25/94: RIH & tagged PBTD at 9247' MD. 5/26/94: MIRU & PT equipment. RIH w/perforating gun & tagged bottom fill at 9238' MD, then PU & shot a 10' interval of perforations as follows: Added perforations: Reperforated: 9180 - 9184' MD (Z2) Ref. Log: BHCS 2/16/92. 9184 - 9190' MD (Z2) Used a 3-3/8" carrier, & shot 4 spf, at 180 degree phasing. POOH w/perf gun. Rigged down. 7/5/94: RIH w/CT & jetted a fill cleanout down to 9305' MD. 7/6/94: RIH & tagged PBTD at 9281' MD. Ref. Log: BHCS 2/16/92. Shot at underbalanced pressure. 7/8/94: MIRU & PT equipment. RIH w/perforating gun & tagged bottom fill at 9284' MD, then PU & shot a 6' interval of add perforations as follows: Added perforations: 9244 - 9250' MD (Z2) Ref. Log: BHCS 2/16/92. Used a 3-3/8" carrier, & shot 4 spf, at 180 degree phasing. Shot at underbalanced pressure. POOH w/perfgun. Rigged down. Returned the well to production & obtained a valid welltest. RECEIVED AUG 1 $ 'J99q At~ska, Oi~ & Gas Cor~s. Cor~rnission ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location- P.O. Box 100360, A,..~orage, AK August 3, 1994 Transmittal #: ARCO Cased Hole Finals Karla Zuspan/ATO- 1529 (907) 265-6547 94068 Distribution 99510,~ ~, Well Log Date Tool Type Contractor Number (M-D-Y) "/'~ 01-03 7-4-94 Leak Det 1 SCH ~ 03-12 7-2-94 Inj Pmf I SCH ~ 03-19 7-7-94 Prod Prof 1 SCH I-2~--L 03.25A 7-7-94 i Perf Record 1 SCH - ,- 63 04-02 7-3-94 Leak Det 1 SCH ~ *04-07 ST1 7-8-94 Perf Record 1 SCH ,,-).z. 05-01 7-9-94 Tubing Cutter 1 SCH ~' 05-11 7-9-94 Perf Record 1 SCH ~/,"o 06-11 7-2-94 Dual Burnt TDT-P 1 SCH ~/~ 06-21 7-1-94 Prod Prof 1 SCH ~-%? 06-22A. 7-4-94 Perf Record 1 SCH -r-c, 07-02 7-4-94 Prod Log 1 SCH ~ 09-31A 7-8-94 G R/Collar 1 SCH - ~7' ~ 09-32 7-7-94 Dual Burst TDT-P 1 SCH ---~'~"-- 15-01 7-2-94 Prod Prof 1 $CH ~ 16-02 7-5-94 Inj Pmf 1 SCH ~._~' 16-10 7-6-94 Inj Pmf 1 SCH ~---~___i._ 16-24 7-3-94 Perf Record 1 SCH I - c,=,6i 17-07 7-5-94 Leak Det I SCH *The correct APl number for 04-07 ST1 is 50-029-20189-00. Number of Records: 19 Kaqa Zuspan Distribution: Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska /I, Mobil Please acknow~ge re.~j~y signing and returning ~y ARCO Alaska, Inc. Is a Subsidiary of AtlanflcRIchfleldCompany ARCO Alaska, Inc. Date: June 14, 1994 P.O. Box 100360,.. Ichorage, AK 99510~~. Transmittal#: 94045 ~ ~' Subject' From/Location: Telephone' To/Location: ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution Well { Log Date Number. (M-D-Y) ¢-,/q-?0i 1-10A ! 06-02-94 i 2-33 i 05-22-94 f 3-18A i 05-19-94 82. ! 3-27 i 05-24-94 -~ i 4-07ST! 05-26-94 Tool Type ,'" USIT f CNL Gas Cons. Commission Anche. rage Run, Scale Contractor SCH SCH ~- CCL SCH ,"BAKER IBP REC SCH : / PERFREC SCH 4-11A i 06-04-94 -~ INJ PROFILE SCH 4-19 !05-25-94 / USlT SCH 4-46 f06-04-94 -Production Profile 1, 1" 5" SCH 5-3A i06-02-94 / CCL 1 5" SCH /' PERF REC /P~atch Setting Rec -'5-',5! 6-3 i 06-03-94 ~r5 i 6-10 f 05-22-94 35 i 6-16 i 06-05-94 i 6-22A ! 05-22-94 /Tubbing Puncher ,,'" CNL ? CNL ~~~"~ i 7-4A i 05-21-94 !i i05-21-94 ¢Production Profile 1 1 5" 1 5" 1 5" 1 5" 1 5" 7-18 i 05-21-94 ¢6r-i lu~% } 7-23 Pref Rec 1 5" 1 5" 1 5" 1 5" 1 5" I 5" , 5II 1,1"5" , 511 , 511 1,~ 5II 1,~ 5II 1, 1" 5" 1, 5" ,f 5II ! 5II 1~ 511 , 5II CNL I 05-24-94 I ,'/ CCL HD i 7-26 i05-21-941~ Prod Profile OS ! 7-28 i 05-26-94 ,/ PerfRec Of 5 i 9-13 i 05-25-94~' Bridge Plug I?-Z¢i 9-44 i 05-20-94 ¢Production Profile /~c~ //il 9-50 I 05-20-94 ,Production Profile 11-29l i 05-31-94 ~ CNL ot~_.5~(/' i 11-291 I 05-30-94 ~- USiT : 11-291 I 05'31'94~ /" TDT-¢ //~~ 11-291 I 05-30-941/" CBT ~'5 11-35 f 05-31-94 / USIT 11-35 i 05-31-941-" CBT ~&, i 11-36 i 05-23-94 I / CBT ~2.. i 14-3 ! O6-O3-94 1-~ PERFREC ~t-llm/l 14-12 i 05-28-94 ]'"' GRLOG '~',,.i 14-12 I 05-28-94 f'Production Profile ~ 14-20 I 06-01-94 "-/' PERF REC 14-34 I 06-01-94 / PERF REC 16-13 i 05-24-94 ~ Baker IBP Rec 17-12 I 06-05-94 ~' Leak Detection 17-19 i 05-26-94 / PERF REC It 5II 18-1 i 06-04-94 18-1 f 06-04-94 SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH 1 5" 1 5" 1 5" I 5" I 5" 1 5" 1,1 2"5" 1~ 5II Pack Off Gas Lift 1, 5" 511 /Tubing Puncher SCH ARCO Alaska, Inc. Is a Subsidiary o1 AtlantlcRIchfleldCompany ARCO Alaska, Inc. Date: Subject: From/Location: P.O. Box 100360, chorage, AK Feb 1 1, 1994 Transmittal #: 94021 BHP Report John Degrey/ATO-1529 Telephone- (907) 263-4310 To/Location: Distribution I~o- 0'5 8,o- q% ~:)-I~ ~:~--~7 Well i Log Date Tool Type Run, Scale Contractor Number (M-D-Y) 1-9 12-17-92 BHP i Camco /1-14 8-11-92 BHP - Camco \1-14 8-11-92 BHP - Camco 2-2 1-10-93 BHP - Camco 2-13 2-12-93 BHP - Camco 2-35 5-21-92 BHP - Camco 3-15A 3-20-93 BHP - Camco ~ 3-20 12-18-92 BHP - Camco 4-7ST 5-17-92 BHP Camco 4-14 1-9-93 BHP Camco ,, 4-29 12-28-92 BHP Camco ...... 4-42 4-27-92 BHP - Camco 5-9 2-21-93 BHP - Camco 5-16 2-21-93 BHP - Camco 5-25 2-21-93 BHP - Camco 5-31 2-21-93 BHP - Camco 5-33 1-29-93 BHP - Camco 5-35 1-29-93 BHP Camco 5-36 1-29-93 BHP Camco 9-24 2-15-93 BHP - Camco ,, 9-40 1-25-93 BHP - Camco 9-51 3-20-93 BHP - Camco 12-7A 12-6-92 BH P - Camco 12-7A 12-10-92 BHP - Camco 12-9 12-10-92 BHP - Camco - 12-29 12-14-92 BH P - Camco 13-15 7-3-92 BHP Camco 13-20 7-4-92 BH P - Camco 13-23A 7-4-92 BHP - Camco 13-32 7-3-92 BH P - Camco 14-11 11-23-92 BHP - Camco 16-19 10-19-92 BHP - Camco 16-21 10-19-92 BHP - Camco 16-30 9-28-92 BH P - Camco 17-3 12-12-92 BHP - Camco 17-10 11-8-92 BHP - Camco 17-11 2-8-93 BHP Camco ,,, 17-20 12-21-92 BHP - Camco 17-21 12-21-92 BHP - Camco 18-15 6-14-92 BHP - Camco ARCO Alaska, Inc. Is a ~ubsh~w~/of AtlantlcRIchfleidCompeny RECEIVED Alaska Oil ~ .(:-'as Cons. '~nchorage C°rr~is$ion ALASKA REPORT STATE OF ALASKA AND GAS CONSERVATION CO~" 'ISSION SUNDRY WELL OPE,.ATIONS Stimulate Plugging Perforate X Alter casing __ Repair well Off'let __ U4,~,,/ 5. Type o~f Well _ 6. Datum of elevation(DF or KB) ~-,~1 ueve,opment X 51' RKB fee{' 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator ARCO Alaskar Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 90' NSL, 593' WEL, Sec. 27, T11 N, R15E, UM At top of productive interval 1709' SNL, 1375' WEL, Sec. 34, T11N, R15E, UM At effective depth 1745' SNL, 1423' WEL, Sec. 34, T11N, R15E, UM At total depth 1759' SNL, 1444' WEL, Sec. 34, T11N, R15E, UM Exploratory Stratigraphic 7. Unit or Property service Prudhoe Bay Unit 8. Well number 4-07 ST1 9. Permit number/approval number 75-77 10. APl number 50 - 029-20189 "c~o 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9494 feet BKB 9036 feet ri yl, uln'u-s'measure-" Kick-off plug @8340-8515' MD, 210 cu ft CL "G" Effective depth: measured 9440 feet true vertical BKB 8989 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth l Conductor 54' 20" 24 sx AS 84' 84' Sudace 2671' 13-3/8" 3900 sx PF 2701' 2701' Intermediate 9353' 9-5/8" 1125 sx CL "G" 8342' 8009' Liner 1390' 7" 303 sx CL "G" 8074-9464' 7760-9010' Perforation depth: measured 9066-9070';9120-9130';9184-9190';9318-9341';9352-9369' true vertical 8663-8667' ;8708-8716' ;8764-8770' ;8878-8897' ;8907-8922'; Tubing (size, grade, and measured depth) 5-1/2",17#,13CR to 3002' MD;4-1/2",12.6#,13CR80 from 3002' to 8114' MD Packers and SSSV (type and measured depth) 9-5/8" TIW 'HB-BP' pkr @ 8019' MD;5-1/2" Camco BaI-O SSSV @ 2203' MD 13. Stimulation or cement squeeze summary i~"'~, ~"' .i',,~"! '::~; ? ':i'-' .... ~::~ ~ 14. Intervals treated(measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation Reoresent~ive Daily Averaoe Production orlniection Data OiI-Bbl Gas-Md W~e>Bbl Casing Pressure 772 2184 9120 - 1149W 3211 9684 Tubing Pressure 278 280 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 FS-2 Senior Engineer Form 10-404 Re;/06/15/88 SUBMIT IN DUPLICATE REPORT OF WELL OPERA ~NS DS 4-07 ST1 Perforating Operations' ARCO Alaska, Inc. perforated DS 4-07 ST1 at a selected interval in the Sadlerochit Sand of the Prudhoe Bay Unit on 9/19/93. The interval perforated was the following: 9066'- 9070' MD (Reference Log: HLS-BHCS dated 2/16/92). 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 9/19/93. RU perforating unit, pressure tested BOP's and lubricator to 2500 psi, okay. SI well, RIH, opened well to flow and perforated 9066'-9070' MD at i SPF, POOH, and confirmed all shots fired. (ref: HLS-BHCS of 2/16/92). Rigged down and secured well. RDC: 12/2/93 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-21-93 REFERENCE: /2-16A 9-25-93 SBT/GR/CCL I~c~-I Ill o Run ~?,-16A 9-26-93 ~~ (c~cb /0,~o-fotl 0 R~ 3-29 9-19-93 ~oducflon ~0o-q%9' R~ 4-1 9-23-93 C~ ~l ;~-~9 R~ 4-4 9-17-93 Pe~ Record ~l~5o-l~ao R~ 4-7ST 9-19-93 Pe~Record ~o-gz~ R~ 4-8 9-23-93 ~j ~-qa 4-16 9-13-93 ~ ~tect/~.~"~l~e~/~a R~ ~-~b 9-5A 9-16-93 ~oducflon/s~,-m]~a~ R~ 9-29 9-15-93 ~ Detect~.~}~,~ R~ /9-35A 9-17-93 Pe~Record ~~11~ R~ ~9-35A 9-18-93 Pe~ Record %la-)lo?¢~ R~ %9-35A 9- ! 9-93 ~od ~oDle I s~ ~)~~2 R~ 9-42 9-14-93 ~od ~offie ~ ¢~;.l~c'~/~ ~ ~0¢l~ 9-44 9-15-93 ~od /12-22 9-25-93 Jewe~ ]¢ffl cbc R~ k12-22 9-26-93 Pe~Record 5q0e-G%o R~ 12-30 9-22-93 POG~ ~t/TBG ~ch R~ ¢-~3 14-4 9-24-93 Pe~ Record 1~350~t~5~ R~ 14-31 9-20-93 ~oducflon ~-q~o R~m 15-2 9-14-93 ~od ~offiel~i~lea R~ ~z-~ 15-18 9-21-93 B~er ~~ble Packer R~ ¢Z-a~ 16-29A ' 9-24-93 ~oducflon/~.~l~~~ R~ ~-2¢517-12 9-22-93 ~oducflon]~)~]~~~ ~55 18-25 9-20-93 ~od ~offie ~t~o~t~o R~ 1, 5" Atlas 1, 5" Atlas 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" ~ oc, ~0~aSch 1, 2" ~-lo~ Sch 1, l"&5" Sch 1, l"&5" Sch 1, 5" Sch 1, 5" , Sch 1, l',&5" .Sch 1, 5" ~s¢~'7 Sch 1, 5"1~16~¢1t~ Sch 1, 5'R~0~}~~- Sch 1, 5" Sch 1, 5" ~0-~Sch 1, 5" Sch 1, 5" Sch 1, 5" ~o~ Sch 1, 5" I ~-~oSch 1, 5" ~- ~z Sch 1, 5" 21~-~Ut Sch 1, 5" Sch Have A Nice Day! Sonya Wallace ATO- 1529 Please sign and return the attached copy as receipt of data. RECEIVED B / APPROVED__. Trans# 93118 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA # PtHLLIPS # LILLIAN TIULANA # EXXON # MOBIL Anchorage, Alaaka 99510 DATE: 9-17-93 2-3 8-24-93 2-8 8-27-93 2-12 8-28-93 2-16 8-27-93 3-9 8-21-93 13'15A 8-17-93 13-15A 8-28-93 4-7ST 8-22-93 4-24 8-25-93 4-26 8-22-93 4-39 8-23-93 ~:15A 8-19-93 15A 8-19-93 5-17A 8-26-93 ~:10 8-20-93 10 8-20-93 6-19 8-24-93 ~6-24 8-20-93 ~6-24 8-24-93 7-15 8-27-93 9-1 8-21-93 8-18-9a ~1-1A 8-19-93 14-32 8-21-93 17-14 8-25-93 Prod Proffiel~/~-~a~0 Prod Proffie/~l~a~~ Run Perf Record ~-1 TBG Cut Record Run Perf Record Perf Record ~s~z~-~z% Run Prod Profile Prod Proffie D-rtl Brat ~ Rl~n ~ ~lor R~ ~ B~t ~ P~ Record R~ ~od ~o~e ] ~'~l~~~ C~ ~0-~ R~m USIT ~lor Rim ~ml B~t ~ ~1R1 N~~n ~~ ~ln ~.1 B~t ~ Rim 1, 5" 1, 5" ~l~S~-~ Sch 1, 5" Sch 1, 5"~vs0-~ls~ Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5"~a~o-~ Sch 1, 5" I~o~o---Sch I~ 1, 5" I~ - Sch 1, 5" Sch 1, 5" ~--'- Sch 1, 5"~ch' 1, 5" s~-zo~ Sch~%~- 1, 5" ~! :~-~e- ~ch 1, 2" ~ ~ m%.o- SCh 1, 5" ~aa- Sch~-~ 1, 5" ~ ~ ao--- Sch % 1, 5" Sch 1, 5" ~oo --- Sch~l~i~ 1, 5" ]o~.-~-- Sch 1, 5" t~zoo-- Sch 1, 5" ~ ~ 2.o~--. Sch ~ Prod Proflle~l'~elc~e~ Run 1, l"&5" Please sign and return the attached copy as r~ceipt of dat~ RECEIVED BY_~~._~ Have A Nice Dayl Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON # BPX # STATE OF AL&SKA 1, 5"lt~a~--- Sch~¢7~ Sch The correct APl# for 4-24 is 50-029-21508-00. The APl# for 5-17A is 50-029-20271-01. ARCO .~t,~-~ka, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 1-3 ~0 ~ 6-4-93 Perf Record Run 1, 5" 1-11 7~' ~f~ 6-4-93 Perf Record R-n 1, 5" 1-12 ~ 6-4-93 Perf Record Run 1, 5" 4-7ST ~ ~ 5-30-93 CBT Run 1, 5" 4-7ST A~ / 5-30-93 TDTP (Borax] Run 1, 5" 4-7ST ~'~,/5-31-93 Perf Record Run 1, 5" 4-18 ~ ~.~ 5-31-93 Perf Record Run 1, 5" 5-14 ~~ 6-2-93 TBG Puncher Record o Run 1, 5" 5-19~.~ 6-5-93 Production Log Run 1, 5" 13-3 ~'.~6-1-93 Le~_k Detect R,_n 1, 1"&5" 13-8~t,'_ 6-3-93 Gas Li/t/~Detect Run 1, 1"&5" 14-8~'~'~ 6-3-93 Leak Detect Run 1, 2" 16-30 a ~ 6-1-93 Inj Profile Run 1, 5" 16-30 · - 6-1-93 TDTP (Borax) Run 1, 5" Please sign s~d ret~t~ atta~/~dzcopy asff___eceipt of dat~ .c I ~veANice~ / / ECEIVED ~n~W~ce dO[ ~ 0 1 P~ROVED s~ 93~2 ATO- 1529 ~a;~ 0il & Gas Cons. Commission' .... Ancbomge # CENTRAL FILES # CHEVRON D&M # CLINT CHAPMAN # EXXON MARATHON # MOBIL # Pm~.~.~S PB WELL FILES R&D # BPI[ # STATE OF ALASKA TEXACO $ch $ch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch STATE OF ALASKA ALASKA '_ AND GAS CONSERVATION CC 'MISSION REPORT""uF SUNDRY WELL OP"L,,{ATIONS 1. Operations performed' Operation shutdown Stimulate ~ Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB) Development X 51' RKB feet ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 service Prudhoe Bay Unit 4. Location of welt at surface 8. Well number 4-07 ST1 90' NSL, 593' WEL, Sec. 27, T11N, R15E, UM ~'~ E C ~tV '~ D 9. Permit number/approval number At top of productive interval 1709' SNL, 1375' WEL, Sec. 34, T11N, R15E, UM 75-77 At effective depth ,:.l U L. 2 71993 10. APl number 1745' SNL, 1423' WEL, Sec. 34, T11 N, R15E, UM Alas,ka 0il & Gas Cons. C0mmissi0r 50 -029-20189 At total depth Anchorage 11. Field/Pool 1759' SNL, 1444' WEL, Sec. 34, T11N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9494 feet Plugs(measured)210Kick-offcu ftPlUgcL "G"@8340'8515' MD, true vertical BKB 9036 feet Effective depth: measured 9440 feet true vertical BKB 8989 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth~ Conductor 54' 20" 24 sx AS 84' 84' Surface 2671' 13-3/8" 3900 sx PF 2701' 2701' Intermediate 9353' 9-5/8" 1125 sx CL "G" 9373' 8931' Liner 1390' 7" 303 sx CL "G" 8074-9464' 7760-9010' Perforation depth: measured 9120-9130';9318-9341 ';9352-9369' true vertical 8708-8716';8878-8897';8907-8922'; Tubing (size, grade, and measured depth) 5-1/2",17#,13CR to 3002' MD;4-1/2",12.6#,13CR80 from 3002' to 8114' MD Packers and SSSV (type and measured depth) 9-5/8" TIW 'HE-BP' pkr @ 8019' MD;5-1/2" Camco BaI-O SSSV @ 2203' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 470 84 5270 262 Subsequent to operation 2390 455 3250 277 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ (,~?,~,,~/vv~ Title FS-2 Senior Engineer Date ~,,/2~,/~ ~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE~ .lILY REPORT OF WELL OPER IONS DS 4-07 ST1 Perforating Operations: ARCO Alaska, Inc. perforated DS 4-07 ST1 at a selected interval in the Sadlerochit Sand of the Prudhoe Bay Unit on 3/8/93. The interval perforated was the following: 9120' - 9130' MD (Reference Log: AWS-BHCS dated 2/16/92). 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 3/8/93. RU perforating unit, pressure tested BOP's and lubricator to 3500 psi, okay. RIH and perforated 9120'-9130" MD at 4 SPF, POOH, and confirmed all shots fired. (ref: AWS-BHCS of 2/16/92). Rigged down and secured well. RDC: 7/1/93 T- ) ~,~ 4 -- C~ Well Work Log Date .~ Code ,.,'tivity DS / Well Descn ,p~3n of Wor~, Tbg/TT Sizes. SSSV Pulled SSSV Pulled Ser. No. SSSV Ran SSSV Ran Set. No. SSSV, Nippje Career Pulled (assoc. wi Kvalve) Carrier Ser. No. Carder Ran (assoc. wi Kvalve) Carrier Ser. No. Min. Rest./Depth SSSV Remarl~ / Tubular Casing Problems Cost Estimate $ $ $ $ $ Time .. l~ Ent~ , - STATE OF ALASKA ALASKA AND GAS CONSERVATION CO IlSSION REPORT OF SUNDRY WELL OPErIATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 90' NSL, 593' WEL, Sec. 27, T11 N, R1 SE, UM At top of productive interval 1709' SNL, 1375' WEL, Sec. 34, T11N, R15E, UM At effective depth 1745' SNL, 1423' WEL, Sec. 34, T11N, R15E, UM At total depth 1759' SNL, 1444' WEL, Sec. 34, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 51' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-07 ST1 JUL 2 1993 · Alaska 0il & Gas Oor~s. r.;0mm~ss~O ,Anchorage 9. Permit number/approval number 75-77 10. APl number 50 - 029-20189 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9494 feet BKB 9036 feet Effective depth: measured 9440 feet true vertical BKB 8989 feet Kick-off plug @8340-8515' MD, Plugs(measured) 210 cuft CL "G" ORIGINAl_ Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 54' 20" 24 sx AS 84' 84' Sudace 2671' 13-3/8" 3900 sx PF 2701' 2701' Intermediate 9353' 9-5/8" 1125 sx CL "G" 9373' 8931' Liner 1390' 7" 303 sx CL "G" 8074-9464' 7760-9010' Perforation depth: measured 9120-9130';9184-9190';9318-9341';9352-9369' true vertical 8708-8716';8763-8768';8878-8897';8907-8922'; Tubing (size, grade, and measured depth) 5-1/2",17#,13CR to 3002' MD;4-1/2",12.6#,13CR80 from 3002' to 8i 14' MD Packers and SSSV (type and measured depth) 9-5/8" TIW 'HB-BP' pkr @ 8019' MD;5-1/2" Camco BaI-O SSSV @ 2203' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 283 74 6981 936-~'''' 404 9383 Tubing Pressure 293 311 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 , ('~, ,'4,~, ~ ~.~'~c:~..~: ~ ,~ ,., v,,, ........ Title FS-2 Senior Engineer t ' ..¢ Form 10-404 Rev 06/15/88 '~';, Date ~, ,,..,/ '.f.,, SUBMIT IN DUPLICATE . ,ILY REPORT OF WELL OPER,, .ON$ DS 4-07 ST1 Perforating Operations: ARCO Alaska, Inc. perforated DS 4-07 ST1 at a selected interval in the Sadlerochit Sand of the Prudhoe Bay Unit on 5/31/93. The interval perforated was the following: 9184' - 9190' MD (Reference Log: AWS-BHCS dated 2/16/92). 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 5/31/93. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. RIH and perforated 9184'-9190' MD at 2 SPF, POOH, and confirmed all shots fired. (ref: AWS-BHCS of 2/16/92). Rigged down and secured well. RDC: 7/9/93 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARC~ CASED HOLE FINALS 3-7-93 Perf Record Run 1, ~' Sch 2-27-93 CNL Run 4, ~' Sch 2-27-93 CNL Run 2, ~' Sch 3-5-93 Dual Burst TDTP (Borax) Run 1,/Y' Sch 3-1-93 CNL Run 2, fY' Sch 3-1-93 CNL Run 2, [Y' Sch 3-6-93 Dual Burst TDTP Run 1, tY' Sch 2-28-93 CNL Run 2, ~' Sch 2-25-93 Dual Burst TDTP (Borax) Run 1, ~' Sch 3-7-93 Collar (Jet TBG Cutter) Run 1, ~' Atlas 3-3-93 Vertilog l~m 1, [~' Atlas 3-9-93 TBG Taft Punch Run 1, [Y' Sch 3-2-93 Perf Recc~d l~_m 1, 5~'. Sch 2-25-93 CCL (TBG Cutter) 'Run 1, lY' Atlas 3-9-93 Perf/GR/CCL mm 1, ~' Sch 2-25-93 SI~L/GR/CCL Run 1, [Y' Atlas 2-24-93 S/]L/GR/C(X, Run 1, ~' Atlas Please .sign and return the attached copy as receipt of data. RECEIVED B / -- Have A Nice Day! Sonya Wallace APPROVED ATO-1529 Trans# 9304~~- ..... # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D ' # BPX # STATE OF ALASKA TEXACO The correct APl# for 1-31 is 50-029-21626-00. The correct wen name for this log is 16-'4. ARCO Alaska, Inc. P.O.Box 1OO360 Anchorage, Alaska 99510 DATE: 10-16-92 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS j..9/.g.$ 1-33 g~-~/Z~ 7-31-92 ~'/'/ CNL/GR Run I Job~5588 Atlas 4-78T?~--?? 5-84~ ~/ FDK-100 (Barax~ Run ! Job~5515A)~ Atlas Please sign and return t~e attached copy as receipt of data. RECEIVED BY_ _ . Have A Nice Day! Sonya Wallace APPROVED ATO-~529 Trans# 92239 # CENTRAL FILES (CH) CHEVRON D&M BOB OCANAS (OH/GCT) # EXXON MARATHON MOBIL # PHILLIPS PB WELL FILES R&D #BPX # STATE OF ~ASKA TEXACO RECEIVED NOV 2 3 1992 Alaska Oil & Gas Cons. Commission Anchorage Ho A L L I~UR TON GGING SERVICES,/NC. O A Halliburton Company September 23, 1992 To Whom It May Concern: Please disregard previously delivered L.I.S. tapes and Prints that are not marked "CORRECTED" for ARCO ALASKA INC. - DS 04-07 (PSGT COMPUTED RESULTS only) dated 12-03-91. ,,~ / ~ The new L.I.S. tapes and Prints have been recomputed using an updated Software Analysis routine. We apologize for any inconvenience. ..~~~ards, David w. Douglas Anchorage Computing Center / RECEiVED OCT 1 5 1992 Alaska Oil & Gas Cons. Commission Anchorage Post Office Box 230450 · Anchorage, Alaska 99523 ° 907/261-7730 · FAX 907/562-1612 ARCO Alaska. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-9-92 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS 1-9 ~ 5 ~//~ 7-26-92 1-15//;q 7-26-92 4-7 ~/q~ 12-3-91 5-12 ~ ~/~ 7-30-92 7-16~q/~ 2-17-92 7-34 4X~ 2-18-92 9-36~~ 2-29-92 15-3 ~Y V/~ 5-31-92 18-~ ~~7-28-92 CNL/GR R~m I Job#5583 CNL/GR R~m I Job#5582 PSGT R-n I Job#L73957-4 CNL/GR Run I Job#5587 CNT R~_m I Job#L73988-2 CNT R!~n I Job#L73989-3 PSGT R~m I Job#L75976-X CNTH Run I Job#92345 CNL/GR R._n I Job#5584 Please sign and return the attached copy as receipt of data. RECEIVED B Have A Nice Day[ Sonya Wallace AT0-1529 APPROVED_ffff~___ Trans# 92232 Atlas Aths HI~ Atlas HLS ItLS HI~ Sch Aths # CENTRAL FILES (CH) CHEVRON D&M BOB OCANAS (OH/GCT) # EXXON MARATHON MOBIL Thi~ is a corrected tape copy. # PHILLIPS PB WELL FILF~ R&D # BPX # STATE OF ALASKA TEXACO RECEIVED OCT 15 1992 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-9-92 REFERENCE: ARCO CASED HOLE FINALS ~,.~'.-~..~_ 4-7 · ~.,._'~..~ 4-~1 ~ ~~~ 2og 2-29-92 2-29-92 12-3-91 PSG CORRECTED COPY R,m 1, 5" 4-23-92 Perf Record Run 1, 5" 9-29-92 CCL (Per/) R,_m 1, 5" 9-22-92 CCL (Peri) Run 1, 5" 2-17-92 DSN Run 1o 5" 2-18-92 DSN Run 1, 5" 9-21-92 CCL (Peri) Run 10 5" 9-21-92 CCL (Peri) ~ Run 1, 5" PSG R,_n 1, 5" PSG ~ Run 1, 5" Please sign and return the~attacl;~ed copy as receipt of data. RECEIVED " Have A Nice D/fly! 0CT ] 5 1992 APPROVED -///// Sonya Wallace _~_z~_. AT0-1529 Alaska 0il & Oas Cons. ¢0mn~issidllrans# 9222~~' ...... Anchorage # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PttlLLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO ALA,_,.,A OIL AND GAS CONSERVATION COMMISS._., REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging~ Pull tubing__ Alter casing X Repair well Perforate~ Other x Sidetrack 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 90' NSL, 593' WEL, SEC. 27, T11N, R15E At top of productive interval 1709'SNL, 1375'WEL, SEC. 34, T11N, R15E At effective depth 1745' SNL, 1423' WEL, SEC. 34, T11N, R15E At total depth 1759'SNL, 1444' WEL, SEC. 34, T11N, R15E 12. Present well condition summary Total depth: measured true vertical 9494 feet BKB 9036 feet 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 51'feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 4-7 ST 9. Permit number/approval number 75-77/Conservation order 258 10. APl number 50- 029-20189 11. Field/Pool Prudhoe Bay Field/Oil Pool Plugs (measured) Kick-off plug 8340'-8515'MD, 210 cuft Class "G" Cement Effective depth: measured true vertical 9440 feet BKB 8989 feet Junk(measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth 54' 20" 2671' 13-3/8" 9353' 9-5/8" 1390' 7" 240 sx Arcticset 84' 84' 3900 sx Permafrost 2701' 2701' 1125 sx Class G 9373' 8931' 303 sx Class "G" 80 74 '-9464' 7760 '-901 O' 9318'-9341~9352'-9369' true vertical 8883'-8903',8913'-8927' Tubing (size, grade, and measured depth) 5-1/2", 17#, 13CR to 3002; 4-1/2", 12.6#, 13CR80 from, 3002' to 8114'MD Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. 9-5/8" TIW 'HB-BP' Packer @8019'MD, 5-1/2" Camco 'Bal-O' SSS V @ 2203' MAY 2 6 992 A!aska.0il & Gas Cons. Prior to well operation Representative Daily Average Production or Injection Data ' nc ora Q OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 17. I hereby certify tha~,the foreow/~ing is true and correct Signed (t/I-'/ .~~, Form 10-404 Rev 66/15/8~1// ,) 16. Status of well classification as: Oil x Gas__ Suspended to the best of my knowledge. Title Drillin~l En~tineer Supervisor Service Date SUBMIT IN DUPLICATE ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY UNIT DS 4-7 ST NABORS 2ES KILL: 7.5 NDNU: 1.5 02/06/92 ( 1) INSTALL BOPE. MW: 8.5 Seawater TD: 9400 MOVE RIG F/ DS 14-5 TO DS 4-7. ACCEPT RIG @ 21:00 HRS, PB: 8645 2/5/92. REMOVE BPV. MONITOR WELL. CIRC OUT F/P. INSTALL SUPV:LAP\ BPV. N/D TREE. N/U BOPE. DAILY:S41,845 CUM:$41,845 ETD:SO EFC:$1,617,845 NDNU: 10.0 PTBG: 13.5 LPRF: 0.5 02/07/92 ( 2) PREP TO RUN SCHLUMBERGER USI G MW: 8.5 Seawater TD: 9400 FINISHED INSTALLED 13-5/8 BOP STACK.. TESTED BOPE. CBU. PB: 8645 L/D 5-1/2 TUBING. RU CASING INSPECTION LOG. SUPV:LAP\ DAILY:S109,602 CUM:$151,447 ETD:SO EFC:$1,727,447 NDNU: 5.0 LPRF: 10.0 02/08/92 ( 3) DISPLACING SEAWTR TO MUD MW: 8.5 Seawater TD: 9400 LOGGED FROM 8550 - 100' TESTED 9-5/8 MANDREL - FAILED. PB: 8645 REPLACED PACK-OFF & TESTED - OK. P/U BHA %1 & 4-1/2 DP. SUPV:LAP\ RIH. DAILY:S75,974 CUM:$227,421 ETD:SO EFC:$1,803,421 PROB: 0.5 PROB CODE: EFC 02/09/92 ( 4) MILLING SECTION FROM 9-5/8 CAG MW: 8.5 Seawater TD: 9400 REPAIRED BROKEN MUD LINE TO HOPPER. DISPLACED SEAWATER WITH PB: 8645 LSND DRILLING MUD. SPOTTED PILL. L/D DP. LOCATED CASING SUPV:LAP\ CONNECTION AT 8329' MILLING SECTION AT 8335'. CIRCULATED. MILLED FROM 8335' TO 8395' DAILY:S40,372 CUM:$267,7~3 ETD:SO EFC:$1,843,793 02/10/92 ( 5) TD: 9400 PB: 8645 SUPV:LAP\ CLEANING BOP. PREPARE TO KICA MW: 9.6 Seawater FINISHED MILLING SECTION FROM 9-5/8 CASING. POH. RIH W/4-1/2 DP. RIH. REVERSE CIRCULATE. PUMPED 5 BBL SPACER, 37.4 BBL 17 PPG CLASS G + .05 GPG D-47 + 1% BWOC D-65 + .1 GPS D135 + .5 BWOC. POH. DAILY:S79,450 CUM:$347,243 ETD:SO EFC:$1,923,243 SlP1 DRIL: 5.0 TRIP: 8.0 RIGS: 3.0 PROB: 8.0 PROB CODE: EFS 02/11/92 ( 6) RIH W/NEW MOTOR MW: 9.6 VIS: 60 TD: 8340' (8340) NOTE: EST CUM COST SHOULD BE $392,997.00. P/U PDM & MWD BHA SUPV:LAP %2 AND RIH. DRILLED CEMENT. CIRCULATED. POOH. MOTOR HOLE ANGLE:28 30 FAILURE. DAILY:S45,754 CUM:$392,997 ETD:SO EFC:$1,968,997 SlP1 PROB: 24.0 PROB CODE: EFS 02/12/92 ( 7) EST TOP CMT PLUG 8100' MW: 9.5 VIS: 71 TD: 8335' ( 0) CHANGE OUT MUD MOTOR. RIH. CBU. POOH. RIH. CIRC & SUPV:DW CONDITION. PUMP 130SX CLASS S CEMENT SLURRY. PULL UP TO HOLE ANGLE:28 30 7850 SQUEEZE DOWN. CBU. POOH. P/U BHA#2 RAN INTO CSG STUB -- SET NEW KICKOFF PLUG. DAILY:S56,902 CUM:$449,899 ETD:SO EFC:$2,025,899 RECE VF.D 6 t992 Gas Cons. Commissio Anchorage ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY UNIT DS 4-7 ST NABORS 2ES S1P1 DRIL: 12.0 PROB: 12.0 PROB CODE: EFS 02/13/92 ( 8) CHANGE OUT MUD MW: 9.6 VIS: 35 TD: 8435' ( 100) RIH W/BHA ~2 TO 8050' TAG CEMENT AT 8099' . SLIDE DRILL SUPV:DW FROM 8342 - 8415'. ROTATE FROM 8415 - 8435'. CHANGE OVER TO HOLE ANGLE:28 30 NEW MUD. DAILY:S47,910 CUM:$497,809 ETD:SO EFC:$2,073,809 SlP1 DRIL: 12.5 TRIP: 1.0 CIRC: 1.5 PROB: 9.0 PROB CODE: SURV 02/14/92 ( 9) RIH W/ BHA #3. MW: 9.5 VIS: 39 TD: 8747' ( 312) CHANGE MUD. REAM THRU KICKOFF F/ 8342'-8435' DYNADLRG F/ SUPV:DW 8342'-8747'. CBU. POOH. CHANGE MWD. RIH W/'BIT. NOTE: HOLE ANGLE:28 30 CUMM COST SHOULD BE $565,479. DAILY:S67,670 CUM:$565,479 ETD:SO EFC:$2,141,479 SlP1 DRIL: 20.0 SURV: 1.0 RIGS: 1.0 PROB: 2.0 PROB CODE: SURV 02/15/92 (10) POOH F/ROTARY BHA MW: 9.5 VIS: 40 TD: 9064' ( 317) NOTE: CUM COST = 619,329 RIH. DYNA DRILL TO 9064' POOH. SUPV:DW L/D DYNA-DRILLo HOLE ANGLE:28 30 DAILY:S53,850 CUM:$619,329 ETD:SO EFC:$2,195,329 S1P1 DRIL: 14.5 TRIP: 8.0 CIRC: 1.5 02/16/92 (11) DRILLING 8-1/2 HOLE MW: 9.5 VIS: 29 TD: 9400' ( 336) NOTE: CUM COST = 667,266. POOH. RIH TO 8902'. DRILLING SUPV:DW 8-1/2 HOLE TO 9400' HOLE ANGLE:28 30 DAILY:S47,936 CUM:$667,265 ETD:SO EFC:$2,243,265 SlP1 DRIL: 8.0 TRIP: 4.0 SURV: 0.5 CIRC: 2.5 EVAL: 6.5 02/17/92 (12) E-LOG CBIL-GR MW: 9.6 VIS: 37 TD: 9494' ( 94) NOTE: CUM COST = 701,647. DRILLING 8-1/2 HOLE TO 9494' SUPV:DW SHORT TRIP TO 9-5/8 CASING SHOE AT 8335'. CIRC. POOH HOLE ANGLE:28 30 F/E-LOGS. RUN LOG 9465 - 8335'. (HRI/CNL/GR LOG). LOG CBIL/GR LOG ON SEPARATE AFE %3B0186. DAILY:S34,382 CUM:$701,647 ETD:SO EFC:$2,277,647 SlP1 TRIP: 7.5 RIGS: 0.5 CIRC: 2.5 CASG: 8.0 BOPE: 2.0 02/18/92 (13) RUN 7" LINER MW: 9.7 VIS: 40 TD: 9494' ( 0) NOTE: CUM COST = 838,882 CONTINUE CBIL E-LOG. RIH W/RR SUPV:DW 8.5 BIT TO 5697' RIH W/BHA%4 TO 9494. CIRC & CONDITION HOLE ANGLE:28 30 POOH. L/D 4-1/2' AND BHA %4. R/U 7" CHROME LINER. CIRC. RIH WI/7" LINER ON 4-1/2 DP. DAILY:S137,235 CUM:$838,882 ETD:SO EFC:$2,414,882 RECEIVED ~laska Oil & Gas Cons. Commission Anchorag~ ACTIVITY SUM/V/ARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY UNIT DS 4-7 ST NABORS 2ES COUT: 8.0 RCSG: 16.0 02/19/92 (14) DISPLACING TO FSW MW: 9.6 Seawater TD: 9494 NOTE: CUM COST $959,504. RIH W/7" LINER. TAGGED BOTTOM AT PB: 9440 9486'. CIRCULATED. PUMPTED 303 SKS CEMENT CLASS G 15.8 SUPV:DW PPG. SET LINER HANGER WITH SHOE AT 9486' REV. CIRC. POOH. TESTED BOPS. RIH TO 8050'. TOP OF LINER AT 8074' RIH TO 9396'. CBU. RECIPROCATED DISPLACING TO FSW. DAILY:S120,622 CUM:$959,504 ETD:SO EFC:$2,535,504 COUT: 2.0 RCMP: 22.0 02/20/92 (15) RIH WITH 4.5 - 5.5 COMPLETION MW: 9.6 Seawater TD: 9494 POOH. L/D 4-1/2 DP. R/U TO RUN 13CR80 COMPLETION. RIH PB: 9440 W/CHROME TUBING. SUPV:DW DAILY:S26,132 CUM:$985,636 ETD:SO EFC:$2,561,636 NDNU: 3.0 RCMP: 16.5 OTHR: 0.5 PROB: 2.0 PROB CODE: WH 02/21/92 (16) RIG RELEASED MW: 9.6 Seawater TD: 9494 CONTINUED TO RIH W/4.5 CHROME COMPLETION. PUMPED CRUDE DOWN PB: 9440 TUBING.SET PACKER RELEASED RIG 0400 HRS. 2/21/92. MOVING TO SUPV:DW DS 1-5. DAILY:S332,186 CUM:$1,317,822 ETD:SO EFC:$2,893,822 SPERRY-SUN DRILLING SERVI~S ANCHORAGE ALASKA PAGE PBU/4-07 ST 50-029-20189 0.00 9065.00 COMPUTATION DATE: 021992 DATE OF SURVEY: 021592 MWD SURVEY JOB NUMBER: AK-MD-920209 KELLY BUSHING ELEV. = 51.00 OPERATOR: ARCO ALASKA FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST SECT. 8325 7993.00 79~2.00 20 23 S 26.30 W .00 1536.008 439.00W 1589.91 8723 8362.25 831'1.25 24 53 S 65.40 W 3.87 1633.658 546.56W 1720,23 8817 8446.72 8395.72 27 12 S 56.90 W 4.66 1653.638 582.57W 1752.04 89tl 8529.45 8478.45 29 30 S 53.70 W 2.93 1679.078 619.23W 1789.16 9006 8611.59 8560.59 30 47 S 52.50 W 1.51 1707.738 657.38W 1829.82 9065 8662.27 8611.27 30 47 S 52.50 W .00 1726.128 6'81.34W 1855.72 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1855.72 FEET AT SOUTH 21 DEG. 32 MIN. WEST AT MD - 9065 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ,ALONG 201.54 DEG. Alaska Oil & Gss Cons. 'Anchorage SPERRY-SUN DRZLLZNG SERVZCES ANCHORAGE ALASKA PAGE 2 PBU/4-07 ST 50-029-20189 0.00 9065.00 CONPUTATZON DATE: 021992 DATE OF SURVEY: 021592 JOB NUNBER: AK-ND-920209 KELLY BUSHZNG ELEV. = 51.00 OPERATOR: ARCO ALASKA FT. ZNTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA NEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDZNATES NORTH/SOUTH EAST/WEST HD-TVD V E,RT'[' CA L DTFFERENCE CORRECTTON 8325 7993.00 7942.00 1536.00 S 439.00 W 9065 8662.27 8611.27 1726.12 S 681.34 W .... 00 402.73 70.73 THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF HZNZNUN CURVATURE NETHOD. SPERRY-SUN DRILLING SERVZuES ANCHORAGE ALASKA PAGE 3 PBU/4-07 ST 50-029-20189 0.00 9065.00 CONPUTATZON DATE' 021992 DATE OF SURVEY' 021592 JOB NUHBER' AK-ND-920209 KELLY BUSHING ELEV. - 51.00 OPERATOR- ARCO ALASKA FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE HEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTTCAL RECTANGULAR COORDINATES DEPTH NORTH/SOUTH EAST/WEST DIFF ND-TVD VERTICAL ERENCE ,CORRECTION 8o:5 7993.00 7942.00 1536.00 S 439.00 W 332.00 8386 8051.00 8000.00 1554.71 S 449.70 W 335.88 3.88 8493 8151.00 Si00.00 1584.06 S 473.51 W 342.81 6.93 8601 825t.00 8200.00 1609.68 S 504.15 W 350.52 7.71 3710 8351.00 8300.00 1631.44 S 541.89 W 359.62 9.10 8821 8451.00 8400.00 1654.86 S 584.42 W 370.82 11.20 8935 8551.00 8500.00 1686.29 S 629.06 W 384.76 13.95 9065 8662.27 8611.27 1726.12 S 681.34 W 402.73 17.97 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT ND ('FROM' MZNZNUM CUR. VATURE) POINTS /C ARCO Alaska, Inc. P.O.Box 100360 Anchorage, .Al~sk~ 99510 DATE: 5-15-92 REFERENCE: ?~._~ 4-7ST ?z-~' 4-s4~ 17-3 OWDW-NW vo-" 'z..37 OWDW-SE · o -- Z3 ~ OWDW-SW ARCO CASED HOLE FINALS 5-8-92 PD K- I OO I C, R i ~ i~3orax) 5-2-92 InJ Prof/Caliper 5-2-92 InJ Profile 4-30-92 Jewelry 5-2-92 Prod Profile 5-9~92 PDK-100/GR/CCL (Borax) 4-29-92 Prod Profile 5-3-92 PITS 5-1-92 PITS 5-2-92 PITS 5,S-92 CCL ~'er~ Please sign and return the attached copy as receipt of data. RECEIVED BY Have A Nice Day! ~'IA'Y 2 '1 '199~ Rim 1, [~' Rml 1, Run 1, Rim 1, Run 1, Run 1, Run 1, Sonya Wallace APPROVED AT0-1529 Alaska '.0ii a Gas Cons. Commissl,._~,,~,,s# 92 10 1 kr, chorag~ # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PtHL~ PB WELL FH, ES R&D # BPX # STATE OF ALASKA TEXACO AtLas Camco Camco Camco Camco Atlas Atlas Camco Camco Camco Camco Atlas STATE OF ALASKA :i"'~i '~',"~ ~'~*"~ ALASKA:, AND GAS CONSERVATION C(,: vllSSlON '~'' ~'''~'' REPORT'uF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well X Perforate 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 90' FSL, 593' FEL, Sec. 27, T11 N, R15E At top of productive interval 1585' FNL, 1180' FEL, Sec. 34, T11N, R15E At effective depth At total depth 1720' FNL, 1190' FEL, Sec. 34, T11N, R15E 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development Exploratory Stratigraphic Service RECE ¥E.D Alaska 0ii & Gas 6or~s, CornCss'~°~ ~.n¢0rage 6. Datum of elevation(DF or KB) 51' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-7 9. Permit number/approval number 75-77/91-386 10. APl number 50 - 029-20189 11. Field/Pool Prudhoe Bay Oil Pool 9400' feet 9017' feet Plugs(measured) Cement Plug @ 8783' MD. feet Effective depth: measured 9328' feet true vertical 8949' feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 54' 20" 240 sx Arcticset 84' Surface 2671' 13-3/8" 3900 sx Permafrost 2701' Production 9353' 9-5/8" 1125 sx Class G 9373' True vertical depth 84' 2701' 8992' Perforation depth: measured All pedorations squeezed and covered by cement plug. true vertical All perforations squeezed and covered by cement plug. Tubing (size, grade, and measured depth) 5-1/2", L-80, 17#, PCT @ 8737' MD Packers and SSSV (type and measured depth) 9-5/8" BeT Packer @ 8625' MD~ Camco Bal-0, SSSV @ 2223' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Shut-In Sidetrack Tubing Pressure 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 Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 826/8 LLG cc: SW, JWP ~ 4-07 DESCRIPTION OF WORK COMPLETED PRE SIDETRACK CTU CEMENT PLUG 12/9/91: A CTU Cement Plug was pumped to Plug & Abandon the wellbore prior to Sidetracking as follows: MIRU CTU & PT equipment. Loaded wellbore w/Seawater, then RIH w/CT & pumped 5 bbls Neat Class 'G' cement, followed by 91 bbls Class 'G' cement w/aggregate, to place a cement plug over the open perforations at: 8968' MD: 1 foot (Z 3) 8981' MD: 1 foot (Z3) 8990 - 9014' MD (Z3) 9250 - 9266' MD (Z1B) 9272 - 9290' MD (Z1A) Ref. Log: BHCS 1/28/76. Could not attain squeeze pressure above 20 psi. Rigged down, leaving cement plug in hole. I 2/1 0/91: RIH & tagged the top of the cement plug at 8782' MD. I 2/1 2/91: Pressure tested the cement plug to 1500 psi OK. I 2/1 4/91: RIH & retagged the top of the cement plug at 8783' MD. 12/18/91: RIH & set a Bridge Plug in the 5-1/2" tubing at 8645' MD. Left the wellbore Plugged & Abandoned w/Bridge Plug for Sidetracking. The Sidetrack was performed from the rig 2/5/92 - 2/21/92, and is reported under a separate Report Sundry. RECEIV[[ Alaska OJj & Gas Cons. Anchora~je ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS 3-s ?I- ~'~ 3-35 ?/-~' ~ 4-3 4-3 ?J'- ~ 4-7ST ??-3~ 5-14 ~z ~ 6-21 -43 ~,/_~,,c~, II-3A gl-/zz~' 14-32 ff~/- -~/~17-11 Please sign and return the attached copy as receipt of data.~ ~ 2-19-92 GR/Perf Run 1, 5" HLS 2-25-92 Collar Run 1, 5" HI~ 2-21-92 CCL/Perf Rn_n_ 1, 5" HI~ 2-9-92 Perf Record Rl_m 1, 5" HI~ 3-2-92 Perf Record Rim 1, 5" HLS 3-2-92 Perf Record Run 1, 5" HI~ 2-11-92 Perf Record Run 1, 5" HL~ 2-22-92 CCL/Perf R~m 1, 5" HLS 2-12-92 Perf Run 1, 5" HLS 2-23-92 CCL/Perf R~_m 1, 5" HLS 2-28-92 Perf Record Run 1, 5" HLS 2-28-92 Perf Record R~m 1, 5" HLS RECEIVED BY Have A Nice Day! Sonya Wallace ATO-1529 APPROVED Trans# 9208~ # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO * The correct APl# for 11-3A is 50-029-20666-01. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS 1-15 2-9-92 Prod Prof Run 1, 5" Camco 3-7 2-27-92 InJ Profile Run 1, 5" Camco 4-7ST 3-1-92 Jewelry Run 1, 5" Camco 4-7ST 3-13-92 Prod Prof Run 1, 5" Camco 4-9 ?~'3 ~ 3-15-92 InJ Prof Run 1, 5" Camco 4-15 3-1-92 InJ Prof R~n 1, 5" Camco 4-42 3-1-92 PITS R~m 1, 5" Camco 5-12 ??-/~/ 2-11-92 Prod Prof Run 1, 5" Camco 6-13 ~o~)~ 2-13-92 Jewelry Run 1, 5" Camco 6-17 ~z-? ° 2-11-92 Prod Prof Rim 1, 5" Camco 7-1 2-18-92 GR/CCL/Jewelry Run 1, 5" Camco 7-1 2-18-92 Prod Prof Run 1, 5" Camco 9-1 2-28-92 Prod Prof Run 1, 5" Camco 9-2 2-8-92 Prod Prof R~m 1, 5" Camco 9-18 3-14-92 InJ Prof Run l, 5" Camco 9-27 2-7-92 Prod Prof Run 1, 5" Camco 9-31 2-8-92 Prod Prof Run 1, 5" Camco Please sign and return the attached copy as receipt of data. RECEIVED BY ~_~ Have A Nice Day! AP P R 0 V E~sk~U~,..,,~. C'°~S' 6ommissio~ Sonya Wallace ATO- 1529 Trans# 9207~-~--~a~ / # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHIL~ PB WELL PILES R&D # BPX # STATE OF AI2~KA TEXACO The correct well name for this log is 4-7ST. ARCO Alask~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOI.F. FINALS * 1-5ST 3-23-92 ~l-t~ ? 2-26 3-10-92 f~-~ ~ ** 4-7ST 3-24-92 4-9 3-13-92 ? 4-12 3-13-92 ?/-~ 5-36 3-21-92 ? ~'-~ 14-7 3-26-92 PFC/em Perf Record MSI Carbon/Oxygen Perf Record Perf Record Prism Perf Record 1Ii16-24 3-9-92 Collar/Peri 6-24 3-9-92 Tubing Cutter 6-24 3-16-92 Diff. Temperature 6-24 3-16-92 Vertilog (?') 6-24 3-16-92 Vertilog (9 5/8") Run 1, 5" Atlas R~m 1, 5" Sch Run 1, 5" Atlas Ru_n 1, 5" Sch Ru_n 1, 5" Sch Rl~n 1, 5" AJ;]8S R!m 1, 5" Sch Rl~n 1, 5" ~ R~ 1, 5" ~ R~ 1, 5" ~ R~m 1, 5" ~ R~m 1, 5" ~ Pleasesignandreturn.t~_~c°pyasreceiptOfdata'R~CEl~/EDRECEIVED BY .__ Have A Nice Day! Sonya Wallace ATO-1529 Alaska Oi/xA Gas/Co~s. Commission APPR OVED_~~d_~ ~ Trans# 92077 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PIHL~ PB WELL FILF~ R&D # BPX # STATE OF ALASKA TEXACO The correct API# for 1-5ST is 50-029-20076-00. The correct well name for this log is 4-7ST. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO OPEN HOLE FINALS 4-7ST 4-7ST 4-7ST 4-7ST . 4-7ST 2-16-92 J SSTVD Run 1. l"&2" 2-16-92 ~HRI/DFL R~m 1, 2"&5" 2-16-92 /~ HRI/DFL (Reprocessed)R~n 1, 2"&5" 2-16-92 ~/HHCS Run 1, 2"&5" 2-16-92~DSN Run 1.2"&5" Please sign and return ti~e attached copy as receipt of data. RECEIVED Have A Nice Day! ,,',, _ ,] _~~ Sonya Wallace APraOVED ATO-152g Trans# 9205~-/- .... # CENTRAL FILF-S # CHEVRON #D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS # PB WELL FKF~ R&D # BPX # STATE OF ALASKA # TEXACO RECEIVED N~AR 1 2 1~92 Alaska Oil & Gas Cons. Commissio[~ Anchorage P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO CASED HOLE FINALS 4-7 2-7-92 USIT-~ment 4-7 ~ 5-6 ~/ 2-7-92 USIT-Corrosion 2-11-92 Collar-Perf ~ 9-44 ~ 2-12-92 Co11~_r-Perf ~> ** 11-3A / 2-9-92 CNL 8z~ t 13-25 ~ 2-22-92 CCL (Peri) ~ 14-5A ; 2-9-92 CNL 14-5A ~ 2-10-92 Collar-Perf 3~//~ 18-14 ~ 2-20-92 Dual Burst TDTP Color Run 2, 5" Run 2, 5" R~m 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" R~m 1, 5" Please sign and return the attached copy as receipt of datm RECEIVED BY ~~'~_~ ' Have A Nice Day~ Sonya Wallace AT0-1529 Sch Sch Atlas Sch Sch Sch # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL #PHILLIPS PB WELL FILF~ R&D #BPX # STATE OF ALASKA TEXACO ** The correct APl# for 11-3A is 50-029-20666-01. RECEIVED MAR 1 2. 1992_ Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 2-21-92 ARCO MAGNETIC TAPE(S) WITH LISTINGS 1-26-92 PDK- 100 R~m I Job# 102126 1-5-92 CNTD R~_m 2 Job#92018 1-5-92 CNTD Run 2 Job#92019 ~ ~_ 4-3 12-1-91 PSGT Run I Job#L73956-3 ~ ~ 7q 4-7 12-3-91 PSGT Run I Job#L73957-4 ~ / ~ 15-14 1-4-92 CNTD Run 3 Job#92020 Please sign and return the attached copy u receipt of datm RECEIVED BY ~_~ Have A Nice Dayt ' ED__//./~ Sonya Wallace APPR OV ATO- 1529 Trans# 92~-~-- Aths Sch Sch HI~ HLS Sch # CENTRAL FILES (CH) CHEVRON D&M DEDE SCHWARTZ (OH/GCT) # EXXON MARATHON MOBIL # PHILLIPS PB WET.T. FILES R&D # BPX # STATE OF ALASKA TEXACO RECEIVED MAR 1 2 1992 ~aska Oil & Gas Cons. Commission Anchora§e ARCO Alaska, Inc. P.O.Box 1/)0,380 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO DIRECTIONAL DATA ~f'- ~ ~ 4-7ST 2/8-17/92 MWD Directional Survey ~//- / ~'>-~i~'~ ~ ~.~ Zl~,l-,sz/92 ~ mx~onsi surly ~> ~/ z4-5~ 1/~4-3~ MWD Dh-ectionsl Survey Job#AL292D6 GLDDI Job~ 1291D47 GLDDI Job#AL192D5 GLDDI Please sign and return the attached .copy as receipt of data. RECEIVED BY ~~ Have A Nice Day! Sonya Wallace ATO- 1529 CENTRAL FILES CHEVRON D&M # EXTENSION EXPLORATION # EXXON M,%RATHON MOBIL ~ PHILLIPS # PB WELL FLS (2 COPIES) R&D # BPX # STATE OF ALASKA TEXACO RECEIVED MAR 1 2 1992 Alaska 011 & Gas Cons. Commission Anchorage GREAT LAND Directional Drilling, Inc. 0gl~lblhL PRUDHOE BAY DRILLING DS4-07 ST COMPLETION REPORT Specializing in horizontal drilling NOTE: PRUDHOE BAY DRILLING DS4-07 ST ORIGINAL WELL 0.0 TO 8300. SIDETRACK FROM 8325 TO PROJECTED T.D. AT 9494. GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY PRUDHOE BAY DRILLING COMPANY DS 4-07 ST WELL NAME PRUDHOE BAY LOCATION AL292D6 JOB NUMBER BOB MAGOS MWD TYPE SURVEY DIRECTIONAL SUPERVISOR 02/17/92 DATE NAME DEPTH INTERVAL DATE SURVEY TAKEN TITLE SIGNATURE 8325.0 FT. 9494.0 FT. FROM TO 02/08/92 02/17/92 FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL'SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIONAL DRILLING, Client .... : Field ..... : Well ...... : Section at: Engineer..: PRUDHOE BAY DRILLING PRUDHOE BAY UNIT DS4-07 S,48.30,W BOB MAGOS INC. S MEAS INCLN C DEPTH ANGLE 7 0 0.00 7 100 0.00 7 200 0.00 7 300 0.00 7 400 0.00 VERTICAL-DEPTHS BKB SUB-SEA 0.0 -51.0 100.0 49.0 200.0 149.0 300.0 249.0 400.0 349.0 7 500 0.17 500.0 449.0 7 600 0.17 600.0 549.0 7 700 0.00 700.0 649.0 7 800 0.00 800.0 749.0 7 900 0.00 900.0 849.0 7 1000 0.17 1000.0 949.0 7 1100 0.50 1100.0 1049.0 7 1200 0.00 1200.0 1149.0 7 1300 0.00 1300.0 1249.0 7 1400 0.00 1400.0 1349.0 7 1500 0.00 1500.0 1449.0 7 1600 0.00 1600.0 1549.0 7 1700 0.00 1700.0 1649.0 7 1800 0.08 1800.0 1749.0 7 1900 0.75 1900.0 1849.0 2000 0.83 2000.0 1949.0 ^Survey Codes' 7/GYRO (GLDD (c)92 PDS407ST B1.30 9:43 AM 2) SECTION DISTNCE Computation...: Survey Date...: KB Elevation..: Reference ..... : Magnetic Dcln.: RECORD OF SURVEY DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD 0.0 S 66.00 E 0.0 N 0.0 E 0.0 S 66.00 E 0.0 N 0.0 E 0.0 S 66.00 E 0.0 N 0.0 E 0.0 S 66.00 E 0.0 N 0.0 E 0.0 S 66.00 E 0.0 N 0.0 E -0.1 -0.2 -0.2 -0.2 -0.2 03/04/92 MINIMUM CURVATURE 02/17/92 51.00 ft 4J0126 30.20 E -0.4 -0.9 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.1 -0.9 S 66.00 E S 67.00 E S 67.00 E S 67.00 E S 67.00 E CLOSURE DL DISTNCE BEARING /100 0.0 N 0.00 E 0.00 0.0 N 0.00 E 0.00 0.0 N 0.00 E 0.00 0.0 N 0.00 E 0.00 0.0 N 0.00 E 0.00 0.1 S 0.1 E 0.2 S 0.4 E 0.2 S 0.5 E 0.2 S 0.5 E 0.2 S 0.5 E N 64.00 E N 90.00 E N 90.0O E N 90.00 E N 90.00 E 0.1 S 66.00 E 0.17 0.4 S 66.33 E 0.00 0.6 S 66.50 E 0.17 0.6 S 66.50 E 0.00 0.6 S 66.50 E 0.00 0.2 S 0.7 E 0.1 S 1.2 E 0.1 S 1.7 E 0.1 S 1.7 E 0.1 S 1.7 E N 90.00 E 0.1 S 1.7 E N 90.00 E 0.1 S 1.7 E N 90.00 E 0.1 S 1.7 E S 90.00 W 0.1 S 1.6 E S 24.00 E 0.8 S 1.9 E 0.7 S 75.79 E 0.17 1.3 S 85.12 E 0.36 1.7 S 86.38 E 0.50-' 1.7 S 86.38 E 0.00 1.7 S 86.38 E 0.00 -0.6 S 32.00 E 2.0 S 2.6 E 1.7 S 86.38 E 0.00 1.7 S 86.38 E 0.00 1.7 S 86.38 E 0.00 1.6 S 86.22 E 0.08 2.1 S 68.07 E 0.79 3.2 S 52.26 E 0.14 DS4-07 7 7 7 7 7 MEAS DEPTH 2100 2200 2300 2400 2500 INCLN ANGLE 0.75 0.83 0.83 0.50 0.58 7 2600 0.58 7 2700 0.75 7 2800 0.75 7 2900 0.92 7 3000 0.83 7 3100 0 7 3200 0 7 3300 1 7 3400 1 7 3500 1 .75 .83 .00 .00 .00 7 3600 1 7 3700 1 7 3800 1 7 3900 1 7 4000 1 .00 .00 .00 .17 .25 7 4100 1 7 4200 4 7 4300 6 7 4400 8 7 4500 10 .25 .00 .83 .17 .00 7 4600 11 7 4700 13 7 4800 16 7 4900 iS 7 5000 21 .92 .92 .17 .58 .17 RECORD OF SURVEY VERTICAL-DEPTHS SECTION BKB SUB-SEA DISTNCE 2100.0 2049.0 -0.7 2200.0 2149.0 -1.0 2300.0 2249.0 -0.8 2399.9 2348.9 -0.4 2499.9 2448.9 0.2 2599.9 2548.9 1.0 2699.9 2648.9 1.9 2799.9 2748.9 2.8 2899.9 2848.9 3.7 2999.9 2948.9 4.4 3099.9 3048.9 5.0 3199.9 3148.9 5.8 3299.9 3248.9 6.9 3399.9 3348.9 8.0 3499.8 3448.8 9.1 3599.8 3548.8 10.2 3699.8 3648.8 11.3 3799.8 3748.8 12.5 3899.8 3848.8 13.9 3999.8 3948.8 15.5 4099.7 4048.7 16.9 4199.6 4148.6 20.5 4299.2 4248.2 28.9 4398.3 4347.3 39.5 4497.1 4446.1 51.1 4595.2 4544.2 64.9 4692.7 4641.7 81.1 4789.3 4738.3 99.9 4884.7 4833.7 121.5 4978.7 4927.7 146.2 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD S 60.00 E 2.9 S 3.5 E S 50.00 E 3.7 S 4.6 E S 21.00 E 4.9 S 5.4 E S 18.00 E 5.9 S 5.8 E S 16.00 W 6.8 S 5.8 E S 4.00 W S 10.00 W S 2.00 W S 10.00 E S 17.00 E S 17.00 E S 8.00 W S 3.00 E S 6.00 E S 2.00 E S 1.00 W S 2.00 E S 2.00 W S 12.00 W S 1.00 W S 2.00 E S 14.00 W S 25.00 W S 5.00 W S 6.00 W S 4.00 W S 5.50 W s 4.00 w S 5.00 W S 5.00 W 7.8 S 5.7 E 9.0 S 5.5 E 10.3 S 5.4 E 11.7 S 5.5 E 13.2 S 5.8 E 14.5 S 6.2 E 15.9 S 6.3 E 17.5 S 6.3 E 19.2 S 6.4 E 20.9 S 6.5 E 22.7 S 6.6 E 24.4 S 6.6 E 26.2 S 6.6 E 28.1 S 6.3 E 30.1 S 6.1 E 32.3 S 6.1 E 36.8 S 5.3 E 45.6 S 2.0 E 58.0 S 1.2 W 73.8 S 2.7 W 92.7 S 4.3 W 115.0 S 6.2 W 140.8 S 8.3 W 170.6 S 10.7 W 204.5 S 13.7 W Page 2 03/04/92 CLOSURE DISTNCE BEARING 4.6 S 50.22 E 5.9 S 51.26 E 7.3 S 48.27 E 8.3 S 44.47 E 9.0 S 40.43 E DL /lOO 0.39 0.16 0.42 0.33 0.32 9.7 S 35.82 E 0.12 10.5 S 31.51 E 0.18 11.6 S 27.58 E 0.10 13.0 S 25.08 E 0.24 14.5 S 23.85 E 0.14 15.8 S 23.25 E 17.1 S 21.75 E 18.6 S 19.78 E 20.2 S 18.48 E 21.9 S 17.34 E 0.08 0.35 0.24 0.05 0.07 23.6 S 16.11 E 0.05 25.3 S 15.05 E 0.05 27.0 S 14.09 E 0.07 28.8 S 12.71 E 0.25" 30.7 S 11.43 E 0.25 32.9 S 10.71 E 37.2 S 8.21 E 45.6 S 2.45 E 58.1 S 1.17 W 73.8 S 2.10 W 92.8 S 2.68 W 115.1 S 3.09 W 141.1 S 3.39 W 170.9 S 3.59 W 204.9 S 3.82 W 0.07 2.82 3.00 2.91 1.84 1.96 2.03 2.28 2.43 2.59 ^Survey Codes: 7/GYRO DS4-07 S MEAS INCLN C DEPTH ANGLE 7 5100 23.50 7 5200 23.50 7 5300 24.00 7 5400 24.25 7 5500 24.17 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 5071.2 5020.2 174.1 5163.0 5112.0 205.3 5254.5 5203.5 239.1 5345.7 5294.7 273.7 5437.0 5386.0 308.4 7 5600 24.17 5528.2 5477.2 7 5700 24.00 5619.5 5568.5 7 5800 24.58 5710.6 5659.6 7 5900 25.00 5801.4 5750.4 7 6000 25.08 5892.0 5841.0 7 6100 25.25 5982.5 5931.5 7 6200 25.92 6072.7 6021.7 7 6300 25.50 6162.8 6111.8 7 6400 25.17 6253.2 6202.2 7 6500 25.08 6343.7 6292.7 7 6600 25.00 6434.3 6383.3 7 6700 25.75 6524.7 6473.7 7 6800 26.25 6614.6 6563.6 7 6900 26.83 6704.0 6653.0 7 7000 27.67 6792.9 6741.9 7 7100 27.92 6881.4 6830.4 7 7200 27.33 6970.0 6919.0 7 7300 26.92 7059.0 7008.0 7 7400 26.92 7148.2 7097.2 7 7500 26.17 7237.6 7186.6 7 7600 26.00 7327.4 7276.4 7 7700 25.00 7417.7 7366.7 7 7800 24.25 7508.6 7457.6 7 7900 23.83 7599.9 7548.9 7 8000 23.25 7691.6 7640.6 RECORD OF SURVEY ^Survey Codes: 7/GYRO 343.2 377.9 412.6 448.5 485.0 521.7 559.1 596.8 634.1 671.1 707.8 744.9 782.7 821.2 860.8 900.8 940.5 979.5 1018.4 1057.3 1095.6 1133.1 1169.6 1205.3 1240.4 DIRECTION BEARING S 6.00 W S 14.00 W S 16.50 W S 16.00 W S 16.00 W RELATIVE-COORDINATES FROM-WELL-HEAD 242.3 S 17.3 W 281.5 S 24.2 W 320.3 S 34.8 W 359.6 S 46.3 W 399.0 S 57.6 W S 17.00 W 438.2 S 69.2 W S 16.00 W 477.4 S 80.8 W S 16.00 W 516.9 S 92.1 W S 18.00 W 557.0 S 104.4 W S 18.00 W 597.2 S 117.5 W S 18.00 W 637.7 S 130.6 W S 18.50 W 678.7 S 144.1 W S 18.50 W 719.8 S 157.9 W S 19.50 W 760.3 S 171.8 W S 18.50 W 800.4 S 185.6 W S 18.50 W 840.6 S 199.1 W S 18.00 W 881.3 S 212.5 W S 17.50 W 923.0 S 225.9 W S 18.50 W 965.5 S 239.7 W S 17.50 W 1009.1 S 253.8 W S 17.50 W 1053.5 S 267.8 W S 17.00 W 1097.8 S 281.6 W S 17.00 W 1141.4 S 294.9 W S 18.00 W 1184.6 S 308.5 W S 19.50 W 1226.9 S 322.9 W S 18.50 W 1268.5 S 337.2 W S 19.00 W 1309.3 S 351.0 W S 20.00 W 1348.5 S 364.9 W S 19.00 W 1386.9 S 378.5 W S 21.00 W 1424.5 S 392.2 W Page 3 03/04/92 CLOSURE DISTNCE BEARING 242.9 S 4.09 282.5 S 4.92 322.2 S 6.20 362.5 S 7.33 403.1 S 8.21 W W W W W 443.7 S 8.97 484.2 S 9.61 525.1 S 10.11 566.7 S 10.61 608.7 S 11.13 W W W W W 650.9 S 11.57 693.8 S 11.99 737.0 S 12.37 779.5 S 12.73 821.7 S 13.06 W W W W W 863.8 S 13.32 906.5 S 13.56 950.3 S 13.75 994.8 S 13.94 1040.5 S 14.12 W W W W W 1087.1 S 14.26 1133.4 S 14.39 1178.9 S 14.49 1224.1 S 14.60 1268.7 S 14.74 W W W W W 1312.5 S 14.89 1355.5 S 15.01 1397.0 S 15.14 1437.7 S 15.27 1477.5 S 15.39 W W W W W DL /1oo 2.36 3.19 1.12 0.32 0.08 0.41 0.44 0.58 0.94 0.08 0.17 0.70 0.42 0.54 0.43 0.08 0.78 0.55 0.73 0.96 0.25 0.63 0.41 0.45 1.01 0.47 1.02 0.86 0.59 0.99 DS4-07 S MEAS INCLN C DEPTH ANGLE 7 8100 22.50 7 8200 21.33 7 8300 20.83 3 8325 20.40 3 8723 24.90 3 8817 27.20 3 8911 29.50 3 9006 30.80 3 9444 28.50 J 9494 28.20 RECORD OF SURVEY VERTICAL-DEPTHS SECTION BKB SUB-SEA DISTNCE 7783.7 7732.7 1275.1 7876.5 7825.5 1308.6 7969.8 7918.8 1341.3 7993.2 7942.2 1349.5 8362.5 8311.5 1494.8 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD S 22.00 W 1460.6 S 406.4 W S 22.00 W 1495.2 S 420.4 W S 26.00 W 1528.1 S 435.0 W S 26.30 W 1536.0 S 438.9 W S 65.40 W 1633.6 S 546.5 W 8446.9 8395.9 1534.9 S 56.90 W 8529.7 8478.7 1579.2 S 53.70 W 8611.8 8560.8 1626.8 S 52.50 W 8992.5 8941.5 1842.4 S 55.00 W 9036.5 8985.5 1866.0 S 55.30 W Page 4 03/04/92 CLOSURE DISTNCE BEARING 1516.1 S 15.55 W 1553.2 S 15.70 W 1588.8 S 15.89 W 1597.5 S 15.95 W 1722.6 S 18.50 W 1653.6 S 582.5 W 1753.2 S 19.40 W 1679.1 S 619.1 W 1789.6 S 20.24 W 1707.7 S 657.3 W 1829.8 S 21.05 W 1835.9 S 831.9 W 2015.6 S 24.38 W 1849.5 S 851.4 W 2036.0 S 24.72 W DL /100 0.84 1.17 1.52 1.77 3.87 4.66 2.93 1.51 0.60 0.66 ^Survey Codes: 3/MWD 7/GYRO J/PROJECTED DS4-07 Page 5 03/04/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN DEPTH DEPTH ANGLE 100 151 0.00 200 251 0.00 300 351 0.00 400 451 0.09 500 551 0.17 600 651 0.08 700 751 0.00 800 851 0.00 900 951 0.09 1000 1051 0.34 1100 1151 0.24 1200 1251 0.00 1300 1351 0.00 1400 1451 0.00 1500 1551 0.00 1600 1651 0.00 1700 1751 0.04 1800 1851 0.42 1900 1951 0.79 2000 2051 0.79 2100 2151 0.79 2200 2251 0.83 2300 2351 0.66 2400 2451 0.54 2500 2551 0.58 2600 2651 0.67 2700 2751 0.75 2800 2851 0.84 2900 2951 0.87 3000 3051 0.79 TVD MD-TVD VERT DIRECTION BKB DIFF CRRT BEARING RELATIVE COORDINATES FROM WELL HEAD 151 0 0 S 66.00 E 0.00 N 0.00 E 251 0 0 S 66.00 E 0.00 N 0.00 E 351 0 0 S 66.00 E 0.00 N 0.00 E 451 0 0 S 66.00 E 0.02 S 0.04 E 551 0 0 S 66.51 E 0.12 S 0.27 E 651 0 0 S 67.00 E 751 0 0 S 67.00 E 851 0 0 S 67.00 E 951 0 0 N 64.00 E 1051 0 0 N 77.26 E 0.22 S 0.51 E 0.24 S 0.54 E 0.24 S 0.54 E 0.22 S 0.58 E 0.11 S 0.89 E 1151 0 0 N 90.00 E 0.11 S 1.58 E 1251 0 0 N 90.00 E 0.11 S 1.68 E 1351 0 0 N 90.00 E 0.11 S 1.68 E 1451 0 0 N 90.00 E 0.11 S 1.68 E 1551 0 0 N 90.00 E 0.11 S 1.68 E 1651 0 0 N 90.00 E 0.11 S 1.68 E 1751 0 0 S 90.00 W 0.11 S 1.67 E 1851 0 0 S 31.85 W 0.30 S 1.50 E 1951 0 0 S 28.08 E 1.38 S 2.21 E 2051 0 0 S 46.29 E 2.54 S 3.01 E 2151 0 0 S 54.90 E 2251 0 0 S 35.20 E 2351 0 0 S 19.47 E 2451 0 0 S 0.64 E 2551 0 0 S 9.87 W 3.29 S 4.09 E 4.25 S 5.13 E 5.48 S 5.68 E 6.40 S 5.91 E 7.35 S 5.72 E 2651 0 0 S 7.06 W 2751 0 0 S 5.91 W 2851 0 0 S 4.13 E 2951 0 0 S 13.58 E 3051 0 0 S 17.00 E 8.39 S 5.61 E 9.65 S 5.42 E 10.99 S 5.39 E 12.52 S 5.65 E 13.91 S 6.05 E DS4-07 SUBSEA DEPTH 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5OO0 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 Page 6 03/04/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL MEAS INCLN TVD MD-TVD VERT DIRECTION DEPTH ANGLE BKB DIFF CRRT BEARING 3151 0.79 3151 3251 0.92 3251 3351 1.00 3351 3451 1.00 3451 3551 1.00 3551 3651 1.00 3651 3751 1.00 3751 3851 1.09 3851 3951 1.21 3951 4051 1.25 4051 4151 2.66 4151 4252 5.46 4251 4352 7.53 4351 4453 9.15 4451 4555 11.05 4551 4657 13.06 4651 4760 15.28 4751 4865 17.73 4851 4970 20.40 4951 5078 22.99 5051 5187 23.50 5151 5296 23.98 5251 5406 24.25 5351 5515 24.17 5451 5625 24.13 5551 5735 24.20 5651 5844 24.77 5751 5955 25.04 5851 6065 25.19 5951 6176 25.76 6051 RELATIVE COORDINATES FROM WELL HEAD 0 0 S 0.54 E 23.58 S 6.55 E 0' 0 S 0.05 W 25.33 S 6.58 E 0 0 S 7.12 W 27.11 S 6.49 E 0 0 S 6.36 W 29.10 S 6.16 E 0 0 S 0.54 E 31.26 S 6.09 E 0 0 S 6.21 W 34.06 S 6.01 E 1 0 S 19.67 W 40.85 S 4.05 E 1 1 S 14.55 W 51.70 S 0.22 W 2 1 S 5.53 W 66.03 S 1.92 W 4 2 S 4.90 W 83.73 S 3.66 W 6 9 14 19 27 36 45 55 64 74 84 93 104 114 125 2 S 4.86 W 105.01 S 5.29 W 3 S 4.60 W 130.10 S 7.54 W 4 S 4.65 W 159.60 S 9.76 W 6 S 5.00 W 193.98 S 12.74 W 8 S 5.78 W 233.65 S 16.42 W 9 S 12.96 W 276.45 S 23.02 W 9 S 16.40 W 318.83 S 34.39 W 10 S 16.00 W 361.83 S 46.91 W 10 S 16.15 W 405.04 S 59.31 W 10 S 16.75 W 448.02 S 72.16 W 10 S 16.00 W 490.92 S 84.67 W 10 S 16.89 W 534.69 S 97.37 W 10 S 18.00 W 579.01 S 111.54 W 10 S 18.00 W 623.57 S 126.02 W 11 S 18.38 W 668.72 S 140.80 W 0 0 S 4.22 E 15.21 S 6.37 E 0 0 S 2.38 W 16.65 S 6.27 E 0 0 S 4.53 E 18.36 S 6.34 E 0 0 S 3.95 E 20.10 S 6.49 E 0 0 S 0.46 E 21.84 S 6.56 E DS4-07 Page 7 03/04/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA DEPTH 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 8OOO 8100 8200 8300 8400 8500 8600 8700 8800 8900 MEAS INCLN TVD MD-TVD VERT DIRECTION DEPTH ANGLE BKB DIFF CRRT BEARING RELATIVE COORDINATES FROM WELL HEAD 6287 25.56 6151 136 11 S 18.50 W 714.49 S 6398 25.18 6251 147 11 S 19.48 W 759.32 S 6508 25.07 6351 157 10 S 18.50 W 803.67 S 6618 25.14 6451 167 10 S 18.41 W 847.97 S 6729 25.90 6551 178 11 S 17.85 W 893.39 S 6841 26.49 6651 190 11 S 17.91 W 940.23 S 6953 27.27 6751 202 12 S 17.97 W 988.30 S 7066 27.83 6851 215 13 S 17.50 W 1038.21 S 7179 27.46 6951 228 13 S 17.11 W 1088.41 S 7291 26.96 7051 240 12 S 17.00 W 1137.54 S 7403 26.90 7151 252 12 S 18.05 W 1185.97 S 7515 26.14 7251 264 12 S 19.35 W 1233.12 S 7626 25.74 7351 275 11 S 18.63 W 1279.33 S 7737 24.72 7451 286 11 S 19.37 W 1323.84 S 7846 24.05 7551 295 10 S 19.54 W 1366.43 S 7956 23.51 7651 305 9 S 20.12 W 1408.03 S 8065 22.77 7751 314 9 S 21.65 W 1447.96 S 8173 21.65 7851 322 8 S 22.00 W 1485.92 S 8280 20.93 7951 329 7 S 25.19 W 1521.61 S 8387 21.10 8051 336 7 S 32.37 W 1555.03 S 8494 22.32 8151 343 8 S 42.94 W 1586.05 S 8603 23.54 8251 352 9 S 53.61 W 1612.58 S 8713 24.78 8351 362 10 S 64.38 W 1632.22 S 8822 27.31 8451 371 9 S 56.74 W 1654.76 S 8936 29.84 8551 385 14 S 53.39 W 1686.27 S 9052 30.56 8651 401 16 S 52.76 W 1721.82 S 9167 29.95 8751 416 16 S 53.42 W 1756.86 S 9282 29.35 8851 431 15 S 54.08 W 1790.53 S 9397 28.75 8951 446 14 S 54.73 W 1822.90 S 156.10 W 171.48 W 186.73 W 201.54 W 216.41 W 231.35 W 247.17 W 263.00 W 278.70 W 293.73 W 308.98 W 325.07 W 340.84 W 356.11 W 371.37 W 386.03 W 401.36 W 416.65 W 431.93 W 449.63 W 473.93 W 505.25 W 542.67 W 584.22 W 628.90 W 675.75 W 722.39 W 768.28 W 813.40 W DS4-07 Page 8 03/04/92 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DL/ DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 100 0 0.00 0 -51 0 N 0.00 E 0 N 0 E 1000 0.17 1000 949 -0 N 64.00 E 0 S 1 E 2000 0.83 2000 1949 -1 S 32.00 E 2 S 3 E 3000 0.83 3000 2949 4 S 17.00 E 13 S 6 E 4000 1.25 4000 3949 15 S 1.00 W 30 S 6 E 0 N 90.00 E 0.0 1 S 75.79 E 0.2 3 S 52.26 E 0.1 14 S 23.85 E 0.1 31 S 11.43 E 0.2 5000 21.17 4979 4928 146 S 5.00 W 204 S 6000 25.08 5892 5841 485 S 18.00 W 597 S 7000 27.67 6793 6742 861 S 17.50 W 1009 S 8000 23.25 7692 7641 1240 S 21.00 W 1424 S 9000 30.72 8607 8556 1624 S 52.58 W 1706 S 14 W 205 S 3.82 W 2.6 117 W 609 S 11.13 W 0.1 254 W 1041 S 14.12 W 1.0 392 W 1477 S 15.39 W 1.0 655 W 1827 S 21.00 W 1.5 PRUBHOE BAY DRILLIN6 J & ORIGINAL HELL \ B~ BS4-07 ST VERTT6AL SE6TZON VIEW Section at: S 48.30 W TVD Scale.: ! inch = 200 Dep Scale.: 1 inch = 200 Drawn ..... : 02/28/92 feet feet Land DJre£tJona] Dt'jJJjn# Marker Identification MD BKB SECTN INCLN A) TIE-IN 8325 7993 t350 20.40 B) TD 9494 9036 t866 28.20 t300 t400 t500 t600 t700 t800 t900 Section Departure PRUBHOE BAY DRTLLrNG Marker Iclent i ficat inn ~,] TIE-IN BI TD MD N/S 8325 ~536 S 9494 ~850 S E/W 85t DS4-07 ST PLAN VZEH CLOSURE ..... : DECLINATION.: SCALE ....... : DRANN ....... : 2036 fl: at S 24.72 30.20 E ! inch = 400 feet 02/28/92 _$reat Land DJrertJona2 Dr j J J jrt# ,, SIDETRACK I / / I 1 I I I i 1 ! 1 / / / I / .,,- / ! / / z I / I ., ! z / / z / / / / / / / I / ! 1 1 I i I ! I I I i ! ; ./"/ i1' / ORIGINAL WELLm 2600 2400 2200 2000 1800 t600 t400 t200 t000 800 600 400 200 0 200 <- WEST ' EAST -> ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS HRI/BCS/DSN2 Runl Job~L66625-9 DIFL/BHCA/CNL Job#NA BHCA/Dn~L/CNL-Cm Run I Job~8~ Rml 2 J~053 Please sign and return the a~ched c~py as receipt of data. RECEIVED BY__ Have A Nice Day! -~// Sonya Wallace APP~ OVED AT0-1529 Tr~ns# 92054~ HIS Atlas Atlas CENTRAL FILES (CH) CHEVRON D&M # DEDE SCHWARTZ (OH/GCT) # EXXON MARATHON MOBIL # PHILLIPS PB WELL ~ R&D #BPX # STATE OF ALASKA TEXACO Alaska O~t & Gas Cons, commission A~chora~e ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 2-21-92 z-25~3 1-11-93 '/12-1-91 · 7,¢''--- '7'7 ,.,' 12-3-91 ~4-7 / .12-3-91 S ~' F/ 14-2 ~/1-19.92 ARCO CASED HOLE FINALS CCI, CPerl) l~m 1. [~' Atlas Per/~ Run 1, ~' HL8 PS~ (Ccm~~ Ibm 1. ~' ~ Pe~o~flon ~ 1. ~' ~ ~~h~ Trap ~ 1. ~' ~ ~ ~ ~m I. 1" ~co Please sign and return the attached co~y as receipt of data. Have A Nice Dayl Sonya Wallace ATO- 1529 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL ~ R&D # BPX # STATE OF ALASKA TEXACO R£C£IV£D FEB 2 5 199~- Alaska Oil & Gas Cons. Commission Anchorage ARCO ALA£KA, INC. F'.O. BOX ~OOS60 ANCHORAGE, ALASKA 995i0 DATE i 1_,-9.. ARCO CArD HOLE F£NALS ' ~2-6-9~" ..CL~ FOR ,S'TRE$.? FRAC ' ~ 2- ~ ,3-9 i v/'/CuI._ k Ui-:5' ~ h;E$$ FF,'AC i2-~8-9~ v .CCL FOR BRIDGE PLUG ~-24-9~~'ERF RECORD ~2-26-9~ ~ CCL FOR T~BING CUTTER ~2-24-9~ ~PEI-<F/COLL~R FOR TUBING 7-28--9 i ~DSN ' 7-22-9i ~~ZN ' ~2-9-9~ y~L FOR ~TRES'~ F'RAC ~2-26-9~ ~ CCL FOR PERF C U'¥ T E R RUN 3, RUN t , 5' RUN t , 5 · RUN t, 5 · RUN t, 5 · RUN t , 5' RUN i, 5 · RUN i, 5 · RUN t, 5: · RUN t , 5 · F'LEA.?E SIGN ANI) RETURN THE ATTACHED COPY AS' RECEIF'T OF DATA. r,:i:t_.b_iVt-L:' BY' :~ (3 N 'T' A W A L. L. ~'::i L; Ii:. ATO-i 529 A F:' F' F;.'U V'I::. D ~ T R A N,? :~,: g"i,:::, ¢.,/, HL$ HLS HL$ HL$ HL$ HL$ HLS' HL$ HLS' HL$ RECEIVED ,JAN 2 1 1BB2 ~iasKa Oil & Gas ~lbs. Commission Anchorage D I ~;-F F;,' I BU'¥ I Oiq .R. -.- CENi'F..'AI_ F' I L.E~: C Iq t::: V R 0 N D & i'"i E X 'i' E N 310 N I'": X I::' L_ 0 R A T ]: 0 N '"- IF X X 0 N "Il' MARATHON ~ HOB I L :~ F' H I I_ L I F ,.~ I::'B WFI...I_ I:'IL..E£ F..' & D :.": B F:'X 3'TATE OF AI_A;if'I<A TEXACO .AF;;E:O RI_ASKA, .[NC.,. P,.O... BO;,( t 0~,560 ANCHORAGE, ALASKA 995 i O DATE' t2-3i-9t REFERENCE ' ,..,'~Z""/>y'' i =i 9 2-3S 'z~-- r"/ ::;-.4 ,¢ ¢'" ~''/ E%?? ¢# .,.,'z 4-s6 4 7°'"L,9 9-i T ARCO CASED HOLE FINALS 0-'27-9 i/LEAK DETECT 5-9i PROD PROFILE ./ 9 i JEWELRY -i9-9i ~/ 1NJ PROH1LE -i8-9i,/,'.-/GAS LIFT -23-9i v/LEAKY", DETECT -14-9i~/F'F~OD F'I;,'f')F'-ILE/Pi ~,-28-9t LEAK DETECT -i 6-9i INJ F'ROFILE/F'IT.!~ - - GR/CCL TIE-IN PRODOCTT-ON -t9-¢i'/'- PROD PROFILE t t-'29-9i ¢ INJ F'ROFILE "'7 PLEASE SIGN AND RETURN THE ATTACHED COPY RECEIVEI) BY _.___.~._-~ HAVE A NICE DAY! SONYA WALLACE ATO- i 529 RUN t , i · F,:UN t, 5" RUN i, 5' RUN t , 5 · RUN i, 5 · F(UN i, 2"&5" RUN i , ... RUN i , 5 · RUN i , 5" RUN i , 5" RUN i, 5' RUN i , 5 · RUN i , 5 · RUN i , 5 · RUN i, 5 · RUN t, 5 · RUN i , 5" AS RECEIPT OF DATA. CAMCO C A bi C 0 [;ANCO CAHCO CAMCO CAMCO CAMCO uAt-iCO CAMCO CAMCO C A H C 0 CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL · "-'F'HILLIF'S F:'B WELL F']:L_E£' R' & D :~: B P X ~. STAI'E OF ALASKA TEX~CO RECEIVED JAN 1 0 199Z Alaska Oil & Gas Cons. Commissiof · Anchorage TO: THRU: MEMORANDUM State of Alaska ALASKA OIL .AND GAS CONSERVATION COMMISSION Lonnie C sm~t:h~. comm i s s i oiler DATE: FILE NO: December 16, 1991 LG12!6-i. DOC Blair Wondze!l Sr Petr Eng TELEPHONE NO: SUBJECT: Wellbore Plug ARCO DS4-7 Prudhoe Bay Unit FROM: LOUIS R Grimaldi Petr Inspector' saturdav~...December 14= ........ 1991 I traveled to ARCO's D.$4-7 in 'the Prudhoe Bay Unit to witness the verification of plug placement prior to sidetracking of this well. The cement was tagged using slickline with a tubing end locater. The top of cement was enco'untered at 8783' (corrected) with. the 'top of perforations at 8968~ leaving approximately 185~ of cement above the top perforations. Pickup off bottom of 'the slickline tools was smooth and showed no signs of the 'tools sticking. After the wireline and tools were withdrawn from the well~ a 1500 psi pressure test was applied, and no bleedoff was observed. In s'ummary~ I witnessed the successful tagging and pressure test of the perforations wellbore plug in ARCO's DS'4-7 in the Prudhoe Bay Unit~ A t t a chm e n t 02-00 lA (P,~v. 8/89) 20/11/5/1EMO1.PM3 4/80 ASKA OIL & GAS CC~:SERVATZON CO~! Plug & Abandonment Report Company Repr Lease'No. p~ ~J Total Depth SION Date Drilling Permit # Sec. T-R Mud Wt. ~- ~ Casing: Drive Pipe Conductor /_~ Intermediate "O.D. Set at Ft. w/ Pene. "O.D. @ ~ ~ C~ / Ft. Surface P~ "O.D. @~373Ft. "O.D. @ Ft. Production~ "O.D. @ ~73~Ft. Plugging Data: 1. Open hole plugs: 2. Open hole isolation plug: J Perforation plugs '(if any): 4. Annulus plugs (if any): 5. Casing s tub plugs: 6. Surface plug: Casing removal: "casing cut at ' "casing cut at ' "casing cut at ' SENT BY~OOLD WEATHER OONTR, - , ;12-18-91 ; 8:24AM ; PRUDHOE OFFIOE~ 9072767542;¢ 1 ALASKA OIL CON S E RVA,T I ON AND GAS COMMI S S ION TO: THRU: Lonnie c Smith Commissioner Blair E Wondzell Sr Petroleum Engr FROM: Lou Grimaldi Petr Inspector DEC 1 6 199! Alaska Oil & Gas (ions. gommi$$ioa Anchorage .,,, Fost-lt TM br~tnd fax transmitts~ memo 7671 ~ ., ' [': ,~~z~./ ',,-,~ o ...... ...... ~~C~ ! ~,~~2 ' ,,, ~.,._ ~2~-r~-~ ....... SENT BY'COLD WEATHER CONTR. 12-!6-9! ; 8:25AM ; PRUDHOE FLOE- 9072787542;¢ 2 Arco Alaska Inc.- Prudhoe Bay Field Well 4*7 APl,e: ~20!89<~ Well Type: Producer -$.~u: Date: 12-31-78 Completion Date.. 2-13-86 New l-"l Workover E] ")riginc~l I~KBE: 51' Hanger Type,, FMC Gen 1 Hanger: 18' oD of Sacllerochlt: 8877' Maximum Hole Angle: 26~ Angle Through Sad,: 172 Annulus FluicI,, Dlesel/9,9~ NaCl/Nai~r Reference Log: BHCS 1-28-76 All De :re RKB Drtlllng MD to Top of Equipment except where noted. J J J J J --. X X ¥ ' '2,.~. O-',~, ·~=~ I I 1 2 3 8625' 4 5 8736' 6 8737' 8738' 9 7 8 Minimum i!~, 0t~ XN No.Ge NippY. ID = 4.4~' 13-3/8' 72~ MN-a3 0 9-5/8" 47~ MN-80 0 5-1/2' 17~ L*80 O' Ga~ Uff Inlommllon (Valve Charge RECEIVED OEC 1 61991 Alask~ Off & Gas Cons. Commission Anchorage Beffom De~erlr~tlon 2701' Cc~ng 9375' Cc~lng Date: 0~-04-91) 3803' (&BOa') 1 CA-MMiG CA RDO 5410' (5355~) 2 CA*MMIG CA RD ~_%u~_, (6240') 3 CA-MMiG CA RD 6464' (6311') 4 C.A*MMIG CC, RD 7147' (6923') 5 CA-MMIG CA ~ (5990') 6 CA-MMIG CA RD 7738' (7452") 7 CA-MMIG CA RD 7807' (7615') 8 C.,A*MMIG CA RD 8103' (778?) 9 CA-MMIG CA RD 8183' (78617 10 CA*MMIG CA RKED t0 PMforc~on D(3ta (ELM Deptl~) R K , 5/16' ORtF R K,," RK RK RK RK RK RK RK f~KP 07-23-90 APerf , CT/-23-90 APen' 12.O;x,90 Aperf 12-31-65 W$O Sqz 12-31-88 WSO Sc:IZ 12-31-88 WSO SClZ 12..31-88 W$O Sqz 01-23-89 I~Perf 01-23-,89 r~Perf PBTD - 9328' TD =9400' Datum 87t::K3' SS: 91217 MD 8800' ~ = 9225' MD Revtslon Date: 12-O1-91 byI~NH Reason: PXN Rug Pullecl Previous Revision: 10-2~91 4-7 ...... ,,, AL .-,KA OIL AND GAS CONSERVATION COMMIS~,ON ',' ,";!? {!,~i~ ~ ;!'".~, ~¥ ,~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing ~ Repair well __ Plugging, x Time extension Stimulate __ Change approved program __ Pull tubing ' Vadance Perforate Other x Plug back f/Sidetrack 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 90' FSL, 593' FEL, SEC. 27, T11N, R15E At top of productive interval 1585'FNL, 1180'FEL, SEC. 34, T11N, R15E At effective depth At total depth 1720'FNL, 1190'FEL, SEC. 34, T11N, R15E 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KBE = 51' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 4-7 ST 9. Permit number 75-77 10. APl number 50- 029-2O189 11. Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9400' feet Plugs (measured) Cement Plug 9017' feet BKB 9328' feet Junk (measured) 8949' feet BKB from 9270'-8625' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 54' 20" 240 sx Arcticset 2671' 13-3/8" 3900 sx Permafrost 9353' 9-5/8" 1125 sx Class G measured 9132~9150~ 9188~9238~ 9242~9266~ 9272~9290' true vertical 8763'-8913' (4 intervals) Tubing (size, grade, and measured depth) 5-1/2" L-80 to 8736' True vertical depth 84' 2701' 9373' RECF. VED Alaska Oil & Gas Cor~s, Packers and SSSV (type and measured depth) 9-5/8" BOT Packer @8625'MD, SSSV @ 2223' 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation 15. Status of well classification as: December 6, 1991 16. If proposal was verbally approved ,~/~ ~>~./c 4 Sk,.~- ;~ Oil x Gas~ Suspended Name of approver Lonnie Smith 12-4-91 Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~f,~, ~,%-~Y'L ~~-~.,./ Title Workover Superintendent FOR COMMISSION USE ONLY Date 12-5-91 Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test__ Location clearance Mechanical Integrity Test__ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 · I App ow,.. No. '" .... co~mm'issioner Date / ~;~ ""//-- ~'7 SUBMIT IN TRIPLICATE E 4-7-ST Sundry Permit Inforn. ,,on Ob!ective: The DS 4-7 well is currently shut-in with confirmed tubing leaks. The well has experienced high water production in spite of a 1988 squeeze job. Recently there has been a dramatic increase in GOR. Therefore, with the requirement of a tubing changeout and a profile modification, a sidetrack to obtain a new wellbore with a quality primary cement job with a new perforation profile is desirable. The proposed sidetrack will be a "twin" of the original well in the same reservoir and fault block with a bottom hole location within +/-250' southwest of the original bottom hole location. The sidetrack plan involves sidetraCking above the 9-5/8" packer with an 8.5" hole. A 7" liner will be cemented in place and the well will be completed with 5-1/2" x 4-1/2" tubing. ,Procedure Outline; · 2. 3. 4. 5. , 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. Kill well· Squeeze perfs (see attached detail P&A procedure). MIRU workover rig. Pull 5-1/2" BPV. Circulate diesel from well. Set two-way check valve. ND tree. NU & test BOP's to 5000 psi. Pull 5-1/2" tubing. Test 9-5/8" packoff to 3000 psi in the FMC GEN-1 and replace if necessary. P/U 9-5/8" casing scrapers and 4-1/2" DP to the top packer assembly. Circulate the hole clean. Run Vertilog in 9-5/8" casing to confirm sidetrack potential. RIH with section mill and cut 80' window in the 9-5/8" casing from 8320-8400' MD. Set a cement plug from 8100'-8500' MD. RIH with a 8-1/2" slick assembly and dress off the plug to 8325'. RIH w/steerable system and kickoff through the section. POOH. RIH with 8-1/2" packed assembly and drill to TD (+ 9500' MD). Run open hole logs. Run and cement 7" 13 CR liner in the 8-1/2" hole. Clean out liner to PBTD and test to 3000 psi. Displace well to seawater. RU wireline and set 7" packer with 4-1/2" tail. RIH with 5-1/2" x 4-1/2" 13CR completion string. Space out, land completion, set packer. Pressure up to set 9-5/8" packer. Test to 3000 psi. Test tubing x casing annulus to 2500 psi. Set two-way check valve. ND BOP's. NU and test new 7-1/16 x 5-1/8" 5M chrome tree to 5000 psi with diesel. Pull two way check valve. Displace diesel down annulus through the upper GLM to freeze protect 2000'. Set BPV. Release rig. Anticipated BHP-7.9 PPG equivalent. Drilling Fluid: 9.5 PPG, V~rj~o~l~lt~~ ppG. Alaska Oil & Gas Cons. Commissio~ Anchora~.e DS 4-7 P&A PROCEDURE', Procedure 1. Outline; Notify an AOGCC representative prior to commencing operations. 2. Rig up coiled tubing unit. 3. RIH with coil tubing circulating seawater. Lay a cement plug from current PBTD of + 9270' MD to ± 8625' MD (343' above top perforation). Note: packer is at 8625' and 5-1/2" tubing tail is at 8737' MD. Down squeeze into perfs leaving cement top no deeper than 8868' MD (100' above top pedoration). 4. RU slickline unit. RIH and confirm cement top at least 100' above top perforations. Note: Tag to be witnessed by AOGCC representative. If cement was squeezed below the 5-1/2" tailpipe, set a magna range plug in the tubing tail just below the packer at + 8650' MD. 5. Set 5-1/2" BPV and prepare Pad for rig to sidetrack. 6. MIRU Nabors 2ES rig for sidetrack. Notes: The 9-5/8" casing from 8830' to surface was tested to 3000 psi w/10.1 ppg brine on the last rig workover 2/6/86. - STACK 135,,,, 500,0, lB ! I ANNULAR PREVENTER 7 PIPE RAMS 3 ' ! ' ~IEAD 2 1.13~/ff' CASING HEAD 2. 5000 PSI TUBING HEAD 3.13-5q~ . 5000 PSI PIPE RAIVI:S 4.5000 PSI DRILLING SPOOL 5. 13-5/8' . 5000 PSI BLIND RAM~ 6. 13-5/8" - 5000 PSI PIPE RAM~ 7. 13-5r8' . 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND Fill ACCUMULATOR RESERVOIR TO PROPER LEVEL WrTH HYDRALI_JC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3(XX) PSI WITH 1500 PSI DOfF_AM OF THE REGULATOR. 3. OB.SERVE TIMF~ THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECOR~ THE TIIVE AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGIN(3 PUI~3 OFF. 4. RECORD ON THE IACC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIM~_ AND 1200 PSi REMAINING AlasJ(a Oil & Bas Cons. Commissie[~ BOP STACK TEST_ A~chora~ 1. FILL BOP STACK At, JO IVI.,~NIF~ WITH ARCTIC DIESEL IN W1NTER OR SEAWATER DURING SUMMER MONTHS. 2. CHECK THAT ALL FK:N.D-EX3WN SCREWS ARE FULLY RETRACTED. PREDETERMINE DFJ='T'H 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. BI_F?D TO 71=RO PSI. 6. OPEN ~t.A~ PREV~ AND CLOSE TOP SET OF PIPE F~MS. 7. INCR~ PRESSURE TO 54X~ PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRES.SURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTRF_AM. BLEED SYSTEM TO ZERO PSI. g. OPEN PIPE R~J~S. BACKOFF RUNNING JT AND PUll OUT OF HOLE. CLOSE BLIND RAM~ AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPF_N BUND RANIS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD Ar,C) LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KFi 1 y COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. S.GN AND SEND TO DRILLING SUPERVISOR. 14, PERFORM CO~ BOP TEST ONCE A WEEK ,AND FUNCTIONALLY OPERATE BOPE DAILY FOR DRILLING OPERATIONS. FOR COMPLETIC,~ WO~OVER OPERATKDN~, PERFORM COMPLETE BOP TEST EVERY 21 DAYS AND FUNCTION TEST 19DP ~Y. DAM 11/20/89 BOP SCH (FOR: NAB 2ES) ARco Al~k~ / BP EXPLORATION ENGINEERING DATA BASED ON ENGINEER 'T~ BUDGET/AFE NO. SHEET NO.__ DEPT. APP'VL DATE 12-~-~ t FILE NO. OF__ AK 2337-1 (6/86) ///'/ / ////// //'/'/ (/ R E C E ~V ~ [) ,~co Ata~a lnc.- Prudtnoe Bay Field We~ 4-7 APle: ~20189-00 Well Type: Producer Spud Date: 12-,31-75.. Completion Date: 2-13-86 New I"1 Workover ITl Original RKBE:51' Hanger Type: FMC Genl Hanger: 18' Mop of Sacllerochlt: 887'/' Maximum Hole Angle: 26~ ~gle Through Sad.. 174 · ~nnulus Ruid: Diesel/9.9~ NaCI/NaBr Reference Log: BH 1-28-76 All D~ ire RKB Drilling MD to Top of Equipment except where noted. ~pms ~ 2223' Camco BaI-O SS,SV Nipple: ID · 4.562" 8605' BOT PBR Assembly 8625' BOT Packer 8724" Otis XN Nipple: ID. 4.4,55" (PXN Plug in Place 10-24-91) 8736' Baker Shearout Su~ 8737" Tubing tail: 5-1/2" 8738' ELM tubing tal: 7-5-86 Minimum ID: Oils XN No-Go Nipple: ID · 4.4,r~" (w/PXN Plug) ca,ne ams Tub~ne - 13-3/8' 72e MN-80 0 --2701' Cclslng 9-5/8' 47d1' MN-,80 0 9373' Casing 5-1/2' 17~ L-80 O' 8737' PC tublng Gm Uft Ir/ormatlan (Valve ~ Dale: 8-4-91 ) 38C~ (3803') 1 CA-MMIG CA RDO RK 5410' (5355*) 2 CA-MMIG CA RD RK 638g (6240') 3 CA-MMIG CA RD RK 6464' (6311") 4 CA-MMI~ CA RD RK 714/" (69237 ,5 CA-MMI~ CA RD RK 7222" (699g) 6 CA-MMI~ CA RD RK 7738' (7452') 7 CA-MMIG CA RD RK 7807 (7515") 8 CA-MMI~ CA RD RK 8103' (7787') 9 CA-MMIG CA RD RK 8183' (7861') 10 CA-MMIG CA RKED RKP 5/16' ORB: 10 Pefforafl~ Data (ELM Depths) 8K;M 3 1 1 7-~ APerf 8~1 3 I I 7-23-90 APelf 89g),~14 3 24 2 12-9.90 Aperf 9048,9049 2 1 0 12..31-88 WSO Sc:lz 9133.9151 2 18 0 12~1-88 WSO Sqz 91~ 2/1B 4P 0 12~1-88 WSO Sqz 924~-92~ lB 8 0 12.~1-88 WSO Sqz ~ lB 16 1/'2 ~ 1-23-89 RP~'f 9272-9290 lA 18 4 1-23-89 RPerf Dakrn 870g SS - 9120' MD 8890' SS = 9225' MD Revision Date: 10-26-91 by Reason: PXN Rug Previous Re. vtdon:8.5..91 4-7 AF(CO ALASKA, INC. F'.O. BOX i00360 ANCHORAGE; ALA£KA DATE ' REFERENCE - i 0-23-9i .. ARCO CASED HOLE FINALS ?~:"'~'1 'Z-es/ :9-2i-,'..7'i F'RE-FRAC INJ F'ROFZLE RUN ,~-/¢..¢ 2-23/ 9-4-9i PROD F'ROFILE RUN 3~' -¢S ~ -"~ "':-9 t qg ."~N. 2-2 6 8 ..,_, F'T TS RUN 2-29A ~ 8-23-9t F'IT£ RUN *,~;.,,') 2-.:.50 ~ 9-4-9i GR/CCL RUN ~,,\'?~,'"'~l ,.7-i ,:.~-k.,/' 9-i 6-9i INJ PROFILE RUN ¢.¢,.r'. 3';,-i '-:b,/ 9-i 5-9t INJ F'ROFILE RUN 75-W S-t-7:u'- (?-i5-9i LEAK DI:.-TEC'F RUb,! ,r¢.-.~~ 3-t "'5'-'~ 8-50-9i PROD F'ROFTLE RUN 7f....,o>( 3-i 7 -~ 9-i 9-9t JEWELRY I-:UN 3;-t 7~,,,/ 9-i 9-9t ]:NJ PROF'ILE RUN <F¢'..-'~:~ 3-30,-,"8-2S-91 PROD F'ROF-'"ZLE RUN ¢'¢'-¢? .75-34,,.- 8-29-9t PROD F'ROF'ILIF RUN ,!-~/ *-),:-* 4-4 ~" ,'.3-..7i-9i PROD F' F;.: O F:' .[ I_ E RUN ?..¢--''/'/4---'7 '-.."":;'-2.-9i F'I:;:OD F'F;:OF'ILE ......... 'RUN ?,¢-~? 4-i5..' ~ 9-23-?i $.f-~-:~> 4.-.29 '"'"'" 9-i 8-9i .... ,.,,.¢ 4--,'::'-.--'- CAMCO CAMCO CAMCO CAMCO C A H C 0 CAMCO CAMCO C AH C (] CAMCO CAMCO CAMCO CAMCO CAML,'O C A H C 0 JEWEI_RY/[.; F;.:/C: F' L-'¥A6 RUN PIl"$ · ' ....... RUN LEAK DFTECT . ":'- ......... 7 ..'.','::.':. "':" RUN i ,. ...... t'0"'"':'. .... CAMCO .............. ' Z.,=';.Z2:. .............. Z .................... i , .--5" .......... C;AHCO .i , "5' CAMCO ..i , ...5, ......... :: ..... ' ...... CAMCO F:'I_EASE SIGN AND'.R~TURN THE'~ATTACI4ED'-.'COE"¥..~.'.~ECEIP.T:,-:OF ":'.DATA ........... -~:~=~:- ............... ='. .............. Bf' ' "- ' ............................ '" ....... :: ' ' . :::::::::::::::::::::: I. iAVE A NZCE DAY~ ~ ..... v"7.]-/ '~ ......... ........................ ~aska Oil & Gas 6ons. uommlssm. ' Anchorage '.~ ..... S'ONYA WALLACIE APF'RO~:~E? ~_~ -- ATO .... · * TI-tIS * * T H !£ **-* THE D I STR I BIJT ]: ON CENTRAL FILES --- PHILLIPS CHEVRON F'B WELL FILES D & M R & D EXTENSION E:XF'L_OI~(A l" I ON $ BF'X EXXON ~ &'I'Ai'IE UF ALA.~/KA MARATHON TE:XA[;O MOBIL C 0 F;.:' 1::t::' C'T' A F' ]: ~ F' 0 R '.-"-- Y E:ORREC"i- AF'I~ FOF,' 2-.50 COREEC'f' AF']:~ FOF.: 4-4 STATE OF ALASKA ALASKA... '_AND GAS CONSERVATION CC, /IISSION REPORT SUNDRY WELL OPERATIONS ;,. Operations performed' Operation shutdown Stimulate ~ Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCQ Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 90' N & 593' W of SE cr, Sec. 27, T11N, R15E, UM At top of productive interval 1585' S, & 1112, Wof NE cr, Sec. 34 T11N, R15E, UM At effective depth 1710'S & 1180'Wof NE cr, Sec. 34, T11N, R15E, UM At total depth 1720' S & 1190' W of NE cr, Sec. 34, T11N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development Exploratory Stratigraphic Service 9400 feet Plugs(measured) 9017 feet 6. Datum of elevation(DF or KB) 51' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-7 9. Permit number/approval number 75-77 10. APl number 50 - 029-20189 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 9328 feet true vertical 8949 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 135'. 20" 240 sx 135' 135' Sudace 2705' 13-3/8" 3500 sx 2701' 2701' Production 9373' 9-5/8" 1125 sx 9373' 8992' Perforation depth: measured 8968', 8981', 8990'-9014', 9250'-9266', 9272'-9290' 1 ~,,]i ?,:iiI ,:":I, "~ ~'~!'~ ~ true vertical 8606', 8619', 8627'-8650', 8879'-8894', 8900-891...7'.~,, ,,..,.,~, ~i]~;?,S,, (~t!~[~ Tubing (size, grade, and measured depth) 5-1/2", 17~, L-80, 8736' MD Packers and SSSV (type and measured depth) Brown 3H packer @ 8625' MD; Camco BaI-O SSSV @ 2223' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 2629 2327 7436 1200 2792 2398 7507 1200 Tubing Pressure 245 240 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run 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. Signed ('~L?L/~r~- ~' ~ f~~ Form 10-404 Rev 06/15/88 Service Title Sr. Area Operations Engineer SUBMIT IN DUPLICATE SUN/nb .II,Y REPORT OF WEIJJ OPER~ IONS DS 4-7 Perforating Operations; ARCO Alaska, Inc. perforated DS 4-7 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 12/9/90. The interval perforated was the following: 8990'-9014' MD (Reference Log: BHCS dated 1/28/76). 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 12/9/90. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. Perforated 8990'-9014' MD at 2 SPF (ref: BHCS of 1/28/76). SI well, POOH, and confirmed all shots fired. Rigged down and secured well. WDM: 6/14/91 STATE OF ALASKA ALASKA, '_ AND GAS CONSERVATION C(~ AISSION ~i'.., ,~"~'~. REPORT'uF SUNDRY WELL OPERATIONS'" 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 90' N & 593' Wof SE cr, Sec. 27, T11N, R15E, UM At top of productive interval 1585' S, & 1112, Wof NEcr, Sec. 34 T11N, R15E, UM At effective depth 1710' S & 1180' W of NEcr, Sec. 34, T11N, R15E, UM At total depth 1720' S & 1190' W of NE cr, Sec. 34, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 51' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-7 9. Permit number/approval number 75-77/90-542 10. APl number 50 - 029-20189 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 135' Surface 2705' Production 9373' 9400 feet Plugs(measured) 9017 feet 9328 feet 8949 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 240 sx 135' 135' 13-3/8" 3500 sx 2701' 2701' 9-5/8" 1125 sx 9373' 8992' Perforation depth: Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, 8736' MD /~. measured 8968', 8981', 9007', 9250'-9266', 9272'-9290' true vertical 8606', 8619', 8643', 8879'-8894', 8900'-8917' .,.,,,,,.;,:~;~<~.;~....-,,,, ~¢~i¥ .~:~: "."' '~. Packers and SSSV (type and measured depth) Brown 3H packer @ 8625' MD; Camco Bal-O SSSV @ 2223' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Average production or Irtiection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 4681 8490 8322 920 Tubing Pressure 269 Subsequent to operation 5472 9538 8323 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. 1084 Service 278 Form 10-404 Rev 06/15/88 Title Sr. Area Operations Engineer Date ~/~....~../~/ I SUBMIT IN DUPLICATE SUN/nb , II,Y REPO~ OF ~JJ OPEI~ iONS DS 4-7 Perforating Operations: ARCO Alaska, Inc. perforated DS 4-7 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 7/23/90. The depths perforated were the following: 8968', 8981', and 9007' MD (Reference Log: BHCS dated 1/28/76). Produced flu/ds 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 7/23/90. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. Perforated 8968', 8981', and 9007' MD with I shot at each depth (ref: BHCS of 1/28/76). SI well, POOH, and confirmed all shots fired. Rigged down and secured well. WDM: 6/14/91 A i",! !:::: H 0 R A [;. E::, A L_ A $ K A 99~ 1 ~ F;.'.EF:'E:F;tENCI'Z' ARCO CASED HOLE FINALS i ' ':~' t "' i ? - 90 4 .... :.3 i 2-9-90 ,1 ..... 7 i,..."~--'c~-'oO, , '.!.'.<-. i 4i 2.-t 9-9 £:, 7"-' i 4 t 2-28-90 '7 .... i4 t2 .... 28-90 '7-'-' i o,..., i 2----28 ..... ':,;'(i:, 9 .... 45 t 2-20-90 'i "'; ... I:.," ..:..... .... t 2-t t .... 90 i ''~,.... .... 5.. i 2----::'_'9....90 i2 .... 2i i2 .... t7--90 i ,-"~-. .... ,." i'~. '~ .... i 6 ..... :;:'() i4 ..... i.3 t2-28-.-.90 i '7 .... i 4 i 2--- 2'? -9 ~:.~ PE:RF: RECOIRD F:'ERF RECORD F:' E: R F:' R E C 0 R D ., PERF F<IECORD CNL./CR/CCI... DIF:FFRE:NI-IAL TEMF:' C N L/' G R /C C; I... D I F-'FEI-?ENT I Al... T'EMF' ,.JLJ NI< BA,.91< E:I"/G ALJGE: C O L. L A R / F:' E R F" C O L. L. A F;:. / F:' E R F:' CCL. C [I L L A I'< /F" E. f',' I" t.; U L L ~ R / F:' E R I:: F:' I... E A S' E ,'ii: I (:; N A N D R E:'i" LI R N T I"IIE A I"'T' A C.'-I"IE: ID C 0 F:' Y I"lAVlii: A NIClii: DAY! R ]: N G RUN t , 5" 'RUN 't, 5 · ". :,:.RUN,:~'I;.~ ...5:" "' '"' '" RLJN ~, ~" ' 'RUN"~ , 5" RUN t , 5" RUN t, 5" AS' RECEIPI" OF:' I) A1'A. A F:'., P R C)., V E: D OGG~~"'~- TRANS :,~ 9 SCH ,..R C I--I 5'CH SCH AI"L.A,S' A'f'I_AS AI'I..AS; ATI..A,? ,.: CH A'I' L. A ;}~' AfL. AS ATI_AS AT'LA,'.? A T' I._ A ;ii: I) I S' T R I B U 1" I 0 N :Il: C E: N 1' IR A I... F I I... iiE,.? · ,,.'"' C: H Iii: ",.," R [) N D 6: l"i :Il: Iii: X 'i" Ii!: N 5' :1:0 N E X P L 0 Fi: A 'l" :1:0 N '"' Iii: ',." Y.: [-~ iq '11' .- .., ...,, i'-'i A R A 'i" I..I 0 N '"'.,,. [i i.:) D :!: 1... RECEIVED JAN 9 1991 ,,, · ,~ ..~. Alasl~'.l:}ll;i~-~s Cons. C;ommilsio~ ' .:~'~'" ~chorage .... !.....~,.,,,,.~.,,,... ..... . .... A L A .'? K A .. BOX i RAGE, ALASKA DATE · 8-8-90 RIFF:ERENCE' ARCO CA£'E"D HOLE FINALS' i ..-':: "~ 25 9,':~ )}11A~ RUI;.'.':,':T TDT-.F' RUt..! ../' I" .... '..' ~ ~-- .... .7 --:~ :-_'::--- i -- '.-T.' 0 Fi' [-_- Fi,'. F I::: E: C ri R D I::'. U N ......... "7',: -9 ~:~ F' IS R F F,,' F' C O F: D i;: U N .q..- ,..., ( -- ... _ ._. · "}. - 7 '7 - '7 .S -- 90 Fi' E R F I::'. E C 0 F: '[) R U i'..~ 4 -- i 2 '7 .... 2:5 -- 9 ,:-} F' I-" R F F.: E C 0 R D Fi..' U N Z~. .... { ":' F:~ -- :":', -- '::.' ;:'~ I"': Fi L. I_.. A R/' Fi' F' [:~.'. r: R i I i'..J 5: - 5 7 '- 2 '- 9 ,:'} F' I.:: Fi: F' R F' C 0 R :C' I:,' U ix] .; .... i 4 '7 - 2 '?: -- 90 T Iii: kJ F',," N 0 T ~ E R LJ N 6-S 8- i -90 CC:L. RUN ? -" :": .}.": ,6 -" 24 --9 ':'} F' I:- R F' R l.:- C 0 F,' :() R L.I N i '": ": " 6 - ?' (_":, · .:,-.., 6'- i F'E:F..'F' RECORD RUN i :'5.-- ':? 6 '7 -- 28 -- 9(:) T B [.; C LJ 'i"T E R R El C 0 F?. D F,' U i'.! i 5.-i 9 ·7--~ 8-90 BRK-DOWN 'i"EHF' RUN .,. L.E~-~I,I) E: T E C.: ]" I C~ i'-~/" F' ]: T,'.'.: I.,:U N F:'Wi)WJ -.2 7 .... 2J -'"?,:':) ' "" / " F'WhWi-2 7-22-'7'0 I_FAK DETEC'i"ION/F'IT:,7 RUN F'I...EF'~SE: ,S'IGN AND RE]"LJF~.'.iW 1"HE ATTACHI-ZI) COF:'Y AS RE[;FIF'-f' OF' DA R [ EIY :O HAVE: ~'::: i"-~.ICF, bAY! AUG ska Oil & Gas Oons. Gomm't s,:'~ L.I._ Y HOFFEC ..... An I<' F' P Ala chor A Pr', P r'~ v I:' D ATO--i _529 /~/~I~ ~/ 'T'R. AN S :~- 9,::~J i 4 7' I) I £' T ~, .l: BLIT I []N CIFNTRAL FILES ~,: F'H II_L T F',S' CHEVRON F'B WELL F]:L_ES D & M R & D EXTENSION EXF'LORATION :,$ BPX EXXON' :~ S'I"A'TF OF AL. ASK A MARATHON 'FEXACO MOBIL T A, C A h C 0 ,':..;'CH S i'-: H $ C iq ,'? C H S C l.-i A "F L A .<-;' fiLS ,'"-',' C H A'i- I_ A ':: HL.S' HLS ,S: C FI C A iff C 0 ['; A F-i C 0 C A id C 0 STATE OF ALASKA ALASk .)IL AND GAS CONSERVATION APPLICATION FOR SUNDRY Ai-'PROVAES'"' 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 Other 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB) ARCQ Alaska, Inc. Development X 51 RKB feet 3. Address Exploratory Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 Ser~oe Prudhoe Bay Unit 4. Location of well at surface 8. Well number 90' N & 593' Wof SE cr, Sec. 27, T11N, R15E, UM 4-7 At top of productive interval 9. Permit number 1585' S & 1112' W of NE cr, Sec. 34, T11 N, R15E, UM 75-77 At effective depth 10. APl number 1710' S & 1180' W of NE cr, Sec. 34, T11 N, R15E, UM 50 - 029-20189 At total depth 11. Field/Pool 1720' S & 1190' W of NE cr, Sec. 34, T11 N, R15E, UM Prudhoe Bay Oil Pood 12. Present well condition summary Total depth: measured 9400 feet Plugs(measured) true vertical 9017 feet Effective depth: measured 9328 feet true vertical 8949 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 135' 20" 240 sx 135' 135' Surface 2705' 13-3/8" 3500 sx 2701' 2701' Production 9373' 9-5/8" 1125 sx 9373' 8992' ,q ,, , ,~! ~&irI ~1~iJ'f i~" ",, Perforation depth: measured 9250-9266'; 9272-9290' ~,;ii'."i;. ir'.ii' ~,~ ,;;','r'' true vertical 8879-8894'; 8900-8917' ' ..:",'iX/,:.. ,,..i'.~'"",~:~"' ::;:.:.;:,~ .....,..~ ....- ..~ ... ~.:.... Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, 8736' MD Packers and SSSV (type and measured depth) Brown 3H packer @ 8625' MD; Camco Bal-0 SSSV @ 2223' MD 13. Attachments Description summary of proposal x Detailed operations program .. BOP sketch x 14. Estimated date for commencing operation 15. Status of well classification as: July 1990 16. If proposal was verbally approved Oil X 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 ~~'~.~44,~ ~ L.~L~"~ Title Sr. Area Operations Engineer Date [ i",~ FOR COMMISSION U~I:: ONLy Conditions of approva '~Notify Commission so representative may witness ~ Approval Plug integrity .... BOP Test .,, Location clearance,I No.~ (~ _ ,..~'".¢~::~ . Mechanical Integrity Test SubSequent form required 10- ~.c,/i ORIGINAL SIGt'.iFD 8¥ _Approved by order of the Commissioner Co.,m~i..s_.signer Date "I [ Iq ICl Form 10-403 Rev 06/15/88 413 APl: Returned- SUBMIT IN TRIPLICATE DES._RIPTION SUMMARY OF PR, . OSAL ARCO Alaska, Inc. proposes to perforate DS 4-7 at selected intervals within the Sadlerochit formation. 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 Depths' 8968' 8981' 9007' Ref: BHCS 1/28/76. WDM' 7/12/90 1. ~)000 PSI ?" WE:LLHCAD GONN£CTOR FLANGE 2. SO00 PSI WIR£LIN£ RAIDS (VARIABLE SIZE:) 3. $000 PSI 4 1/6" LUBRIC, ATOR 4. 5000 PS~ 4 ~/6" fLOW TUB[ PACK-Orr 2 H]REL ]NE ~ULI BOP EOUIPHENT ARCO Alaska, Inc. Prudhoe Ba~ _,~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manage,' September 15, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-7, Approval No. 8-744 - REVISED Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/RAC/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 4-7) Wl-3 ARCO A~aska, ~nc. is a Subsidiary of AtlanticRichfie~dCompan¥ AR3B---6132-O STATE OF ALASKA ALASK~ 'LAND GAS CONSERVATION C~ MISSION REPORT' SUNDRY WELL OP -r.IATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing ~ Repair well Other X 2. Name of Operator ARC© Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 90' N & 593' W of SEcr, Sec. 27, T11N, R15E, UM At top of productive interval 1585' S & 1180' WofNEcr, Sec. 34, T11N, R15E, UM At effective depth 1710' S & 1180' W of NEcr, Sec. 34, T11N, R15E, UM At total depth 1720' S & 1190' W of NEcr, Sec. 34, T11N, R15E, UM 6. Datum of elevation(DF or KB) 51' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number DS4-7 9. Permit number/approval number 75 - 77 / 8 - 744 10. APl number 50 -029 - 20189 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth' measured true vertical 9400 feet Plugs(measured) 9017 feet Effective depth: measured 9328 feet true vertical 8949 feet Junk(measured) Casing Length Size Cemented Conductor 135' 20" 240 sx AS Sudace 2650' 13-3/8" 3900 sx Permafrost II Production 9322' 9-5/8" 1000 sx 'G'& 125 SX Permafrost II Measured depth True verticaldepth 135' 135' 2701' 2701' 9373' 8992' Perforation depth: measured 9250 - 9266'; 9272 - 9290' true vertical 8890 - 8905'; 8911 - 8928'; Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8737' MD Packers and SSSV (type and measured depth) BeT Packer @ 8625' MD; Camco BaI-O SSSV @ 2223' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) SEE ATTACHED Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 5251 20718 8181 3506 3573 3638 Tubing Pressure 1049 244 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 /¢~'~'~f./~/,4.~,...,,/ Title Operations Engineering Manager Form 10-404 Rev 06/15/88 D.M. FIFE Date SUBMIT IN DUPLICATE DS 4.7 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEI=71:: FOR WA'r-kR SHUT.OFF 12111188: Performed Fill Cleanout, followed by pre-squeeze stimulation as follows: MIRU CTU & Stimulation Equipment. RIH w/CT and washed perforations at: 9048 - 9049' MD Ref. Log: BHCS 1/28/76. 9133 - 9151' MD 9190 - 9239' MD 9242 - 925O' MD 9250 - 9266' MD 9272 - 9290' MD Pumped the following treatment: 71 bbl~ 12% HCl w/Xylene, followed by, 68 bbla 8-1.5% HCI-HF, followed by 71 bbl, 12% HCI. Displaced w/Meth-Water. POH. Rigged down. Flowed well. I 2128188: The Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 pei. RIH w/CT and fluid packed wellbore w/seawater. Pumped 89 bbla cement, squeezing perforatiorm: 9048 - 9049' MD Ret Log: BI-ICS 1/28/78. 9133 - 9151' MD 9190 - 9239' MD 9242 - 925O' MD 9250 - 9268' MD 9272 - 9290' MD Contaminated cement with 200 bbls contaminant. Cleaned out cement. Performed Injectivity test. Resqueeze required. Rigged down. 12131188: A Resqueeze was performed aa follow~: MIRU CT & Cementing Equipment. PT equipment to 4000 pal RIH w/CT and fluid packed wellborn w/seawater. Pumped 69 13bl~ cement, squeezing perforatior~: 9048 - 9049' MD Ret Log: BHCS 1/28/78. 9133 - 9151' MD 9190 - 9239' MD 9242 - 9250' MD 9250 - 9268' MD '9272 - 9290' MD Contaminated cement with 179 bbl~ contaminant. 111188: Cleaned out contaminated cement from WB. 1123188: Reperforated: 9250- 9266' MD 9272 - 9290' MD Ret Log: BHCS 1/28/78. Returned well to production and obtained valid production ARCO Alaska, Prudhoe D~,.v =r~gineerin~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 283 4248, Donald F. Scheve Operations Engineerh'~§ Manager September 6, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-7, Approval No. 7-49 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/MJB/jp Attachment CC: J. S. Dietz, BP J. Gruber, ATO-1478 PI(DS 4-7) Wl-3 ARCO A~aska, inc. is a Subsidiary of AitlanticRichfJie~dCornpany AR3B-.-6132-C STATE OF ALASKA ALASK L AND GAS CONSERVATION C MISSION REPOR'! SUNDRY WELL OF,.:RATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X 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 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 90' N & 593' W of SE cr, Sec. 27, T11N, R15E, UM At top of productive interval 1585' S & 1180' WofNEcr, Sec. 34, T11N, R15E, UM At effective depth 1710' S & 1180' W of NEcr, Sec. 34, T11N, R15E, UM At total depth 1720' S & 1190' W of NEcr, Sec. 34, T11N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 9400 feet Plugs(measured) 9017 feet 6. Datum of elevation(DF or KB) 51' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number DS4-7 9. Permit number/approval number 75 - 77/8 - 749 10. APl number 50 - 029- 20189 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 9328 feet true vertical 8949 feet Junk(measured) Casing Length Size Cemented Conductor 135' 20" 240 sx AS Surface 2650' 13-3/8" 3900 sx Permafrost II Production 9322' 9-5/8" 1000 sx 'G'& 125 SX Permafrost II Measured depth Trueverticaldepth 135' 135' 2701' 2701' 9373' 8992' Perforation depth: measured 9250 - 9266'; 9272 - 9290' true vertical 8890 - 8905'; 8911 - 8928'; Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8737' MD Packers and SSSV (type and measured depth) BOT Packer @ 8625' MD; Camco Bal-O SSSV @ 2223' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) SEE ATTACHED Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 5251 20718 8181 .... 3506 3573 3638 Tubing Pressure 1049 244 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 Operations Engineering Manager Form 10-404 Rev 06/15/88 D.M. FIFE Date .._~.~/Z~'7 SUBMIT IN DUPLICATE DS 4-7 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR WATER SHUT-OFF I 211 1188: Performed Fill Cleanout, followed by pre-squeeze stimulation as follows: MIRU CTU & Stimulation Equipment. RIH w/CT and washed perforations at: 9048 - 9049' MD Ref. Log: BHCS 1/28/76. 9133 - 9151' MD 9190 - 9239' MD 9242 - 9250' MD 9250 - 9266' MD 9272 - 929O' MD Pumped the following treatment: 71 bbls 12% HCl w/Xylene, followed by, 68 bbls 6-1.5% HCI-HF, followed by 71 bbls 12% HCl. Displaced w/Meth-Water. POH. Rigged down. Flowed well. 12128188: The Squeeze was performed as follows: MIRU CT & Cementing EquipmenL PT equipment to 4000 psi. RIH w/CT and fluid p;~cked wellbore w/seawater. Pumped 89 bbls cement, squeezing perforations: 9048 - 9049' MD Ref. Log: BHCS 1/28/78. 9133 - 9151' MD 9190 - 9239' MD 9242 - 9250' MD 9250 - 9266' MD 9272 - 929O' MD Contaminated cement with 200 bbls contaminant. Cleaned out cement. Performed Injectivity test. Resqueeze required. Rigged down. 12131188: A Resqueeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/seawater. Pumped 69 bbls cement, squeezing perforations: 9048 - 9049' MD Ref. Log: BHC..,8 1/28/76. 9133 - 9151' MD 9190 - 9239' MD 9242 - 925O' MD 9250 - 9266' MD '9272 - 9290' MD Contaminated cement with 179 bblS ¢ontaminanL 111189: Cleaned out contaminated cement from WB. 1123189: Reperforated: 925O - 9266' MD 9272- 9290' MD Ref. Log: BHCS 1/28/76. Returned well to production and obtained valid production test. R E F:' F' R Ii:' N C E ' A I';,' C 0 C A,S' E D H 0 I.. E I= :~ N A I_ t -' ;',:.': '.i~: 5,: .... 6 '- iii 9 P I::..' 0 D, I::' R 0 F- I L.. EZ,,'" L.. F:-. A K I..~ E '1' I::. C'! J. 0 N R U r,! i 2 .... i I '.~ '"' 4 "" ti! 9 T' liiZ H F:'/F:' I._ U .[ D D E iq,~' _[ T Y I",' U N '"" ':) 4 ,::~ _. ", .:'.'~ _.. :::~ c;, C 0 I... I... A R/' F:' EZ F:: F:' I:;,' I N i .,'.. .~ ..... ,,:'. ..... ; .. :.".5 '-. 9 5 - t Iii .-. 89 C iq I....-.. G A Ii H A F:: U N t '.?.:'"' 9 ]'.< .... i Ei "" iii 9 I) :[ F F:' l" Ii:' H P R I.J N i S-. t (-) 5 .... .3 .... li~ 9 I iq,J Ii-] C '1" I 0 N F' R t:.J F' I I_ E R U N S .... i 2. 5 .... ','5 .... 89 ]: iq,.J E. C "l' I 0 N I::' R 0 F:' I L. E/'lr' I!!. H P R U N 4 '- "> ' ..... :' ' , ,.. .:> .... ,... 0 ""8c~ CNL-GAiiH~ I.;,' U N 4.... 5: 5 .... t 9-... 89 C N L.-..-r'; A H H A R LJ N i 4 .... ? :5-t '?""~39 CNI..""L, AMMA RUN ,! .... t 5 5-'.L'.<.... 89 I N J ii. C T .1:0 N F:' R 0 F' ]. L. IE I:,: U N i 4 -.. 2 (.> 4 - i .... 89 C 0 I.. I.. A R / F:' I!:' R F:' I::: U ii · 4.--. 26 5 .... t Iii..-. 89 C i'.f L...... £; A M H A R U N i · ......) ~.. ,,- 5 "" 5 S" ,.... ?"- ~ 9 C: Ill I_ L. A R / P E I:;,' F:' F,' U N 5; "' t ? 3 -" 29 "" 89 C r)I... I_ A R /F:' [il R F:' R U N t 7-.-S0 5 .... t'?--89 DUAL. B(JI:(,.~T I"D'F..-F:' RUN '7- 30 5 .... I '?-89 C N I... R U N 9....2FJ ~',.$ .... S0-.89 COL. I_r:~I:;: TO ;~'E'F F:'ATCH RUN t i -.- i E:,5 .... i 0---8'.i;' I... E A I< D E'I E Il; T' I 0 N R t..I N t t --26 '" ' .... .) -.....> -. 8 ..,' l' N ,J E C "f' I 0 N F:' R 0 F I L IF.: / T I_::' ii F:' 14,' I.J N t 8..- '~ 5 .... 8 .-.. 89 F:' I... L.I I D D Iii] iq,~' .'[ T Y / 'l" Iii] M F:' R U N i .. t 8 '"' 9 5 "' 8 '"' 89 F:' I... U I D I) li!] N .~.' '.[ T Y / 'l' Ii:.: M I::' I';: U N t 8 '"' 23 3 -' 26 "" t'39 C 0 L.. I... A R/; P [il R F:' R U N i P I.. E A 3; Il_.- &' I (~ N A N D F< IE T U R N T I"llii] A T T A C I"1E D C 0 P Y A $ R E C Ii:.' I F:' 'I' 0 F:' D A'F A ATL. A ,iN." C A M I._'. 0 C A r,i il; 0 A I' L_ A r::~ 'f' I... A .?;' r:~ 'f I... A ,i~,' C A H t.; 0 HL.;f A 'rL.A,.? I.iL.~' I-i L..,~,' 6' C I.-I ,~' C I.-I C A ~,i C 0 C A Id C 0 C A a C 0 C A H C 0 H I...,S;' R E C; ii: I V E D B Y ,, (,~ Alaska Oil & Gas Cons. Commmslon Anchorage I) I ,S' T R I B L.I T I 0 N · ,'"' CENTRAL FILES ~'"'I::'HII_L. IF',~,' · ,.-"" C I"1E V R ID N P B W E: I.. l_ F:' I L.. ~:.,S' I) & M R & D .... I ' .... :.": f:' -.1: E X'¥ E iq,? 10 N E. X f' I.. il', A'i" I 0 N B X :,-'E X X 0 N :~ ,.¥ T A"I' Iii: 0 F' A I.. A,S' I< A M A R A T I"10 N .,.'"' 'l E ;', A -. O ~,: MOB I I... ARCO ALACK. A, ~NC. F'.O. BOX i(DC~36C, ANCHORA(~E: ALASKA DATE - ..,.~- ~ 6- 8 o~. , REFERENCE · ARCO MAGNETIC TAPE(£') WITH LIS'TING(Z') i -2J 5-'[6-89 i -30 5-J .3-89 'J -3'2 5-i ~3-89 3-c? 5- J 8-89 4-2 5-2~-89 4 -_. ~ _,.q' - '~, '7 - 89 4-7 5-~ 9-89 a-"~6. .. _,~-{ 8-89 5-4 5-~ 'J -89 6-22 ..,~'- { ..'~-89 6-24 5-{ "~-89-. 7-3 5-{ 3-89 ,.. '?-34 .5- t "~-89.. { 2-{ 5-{ 3-89 'J 4-3 5-~ 4-89 PLEASE SIGN CNL JOB$3~3~ CNL JOB,S81 4 CNL JOB:~S8 i '3 CNL JOB~3836 CNL JOB~6~4i CNL '. ,., ' JOB~3839 CNL' L'/ - ~-' JOB~:58:'SU CNL JOB~5855 CNL dOB~SSi'? CNL dOB~5825 CNL dOU~824 CNL JOB,S82'? CNL " JOB~S82S CNL JOB~S8°6~ CNL .dOBbS828 AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. AFl_AS' ATLA3' A ]'LA.%' ATLAS' A -i I_A ',37 A i'L. AE,' ~'~'11_AJ~ A ('LAd:.' A rLAfi: A'f'LAZ A'f'LA~ ATLAS' A]'LA~ ATLAS' AI'LA~ RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-~529 APPROVED ¢____ TRAN~ 89228 DISTRIBUTION CENTRAL F-ILES (CH) CHEVRON D & M TAMMA$.J.B~O,WN (OH) .... '"' MOB I~}:';..~;... ;"', '.-~... :~.,.~gs~.. ,~,. ,~,_ '~ F'HILLIF'5" F'B WELL R & D BF'X $'¥A]' E OF TEXACO F'ILE~ ALASKA THE CORRECTED AP l~ FOR 6-22 IZ' 50-029-208~6. ' '."!'7'.: .... ., Alaska Oil & Gas Cons. Commission Anchorage ARCO ALA~F,A, INC. F'.O. BOX iC~(~3~¢~ ANCHORAGE, ALAS'KA 995 f DATE ' 5-9-89 REFERENCE' ARCO CASED HOLE FINAL£ t-8 4-i 6-89 INJECTION PROFILE RUN t-24 4-8-89 PRODUCTION PROFILE RUN o_i '-' 4-")3-89 TEMF' RUN t 2-'i4 4-i 5-89 PRODUCTION PROFILE RUN 2'-i7 "2-t 7-89 SPINNER/TEMP/FLUID DEN$/GR RUN t 2-25 4-t 33-89 F'RODUCTION PROFILE RUN 4'-7 4-t 6-89 F'RODUCTION PROFILE RUN t 4-2~ 4-t 8- ,.,9 SPINNER/TEMP RUN t 7-2"5 4-i(D-89 ' LEAK DETECTION RUN i 9'-t 4-i 33-89 F'RODUCTiON PROFILE RUN it-33 4-'24-89 LEAK DETECTION RUN i tt-t¢ 4-t 4-89 LEAK DEFECTION RUN t t -t 6 4-i,"~-8':", F'RODUCTION PROFILE RUN t2-'7A 4-i9-89. F'RODUCTION LOGGING SVCS. RUN 1 t2-t0 4-2t-89 GAS LIFT SURVEY RUN i2-29 4-25-89 TEMF' RUN t33-5 4-t 4-89 LEAK DETECTION RUN i3-8 4-22'-89 PRODUCTION PROFILE RUN i 17;-23A 4-233-89 MI INJECTION PROFILE RUN t i4-2 4-i9-89 F'RODUCTION PROFILE RUN t 4-t 8 4-6-89 PITS RUN t6'-tt 4-24-8:7 LEAK DETECTION RUN t'7-6 4-t 9-89 INJECTION PROFILE/TEMP I'<UN i7-8 4-~'7-89 MULTI-RATE INJECTION PROFILE RUN t t8-3 4-2i-89 F'RODUCTION LOGGING $VC$, RUN i i8'-7 4-'2i-89 F't;~ODUCTION LOGGING $VC$. RUN i F'LEAS'E S'IGN AND RETURN THE ATTACHED COPY A~' RECEIPT OF DATA, RECEIVED ,,~,,,,,.; ..m~,.,~,'~,~ - '~' E DAYL. SALLY HOFF~C': '..::( ,.' ATO- t ~'vo · "' CENTRAL FILES ~ - PHILLIF'S '"'.,,. CH E¥ R 0 ~ ~'~ MOB I L ' EXTENSION EXPLORATION '~- BF'X "" EXXON '" STATE OF: · ~. 11' MARATHON ',r'"" TEXACO ALAS'K A C. AMCO C A i'd C 0 CAM[;(] CAMCO C A M C 0 CAMCO O T I ~ CAMCO CAMCO C A ~'i C 0 CAMCO CAMCO A'[LA~ CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMUO A'f'[..A2' A T L A '(J * THE CORRECT AF'I$ FOR 2-t..) I~ 50-()29-"~0':~77 ** THE CORRECT AF'I~$ FOR t6--t I IS 50-029-20516. ,:-~ N C: I'-I 0 f~'. A 6 E .. A I... ,':'~ ,5,' I< A ? 9 5: i O I:;: liiZ F:' IE F;,' E i".! C: E-.E · A I:~ C: (] C A S' E:' i{}, H 0 I... iii; F' ]; i"..! A I... ,':? F.'. I...i i".! i , 2" ,E'::.;" it) I ,~i; "f' I:('. I B U 1' I 0 N :I~ C; Iii: N'f' R A L F' :[ I... E S .,.'"' C t--I iii: V 1:(1 r',,.. N )}&id :IL Iii: X "f' E N ,S' I (:) N I'E X F' I... 0 F~'. A 'f' I (:) N .,,.'"' Ii!: X X. (] N H fi t:;" A "f' I"t 0 N ,,.'"' I'i (] .I.:31 I.. ARCO ALASKA, INC. F'.O. BOX i00560 ' ANCHORAGE, ALASKA 995i0 DATE' t-~'7-89 REFERENCE' ARCO CASED HOLE FINALS 5-i7 4-'7 . 5.-i6 ti-i i2-2 i '":'-":' t i~. '~ - ~_'":' 8 2-5-88 COLLAR/PER!:'- 2-9-88 COLLAR/F'ERF i2/4-5./88 BIF'/'S'IGMA BOREHOLE OVERLAY --~ ~ -~ .- -~ ~ ..! - °-i..- 2-(38 UOL. Lr..~R/I- ERF · .'~- i ,'~-- P., 8 COLLAR/F'ERF - - OI..L~.~I",, I-I"RF i2 tt 88 C' "'-'"-'-'"' --'-i"':'., 88 r:OLLAR,"F'ERf"... 2-i '7--88 C 0 I_ L_ A F,: / F' E t:;.' F'- RUN i , _,'"~" RUN t, 5 · RUN i , ._..~" RUN 'i, 5' RLJN~; i-'5,-,":" R UN i, 5" RtJN i,..; ~" I:~:tJN2 1 -S, 5" I:'L. EA:'::E: SIGN AND RETURN 1'HIE A'FTACHED COF'Y AS I:;'.E:C:EIPT OF DATA, GEAR GEAR A'I'LA~;' GEAR GEAR Gii:'AR G E A R HAVE A NICE DAY! - "% A'r 0-- ~ 5'2 9 ~a ~ & ~s Con~ C~.mmissio~ TRAN~ ~:890~ A F:' PR 0 V E D ...~ ..... BI., , RIBUT]:ON ~ CENTRAl_ FII_EZ 0 CFtE:VRON D & M :~: EXTENSION EXF'L_ORA'f ION ~ EXXON M A I:;: A T FI 0 N ~ MOBIL :,,- F' H :[ L I_ I F' $ F'B WEI...L. FILES R & D ~ 5; A F:"C ¢ $1'Ai"E []F ALASKA · '" T E X A C 0 ..x- THIS I_OG ]:5' F'RINTED WI:TH THE WI:;.:ONG AF'I$.: I'T' ':-'jHOUI_D BE 5,'..)--029"-2(')2i5.. ARCO Alaska, Inc. ,, Prudhoe Bay Engineering Post Office Box 100380 Anchorage, Alaska 99510-0350 Telephone 907 263 8,24.8 Donald F. Scheve Operations Engineedng .Manager September 26, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-7 Permit No. 75-77 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced wello Very truly yours, D. F. Scheve DFS/DMF / j p At tachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 ?!(DS 4-7)W1-3 WELLS3/31 ARCO Alaska, Onc. is a Subsidiary of AtlanticRichfie~dCompany AR3B--6132-C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMisSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend '.'q Operation Shutdown ,~ Re-enter suspended well [] Alter casing .~ Time extension ~ Change approved program iq Plugging '-q Stimulate ~ Pull tubing fq Amend order ~t Perforate _~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 51 ' RKB feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 90' N & 593' W of SE cr, At top of productive interval 1585' S & 1112' At effective depth 1710' S & 1180' At total depth 1720' Sec. 27, TllN, R15E, UM W of NE cr, Sec. 34, TllN, R15E, UM W of NE cr, Sec. 34, TllN, R15E, UM 7. Well number DS 4-7 8. Permit number 75-77 9. APl number 50-- 029-20189 10. Pool S & 1190' W of NE cr, Sec. 34, TllN, R15E, UM Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 9400 feet true vertical 9017 feet Effective depth: measured 9328 true vertical 8949 Casing Length Size Conductor 135 ' 20" Surface 2705 ' 13-3/8" Production 9375 ' 9-5/8" Plugs (measured) feet feet Junk (measured) Cemented 240 s× 3500 sx 1125 sx Measured depth 135' 2701' 9373' ~ue Verticaldepth 135' 2701' 8982' Perforation depth: measured 9135-9151'; 9190-9239'; 9242-9266' true vertical ; 9272-9290' 8760-8778'; 8817-8853'; 8871-8894'; 8900-8917' ~bing(size, grade and measured depth) 5~", 17#, L-80 to 8736' MD Packers and $$$V(type and measured depth) Baker SAB Packer @ 8625' MD; Camco Bal-0 SSSV @ 2223' MD 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation October 1, 1988 14. If proposal was verbally'approved Name of approver Date approved 15. I hereby,gertify that the foreg_oing is true and correct to the best of my knowledge Signed ,~_,¢~,~~_~/~--~¢-1~ Title Operations Engineering Manager Date Commission Use Only Conditions of approval Notify commissionsorepresentativemaywitness I Approval No. [] Plug integrity ~ BOP Test [] Location clearanceI Approved by ORIGI~'~[ SIGNED BY !_ONNIE C. SMITH · -~pproved Copy Returned -- ---Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 WELLS3/31 D. M. Fife, 263-4278 Submit in triplicate DS 4-7 CTU Cement Squeeze Project AFE# 797961 Procedure 1. Shoot squeeze perforations as follows: Zone Perforations SPF V2 9048-9058 LSD V2 9086-9096 LSD (Ref.: BHCS 1-28-76) 2. Make a slickline tag run to verify the PBTD. Last PBTD was 10228' MD (ELM) on 5-7-87. 3. Surge the well with a surge tool. 4. Perform a dispersed xylene/HC1, full strength mud acid wash. Test well. 5. Change out the live gas lift valves with dummys. 6. RIH with coiled tubing and fluid pack the wellbore with filtered seawater. 7. Pump 75 bbls of cement followed by 2 bbls of water and 150 bbls of contaminant. Hold 5100 psi squeeze pressure for 60 minutes. Squeeze off all the perforations as follows: Zone Present Perforations SPF T5 9133-9151 4 R6 9190-9239 4 R7 9242-9266 4 R7 9272-9290 4 (Ref.: BHCS 1-28-76) 8. Jet or reverse out the contaminated cement. 9. Perforate as follows: Zone Present Perforations R7 9242-9266 R7 9272-9290 10. Assess the integrity of the squeeze. 11. Perforate as Zone follows: Present Perforations V2 9048-9068 V2 9086-9104 T5 9133-9151 R6 9190-9239 SPF FSD FSD SPF LSD LSD LSD LSD Reperf Reperf Add Perf Add Perf Reperf Reperf (Ref.: BHCS 1-28-76) (Ref.: BHCS 1-28-76) Other Well Information: Current stares: On production. Expected static bottomhole pressure: 3700 psi. @ 8800' SS. Expected fluid in wellbore at reperforation: seawater. 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF WIRELINE BOP EQUIPMENT 6 5 4 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSi 4 1/16" PIPE RAMS .3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. ,5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. ,5000 PSI 4 1/16" STUFFING BOX CO ] LED 'I'UB ] NO UN ! '1' BOP Ei2U ] PHEN'I' I! SUMMARY OF OPERATIONS - DS 4-7 Began Perforating operations on 7/5/86. RU perforating unit, pressure tested equipment. RIH w/gun #1, shot intervals 9272'-9290'MD (4 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. RIH w/ gun #2 shot intervals 9242'-9266'MD (4 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. Secured well, RD. Depths referenced to BHCS 1/28/86. ARCO ALASKA, INC, P.O. BOX ~0568 ANCHORAGE, ALASKA DATE' 2-t6-88 REFERENCE: ARCO CASED HOLE FINAl. ~-4 ~-22-88 t-~ t-22-RR ~-~6 ~-2t-88 ~-~9 ~-23 4-20-88 t-2~ ~-24-88 2-4-88 4-~R 2-3-88 4-22 ~-29-88 7-t~ 2-5-88 g-54 4-25-88 ~5-t ~-24-88 ~-~7 ~-25-88 t~-28 t-22-88 ~4-22 ~-27-88 ~-2 t-25-88 ~6-5 4-28-88 ~6-~9 2-~-88 ~6-~ ~-28-88 t~-28 ~-2g-88 t7-2 ~-5~-88 ~7-8 ~-25-88 ~7-~8 4-25-88 PR,PRFI...E/FM/TP/FD/W RLIN FLOWMETER RIIN PRD,PRFLE/FM/TP/FD/W RUN PRD.,PRFLE/HF'FM/TEMF'/DEN RI. IN PRD,PRFLE/HPFM/TEMP/DEN/WHUT R~JN PIT~/TEMF' RI. IN F'IT~/GR/TEMP RI.IN PIT~ RLIN F'IT~/TEMP RI.IN F'~T~ RI. IN FLOWMETER RUN PIT2/TEMP RLIN PRD~PRFL. E/HPFM/WHLIT RUN PRD,F'RFL. E/HF'FM/WHLIT/GR RI. IN GAMMA RAY RI.IN PRD~F'RFL. E/HPFM RUN PRD,PRFL. E/$PIN/TEMF'/WHUT RUN IN,.J,F'RFL. E/FM/TP RUN INJ,PRFLE/HPFM/TEMF' RUN PIT£/TEMF' RUN PRODUCTION PROFILE RUN F'RD,PRFLE/$F'IN/TEMP/GR/WHUT RUN F'RD,F'RFLE/HF'FM/GR/WHUT RLIN INJ~F'RFLE/HPFM RUN INJ,PRFLE/HPFM RUN ~, 5" t, 5" 9, 7, t, 4, 5" 4~ 5" 4, 5" 4, 5" t, t, 5" ,y , PLEAS'E SIGN AND RETIJ~ THE~TTACHED COF A,.~ R~.PT OF DATA., RECEIVED BY ~~t!~~~~~s .......... HAVE A N I CE ~/k~sk~ Oil & Gas Cons, Commissi~ PEGGY BENNE'~ ...... ~chomge ATO-t 529 TRAN,~ ~88t G5 /~ AF'PROVED DISTRIBL.IT~ON ~ CENTRAl_. FII_E2 '.,,.PHII_.I._IP2 .,,-'" CHEVRON PB WEI.. L. FTL.E..~ D & M R h D - EXTEN£ION EXPLORATION .-~'.~AF'C ~- EXXON ~ ,.~TATE OF AI..A£KA MARATHON ,-~ TEXACO ~ MOBIl_ ~AMCO CAMCO ~AM£n ~AMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO ARC. fl AI..AgKA, INP.. ANCHORAGE, AL. ASKA 99~10 DATE: REFERENCE: ARCO CASED HOLE PR.PRFI..,E/FM/TP/FD/U FiOWMETER RIIN PRD.PRFLE/FM/TP/FD/W RI.IN PRD,.PRFLF/HPFM/TFMF'/DFN RIIN PRD~PRFL. E/HPFM/TEMP/DEN/~HIIT RUN PIT~/TEMP RIIN PITS/GR/TEMP PITS PIT~/TEMP PIT~ FI_OWMETER PIT~/TEMP PRD~P~FL.E/HPFM/WHL~0il&GasGoDs. CommisC~CRUN F'RD PRFL. E/HPFM/W~[~R ~cborage RUN GAMMA RAY RUN RI.IN 9 ~ .5" "l, RUN ~1 , 5" RUN 'l , .5 · RLIN ~, 5 · RUN "i , 5 · RUN t, .5 · RUN t, 5' P, llN' 'i, 5' RLIN t, 5 · RUN t, 5 · PRD°PRFLE/HPFM PRD.PRFLE/$PIN/TEMF'/WHI.IT INJ,PRFLE/FM/TP INJ.PRFLE/HPFM/TEMP PITS/TEMP PRODUCTION PROFILE IN,,,~.,'~.,,.,,,/~,J. PRD~PRFL. E/HPFM/GR/WHUT INJ~PRFLE/HPFM CAMCO CAMCO nAMnn ~AMCO OAMnn CAMCO CAMcn CAMCO CAMCO CAMCO CAMCO CAMCO CAMCn CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO --~-~ 7-t~ L~'-25-88 INJ,PRFLE/HPFM RUN t , 5" CAMCO PLEAXE SiGN AND RETiJRN THE ATTACHED COpy A,.~ R_LECE:~/~. PEGGY BENNET~ D ' ..... ............. , DaM ~ EXTENSION EXPLORATION ~ ~AF'C ~ ~. / f EXXON f STATE OF AI..A2~A / ARCO AI_A,TKA, IN£, ANCHORAGE, ALASKA 995t0 DATE: 2-~ 6-8R REFERENCE: ARCO CA,~ED HOLE FINAl. t -4 t -22-88 t -t 3 t -22-RR t-t 6 t -2t -RS t --t 9 t -.:.O-DR t -25 i-20-88 t -23 t-24-88 . ,~,{"'~ 4-~ a 4-22 ~ -29-88 9-~4 ~ -2~-88 ~ ~ -~ 8 4 -3~-88 ~ ~-~ ~-24-88 ~ 3-4 7 ~-23-88 ~ 3-28 ~ 4-~. ~-27-88 ~ 6-2 ~ -25-88 ~ 6-5 ~-28-88 ~ 6-~ 9 2-~-88 ~ 6-~ 9 4-28-88 ~ 6-20 ~ -29-88 ~ 7-2 ~-~ -88 ~ 7-8 ~ -25-88 ~ 7-~ 0 ~-25-88 PLEASE $I RECEIVED HAVE ANI PR,PRFI...E/FM/TP/FD/W Ft. OWMETER PRD.PRFLE/FM/TP/FD/W PRD..PRFI. E/HF'FM/TFMF'/DFN PRD~PRFI..E/HPFM/TEMP/DEN/WHIIT PIT~/TEMF' F'IT~/GR/TEMP PIT~ F'IT~/TEMF' PIT£ FLOWMETER PIT~/TEMP PRD~PRFI...E/HPFM/WHUT PRD,PRFLE/HF'FM/WHIlT/GR GAMMA RAY PRD~F'RFL. E/HPFM PRD~PRFLE/$F'IN/TEMF'/WHUT INJ,F'RFLE/FM/TP INJ,PRFLE/HPFM/TEMF' PIT£/TEMF' PRODUCTION PROFILE PRD~F'RFL. E/~F'IN/TEMP/GR/WHUT F'RD~F'RFI...E/HF'FM/GR/WHUT IN,J~F'RFLE/HPFM INJ , PRFLE/HF'FM GN AND RETI.~AN~ Tt--J;E.&~XT~~ COF_~ RI.IN RI IN RI.IN RI. IN RI.IN RI. IN RI.IN RLIN RI.IN RI. IN RUN RUN R.I.IN RI. IN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RECEIPT OF DATA., ~AMCO CAMCO ~AMCO CAMCn CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO PEGGY BENNETT AT0-t529 TRAN£ ~88t05 APPROVED DI~TRIBLITION ' CENTRAl.. FII_EX ~ . -,-'"CHEVRON D & M · ,.'" EXTEN,~ION EXF'I...ORATION .~ EXXON MARATHON ~~ MOBIl_ -.-'"PHI I_.1._ I F',S' PB WELt.. FTI. EX R & D ~'"' ,~AF'C. .~ ,S'TATE OF AI..A,S'KA .~ TEXACO ~' P R 11'4 T I... ~"" ..... ' ....... ,. ' F: F,.l::.(,l:-' I...E'T'TFF';.'i I)ATA ('T'IZN.'7592) ' (' T I:.: t',l 5 9 ? ) I)A'I'[:'-RT."I;07 ]'15 · I AIFI:i'FF:I:-:' RY~TF'H: I.. ['ICAI.. F'OF;.'H.~' ( 1::'~99 ) CI...A.~'.S' (' Z ) A hi ri :! N r. ll',ll.l fi R {'.'. 0 A I. a z~' I< a, I n c, F:',.O, Bo× t(.)():360 A n c h o r a g F..:, A I. a .?.~' k a I) A T E · R E F:' E I:( E: N C [:: ' AI:~CO Cas'ed I.-Io I. e F:'ina I. N i.?rcibl, e ga.q' !njF".c'l'ion F'rofi le F:' r o (:1 u c t: i o n F:' r o 'f i I. e / (; I:;.'. /F:' I... I n j e c t' i o n F:' r o 'f" i [ F..., I I') j e c t.. i o 'n F:"r o f i I. e F:' r' o (':11.~ c '1' i o r) F:' ~" o f i I. (:., Lea k Det:ec t.. i on/l::'H/"f'emF~ ,. H~I., In.jF.-.,c'l'ion F:'rofi I.e His't.::ibl. e (;a:'.,' ]:njec'!'ion F:'rofi I.e 0-.-9, i ("~----8'? 1) ;.~ t' a f r a c / I-.I o i ..(;' t' (.)-. i 4--8 7 F:' u. m p I r, Te m p ,. / (; R R u n t , 5" R un t , 5" I'~ II R u 'n I , ... F;,',t¥~ 'f , 5" Run ~, 5';" F~'.u.i] t , F;,'un I, .5" I:~'ur,'1 , 5" I~ II R u n i , ... Ru.'n t, .5;" C a m (:.: o C a m c o ('.'. a lo ¢:: i] a m c o C a m c: r:.~ C, a m c o ('.'. a l~ ,": ~;.', C a m .r.: o C a m r: o C a mt.: o F'l. ea.~'e .s'ign and re'l'urn 1'he at'facht....',d copy a.s receip'l' Fi: e c (:.) r d s F' r o c e.s' r~r'"T-C~ 011 & Gas Cons. Commisslo ~ ~ A T 0-1 5 2 ? ~ .... Anchorage ~s 'i"ran.~ ~:8759~),'.. ~ A I:) P r o v e:, d D:I: ,.t."'Ft:~ .l: BUT '[ o 'f" d a 'l'a., ~: C e n t.- r a I.F:' i I e,? ¢{: F:' h i I I. i p s' ~",: C'. I') e v )" o)') F' B W e I. I. F' i !. e.? I) ~. H R ~, D ~: E x t' F.. n..-': i o)') IF: x p I. o r a '1' i o)') :I~: Y.,' A F' C ,..'" IZx'~nn. ....... .,. .?t'at'e of A I. as'l<a N a r a !' I') o n :)): T e x a c o · '".0,. i"i o f.'., i I I:;: E }::' Ji!i R E ?:.! C E · A R C O P r' e :~.,.? u ~- e i') ]';? 'i" I::: 7!i 'f:-,' ! I T '[ O N iii: e'~"~ -t' 'c ,:..'~ I. I::' i L e ::.:.: .,,- P h i t. I. i j::, .'..!: C: l':: ,'.:..', ',,.,"'c o 'r; I::' F': t,.t ,.'.5¢, t. I t::' i t. ,':., :::: · "' )7) *. !"J "" R i:.~, 'il) E ::.:: '~' ~'-.'..', '~';.::!: i o :,"~ E x !::, L c', ::" ,-'.-:~ '~' i o'r~ :?,: :ii.' A F:' C :~,I: Ji!~ X X C, '~"t :JJ: ~i: 'l: ...'.~ 't: ~:: O '( A J....'fi .5:..' }'"'J .:.:! 'r' ,.'..'j '{' h 0 'r) :JJ: "!' i-7.) x -..'.-'~ c 0 '"' 75,'.::, I", i I. · .~' .. /.; c. h F"' I. ~:)p e T ~" o I. I::' I. ,::~ p e t ¥' o [ ;? c h I:;; ¢.:.:, c e i v e d B '/.., ............................................................................... I..I r:':'~ V I!!i r-":~ U. ;11 E: E D r:.~ 'r" ! F;,' ,:::, :i~: ...':~ 'n 'n (-.'(, I::' e.', (.:.:, I< ~':'.'~'i" 0 .... t '3 2. 9 '.!i' '" ~' .'-tII. ("l "? :"t TM ' ' I', t--' I''t "' :,,'c', , · : ~. ~..-.. ' .'..-,, f ..,-" , i I:." I::'~ i" C) V 6.? d .................................. : .................... i... ..'0 ;I; ,?;' 'i" F;.: ]; :[i{ t.J "1" ;1: C]I',! a.s~ r'ec:eipt.' o'f' (:la'to RECEIVED FEB 1 0 1987 Alaska 011 & Gas Cons. Commission Anchorage I::'h i I. Lip F:' B U ~..'.:, I. I. F:' i I. (-:.: .'.. ~' I:;~ & .'(," ,, } r~ ~ I( (, :: '" .~ X ,.': :: :: ARCO Ala.<.;'{<a, Inc~ A r, c h o ',"a g e, A L ,:, s' i< ,';', 99.5 I)ATI:::' October t4 ,~986 R E I::' E R E N C E ' A R C (.'). Pi a g n e -I.- i c 'l" a I:~ e ::; w / L i s' 't' i n g "-'-4-7 5--..27.--.86 I.'::CC.~2S()r:,~ CN.-MS,' & avg~ CN ---?--.~3 '.:.$- t -.86 ECCf,:2426 CN--M,?7 & avg, CN (-!., -----"? .... t6 5----S----86 E'CC."J:2.4;:50 CN,.:.,SN,L. SN,CCL.,C.;R & avg,. -----.--t t-t6 9.-.-26-.86 IECC:II:2537 CJq.-J"i5' & 8vg,, CN /75 7-I ¢031¢5-O F:'Lea:'e .'..:ign and re't'tirn 'l:he a't"i:ached COl:>y as' receip'l: Received By ............................................................................... HAVE A NICI":: I) AY! R o :..:.' a r, -ne F: e e J< A T 0 -.. 'l 5.-.. ''~ 9 {::' TRANY ~.'866S9 CN & 6;R o f d a .!: a ~ I)r ez'.? D r e .'.-; I)r es':' Dr es'.<.:' I) 15' T R I B U T ]: 0 N · 'I~ C e n 't' r a I. F' i I. e ~ Chevron I) & M E x 't' e n :: i o~"~ E: x i:~ [ o r a 't' i o n E x x o ~'~ M a r a 't h o n Mob i I. F'h i I. I. i p .? PB WeLL F:'i Les' R & D J{. ('* · · ,,- ,.~ Oil J 0 ,.9't'ate of AI. as'l<a T e x a c: c::, ~ ' ,At, ohm'age ARCO Alaska, Inc. Post Office'b,.,,, 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)W1-3 PI(DS 4-7)W1-3 J. G. Ambrose J. Gruber ARCO Alaska, Inc. is ,3 Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASF. , OIL AND GAS CONSERVATION COMN .SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [.~] Stimulate ~ Plugging rZt Perforate ~ Pull tubing [%; Alter Casing ..... Other '= 2. Name of Operator 5. Datum elevation (DF or KB) .,~ ARCO Alaska, Inc. 51' RKB Feet 3. Ad¢~)eSs~ Office Box 100360, Anchorage AK 99510 6. Unit or P[ooer. tv name , P~-ddtioe 'Bay Unit 4. Location of well at surface 90'N & 593'W of SE cr., Sec. 27, T11N, R15E, UM At top of productive interval 1585'S & 1112'W of NE cr., Sec. 34, T11N, R15E, UM At effective depth 1710'S & 1180'W of NE cr., Sec. 34, T11N, R15E, UM At total depth 1720'S & 1190'W of NE cr.~ Sec. 34~ T11N, R15E, UM 11. Present well condition summary Total depth: measured 9400 feet Plugs (measured) true vertical 9017 feet 7. Well number DS 4-7 8. Approval number 75 -77 9. APl number 5o-- 029-20189 10. Pool Prudhoe Bay Oil Pool Effective depth: measured 9328 feet true vertical 8949 feet Junk (measured) Casing Length Size Cemented Structural Conductor 135' 20" 240 SX Surface 2705' 13-3/8" 3500 SX Intermediate Production 9373' 9-5/8" 1125 SX Liner Perforation depth: measured 9242' -9266', 9272' -9290' true vertical 8871' -8894' , 8900' -8917' ~bing(size, grade and measured depth) 5~" 17# L-80 8736'MD Packers and SSSV(type and measured depth) Baker 3H Packer @ 8625'MD 12. Stimulation or cement squeeze summary Measured depth 135' 2701' 9373' True Vertical depth 135' 2701' 8992' Camco BAL-O SSSV @ 2223'MD 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 ~bing Pressure 5489 5224 1723 1350 1034 5605 5534 2045 1350 1011 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 Form 10-404 Rev. 12-1-85 JGA (263-4361) Opr. Engr. Mana§er Dat e,,~ ,~'/n Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well / OIL ~i[ GAS [] SUSPENDED [] ABANDONED '-3 SERVICE [] 2. Name of Operator' 7. Permit Number , , ARCO Alaska, Inc. "'75-77 __ 3. Address 8. APl Number P.O. ]?,ox 100360, Anchorage, Alaska 99510 50- 029-20189 4. Location of well at surface 9. Unit or Lease Name 90'FSL, 593' FEL, Sec. 27, TllN, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1585' FNL, 1180' FEL, Sec. 34, TllN, R15E, UM 4-7 At Total Depth 11. Field and Pool 1720' FNL, 1190' FEL, Sec. 34, TllN, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Ptudhoe Bay Oil Pool 51' RKBI ADL 28325 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116' No. of Completions 12/31/75 01/28/76 02/04/76w 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 9400'MD 9017'TVD 9328'MD 8949'TVD YES ~ NO [] 2223 feet MD 1850' (Approx.) 22. Type Electric or Other Logs Run DIL, BHCS/OR, FDC, OR/CCL, CBL/VD, Gyro, 6R/C_NL/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.04~ H-Z~O Surf. 84' 32" 260 SX AS cm~. 13-3/8" 72.tb MN-80 Surf. 2701' 17~" 3500 SX PF 11 & 400 SX PF 11 9-5/8" 47.4~ MN-80/ Surf. 9373' 12~" 1000 SX Cla~s G & 125 ]X PF 11 $00-95 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) 9132'-9150'MD 8763'-8880'TVD 4 spf 5~" 8736' 8725' 9188 '-9238'MD 8816' -8864'TVD 4 spf 9242'-9266'MD 8867'-8890'TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9272'-9290'MD 8896'-8913'TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 10/77 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 7/07/86 6.1 TEST PERIOD ]1~ 1660 1192 520 450 Flow Tubing Casing Pressure CALCULATED,a~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 1011 1350 24-HOUR RATE ~ 5605 553t~ 2045 27.0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit ir~ duplicate O F O L O (; I C ~,I A F:( I(. E: R S '1" 8877' Top Sadlerochit 9310' Bottom Sadleroch 3 '1. L.. I S T C) F A T T/\ C H IVl E ltl -I' S , TRUE \J'Eu{T, D[(P'I'H 85].9' N/A 8932' 32. I hereby (:erl i'fv that ~he fore~toi'nfl is true and dorrecl to tl~e best o'f my k'n'6vvtedqe :" ............ '' ' ( ................................ s i.q n~?~:l ................. Ti t I e ........ _~.a_g~.[ ............................... r)~ t e INSTRUCTIONS General' This form i,s designed for submit:ting a cornplel:e and correct well completion report and log on all tvpes ot: lands and leases in Alaska. I'l:em 1' Classit:ication of Service Wells' Gas injection, water iniection, steam injection, air' injection, salt water disposal, water supply 'for injection, observation, injection 'for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) fordep'th measurerTtents given in other spaces on this form and in any attacl'~rnents. Item 16 and 24' I'f this well is cornpleted for separate production from more than one interval (multiple completior~), so state in item 16, and in item 24. show the producing intervals for only the interval reported in item 27. Submit a separate form 'for each additional interval t:o be separately produced, showing the data perl:iner~t 'to suct~ interval. 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ltem 23: Atl:ached s, -l~')plemental, recor"d,.~ for' this well should show the details o'f any multiple stage cement.- lng and the location of the, cementin,c tool. Item 27' Mel::hod of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersil:)le, Water-In.. jec:tion, Gas lniection, Shut.-in, Ott"ler-.explain. Il:em ,,._")~',._.,. If no cores tal<en, indicate "none". F r' rm 1 0.4,0'? ARCO ALaska, Inc. I::'~0. Box t00;360 ,-,nt. horage, ALa:ska 99~ 1 0 DATE:' Ju. Lyt 4:t986 RE:.F'E RI:-'N CE 4.-'7 4-t.. ''~ ~ 4...-'23 4.-5;3 ARCO Cased Hole Final. 5-26-.86 CN/[~R Mul. tis'pac:e Rtll'i t [~' ;3-.-2-.-86 ACBLog VDI.../,~ i gn Run t 5" 4-.-9-86 ACBLog VDL./5'ign Run t 5' 4-t t .... 86 ACBI...og VDl../.~ign Run 'i5' 6-24'-- 4 .... 7-86 A[;BL.o~ VI)L../$'i gn Run t '5" e c e i v e d B y ..... ~ ........ ¢ ..... ¢,..:,;.::,.. ZL~'L;...] .......... ,%~L',P' ~' '~ ' "''~ ¢'''' I...inda Flul. ce A T 0 - t 5 '29 Dr e.s.s Dr e.s.s Dr es'~' Dr e.s ~: Dr e~ .s' of data,, D 15' T R I B U 'l' I 0 N "'... I::'h i I. I. il.'. .. t::'B We L L R & D :~ .*;' o h i c', :II: ,?:,' 't' a 't' e o f '"'-,rTe .x a c o A I. as'k a ARCO Ata:?ka, Inc P.O. Bo× t08360 Anchormge, A!mskm REFERENCE' 9-75i 5-i 7-86 Bmske} F'Iow..'~e~:er Run i 9-6 ~ ~ ..... ~-,7-$o b~mma Ray 2pi:~nmr Ru~':, i 2-!6 5-18-86 Tempera~ttre Log .Run I -18 ~' I°-86 Temp¢=r: ~. - u¢ ~ :.i:',D %oq 4-7 5:-1 6-86 Gamma Ray S'p i i~nel' "'r: ,~ j j,- -- ~ 3-.27 5-~ 4--8~ Tamp er ,:: 't' :::- e Log Run 4 5' C a m C O f::: .:4 ~,; c -:.':'-- Camac C a ,,':'~ c: o F': A ii! C C: F'l.e~e ~iqn and return ~hm attached copy as receipt of d~la. .. Received By. HAVE ~ ~ICE DAY! irma Carkin " AT0-1529 TRAN$ ~'' ~8e, 348 ',", v '~TRIBUT ]'ON ~--"~/ . Aiaska Oi; &'Gas STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION COMM,,.,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~--' Suspend _~ Operation Shutdown [~; Re-enter suspended well "' Alter casing ~] Time extension 21 Change approved program '-' Plugging ~ Stimulate ~i Pull tubing '- Amend order 7~ Perforate~ Other 5. Datum elevation (DF or KB) feet 2. Name of Operator AP. CO A_lasl~, ~c. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 90' N & 593' W of SE cr, Sec. 27, TllN, R15E, At top of productive interval 1585' S & 1112' W of NE cr, Sec. 34, TllN, R15E, UM At effective depth 1710' S & 1180' W of NE cr, Sec. 34, TllN, R15E, UM At total depth 1720' S & 1190' W of NE cr, Sec. 34, TllN~ R15E~ UM 11. Present well condition summary Total depth: measured 9400 feet true vertical 9017 feet Plugs (measured) 51' RKB 6. Unit or Property name l~'ud_hoe 3~y I~d_t 7. Well number DS 4-7 8. Permit number 7S-77 9. APl number 50-- 029-70189 10. Pool Prud~oe Bay Oil ?ool Effective depth: measured 9328 feet true vertical 8949 feet Junk (measured) Casing Length Size Structural Conductor 135' 20" S u rface 2705' 13-3/8" Intermediate Production 9373' 9-5/8" Liner Perforation depth: measured 9133'- 9151' Cemented Measured depth True Vertical depth 240 SX 135' 135' 3500 SX 2701' 2701' 1125 SX 9373' 8992' , 9190 - 9239', 9252' - 9262', 9272' - 9277' true vertical 8760'- 8778', 8817' - 8853', 8877' - 8885', 8895' - 89007' ~ .... i i~ Tubing (size, grade and measured depth) t5~'~' 17# L-80, 8736'~) Packers and SSSV (type and measured depth) Brown 3H Packer ¢. 8625'MD C~3mco BAL-O SSSV 0 2223'MD 12.Attachments Description summary of proposal J~ Detailed operations program FL-J BOP sketch 13. Estimated date for commencing operation June 1, 1986 14. If proposal was verbally approved Name of approver ,7..,,'".,. Date approved 15. I hereby~ certify th,at thc foregoing is true and correct to the best of my knowledge Signed 4~¢!~,~. ,,~~¢,~.~ Title Operations Engineering Manager Commission Use Only Conditions of approval Approved by Form 10-403 Rev 12-1-85 Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI ~ :b,~,,~ .,' ~:~.::,.;:':,.,.i,',' :..' ,".' · ........ . .............. by order of ~. L. ~/~,..~ ..... Ok, Commissioner the commission Date Submit in triplicate (JGA 263-4361) ARCO Alaska, Inc. proposes to perforate DS 4-7 at selected intervals within the Sadlerochit Sand of Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. Ail wireline work will be done through a 5000 psi ~ 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 1-28-76 Proposed Perforation Intervals: 9048' - 9068-MD 9086' - 9104'MD 9242' - 9252'MD 9262' - 9266'MD 9277' - 9290'MD STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION COMM',_,¢ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2~' Suspend ~ Operation Shutdown ~ Re-enter suspended well 1'2~! Alter casing Time extension ~- Change approved program Z_~ Plugging F_2 Stimulate [2 Pull tubing ~' Amend order [£ Perforate~' Other 2. Name of Operator ARD3 A_las~% ~tc. 3. Address Post Office Box 100360, Anchorag% AK 99510 4. Location of well at surface 1093' S & 345' W of NE cr, Sec. 34, Ti!N, R15E, UM At top of productive interval 1363' N & 1972' E of SW cr, Sec. 34, TllN, R15E, UM At effective depth 1224' N & 1594' E of SW cr, Sec. 34, TllN, R15E, UM At total depth 1156' N & 1539' E of SW cr, Sec. 34~ TllN~ R15E~ UM 11. Present well condition summary Total depth: measured 10715 feet true vertical 9084 feet Plugs (measured) 5. Datum elevation (DF or KB) 64' RKB 6. Unit or Property name ~rud~oe ]~v Urd_t 7. Well number DS 4-3 8. Permit number 7]-5 9. APl number 50-- o?.q.-?r~92 10. Pool Prudhoe Bay Oil Pool feet Effective depth: measured 10625 feet true vertical 9015 feet Junk (measured) Casing Length Structural 115' Conductor 911' Surface 2705' Intermediate Production 10669 Liner Perforation depth: Size Cemented Measured depth ~ue Vertical depth 30" To Surface 115' 115' 2~' 575 SX 911' 911' 13-3/8" 2135 SX 2705' 2705' 9-5/8" 1880 SX 10669' 9033' measured 10390'- 10415', 10452'- 10498', 10514'- 10558', 10567'- 10595' true vertical 8821'- 8840', 8858' - 8903', 8915' - 8949' Tubing (size, grade and measured depth) 5~" 17# Mq-80 & ~4~' 12.6# Mq-80, 9900'MD Packers and SSSV (type and measured depth) Baker SAB Packer ¢ 9715'MD Ot_i~ ROY SSSV ¢ 2]g4'MD 12.A~tachments Description summary of proposal Detailed operations program [] BOp sketch 13. Estimated date for commencing operation June 1, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby, dcertify thaLthe foregoing is true and correct to the best of my knowledge Signed ~'/~~~,.,~ Title Operations En~_neerinK ~nager Commission Use Only Date Conditions of approval [] Plug integrity [] BOP Test ' :" · Approved by[~; Notify commission so representative may witness [] Location clearance Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 ,(JGA 263-4361) Submit in triplicate ARCO Alaska, Inc. proposes to perforate DS 4-3 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 VIP 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 4-1-71 Proposed Perforation Intervals' 10290' - 10340'MD STATE OF ALASKA ALASKA U,L AND GAS CONSERVATION CO~vlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well /i, OIL ~(X GAS [] SUSPENDED ~ ABANDONED [] SERVICE [] / 2. Name of Operator 7. Permit Number ARCO A]aska, Inc. 75-77 ...... 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20189 4. Location of well at surface 9. Unit or Lease Name 90' FSL, 593' FEL, 5ec.27, T11N, R15E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1585' FNL, 1190' FEL, Sec.34, T11N, R15E, UN 4-7 - At Total Depth 11. Field and Pool 1720' FNL, 1190' FEL, Sec.34, T11N, R15E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i I Pool 51' RKB ADL 28325 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16.--No. of Completions 1 2/31/75 01/28/76 02/04/76* N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9400'MD, 9017'TVD 932.8'MD, 8949'TVD YES Lz~x NO [] 2223feetMD 1850' (approx) 22. Type Electric or Other Logs Run D I L, BHCS/GR, FDC, CR/CCL, CBL/VD, Gyro, GR/CNL/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 Surf 84' 32" 240 sx AS cmt 13-3/8" 72.0# MN-80 Surf 2701' 17-1/2" 3500 sx PF II & 400 sx PF II 9-5/8" 47.0# MN-80/ Surf 9373' 12-1/4" 1000 sx Class G & 125 sx PF II S00-95 -- -- 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) 9272' - 9277' 5-1/2" 8736' 8625' 9252' - 9262' 9188' - 9238' w/4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9132' - 9150' DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED N/A 27. PRODUCTION TEST -. -- Date First Production Method of Operation (Flowing, gas lift, etc.) 10/77 F1 owl ng Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO -- 4.1 TEST PERIOD ~ 1049.7 727.4 0 27° 62/~64/ 693 ., Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1327 0 24~HOUR RATE ~ 6145 4258 0 27.0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ':'" '"':" ',i. ...,. I ""' 'r;i' ,: ":'_::"" .'.'..;?.: .?t:~. .,$, ~ ~I,.m.. .... ' .... ~ ..~, ,~:,., .,: -;,:.,. Form 10-407 Rev. 7-1-80 * NOTE: Well was perforated 5/3/77. Well was recompleted 2/13/86. CONTINUED ON REVERSE SIDE DAM/WC86 Submit in duplicate~¢)// Top Sadie 'ochit Base Sad] erochi t 8877' 8519' N/A ,,, 9310' 8932' Workover Wel'l Histsory 'i;~ ,2 - ........................... .... ~, I her el~y (,()~ I.~[y t lint the fc,x'e~-to~B:l m true and (orr'eot lo the best o't ~ny t<r~owle, lqe I '/"~ ~ ....... ~1'- ~ - Assoc~at:e Engineer _ ~ ~, :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: . :" INSTRLICTIONS C.~c. nc.r'al' This 't:orn~ is designed for' sL~bmitting a complete and correct well cor-npletiorl repor't arid log or'l a [ I t V P es o f: la n d s a n d I eases i n A I a s k a. It:em 1' Classit:ication of Se'v ce W/ells: Gas injection, water injec',tion, steam in.ie, ction, air irliection, salt war:er disposal, vval:er st~l:)pl¥ for injection, observation, in ectior~ 'for in-situ combustion. Item 5: indicate wt~ich elevation is used asr-~'-,-,c ft-;~ (.nc~.'~ (wl~ere not o'therwise shown) for deptl~ n'~easurer~'~ents give~ in other spaces ()n this 'form and in any attachments, lte~¥'~ 16 and 24.: [-f this well is completed 'for separate production from more than one interval (mul-tiple completion), so state in iterT~ 16, and in item 24 show the producing intervals i:or only the inl:erval r(:j., or ted's) ..... ~' [n item ~' ,,:.7. Submit a separate form for each additional interval to be separately produced, sl~owin(..] the da'ha pertinent to such interval. ,,' Item 21' Indicate whether from .ground level (G L) or other elevation (DF, KB, etc.). Item 23' Attached ..uppterner~tal records for this well should show the details of any multiple stag{!:' cement- ing and tl~e location o'f the cementing tool. Item 27' M. ethod of C)pera'tion" Flowing, Gas Lift, Rod Pump, Hydraulic, Pump, Subr'¥~ersible, Wa'ret In.- jection, Gas Injection, Shut~in, O'ther.-explain. Item 28' It: rio (:ores 'tal<en, indicate "none". ARCO Oil and Gas Company ,, Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only, mstr~ct I Cou,,,y. ¢ .... ~, o,b .... gh ~State Alaska I North Slope Borough Field ILease or Unit ?rudhoe Bay I ADT, #28325 ITitle Recompletion Auth. or W.O. no AFE AS0308 WWS #1 API 50-029-20189 Operator Alaska Well no. 4-7 W/O ARCO Alaska, Inc. Workover 1/26/86 1800 Hrs. Complete record for each day reported Date and depth as of 8:00 a.m. 1/27/86 1/28/86 1/29/86 1/30/86 1/31/86 2/01/86 thru 2/03/86 ARCO wi Prior status if a W.O. 21.66% 9-5/8" @ 9373' 9279' PBTD, Att to retrv SSSV 9.1 ppg Bridgesal/Diesel Accept ri~ @ 1800 hrs, 1/26/86. ND tree, pull BPV. w/diesel. RU Otis, tst lubr, att to retrv SSSV. Load tbg 9-5/8" @ 9373' 9279' PBTD, Wt up Bridgesal fluid 9.2 ppg Bridgesal/Diesel Pull SSSV, att to shift slv, failed, RD Otis. Bullhead kill pill to perfs, hesitate, locked up @ 600 psi std'g press. RU Schl, perf tbg f/8540'-8542' & 8544'-8547' w/4 SPF, 0° phasing, RD Schl. Att to kill Well w/9.2 ppg Bridgesal/diesel fluid; stiff formation rtns. Observe well, ck kill pill; taking fluid @ 350 psi, .5 BPM. Wt up fluid to 9.6 ppg. 9-5/8" @ 9373' 9279' PBTD, Chg over fluid sys 10.2 ppg NaCl/NaBr Wt up fluid, pmp kill pill #2, chase w/9.6 ppg diesel/brine. Sqz perfs. Displ ann w/9.6 ppg brine/emulsion fluid; stiff formation rtns. SITP = 200 psi. Chg out fluid to 10.2 ppg NaC1/NaBr. 9-5/8" @ 9373' 9279' PBTD, CBU 10.2 ppg NaCl/NaBr Displ well to 10.2 ppg brine. Set BPV. ND tree, NU & tst BOPE to 5000 psi. Spear tbg hgr, shear out PBR, CBU. 9-5/8" @ 9373' 9279' PBTD, RIH w/OS 10.2 ppg NaCl/NaBr CBU, POH w/5½" tbg. #1 & RIH on DP. 9-5/8" @ 9373' Chg rams to 3½" & tst to 5000 psi. PU FTA ./.'. ':': "". ':i) ''~ :'.~x.,.'t': '"'~,;. ,'::" 9279' PBTD, RIH w/FTA #6 10.2 ppg NaC1/NaBr ". Fin RIH w/FTA #1, latch onto fsh, POH, no rec'y. RIH w/FTA #2, latch onto fsh, wrk & POH; no rec'y. RIH w/FTA #3, latch fsh, POH & LD fsh. PU pkr mill, RIH w/FTA #4, mill pkr, POH, chg pkr mill. RIH w/FTA #5, mill pkr, rel pkr, CBU, POH slow jarring pkr thru colrs, pkr stuck @ 2653'. Jar free, POH, no pkr. PU FTA #6 & RIH. The above is correct Signature [% ~, I Date I For~'0r~'preparatlon and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, 2/21/86 ITM Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drdl stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets unlil final completion. Report official or representative test on "Final" form. t) 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 siring until completion. District Field Date and depth as of 8:00 a.m. The above is correct Alaska County or Parish North Slope Borough Lease or Unit Prudhoe Bay ADL #28325 Complete record for each day while drilling or workover in progress 2/04/86 2/05~86 2/06/86 2/07/86 2/08/86 thru 2/10/86 2/11/86 State 9-5/8" @ 9373' 9279' PBTD, POH w/fsh 10.2 ppg NaC1/NaBr RIH w/FTA #6, tag fsh @ 2650', jar loose, POH & LD pkr & tailpipe. RIH w/RTTS & FO closing ti, set RTTS @ 2738'. Set csg & FO's to 3000 psi, POH. RIH w/FTA #7, tag fill @ 9150', latch onto fsh & POH. 9-5/8" @ 9373' 9279' PBTD, RIH w/FTA #9 10.1+ ppg NaC1/NaBr POH w/FTA #7. MU & RIH w/FTA #8, rm thru perf f/9157'-9195'. Wt brine back to 10.1+, POH. Spot Bridgesal pill, POH. MU & RIH w/FTA #9. 9-5/8" @ 9373' 9279' PBTD, PU BHA 10.1 ppg NaCl/NaBr Fin RIH, mill thru perfs, circ, spot kill pill, POH, LD mill. RIH w/FTA #10, tag up on perfs, wsh thru, tag fsh, mill over ragged TOF, latch, rev circ & POH w/4½" tbg fsh. PU new BHA. Alaska 9-5/8" @ 93.73' 9279' PBTD, Drl cmt 10.1 ppg NaCl/NaBr RIH w/scrprs to 8890', POH. RIH w/RTTS on 3½" DP, set @ 8830', tst csg to 3000 psi, POH. RIH w/bit, wsh & rm 9212'-9268'. Drl cmt @ 9268' while filtering brine. 9-5/8" @ 9373' 9328' PBTD, Mill pkr 9.9 ppg NaCl/NaBr Drl FC & firm cmt to 9328', rev circ & filter brine, POH, LD DP. Chg pipe rams, tst; 0~. RU & rn 5½", 17#, L-80 R-3 AB Mod 8RD tbg. Pkr prematurely set @' 7800', att to move w/o success, shear out, POOH, LD tbg. Chg pipe rams, tst. PU FTA #1, TIH w/DP, tag & mill on SB-3 pkr. 9-5/8" @ 9373' 9328' PBTD, POH, LD DP 9.9 ppg NaC1/NaBr Fin mill pkr, CBU, POH, rec'd SB-3 pkr & tailpipe fsh. RIH w/8½" bit/scrpr to 8800', spot salt pill, POH, std back 24 stds DP. Cont POH, LD DP. IWell no. 4-7 W/O S ,~r.~,~ ~ % C %(-~ IDate For form preparation and distribution see Procedures Manual Section 10. Drilling, Pages 86 and 87 2/21/86 ]Title Drilling Superint en~d.ent ARCO Oil and Gas Company Daily Well History--Interim 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 descriotlon of ali cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion, Report official or representative test on "Final" form. 1/ Submit "lnlerim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which od string is set SubmH weekly Ior workovers and following setting of od string until completion, District Alaska North Slope Borough County or Parish Field Lease or Unit Prudhoe Bay ADL #28325 Date and dept. Complete record for each day while drilling or workover in progress as of 8:00 a.m. State Alaska Well no. 4-7 W/O 2/12/86 2/13/86 9-5/8" @ 9373' 9328' PBTD, Rn'g tbg 9.9 ppg NaC1/NaBr POH. PU RTTS, RIH & set @ 2763'. Tst csg to 3000 psi, POH, LD RTTS & 3½" DP. Chg rams to 5½" & tst. RU & rn 5½" tbg. 9-5/8" @ 9373' 9328' PBTD, WO new dummy vlv 9.9 ppg NaCl/NaBr RIH w/194 its, 5½", 17#, L-80 AB MOD tbg & lnd w/SSSV @ 2223', Pkr @ 8625', XN nipple @ 8724', tailpipe @ 8736'. Drop ball, set pkr @ 8617' WLM. Tst tbg to 2500 psi. Shear PBR, shear shear-out sub, set BPV, ND BOPE, NU & tst tree to 5000 psi. RU WL, pull dummy SSSV, pull orifice vlv. RIH to set dummy vlv in GLM, unable to locate. RIH w/new dummy vlv. The above is correct Signature~x,..,~ ~ ~..~' ~ . JDate For fo~'m preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 2/21/86 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided, The "Final Report" form may be used for reporting the entire operalion if space ~s evadable. DistrictAlaska Coun:y or Parish Field Lease or Unit Prudhoe Bay Auth. or W,O, no. ~T tie I AFg AS0308 North Slope Borough ADL #28325 Accounting cost center code State Alaska Well no. 4-7 W/O Recompletion WWS #1 Operator ARCO Alaska, Inc. API 50-029-20189 A.R.Co. W.I. 21.66% Spudded or W.O. begun Date Workove r l / 26 / 86 Date and depth Complete record for each day reported as of 8:00 a.m. 2/14/86 I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well our I Prior status if a W.O. I 1800 Hrs. 9-5/8" @ 9373' 9328' PBTD, RR 9.9 ppg NaCl/NaBr Set dummy vlv @ 8206'. Tst ann to 1000 psi; OK. RIH w/SSSV dummy, could not shear off. Cut WL, POH, set BPV, RD WL. Secure well. RR @ 1500 hrs, 2/13/86. Old TD Released rig 1500 Hrs. Classifications (oil, gas, etc.) Oil New TD PB Depth 9328 ' Date Kind of rig 2/13/86 Rotary Type completion (single, dual, etc,) Single Producing method Official reservoir name(s) Flowing Sadlerochit Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87~ 2/21/86 Title Drilling Superintendent STATE OF ALASKA ,,,:, ALASKA 6, _ AND GAS CONSERVATION CO,, IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERAT · Drilling well [] Workover operatior~L~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 75-77 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20189 9. Unit or Lease Name Prudhoe Bay Unit 4. Location of Well atsurface 90' FSL, 593' FEL, Sec.27, T11N, R15E, UH 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 51 ' RKBI ADL 28325 For the Month of February , 19 86 10. Well No. 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 12.Depthatendofm~nth~f~~tagedri~~ed~fishingj~bs~directi~na~dri~~ingpr~b~ems~spuddate,remarks Accepted' rig @ 1800 hfs, 1/26/86. Killed we]]. ND tree. NU BOPE & tstd. Pulled 5-1/2" tubing. Jarred & milled on fish; recovered pkr & tailpipe. Set RTTS. Tstd csg to 3000# - ok. Attempted to run 5-1/2" tbg. Hilled on fish; recovered pkr & tailpipe. Set RTTS. Tstd csg to 3000# - ok. Ran 5-1/2" tbg. ND BOPE. NU tree & tstd. Secured we]] & RR ~ 1500 hfs, 2/13/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 5-1/2", 17.0#/ft, L-80, R-3, AB-MOD, 8rd tbg. SSSV ~ 2223', pkr @ 8625', tail ~ 8736'. 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED -~n ~ ~ TITLE Associate Engineer DATE NOTE,.--Report this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 1 O-404 DAN/MR20 Rev. 7-1-80 Submit in duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C0MMISSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 4. Location of Well Surface: 99510 90' FSL, 593' FEL, Sec.27, TI1N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) __ RKB 51 ' 12. Perforate Stimulate Repair Well Pull Tubing I6. Lease Designation and Serial No. ADL 28325 Check Appropriate Box To Indicate Nature of Notice, Report, or 7. Permit No. 75 -77 8. APl Number 50- 029-20189 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 4-7 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing [] [] Abandon [] Stimulation [] Abandonment [] [] Change Plans [] Repairs Made ~ Other ~ [] 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). Accepted rig ¢ 1800 hfs, 1/26/86. Attempted to kill well. Perf'd tbg f/8540' - 8542', 8544' - 8547' w/4 spl 0° phasing. Disp well w/10.2 ppg brine. Set BPV. ND tree. NU BOPE & tstd to 5000 psi - ok. Retrieved tb. hanger. Pulled 5-1/2" tbg. Fished & recovered PBR. Milled pkr & recovered. Recovered tailpipe. Set RTTS 8830' & tstd csg to 3000 psi - ok. Drld FC & firm cmt to 9328' While attempting to run 5-1/2" tbg, the packer set prematurely ~ 7800' Milled on pkr & recovered. Set RTTS ~ 2763' & tstd csg to 3000 psi - ok. Ran 5-1/2" completion assembly w/SSSV 8 2223', pkr ~ 8625' & tail ~ 8736'. Set pkr & tstd tbg to 2500 psi - ok. Set BPV. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp tubing w/14 bbls diesel. Secured well & released rig ~ 1500 hrs, 2/13/86. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ~ Title Associ ate Engineer The space below//or Commission use Conditions of Approval, if any: Date ,~-t 3-8Lo By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU14/SN02 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.. Post Office ~ ~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- State Reports Dear Mr. Chatterton' Enclosed are the January Monthly Reports for the following wells' 1A-8 3F-16 3J-13 3N-2A 4-27 L2-25 2A-11 3I-1 3J-14 4-7 4-28 L2-29 2A-12 3I-2 3J-15 4-17 16-21 L3-5 2H-5 3I-3 3N-1 4-18 16-24 L3-23 2X-8 (2) 3I-4 3N-2 4-24 L1-9 .Ugnu State #1 · If you have any questions, please call me at 263-4944. Sincerely, d. ~ruber Associate Engineer JG/tw GRU13/L111 Enclosures ARCO Alaska, Inc. is a Subsidiary of AllantlcRichfieldCompany RECEIVED FEB 1 1986 Alaska 0il & bus G(ms. Gmn~nission Anchorage STATE OF ALASKA ~ ALASKA ~'.,_ AND GAS CONSERVATION cO,..MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operationX~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well at surface 90' FSL, 593' FEL, Sec.27, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 51 ' RKB I6. Lease Designation and Serial No. ADL 28325 7. Permit No. 75-77 8. APl Number 029-20189 50-- 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 4-7 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of January , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig @ 1800 hfs, 1/26/86, Killed well. ND tree. NU BOPE & tstd. fish (pkr) as of 1/31/86. Pulled 5-1/2" tubing. Jarring on 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Associate Engineer NOTE---Report oZhis form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAM/MR03 Rev. 7-1-80 Submit in duplicate ARCO Alaska, Inc. , Post Office Box ,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 18, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 4-7 Permit No. 75-77 4-12 78-18 Attached are the "Intention" Sundry Notices detailing work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS:JEB:dp Attachment cc: SOHIO Alaska Petroleum Co. File Pi(DS 4-7)W1-3 PI(DS 4-12)W1-3 ARCO Alaska, ~r~c. is ,; Subsidia~'y of Ait~anticl~ichfkr:.kfCo~p,?~p.y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 90' FSL & 593' FEL, Sec.27, TllN, R15E, UM Total Depth: 1720'S & llg0'w of NE cr, Sec.34 TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 52 ' RKB 6. Lease Designation and Serial No. ADL 28325 12. 7. Permit No. 75-77 8. APl Number 50- 029-20189 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 4-7 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 [] 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). ARCO Alaska Inc., intends to install Kinley Button Gas Lift Orifices at DS 4-7 in the following manner: 1) MI and RU Electric Line Unit 2) Set Kinley Button Orifices as follows: - place one ¼" orifice at approximately 4500'MD (4500'TVD). 3) RD and unload well. 4) Obtain capacity. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /¢~I'~~Y~ Title Oper. ~.ngr. Mgr. The space below for Commission use Conditions of Approval, if any: Date Approved by CQMMISSIONER Approved Copy ~®t,urned/ By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post October 30, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 4-7 Dear Mr. Chatterton: Enclosed is a Sundry Notice for DS 4-7. We propose to pull tubing and repair this well. ~e expect to start this work on December 15, 1985. If you have any questions, please call me at 263-4944 or Eric Witten at 263-4968. Sincerely, Gruber Associate Engineer J G/tw GRU12/L47 Enclosure STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION CO~/IMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0, Box 100360~ Anchorage, AK 99510-0360 4. Location of Well Surface: 90' FSL, 593' FEL, Sec.27, TllN, R15E, UM 5. Elevationinfeet(indicate KB, DF, etc.) RKB 51' 6. Lease Designation and Serial No. ADL 28325 7. Permit No. 75-77 8. APl Number 50- 029-20189 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number · 4-? 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il 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 Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc., proposes to perform a workover to repair the subject well. The procedure will be as follows: 1. MIRU. Kill well. 2. ND tree. NU ROPE & test. 3. Pull tubing. Retrieve packer. 4. Clean out fill to top of fish. Recover fish. 5. Set 9-5/8" x 5-1/2" packer. 6. install a 5-1/2" x 7" tapered string. Land tubing. 7. ND BOPE. NU tree and test. 8. Secure wel~l & release rig. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within permafrost intervals. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: December 15, 1985 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space b~l/ow for Commission use Conditions of Approval, if any: Approved by ¢~pproved Copy COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 GRU12/SNl 1 Rev. 7-1-80 X) ;? ~i=i: '"' 2 i "?'"' :3 "'"" .... ',iii', -"; ;? t' <'..'~ t' i ~'" ,<':~ ~ 'r' ',.,' ;:.'~ ',:' . f) ;1'7 "'; .............. ;" '"' '''~ ' ... "', ..... ," ~ ...... ...:'.,:'::, '"',:::; ;ii; t' .:':'~ .I. ........ , . ,. I ,: ,? u. i" 'v' (-:.? :.: .... f':' ,'!'? .':':i- ..... i,:'::, ?!; ..... :.?.;'"' i (';: ..... :!!!: '"" .... .... - ..;. i...: 0 h'~ iFi ~;:;~ Y'i 'i") <'..'j '~' <~'t '.i'i': .:'.-'i .S' G." i:;.i (.:' I::' ;'" 'i" ..........f':' · ."':.' . ,."ii, .......,-4 ,.~. :iii', ........ ...,.' .... :]ii: ...;4 'fb ]ti']': I..J :iii: ....... ; "::' '"' ':::' '"" (:: ,:3 ~'n fn ~::'., !"l '"'" . -.;....'". ........ ...; ...... ..':'~ t' <':'~ iii!.: .:~ :!i.' ,;.:.:: I::~ ~'.:i: F: ,;::, 'r' t: ¥;, ,!:.' ... 'i ......: .... ..::, :iii: .... ~'::~"":ii~ .'"' ': ., ' .........' ...,. F:' }i': !..! · ..,. L.: c~ ~'~'~ ;'~'~ o y'~ i") ,.'..'~ 'I- .:':'~ i(']': .;:'~ ..:.' ;:..', i::.] K..', i::' c, 'r' '! ,. 'n ,?i.' "~ ,:!':, "" 2 "? "" 2 ':? ....... ..':!: ::" ..... :::: '"" I::~ f':' i'~, · '..' .'. .', ~ .., ~...~ "7 ...... I.....:TI I'l'i C (3 ARCO ALaska, Inc F'.O. Box Anchorage, ALaska 995t (3 DATE· Sept'ember R r..:' F E R E N C E · A R [; 0 i '~ i 984 Ca.s'ed HoLe F in~ '¥empera'l'ure Log Temper a i.. u, re I...o9 CH CNL Temperature Log I= I. ti i d D e n.s 't' i y D I) 1' / N L.. L.. / G R ,?pinner L. og Injec'l.'ion Prol"'i Le L. o9 R un t Run 2 Run i Run t 5" C a m c c, 5" C a m c: o .5" 5" C a m c o ':~'"DA '5" I)A 5" C a m c (:.', - .5" C a ,',', c c, .sign an(:l ret'urn 't'he a't"t'ached copy as' 'l' R A N S :,",: ''z ') 2 r e c e i p t o '1"' d a t' a ,, "' ~¢1 .... I I) 1. ,:, I' I'~ I B LJ T I 0 N Ch err on E x p l o r a i.' i o n ,S' e r v i c: e.s Exi'en.s'ion ExpI. oration E:x xon Gett'y Hara t'hon Mob i i. Mol:.)i I. E & F:' F:'hi LLip.s Pr udhoe Bay WeLl. Sohio State of ALaska F:'i Les ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 2, 1982 Reference: ARCO PRESSURE DATA D.S.5-6~/ 1-15/16-82 D.S.5-13 ~ 10-10/11-81 D.S.11-5 4/24/82 D.$.4-7~/ 3-24/25-82 Pressure Survey Pressure _Survey Pressure Survey Pressure Survey Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal f/ 207 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO' MARATHON CHEVRON MOBIL & ~"~ Cons GETTY ~n.c.§o/~.,~v~ ?o.,., D&M GEOLOGY ARCO Alaska, Inc. Post Office B !t50 Anchorage.; ,a 99510 Telept~one 907 277 5637 January 21, 1982 Reference: ARCO PRESSURE DATA D.'S.9-3 11/20/81 D.S.3-4 11/20/81 D.S.17-6 11/15/81 D.S.3-2 11/19/81 D.S.17-1 11/1'5/81 D.S.9-1 11/21/81 D.S.16-16 11/15/81 D.S.16-1 i1/14/81 D.S.4-7 12/2/81 D.S.9-8 11/15/81 p.s. 16-11 11/14/81 D.S.9-5 11/22/81 D.S.9-15 11/24/81 D.S.4-6 11/25/81 D.S.9-6 11/16/81 p.s.3-18 11/19/81 D.S.9-4 11/21/81 D.S.9-12 11/20/81 D.S.9-10 11/20/81 D.S.3-6 11/18/81 p.s.3-7 11/18/81 Pressure Surve'y !! II II Il Il Il Il Il Il Il Il Il ll Il Il Il Il Il Il Il II II II II II II II II II D.S.9-6' 12/9/81 D.S.9-6 1/1/81 D.S.9-17 12/10/81 D.S.9-6 12/23/81 D.S. 12-9 1/4/82 p.s. 12-10 1/3/82 D.S.12-12 1/2/82 D.S.12-11 1/2/82 D.S.16-9 1/8/82 II Il II II II II II Il II II DISTRIBUTION /~~ease sign and ~'~return the attachedNORTH GEOLOGY R&D copy as receipt of DRILLING data. PHILLIPS SOHIO MARATHON CHEVRON Mary F. Kellis North Engineering EXXON MOBIL GETTY D&M Pressure survey II II Ii ii II II II II II II II II II II II II II Il II II II II GEOLOGY STATE oF ALASKA Transmittal #902 ARCO Ala$&8. ii'JCl JS a SuoSld,ary OI AHantlcRichhe,dCompany ! I[ " ,,."::-:i-, ~ iT'] , .. : ; ALASKA OIL A~IB GAS CO~SERVATIOfl CO~ISSIO~ t / 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501 TELEPHONE(907) 279- 1433 June 22, 1981 A D M I N I S T R A T I V E A P P R O V A L NO. 165.2 Re: The application of ARCO Alaska, Inc., operator of the Eastern~n~_Op~ting Area, Prudhoe Bay Unit, to replace key wellr~D.S. 4.r~72with D.S. 4-13 in the gas-oil contact moni- toring pro~'~m set out in Rule 9 of Conservation Order No. 165. Mr. J. A. Rochon District Operations Engineer ARCO Alaska, Inc. ?. O. Box 360 Anchorage, Alaska 99510 Dear Mr. Rochon: The referenced application was received on June 19, 1981 and stated that the D.S. 4-7 well will no longer be suitable as a key well because of mechanical difficulties in the well bore. The application also stated that the well D.S. 4-13 would reflect the movement of the gas-oil contact in the area of the field previously monitored by the D.S. 4-7 well. The Alaska Oil and Gas Conservation Commission hereby autho- rizes the replacement of the D.S. 4-7 well by the D.S. 4-13 well as the key well in the gas-oil contact monitoring program pursuant to Rule 9 of Conservation Ord.er No. 165. Yours very-truly, Harry W. Kugler Commissioner BY THE ORDER OF THE COMMISSION /~l'lbU UII dllU k.~db bUIll~Jdlly North Alask? -"istrict Post Office 360 Anchorage. Alaska 99510 ,..~ 7 5637 Telephone 907 '~"' Jerry A. Rochon District Operations Engineer March 19, 1981 Reference: ARCO PRESSURE DATA D.S.3-4 2-7/8-81 Pressure Survey ' D~S.4-7 ~ 3/11/81 " " D. S. 9-'6 2-25/26-81 " " D.S.9-12 2-15/16-81 " " ~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #130 DISI-RIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA r- -'4 · , EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO OH ,and Gas Company ,s a Oivi'~ion of AtlanticRicht~eldCompany ARCO Oil and Gas Company North A Dislrict Post Offi,.,_ ~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 21, 1980 Reference: ARCO Pressure Data D.S. 4-1 5/8/80 Pressure Survey D s ~ .... -~ 5/12/80 " " D.S. 4-6 5/10/80 " " p.s. 4-5 5/15/80 " " D.S. 4-5 9-7/8-80 " " ___ i ~,4-~_,.. 4 F?,I/' __. T ^ T~C -__ STAT FILF;'V~-'3J ,(,-~.-",'x I , : ~: __ ,, ~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 ARCO Oil and Gas Company is a Oivision o! AtlanticRichfleldCompany ,::RECE! V_ED //7- , ::)- ,, NOV 2 5 1980 Alaska 0il & Gas Cons. Commission Anchorage Norlh Alas~' "}istrict Post Offic x 360 Anchorage, ~laska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 14, 1980 Reference: ARCO Magentic Tapes D.S. 1-1 9/5/80 Tape #102144 D.S. 5-9 9/1/80 Tape #102165 D.S. 2-17 8/8/80 Tape #102164 Run 1 D.S. 5-10 10/4/80 Tape #61062 Run 2 .... ' 10/1/80 Tape #61057 Run 4 ease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #805 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MAP~THON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company is a Division ol AllanlicRichlieldCompany Form 10-403 Submit "Intentions" in Triplicate REV. 1-10-73 & "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.) 1. OIL ~l GAS ~--~ WELL I-~J WELL L__J OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 90' FSL, 593' FEL, Sec 27, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 52' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20189 6. LEASE DESIGNATION AND SERIAL NO. ADL 28325 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 4-7 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field/Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 34, TllN, R15E, UM 12. PERMIT NO. 75-77 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT~)FF I-----i FRACTURE TREAT SHOOT OR ACIDIZE REPAir WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAI RING 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 starting any proposed work. Repair opns commenced 2100 hrs, 9/2/80. Rig up to kill well. Pull BPV and shift 5½" tubing sliding sleeve. Circ tubing and 9-5/8" x 5½" annulus w/Brine. ND tree, NU BOP stack and test same. Circ well w/Brine and pull 5½" tubing. Pressure test 9-5/8" csg w/3000 psi, ok. TIH w/overshot and retrieve PBR and K-anchor. TIH w/new K-anchor and PBR assembly, set and test same w/3000 psi, ok. Run 256 jts 5½" 17# L-80 tbg, shear PBR and land tbg. ND BOP stack, NU tree and test same. Test tbg and 5½" x 9-5/8" annulus, ok. Pull dummy tbg safety valve, shift sliding sleeve, and displace tbg and annulus w/diesel Cut off tailpipe at 8726'. SEt and test safety ball valve, set back pressure vaive. Release rig. 1100 hrs, 9/9/80. 16. I hereby certifY that the foregoing is true and correct SIGNED, *~~' 7~~--~:~ . TITLE District Drilling Eng. (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side ARCO Oil and Gas ""~mpany Norlh Alasl s;rict Post Oflice ~,ox 360 Anchorage, Alaska ,99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 21, 1980 Reference' ARCO Cased Hole Finals D.S. 1=10 12/9/79 DSTNDT Run 3 2" & 5" (same log) D.S. 4-6 10/1/80 CNL Run 5 5" D.S. 4-7 ...... ~ 10/1/80 CNL Run 4 5" D.S. 6-3 10/5/80 CNL Run 3 5" D.S. 9-7 10/2/80 CNL Run 2 5" D.S. 9-16 10/3/80 CNL Run 2 5" P~lease sign and return the attached copy as receipt of data. --[-STAT TEC --_]'-STAT TEC CONFER: ' FILF: __ Mary Kellis North Engineering TRA2~SMITTAL #737 DISTRIBUTION NORTH GEOLOGY E~XON R&D MOBIL DRILLING GETTY ENG. ~D~AGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO OH and Oas Company ~s ,30i',,,s~on ot AllanhcRichtletdComo.]ny ARCO Oil and Gas )any October 20, 1980 Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 / _ I co:,v, ">1! RES ENG 1 ENG / _1 ~_eNO~ ---.,! i' ~ -~n~~..- .._ J ~:T,b.T TEC ~! STAT TEC -coNFER: Subject' DS 4-7 (Permit No. 75-77) DS 5-13 (Permit No. 77-26) Dear Si r' ~'~-~ .",- , , : ,~ i~ /7--i: \, ~..~-'~':,'."!'/ I: I '~ ~N¢/ _~ _ !3 ~? ~~o~! I /! ~At T~C ~ Attached please find our completed Sundry Notices of Sub- sequent Report for the subject wells, detailing the individual well workover histories. Yours very truly, P. A. VanDusen District Drilling Engineer PAV'sp Attachments ARCO Oil and Gas ~any August 12, 1980 Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 4-4, Permit No. 71-11 DS 4-7, Permit No. 75-77 Dear Si r' Enclosed is a Sundry Notice detailing repair work to be done on the above-mentioned wells. ~--P. A. VanDusen District Drilling Engineer PAV/jh Enclosures Form 10-403 REV,. 1-10-73 Submit "Intentions" in Trlpllcate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WI~LLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-029-20].89 6. LEASE DESIGNATI{~)N AND SERIAL NO. ADL 28325 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. OIL [~] GAS E~ WELL' ~I WELL OTHER NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchora§e, Alaska 99510 27, T11N, T15E, UM 4. LOCATION OF WELL At surface 90'N & 593'W of SE cr Sec. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 52' RKB Check Appropriate Box To Indicate Nature of Notice, Re 14. 8. UNIT, FARM OR LEASE NAME Prudh0e Bay Unit 9. WELL NO. DS 4-7 (31-34-11-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 1720'S & 1190'W of NE cr Sec. 34, T11N, T15E, UM 12. PERMIT NO. 75-77 )or~, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT~)FF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE'- Report results of multiple completion on Well COml31etlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~ertlnent details, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company proposes to repair leaks in both the 5-1/2" tubing and 9-5/8" production casing by killing the well & pulling the 5-1/2" tubing. The leak in the 9-5/8" casing will be located & evaluated. The 9-5/8" casing will then be patched and/or squeeze cemented. New plastic coated 5-1/2" tubing will then be run. 13-3/8" 5000 psi RSRRA BOP stack will be used. The BOP eq Necessary will be le wireline 1 will be fl be install uipment will be pressure tested each week and operationally tested each trip. provisions for subsurface safety equipment will be rerun. A non-freezing fluid ft in all uncemented annuli within the permafrost interval. A 5000 psi WP ubricator, tested to working pressure, will be used on all wireline work. Well owed to producton facilities during testing. The downhole safety valve will ed and tested upon conclusion of the job. Estimated Start Date' 8/17/80 Sn:)scqLteut \Vol'k tleported on Form No/':?v -'':~ _ ~at~d ~/-~/~-~ 16, I hereby c~f~ha~e fo~n9 I~e and co[o rect ~,~:~' SIG'ED';~:~J~ ~,~District DrillinQ Enqineer_. DAT. ,8/12/a0 / · (This space for State office use) PPROV ED BY T It LE C~a.i_marl CONDITIONS O~AP~AL, ~ /~NY: See Instructions On Reverse Side Eng. ~l~u}ager Phillips D ~] ,xl Sohio Ceo log>' }.iarathon State o£ 'Alaska DATE 08/i3/80 Approved Copy' Returned '.'.: i ~. '...;,.' At}CD ©ii an,') C,J$ Company I5 q ~-~'t~5,on OI .&lJ3nt,~.~,~chl,'-'iJCort',pany ?oc, t Of~i'-~ x' ,,nuh:3r.? .~ska . 'Tc.(e:~hene :)07 2'7'7 June 4, 1980 Reference' ARCO Cased Hole Logs D.S. 1-2 5/14/80 CNL Run 2 5" p.s. 1-14 5/15/80 " Sun 2 5" ,~--~Z~~ 5/15/80 " nun 3 5" D.S. 5-5 5/16/80 " Run 4 p" D.S. 5-7 5/16/80--' -" Run 4 5" D.S. 5-12 5/16/80 C~L Sun 3 5" D.S. 5-17 4/4/80 Spinner 5" r~~o~e2se sign and return the attached copy as receipt ata. ~. J. Sahlstrom North Engineering TRANSMITTAL #360 DISTRIBL~ION Nort]~ Geology R ~ P [h'illing Eng. Manager Geology State o£ Alaska Exxon Mobil Getty Phi 11 it) s Sohio Marathon Ct~ev~on Aizska Oi! & [:, ". ARCO 011 and C~a~ Como~nF .l)ecember 11, 1979 Reference' P~closed are Nagnetic Tapes for the following ARCO wells' D.S~._I-8 10/27/79 Tape #57073 Schlt~nberger {-"i~.S. ~7~_.5 10/50/79 Tape # 57075 " D.S. 5-12 10/27/79 Tape # 57074 " ~//Please sign and retu~ the attached copy as receipt data. K. J, SM~lstro, n North r,-oineering,_..~ I'!b~\:S?,!ITTAL # 513 DISTRI 8N'ION Nor t.t~ Geology E.,a~ on R & D ~iob5.1 J)v.[ 11 ing Get ty }lng. Manager I} & }[ Sohio Ceo] oov ~.~arathon State o[ Alaska Chevron Alaska. Oil and Gas Conservation Ccmmission Lonnie C. Sxith Commissioner December 5, 1979 Blair E. Wondzell Petroleum, Engineer High Annulus Pressure ARO0 Prudhoe Bay_ Well DS 4-7 As you requested, Ben LeNonnan and I investigated the high 13 3/8" annulus pressure reported on ARCO's Prudhoe Bay well DS 4-7. t~Te determined that the reported data didn't make much sense. Ben called ~,~. A1 Brown at Prudhoe Bay add explained the situation to him. Mr. Brc~n had seen the report and he was also confused. He said tb~t he vaDuld have Don Franks look into the situation and give Ben a call. y~. Franks called Ben and explained that the 9 5/8" pressure was 2100 psi and the 13 3/8" pressure 100 to 200 psig. He also said that the engineers had been trying to bleed off the annulus to dete~r~ the c~cation point. I~en he called, Mr. Franks said they had shut the well in (since Ben's trip) and ~re bleeding the annulus thru the flowline to the coam~pn line (~n line pressure is about 710 psi). Apparently DJ~.CO has at least one other Prudhoe Bay well (on DS 2) which also has ccmmunication problems. If we find out additional information, we will let you know. ' h 9,a 7 '-). .... 1979 Novel~be'~ 26, lle ftc fence ' Enclosed are Cased Hole Logs for the following ARCO wells' D,$, 1-S 10/27/79 D.S. 1-12 10/25/79 D.S. 2-1 10/27/79 ~?'Df~,.;'~?[> 10/50/79 D.S. 5-5 ~0/26/79 D,S. 5-7 10/26/79 D,S, S~12 10/27/79 D.S. 6-3 10/29/79 CNL Rmn 1 5" " Rlln 1 5" EPL Ran 1 5" CNL ~an 3 5" " _Pun 3 5" " Run 5 5': " I~an 5 S': " Run 2 5" D.8~ 9-4 10/29/79 G~iL Run 2 5" - ase~ sign and return the attached copy as receipt o£ data. K, J, Sahlstrom North Engineering TJL,'V,~S~\!~['J]';\L f..:' 487 DISTIUBIH'ION North ( ]h'.i_ ] 1 :Lng ]'Cng, ~qanager Geology State of Alaska ~xxon Hob ii Getty Sohio Harat.hon Phi 11 ips Chew-on October 19, 1979 Re£erence' Fmc!osed are Pressure Buildui)s for the following ARCO D. S:~_-2} .... 9/4/79 Gearhart-G~:en ........ Dyr~__,. 4-7 X 9/28/79 " " . , _[ e sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering 419 I )1 ,c;]'p,j,>.,,t>' r,' .,-.. ~q'~.l~ ili (;et-t)' Sol~5o ,".k.t r~ ilion t)i~ [ 1 l ii)s Ch ev North Ala~,, ...... ~rict Post O,,~c,~ Anchoraqe,. Telephone o~.~ 277 5537 August 28, 1979 Reference' Enclosed is the Spinner Survey for ARCO well D.S. 4-7. / Please sign and return the attached copy as reCeipt of data. Very truly yours, K. J. Sahlstrom North Engineering T~NSMITFAL #' 298 DISTRIB[fFION North Geology Exxon Dri 11 ing Mobil Eng. ?,!anager Getty R & D Sohio Geology Marathon State of A].aska Phillips D & M Chevron August 15, 1979 Reference' Enclosed are Cased-Hole Logs for the following ARCO wells' D.S. 5-17 D.~5~_~17 /---¢. s. 4:7.D D.S, 4-5 D,S. 9-6 5/29/79 Casing Collar Log & Perforating Record 5/27/79 " ,, ,, t, ,.., 6/14/79 Compensated Neutron Log 5': 6/11/79 " ,, ,, 6/13/79 " ,, ,., 5/24/79 continuous Flm~ Survey 5 Please sign and return tBe attached copy as receipt of data, truly yours, R. A. Bellinger North Engineering TFO%WSMI~TAL # 264 DISTRIB[H'ION North Geology Exxon Dri 115.ng Mob i 1 Eng. Manager Getty R & I) Sohio Ceo 1 ogy Marathon State of Alaska Phillips I) & bi Chevroa ! ALASKA OIL ANO CAS CONSERVATION CO~i~SiON f July 20, 1979 / $001 PORCUPINE DRIVE.ANCHORAGE, ALASKA 99501 ARCO Oil and Gas Company Attn: Rosie Hamlin North Alaska District P.O. Box 360 Anchorage, Alaska 99510 Rosie: The following material from Prudhoe Bay drill sites was received July 19, 1979 with no accompanying transmittal: . ~'BH, P Build~. Flow Profile Surveys ?/.,,,"/,.), ,~-~ - ,~-7'-> 5'~-; ~-3; 5-8 ~ ~-::]. V Co~puter Processed Log (Schlumberqer Cyberlook) 14-5 Very truly yours, William Van Alen Petroleum Geologist Pos( Ot~i~o Box 380 Ar.~-:,Alaska 995i0 Te.,::~¢~lone 90/277 5.'.;37 July 16, 1979 Re£e fence ' tMclosed are the £ollowing ARCO magnetic tapes' · D.S. 13-1 #54256 '!ii23/78 Run D.S. 4-5 #54260 14/78 D.S. 14-3 #54257 21/78 'R~n 2 D.S. 5-2 #54261 12/78 Run 1, 2 PLease si~ and retu~ the copy as receiFt og data, Very ~y yours, -~ E. A. ~ellinger Nortlt Engineering .. TRANSMITFAL # 225 UOIS'gllltl/lnq. . .,,,O/¢r;'/nlf'~t~¥' ,.. .~! ./~,, (7 No:th C, eology l~:illing .! ~ W Eng. Manager R& D ~State of Alaska I) & ~1 DISTI~I BIFI'ION ].~xxon i, Iob i 1 Getty Sob lo ~Iarat]~on Chevron Pc,~! O','.,i: 3~0 ..". Anci~oraSie, ,,,fat;ka 9g.510 Telz,~l~ol~e fl07277 ' /~~".S. #4-6 D.S. $4-~1 3-07-79 3-04-79 3-19-79 Please sign and return the attached ~opies of the ~ransmittal as reCeipt of data.~/~.~- ,y//]_~/~'v Very truly yours, '~ R. A. Hamlin North Operations Engineering Transmittal #154 DISTRIBUTION North Geology Drilling Eng. Manager R & P Geology State of Alaska Exxo~ Mobil Getty Sohio Marathon Phillips Chevron AtlanticRichfieldCompany North Arnerir'*'~ Producing Division Alaska lie.... Post Offic~'-,,,'0~ 360 Anchorage, Alaska 99510 TeleDhone 907 277 5637 December 15, 1978 Reference: Enclosed are copies of the following Transient Pressure Buildup Surveys: ~-D ,~D ~D .S. #486. 10/2-3/78 Camco .S. #4-7 10/4-5/78 Camco .S. #4-8 10-03-78 Camco .S. #4-10 10/6-7/78 Camco .S. #9-3 10/12-13/78 Camco .S. #9-4 10/14-15/78 Camco .S. #9-8 10/18-19/78 Camco .S. #9-10 10/16-17/78 Camco .S. #9-12 10/20-21/78 Camco .S. #9-15 10/22-23/78 .Camco Please sign and return the attached copy of the transmittal letter as receipt of data. Very truly yours, R.A. Logue North Operations Engineering Transmittal #615 DISTRIBUTION North Geology Drilling Eng. Manager Dallas Geology State of Alaska D & M R & D EXXOFI Sohio Mob il Marathon Phillips Chevron Getty AtlanticRichfieldCompany ,. North Amer: Oroducing Division North Alask- .strict Post Office BOX 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: DS 4-1 Permit No. 70-42 DS 4-2 Permit No. 70-63 DS 4-3 Permit No. 71- 5 DS 4-4 Permit No. 71-11 DS 4-5 Permit No. 71-25 ~~Permit No. 76-83 ~_DS_~7 j Permit No 75-77 ~-~~-~'~' Permit No 76-10 DS 4-9 Permit No. 76-30 DS 4-10 Permit No. 76-42 Dear Sir: 4 Enclosed please find a Completion Report/.for the above- mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer FMB:lr Attachments SUBMIT IN DL. .CATE* STATE OF ALASKA !Beeotherln- st ructions on reverse side) OIL AND GAS CONSERVATION COMMITTEE , i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE 0I" WELL: Oil, ~ GaS ~ 1.~ Other %'ELL WELL ~ DRY b. TYPE OF COMPI,ETI¢)N: Nt.:W ~-' P.'(,RK ~ DEEP- ,~ PI. UG ~ DIFF. ~EII ---: ~V Ell~ EN ~ BACK ~ P. ESV R. Other Perforated 2. NAME 0F OPERATe)II Atlantic Richfield Company .4DDRES~ OF OPERATOR P.0. Box 360; Anchoraqe, Alaska 99510 4. ;,o(:.,'rx,~x ,Jo WI:LL iReport location clearl~t and in accordance with an;/ State requirements)* At surface 90'N & 593'W of SE cr Sec 27~ ?llN~ R15E~ UM At t,~p prod. interval reported below 1585'S & 1190'W of NE cr Sec 34, TllN-R15E At total depth 1720'S a l190'W of NE cr Sec 34, TllN-R15E 5. AP1 NUA'IEi~CAL CODE 50-029-20189 6. LF~ASE DF. SIGNAT/ON A.ND SERLAL biO. ~DL 28325 17. IF INDIA/N-, A_LLOT2*EE OR TRIBE NA~%~LE 8. UNIT,FA-tL~I OR LEASE NAAIE ?rudhoe Bay UNit 9. %VF_J~L NO. DS 4-7 (31-34-11-15) 10~.FLEL~ch-ND PO~L, OR Fruonoe Day Prudhoe Oil Pool i1. SEC., T., 1~., 5~., (BOTTO5~I 1IO1.21 OBJECTIVE) ec 34, TllN, R15E ~2. ~T ~o. 75-77 1:' i)A_TE SPUDDED 114. DATE T.D. REACHED 12-31-75{ 1-28-76 l,'; L'OTAL Di';t'TII. MD & TVD[9. PLUG, BACK AID & TVD~. Lb-' iWIULTI~PLE COAZPL., 21. I{O~V I%/~N'Y* ROTARY TOOLS 9400'MD, 9017' TVD ~9279'MD, 8902'TV~ Sinqle Ail ~. PRODUCING !)TrI'EItV.'\L(S~, OF THIS CoMPLETION--TOP, BOTTOM, NA2'~IE (NID AND TV-D)* Top Sadlerochit Base Sadlerochit 2; TVPE Idl,~-H 'Ti:lc /._ND O'I'HE[~ LOGS RUN I15. DATE COAIP SUSP OR &t~A~D. I16. ELEVATIONS tDF, RKB, RT, OR, ~TC)* {17. EL~rV. CASINGHEAD pert 'ct 2/4/76 5/3/77) 51' RKB . INTERVALS DRILLED BY I CABLE TOOLS 23. ~VAS DIRECTIONAL , SUF~VEY RIADE 8877 'MD, 8519 'TVD 9310'MD, 8932'TVD ~ Yes DIL, BHCS/,GRt FDCr GR/CCL and CBL/VD CASING RECORD (Report all strings set in well) C,:~.SI2'~'C; S1ZI': tW.E. iGHT. LB F-P..[ ~ GRADE l[ DEPTHi~,SET., (MD) I 11aLE SIZE184 ' ~'&~W C~xILNTING RECOP~ ~ ~'rfOUk,T PULL~ 20" 9~wetco / H-4nl P. I 32" "I 240 sx Arcticse~-'.cm~ sx erma ros 9-5/8" 47 Butt I~N-801 9373.' 12-1/4 1000 sx Class I&soo-~5 . ' ,.& 125 sx PF II 2nd st~qe SJZH [ TOP (liD, EOTTO2i (},ID) SACKS CE},i~-T* SCi[E~ (A'iD~ SIZE DEP~ SET (AID; i PACKER SET (A'ID) -1/2" ' a632 ' 28 PI(I{FO[iA'I'IONS OPEN TO PRODUL~I'ION Iintcrval, size and number) 9 2 7 2 ' - 9 2 7 7 ' " o~n~ 12(T2V.~ (~ID) ,U,[OU~-~ 2~Xb -}3ND O~ Ai.~¥E>ZAL US~ 9188'-9238' 9132 '-9150' W/4 shots per foot PRODUCTION D..k'ii.i !:[[::-_"l' [q:t)L:UCI'ION [ PIIODUCTION MEir-{OD ~Fiov,'iing, gas Ill;., pumping--size and type of pump> Oct 1977 [ Flowinq lnt3uRs ,t ESTrD Ici!aXE SIZE IPROD'N FOR DATE ,;F TEST. ! [ ITESi~ PEFLIOD 1327 ! 4.1 I 27°62/6~ ~%,', TVJIlN(; ~CAS, I. NG PRESSURE ICALC~T~ OI~BBL. 0 6145 ~'1. Dmposrrmx o}' Gas ~Sold, used ~or ~ueI, vented, etc.) Reinjected I ITr ELL STATUS ~.Producing or unut-ln) I Producinc oIL--BBL. C-;YS--A ICF. \V£FI'Er~--BBL. I GAS-OI~R-kTIO [ Z049.7 I 727.~ 0 I ~qq GAS--A~CF. %VA'I'~--BBL. ] OIL GRAVITY-~I (CO~.) I 4258 .1 0 I a _ TE~T wITNESSeD BY Production Dept. 32. 1.181' OF ATTACHMENTS able records ~ . q ' C' N V}~/"~ '~~-~JP~/'/ '~ ~Z~)he roby.~.~ ~~/ ~ ~//]pce .rtify r t,att~he If~ regol ng anal atta q~ ed i n f c)rm at lan. ' ' TITLEIS completeDiStrictand correct aSDrl~determinedRn ~ ~ n ~rfr°m all-avail DATE_ '// - . __ __ ~ ____ ~ ..... // c . ,.. *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS C3eneral: THis form is dus~.)ned for s,u~br~ttirxc3 a complete ~r'~J ccr'ro.c~ ~o~~, co'~rc~t~on repc~rt a,~d Jog on alt types of lan:~s and te~ses ~n A~aska. Item: 16: In'J.,cate ~sh,c~ eJevatlon is u,,::r:-cJ as reierc'"x,-e (,vhe'e r,o' o'~er.',.~e she.,.,.:! ~o, c~epth me,~sure- merits g,ver'~ ~n cther spaces on JJems 20, and 22:: l{ t~'.;s v,..eJl is cor'np'etu<~ for se:::,ar.~': ~:r :{ Lt':,,.. ~-: ....... .o"t-. t~',a'-, c.:'e r,t~'.rvaJ zone (~..uJt ]b'~e coq~pfetJor'.], n,o state Top(s), bottom(s) and na~',e (s) (~f any) for only the ~n'e'..~ r'e,,,,',:te.~ ~r', ~te.~: 30 S.,~r,,~,t a separate report (pa0e) on this {orca, ade,'~uateiy' identiJicc], {or each ar:d ',o~,,~ ir't~: raj to be seper'ate]y produ,ze:~, show- ing the a~tiona~ data per't~ner~t to such ~ntervai. I~m26: "Sacks Cement": Attact~ed supplemental records for th~s w. eJl shou!a show the details o{ any mul- tiple stage cemontir~g and the location of the cementing tool. Item 28: Submit a separate completion re~rt on this form for each interval to be separately produc~ (See instruction for items 20 and 22 above). 34. SUMM'AItY ()~' b~()llMATI(.)N TI~LS'I'.S IN('I,LII)IN(; INTIqRVAL TF~qTED. t~HE~qURE DAT~ ~ ~COVE'RIE-q ()F ()IL GAS. 35 G~G IC MARKER WAT}~I{ AND MUD NAME , Top SadlerochJt 8877 8519 3ase SadlerochJ t 9310 8932 3fi. coil,E DATA. A"I'I'A('ll IIRIEi,' D.~C~IP.I~ONS OF LITIIOLOGY. P(.)ROKITY, FIIA("~'~I%ES. APP.~N.T DI. PS' AND: I)~TE(?T~I) NII()WS OF OIL, GAS Oll WAT~{. .... .... AtlanticRichfieid Ccr~'~pany I',,Ior~l~ Ameri F:roducing DiviMon North ?,, l :~.':; ~' ' {rict .. Post Oifice Box 360 Anchorafie, Alaska 9~510 Teiepi~on(~ 907 277 5637 June 21, 1978 ~.,?r. O. K. Gilbreth, Jr. State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 In response to your request for data pertaining to reservoir pressure information, please find the enclosed data. A list of stabilized flow rates prior to shut in and cummulative oil produced since last pressure equalization has been tabulated for all wells requested; with the exception of the following' D. S. #1-11, 1-12, and 1-14-To be.run in the future. D. S. #2-11, 2-12-Are currently being run. D. S. #3-9, 3-10-No plans for these wells to be drilled at this time. Per your request, copies of Initial Static Pressure reports are again being submitted for the following' D. S. #4-7-Distributed to State 5-19-77 D. S. #9-3-Distributed to State 11-24-77· NGI #3- Distributed to State 19-78 NGI #5- Distributed to State 10-9-77 ' To date, no pressure buildups have been run on NGI wells. Plans are to run pressure surveys only at this time. I hope that this information will satisfy the state requirements adequately~ Very truly yours, ,] .-- / 4 7/ '-,~.__ - J. A. Rochon gAPv/ ]LAZ,I er HKVP }:TO;P, ' T. Acid or Fracture Treatment I,og - 1.;!IP }>aildup & I:J. ow Profile Su~'ey };orcho~e Geo~et-ry Log ............ Carbon Oxygen I,og . . _ (,¢_,~.no Collor Lo~ Cement Bond Log ............ 'Compensated Reutron 1,62 - Casea tlole ..... ' ....... Cove AnaIysis- Interval Core No. Core Descrlpt.ion' (~.IC) - Interval Core Description (Cony.) - Core No. .............. }.}ircct:ional Surv¢)' - Gyro - S~ng].o Shot . ~ )4ultishot · }in~l].neering l>roduct, ion' Log ' ]:lu~d Analysis ....... : .... .}:]u:ld Denqity Gamma Ray ],ocation Plat ............ ~'lontl~ly lse_l.[ Test })ara Nud Log Perforating Reco~d . State Reservoir Pressure Report Surveillance Reports Tempm-ature l,og &W'7/9 ....... k[,C--- - ~// .._~ .... T'rans:mnt Pressure Surveys - Compensated FoTmation Density I,og - Compensated Neutron-}:ormat:~on ])ansi1:)' l,og - }kn'o]~o]e Co;itpcnsatcd Sonic - tkrros:i.'[y At:] antic R:~ch[:[e].d Cc):nj)any Anc]~or;~ge, Ala:;]~a 995]1.[) Seale o . . · ]Jato ' Xerox- S~p-.a 'BL Lira ~.iP~~ OF I~k'.!2alkL ~CES Divisi6m of Oil and O. K. ~re~, Jr F~~~ 9, 1978 D~~or H. H~l~n Hoy~ ' ' ~f ~oleu~ ~g~ ·est Surface °~fe~y Valves (SSV), SubSurface Safeway Valves (S~-~"V) , Ix~ Pressure Pilots ap.d Annular Pressures on AFrO's Drill Sites ~1, ~4 Subject test involved ~o separate trips to ~ Bay, ~ first cn January 16, 1978, and the second on January 22, 1978~ vzith eight cuma31a.- tive days spen% testing. Part of the second trip ~s uti!~d retes%- ing certain %~ells on drill site 91 after guide l~s ~re agreed upon at a n~eting be~,~een ag'ency and AR(/D production personnel c~ January 20~n. Listed below are ~J~e resufLts of t~he tests: L.P.Pilot Initial SSV SSV SSSV SSSV 9 5/8" Actunted Flc~J~ng Tested Test Tested Test Annulas @ PSI Pressure @ PSI Rs~lts @ PSI P~su!ts .PS__I 1-1 720 1550 640 OK 825 (tK 25 1.-2 700 1270 675 OK 720 ~K 0 1-3 700 790 620 OK 660 Failed 0 1-4 660 1020 680 OK 700 OK 0 1-5 700 900 740 OK 700 OK 90 1-6 700 1550 800 OK 810 OK 0 1-7 700 1140 695 CiK 650 Failed 60 1-8 700 1140 740 OK 750 Fail~/ 0 1-9 700 1600 970 Failed 1000 Failed 0 1-10 * ** In--able 4-1 780 1400 700 OK 700 OK 0 4-2 2075 * *** Failed 0 4-3 680 1300 750 Oil 750 OK 0 4-4 775 1450 750 OK 750 C~ 0 4-5 670 1560 700 C~ 890 OK 0 4-6 700 1300 * *** Failed 100 ~2'~'~ 700 1500 775 OK 700 OK 0 ~ -4~'~ 700 1350 700 C~K 760 Fail~ 0 4-9 650 960 660 OK 650 O1~ 100 4-10 650 1450 700 C5~ *** Failed 50 * Not tested ** SSSV ino~_rable. Beinc3'ipulled. *** SSSSV would not close. 13 3/8" PSI 0 0 !10 100 0 5O 0 0 100 0 250 0 0 0 0 0 0 0 2 Of the ~m_nty F~SV's tested, nine, ~r 45%, ~_re inoperable ~r failed. Fifteen SSV's tested successfully and one failed. 5~%r~ SSV's -..~.~mre not tested after it ~s four~ ~e SSSV's in the ~..~!is ~u/z! not test. three SSV's will be tes"'~d when SSSV's in these ~lls l~ve been Field ~srmction reports ~re pzmpared ~ond copies mailed to A1 production su[~-rJ~t~d~,t, ~d Dcm Franks, assis'te~% production ~Jerinte~dant. Originals of tJ~e field im~pec~ci~n reports are a~cb~w/ to ~his report. Attad~ment DRILL SITE #4-7 PERFORATE /kND CLE/h\IJP RECORD April 28-29, 1977 D.S. #4-7 was drilled a bottom hole location in the Northeast Corner of Section 34, TllN, FdSE, Prudhoe Bay Field. Depths of interest are' Measured Depth Subsea Depth Zone Top of Sadlerochit 8874' Gas/Oil Contact 8984' Perforations 9132-9150' Reference: BHC Sonic 1/28/76 9189-9238' 9252-9262' 9271-9276' Base of Sadlerochit 9310' Junk Left in Hole None 8473' Cong. 8578' Cong. 8727-8744' LBS 8783-8828' LBS-S~'~ 8841-88S1' SMB 8859-8864' SMB 8889' On the first gun ~n2n, fill was encountered at 9279' M.D. Due to fill, the first gunwas fired three feet off bottom from 9271' to 9276', one foot high. 2T~e well was flowed on a 36/64" choke at 4000 BPD and 200 psi tubing pressure for ten minutes flow. Having a tandem gun in the hole, the second portion was fired frown 9252' to 9262'. The flow rate increased to 6000 BPD on a 36/64" choke at 350 psi tubing pressure. The well. was shut-in to retrieve the guns. The third gun was shot from 9213' to 9238' with the well flmving 5500 BPD on a 36/64" choke at 525 psi tubing pressure. The tubing pressure increased to 700 psi. ~e turbine meter was bypassed due to a flow rate of over 6000 BPD. With the choke reset to 44/64", the well continued to flow with a 550 psi tubing pressure. The calcium chloride water came out in a slug of emulsion. Shakeouts shm~ed the final calcium chloride content to be .1% from a high of 40%. Final flowing pressure was 1375 psi on a 44/64" choke. Shut in tubing pressure was 1410 psi. ~e well flowed a total of 379 bbls. in 75 minutes for an average flow rate of 7277 BPD. ~e maximum flmving wellhead temperature was 44°F. A fluid density log was run showing the calcium chloride water cleaned out to 9274' M.D. (8862' ss) leaving ~vo feet of perforations covered. 'fine well was flowing at 1120 psi tubing pressure on a 44/64" choke when the fourth g~ was shot from 9132' to 9150'. Within the first minute, the pressure rose to 1200 psi. Shut-in pressure built up to 1480 psi. The well was flowing at 1280 psi tubing pressure on a 44/64" choke when the fifth gun was shot from 9189' to 9213'. ~e flowing pressure built up to 1330 psi within five minutes. The shut-in tubing pressure was 1480 psi after 24 hours (1521 psi by Amerada). An ~nerada pressure bomb was used to obtain the 8800' ss static pressure, 4367 psi. ~e well was then flowed for one hour on a 1" d~oke. After 30 minutes the well was flowing at a tubing pressure of 1160 psi. The final flowing tubing pressure was 1200 psi. ~e volume flowed was 517 bbls. for an average flow rate of 12,408 BPD. Only one ~nerada bomb operated for 48 minutes of the flow period. Using the last bottom hole flowing pressure of 4044 psi, the maximum drawdown is 323 psi. This results in an approximate productivity index of 38.4 STB/psi. The total estimated volumes of oil and gas produced during the perforation operations were 825 bbls. oil and 619 b~F gas. 5131177 Drlg. Permit No. Operator Al, Oil and Gas Conservation Commi _~ Field Inspe~ion Report -~U~.~' Wel 1 / F~l-e~F~m Sec Represented by~~A~ Name & Number_~)~ Satisfactory Type Inspection Yes No Item ( ) Location ,General ( ) ( ) 1. Well Sign ( ) ( ) ( ) ( ) 2. General HousekeepinQ ( ) ( ) ( ) ( ) ~.. Reserve Pit-( )open( )filled ( ) ( ) ( ) ( ) 4. Rig ( ) ( ) (~7'~Safety Valve Tests ( ) ( ) ( ~I~)" ) 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 ( ) ( ) ( ) ( ) l l. P&A Marker ( ) ( ) ( ) ( ) lZ. Water well-( )capped( )plugged ( ) ( ) 29 ( ) ( ) 13. Clean-up ( ) ( ) 30 () ( ) 14. Pad leveled ( ) ( ) 31 /95 Total inspection observation time__ ~ hrs/-~l;:$~ Total number Rema r k s Satisfactory Type Inspection Yes No Item ( ) BOPE Tests 15 16 17 18 19 20 21 22 23 24 25 26 27 28 "Casinq set B TesL fluid-( )wtr.-[--~-)mud ( ) oil Master Hyd. Control Sys.- psia ~!2 btls. , , , psi.q Remote Controls Drilling spool- "outlets Kill Line-( ) Check valve Choke Flowline ( ) HCR valve Choke Manifold No. valvs fl~_s .. Chokes.-( )Remote( )Pos.(-~dj Test Plug-( )Wellhd( )csg( )none AnnUlar Preventer,_ ~siQ Blind Rams, psia Pipe Rams psiq Kelly & Kelly-cock psig Lower Kelly valve Dsio Safety Floor valves-('--)-'BV / )Dart eaks and/or equip, failures ~:~ days or when ready North Alaska District Fmgineering 'T RAN S M I T TA.L ' . ~to: "../'~.e.yg'.,/:['..:i~::::..'.....--~::';....:'. -..-.. :'. We~ Na~.a'~ :;D~..,:~~:7....V..>:.:.:?../?::<:,~7~:.): ... ..,~..,~ ....'.:"-'-:- ..... >:. . ('~..?.~ .-..'..[-. ~.: ::.- :.' .- __, . _ ......... . .. . ..:-...... .. . .~ . .~ ~ ~.. .:-.-. .. ..... .. - ..,...., ...:. ,..... ...... . ~ ~.;... -. . -- . - .... ... ...... .. . ...::....::. .... .... ... ''-" 'transmitted herewSth are rh~ f6~owSng fo~ the s~eoj ect'~,e~'-~ / .... .:'":'".~-~:. -..- . ' P, un No,. -"' · · . BHC Sonic/Caliper Log .. · .' BHC Sonic/Calipe{~ - Grot, mn'Ray LOg · ." BttC Sonic/Ggmma Ray Log. . - .... Caliper/CCL ...' ... -' Cement Bon& Log/vOL.'''''' "--. " __~' Compensated Formation Density L~g' " Compensated. Neutron~Formation- Density: Co~npensated Neutron Log . .. ..Core. Analysis - Inter~.al . · · Core. No, .. · Core DeScription [SWC) - Interval · Core Description (Con.v.) - Core No. ......... 'Directional Survey..- Gyro.' ' · ... Si'ngle Shot" · "Multishot ])rifl Stem Test'- ;£est No. 'l~aal Induction' Laterolog. : }':m~ation Density Log ' . -. Fo~nation Density .Log/Gar~a P~M'.- - . Scale" Gamma Ray/CCL Laterolog .' Location Plat.... ... Microlaterolog Microlog Nudlog- Inte~al Sample Log (A.iLCo~ - S~ergetic Log TVD- 1)I L. . TVD-PorOsity' Log .-. - -. -. .o Xer&k' sepia- . o . . .-. ,. · . · · - . '.- BL Line": ..:-..:. · . ~ ' o o . . · . : . ,- _ . , . . .. .- . . . -/ · .. ..-. · . . % · _ o . ]lccdipt Acknowledged For' I)ate' Please return receipt to' Attn': ?,h'. Do'oran Jackson A~l"~ntic Richfield Co:..-~pany North Alaska Engineering P. O. Boy 56'0 North Alaska District Engineering TRANS~I TTAL To' From: J. A. Rochon/D. R. Jackson Date' Decen~er 16 Well Name: D. S. 4-7 Transmitted herewith are the following for the subject well' ~m No. Scale BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BItC 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 (S~qC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Singl~ Shot b~ltishot Drill Stem Test - Test No. Dual Induction Laterolog . Formation Density Log Formation Density Log/Gamma Ray Gan~a Ray/CCL Laterolog Location Plat Microlaterolog Microlog Mudlog - Interval San~le Log (A.R. C0.) - Interva% Synergetic Log TVD-DIL TVD-Porosity Log 1 Nuclear Flolog 5" Xerox Sepia BL Line Receipt Ac~mwledged For: Attn' ~k. Do~ovan Jackson Please return receipt to: Atlantic Richfield Company North Alaska Engineering P.O. Box 360 Anchorage, Alaska 99510 TO; North Alaska District Engineering T R A N S ?'.'I I T T A L r].o. From' J. A. P, ochon/D. R.. Jackson . . '_i _.' l')n ['.c' _._. lXla_y_S]-:-lg77- Nel ii. Name' D.I)_;S. ,#4-7 Trnn.'-uu_i.i:t,ud he'rctv:i_th a-re t]~e followS.ha for the subject well' Scale BI lC Sonic/Cal:i_pe'r ................ .I-~ll(: Sonic/(}all.:ipe~r ~ 6anm~a Ray Log ............... I?,iIC Son:i.c/Gamn~a Ray Log (:~ll :i per/ Ceme~rt. ]-onc I,og/V])L (;ompz::~sated Fon'nation Density Lo% ................. (:o~ni~ensatcd Neu'[.'ron-Formation Dens ........ 1 ..... Corq'~cnsntcd Neutrori I,og Co're .A~ a ].)' ~:, is - In t c Fval ............... Core No. Coro ])escrJ.ption (ShrC) - Interval Core Desc:rJp'Li. on ((Sony.) - Core No. ])i.rect:i.cma 1 Stu'v ey -- Gyro .............. SinSI e Shot Mt~l.'Lishot J)r[l]l. Stem 'J'est -- Test No. ]):.u~] ]'nducti. on Latero]_o~ ];on'~!atio~l Dens:i. ty J,o~ ],'or~n:.~t'.:i.on DensSty Log/Gamma Ray ]'.,a Ix)ca'iii on Plat H:i cro'l -. Ivktcllog-- S:~nl:)ll.e Log (A.R. Co. ) - In%er-val Syne'r?;et:i.c l,og 'lTl')--Po'rosity Log .... 1 ....... E]_uid ..... ? .......... It Sl! lic;ce:ipl: Ad~nowlc,,dged ]':or' ].(l. ea.~;e 'rc'['tn'n 'recci.pt to' At~a~.:Lc RS.chfield~Company NoS~ Alaska Engineering Manager P. O. Box 360 Jg~10 ~chorage, Alaska c ~ Xerox Sepia BL LSne _. I ea. ea. ea. ea. ,/ ea. #423 Atlantir;RichfieldCompany North Amer;- ~n Producing Division North Alas istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 6, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subjec Drill Site 4-7.~31-34-11-15) ~8 (33-26-11-15) Drill Site 4-9 (33-35-11-15) Drill Site 4-10(33-27-11-15) C. 'GEOL~ .... ,~,. 5 !.-_NG "2 3 GEOL ... __r Permit No. 75-77 Permit No. 76-10 Permit No. 76-30 Permit No. 76-42 Dear Sir: Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure RECEIVED ~.-- ~ - .~:~ . ..,~ ~.~ 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.) 5, APl NUMERICAL CODE 50-029-20189 6. LEASE DESIGNATION AND SERIAL NO. ADL - 28325 7, IF INDIAN, ALLOTTEE OR TRIBE NAME 1. OIL ~ GAS F-'] WELL I-~J WELL OTHER 2~ NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay 3. ADDRESSOF OPERATOR 9. WELL NO. P. 0. Box 360 Anchorage, Alaska 99510 Dr, II Site 4-7 (31-34-11-15) 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT At surface Prudhoe Bay -Prudhoe Oil Pool 90'N & 593'W of SE cr Sec. 27, T11N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 52' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 11. SEC., t., R.,M., (BOTTOM HOLE OBJECTIVE) 1720'S & 1190'W of NE cr Sec. 34, T11N, R15E, UM 12. PERMIT NO. 75 - 77 }ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) Perforate REPAIRING WELL ALTERING CASING ABANDONMENT* (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~ertinent details, and give pertinent dates, including estimated date of starting any proposed work. Began perf operations on 4/28/77. Tstd tree, csg & tbg. Ran temp survey~_--F~lQ~d dummy valve. Ran GR/CNL/CCL logs from 9276'-8300'. Tstd BOP to 5000 psi OK.i' Perf'd !~ntervals 9272'-9277' 9252'-9262' 9214'-9239' 9190'-9212' 9133'-9151' w/4 shotg~-pe~-f~cl' Ran , , , , static BH press survey. Flowed wel'~. Ran & s~ ball valve @ 2189'. 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 OK. Released well to Production Dept on 5/3/77. RECEIVED Divi$ic, n of Oil~, ~nd 16. I hereby certify that the foregoing is true and correct TITLE · / District Drilling EngineerDATE.5~//~/? ~ (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side STATE of ALASKA TO: ~ FROM: DATE : ~'¢-, ~" 1977 SUBJECT: To_ ??itr~s ~bsurface E~%fety Vai%~ ~_ ~,~, ~m-fac-e Cc~.~ol S&fe~y Valve for _~Jcco ~ 4~7 ~ ,=.. % !:~ at 6:00 ~.~4 for ci~¢~-¢_3~: L~ at ~'~i~ ~~ 3, 1977 ~ ~ 1~-:~ r,~3 - ~rL~.~ f~ a 7:00 A~=~ .... ~:-,~.~j~ ~ ~~ P~V. ~nd m~riv~ in Pr~7~ at 9:40 ~z~.. ~3~ of SS. ffV ~ S~7's for .~. J~ ~c~-~. :,. ~~~- ~ ~]ng was 1550 psi. ~ ~g¢ ~ clo~ bl~. do~¢n to 600 psi a~! I ~~1 ~ pres~ f~ ~ m~~s %,~ no ~ s~=~: I wi~s~ bests of t~ ~~ac~ ~f~ ~.1~ ~ ~a~ ~%rol safe~~ -~3ze f~ ~r~ ~ ~ 4-7 A-'ct~c~:',ez r t Drlg. Permit No.. Operator A1 Oil and Gas Conservation Commi Field Inspection Report Well/Platfm Sec '~T Represented bY ~ ~ ~ .~..~? ~ Name & Number Satisfactory Type Inspection Yes No Item ( ) Location,General () () () () () () () () () () (,) () () () () () () () () () 1. Well Sign 2. General Housekeeping 3. Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 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 SatisFactory Type Inspection Yes No Item ( ) BO?E Tests () () () () () () () () () () () () () () () () () () () () () () () () () () 15. "Casing set @ 16. Test fluid-( )wt~ )mud ( ) oil 17. Master Hyd. Control Sys.- psig 18. N2 btls. , , , psi.q 19 Remote Controls 20. Drillin,q spool- "outlets 21. Kill Line-( ) Check valve 22. Choke Fl owline ( ) HCR valve 23. Choke Manifold No. valvs flgs 24. Chokes-( )Remote( )Pos.(-~,dj. 25. Test Plug-( )Wellhd( )csg( )none 26. Annular Preventer, psig 27. Blind Rams, psi§ ( ) ( ) Il. P&A Marker ( ) ( ) 28. Pipe Rams psig ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve psig ( ) ( ) 14. Pad leveled ( ) ( ) 31. Safety Floor valves-~--)-BV ( )Dart Total inspection observation time hrs/days Total number leaks and/or equip, failures Remarks -~ .' ~ '.: -~" ~'~ ' .-' . -' ~ '~ ~ i' ~ ''~,~. ' - CC' Notify in days or when ready Inspected by Da te ~/? ? AtlanticRichfieldCompany North Am'-",can Producing Division North Al District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5,537 Mmrch 25, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Drill Site 4-1 (23-35-11-15) Drill Site 4-2 (13-26-11-15) Drill Site 4-3 (23-34-11-15) Drill Site 4-4 (14-36-11-15) Drill Site 4-5 (23-27-11-15) Drill Site 4-6 (22-03-10-15) 'Dril~ '~i~A-~ZS (33-26-11-15) Drill Site 4-9 (33-35-11-15) Drill Site 4-10 (33-27-11-15) Permit No.-70-42 Permit No. 70-63 Permit No. 71- 5 Permit No. 71-11 Permit No. 71-25 Permit No. 76-83 Permit No. 75-77 Permit No. 76-10 Permit No. 76-30 Permit No. 76-42 Dear Sir: Enclosed please find a Sundry Notice outlining our plans for the above-mentionedwell. Very truly yours, Frar~ M. Brown District Drilling Engineer /vp Enclosure Submit "Intentions'' In Triplicate & "Subsequent Reports" in Duplicate -, Form 10-403 REV. 1-10-73 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 - 20189 6. LEASE DESIGNATION AND SERIAL NO. ADL - 28325 7. IF INDIAN, ALgOl-TEE OR TRIBE NAME ~' OiL F~ c^s r-1 WELL ~l.~J WELLL--J OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay 3~ ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 360 Anchorage, Alaska 99510 Drill Site 4-7 (31-34-11-15) 10. FIELD AND POOL, OR WILDCAT N & 593' W of SE cr 27, T 11 N, R 15 E, UM 4. LOCATION OF WELL At su trace 90' Sec. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) .~2' PKB Check Appropriate Box To Indicate Nature of Notice, Re Prudhoe Bay - Sadlerochit 11. sEc., T., R., M., (BOTTOM HOLE OBJECTIVE) 17.20' S & 1190' W of NE cr Sec. 34, T 11 N,. R 15 E, UM 12. PERMIT NO. 75- 77' 3crt, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Perforate . SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE-' Report results of multiple completion on Well Completion or Recompletion Repor~ 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. 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 lubricato utilized wi th all wireline work. hollow carrier type guns at 4 sh surge tank to recover load fluid recovered liquids will be retain the oily waste disposal faciliti be vented to the atmosphere duri hole safety valve will be instal Estimated start date' r, tested to working pressure, will be All perforations will be made with ots per foot. Well will be flowed to a s and any produced well fluids. All ed in the surge tank, then trucked to es for disposal. Any produced gas will ng perforating operations. The down led and tested upon conclusion of job. May 19, 1977 ~,~.. 16.SlGNEiI hereby certify~~~that the f_oregolng Is true and correct District Drilling Enqineer DATE.. TITLE ' (This space for State office use) CONDITIONS OF APPROVAL, IF AN/~: - TITLE .Petrmleum Engineer - DATE 3-30-77 See Instructions On Reverse Side ,, , September 8~ 1976 Mr. Hoyie Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage~ AK 99501 Subject' D~.9-~=2~( 31 - 1 2-1 O- 1 5 ) ~~4-~Z~,~ 31 34-11-1 5) Dear Si r' Enclosed please find the subsequent Sundry Notices for the above mentioned wells. Very truly yours, C. R. Knowles District Drilling Engineer CRK/jw Enclosures Form 10-403 Submit "Intentions" in Triplicate REV. 1-10-73 & "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 50-029-20]89 6. LEASE DESIGNATION AND SERIAL NO. ADL 28325 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. Oil E~ GAS E] WELL WELL OTHER 2. NAMEOF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 360, Anch0ra§e, AK 99510 DS 4-7 (31-34-11-15) 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL At surface 90'N & 563'W of SE cr Sec 27, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc,) 19.5' Pad 52' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re Prudhoe Bay - Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 34, TllN, R15E, UM 12. PERMIT NO. 75-77 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) C0mpl eti on (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. Accepted riq 2 1600 hrs 8-16-76. PU 8-1/2" bit. RIH to 2600'. Displ diesel w/lO.7 ppg mud. Staged in hole. Circ @ 2000' intervals to 9274'. Chgd over mud to 10.5 ppg CaCI~ wtr. Press tstd 9-5/8" 3000 psi. Ran ~1/2" 17# MN-80 8rd LT&C (A-B) tbg w/shear sub ~ 8773', "X" nipple @ 8708', Baker pkr @ 32', PBR @ 8594, "XN" nipple @ 8588', "XA" sleeve @ 8550', & "ROi' nipple @ 2201'. Installed & press tstd tubing hanger 5000 psi OK. Unable to seat test plug properly in OCT tbg hgr. ND & replaced tbg hgr. NU. Install back press valve & tstd 5000 psi OK. ND BOPE. Installed & tstd xmas tree. Dropped ball & set Baker pkr @ 8633'. Shear press @ 2900 psi. Press tstd tbg & tbg anul OK. Opened XA sleeve @ 8550' & displaced CaCI^ wtr w/diesel. Closed & press tstd XA sleeve OK. Set dummy valve in RQ nipple @ 220~' & tstd control lines 5000 psi OK. Ran GR/CCL logs & dummy gun from 9232' indicating 47' of fill on btm. Pulled dummy valve. Set OCT back press valve in tbg hgr. ND xmas tree & install BOPE. Install 2-3/8" rams & press tst. PU 2-3/8" tbg. Cleaned out to PBD @ 9279'MD. LD tbg. Ran 2-7/8" dummy gun w/GR/CCL. Tag btm @ 9278'. Set Baker BP @ 110'. Reinstalled BOPE. Set OCT back press valve in tbg hd. ND BOPE. Install & press tstd xmas tree. Opened XA sleeve in 8550'. Displ CaC12 wtr w/diesel Closed & press tstd XA sleeve. Press tstd tbg.& tbg anul, OK. Run dummy valve in RQ nipple & dummy gun to 9269' press t!std tbg &'tbg anul, OK. Released rig @ 1200 hrs 8-25-76. 16. I hereby certify th t e (T his space for State o~t/~, APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE '.. DATE DATE See Instructions On Reverse Side Atla nt ic F{ ichfieldCom pany [-,_0, L~i ~l,qC' n J)roduoiy~g Division North Al,as, sbict Post Office) l~ox :~oC, Anchorago, Alaska a ~,~-~ r'~.¢ ~,.,, .~ May 13, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99504 RE: DS 4-7 (31-34-11-15) Permit No. 75-77 Dear Sir: Enclosed please find a Sundry Notice for the above mentioned well. Yours very truly, ! G. R. Knowles D±str±¢t Drill±rig Engineer CRK/jr Enclosure Form ?--3 ~ kLEV. 9-30-6 9 S~bmtt "Intentions" in Triplicate & "Subsequent geports" L'~ Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMI'F[EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals lo drill or to deepen Use "APPLICATION 'FOR f°'EH/~IT--" 'for such 'p~o/~osalJ.) WELL WELL OTHER 2. NAME OF OPEirLATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage~ AK 4. LOCATION OF WELL At surface 99510 90'N & 563'W of SE cr Sec 27, TllN-R15E,UM 13. ELEVATIONS (Show whether DF, RT, GH..lc. 19.5' Pad ' 52'RKB 5. APt NL~vLER/C~ CODE 50-029-20~89 6. LEA. SE D~IGNA~ON AND SERIAL NO. ADL 28325 7. IF INDIA.N, AJ.~L,O'I-I'EE OB. TH/BE NAaRLE 8. UNIT, FAP~,I OR LEASE NA~IE prudho~ Bny 9. VFELL NO. BS 4.7 .. (31-3~-11-]5) 10. ~-~ ~D POOL, OH WI~C~T Prudh°e Bay, Sadlerochit Pool 11. SEC., T., R., .M., (BOTTOM HOLE OBJECTIVE) gee 34, TllN-R15E, UM 12. P~R_%IIT NO. 75-77 Check Appropriate Box To indicate N~ture of Notice, Re ~ort, or Other Data ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF i [ FRACTURE TREAT 8HOOT OR ACIDIZE REPA1R WELL ,Other) COMPLETION .MULTIPLE COMPI,ETE ABANDON* CHANO~ PLAN8 {__{ WATER SHUT-0rr i ; REPAIRING WELL FRACTUKE TREATMENT }__ ALTERING CASING 8HOOTING OR ACIDI~ING { [ ABANDONMEKT' (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. L,?:MCRIBE I'nOPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and .give pertinent dates, including estimated date of starting, an)' proposed work. The Atlantic Richfield Company proposes to Complete this well with a single string of 5-1/2" tubing. The production packer will be set ~ 8650 feet and the well suspended in an unperforated condition. certify that the f regoin~ is true and correct 16. I hereby SIGNED District Drilling Engineer DXTE TITLE 5-13-76 (This space for State office use) CONDITIONS OF(~PROVAL, IF ANY: See Instructions On Reverse Side A'I'I.ANT£ C ItT Ci ,1'! !!Lb CO:XlIU\NY ' ' _ ' ;t;Ol ti-lO. - ~ ' T'rap. s.m:Lttcd he~ew:'~ti~ are the fol]_owzng ~' - ~uo3ect well' Run No. Scale Xero× Sepia ILL I,ine N-~C Sonic/Caliper Log I;[iC Sonic/Caliper - .~,.o.y Log "' oon.-LC Gam. rita Ray I bi lC ~' ' / Cc ..... nt lk)nd. ]. Compcnsat:cd Fon-p,,al;ion Density Log ]x~ .... il. [kx~pe~ated NeuE'ron-Fo~na~o~ '~ ~4 Cy Core ~mlysis - Interval Co-re J)escrJ.ptZon (St?C) - ' .... -, Co're 9escri. ptto~ (Cony.) - Core No. 9_t'rectional Su-rvey - Gyro t,,lui, t/Shot ])t'J ].l Stem Test - Test No. -').- ...... i~,.~a.l rnductkon I,aterolog .............. l':o-nna'aion Dens it-.y . I:ornm't:ion Densi. ty I o{-~ - Gamma Ray Gammxt Ray -- Neutron Log La~e-rolog Loca.rion PI. at " .~, , .. NZc'rolog . ', ,. '" Nudlog-- Inter"~/al Log ox.!C{coD.::.- Synerge'aic Log 5; ' ' - · '~d __211c 511 _ (t L'cceJi)I: Ackno,,.~ledsed For' .~),t ('e B):' Atlan~icR~chfieldCompany North Ame~ ~ .Pmducin~ Division NotCh/\i~sl, ,strict l;osi: Offic,s L:~ox 300 Ar~chorage; Alaska 995i 0 February 9, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 RE' DS 4-7 (31-54-11-15) Permit No. 75-77 Dear Sir' Enclosed please find the Well Completion Report with attached Drilling History and Gyro Survey for the above-mentioned well. Yours ve7 tru}y/ /¢ C. R. Knowles District Drilling Engineer CRK/cs Enclosure ..:. I~,r-u I'7 .~.-~,, SUBMIT IN DDiZ3:,.JATE* STATE OF ALASKA st ructions on OIL AND GAS CONSERVATION COMMITTEE WEkk COMPLETIO~ OR RECOMPLETION REPORT AND LOG* ~VEI.L~ WELL ~ b. TYPE OF COMPLE~ON: WEI.I ~WER ~ EN ~ BACK RESVR. 2 NAME OF oPERATOR Atlantic Richfield Company ,~. ADDRESg OF OPERATO~ P. 0. Box 3b0, ~chorage, Alaska~' 99510 ..... .... ~- :.ac., r~x oF w~:LL ~Report locatio~ cteart~ and ~n accordance w~th an~ State requ~})~ '~" ' ' At surface 90'N fi 595~ of SE cr Sec 27, TllN, R15E, ~ ~t t~p prod. tnterral reported below 1585~S [ 1190~ o~ ~ cr Sec 34, TllN-~SE At total dep~ 1720'S fi 1190~ of ~ cr Sec 54, 5. AP1 NU;',SY_SLICAL CODE 50-029-20189 6. LEASE DESIGNATION A-ND SERLkL NO. ADL 28325 "~ ~" '~ ~ ~q7~ Pru~oe Bay Prudhoe Bay-Sadlerochit sec., T., R., ~., (BOTTO~ ~Or.~. POOl oBJF.~TIVE) Sec 34, TllN, R15E 12. PEI~N{IT NO. 75 -77 1 12-31-75 I 1-28-76 [ 2-4-76 { /SZ'?RKB , , CABLE TOOI.S 9400'm~017,~ ] 9279'b~¢902'~),1 N/A~ ~ ~1 None ~DUCiNG !NTEHV..XL(S), OF ~IS COMP~TION--TOP, BOSOM, ~*~IE (NID A~ )' 23. %VAS D!REUTION~ [ SURVEY 5tADE None . ~Yes 2;. 'FxJPE 1.2I.F2(":'i11(' .,'tND ()TilER. LOGS RUN DIL, BHCS/GR, FDC, GR/CCL and CBL/VD CASING RECORD (Report at1 strings set in well) c~,.sr¢o :,,z.,¢ ] lb/fl[Grade 'lThread ~.epth '"set (MDJ i Hole---Size} c-m,=~.~'G RECO~ i ~'['O~--~--T PULLED 20" [ IH.40 {v-etco '4,beiow p ad/ 32;' 1240 sx Arcticset 13-3/8" [ 72 IMN-80 {Buttres~.J270i' ' 17-1/2" 13500 sx Pemafrost 9-5/8" [ 47 [MN-80 [Buttres~ 93'7~' 12-1/4" I1000 sx Class I &[S00-g5~Buttr~es~ ., ' ..',. l a_!2S sx PF II 2nd s~age. 26 LINEi{ tI.ECJ O I{-D 28 PI~:iiFC)[{A'J tONS OPEN TO PRODUCTION (hlterval, size and number) 27. iUBING REJ. OIZD SCREEN (AiD SIZE DEPTI-I SEiU (!iD ! ! iPA_CKER SET (2.'ID) ,i ACID, S[[OT, F2;KC'i URE, C-F. ,IEN? SQU--~Z:2, ETC. N/A N/A L 30. PIZODUCTION DA'ii; F'ii;h;i' P!:OL;L:CTION [ PRODUCTION MEI[{OD fFlov.'i:~g, 2.33 lifi, pump~g--size and type of pump~ I[%VELLznub-in/STATUS (.Producing or N/A } , [Suspended DArE ,;F TgST. [tLuURS q ES'L'~ [CI!OI(E SiZE IpnOD':¢ FO~ OI~EDL. G.X~A'ICF. %V/~--BBL. I GAS-OIL p~.YTIO '-- ~6:x..,:[ 'Ft'rHNr; lC,.XR[~G PRESSURE CAi,C~T~ OI~BBL. GA~Z,'IC~. ~rA'I'~--BBL. {OIL GRAVITY-~I (CO~.) I 1 ~1. [ ISPUSI{'ION OF GAS tSold~ used ]or/uel, vented, etc.) [TEST WITNESSED BY t 32. I.IST t)F ATTACHMENTS Drilling History and Gyro survey horeby certify that the forgoing and~taehed lnfoimat[~n i~ complete and correct as determined from all-available records *(See Instructions and Spaces for Additional Data:on Reverse Side) INSTRUCTIONS General: This forrr,~ is cies~,3ned for afl t/pes of lances and leases in Alaska. ments g~von ~n tiber si~aces on ~h~s Items 20, and 22!: tf t~',~s Yve!J is r'Ornp:etO<t for separ,~', r" T!.,ct;-~r-: ~ ........ C'? ~!~3. rq Cr'O .:':'crva~ zone (mult,p!e comp~etior~} r,o state in )teP~ i-'0 and top(s), bottom(s) and na~,e (s) (if any) for only 1he inte'.~ , ro:.,(,tc-r] ir' :'o'}. 3L~ S.~i)r"..t a separate renort (page) on this form, arJe<!,.~ately icJentiflccJ, for each ac~5:t,c)r',al ~r tu val to be seperately produce:J, show- ing the a~]~tional data pertinent to such ~nterval. Item26: "Sacks Cement": Attached supplemental records {or this well shout;J show the details of any r-nul- tiple stage cemonting and the location of the cementing tool. Item 28: Subn~it a separate completion report on this forn~ for' each interval to be separately produced. (See instruction for items 20 and 22 above). SUMMAI¢."~ OF' P()I{MATI()N TIf. L-~T?; IN('I,UI)IN(; INTI-~IiVAL "I'~7,.'-7,'F}CI'> I~'liI~;,S.c, UIiE DATA A_N'D P,.~('¢)VI~iItlF~S ()F ()II, GAS WATI~I/. AND MUD NAME MEAS I)IWPTI{ T~I.T'E VI~.ItT Top Sadleroch±t 8877 8519 Base Sadlerochit 9310 8932 DATA, ~NI)'. DE'I'ECT'i'EI) .NIIt)WS OF OIL, (iAS Otl IVATIB"II. .................... ATLANTIC RICHFIELD COMPANY DS 4-7 (31-34-11-1S) AP1 50-029-20189, ADL 28325, Permit No. 75-77 Drilling History Spud @ 3:30 AM 12-31-75. Drilled 17-1/2 hole to 2715'. Ran and cemented 13-3/8" 72# MN-80 Buttress csg @ 2701'; FC @ 2624' w/3500 sx Permafrost II cmt. Washed and blow dry 20"x 13-3/8" annulus. Recement w/400 sx Permafrost I'I. Cut off and lan~ded 13-3/8" csg. ND 20" Hydril, tested packoff @ 2000 psi, NU and test BOPE. blade up 12-1/4" BHA, drilled FC, shoe and formation to 2895'. Test- formation w/525 psi. Directionally drilled 12-1/4" hole to 9362'. Trip to log. Bridge @ 9130', tripped to wash bridge to bottom. Drilled to 9400'. POH. Ran DIL, BHCS/GR and FDC logs. Ran 9-5/8" 47# MN-80 and S00-95 Buttress csg w/shoe @ 9373. FC @ 9289 and bottom FO @ 2653', top FO @ 2414'. Cemented w/1000 sx Class G cmt. Landed 9-5/8" csg, installed packoff and tested w/5000 psi. RIH w/RTTS and cemented thru bottom FO @ 2653' w/125 sx Permafrost II cmt. Closed bottom FO and upper FO and circulated 9-5/8" x 13-3/8" annulus prior to pumping 275 bbls Arctic Pack. Break thru @ 170 bbls; final water 0%. Closed FO and tested w/3000 psi. POH. Ran GR/CCL, CBL/VD logs and gyro survey. LDDP. Displaced mud to water and water to diesel @ 2538'. ND BOPE, NU and test xmas tree. Released Rig @ 0100 hrs., 2-4-76. Suspended oil well. A PETROLANE CZ~PANY Atlantic Rich£ield COMPANY D. S. 4-7 WELL NAME Prudho e Bay LOCATION JOB NUMBER A276 G0054 SURVEY BY Jay Mar;cin TYPE OF SURVEY DATE Gyro-scop~o', i'7~ {?~ i!~[i ~"'"'? ~ ? i{'~"-i~-17-76~, OFFICE Alaska -OY'qOSCOPlC ",IETHOD OF SURVEY ............... .... CO.',.'!PUTED"-FOq EASTMAN WHI'PSTOC. K .... I.NC._. ~:.Y___F~__?,_.__L~N_D_SE_?__A.,i~_D_A..S_S.OC_.~_,.",.._T..E_S ...................................................................................... ............................................ P.E'CORD-' OF' SURVEY ........................................................ ................................. ~-Li--~K[~O-O,"+"::"6BS-~'66,-.~'or.~;,,.'.~' ~'¥- I ~ ?'. ~LEC"r~ox...C .... CO...',,~PUT~ .......................... ............. .. ......................... /..,., ". ............................................................................................................ . .............................................................. .~::{ ................... . ....... ,.. . ................................................................................................... :' x , .......... .......... ' .................................. .._.i i'. .... i. "" ~^s. '~q~F'T'-V'F'r~T:~C~L ....... ' SU~ ~R'rF'T ...... "rO"rAL COOR~^TES C L 0 S Ui? ~_.S ............... v~qr.,t~:~',' s~c"r~o,, DEPTh! ANGLE DEPTH./ SEA D~rRE~ ........ . ...........................D.]:._STANCE .. ANGLE .... DEG/iOOFT .......... DISTAIN( D '- M ........... ..'""" ..... DEG. D i'"1 S .............. .............................. j..~ ......... . / - ................................ .~': ............................................................................................................................... ,, 100 .... 0 ........ 012"'"10-'0-.00 '- 49.00 855.00E .11~3o00 N ..... 250.'00 .... W ......... 1'2'09.12 N ].1 55 57 W (),,000 ........ -.5!0.9 ' - 2(')0 -'0 ....... 0~ ...... 200,,00 ..... 14.9.00 566.00E 1183.00 N ..... 250.00 ..... W .............. 1'209.12 N 11-55 5'7 W O,OOO -510.~' .......... ~ ....~ ......... ~f ......................... '~" '~" - ] .................. "~ ..... 300 ......... O'-P'O ..... iSD-d",'-O'O ........... 24'9'.'00 566.00E- -i"1-'~-3 .-O0--'N ..... 2"5-0-.-0-0--~ -I-2-0-9-,-'1-2 ..... N ....... l"!' '5~ 57 ~,, (. · 30(. -5 ! u,, ....... ~00 0'"' 0 ........ Z~'O0'.O0 ........... 349.00- 566.00E 1183.00 N - 250.00'-W ............ !"269.12' N l! 55 .... 5'7 W "0.000 .............. -510~8' " 500 ,/'0 lO ............ 49q.99 ...... 448.99 ..... S66,~00E"- 1182.93 ,N ...... 2a~.o~6 .... W .............. I209.04' N'II' 55'36"W ..... 0.170 ................. -510,9 ......... .~ ~, ~. ., ,., ~ ......... ?' ........................ '~ .... ~"' ...................... ~11 ~" 6007` ........ 0 .... 1'0 ......... 5-99'"."99 ......... 5a8'"-99 ......... 567.'00'E--- 1'~-'~'':;----r~''~' ..... ~ .... 2-419-'.'-5'-9 -W ....1-2"08'.'8'6 ....... Iq .... I1 54. 5~ W C.0C, 3 -..!.,..0- .... 70~) 0 0 699.99 ...... 64.8.99 S67.00E .... !182,,76 /'.~ .............. 24goaS--w ........... 1208.78' N'-'l'l"'54 -.34.'-W ........ 0.170 -5!I,,if 800 0 0 799.99 74.8.99 567.00E !182,,76 N 2a9.45 W 1208~78 N Il 5~ 3/+ W 0.000 -5? ............ ~.'0'0 ........ 0 ..... 0 ........ ~"99'",'9'9'' .............. 848.99 S6'f. OOE Z182.75 N ............ 2a9.45 ..... W ........... 1.208."78 N.11..54,.:54.,W ....................... 0.000 IOOQ 0 10 999..~9 ..........948.99 N6a. OOE 1182.7(.: _N ....... 24q..31 ......W ............. 1208.75 .... N 1.1 ..... 54 .... IO__..W ...... 0.170 ..............-5!!,2~ 8 !!~ 0 30 1099,9c~ 104.8,99 Ngo,ooF. !!82,89 N 24.8,74 W 1208,76 N .1.1 52 31 W 0,3~0 !20(') ' 0 0 .t199,99 1148.99 Ngo,ooE !1u2,89 N 245.31 W 1208.67 N ii 51'?15 W 0.500 -512.1~ ' 130~ O' 0 ..... 1299'.'99 ........124.'8.99 ......... Ngo.ooE ...... 11U2.89 ~,! ......... 24.'8-.31 ...... W ............. 1208'.'6-? N .... 1i' 5! !8 'W 0~000 .................... -512~1~ -"140d~- 0 ....... 0 .......... 1399-,'99 ........... 134.8.9e N90,OOE'-1!82.~9 N .......... 248'.'3'?,- ....... W- ............. !20U.'67 N '11 51 '18 W .... 0'~000 ..................... -5!2~!~ _-_-"'is'6"OV '0- -6--i-~-~'-cfJ9'9' .......f'4'4-8 '"99 ........... ,N9'O-,'O'o'E ......... i'1'82', s'9 ..... tN ......... 2-4'8-~'3'1 .... '~] ..... .I"2'0'8",'6''t ....... N ..... I"! ...... 5'1 ....... l'8""-w ..................... O' ~"00'0 ..................... -512.. ~500 _1.' 9 1548,99 N90,OOE !182 ~9 ~ .......... 24~3. 3~ ....... W ........... !2.08,67 N 11 51 18 ~ 0.000 . 1 , Z?O0~ 0 0 1699',:)9 161+~,99 ...... Ngo.o0~ .... 11~2.o'~ N 2~+8.~I W 120~,67 N 11 51 ].8 W 0o000 -512.1 ........... .1 ~. 00 ........ 0 ........... 5 ............ Z"799 .'"9'9 ............. 'L 7 4 .8'. 99 ........... N 9 0 · 00 w ......... z 1 s 2'. 9 ~"-'-'~ ........ 2"~'.'~"."~,"~ ....... w ........ z"2' c)'~'."7'2 .... ~., ". :L .... 5 ~ ........ ~ 7 "'w .............. 0.0 9'o ...................... -~ 12 . i 1900 0 4.5 1899.99 1848,99 .......... 2.qo.o , o ..... 5..0 ........ !?_e.%...9.,~ ........... z 9~.,...~ ...... 2!0.0 ...... 0 .... 45 ....... 2_09_9.._.97 .......... 201~S.97 2200 0 50 2199,95 21~,e5 2300 0 50 229'9,95 224So95 2400 0 30 2399.94 S2~,OOE 1181~2 ~.' 2~8,6~ W 1208,28 N !! 52 3! W 0,660 -511~6 .... $32o00E 1!~1~20 hi 247.99 W !206~95 N !I 5!...._.2,b .... W ................... 0....090 -5!'1~3 $50,00~ 1180,25 N 247,00 W 1205,82 N !1 49 13 W 0,090 .... -51'1,6 S50oOOfi 1179~45 N 245,87 W 1204~81 N ii 46 3! W 0,090 -5i2~0 S21,00~ 11'/8,27 N 24.5~03 W 1203,4.~ N !1 44. 51W 0,421 -512~0 117'?,17 ~! 21+4,64 W !202~S2 N I1 44 24 W 0.~40 . .-5':LI~6 ............................... R ECO.R D__._OF .... 5 URV E_Y ............................. A L. L__.C A L CU L_A T ! 0 N 5.._. P E R F 0 R .v.E.D .... 9 Y.__I__B_.._..Y.' E L_EC_TR ON_I C_C~O I~:_P.U_T. E R ......................................... t'---~.-~.~-;--~-R-'i"F-~--~/-Ik:~ T i C A-'L- ............ S'O'B ............. -D'~,"']: F T TOTAL COORD]:NATE5 _ D.EP T H ._ ANGL._.~ ..... DE?TH ............. SEA ..... D]:REC .......................................... D.]: ST. ANCE .......... A~XtGL E ........... D~C,/!OOF.Ti ..... D~.ST~ D ,M D. E,.G. D .... [vl ..... S ...................................................... 2600 0 35 2599,93 2548,93 S 4,00~' 117.5,22 N__2..4:.4_,_8_O_W _I_2._07.,_4..t+__N ..... 11 45 59 W 0,!23 __ -- __.2700 ........O 45 ....... 2699,92 ...... 262+,B.92 ..SIO,OOW ..... 1174.06 .... N .............. 244.gL~___W ...... 1199.34__..N .... 1.! 47 .... 4..%' 0..160 ............. 2P, O0 0 45. 2799,92 27z+~,92 ,.S .2..,OOVV ......... 1.172._".76 ....N ....... 2_4.5_,.08__.W ............. I1.98..09.. N...I.I .... ~+8 13._W ................. 0,105 ........................ -508,65 _29.0 o o 5_5 =:: 2.%97....2..1 ...... 2.s.~,s.~..9 ]. ........ s]...o.....o.oE__..~31._1._,_3.o .... N__.g..~.{,_.._s2.._w ...... 1..17~.....6..4._N ..... 1...1 .... 45___z+2_!,~ .... o_._.]. 8 o -5 o 3000 0 50 2999,89 294B,~9 S17,00E ........ 1.1.69.,.80 N ..........244_,.61 .....W .............. 1!95,.10 .... N~.ll z+8 39.W ............... 0.,.09.0 ............................ 3100 0 45 3099,88 3048,88 S!'ZoOOE I!68,4'Z N 22+4,21 ....... W .......... 1193.,72 N...1!_48 18 .... W .................... 0.,09.0 .................... ................................................................. _.-_-~.2.0.o ..... 0 ..... 5_..o___.~_1..~.&..,~2__.3_!.4_C,.~.? .......... s ..... e..~.o.o.V; ..... ]:....1._6,..7_,._1..O__N 2..~._47_I_o_~'. ...... L!.~).2.,..~..5 .... N ....... i_1 ..... 44. 48 v,, o. o $ o ~ - ~ o [, · o..3 3300 1 0 3299,86 3248,86 S 3,00E 1165,50 ...... N ................ 24.4.~17 .... ~ .......... 1190,80. N 11 49 56...W ........ 0.~160 ..................... -505,0! ......................................... 3400 1 0 3399,85 332+8,85 S 6,00E 1163,?5 N 244,03 W 1189,07 N~!1.50 35 ..... W .................. 0,052 ........................ --:-"'~'oo ..... z ......... o ............ ~'~g~'~"'s'~ ........ ~s.s~ s 2,oos ........ ~']~'.'o2 .... N .................. ~'~",s~ ...... ~ .............. ~'zs:,~+ N ~ ~ ~ W 0.0:0 -~O:~.Z~ 3600 ! 0 3599,82 ..........3548,82 S 1,.O.OW ...... 1160_,.2.7 ...... N .................. 2_4.3..,90._._.k~ .................. 11.85.,6.3 .... N .!.1 52 16~.W .................... 0,052 ..................... ....................... ......... 3700 ........ 1 0 ........3599,80 ......... 3648,80 S 2,00E ...... 1.!58,53 N ................ 243~88 W .............1.183,92 N !1 .... 53 16...W .............. 0..,.052 3~00 1 0 3799,78 3748, F8 ........ S ..... 2.,.O..O.W .......... 1_~.5_6..,....78 ........ N ......... 2_4..~.,...8_8 .... W_. 1..~.82..,2..! .... N l..l .... 5~+~..._i._9.._.W ......... 0..,...02..0 ..................... ....... ~'-s'o© ...... ~'-i'o ...... ~"S"~'~-."-~'-z ..... ~'S~.. v7 sz 2. oow ~ z ~, ~o N ............. ~_~4....,Z ~ ..... ~ .............. ~_.~ so.z+.2 .... ~ .... ~ ~ ..... ~S .......... ~L_..~' o..?0 .................. ................................ ........ 420.0 .......... 4 ...... 0 ......... ~199,.61 .......... 4.148,6! S14,00W ......... 114.6.,09..~.N .............. 2.44.,81 ...... W .................. 1!..7!.,94 N 12 ..... 3 .... 27.....W .......... 2.,.751 ......................... -~+92 ......... 4300 ....... 6 ...... 50 ......... 4'299,!.5 ........4248,15 S25,00W 1.!37,.20 N ................ 2.4..7,96..~' ............... 1163,92 N _12 !8 ..... 1 W ..........2,84.~. -484,9~ ~..4.0.0 ..... 8._1_0__4_~...8_,_~9 4.347_,2.9 .......... S .... 5..,..OOW ............. 1...1.2.4:..,_..6..5 .... N .... 2.5._!..,..32 ....... ~{ ...... 1.1.52 · 39 ...... N ..... 1.2 ....... 35 ..... 4. 8._.W ...................... 1.,_39..0 ...................... ........ 4500 10 ............ 0 ............ z+49.,{..,_03 ............ 4446,03 S.6,OOW ....... 1.108..,93 ....... N ............... 2.52.?.83 ....W ............... !.13'7.,39 N 12..50 ...... 38 W .......... 1,8.30 ..... . ......... 4600 .... 11 5.5 ........... 5...,_.20 ..... ~_.5.44,..20 S.. z+, OOV~ ....... !.0.8.9.~.9.8 ........ N ........... 2...54...,..49 ...... W .......... ! !._].9_, 30 N 13 ...... 8 3 2.._..W ............... !,9.32 .......................... .__47.0..0 .... !.3 ...... 5_5 ..... /+.6.9.2_, 66 .....4641,.66 ........... S ....... 5,5 OW ...... 1_0.6 ~.,._6.9 ....... ~ ............ 2~5.6_,_3.~._...W ...... 1.09.8..,~0 3 ..... N ..... 13 ......... 30 ....... 3..~..W ...................... 2..,.002 ................ -~436 ....... ~eoo .... 1~ 10 ........... ~.7.8.9...22 ......... ~+738.22 s..~..oo~v .......... 1.0.~,Sl .... N ............. 2..58_._4S ..... '~' ............ !07..3.40 .... N..~3 5~ ~..V,, 2.2~3 4900 .... 1.8 ..... 35 ........... 4882~,.65 ............. 4833,65 S .... 5,00W ............ lOt2,0z+..~N ............. 260,84._~g .................. 1045,11 N. lZ+ 27 !0 W 2,422 ........... ........... ~o.0.0 ...... ~..1 ...... 1.0 ....... ~.s..7..S...As ........... '*?~Z..,.~ .......... s ...... ~z. oow ............. s.7..~L,.~.~ .... N ................ ~..~.~.....~.0_~'. .............. ~.0..!.~.,.~.! ...... N :..~ ~ ...... :~ ...... ~ ~..~_S 0 ................... - ......... 5100 23 .... 30 ........... 50.71,.1.8 .......... 5020,18 ...... S 6,00W ............92+0,32+. ~ .............. 26~,_4. z+_.._W ......... 9.7.7,63 N 15. 52 35 W 2'.,33~ -351~ ...... 5200 23 ....... 30 ........ 5..162.,.8.8 ............ 5!.1..1,..88 S.14.,OOW .............. 90!,10 N ....... 2.74.,36_.W ............... 94'!, 95 N..16 56. 3 W 3,188 -322~0' ALL CALCULATIONs PERFORF'.ED TRUE __ _ .. ~EAS, DRIFT VERTICAL S~,_. DRIFT ~OTAL COORDINATES --DE~TH'--ANGLE"' DEP~ SEA D !REC D ~ DEG, 5400 5500 5600 5700 5800 DOG_.LEG ................ C L O S U R E S S~V=qI'~v ...... S~'CTION__ DISTANCE A~'4GL :: D',!G/i00~T ....... ._ D v. S 2z~"%5' ' 5345,68 ...... 529~..58 S15.OOW 823,'0i -N .............. 296-"39 .... ~] ............ 874'-75' N -19'-48 2-0 W 0.254 ....... .......... .. . 2~ 10 ...... 5435-,88 "' 5385,88 ....... SIS,OOW- -78"3,'59"-N ............. 307.69 W .......... 8z+1',8~ N 21 25 19 W 0,080 -22a,79 24 lO 552 8,12 54-77-, !2 ........ Sl'?'. OOW ........ V~'/.d,'~-'N-- 3"1%~-3"2--t,.; .... g-O'9-,'-'a'~ ...... N'-'2'3 1'3 ...... l"'~-'-'W .............. 0.'4'0-9 .......... :1-9"1-,-90 24 0 ....... 56!9.~1 ........ 5568,~1 S15,OOw 705,20 N 330,91 W 778,99 N 25 8 !7 W 0,237 -:b9,13 . . . 2~ .... 35 ........ 5710,55 ~659.55 S16,OOW 555,65 N 3z, 2.25 W 7~8,z~9 N 27 12 38 W 0.~90- -126~31 .................................................. 5900 25 0 5801,3~ 5750'",3'4' -S'!'8"~-o"OW ......... 5'2'5-""5"~N--354,SL W 719~03 N 29 32 29 W 0,54a -92,41 . ................... .. ........................................ ...... 6000 25 - 5 .... 5891,93 584.0,93 S18,OOW 585,29 N 367,60 W 69].,15 N 32 7 52 W 0,090 -b7~77 .................................. .... 6100 25-"%5 ...... 5982,'~4 ........ 5931,~4 - SlS.0Cw "' 54z,',~4-'""'N ............ 3bO,--/z~-'W ................. 664,69 N 34 56 46 W 0.160 -22.96 ...... 6200 ..... 25 .... 5'5- 6'0'72""-5"~ ..... 602!',53 .......... S18-, BOW ...... 5'0'3'-~'8'2-N'--3'~'-2-7 w 539',-75'""'[N'- 38 ......... 2 .... 4'Z'-"W ................ 0"-,-~8-7 .................... ~-2 ..................................................... ..... 5300 25'30 .... 5152.72 611.1.72 s18,Sgw ....... ~6z,67 N .............4'08',03'-w ................ 5~6,90 N ~! 24 33 W 0.~30 ~8.22 ..... 6~00 25'-10 ......... 6253.1~ ...... 6202.LL S~9,50W' ~22,2! N .............. ~2'~-.96"-W ............596,93 N' 44"58 5~ W .... 0"375 ....................... '- 6500-25 ...... 0 ........... 5~3~,2~ ......... 6383,24 ...... SZS,50W ..... 3~1-',92-'-N ........... 499-,-22-W ..............5-5~,5z+ ...... N ..... 52 ...................................................... 43 26'""'W ................ 0".090 ........................... 153,69 ........................................... ........ 6700 .... 25 ..... ~5 .....652~,59 6473,59 S!8,OOW 301,22 N .... _~.5_2.~_6_~ W 552..0.6 .....N ...... 5.8 ...... 55 ..... ~6.......'~ ................ 0.,....7_55 !88~87_ ...... 58-~"0 .... 25 .... ~-5 6614,~'/. 6~53.47 5~7,50w ............2.59.,/+7 ...... N ................. ~.76,..01 ....W ............... 5z, 2.~3 .... N_..6.1 .... 2z, 19 .....W ............. 0...5.09 ....................... 22- ......................................... 6900 26 50 6703,93 6652,93 '518,50W ................ 216,97 .......N ................. 48..9._,..82 ...... W .......... 535,72 .... N .... 66 ....... 6 30_.W ................... 0,6.2~ .......................... 26~,2l ..................... 7000 27 40 6792,82 6741,82 517,50W ].V3~4! N 503,97 W 532.97 N 7! 0 41 W 0,858 298,69 ...................................... t .................................................................................................................................................................................................. TiO0 27 55 6881,2~ 6830,28 S17,50W ........... 12_8~..9.3 ..... N ................ 5!.7..,99 ....W ................. 533,80 N...76._ 1 _.19 ..... W ................. 0,260 ................... 335~62 ........ 7200 27 20 ~969,87 6918,87 S!7,OOW 84~64 N 531~75 W 538.44 N 80 57 21 W 0,599 7300 26 55 7058,87 7007.87 S17,00W 41.02 N 545,08 W 546 ...................................................................... ~ ...... F ""'"" ~ ........ ' ' ~,'"~ ~ ........ ~140'0 ...... 26 55 71A8.02 7097,02 518,00W ,..,1o o 5.)o,. fO ....... W ................. 558 7500 26 '-!0 ........ 7~3"7','4'8 .......... 7186,48 ..... 519.50W .................... ~+-4',~'9'"'5 ............... 573,07 W 574. ......... 7 600 ...... 25 .......... 0 ....... _7....3.2..7_.,_29 .......... 72?.6.°.29 .......5.~..8..,...5()W .......... 8_6..,..0h ...... .% ............. 5J~.?_,...3.8___w 593 7700 25 0 7417,55 7366,55 S19,00W 125,83 S 601.22 ..... w .................. 6.1z~ 7800 24 15 7508.~+5 7457,45 S20,OOW 166.!0 S 615,13 W 637 ,62 N 85 41 ~+4 W 0.410 411,10 .70 S 89 46 39 W 0.453 ,79 S 85 33 38 W 0.8t4 ,65 S 81 39 50 W 0~257 521~27 · a5 S 78 5 15 W 1~004 556,82 · 16 S 74 53 18 W 0~769 59!~54. ....... 7900 2'3--50 ........ :?'5"99-'.78 ........ 7548.?8 ......... $1.9~,.OOW .... 2..O.4.,..5.! ........ ,5 ......... 6_2~8.?_7_3 .... W .......... 661......16......S .... 71...58 ....52 w ........... ..... -8"0'0"~ ...... 23---i'5 769!,~5 7640,45 S2!,OOW .............. 2a2.,.0.5 ..... S ........ 6/+.27.39.__W ................ 686,z~8 s 69 2! !3 w .... 0,667 _ 55s,95 ...... 8100 22 30 ....... 7783.58 ........... 7732,58".' s22,00w 278,21 S 655.64 w 713,15 S 67 2 15 w 0~764 ..... 692~07 8200 21 20 7876,35 7a25,35 S22~00W 3!2,83 s 670~62 w 740,00 S 64 59 ~! W 1.160 72~,05 TRUE ..... ...... .................... ..................... D ...... v, ..................................................... DEG. 8~00 20 50 7969,55 7918,~5 S26,00W 3~5,89 S ...............'6fl5~"26 ~j ............ 767,52 S 63 13 48 W 0,712 '- 755,~9 8400 19 15 8063,59 8012,59 ........................ S27,00W ...375,~.7_.5 ................... 700,55 W '/95,t5 S 61 45 8500 18 5 8158,33 8107,33 S28,00W 40~,76 S '115~33 W ................ 821,91 S 60 29__~9 W L.Z64 8~ O~ 8800 17 0 825~,68 8202~68 S29,00W ~31.25 S .... 729,7Z .............. W 8~'t~62 S b9 Zb 2 8700 16__40 83.4.9_,_3.9 ......... 82.98,39 S29,00~' ......... 456,58 .... S ......~z+3_,~5_.W ..... 8.72,'7.2 ....S ..... 5.8 .... 8800 .... 16 35 84~5~2~ 8391+,21 ...... S2-9-,50W~8-1',55_ . S ......V57_..~.~/~.__W ................. 897,81 S 57 .... 33 4~..W ........... 0,09.0 ..... 895~.0.E -" . ............................ 8900 17 ..... 0 8540.9a 8~89.94 S30.O()W 506.6a S 772,08 W 923.46 .5 56 43_..3'7 W 0.412 921.59 9000 !7-'1-0 ....... 8636 ,-'.53 ....... 8585,534 ........ S30,OOW ..... ..... 9100 ..... 1'7--3'0-~87'3"i'"-9'9 .... 86'8"0'.'99 ........ S30""'0'0~ 557.88 S 801,66 W 976,68 S ...... 55 9 55.W .............. 0,330 ...................... 976o_0.3 .... 9200 18 0 ..... 8"8'27,23 8776,23 "S30,OOW ..... 584,29 S ........ 8!6',~9'! ....W ............. ~'0"0'4,36 S 54 25 33 W ............. 0_,..500 ........................... ].O04.0E ............................................'~' 9289 ~8 ..... 0 ......... 8-91"1,'8'7 .... 8860 87 '-530,50W 608.04 S ...... 8~0,'7'6 .... W ............... 1'02'q,5t 'S 53"47 '56'W ~ ~ .......................... ~ ....... ~ ................. ". ..... ~ ......................................................................... 9400 !8 0 9017,4~ 8966,44 S31,OOW ........... 637.52 S . BOTTOM HOLE'"c~'os(J"~'E- ........... 1061.16 FEET AT S 53 4 26'W .......................................................... ' ..... . ................................. .... ]:NTERPOLATED TRUE_ VFR'r~iCAL DEPT~'~ ~6]~'~t~-A'''rr:S AND CLOSURES FOR GIVEN · 'f"~ u~ .... .................................................................................. --C-ODE ~,~ASURED VE!:~T"~-CAL TOTAL CO0!TDI.NAT~S ........................ C L 0 S U R.E ............. SUB ........................ D.rSTANCE ANGL~:S S=:~ _ N A !,~ E ............ . ........ ,r) '--_ .T H ................. - D ....... v ..... 5 ............................ 7-i~'z~ ....... &~93.-x',6 i22.'67 N 519.91 v,, 5-~ i~ N 76 ~% 2~ %,,' SBa2"'6b ..................................... ~ ....................... .,' .,- ~630 735~.29 98.~9. S ~e~ .~6 ~ ............. ~99,6~' ~ " ' 73a'~ .................... 887T .......... 85~8.9~ _. 500.88 S 768~82_,,~ ....... 9IT.z+2S 56 Fa 3!~ 4:-3z,~,,q?,~)z+ ..... ..'..SJtSt.. ........... ~a~'- .... ~:~'~ ' .... ........ ~:.,.a__s._ :a~.~_~.,, ................. ~.o~ s ~ ~ ~,~ ",'~ :::'~::~,~ ............................ ......... ' ......................... .... ' . ..' .......... . .~, ., · .... ............................... ~.036 .................. 8670.9~ 5~,3~ 5 7-92.~0 W ..................... 959-z+O ..... S E>5 ~9 5 ~,~r ~'5.~ ........... ....................... ................................ . .............................. - .................. - ........................' .... .. . -". .................................................... ..... 925~ 8888.09 60~ .~+~ S 828.80 ...................................................... " ~' a ~ i:~ 9.9 Z ....... .......... .................. 9288 ......... 8910.92. 80'7.84 S .830,50 .............. g~lO 893Z.8~ 5~3.65_.5 ......... '~. 8,~.02 ....... ~t~ ..................... LO.3.5..."..~B'. .... 5__53_..3.g Z7 '~ ?:,880.~z' . ....................................... ........ ~ ........... . ..................................................... L~L~SSLZ;S ..................................... ~ 'S ....... .'. ..... ; .... ~ .................................................................................................... '"" S"'"SSS..SS , . .... ........ ' ............................................................................... .................. . ............... .......... ._. ........... ............................................. . ................ ._vEASURED DE°~H.__AND__.O!HER DATA FOR EVERY EVEN I00 ~'EbLT O.F_..SUB _SEA TRUE ~',~EASURED ...... V.ERT1:CAL SUB D¢OT~ ~EP'~H _._SEA MD-.TVD ..... VERT ! ~/\L ...................... . - ...... ............... TnT~L D .D!F_~ERz '~NCE . ....... C02~,-.C~ ~ION ................ C.O.OR .INATE$ ........................................................... - 15~ .............. :5:" ........ lOO o o · _ 251 251, 200 0 0 351 351, 300 0 O ~51 ~..53, .......... ~00 .................. 0 .................................... 0 ...... 55!, 551 ......................... 500 .... 0 ........ 0 651 .................................. 6.5_!.,.. 600 __0 ............ 0 751 7_5_1_. ........... !.00 ............... 0 .................................. 0 · _ 1183,00 N 250,00 W · ~83o00 N ZSO,O0 1 ~ 9 ¢'~ . . ' . ...................................................................... !IS;2.87 ~ 28+9.~2 w ..... ............................. !!82~77 N 2~z+9 W ........................ _851 .......................... 851. ... 800 ...... 0 .................................. 0 ......................... _~!82.,~6. N 289,85 W' . ..................................... ~51 95!. o,,00 .... O ............ 0 ..................... I18.2..~.7.5 .... N . _ 2~9~z~.! W ...................................... 105_1 ...... 1_0,5_1..., ............. 1,000 ................. 0 ..................................... 0 !_! 92_..8/-+ .... N .................. 249 ,,.! 0 __W ......................................................................... 1151 ].151, !lOC 0 ._ 0 118° 89 N 2z+8,~.1 W ........................... ~f._~ .-' . , .... . ................................................................. 1251 1251, 1200 ...... 0 ................... 0 ........................... !.1.82.,...8.9 ..N ......... 2 . .. 1351 1_3..53.., ....... 1_300 ............0 ....................................... 0 i_I..8.2_,.89 ..... N ..................... 2 1~.51 16,51. faO0 0 ......... 0 ............................ 1182,89 N 2. 155.t. 155!, 1500 0 ............. 0 ................................... 1.I b 2_o..8.9. N 2. ! ¢, 51 1_6_.5A. ................ 150.0 ................... 0.......'._i ............................................ 0 ........................................ !_!_ 8.%o_*, 9..._~ .................. 2 1751 1751. 1700 .... 0 ................................ 0 1182,88 N .~. 21 1851 185!. 1. ~ 00 0 ............................ 0 ................................... 1.1.82 · S a N 2 _. ........ 1951 ................................ 1-95!, !q00 0 0 1181%8_1 ...... N ................. 2 2"o-5"1 ................. ~2 o'r~-~. .................. 2000 ......................... o ................................................... o .............................. 215'1 ............................... 21-5'1. " 2100 0 0 1179,..8.8 .._N. . . 2 2251 2251. 2200 ..................... 0 ....................................... 0 1!'~8,9! N 2351 2351. 2300 0 0 ........................................ !.!..77.. 65 N ..... 2 ........................ 2/-+.51 ...................................... 2~'-i. 5._!_. .......... 2a00 ......... 0 0 ............................................ 1..!7_5...7.1. N 2 2 5 51 2. 5 51 .2 5 0 0 ...................... 0 ...................................................... 0 ................................... l ATA, 7_3 .... N ............... 2 2651 ............................. 26 5.1.. .......... 2600 2751 2751, 2700 0 0 .................... 1173,,"+0 N ...................... ~..s.5.! ....................................... 2.p,..5..1... .................... 2 a 00 .......................... 0 .................................................. 0 2951 295 ],, 2900 .................. 0 ............................................... 0 ....................................................... ............................................. !6..,....z .,...N 2 aa,, 6.0 W 3051 3051, 3000 0 0 i o 315 ! 3151 · 32.00 0 3251 325!, 9200 0 0 1!66.32 N 2,q.z~.,,!'7 W ................................ 335! 3351, 3300 0 0 1!64,61.. N 26z+.!l.W ...................... ............. 3451 ............................... 3'4'5!. ....... 3400 0 0 1162.87 N 214.3,96 W ............................................................................................... N'EASURED DEPTH AND OTHER DATA FOR ..V_RY ..V..N 1..'~ -r:E~:T OF SUB SEA .~'E'~'+-L~--~- ............... ~' .. ~ ~.-_ ........... '~ , ~ . . _ . .. TRUE ~EASURED ...... VER T ICAL SUB ,MD-TVD ........... _ vsRTI CA1]'-'ii.V"i./._i-_-_-_-_~._--.-iiii- ..... .................... - ......................... ........ DEPTH -- [)EP_TH ..... SEA ....D_!.FFK.Rr-.NCE ........... CC"R.r~ECT_!ON ....... ___T..O!.AL .__COORD:NATES · . . ................. s~-: ...................... B ~5 ::-. ..... 66oo .... o ....... e ~ 1- 5%...s ~ .... ~ ........... ,?.~s. ,~o. w ~75! ......................... 3751, _. ~700 _.. ................... O 3a51 ....................... 385~ · 3~00 ........... 0 ............. 0 ............................. !!5%...~o 2~-~, :96 i,',' .........................................., 3951 3951. 3900 .............. 0 .............................. 0 _I..!.5.3.,.~6 N ......... :,:~a~2S ~,','. ................................................ 4051 4051. 4000 .. 0 0 ............. !151.70 ,N ~..44~6 W 4151 4151. 4100 '. 0 ............ C' . .............................. 1.!48.89 N 2/+.:~z+O ...... 4252 4.2_5.!_.,, .......... 420_0 ................ 0 0 !_1_4_2_._02 ...... N ......... 246,04 ..... W ............................................................................. 4352 4'~51. 43n0 I .. ! 1..!.31.09 N .. ~.5~'~o W 4453 4451. 4400 ....... 2 .............. i ........................ I~16,70 N 75~ 05 W _ ~+ 555 4.5.5.1.. ___~"_4.500 ................. 3 ............................................. 4657 465.1_. 4600 6 S ................................... 10_77.69 ~ ,'.-.!55~4! W ...... 4760 4751.' _.4700 9 ................... ............................... 3 1052,62 N 2p7.5~ W ....................................................... ....... 4a65 4~51, 4~00 13 .................................................... a .............................. 1.0. 2..':)..,. .0 z~ .... N ............. 259_...9. L ........ !,I ............................................................................... ............................... 4'970 4,951. 4900 !9 6 988.77 N .:&2.,~g7 W 5078 505!. 5000 2'7 ~ °48.9L': N 756.~5 W ........ . t.~ .............................. -" ~' - ............ 5.!.B_7 ........................ 5.!.5.1.. ............. 5.100 .................... 35 9 __ 9_.0 6_....14._. N 273° !5 W 5296 5251. 5200 45 9 863.,~.76 N ,.".' S/-+ , 34. .W ........................ 5'406 535!. 5300 55 .1.0 8_2.0.7 ! N 297.05~' 5515 5451.. 5400 64 9 777,69 N .!:r.)9~40 W ...................... 5'52'5 ......................................... 5.5.51., ......... 5500 ....... 74 lO 7.3.4.55..N 322~29 W .............................. 5735 . 5651. 5600 83 o 6Ol,,62 N 334.~$'~ W 5844 575i. 5700 93 !0 648.04. N :::...,~.7045 W ~o~.~.].:: .............................. ~:<.:~.:.. ............ 5~oo .......... :.:,<. :.: ........................................... 5.~?;.s:.: ,'~ ::-/<:~.:: w 6176 6_0.5._1.., ........... 6000 124 !0 513,,7:..: N "-'90~,35 W 12 467~90 N 405~94.. W ................... ~O'2'S':7 ................ i .............. ~ :.51.1 ' .......... ~ ~'' O0 ..... &398 6251. 6200 !47 Il ................................................... 421'~.04, N 421,,29 W ................................................................ ~ t 8, .... + I~ .t.....,b~ ............................................................................. 5518 5"4'5!". &/+O0 !57 !.0 334,.66. N :.~51,,58 W 6729 6551, ..........6500 178 . !! 2.89,,19 _N 466~52 W 6841 6651. 5500 I~9 ....................................................................................................................................... 11 24.2~17 N 48!,36 W 5953 .................................. 67.51, ..... 6700.. 20.1 12 ............................................ .,.,.....7 N 97,14 ................... ~:..:,:. ~.~oo ............. 7179 6951 · ....... 6900 2 ''~ .................... 7'2"9.1 7.0.5.!_, .......... 7000 ............ 240 12 44,93 N 543,~',9 W .......................................................... ~ ..... ..................................................................................................................................... ......................................................................... FOR EVERY EVEN !O0 FEET OF SUB SEA ~v'EASURE9 9EPTH AND OTHER DATA ,?5.9_7? TRLJE ........................................................ V. ~_R_T_I_CA L_.S UB N D.-_T..V.D V-~ 7 T..!.CAL F. r~ E.N,, F_ '- ',' · ~-P TH $,.. A_~ I FFER C CO2R~- C zON T O_T_A..L C 7!51. 7100 252 7~03 ............. 75!5 725!, ........ 7200 ........ 25a ............................. 7626 7.351. ..........7300 .... 2_75 ............................. 72_3~ 7_4.%.I_, ..... 7_~00 .... 2.8~_ 7~47 .................. ~_551, ....... 7500 .......... 296 ~95~ 7651, 7600 30.5 ~5 7~_5_h. ..... ~..7_0.0 ..3_l..Z~ ~!7-~ .................................................................. 7 _~ 5 ! ill 7 ,.~. 00 322 ....................... r~ C~ ....................................... ..~0~ ~ ~ ............................. 828.0 .............. 795!~ ......... 7900 .......... 329 ............................................. 7 ..................................... 339_,2.9...S .............. 682.,_!7 ..... W 5 ~02 .... S ................. 7!4,16 W .......................... 8492 ............................ 8.151, .............. 8100 .............. 341 ...................................................................................... 8597 82.5.1., ................. 8.200 ............... 3 46 .............................................. 5 ...................................... ____.4.30_,_48 ............... s"7'o'2 8 ~ ~ L. s ~ o o ~ ~ ~ ~ ~_~.A,._o..o .... s .............. s-~d~ g~}il. ................. ~'~,~'o'01~"~"'~ ........................................... . 4 ~_~._o,~ ...... s ............ ~ ~ ~...~ .... w ........................................................................................... 8910 8~51, 8500 35° /+ 509,17 S 773.54 W ..................................................................... 9 01 5 ~ S ~ l ~ 8 6 0 0 ~ S ~ ~ 5_%%.? 2 .... S ............ 7. %8...~..9..8 ...... W ....... '~ ~ ~63~0~ S 80~.~7 W 9:20 8751. 8700 BSa,, : .............. ,._,_, - ~'~ ~'~ %'~'-1 ' ............ s'Soo ................... ~ ~ ~ ~, ~ ~ o. ~: s 8: o,:: w ....................................................................... ' ................................................ "'_ ......................................................................................................................................................... ............................... ~':s o , ~: :_, ..... %t.o.o ........... ~_:f~ ..................................... ~ ~..:.:._op_....s ................. e,.:.!.A.kw ..... ......................................................................................................................................................................................................................................................................... ~ ......................................................................................................................................................... .................................................................................... ~ ................................................................................................................................................................................................................ !NTERPOLATED VALUES FOR EV~-~"-'!"O00 FEET OF ~/EASU~ED DEPT~, TRUE HEASU~ED ............ VERTICAL SU9 .................. DEPTH ................. D._E.P_TH ......... SEA __3.000 29_99. ..... 29 aO00 ~9°o· 39 ............ 5000 ........................... &978, 49 ~000 58,9~o ............. 58 7000 792. 67 8000 691. 76 . . .L. . , ~' ~_..,,~ ................................. 4n. ' I°* 21 N 04-7,09 ...,. ............. ... ,....4 · ....... ,'_ . ............................ 4.,.'.I .................... !.(. q ® .L '~' 4R. ~ !q2.~! N 244,35_W 27, . 978.17 .T 263,g0 W ? 8636. 85~5. 532°05 9000 , 40, ...................... ~5o29..,_v N ...........3&_7_,5g__W ........................................................................................................................... 4!. 173.30 N 503.59 W 40, 242,04 S 642~39 W .... $ 7..8.6...., ?..6__},^.~ 400- 800- 12OO 64( VERTICAL SECTION · SCALE i": I000' . ATLANTIC RICHFIELD COMPANY DRILL SITE 4-7 ......... RADIUS OF CURVATURE METHOD GYROSCOPIC METHOD ALL DEPTHS SHOWN ARE TVD. '-TVD = 9017 ...... TMD: 9400' 4800 . . - ....... · _ .... : ........ 5600 _ . . 6000 4oc0! .... ! - 6400 ! · 6800' , . ...... ~ ~ - 7200 7600 · HONIZON¥~I~ VIEW SCALE I"= 200' ATLANTIC RICHFIELD COMPANY DRILL SITE 4-7 RADIus OF CURVATU~E ME-I-HOD GYROSCOPIC METHOP TVD=9017' · TMD =9400 ALL DEPTHS SHOWN ARE TVD. LOCATED IN THE APPENDIX UI WFL [21 IPR LOG UI CALIPER SURVEY Ul VOLAN CURVE DATA [21STRATIGRAPHIC HIGH RESOLUTION DIPMETER [21 OTHER: 02~]01B OEPARTHENT OF fiATU[{AL ~.[..:),,u,'-~.,:~..', Division of [)ii and aa TO: F-n K r:;i 1 ~'"""'" Jr !)i rector Ti~ru' i!oyle i-i. llamilton Chief Petroleum En~ineeff FROM: Petroleum !nspecgor DATE SUBJECT: ..... .xt,~ show up for January 7, 1976, I departed _r~iy :"-'~*~' at 7-30 A,."---~ for an ?:'00 ~'* ~ ~ ~ AM for Deadhorse. Shortly before o-O0 ~" ..... c.,art.r a'B ~. ~ ~q we ~,~e~? info,ed we ._. ,.~oc on standby for "' ' were bumped from the fl i '~ r~en s .... qn, due to crew changes. He ? ~ 10'00 flight and did depart at !~:15 AH, arriving at Deadhorse via Fairbanks at 1 ;u Pr-l. Temperature -27° r ~.~{ind NE Russ Douglass took a BP bus to BP operations and i took an ARCO bus to ARCO base . _.:, ._ '""'" '-' ' b!l~ tests I t ~..-~a s camp where I con,.acteu P, ill Congdon r.~marding ~n~duling of ~' ~ ..... dec]de,-_, DS 4-7 would conduct tests first and Shorty Allen, ~,~, drilling foreman, took me to Rowan Rig ,,~o.2~ on Drill site ..-:'o. ~-~. Toolpusher. for. Ro?:an ',~?as Joe Uam~,l i'J, ipplin9 up was in progress. Januaryo", 1976 .- While.. awaitinq._ final nipr, ling., up, _T toured tN~.:~ location and found it well orfian{z~ed, the reserve pit well built, the.well sign ptaced~ and the rig in general good condition Steel welded + " Tests beqan at lO'2O A~q with the hydril 'testing to ~0~, PS ~ " forty flanges in the choke manifold tested to 5000 PSIG. Two wing valves on the , ' tes~e~ to 5000 IG. Th.e check CJ]OKe line and two win.q' valves on the kill line ~ ~ PS ' valve on 'the kill line leaked, but was repaired and later tested to 50~ FSIG. Blind rams and pipe rar:-i~were tested to,.,,:,,.:,.,":nnn PSIG. ~OOu and" ~'~ ~' rams and I-.~ ~ot~les tested at Ir-'-'~'.;uU, ~8.00,, -, n, x4uu .... PSTG. B!i-d_.. ~ rams, h.ydril were actuated from both the primary a~ remote controls.. The manual adjust- able choke and Swaco super choke were actuateo. k~,~y froze in the rathole. The standpipe and Several hours delay occurreo xhen the rotary hose also froze and the rotary hose was removed fr.-~m the. standpi~ for thaw- lng operations. Tests · ' a · pu cock and lower kelly valve tes~,,c! to 30n(~ resume,.~ at il 4% ,,. with kelly Both ball type and dart type floor valves were in evidence on tim flor. Tests were concluded at 12 15 A,,~, January 9th A field inspection re~rt .was prepared, the original given to Shorty Allen, a copy for Benny Loudermilk,. and a copy attached to this report. J~.nuar~an(~ 'lu, ~ ',=,u~= - These" two days spen~ at drill site ~4 .... awaitin~ upcoming b/ b,. :":.U. ~. Fi eld Trip Report Ben Le Norman m January 23, 1976 January ll, 1976 - We arrived at DS 6=3 at 9:30 A~qo The drilling foremar; for ARCO was Jack Morrow and the toolpusher for Parker Rig ~ha. 141 .was Tom Black. Tests began at 4:25 PM with eight plug valves and thirty flanges in the choke manifold testing to 50~)0 PS!G. The manual adjustable choke was free moving and the Swaco s~per choke actuated° ~.Ihile awaiting nippling up of the stack, we toured the location and found it to be well organized, the reserve pit v..~ell built, the rig in good repair, and the steel welded fuel tanks not berm. ed. The well sign was not on location as it had not been received from Anchorage, according to Jack ~orrow. ~12 Bottles tested to 1400, 1500.~ 1600, and 2000 PS!G. Two fully charged bottles were irt reserve. Blind and pipe rams and hydril were actuated by primary and remmte controls. Blind and pipe rams closed in four seconds, the hydril in ten seconds. Blind rams, pipe. rams., and wing valves on the kill line tested to 5000 PSIGo The inside wing valve on the choke line tested to 5000 PSIG? but the outside wing valve leaked and was repaired and later tested to. 5000 PSIG. The hydril tested to 300,q PSIG. The kelly cock and lower kelly valve were tested to 5000 PSIG and both ball and dart type valves were on the floor. Tests were concluded at 6:40 PM and a field inspection report completed. The original was given to Jack Morrow, a copy mailed to Benny Loudermilk, and a copy attached to this report. January 12, 1976 - We arrived at ARCO DS 9-1 at 2:15 PM. The ARCO drilling foremen was Ken Jones and the toolpusher for Rowan Rig No. 34 was Char!ie Ingerson. Nippling up was still in progress, so we toured the location. The location was well organized, reserve pit well built, and rig in good repair. The steel welded fuel t~nks were not bermed and the well sign had not arrived from Anchorage. Januar~ 13, 1976 - Tests began at 1:40 PM. Top pipe rams, wing valves on kill and choke line and check valve in the kill line tested to 5000 PSIG. Bottom pipe rams would not test as they were closing on the taper of the too! joint. The test plug sub had to be shortened to facilitate this test. Blind rams were tested to 5000 PS!G and the hydril to 3000 PSIGo Sixteen valves and thirty-six flanges in the choke manifold tested to 5000 PSIG. The manual adjustable choke and the Swaco s~)per choke were actuated. The accumulator was tested to 3000 PSIG and all preventers actuated v~ith both primary and remote controls° There was no N2 backup at the accumulator, but Ken Jones stated they would get all material on location to fabricate the syst~ as soon as possible. Kelly cock and lower kelly valve were tested to 5000 PSIG. Ball and dart type valves were on the floor. Finally, the bottom pipe rams were tested to 5000 PSIGo Tests were concluded at 11:45 PM. Field Trip Report Ben Le Norman m 23, 976 January 1 A field inspection report was completed, the original given to Ken Jones, a copy ~.ailed to Benny Lot~.dermilk and a copy attached to this report. January 14, 1976 - We departed Deadhorse at 10:50 AH arrivine in ~nchora~e at 12:30 PM and at my home at 2-00 P~q. In sunmary, we witnessed [10P tests at ARCO drill sites 4~7, 6-3, and 9-!. Attachment Ala, Drlg. Permit No. Operator Satisfactory Type Inspection Yes No Item ( ) Location,General () () ()'() () () () () () () () () () () () () () () () () 1. Well Sign 2. General Housekeeping t. Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 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 Oil and Gas Conservation Commit'~=,' Field Inspection Report Lii~ ~, ~. ~ .~ Wel 1/Ptatfm Sec,~-? T ~?~,/ R/..'., ,>, ~/M Represented by ~_~ ~.-.~.~ Name & Number ~.~,~ ~ '~. Satisfactory Type Inspection Yes No Item (.~)' BOPE Tests ( ~ ( ) 15...~,~ ~inq set ~.~??.:~-,~ (~:,)." ( ) 16. Tesg fluid-( )wt~ )mud (.r/)'~oil (~=)' ( ) 17 Master Hyd. Control Sys.-,~L.~-:~psi9 (~) ..... ( ) ~18 N2 btls.~-. ~]= ~-, ~'.:,~,~:.~.~.~,.~' .-~. psi9 (~)-~ ( ) (~)-- ( ) (~,>~' ( ) (~.)~ ( ) (~):~ ( ) (.:).-.- () 19 Remote Controls 20 Drilling spool- ~ "outlets 21 Kill Line-(~.-~)"Check valve 22 Choke Flowline ( ) HCR valve 23. Choke Manifold No. valvs? flgs 24. Chokes-(~.-tRemote( )Pos. (]~]-A-dj. 25. Test Pluo-(.:_~)Wetlhd( )csg( )none 26. Annular Preventer ~3~?~:.;.,_-:psi~ 27. Blind Rams~-:L~,~.~psiq ( ) ( ) 11. P&A Marker (~) .... ( ) 28. Pipe Rams.~-~-~,~¥~r psiq ( ) ( ) 12. Water well-( )capped( )plugged (~.) .... ( ) 29. Kelly & Kelly-cock,/~::-~,~_~ psig ( ) ( ) 13. Clean-up (~_)'~ ( ) 30. Lower Kelly valve .,~!:~.-~:_ psio ( ) ( ) 14. Pad leveled (:::)~' ( ) 31 Safety Floor valves--L-(-~BV (~)Dart Total inspection observation time ~ ~.'-~ hrs/days Total number leaks and/or eQUiP, failures / Remarks ~ · ~ -'~---' ~'~ ~:~L~i~ ~.-:.- :~' :~,:~ i~. ~'.-~ ~,~ ~ :~'~ . . ~.~ · -...i~- CC' Noti fy in days or when ready Inspected by ~! ]~ /- ~. .... ~Date~,,~.-~ ~ _ Aiaska 99510 907 ¢,7 5637 January 14, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 RE- DS 4-7 (31-34-11-15) Permit No. 75-77 Dear Sir' Enclosed please find the Monthly Report of Drilling Operations for the above mentioned well. Very truly yours, C. R. Knowles District Drilling Eng±neer Enclosure CRK/BDR/cs ~,-.~ ~o. P-~ STATE OF ALASKA ]~-'V. 3- 1-70 OIL AND GAS CONSERVATION COMMII-rEE SUBMIT 1~ DU~PLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~-API NU~¢ERICAL CODE 50-029-20189 90'N & 593'W of SE cr Sec 27, TllN, R15E, UM 6 LEASE DESiGNA~--ION AND SEt{IAL NO. ADL 28325 1. ? IF I.~;DiAAY. ALOTfEE OR TRIBE NANIE 0IL [~ GAS WELL WZLL OTHER 2.N~E OF OP~TO~ 8. ~IT F.~i OH LEASE Atl~tic Richfield Company Pru~oe Bay ~. ADDRESS OF OPhiR 9 W~ P.0. Box 360, ~chorage, Alaska, 99510 DS 4-7 [51-54-11-15] 4. LOCA~ON OF W~ 10. FT~I.~ .~D P~L. OR %VILDCAT P~oe Bay - Sadlerochit Pool II. SEC.. T., R.. M.. (~OM HO~ o~ Sec 34, TllN, R15E, UM 1~. PElq.~IT ~O. 75-77 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA_'x'GF-,S IN HOLE SIZE. CASING AND C~<[ENTING JOBS INCLUDING DEPTH SET AND VOLUiMES USED. PERFOI~ATIONS. q-F~TS A_N-D RESULTS FISHING JOinS. JLrNK L~q HOLE A~ND SIDE-~CKED HOLE AND ANY OTHER SIGNIFICANT CI-LA. NGF-.S IN HOL~ CONDITIONS. Report on Operation for December Completed rigging up and spud @ 3'30 am 12-31-75. Drilling a 17½" hole on January 1, 1976. NOTE --Report on this form is required for each calendar month% regardless of t tatus of operations, and must be filed in duplicate with the oil and gas coneervat~on committee bythe 15th of the succeeding month, unle~a otherwise directed. December 18, 1975 Re: Prudhoe Bay DS 4-7 (31-34-t1-15) Atlantic Richfield Company State Permit No. 75-77 C. R. Knowles Distric Drilling Engineer Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 Dear Sir: Enclosed is the approved application for pe~it to drill the above referenced well at a location in Section 34, Township llN, Ran.~ 1SE, I~4. Well samples, core chips and a mud log are not required. A directional survey is required. Many rivers in Alaska and their drainage systems have been~ classified as important for the spawning or miqration of anadromous fish. Operations in these areas are subject to AS 16~'50.870 and the r~lations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to comm~nci~ operations you may be contacted by the Habitat Coordinator's office, Depart- ment of Fish and Game. Pollution of any waters of the State is prohibited by A.q 46, Chapter 03, Article 7 and the regulations protmul~oated thereunder (Title I8, Alaska . Administrative Code, Chapter 70) and by the Federal ~atem Pollution Control Act, as a~mnded. Prior to conraencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the iss~mnce of this .permit to drill. To aid us in scheduling field work, we would appreciate your noti~fing this office within 46 hours after the well is spudded. .We would also like to be notified so that a representative of the Division may be present to witness testing of blowout preventer equipment before surface casing shoe_ is drilled. C. R. Kno;~les Page 2 Dec~ber~. 1"~ , 197~ In the event of suspension or abandonment please give this office adequate advance notification so that we may have a witness present~ Very truly yours, Hoyle H. Hamil ton Member Alaska Oil and Gas Conservation Committee HHH 'bjm Enclosure cc' Depart~nent of Fish and Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enci. Departn~ent of Labor~ Supervisor, Labor Law Compliance Division w/ encl. AtlanticRichfieldCompany No,'th America 9ducing Division i'-4 o ri_l'~ Alaska Post O.~fice Bo:.: 360 Aliciv)rage, Alaska 99510 'r~l.:~pl~o~e 9r)'f !77 5637 December 15, 1975 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 RE' DS 4-7 DearMr. Gilbreth' Enclosed herewith is our Application for Permit to Drill DS 4-7 and $100.00 filing fee. The required survey plat will be submitted as soon as it is available. For your information, as well as for the State Department of Labor, the surface and target location are on Lease ADL 28325. The effective date for lease is October 1, 1965, with a termination date on March 27, 1984. Very truly yours, C. R. Knowles District Drilling Engineer CRK: alh Enclosures SUBMIT IN T/RIPLICi . (Other instructions on l~orrn P--I rever_ce side) BEV, 9-30-63 STATE OF ALASKA OIL AND GAS CONSERVATION .COMMITTEE ,, APPLICATION' FoR 'PERMIT TO DRILL, DEEPEN, OR~ PLUG BACK la. T~PE OF WORK DRILL W£LL WELL OTHER ZONE 2.NAME OF OPE~ATOH Atlantic Richfield Company P. O. Box 560, ~chorage, Al~ka 99510 DEEPEN J--J PLUG BACK J-] MULTIPLE ~.~ ZONE 4. LOCATION OF %VELL At surface 73N & 602'W of SE cr Sec 27, TllN-R15E At proposed prod. zone 1320'S & 1320'W of NE cr Sec 34, TllN-R15E 13. DISTANCE IN MILES AND DIRECT!ON F_-iOM NEAREST TOWN OR POST OFFICE* API# 50-029-20189 $, 6. L.F_,~SE DESIGNATION ,~Nq:) S]51qJ3%L NO. ADL 28325 8. U~IT, FAR~[ OR LE~E 'N~ME P~oe Bay DS 4-7 i0. F1ELD AND PooL. O1~ %VILDCAT Prudhoe Bay-Sadlerochit Pool 11. SEC., T.. R.. AC., (BOTqTO,%'% HOLE OBJECTIVE) Sec 34, TllN-R15E, Approximately 6-1/2 miles northeast of Deadhorse 14. BOND ]NFOF~MATION: Statewi_de Federal Insurance Co. #8011-38-40 TYPE Surety and/or No. 15. DISTANCE FRO,M PROPOSED* /~6. NO. 'OF ACRF_~ iN LEASE LOC^TIO~ TO NEAREST 1 PROPERT~ OR ~^SE LINE, ~. 1320' 2560 (AI.~ to nearest drJg, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION* ]I9. PROPOSED DE"PTI{ TO NEAREST %VELL DRILLING, COMPLETED, Oil APPLIED FOR, FT. 3200' 9450' ~.mou.~t $100,000 17. NO. AC~ES ASSIGNED TO THiS WELL 32O 20. ROTARY OR cABLE ToOLs . Rotary 22. APPROX. DATE WOtRK WILL START* 21. ELEVATIONS (Show whether DF, RT, CH, etc.} 19.5'Pad, 52' RKB January 5, 1976 23, PROPOSED CASING AND CEMENTING PROGRA~M 32" ' '20" ~"94# H-40 100"± circ to surfaCe approx ~00 sx 17-1/2"" 13-3/8" 72# 5,~-80 2700'± . circ to surface approx 12-]/4'" 9 "' ..... ' ..... .- ' ..... .... -5/8 ..... 47# ib~-80 9450', ...." +~500'cmt:, c01umn., on lst,,,..sta~e. ........ &, ,RS-95 ,.,,,300[.cmt col~n.on. 2n~ sta~e ±125 ' , , SX The Atlantic Richfield Compm~y proposes to directionally drill this well to 9450'~,~+, 9020'TVD) to produce the Sadlerod~it zone. Logs will be run across selected intervals. A 20-3/4", 2000 psi Hydril will be used on the 20" conductor. A 13-5/8", 5000 psi Hydril m~d 13-5/8" 5000 psi pipe and blind rams will be used on the 13-3/8" casing. /]~e BOP equipment will be pressure tested each week and operationally tested each trip. A non- freezing fluid will be left in all uncemented annuli within the permafrgst interval. This will be a suspended, cased hole. rN ABO%~ SPAC~ ]D~-~;CI~IBE I~ROPOSED PRO~T~RA_M: If proposal ts to deepen or plug baak, give da+~a on present propgsc~ ~ew produc[ive zone. If pro~a! is to drill or deepen direct onally E~ve per%lnen~ dat~ on subsurface k~c~tions true vertical depths. Give blowout preventer program. ,. ' ~,, SX (This space for State office use) jSA.MPLF~S AND CORE CHIPS [] YES ~] NO DIRECTIONAL SURVEY X] Y~ [] NO 75-77 CONDITIONS OF APPi~OVAL, IF A/N-Y: j A.P.I. .~q3q'.WJ[l!q/CA-L COD?.- · 50-029-20189 ~ov~^~ December. 18, 1975 ~.~ De_cemb,er. 187 !975 CHECK LIST FOR NEW WELL PERMITS Is the permit fee attached ............ · . Is well to be located in a defined pool ......... Is a registered survey plat attached ............ Is well located proper distance from property line . Is well located proper distance from other wells ....... Is sufficient undedicated acreage available in this pool ..... Is well to be deviated ............... Company Yes No Remarks ]. Is a conservation order needed ............. 2. Is administrative approval needed ......... 3. Is conductor string provided .......... Is enough cement used to circulate on conductor and surface Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ...... ~. Is operator the only affected party ........... /~.,;~i 9. Can permit be approved before ten-day wait . D. Does operator baize a bond in force S. Will all casing mive adequate safety in collapse, tension & burst 9. Does BOPE have sufficient pressure rating . . dditional Requirements' 7. Will surface casing protect fresh water zones ...... ,,- ,~,' Approval Recommended' Geology _E n__9 i nee ri na' TR,x HWK '~'~'i-~,,~ OKG HHH Revised 1/15/75 Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. ., No special'effort has been made to chronologically organize this category of information. LIBRAJlY Tg-PE CURVE SPECIFICATIONS Company ARCO Alaska, Inc. ECC 2:308 Well D. S. 4-7 ~ Field Prudhoe Bay County, State North Slope, Alaska Date 3/26/86 Curve Name (:\bbrev.) Standard Curve Name Files 1-3 CCL ! Casing Collar Locator CN I Compensated Neutron SSN i Short Space LSN GR Logs Used Scale CNAV Long Soace Gamma Ray' File 4 Average CN CN - Multispace 60 - 0 5O - 55O 0- 200 0 - 100, 100 - 200 60 - 0 :CC NUM~-R ALASKA ~PRUDHO~ 5AY Z305, UO INC, 'l/ bU~vb.5 ;;S 5N1 LSN1 ~SR.~ CN3 CN1 SSN2 LSNZ CNZ ' '"'"'"'"' "' r i, , i ' ,~," ' '"' I i,i ", ,' . ,,Nih ,,,, ~ , I ..... iIIh. ..... ~ ~'' ' "" i, .... ,, · ................. ...... ' ,,,,' ,,' , ~ ,' ,Ih'" I, ,~11 ,~', ,' II Ii ',, '"i'I:1 ,,:~r I ii:' ',, I' ' ',,i" ,,I ,/'', ,111"1,~1,, ," ,,,,,~,,,1~11t? II ii~ '~",1 "h, I'" ~ ,:,' ''~ I: '" I'J' '~'",,1'" ,1' II1" '111', h, ,11:1' ,llhl",i,, :? %,!,'111', ,, ,,," ,,,, ,1',11, ',, '11 i',I , ,,'11 ,"1,,,"",,"" ¢' '" ,,,", ,'" ~,,~,, ,1',, ,," "' ' ':"' ' "~""' ' · ,,: II1' ,: ' , I' , I, ,h ~'' '11 I I ,lllh ,,1, ,Ih, IN ,: ,," I" I' "1~: II ,11 · I I,i '" I , r "11,1" "", i ..... , '11II" ' ,,' ,,Ii ' ,,1,, ,, ,111 i ,,i., ,, .. i,,: ,,: :,, ~,, ,,, , ,, ~ 'llIl' ' 'l" i ' '" ii ' i' QI' Imm~ m I : . ,i i" ' ' i'"':llI' "" ,i,., i ~i" ~.11 Ill illl~, ,11~ ,i, ':, ,111' ~1:~, ~ J' ii, ,' ',~,, ,,c'" Ilh 2" ~ "'" Ir, ,11, I'ml !..'1' ~l,.jI ,, Ill I1, I1, "" ,: IIII Jl, ' ,~ I ......... "mi II II I' III1' ,,I ,, ~ 9 ~ U', .h "' ,' , · · , , ,, ,, , , ,,r', "' , ,~11 i,j" , ..... : ' ', h n ii Ii' 'r 'n ,II' i" Im ..... I~ , '" ' !' ,,' III /' ;'" Ihl, iii 1,1 ,hiI ' I ,",ir ' i,i "' ,' i, i ii ,,, ; "" i ,,11 i 0. a 5 0 0 .. ".' ".: :.? :~.~. '~: ..... ,,,', ................ , ........ , ......... ,,,,,, ,,, :,,,,, .............. :,,,., ......... :,, ,:", .... , .......... , .......... ,,,,,,,,,,,,,, ......... ,,,,~ ....... , ..... ,,,,,,,,, ............. ,, ,' ,',,,,,, ,,,, · ' ' - '= '" ';"~. 4~' '"":1,11' I':' ' I,, I1: ' . ,," ,i,,i ~,1 ,:1' ,h ,~.'",1 ",,11~i,'' I" "" ~'J'' Iii:: 'I'¥' ;:h I';,, 'r"i:'"' ¥.' ,,111 ,'" i ;",'" ,11,I, ,'".ji!i'" iiiI' ,' i,l",:" ,~, '!!' ~;,,' "'9' ,: ,,h,ii '" , '. ,,,." "'"2" i, ,,!,11" :'1 ....... I, ,, ,,, , ~1, ,,, I,,,: i . ','.,:'?,,,,,:?,:,:,"ill "I'i'"1'i" ' : '"'i"h'.''' "'1"' ' I ii':11 I1' II1~' ': '" .I '::" .I, '!" ~,.,'..1'" ..,I '1., "..".; ,.': .,~l~, :!1],111' '1'" ,11;, III; .:'" I'1'!'1'''' ,:" ,,, ,,, ,!"i'. !1'?1¢,, .!" #cji j"' .,l!lliill,' , I1~',,'"', ii,,,,i,,,!!' iii ii,'.,'"'", ir, ,'" i"?, '"' ,:!:. ,,./l'.lill,......,~1 ,ill '.. I¢ i1'.: .,;".!1' .~ .I ii,I ii,'1 I" ...,~ '" I1' ".19' !1 I1! '" ~1, ' !" I '1 . "ii ,"1 .".,,.';;' , '., i' I II ~ rll r i . ,1' ,,:' ,,~ ' ii, .:" ~r m~ lmmmmm mm ~mm ~F ~ m m mm mmmmm mmm r mmm~m mmm mm mmnr m mmmm ~mm mF m~mm m:m mm mmmmm m mm~m m m mmmm m ~mm~m mmmmm mm mmm mmm mm m m m mm:m mm m ~mm m mmm m mm mmmmmmm ~m ..... ".' rm. mmm. "'"' ? .'m~'~'~ .~m .' I1'." ' h.?. '"",".'",'"'"'.'"".,.'"' ' ',.'.. '"',,ii' I1'I',ii :" i"j'"::','~ i',:'',"i","" ?' ,17 II..,.':' 'h II,., ?1 i' I "'" ,I' ""'"'"'"""'," '""'"i"' I"?'" "" ..?," . "." ' "11 ~ Iv ,', h ,,:u~'''1' ,,' ~1,,,,, ""1"11' .':... ".". '... '": .... i: "..,. 1.1~~ .;,I,, ,: ~ iii I~1 .,I,,,I i1', iii..;,..,... ;11' ~ ..;!1; ..,1!: I~ ii .......... ~,111, .,111 , .,..i, I ii...1"1 ,,, ,,!' iii1: ,. iI ..~1 ii1~ ,,,,~ "',hi '. i .;11 .i 'i'' i1" ... I,.. ,; .... i,, ~. h.. ' '" "~ :' ." '"" I," '"' '1:'1",h Ih. ,. I' I1~ "' "" I',.. ii I i.' '1~ '" ":'"' '1 'l"~ '"" ~1 ,/.:Ih" .... ~' ,,11 :~,,'"~',:AI' ;'"' ,I;, ?,)1111,-mm-mm- .11:I III 11,72' ,,' ',,11 ~u~.)l'..,I,,r 'llll"llh/.1' .ihl, ,1" I.ill.,L' ,i,,,,:li,,,, ¢11",:.' ,11%' :"'11.1¢ .'"'¢ ~"1~I));;', ,i,,~,,~; i I II)1111 ~,1,,~. ,;, '.,I,j,;i .:.,i, ?:ll~,lllI~l.. ,;i;i,,,,111.' .,,::, ,, .,I ,11,, ;~, ,,, ,,,, ~.1, .11;;i, '1:. ~ i, ,.: !..11 ;;, .?.., ' ~", i"" '1 i' iii ,i "11;i .' I1, ', ,,,, iiii,,. '11' ,,11.¢ ,,i ,11 ,,, !~u~, ,,, ,,,,, ,i ~,,.,,, I1'. ,,, Cul, I, i,,,,,,,,, iii,, .,, ~JI ,,i .. ,L, ,' '1~, u ..... ,I, ,,I,, "~, ii,, ,., ~,,,~ ,Ih,, I .... ,, ,, ,11, ,, ,h h,, ,, II ..... I I ,I,., .............................. i mil .... ImmlI i ml~ im ir iI .... m~ II mm '~ m mr mr II i,Ii '; ," ,, ,, ,"' ' ' ",,,','1,' ",, ~",,,' '"Ill' "1 m"mm,m.m,m- ,i' ? j,; , ',,,,:;i,''1', ';",,, ,l'". '" i ,' :,1,, il'"'"' i'i I,l" ,!1 'l',li '!1 i,,~'lltl~ ,;, {" ,,111 iI ,, ,, i1,, , i ...... ~JiiiiI i1, il' i1,~ ii ii ,11 ,,~; ;:,,, i,: ' ,,;, ~l' !11,, ,i .,i Jr ii1,,,1! ,,' ~, ,l~ ,, :' ~L~ I1'1 ''v "" il! i1, ,' i1' ,,' ,,I ,'lll,,lllI .,i ~.~'i'!'.:i..O~TE.:'IO'/ ~/~6 TIME: ··16: O: 7 6RCO ALASKA :NC. ':'.'"~ DRUDMOE BAY D=PTM ~AMM~ RAY LONG SPAC; PASS PASS D~SS PASS PASS PASS ~ 5 6 4 5 6 ~01. 2~3. 2~. 251. 17. 1~. 17. 17. 18. 1,7.' 95. 95' .',1 96. 95. 98 ?0.~ 96, 65,7 7'8,1 .U $831. 281. 271. 277. 17. 21. 8535. 259. 271. 286. 19. 17. 17. 97. 9~. 96. 87.$ 5b.$ 90.1 9.0 17. 94. 9Z,. 9~. 63.4 ?"!.i'.. P'R U D H 0 E BAY TIMS: ;~9.,, 23';,. _>39. >23._ 1 7 . 20 · 1 $ . 1 01 · 98:; 24. 32. 47 22. 24. 3O 23. 107. 103. ' '5'7,:1 :".. OAT:: 10/ 9/S6 ARCO ALASKA iNC. PRUDHO~ BAY TIME: 16: DEPTH GAMMA RAY D4SS P~SS PASS ~ 5 6 LONG PASS 5597. 191. 195. 194. 55Y9. 195. 199. 2uu. ?i. ~D. iU 5911 · 8 .~914, ZO1, 1~, B915. 203. ~O0. 8916, 202. 198, 391~. 190, 1~2, ~918, ~17, 190, 8919. ZOO. 200. ~g21. 182. 1~1. 6~gZ. z 19-;-- 2 z ."' 1...,,- ...... 2.?..,... 2.5., .... ,'" 24, ?': 189. 23. 24. '~02 · 23 22 8926. 227. 230. 224. 25. 30. ~9~7. ~? 2~0 ~3~. ~. · ~ 1, o...... 1,10,, ..... ~T'~,,,,,~,,, '~ '~:;~T'"', '"'"'~"~:'~'"'~""'"'"' .'".""~,.'g~'''' ....... ;9'9. ~'. o ........ ".::"......"::' ...' i' , .i , '"'.. · i...~ ........ iI .... iiii ,, ,111 ....... ~,...,i, .. i,~..., i~.,., , .h "1.. '?L ...... I. i ..... : .... Lmm.mm I ul, ..... "' ',... ,u' ,.. ~,',, I1"" ', III''''1 , '11" .il, 'm 30. 123. 116· 114. 52.7 45.6 42.6 -9999.0 8931. 241. ~44. 111 · .u ·u PRUDHO5 BAY TIM~: 16: U: ~ ," :,, "~',~ :'!~, '~'"'~ 'A', "" ':= r, ,,, ,,,~: ti,'' "," '"L ,'"," r u,,"' ~ ,, :,,,,,~,, ,:,, ~,r : ,,,"" ,,,,,,,:,,, ,:r.i,,,,,,:,, ,, ,=,, ,,, ,,,:, ,, ,,,,, ,,,'" ,, ,,,,, ;,] ........ r'" "," ,"', ,," ,," ,,, '"~'" ,",, ," ,": ,,'"" ,~' ",,,,,,,, ,'"' ",C', ....... ,,'" ',, ",,,'," ' ",,,, ." . ' "'..~ 1_, ~ ,,,~,'~' ~..,, .., .... ' .... , .. ,,. , .. ,, ,,, j, ,.,. ,.,, ,, ,,,. :.. ~, ,,, ,.. i .. ,.,,..., :. i,,:., ...,.,, . .., ....,,,, .., ,, ,, ..... ,, .. ,, ,,... ,.... ,.. . .. I,'J'' " "11' " ........ ,,, ,,1:,,' ,,~:,',,,,,, ,":',Jp ',,,J,,o",j~ :lJ'J~ '"~'",, "l',~"t'~' ,~'~j,,'" '~i"~',~'~:," '",,J~,,' ':'"'~,,:,'JJJ,,LL '"J ~'"j, ~"1,,"' ',",~'",i~':',"l~,,jj' 'J'"~ ]'".,1,' Iii'"' ?",,JJl'",,~l~"'"l'J ,,'" ~"'"JJJ" "'J' '"'1:'"' "? 'l' .J L-~l M GAMMA LONG S~AC: 152. 165. 155 ?,.0 176. 163. 4 ~j 2 j 8 1.B3. 179. 1'7~ 23.8 2~.'3 ,.:OAT'E: 10/ 9/86 TIM,.=: 16: O: ? ~RCO ALASK~ ?,..PRUDHOE BAY 3EPTH GAMMA RAY LONG .... '"' mASS PASS D~SS PASS PASS PA,SS 4 5 6 ~, 5 6 $993. 182. lm5. 176. 67. 66. 67. 8996. 170. 177. 179. 61. 60. 8999. 176. 182. 175· 6.8. 1~4. 161. 62. 22,8 3.4 9003. 187. 182. 1,~2. 59, 62. 62". 56, 156. 9'011. 19'?.. 192. ?~,,~'7':,,. ;)012. ;~01]. 1~9. · I 9Olb. 1~u 1;Z. l~..~., .... :~...4..,, ...., -' ~"~"'"" ~"i ...... :? ....... 'f' 9'01.5 · 1 ~: 901b. 1Fb. I~.Z. 1FO. 64. 52. 9017. 15~. 151. 1~. 61. 57. 9018. l FZ, 17~. 18,3, 58. 60, ~3. 161. 157. 64. 156. 157. 57,. 1,,55,. 16 ' 5' 1 , 28.9' 29.1 ~0.23. 170. 100. 17~. 43· 45. ~025. 166, 160. 16.~, 44. 4~. 9027. 159. 176. 171. /~5. 44· 43. 143. 149, ~3. 29. 32, 33·8 .%; ........ ,,,, .......... .......... ., ~ .... , .... ,, ,~ , ,, ! ,,,,,,, ~,, ..... ,~ ,,, I ............... ..:: .............. : ...... E ,. ~ .......... ~, r'~.. , ~ ~, .~,, ~ .=, ,~,. ¢=,,, ~, ...... & ,,~, ~, . !,~.1.,, .: .,~ J. J., ~., J, ,,,, . .......... .~ ...... PAGE .~Cu 'P~UDHO~ BAY .L NL, o ' ~06]. ]i6. ]]~. i28. 38. 35. 35. 128. 9004. 90. .~. 101. 37. 36. 36. 153'. 131,~ 906~.' V7. ~. ii1. 38. 36. 36. ,139. 134. 90{~6. 9~+. 10o. i-iO. 39. 35 ,3,9,.,,,,, DATE: 10/ 9/86 .'&RCO ALASKA INC. · : ~RUDHO= BAY 16: 3:7 PAGE ? SEPTM S A M :,,la, RAY .~SS PASS PASS 4 .5 5 PASS PASS mASS 4 5 6 SHORT SDA,,E ,,,,OHm. N TRON ,,,. .. 5 4 5 6 .NEUTRON i ,,, ill ,, ,~ ,i, ,i ,, ,! i11 ii , ii iii i ,1, , ,ill , ,, i, 9039. 119. 151. 12:3. 36. 131 . 136. 13 ~8.7 8.1 9.5 .U 9103. f~. gL. VO.': 91g). qL)~,· :",~. 9106. 10~,. 11~. 9107. 110. 130. 9108. 108. 117. '9109. ~z · 911g. 95. 96. 9111. 36. 9~. 9112. $/,. 94. 9113. 96. 9114. 102. 99. 1 z 3~- ~ ~ ' 1 ~..~,:'T". ~'.,t':--:::.~ 1~.o'. -~' .1-T-':~,,~ST'' ~,,.;, ,~ ,,:~ ~ .... ~. ~ I '~',0"~' ' '3 ~' ~5, 39 · 35 · 1U1, 34, 3F, 1U3, 30, 32, 38, 138, 32, 128. 30, 1..2'4,,,..... 128. .6' 37.1 129,. 12 40.9 ' 42.5 .u .u 9119. 80. 8..'9, 8 -'"/· .u 9123· 82. ~5. Sb. 35. OA J'~: iOi PRUDHO: BAY PAGE " ' , ,,,:,,~r,:, 'i:,,",~r,!il,,,, ,',',, "h,','~',, ':~"'i",i? ": ,f" ,':'"'",? ,:,':',',,,',,,!"',' :"'r ,, ','~,: ,',:,[::,,,,,' :', ;'"'i'::i"' ;'" '""'i'"'" ",,"~:,, ,":' ;,,'"~"; "'"~Ii"!"' ,,:l, ,,,'1'~ '!"' ,','", ',,,," I,",,,,'b ,,' ",,, ,,I,' ,,,,'' i:" ",llil: ",,i, . ,' ::,~',,' ,,,11¥,"['",'".'",,','1,', ,,"',',1,[, '" ,' ,,',1,, ',:,'"[,:":,'r',,r :",,,',',',' ,',',' ,',,,~" · ,,, ...... ,,, ...... , .... , ...................... ,,,,, ,, ' [1'~,,, ,AI ~': ~'1' ,S ?'~I'l ~,11]1 ,j,II '[II' ,[,,Il' III '~,,~ ':,' [,,iii"Ii ',1 '1':', , i '~"[ j, '1111 h'l" ij'l:[,,i, I"ll: ~JJ i,~llI [' l, I .[ii,' r ,]'lj? ::" I"l'jj? jh,,I'? iJJ ,' [IJJ::Ij[," ,'lI }J]'jj;:~ I:',,jl'l Jill :"11' ,I '11 "'~' iii?lq 'Ii 'il, I 'ljlJllj:lll: I~",j~lJ,' ,Iiih I,"I,hl irq IH JlJ' '1111 "1 h ' :" !"' ' !'l~' ' ' "H,' ,1:'"~,'''1'" ,I,r],,,!,'' '""?i',!1: ,'~l,,'1'''1 ' JJZ'"?,'""'"' !"," II, ii,,,D,! 'J"D'"" IIj'l""J''''' '¥'' II1'"'"'~ '"i'J'"' "' '""' I"'"'" '"' '"' '[" '""" ' ~'l'"' "11'" "1 b~ :. R I .,-i L, A HPi A R, AY L .r.J N '~ S ,-' ~ L ,:.' 9-i 7-i. ~; c-,. L, 3 · ~i72. 51. ' 45. ~i7'.~. 55. 9-i 7~. 50. 55. ~-i 75. 52. ~. 9i?o. 52. 55. 25. 27. 24. 55. 27. 23. 23. 57. 32. 27. 31. 41. 37. 31. 35. 111· 106. 109. 109. 122. 112. 1 ,,3,4,,,.,,, · ,3 , 46.5' 1 I 40,.9 45. OAT,:: 101 9/86 TIME: 16: O: ~RC, O AL/ISK~ ZNC. PRUDHOE BAY P4SS PASS PASS PASS D&SS PAS 4. 5 '5 ,~ 5 /-!. ) , :111hI' , , ,i,iiiiii,I ,i,, ,i,, i ,,~,,,,i , dllI I, ,,~,,11 i,' iiiI I,~ ,,:,,':~]h~'::,i I1~11 I~iiiI ,llhll'll' i~I~ii~II~u II~hl'll'lllI ii~1,, ,~,?,1,111111,~ ?:1 ,,,~1'1, iIIi1~1,, ihl,l'l,ii ,1~. iiiiiiiiii 41 III1.']1~1, ~,,?1 ',,,1717511 Iihh IIi1"111'1]~,,, I hlhlllulllll I]MI ~1111,,, illj I~, 'i "I :lhllll' '~1 I". IIii1~ I I ,,iClllllll, III Pill II IhlI I IlhhII :"'l'lllhll', .U 9ZZ~. 57. ~1. )2. 27. 26, 23. 107. 108. 9225. ~7. 58. ~?. 27, 25. 25. 110· 110, ~ZZ6. 58. az. ~8. 27. 24. 2~'.:, ~ 9230. 48. 49, ~1. 29, 36. 9231· 55. 53. 48. ~7. 28. 31. 115, 9233 67 =3, 50. 27. 26 25 · · ~' · · 9235. 57. 65. 55. 31. 26. 24. · '9 47,',9 4:6'. 6 47.7 .. 11~. 117, 48.7 37.4 41.5-9999.0 15, ·u PRUDHO~ BAY PAGE 10 . r , ' ,,, ,,, ,'"r ~ bm, ',,,,~ mm ,:,, HI ', r ~r ;~," ,,: n Il~ .,,,r... "111 ~ .. iii. ,. ~..r;.,,. ,'"111'"', .u.'....,'.~:...I . II. "'"' .......'"'...h ...' ,' .11 ~1...,',.? '"' "'er =i "..,,,. ,'"'".,, V'..,..'.::",1'"' '" ..." .:' ,..¢'.11' 'r ~.. ,' ,' , ,,,,": :,i,,,,':: ,,,,,,,?' ,ii, ,;",,,,::" ?. ,' ,,:, ,,,, ,, ~, ........ ' ,,, ,,,,",, ,,,~: ,, ,,,,,',,,, ~,", ,,,,, ,,,",,",,,~" ,,, ,,;,,,,,,,",, ,,,,,,,,,,,:' ;" ,' ,? ,,,'v ',,' ,,,,,,,,,, ,,',,,,,:" ,,,, ,,,,,,,,,,,,,,,,, ,,,, ,,,,,,, ...... , ........... , ' "' I' '" ~ .' ,"'. ii ''"'" '"'" ;" ~iI" '";'"~'" ': '~ "'"" "!""'i;' .: '~::'i?. =:' '; ':' .' ',::" .. '='";' l".J-i:-- .i" "'..'"'",,",'"".'"",'".'",'" .:'?' ,." ;m;'". ?' ,!'l.'..:'m" ¢:"'. '"' ./' ii:' ,' ;i' ? :'"' 11 ~,11 .,..,i!, .lilN' .; , ,.I "1 :!' .:;' ~, 'I ". "I .iii";; ..r 'III .I1~ iL' ~,.. i:' . ,ii I!."I i:I ., II''1 i,, ".,:! ?1!11'. ?r '. ,: ....:1" 41i :" .i.:' "...,'. ,: ~.ii i~ ,,, .......' A,, ~r~A~'~'~:~''~`~'~'~'i:~'~'~';~ :,,, :,;? i,,,: "~':,;"I"",":' ,,",~,,,,:'"'",,,:" ",'",,:,,,",',,~",,,'"' ,,',,?,",,','"',,,,,,,,,?',,~,,!'", :'/,',,,,'""'",,l";'mr4, hmmrN''~//"r:'''',,:'''?4r ,,':/4,":"::r:,::,r'?7 ,rr"":, 4=m,, '" ' '.h' .r' ..i... r' ' "..,~ i,,..'"' ,,.i i ii. '" .i ,' ii i1'..,ll,'.lil." ,.i ~',..,~,111.,'1 :.11 i.' ,111,;, I.i,:..l ',.11.11,' ?;1!1,.? .¢i "~1:'.i' .? .,;:' :',~&' '. ',,I;", ,i,l,~l." ~' ,,::'" ~1' ~; "I,,l'U .I",, ,11 Civil., .I'.,..., ,i., .,, ,, .,,...,. [ ,.ii,'".. ,i, ~;,,? .i, .' .::,., '" '.'1 ,,' ', ,:" '1 :; ':',1, ~." i:.' ,. ~, ';" ~,,11, ,' i, .'" , ,. .......... ~ .............. ~ ¢,-, ,,,~ , 1,~ .... . , ", .... ",. r . ~' ",~ "'"' '~' I~' ' ~ ,' '""'~i;' '"~h"Y"II "' Ir %' "' i '~',~.'~""1'. ,,,"" Ilch',lll'',"~' ~'' "~' ¢,1 t. , .,, i.,,. ',, 11. i. ,' 'h ... '~, 'h,. ~.. h. ~".. ," ~ ,,,,,. ~!!'".,,'". ¢ ~, #...,' h ,~¢,,!!!, ~,~¢ %!. '1. I'~. "1 , ~ .."., '" " ... '. '..,,, .',.,,""'" .:' .. ',' .,....~' '"'.,I '. '"" .,; .'" .'~q"!', I'", ' '~':" "! i' '1I' h,' :~' ,;" ~ ";' '" ~!..,i.~'~I' ,. ~1~,, ~" ~..1~" ,.,; ¢'",1' ¢,,1" .~1' ?. ,,~, i~ ," , .~' I~'" Ii' I1' ",1'. ii '" ' ;1' .II'll "' ,11. ,111~¢ '"" '.:' ..I' .1',~' I1' ~II' , ,.~..'"li',i" ,, I,:'" II!" "' .,'"". I?,,,.,. ',.' '" ' '"1 ",. '~ ,.. '.'",' ... ~' .,,, .'%" II ,"~... ,,11~II~ ,1'[ '".~11111,.."" II1' I",,b¢.'~!'",llr' ~"r,;i..',lllllL.~" dh ii ii1'! '"'li'd!!l,,,~.ll"'.,., Jif,I.;,',,! .~¢'~,.~,.',, ]',111 '".,.i,"]11, ,,' I,.' ,,17.~ ,,llr ,,'d' '"',,' ,F ..111 ,, '..,r.,¢' .ih 'I' ,,,' .,I.,~ ',lll'..'ll~[r ,I,,~,.,...., .i ..r'J,.I '.1 ..' '..",', ..' . ,,.,,, .. .. .... ", .' ".,,,,r ' ,' ir .h '. ,'~,"... '" ~'.~''~ ' '"11'.~" ;;.'~ ",.,~¥"," I',,i ~'" ~,1~ I'i., ~";" .,,' '"ill ' ' '",,1''" '"L.,!'"'h ", ?" ~,I,P '1]'"'~' .111' :'1%"',,, ¢,,' '" .,'" 'r.,'",, "~';"1.""'" .... , I , '~'" .' .... I~ I!r,. ~!, '",, ~' I', .,' ,lll,,ill '.11 I"h,' ,,r ,,. i! II" ,. i1,, '¢I ,' ii .... '11.111 ih,~ II ' h III1., "i Iiii. iii. Ih, ..Ih ,ihh~ '"hl I' '!h I1'..I ,.h,'', '11~.11 I, "1."1" "'h.,'",,"l' ',,..:' i[i,. I..I .... " '. . . .' .. ".I' . '"' ,, ,h ,.I'' .~"~;'h,, I, ,. h.' ,.,I ,!....i~,,ri...~ ,11~1,, .,,.~ , ~! iI ..,N~ .? ~ ,? h'. ~ ,~?',h .',h ',. ,.,.~¢..,,. ~ .... , .. ~'. ,, ¢.,? ,~,~ ~. ,%, .,I I'N Iii .?' ...'1 ¢' '" 'I! '" .',' ~ '~''" "h. I . %,I'~'"' ",,, '"" . ' ".'" ' ":'" ....... '" 2 . II. % ...... 112:"'1 .' II' ~.~i .... I ~;471 ':~ I'~., .'i. ~'11~I1'' ~11;,I:'"" ?,,.1~1!'~'1' '7,,~]~di:I' ? I1'.1' I ,er: L~ I"~111¢ t''''F '.¢ '1!" :~"',.i.,:"~".,"":~'['''' I; nh .".1;i ..ii; ,'"r ~n;l~'.' ~"1 ,I.~,1 ~l;r ~.ll::.~,i~,il' i II ,1~ ".~.,r., ....... i,'l '1.I' .' I": '1 ii/111:,'1 iI''1' II. I i.', I~, I ..4~'¢,:~.~. 'I f." ¥ i t~' :~' ~m: ~'~ I1~ I ~ "':~ I'¢i '~ I~"1, '1 11~4~IIIII1"~ I"~'!il' I~¢:1111"'ll'lli;"li" '~' ","111 "I'1"1:1"~'11 'l~llilll't'l'~iI~"l'l'lll";~"l"L;;';'''11''''1' 'll~u'~ll'l"l'l' ~1~11'~! ,.,.,',:. ,:.~i I ': ".1.,11,, ¥,,,~',.;',',,,;i,".'~,,.,:., PROGRAM: L~SCAN REVISION: 5.1 ' PART- N~.M'BER.: '~5790-PE32 Start of e'xecdtion: Mon 22 MA-Y 89 1:28'~. '**** REEL HEADER **** LIS 89/19105 ATLAS 01 eOmo_qou¥ UOlSS!mmo3 'suo3 s.9 ~ i!0 6 6! 9 Z 'LIS CUSTOMER FORMAT TAPE" **** TAPE HEADER **** LIS 89/19/05 3838 01 'THREE PASS CN/MS AT 9287-8805 FEET' FILE # 1 PASS 1.001 **** FILE HEADER ***.* 1024 CN : ARCO .ALASKA INC. WN : FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 12 CURVES : NAME CODE SAMPLE# UNIT 1 GR 68 1 2 TTEN 68 1 LB ..... . A ~ ,. ~ BYTES 4- , G,..1T~ qECORO 2EaTH SR CCL SSN CN CNr 92~5.000 O.O0000CO 1.30.0000 5'3.03'300 O.O000eO0 O.O0000CO 9235. OeO 1 ,'2-$ · 1 642 !.00000'",., 17,5, .4,086 SS. 4001 2 39. 4001 2 91R5.0C'3 51. 524,49 3.000000 171 .1957 35.-:qR951 5c;'. 8.Sq51 9135.000 749.3091 5.000000 177.0892 34.70126 3R.79126 ?085.000 55.80016 .5. 00000'3 1 6}. 6 21 o xc,'. 11433 ~3,11/~33 9035.000 256.489S 5.000~'''~ 194 681~ 3~.30X~1 37,30341 8985.000 352,S344 = 0~0~O0 19~ 7207 2~.36x5=,.., ..., 33.36653 ~q35,000 412,2300 5,OO0OO0 166,7959 44,33260 43,33260 5885,0,00 3/-,713210 7, 0008nn.~ ~ 228, 4~14.~ 1-z. o032/-+ 21,9C, 324 5835.000 41,.3513 5.000,003 13814381 66.87132, 70.8713-.'3 O) 904 5YTES * TTEN CqSN v ~' CNRA O.O000000 88~,464& 178.4086 0.552923~':-01 8~2. ¢x6'7 171 .1057 0.~472361E-01 882.3042 177,0892 O. ~602S05 E-01 852.4683 169.6219 O. 61 35383E-01 851 ,7332 1~4,6818 0.6792289~-01 857,4321 196.7207 0,7383913E-01 r, 43. 189c 165.7957 O. 57~4014E-©1 849.5151 228.4814 0.1017899 '51 0952 138.43~1 0.~691934E-01 TEN LSN -100,0000 00000"" ~0 ~.363830 46.59486 -5.0~561o 44.29832 -7.2~43~2 46.76787 -10.21140 41.67779 -9.928364 52 ~339 -3.709716 5~ 1~277 -6.742332 38 0~24 . J '~ -7,011347 93,02835 -0. ~058096 25,98170 SPD CLSN 0,0000000 O.O000OO0 25, -~6170 11,64871 26,03310 11.07458 26.co~0 1t .69197 10.40695 26.99730 13.22335 26.99730 ,.2,69 2~ 997z0 9.514063 26.99730 ~ 2571,~ ~6.99730 6.49542S TOTAL DATA RECORDS : STARTING TAPE DEPT~ : tILE TRAILEP **** S1 92R~ On ENDING TAPE DEPTH = 8~0= on P~,SS 2.C02 102,4 cORN!AT ONE OEP qECOqO (TYPE~' 6/*) TH PER FRAME TAPE~E~T~, ,, UNTT~ : FT CODE SAFi, DLE,~ UNIT ~8 1 ~P.T. 6S 1 LB 6 ~ I ~ / M M 63 1 V 0 L T 6©.~ 1 CTS 67 1 'TS 6~_, I -~=TS ~F 1 CTS 6-3 1 PeT 6c~ I ~CT ~& I C/C AYT=S_ ~ 4 4 4 4 4 4 DEPTH CCL CN o2~51000 100.0000 O.OOOOOOO 6 o~ooon 36.36612 91 85.00,3 7. O000C,? 32 570~'~ c~13f · :300 7 . 000 r'. ,~, ,., 3'2.01~23 7.0000J3 41.8aR40 c~0~:5. 000 7 000.~3© 29.4520,6 (TYPEJ O) GR SSN CNC 0.030000 5,3.0000 O.30000G 1 32. 236 1S2.101 40.3661 ~0.9866 171.625 3~.5703 774. 182./.23 36.0182 62.9977 170.~14 45 ~4 255.743 1'~2.164 S3.4520 994 ~YTES ~ TTEN C S S N '"' N ,., R,~ O.OOCO000 60.00000 0.0000 ~-,.., O ~68 7'~66 182.1017 O. 641 8520 E-0! ~8.0'~7~ 171.6254 0.6892228F--01 571.9280 1 ~,~. 4')'z7 O. 6'970412 E-01 841.6050 t73.91/.8 O. 58m41 43E-01 839.4651 192.16/-8 0.7369536=-01 T F. N LSN - I00. u',-,'O0 0.0000000 2.3:2_1051 /-6.75294 4.1;30331 50.8-.'5273 -5 An31 = 5 · 4.0.29590 -4.50485! 56.64:6:51 CLSN 0.0~'~ Od ~:~0~~ 24.99750 I t 6~2~ 24 997=~ 11.82S$1 12,715~$ 25.9:~7~1 10.07397 25,99741 14.16!65 2S. 3'~255 32.3 ~ ?_,. 55 O. 39 35. "300 407.66~: 5 1 . O00COO 1 67.2~61 34. S 248'P 38. 524~9 S$85.000 5.000000 23C.0800 17.30473 71.30473 88 35. 090 43:3. 304~. o.OaOCOr~~ ~ 1-'~._, .698~ 7t .16237 75.16~-3Z 819.354~ 167.2S61 0.6535100E-01 $16.6314 -~O.O~O0 0.1035~07 8,.98.7510 139.6082 -~.322233 44.30842 95.61~69 -3.896986 25.03320 t1.'~096n. ~, ~ Z 5.9'.o.. 1:.50 :3 31~ 2~ 997/..,1 6.3~5757 TOTAL D&T.A RECORDS : STARTING TAPE DEPTH = FTLF~ _ TRAIL~R~ **** 51 9285.00 ENDING TA~E DEPTH = 8805.00 FiLE PASS 3 **** FiLE HE&DER 1 924 ONE D=p RECORD (TYPE~ 64) TH P~R FRAME TAPE OEPTb UNIT : ~T CURVE S : N a, t,'i E C 0 O 1 G ,,.7. 68 ~ TTEN 68 3 TEN 4 ¢'°D ~'~ 5 ~'CL 6~ 6. SSN 68 7 CSSN 6£, ~ LSN 9 CLSN 60 ~ CN 11 CNC 2 ChRA E SAM~ 1 1 1 1 1 1 1 1 1 1 1 1 LE~ UNIT APl LB F/MM VOLT CTS C-~S C T .S CTS PCT k., , C/C BYTES 4 4 4 4 4 4 4 4 * D,~TA qECORD DEPTH CCL C N q?-~7.0'""3 100.0033 (T SS C N 0.0 YPE$ '3 000 O ,3 .uuuO0 O) 994 BYTES * TTEN ~'SSN C N P .a. 0.0003000 60.00000 TEN L S N -100.0000 O.O00000O SPD CLSN 0.00000~0 ~37.00u 112, ~,~9~ 4~. 0009 263 ~470 26.44272 50.4/-272 26~_~.o. ,7u 0.79~2459E-01 9137.0n0 945 &47¢ 8gl n50~ .. . ~' i-~ ~ 5.030000 173.672P 173.6719 x4.227~1 x~ 227~t 0 66~P3~9=-~ ?037 · 000 5 ¢ · 20379 832. 7004 1.0"~000'm',. '~' 18:~.3548 1~3.-* -354~ 59 °4~4 a~ c4554 0 505~14P=-0 0637. OOO 26~. 6101 864 · 2737 5.000000 195.3529 105. ~526 32 04~47 x.O. ~A:;47 '~ .~. ~-ul ...... o.696A490 ¢, 898'7, .000 34'~;.4954 8'~9.~ .4712, 5 · 300000 gO6. 0077 i06. 0377 pa 416~o S~ ~1~3:~ O 7~4~10Ac-01 3977.000 415,$933 ~ 1',~ 19~3 5.000CO.~ 43.o0057 44.c0050 31 7 9:~&~ I o!{. I 993 -5.7178'37 52.17560 0.3412952 46,55233 -/, cx7x41 44 ~156 -~5.ZA95~ v 60.50122 -7. '~t 3~ ]6 40 .I 9075 -11.357 39,a9995 -5.8:~955! i4.7t460 ~b. YY..'~ 1 ~0 91 t a i5.9974,1 13 r',314 C 15.99741 11.5~38~:u,~ 25.997al 11.!o739 25.90741 13,60924 2¢.99741 15.12530 25.99741 10.0475~ ?5.99741 Z5.99741 6.!75645 TOTAL, DATA RFCr'R'-'$_ ,., u: : STARTiN'S T.APF DEPTH = ~'rLC_~ TR&ILr-'q. 51 9'~:TM no TAPE uSPTH = 8807.00 **** TApc LIS 01 TRAIL=R **~* TOTAL PECCROS !N THIS LOGIC.~L T~OE : 166 **** REEL LIS 89119/05 aTLAS 0 1 Tm~,ILER **** TOTAL RECORDS If'd THiS LCGT. C~L ~E~L : '1 e;f TOTAL R--CORDS iN THIS PHYSZC~L R~EL: 107 --nc! of ex,cut±on: ,"4on 2Z t,',~¥ ~9 1:29!~ 21aps-~d sxec.+icn. +ime. = &~.~..~O s~cond~.~ SYST:!.I RETURN CODE * ALASKA COMPUTING CENTER . ****************************** . ............................ * ....... SCHLUMBERGER ....... . ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : DS 4-7 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292018900 REFERENCE NO : 98582 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/12 ORIGIN · FLIC REEL NAME : 98582 CONTINUATION # PREVIOUS REEL : CO~ff4ENT · ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-7, API# 50-029-20189-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/12 ORIGIN : FLIC TAPE NAME : 98582 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-7, API# 50-029-20189-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 4-7 API NUMBER: 500292018900 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 12-NOV-98 JOB NUMBER: 98582 LOGGING ENGINEER: V. LOMAX OPERATOR WITNESS: C. SHIIMWAY SURFACE LOCATION SECTION: 27 TOWNSHIP: liN RANGE: 15E FNL: FSL: 90 FEL: 593 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 51.00 DERRICK FLOOR: 50.00 GROUN~LEVEL: 15.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 000 7. 000 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA ~ ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: HALLIBURTON BASELINE DEPTH 88888.0 9229.0 9219.5 9212.5 9195.0 9194.5 9176.0 9138.0 9135.5 9115.5 9086.5 9068.0 9025.5 9002.0 8985.5 8957.0 8940 5 8932 5 8909 5 8890 5 8882 0 8865 0 8856 0 8850 5 100 0 $ REMARKS: .......... EQUIVALENT UNSHIFTED DEPTH ...... GRCH CNTG ............... 88888.5 88888.5 9229.5 9229.5 9219.0 9219.0 9213.0 9213.0 9195.0 9195.0 9176.5 9138.5 9135.5 9116.0 9088.0 9068.5 9027.0 8986 5 8957 5 8941 0 8932 5 8910 0 8890 5 8882 5 8866.0 8856.5 8851.5 101.0 9176.5 9135.5 9116.0 9088.0 9068.5 9027.0 9002.5 8986.5 8957.5 8941.0 8932.5 8910.0 8890.5 8882.5 8866.0 8856.5 8851.5 101.0 CONTAINED HEREIN IS THE CNTG DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 4-7 ON 19-AUG-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTG PASS #1 GRCH TO THE BASELINE GA2V~IA RAY PROVIDED BY THE CLIENT (GR.BCS); AND CNTG PASS #1 NPHI TO GR.BCS. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9255.0 8830.0 CNTG 9266.0 8830.0 $ 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 ANDDEPTH 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 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 4 TYPE REPR CODE VALUE 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB lV-UFZBSIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1197083 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9368.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG -999.250 NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG -999.250 FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG -999.250 CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG -999.250 GR.BCS 93.557 DEPT. 8332.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG -999.250 NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG -999.250 FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG -999.250 CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG -999.250 GR.BCS 102.951 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 98/11/12 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 SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9255.0 8832.0 CNTG 9266.0 8832.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888 0 9257 5 9243 5 9229 0 9221 5 9212 0 9208 5 9194 5 9183 5 91 79 0 9176 0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG 88888.5 88889.5 9229.5 9221.5 9209.0 9195.0 9176.5 9259.0 9244.0 9212.0 9183.5 9180.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 9175 0 9158 0 9153 0 9146 0 9141 5 9141 0 9134 0 9131 5 9128 5 9126 0 9118 5 9115 5 9104 0 9087 0 9085 5 9068 0 9067 0 9059 5 9045 0 9027 0 9017 0 9007 5 9002 5 8998 0 8985 5 8957.0 8954.5 8940.5 8925.0 8910.0 8909.5 8890.5 8890.0 8885.0 8865.5 8864.0 8850.5 8848.0 8847.0 8841.5 8838.0 8833.5 100.0 $ 9153.5 9141.5 9134.5 9116.0 9105.0 9088.5 9068.5 9028.5 9003.0 8986.5 8955.0 8925.5 8909.5 8890.5 8866.5 8851.5 8848.5 8839.5 8834.5 101.0 9175.5 9158.0 9146.0 9142.5 9130.5 9128.0 9126.0 9119.0 9104.5 9087.0 9068.0 9060.0 9046.5 9018.5 9009.0 9002.5 8999.0 8986.5 8957.5 8941.0 8910.5 8890.0 8885.5 8864.5 8847.5 8842.0 100.5 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. ALLOTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 7 ** 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 0.5 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 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1197083 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: DEPT. 9267. 500 NPHI . CNTG 32. 726 ENPH. CNTG NRA T . CNTG 3 . 176 CRA T . CNTG 3 . 198 ~ . CArTG FCNT. CNTG 582. 443 CNTC. CNTG 1755. 652 CFTC. CNTG CFEC. CNTG 548.249 GRCH. ClFTG -999.250 TENS. ClTTG DEPT. 8832.500 NPHI.CAPTG 46.980 ENPH. CNTG NRAT. CNTG 4.178 CRAT. CNTG 3.980 E19RA.CNTG FCNT. CNTG 370.114 CNTC. CNTG 1502.431 CFTC. CNTG CFEC. CNTG 449.712 GRCH. CNTG -999.250 TENS. ClFTG 34. 799 CPHI. CNTG 5.138 NCNT. CNTG 581. 624 CNEC. CNTG 2467. 000 CCL. CNTG 42.781 CPHI.CNTG 5.861 NCNT. CNTG 376.218 CNEC. CNTG 2420.000 CCL.CNTG 30.574 1856.798 2816.929 0.038 46.402 1624.135 2635.595 0.070 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE ·FLIC VERSION ·O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AUU?~BER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9255.0 8802.0 CNTG 9266.0 8802.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: BASELINE DEPTH 88888.0 9261.0 9239.5 9231.5 9229.0 9226.0 9219.0 9208.5 9202.0 9191 5 9183 5 9177 5 9158 0 9146 0 9142 0 9140 5 9136 5 9134 0 9118 5 9115 5 9103 5 9087 0 9085 5 9068 5 9067 0 9039 5 9025 5 9017 0 9004 5 9001 5 8985 5 8955 0 8946.5 8940.5 8929.5 8925.5 8886.0 8885.0 8882.0 8865.5 8850.5 8847.0 8845.5 8841.5 8833.0 100.0 $ REMARKS: .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. 88888.5 88888.0 9229.5 9226.0 9192.0 9141.0 9134.0 9116.0 9088.0 9068.5 9027.0 9003.0 8986.5 8941.0 8925.5 8886.0 8882.5 8866.5 8851.5 8845.5 8842.5 8834.0 101.0 9261.0 9240.0 9231.0 9218.5 9208.5 9202.0 9183.5 9178.0 9158.0 9146.0 9142.5 9136.5 9119.0 9104.5 9087.0 9068.0 9040.5 9018.5 9005.5 8986.5 8955.5 8947.0 8940.5 8930.0 8885.5 8847.0 100.0 THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT PASS #3 GRCH TO PASS #1 GRCH; AND PASS #3 NPHI TO PASS LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 10 #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 1 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 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1197083 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 11 ** DATA ** DEPT. 9266.000 NPHI.CNTG 30.698 ENPH. CNTG 33.764 CPHI.C1TTG NRAT. CNTG 3.235 CRAT. CNTG 3.087 ENRA. ClgTG 5.038 NCNT. ClTTG FCNT. CNTG 556.208 CNTC. CNTG 1776.383 CFTC. CNTG 558.790 CNEC. CNTG CFEC. CNTG 554.777 GRCH. CAUfG -999.250 TENS. CNTG 2486.000 CCL.CNTG DEPT. 8802.000 NPHI.CNTG 49.360 ENPH. CAFfG 45.957 CPHI.CNTG NRAT. CNTG 4.244 CRAT. CNTG 4.110 ENRA. CNTG 6.126 NCNT. CAUfG FCNT. CNTG 362.030 CNTC. CNTG 1496.507 CFTC. Cl~fG 379.131 CNEC. CAFTG CFEC. CNTG 437.023 GRCH. CNTG -999.250 TENS. CNTG 2364.000 CCL.CAFTG 33.066 1775.024 2794.969 0.037 45.612 1526.751 2677.222 0.008 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE · 98/11/12 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 CNTG 1, 2, 3, $ REMARKS: THE ARITH~4ETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 12 LIS FORMAT DATA ** 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 ELE~ CODE (HEX) DEPT FT 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC dWAV CPS 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1197083 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 13 DEPT. 9266.500 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.~AV -999.250 CFEC. CNAV -999.250 GRCH. CNTG -999.250 DEPT. 8831.000 NPHI.CNAV -999.250 NN~T. 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 ClTTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV -999.250 CFEC. CNAV -999.250 GRCH. CNTG 154.564 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE ·FLIC VERSION ·O01CO1 DATE · 98/11/12 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 SU~ff4ARY VENDOR TOOL CODE START DEPTH CNTG 9278.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: STOP DEPTH 8828.5 19-AUG-98 8Cl -205 2111 19-AUG-98 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 14 TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 9284.0 9272.0 9000.0 9266.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA14MA RAY CNTG COMP. NEUTRON $ TOOL ArUM~ER ........... SGT-L BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8. 000 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) : PRODUCED FLUIDS 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 WIN-DOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 15000 TOOL STANDOFF (IN): REMARKS: JOB RUN OFF THIRD PARTY CRANE. DEPTH CORRELATED WITH HES BHC LOG DATED 2-16-92. PUMPED 300 BBL DIESEL TO TAKE PRESSURE OFF WELL PRIOR TO RUNNING IN HOLE. THEREAFTER, PUMPED 1 BPM TO MAINTAIN PRESSURE. RAN LOGS ON SANDSTONE MATRIX @ 1800 FT/HR. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #1. LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 15 $ 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 NUM~ SAMP ELEM CODE (HEX) DEPT FT 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PSI 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA PS1 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PS1 CPS 1197083 O0 000 O0 0 $ 1 1 4 68 0000000000 CNEC PS1 CPS 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 RCEN PS1 CPS 1197083 O0 000 O0 0 $ 1 1 4 68 0000000000 RCNT PS1 CPS 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1197083 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 16 ** DATA ** DEPT. 9278.500 NPHI.PS1 41.214 ENPH. PS1 29.432 TNPH. PS1 TNRA.PS1 3.663 RTNR.PS1 3.750 ENRA.PS1 4.602 CFEC. PS1 CNEC. PS1 2733.570 RCEF. PS1 601.612 RCEN. PS1 2583.916 RCNT. PS1 RCFT. PS1 480.550 CNTC. PSl 1792.110 CFTC. PSi 499.549 NPOR.PS1 GR.PS1 5.373 TENS.PSI 1975.000 CCL.PS1 0.017 DEPT. 8828.000 NPHI.PS1 45.035 ENPH.PS1 38.466 TNPH.PS1 TNRA.PS1 3.873 RTNR.PS1 3.589 ENRA.PS1 5.480 CFEC.PS1 CNEC. PS1 2783.860 RCEF. PS1 552.649 RCEN. PS1 2813.103 RCNT.PS1 RCFT. PS1 439.524 CNTC. PS1 1663.283 CFTC.PSi 446.033 NPOR.PSl GR.PS1 163.066 TENS.PSi 2345.000 CCL.PS1 -999.250 39. 610 593. 966 1829. 715 39. 610 41.946 507.968 1850.249 38.006 * * END OF DA TA * * **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION . O01CO1 DATE · 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION · O01CO1 DATE · 98/11/12 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: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG 9278.0 8830.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 17 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG IATrERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 19-AUG-98 8Cl -205 2111 19-AUG-98 9284.0 9272.0 9000.0 9266.0 1800.0 NO GR GAiVff4A RAY CNTG COMP.NEUTRON $ TOOL SG T- L BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.000 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) : PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERiCzAL SAiV-DSTON-E 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): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 15000 TOOL STANDOFF (IN): REMARKS: JOB RUN OFF THIRD PARTY CRANE. LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 18 DEPTH CORRELATED WITH HES BHC LOG DATED 2-16-92. PUMPED 300 BBL DIESEL TO TAKE PRESSURE OFF WELL PRIOR TO RUNNING IN HOLE. THEREAFTER, PUMPED 1 BPM TO MAINTAIN PRESSURE. RAN LOGS ON SANDSTONE MATRIX @ 1800 FT/HR. 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 $ 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 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS2 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 RCEN PS2 CPS 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 19 NAME SERV UNIT SERVICE API API API API FILE NUMB NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CNTC PS2 CPS 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1197083 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9278.000 NPHI.PS2 50.118 ENPH. PS2 38.465 TNPH. PS2 47.852 TNRA.PS2 4.152 RTNR.PS2 4.250 ENRA.PS2 5.480 CFEC. PS2 478.031 CNEC. PS2 2619.743 RCEF. PS2 484.185 RCEN. PS2 2476.320 RCNT. PS2 2095.687 RCFT. PS2 484.185 CNTC. PS2 2052.616 CFTC.PS2 503.328 NPOR.PS2 47.852 GR.PS2 16.241 TENS.PS2 1795.000 CCL.PS2 0.088 DEPT. 8830.000 NPHI.PS2 47.022 ENPH. PS2 46.538 TNPH. PS2 45.666 TNRA.PS2 3.982 RTNR.PS2 3.833 ENRA.PS2 6.173 CFEC.PS2 432.080 CNEC. PS2 2667.392 RCEF. PS2 427.173 RCEN. PS2 2486.898 RCNT. PS2 1527.584 RCFT. PS2 345.869 CNTC. PS2 1519.632 CFTC. PS2 384.684 NPOR.PS2 46.458 GR.PS2 161.630 TENS.PS2 2363.000 CCL.PS2 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION . O01CO1 DATE · 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 20 FILE NO?4BER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~94ARY VENDOR TOOL CODE START DEPTH CNTG 9279.0 $ LOG HEADER DATA STOP DEPTH 8801.0 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) 19-AUG-98 8Cl -205 2111 19-AUG-98 9284.0 9272.0 9000.0 9266.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GANfl~A 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) : 8. 000 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) : PRODUCED FLUIDS 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): LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 21 BASE NORMALIZING WIArDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 15000 TOOL STANDOFF (IN): REMARKS: JOB RUN OFF THIRD PARTY CRANE. DEPTH CORRELATED WITH HES BHC LOG DATED 2-16-92. PUMPED 300 BBL DIESEL TO TAKE PRESSURE OFF WELL PRIOR TO RUNNING IN HOLE. THEREAFTER, PUMPED 1 BPM TO MAINTAIN PRESSURE. RAN LOGS ON SANDSTONE MATRIX @ 1800 FT/HR. 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 NUM~ SAMP ELEM CODE (HEX) DEPT FT 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS3 PU 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 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) TNPH PS3 PU 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA PS3 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS3 CPS 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 RCEN PS3 CPS 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1197083 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9279.000 NPHI.PS3 63.475 ENPH. PS3 48.495 TNPH.PS3 71.256 TNRA.PS3 4.885 RTNR.PS3 5.000 ENRA.PS3 6.330 CFEC. PS3 478.031 CNEC. PS3 3025.967 RCEF. PS3 484.185 RCEN. PS3 2860.305 RCNT. PS3 1843.771 RCFT. PS3 362.577 CNTC. PS3 1805.878 CFTC. PS3 376.912 NPOR.PS3 71.256 GR.PS3 5.414 TENS.PS3 1890.000 CCL. PS3 0.064 DEPT. 8800.500 NPHI.PS3 47.121 ENPH. PS3 45.402 TNPH. PS3 45.519 TNRA.PS3 3.987 RTNR.PS3 4.109 ElmirA.PS3 6.081 CFEC. PS3 441.725 CNEC. PS3 2685.932 RCEF. PS3 448.917 RCEN. PS3 2581.569 RCNT. PS3 1546.186 RCFT. PS3 354.127 CNTC. PS3 1494.418 CFTC. PS3 379.127 NPOR.PS3 44.852 GR.PS3 146.235 TENS.PS3 2342.000 CCL.PS3 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE · 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 14:59 PAGE: 23 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/11/12 ORIGIN · FLIC TAPE NAME : 98582 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-7, API# 50-029-20189-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 98/11/12 ORIGIN : FLIC REEL NAME : 98582 CONTINUATION # '. PREVIOUS REEL : COM~4ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-7, API# 50-029-20189-00 ALASKA COMPUTING CENTER , ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 4-7 ST1 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA AP1 NUMBER : 50-029-20189-00 REFERENCE NO : 95292 O ALASKA INC D.S 4- 7ST PRUDHOE BAY Run 1' 8 - May - 1992 PDK-100 ,Borax Loc 33 t334 RECEIVED NOV 2 ~) 1992. Alaska 0il & Gas Cons. Commissio Anchorage Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD D.S. 4 - 7ST 500292018900 ARCO ALASKA INC. ATLAS WIRELINE SERVICES 01-OCT-92 5515.03 K. BRUNNER K. MORRIS 27 liN 15E 90 593 51.00 50.00 15.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 9373.0 PRODUCTION STRING 7.000 9464.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS N/A GR N/A UNKNOWN PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: EQUIVALENT UNSHIFTED DEPTH 47.00 29.00 BASELINE DEPTH 9114.0 9139.5 9176.5 9198.0 9207.5 9213.0 9226.5 9229.5 9270.5 9279.0 9288.5 9298.5 9318.0 GRCH 9114.0 9138.5 9176.0 9197.5 9206.5 9212.5 9225.5 9228.5 9270.0 9278.0 9287.5 9297.0 9316.0 RECEIVED NOV 2 ,'5 199~. Alaska 0tl & ~s Co~s. Corr~mi~sior~ Anchorage 9347.0 $ REMARKS: 9347.0 PDK-100 (BORAX LOG) LOG TIED INTO JEWELRY LOG RUN 3/1/92. MADE BASE PASS WITH SEAWATER IN WELLBORE. FIRST BORAX PASS MADE WITH 20 BBL BORAX AWAY. SECOND PASS MADE WITH 48 BBL BORAX AWAY. THIRD PASS MADE WITH 63 BBL BORAX AWAY. OPEN HOLE GAMMA RAY FOR DEPTH MATCHING SUPPLIED BY ARCO ALASKA INC (SEPT 25, 1992) SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS SIGMA(PDK) DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT SIGMA(PDK) PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS SIGMA(PDK). $ FILE HEADER FILE NUMBER: 1 EDITED CURVES PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 9133.0 PDK 9146.0 $ STOP DEPTH 9322.0 9334.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH SGMA 9114.0 9114.0 9177.0 9176.5 9198.0 9197.5 9202.5 9202.0 9207.5 9206.5 9212.5 9212.0 9222.5 9221.5 9229.0 9228.5 9252.0 9251.5 9270.5 9270.0 9298.0 9296.5 9318.0 9316.0 9347.0 9347.0 $ EQUIVALENT UNSHIFTED DEPTH BASE PASS. ALL PDK CURVES SHIFTED WITH SGMA. GRCH DEPTH MATCHED TO OPEN HOLE GR. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 4 - 7ST : PRUDHOE BAY : NORTH SLOPE : ALASKA REMARKS: * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units GRCH PDK 68 1 GAPI BIF PDK 68 1 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 00 201 24 1 4 00 201 24 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 8 PHI PDK 68 1 PU 9 RATO PDK 68 1 10 RBOR PDK 68 1 11 RICS PDK 68 1 12 RIN PDK 68 1 13 SGMA PDK 68 1 CU 14 SGMB PDK 68 1 CU 15 SS PDK 68 1 CPS * DATA RECORD (TYPE# 0) Total Data Records: 32 966 BYTES * 60 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 Tape File Start Depth = 9347.000000 Tape File End Depth = 9114.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7473 datums Tape Subfile: 2 153 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 9185.0 PDK 9198.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 9168.0 9168.0 9192.5 9192.0 9198.5 9198.0 9207.5 9206.5 9215.0 9214.5 9218.0 9224.5 9223.5 9229.0 9229.5 9228.5 9240.0 9260.5 9270.5 9270.0 9279.0 9278.5 9288.5 9287.0 9297.5 9306.0 9304.0 9317.0 9317.5 9315.5 9327.5 9344.0 9344.0 $ REMARKS: for each pass in separate files. STOP DEPTH 9322.0 9334.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 9168.0 9198.0 9206.5 9217.5 9228.5 9239.5 9260.0 9270.0 9296.5 9315.5 9326.0 9344.0 20 BBL BORAX AWAY PASS. ALL PDK CURVES SHIFTED WITH SGMA. $ CN : ARCO ALASKA INC. WN : D.S. 4 - 7ST FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID' F 15 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 MSD PDK 68 1 4 8 PHI PDK 68 1 PU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICS PDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 15 SS PDK 68 1 CPS 4 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 60 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 24 Tape File Start Depth = 9344.000000 Tape File End Depth = 9168.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5649 datums Tape Subfile: 3 74 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 4 is type: LIS 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 SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9182.0 9322.0 9195.0 9334.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 9170.0 9170.0 9192.5 9192.0 9195 . 5 9195 . 0 9202.0 9202.0 9209.0 9208.0 9209.5 9209.0 9212.5 9212.0 9213.0 9212.5 9215.5 9215.0 9217.5 9217.0 9220.5 9219.0 9226.0 9225.0 9229.0 9228.5 9229.5 9229.0 9240.0 9239.5 9252.5 9252.0 9261.0 9260.5 9270.5 9270.0 9271.0 9270.5 9279.0 9278.5 9295.0 9294.0 9297.0 9296.0 9301.5 9300.0 9316.5 9316.0 9315.5 9326.5 9325.0 9346.0 9346.0 9346.0 $ REMARKS: 48 BBL BORAX AWAY PASS. ALL PDK CURVES SHIFTED WITH SGMA. $ CN : ARCO ALASKA INC. WN : D.S. 4 - 7ST FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA EQUIVALENT UNSHIFTED DEPTH SGMA 9170.0 * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 2 BIF PDK 68 3 BKL PDK 68 4 BKS PDK 68 5 CSL PDK 68 6 LS PDK 68 7 MSD PDK 68 8 PHI PDK 68 9 RATO PDK 68 10 RBOR PDK 68 11 RICS PDK 68 12 RIN PDK 68 13 SGMA PDK 68 14 SGMB PDK 68 15 SS PDK 68 1 GAPI 4 1 4 1 CPS 4 1 CPS 4 1 4 1 CPS 4 1 4 1 PU 4 1 4 1 4 1 4 1 4 1 CU 4 1 CU 4 1 CPS 4 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 60 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 24 Tape File Start Depth = 9346.000000 Tape File End Depth = 9170.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13122 datums Tape Subfile: 4 80 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 5 is type: LIS 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 SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9183.0 9322.0 9196.0 9334.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 9169.0 9169.0 9193.0 9191.5 9199.0 9198.0 9203.5 9202.0 9208.0 9206.5 9207.0 9216.5 9215.0 9218.5 9217.5 9223.5 9221.5 9229.5 9228.5 9230.5 9229.0 9239.5 9239.0 9261.5 9260.5 9270.5 9269.5 9271.0 9270.0 9279.0 9278.5 9298.0 9296.5 9306.5 9304.5 9317.0 9315.5 9317.5 9315.5 9345.0 9345.0 9345.0 $ REMARKS: 63 BBL BORAX AWAY PASS. ALL PDK CURVES SHIFTED WITH SGMA. $ CN : ARCO ALASKA INC. WN : D.S. 4 - 7ST FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA EQUIVALENT UNSHIFTED DEPTH SGMA 9169.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 MSD PDK 68 1 4 8 PHI PDK 68 1 PU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICS PDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 15 SS PDK 68 1 CPS 4 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 60 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 24 Tape File Start Depth = 9345.000000 Tape File End Depth = 9169.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11298 datums Tape Subfile: 5 74 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 6 is type: LIS 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: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9131.0 PDK 9143.0 $ LOG HEADER DATA STOP DEPTH 9330.5 9342.0 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): 08-MAY-92 FSYS256 REV:G002 VER:2.0 1620 08-MAY-92 9440.0 9349.0 9150.0 9334.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY PDK PDK-100 $ TOOL NUMBER 2725XB 2725XB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9464.0 0.0 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) : SEAWATER/BORAX 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 800 FAR COUNT RATE HIGH SCALE (CPS): 2800 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: BASE PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 4 - 7ST : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool Code Samples Units 1 GR PDK 68 2 BIF PDK 68 3 BKL PDK 68 4 BKS PDK 68 5 CCL PDK 68 6 CSLS PDK 68 7 CSS PDK 68 8 G1 PDK 68 9 G2 PDK 68 10 GElS PDK 68 11 ISS PDK 68 12 LS PDK 68 13 MON PDK 68 14 MSD PDK 68 15 PHI PDK 68 16 RATO PDK 68 17 RBOR PDK 68 18 RICS PDK 68 19 RIN PDK 68 20 SGMA PDK 68 21 SGMB PDK 68 22 SPD PDK 68 23 SS PDK 68 1 GAPI 1 1 CPS 1 CPS 1 1 CU 1 CPS 1 CPS 1 CPS 1 CPS 1 CPS 1 CPS 1 CPS 1 1 PU 1 1 1 1 1 CU 1 CU 1 F/MN 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 06 511 09 0 4 4 00 201 24 1 4 4 39 705 61 6 4 4 74 169 61 6 4 4 92 630 79 6 4 4 00 201 24 1 4 4 00 201 24 1 4 4 35 975 96 1 4 4 36 631 32 1 4 4 74 169 61 6 4 4 00 201 24 1 4 4 71 162 89 6 4 4 32 125 68 0 4 4 00 201 24 1 4 4 00 201 24 1 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 96 761 61 6 4 4 00 201 24 1 4 4 52 386 28 5 4 4 05 626 89 6 92 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 94 Tape File Start Depth = 9347.000000 Tape File End Depth = 9114.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35515 datums Tape Subfile: 6 168 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 7 is type: LIS 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: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9184.0 PDK 9196.0 $ LOG HEADER DATA STOP DEPTH 9328.0 9340.0 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): 08 -MAY- 92 FSYS256 REV:G002 VER:2.0 1701 08-MAY-92 9440.0 9349.0 9150.0 9334.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY PDK PDK-100 $ TOOL NUMBER 2725XB 2725XB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9464.0 0.0 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) : SEAWATER/BORAX 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 800 FAR COUNT RATE HIGH SCALE (CPS): 2800 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: 20 BBL BORAX AWAY PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 4 - 7ST : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 4 15 PHI PDK 68 1 PU 4 16 RATO PDK 68 1 4 17 RBOR PDK 68 1 4 18 RICS PDK 68 1 4 19 RIN PDK 68 1 4 20 SGMA PDK 68 1 CU 4 21 SGMB PDK 68 1 CU 4 22 SPD PDK 68 1 F/MN 4 23 SS PDK 68 1 CPS 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 92 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 71 Tape File Start Depth = 9344.000000 Tape File End Depth = 9168.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 28219 datums Tape Subfile: 7 145 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9181.5 PDK 9193.0 $ LOG HEADER DATA STOP DEPTH 9330.5 9342.0 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): 08-MAY-92 FSYS256 REV:G002 VER:2.0 1724 08-MAY-92 9440.0 9349.0 9150.0 9334.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY PDK PDK-100 $ TOOL NUMBER 2725XB 2725XB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9464.0 0.0 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): SEAWATER/BORAX 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERML): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 800 FAR COUNT RATE HIGH SCALE (CPS): 2800 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: 48 BBL BORAX AWAY PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 4 - 7ST : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 2 BIF PDK 68 3 BKL PDK 68 4 BKS PDK 68 5 CCL PDK 68 6 CSLS PDK 68 7 CSS PDK 68 8 G1 PDK 68 9 G2 PDK 68 10 GElS PDK 68 11 ISS PDK 68 12 LS PDK 68 13 MON PDK 68 14 MSD PDK 68 15 PHI PDK 68 16 RATO PDK 68 17 RBOR PDK 68 18 RICS PDK 68 19 RIN PDK 68 20 SGMA PDK 68 21 SGMB PDK 68 22 SPD PDK 68 23 SS PDK 68 1 GAPI 4 1 4 1 CPS 4 1 CPS 4 1 4 1 CU 4 1 CPS 4 1 CPS 4 1 CPS 4 1 CPS 4 1 CPS 4 1 CPS 4 1 CPS 4 1 4 1 PU 4 1 4 1 4 1 4 1 4 1 CU 4 1 CU 4 1 F/MN 4 1 CPS 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 92 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 71 Tape File Start Depth = 9346.000000 Tape File End Depth = 9170.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 52436 datums Tape Subfile: 8 Minimum record length: Maximum record length: 145 records... 62 bytes 966 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9182.5 PDK 9194.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: Tm 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 PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S 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 9328.5 9340.0 08-MAY-92 FSYS256 REV:G002 VER:2.0 1736 08-MAY-92 9440.0 9349.0 9150.0 9334.0 1500.0 YES TOOL NUMBER 2725XB 2725XB 0.000 9464.0 0.0 SEAWATER/BORAX 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 800 FAR COUNT RATE HIGH SCALE (CPS): 2800 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: 63 BBL BORAX AWAY PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 4 - 7ST : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 4 15 PHI PDK 68 1 PU 4 16 RATO PDK 68 1 4 17 RBOR PDK 68 1 4 18 RICS PDK 68 1 4 19 RIN PDK 68 1 4 20 SGMA PDK 68 1 CU 4 21 SGMB PDK 68 1 CU 4 22 SPD PDK 68 1 F/MN 4 23 SS PDK 68 1 CPS 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 92 * DATA RECORD (TYPE~ 0) 966 BYTES * Total Data Records: 71 Tape File Start Depth = 9345.000000 Tape File End Depth = 9169.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 45140 datums Tape Subfile: 9 145 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 10 is type: LIS 92/ 9/29 01 **** REEL TRAILER **** 92/10/ 6 01 Tape Subfile: 10 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 6 OCT 92 3:01p Elapsed execution time = 29.66 seconds. SYSTEM RETURN CODE = 0 PROGRAM: L TSCAN REVISION: 5.1 P;iRT NUMBER: W5790-P:32 Start of execution: Mon **** REEL H-=~DER LIS 89119105 ATLAS 01 'LIS CUSTOMER FORMAT 22 MAY 8,9 1:28p e6e.lo_l, iOu¥ 'JO!SS!LULUO0 'Suo3 see x2 l!O ~sqV TAPE' **** TAPE LIS 59/19105 HEADER **** 3838 01 'THREE mASS CN/HS AT 9287-8805 FEET' FiLE ~ 1 **** mILE HEADER PASS 1.001 102& CN : ARCO ALASKA WN : :.0,5.4-7 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA i NC. FORMAT RECORD (TYPE# ~4) ONE DEPTH PER FRAME TAPE DEPTm UNIT : FT 12 CUmVES : N A M ~- C 0 O E . _ ~ TTEN 6.2. SAMPLE~ 1 UNiT &PI SYTES * HHHH HHHH * * HHHH HHHH H H A LL LL II BBBB U U RRRR TTTTT O N N * * HHHH HHHH H H ~ LL LL II B B U U R R T O O ~ N * * HHHHHHHHHHH HHHH A A LL LL II BBBB U U RRRR T O O N N N * * HHHHHHHHHHH H H ~ LL LL II B B U U R R T O O N ~ * * HHHH HHHH H H A ALL LL II BBBB U R R T O N N * * HHHH HHHH * *HHHH HHHH L O G G I N G S E R V I C E S , I N C . * * * * * -- . * * * * * * * * * . LIS TAPE VERIFICATION LISTING * * * . COMPANY: ARCO ALASKA INC. * . WELL: DS 4-7 - CORRECTED * . API #: 50-029-20189-00 * . DATE: 03-DEC-91 * . FIELD: PRUDHOE BAY * . BOROUGH: NORTH SLOPE * . STATE: ALASKA * * * . LOGS: PSGT * RECEIVED. OCT 1 5 1992 Alaska 011 & Gas Cons, Commission Anchorage Page 1 REEL HEADER RECORD TYPE 132 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER PREVIOUS REEL NAME COMMENTS: --- COMCEN --- 92/09/08 --- ANCH --- 739574 TAPE HEADER RECORD TYPE 130 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER PREVIOUS TAPE NAME COMMENTS: --- COMCEN --- 92/09/08 --- ANCH COMMENT RECORD TYPE 232 TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 04-07 500292018900 ARCO ALASKA INC. HALLIBURTON LOGGING SERVICES 08-SEP-92 L73957-4 BEALS MOSTELLER 27 liN 15E 90 593 51.00 15.00 RECEIVED OCT 1,5 199~ Oil & G~ Cons. Oommi~slon Anchorm:je CASING DRILLER'S CASING Page 2 BIT SIZE(IN) SIZE(IN) DEPTH(FT) WEIGHT (LB/FT) lST STRING 13.275 2701.0 72.00 2ND STRING 12.250 9.625 9373.0 47.00 3RD STRING 12.250 5.500 8737.0 17.00 PRODUCTION STRING 12.250 5.500 8737.0 17.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: FDC PBU CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH PSGT 8856.0 8859.0 8897.5 8900.5 8964.5 8967.5 9048.0 9051.0 9134.0 9137.0 9203.5 9206.5 9271.0 9274.0 $ REMARKS: TIED INTO SCHLUMBERGER GR/CCL DATED 02-FEB-76. FILE ORGANIZATION: FILE 1: EDITED PASS 1 DATA ( .50 FT DEPTH INCREMENT ) FILE 2: EDITED PASS 2 DATA ( .50 FT DEPTH INCREMENT ) FILE 3: EDITED PASS 3 DATA ( .50 FT DEPTH INCREMENT ) FILE 4: EDITED PASS 4 DATA ( .50 FT DEPTH INCREMENT ) FILE 5: EDITED PASS 5 DATA ( .50 FT DEPTH INCREMENT ) FILE 6: AVERAGED PASS 1-5 ( .50 FT DEPTH INCREMENT ) FILE 7: RAW DATA OF PASS 1 ( .25 FT DEPTH INCREMENT ) FILE 8: RAW DATA OF PASS 2 ( .25 FT DEPTH INCREMENT ) FILE 9: RAW DATA OF PASS 3 ( .25 FT DEPTH INCREMENT ) FILE 10: RAW DATA OF PASS 4 ( .25 FT DEPTH INCREMENT ) FILE 11: RAW DATA OF PASS 5 ( .25 FT DEPTH INCREMENT ) FILE 12: COMPUTED DATA FILE ( .25 FT DEPTH INCREMENT ) $ FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.001 --~-- 0 ~-- 5 --- 92/09/08 --- 1024 --- LO COMMENT RECORD TYPE 232 Page 3 FILE HEADER FILE NUMBER: 01 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 01 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 9272.0 8856.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH- BASELINE DEPTH PSGT $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #1. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 84 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GRCH PSGT 739574 GAPI LIRI PSGT 739574 COIR PSGT 739574 STUN PSGT 739574 API CODE FILE# SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 #SAMP REPR. 1 68 1 68 1 68 1 68 1 68 Page 4 ITCR PSGT 739574 00000000 0 4 1 68 HPLI PSGT 739574 00000000 0 4 1 68 TCCR PSGT 739574 00000000 0 4 1 68 BKG1 PSGT 739574 00000000 0 4 1 68 BKG2 PSGT 739574 00000000 0 4 1 68 RIC PSGT 739574 00000000 0 4 1 68 KIC PSGT 739574 00000000 0 4 1 68 HIC PSGT 739574 00000000 0 4 1 68 SIIC PSGT 739574 00000000 0 4 1 68 CLIC PSGT 739574 00000000 0 4 1 68 CAIC PSGT 739574 00000000 0 4 1 68 FEIC PSGT 739574 00000000 0 4 1 68 SIC PSGT 739574 00000000 0 4 1 68 FERC PSGT 739574 00000000 0 4 1 68 TENS PSGT 739574 LB 00000000 0 4 1 68 TEMP PSGT 739574 DEG 00000000 .0 4 1 68 DATA RECORD TYPE 0 DEPT = 9272.000 GRCH = 648.764 LIRI = 1.478 COIR = .747 STUN = .009 ITCR = 5690.824 HPLI = 1.331 TCCR = 8171.431 BKG1 = 8.549 BKG2 = 24.262 RIC = .696 KIC = .390 HIC = .119 SIIC = .052 CLIC = .013 CAIC = .003 FEIC = .083 SIC = .079 FERC = 2.451 TENS = 2975.422 TEMP = 22.700 DEPT = 9072.000 GRCH = 64.027 LIRI = 1.399 COIR = .595 STUN = .006 ITCR = 9497.367 HPLI = 1.229 TCCR = 11933.180 BKG1 = 6.149 BKG2 = 5.165 RIC = .796 KIC = .384 HIC = .082 SIIC = .058 CLIC = .008 CAIC = .003 FEIC = .095 SIC = .094 FERC = 2.392 TENS = 2946.812 TEMP = 23.800 DEPT = 8872.000 GRCH = 441.093 LIRI = 1.434 COIR = .636 STUN = .007 ITCR = 9895.271 HPLI = 1.291 TCCR = 10048.390 BKG1 = 7.103 BKG2 = 13.157 RIC = .985 KIC = .382 HIC = .087 SIIC = .043 CLIC = .008 CAIC = .001 FEIC = .102 SIC = .088 FERC = 2.397 TENS = 2889.593 TEMP = 24.900 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.001 --- 92/09/08 --- 1024 --- LO --- COMCEN.002 RECEIVED 0CT ] $ ]992 Alaska Oil & Sas Cons. Commission Anchorage Page 5 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.002 ~m 0 ~ 5 --- 92/09/08 --- 1024 --- LO --- COMCEN.001 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 02 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 02 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 9272.0 8862.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH PSGT $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #2. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 84 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN Page 6 RECEIVED OCT 1 5 1992 Alaska Oil & Sas C~s. Commission Anchorage 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS API CODE FILES SIZE ~SAMP REPR. DEPT F 00000000 0 4 i 68 GRCH PSGT 739574 GAPI 00000000 0 4 1 68 LIRI PSGT 739574 00000000 0 4 1 68 COIR PSGT 739574 00000000 0 4 1 68 STUN PSGT 739574 00000000 0 4 1 68 ITCR PSGT 739574 00000000 0 4 1 68 HPLI PSGT 739574 00000000 0 4 1 68 TCCR PSGT 739574 00000000 0 4 1 68 BKG1 PSGT 739574 00000000 0 4 1 68 BKG2 PSGT 739574 00000000 0 4 1 68 RIC PSGT 739574 00000000 0 4 1 68 KIC PSGT 739574 00000000 0 4 1 68 HIC PSGT 739574 00000000 0 4 1 68 SIIC PSGT 739574 00000000 0 4 1 68 CLIC PSGT 739574 00000000 0 4 1 68 CAIC PSGT 739574 00000000 0 4 1 68 FEIC PSGT 739574 00000000 0 4 1 68 SIC PSGT 739574 00000000 0 4 1 68 FERC PSGT 739574 00000000 0 4 1 68 TENS PSGT 739574 LB 00000000 0 4 1 68 TEMP PSGT 739574 DEG 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9272.000 GRCH = 677.493 LIRI = 1.485 COIR = .735 STUN = .011 ITCR = 5216.755 HPLI = 1.316 TCCR = 7442.603 BKG1 = 6.122 BKG2 = 26.610 RIC = .701 KIC = .391 HIC = .115 SIIC = .052 CLIC = .012 CAIC = .002 FEIC = .084 SIC = .080 FERC = 2.520 TENS = 2875.288 TEMP = 25.400 DEPT = 9072.000 GRCH = 84.322 LIRI = 1.405 COIR = .621 STUN = .007 ITCR = 10044.470 HPLI = 1.273 TCCR = 11891.100 BKG1 = 6.765 BKG2 = 6.216 RIC = .845 KIC = .384 HIC = .084 SIIC = .056 CLIC = .010 CAIC = .001 FEIC = .095 SIC = .092 FERC = 2.443 TENS = 2946.812 TEMP = 26.800 DEPT = 8872.000 GRCH = 447.448 LIRI = 1.428 COIR = .628 STUN = .006 ITCR = 9510.494 HPLI = 1.273 TCCR = 9843.645 BKG1 = 7.922 BKG2 = 13.270 RIC = .966 KIC = .382 Page 7 HIC = .085 SIIC = .043 CLIC = .006 CAIC = .003 FEIC = .101 SIC = .090 FERC = 2.455 TENS = 2846.678 TEMP = 28.700 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.002 5 --- 92/09/08 --- 1024 --- LO --- COMCEN.003 FILE HEADER RECORD - TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME COMCEN.003 --- 92/09/08 --- 1024 --- LO --- COMCEN.002 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 03 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 03 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 9272.0 8862.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH-- BASELINE DEPTH PSGT $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #3. $ Page 8 LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 84 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65' .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GRCH PSGT 739574 GAPI 00000000 0 4 1 68 LIRI PSGT 739574 00000000 0 4 1 68 COIR PSGT 739574 00000000 0 4 1 68 STUN PSGT 739574 00000000 0 4 1 68 ITCR PSGT 739574 00000000 0 4 1 68 HPLI PSGT 739574 00000000 0 4 1 68 TCCR PSGT 739574 00000000 0 4 1 68 BKG1 PSGT 739574 00000000 0 4 1 68 BKG2 PSGT 739574 00000000 0 4 1 68 RIC PSGT 739574 00000000 0 4 1 68 KIC PSGT 739574 00000000 0 4 1 68 HIC PSGT 739574 00000000 0 4 1 68 SIIC PSGT 739574 00000000 0 4 1 68 CLIC PSGT 739574 00000000 0 4 1 68 CAIC PSGT 739574 00000000 0 4 1 68 FEIC PSGT 739574 00000000 0 4 1 68 SIC PSGT 739574 00000000 0 4 1 68 FERC PSGT 739574 00000000 0 4 1 68 TENS PSGT 739574 LB 00000000 0 4 1 68 TEMP PSGT 739574 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9272.000 GRCH = 652.420 LIRI = 1.475 COIR = .743 STUN = .012 ITCR = 5286.123 HPLI = 1.253 TCCR = 7582.527 BKG1 = 5.822 BKG2 = 25.642 RIC = .697 KIC = .389 HIC = .116 SIIC = .056 CLIC = .012 CAIC = .002 FEIC = .083 SIC = .083 FERC = 2.409 TENS = 2932.507 TEMP = 29.200 Page 9 DEPT = 9072.000 GRCH = 98.254 LIRI = 1.404 COIR = .605 STUN = .007 ITCR = 8838.893 HPLI = 1.283 TCCR = 11368.800 BKG1 = 6.890 BKG2 = 6.155 RIC = .777 KIC = .386 HIC = .083 $IIC = .058 CLIC = .010 CAIC = .002 FEIC = .094 SIC = .092 FERC = 2.417 TENS = 2932.507 TEMP = 30.600 DEPT = 8872.000 GRCH = 473.681 LIRI = 1.441 COIR = .649 STUN = .007 ITCR = 9124.859 HPLI = 1.295 TCCR = 9564.271 BKG1 = 6.090 BKG2 = 13.803 RIC = .954 KIC = .381 HIC = .086 SIIC = .043 CLIC = .008 CAIC = .002 FEIC = .102 SIC = .088 FERC = 2.441 TENS = 2860.983 TEMP = 31.800 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.003 m~ 5 --- 92/09/08 --- 1024 --- LO --- COMCEN.004 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE --- COMCEN.004 --- 92/09/08 --- 1024 --- LO OPTIONAL PREVIOUS FILE NAME --- COMCEN.003 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 04 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 04 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 9271.0 8861.0 Page 10 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 BASELINE DEPTH ......... EQUIVALENT UNSHIFTED DEPTH PSGT 8864.0 8865.0 8900.5 8901.5 8967.5 8968.5 9051.0 9052.0 9137.0 9138.0 9206.5 9207.5 9274.0 9275.0 $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #4. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 84 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GRCH PSGT 739574 LIRI PSGT 739574 COIR PSGT 739574 STUN PSGT 739574 ITCR PSGT 739574 HPLI PSGT 739574 TCCR PSGT 739574 BKG1 PSGT 739574 BKG2 PSGT 739574 RIC PSGT 739574 GAPI API CODE FILE# SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 Page 11 KIC PSGT 739574 00000000 0 4 1 68 HIC PSGT 739574 00000000 0 4 1 68 SIIC PSGT 739574 00000000 0 4 1 68 CLIC PSGT 739574 00000000 0 4 1 68 CAIC PSGT 739574 00000000 0 4 1 68 FEIC PSGT 739574 00000000 0 4 1 68 SIC PSGT 739574 00000000 0 4 1 68 FERC PSGT 739574 00000000 0 4 1 68 TENS PSGT 739574 LB 00000000 0 4 1 68 TEMP PSGT 739574 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9271.000 GRCH = 626.825 LIRI = 1.516 COIR = .712 STUN = .014 ITCR = 2732.994 HPLI = 1.343 TCCR = 4118.702 BKG1 = 4.397 BKG2 = 22.396 RIC = .664 KIC = .386 HIC = .126 SIIC = .051 CLIC = .011 CAIC = .002 FEIC = .084 SIC = .075 FERC = 2.517 TENS = 2946.812 TEMP = 32.200 DEPT = 9071.000 GRCH = 108.521 LIRI = 1.448 COIR = .604 STUN = .009 ITCR = 4863.050 HPLI = 1.330 TCCR = 6321.481 BKG1 = 3.075 BKG2 = 5.638 RIC = .769 KIC = .380 HIC = .090 SIIC = .057 CLIC = .007 CAIC = .002 FEIC = .096 SIC = .088 FERC = 2.420 TENS = 2903.897 TEMP = 33.400 DEPT = 8871.000 GRCH = 481.736 LIRI = 1.437 COIR = .613 STUN = .010 ITCR = 4151.306 HPLI = 1.308 TCCR = 4886.675 BKG1 = 2.797 BKG2 = 12.856 RIC = .850 KIC = .379 HIC = .093 SIIC = .044 CLIC = .004 CAIC = .003 FEIC = .101 SIC = .086 FERC = 2.524 TENS = 2846.678 TEMP = 34.700 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.004 --- 92/09/08 --- 1024 --- LO --- COMCEN.005 FILE HEADER RECORD FILE NAME SERVICE SUB LEVEL NAME TYPE 128 --- COMCEN.005 Page 12 REC'EIVED 0CT I 5 t992 Alaska 01t ~ (~a~ Cons. Commission Anchorage VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME ------ 5 --- 92/09/08 --- 1024 --- LO --- COMCEN. 004 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 05 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 05 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 9272.0 8862.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH-- BASELINE DEPTH PSGT $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #5. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 84 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 Page 13 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE~ SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GRCH PSGT 739574 GAPI 00000000 0 4 1 68 LIRI PSGT 739574 00000000 0 4 1 68 COIR PSGT 739574 00000000 0 4 1 68 STUN PSGT 739574 00000000 0 4 1 68 ITCR PSGT 739574 00000000 0 4 1 68 HPLI PSGT 739574 00000000 0 4 1 68 TCCR PSGT 739574 00000000 0 4 1 68 BKG1 PSGT 739574 00000000 0 4 1 68 BKG2 PSGT 739574 00000000 0 4 1 68 RIC PSGT 739574 00000000 0 4 1 68 KIC PSGT 739574 00000000 0 4 1 68 HIC PSGT 739574 00000000 0 4 1 68 SIIC PSGT 739574 00000000 0 4 1 68 CLIC PSGT 739574 00000000 0 4 1 68 CAIC PSGT 739574 00000000 0 4 1 68 FEIC PSGT 739574 00000000 0 4 1 68 SIC PSGT 739574 00000000 0 4 1 68 FERC PSGT 739574 00000000 0 4 1 68 TENS PSGT 739574 LB 00000000 0 4 1 68 TEMP PSGT 739574 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9272.000 GRCH = 692.119 LIRI = 1.497 COIR = .702 STUN = .012 ITCR = 2947.484 HPLI = 1.351 TCCR = 4232.518 BKG1 = 4.095 BKG2 = 23.777 RIC = .696 KIC = .391 HIC = .119 SIIC = .053 CLIC = .015 CAIC = .000 FEIC = .084 SIC = .075 FERC = 2.445 TENS = 2903.897 TEMP = 37.000 DEPT = 9072.000 GRCH = 91.353 LIRI = 1.438 COIR = .597 STUN = .009 ITCR = 4882.817 HPLI = 1.331 TCCR = 6274.823 BKG1 = 3.223 BKG2 = 4.538 RIC = .778 KIC = .383 HIC = .092 SIIC = .057 CLIC = .008 CAIC = .002 FEIC = .094 SIC = .088 FERC = 2.502 TENS = 2918.203 TEMP = 38.100 DEPT = 8872.000 GRCH = 468.539 LIRI = 1.426 COIR = .635 STUN = .010 ITCR = 4293.102 HPLI = 1.295 TCCR = 5114.629 BKG1 = 3.037 BKG2 = 12.334 RIC = .839 KIC = .381 HIC = .093 SIIC = .041 CLIC = .009 CAIC = .002 FEIC = .100 SIC = .087 FERC = 2.468 TENS = 2846.678 TEMP = 39.100 FILE TRAILER RECORD TYPE 129 Page 14 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.005 --- 92/09/08 --- 1024 --- LO --- COMCEN.006 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.006 ~ 0 --- 92/09/08 --- 1024 --- LO --- COMCEN.005 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 06 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS PSGT GRCH $ REMARKS: 01,02,03,04,05 01 GRCH FOR AVERAGE FILE IS THE PASS #1 GAMMA RAY. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 84 4 1 66 1 Page 15 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GRCH PGAV 739574 GAPI 00000000 0 4 1 68 LIRI PGAV 739574 00000000 0 4 1 68 COIR PGAV 739574 00000000 0 4 1 68 STUN PGAV 739574 00000000 0 4 1 68 ITCR PGAV 739574 00000000 0 4 1 68 HPLI PGAV 739574 00000000 0 4 1 68 TCCR PGAV 739574 00000000 0 4 1 68 BKG1 PGAV 739574 00000000 0 4 1 68 BKG2 PGAV 739574 00000000 0 4 1 68 RIC PGAV 739574 00000000 0 4 1 68 KIC PGAV 739574 00000000 0 4 1 68 HIC PGAV 739574 00000000 0 4 1 68 SIIC PGAV 739574 00000000 0 4 1 68 CLIC PGAV 739574 00000000 0 4 1 68 CAIC PGAV 739574 00000000 0 4 1 68 FEIC PGAV 739574 00000000, 0 4 1 68 SIC PGAV 739574 00000000 0 4 1 68 FERC PGAV 739574 00000000 0 4 1 68 TENS PGAV 739574 LB 00000000 0 4 1 68 TEMP PGAV 739574 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9271.000 GRCH = 648.764 LIRI = 1.487 COIR = .733 STUN = .012 ITCR = 4381.692 HPLI = 1.334 TCCR = 6301.569 BKG1 = 6.103 BKG2 = 24.511 RIC = .693 KIC = .390 HIC = .119 SIIC = .052 CLIC = .013 CAIC = .001 FEIC = .084 SIC = .078 FERC = 2.490 TENS = 2929.646 TEMP = 29.300 DEPT = 9071.000 GRCH = 74.912 LIRI = 1.420 COIR = .605 STUN = .007 ITCR = 7605.730 HPLI = 1.290 TCCR = 9513.541 BKG1 = 5.215 BKG2 = 5.682 RIC = .795 KIC = .383 HIC = .085 SIIC = .056 CLIC = .007 CAIC = .003 FEIC = .095 SIC = .091 FERC = 2.444 TENS = 2921.063 TEMP = 30.560 DEPT = 8871.000 GRCH = 445.215 LIRI = 1.441 Page 16 COIR = .636 STUN = .008 ITCR = 7272.009 HPLI = 1.289 TCCR = 7702.558 BKG1 = 5.245 BKG2 = 13.267 RIC = .926 KIC = .381 HIC = .090 SIIC = .041 CLIC = .007 CAIC = .002 FEIC = .102 SIC = .088 FERC = 2.463 TENS = 2855.261 TEMP = 31.840 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.006 --- 92/09/08 --- 1024 --- LO --- COMCEN.007 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.007 --- 92/09/08 --- 1024 --- LO --- COMCEN.006 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 07 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 01 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT $ 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): 9285.0 8859.0 03-DEC-91 2.1H 1846 03-DEC-91 9271.0 9278.0 8870.0 9276.0 oo.o RECEIVED Page 17 OCT '1 ~ 1992 A!aska Oil & ~ Cons. Commi.ssl.on Anchorage DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NO TOOL NUMBER GR NGRT-A PSGT PSGT-A $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 114434S 008 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): 12.250 9373.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): DEAD CRUDE 203.0 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: $ LIS FORMAT DATA 0.0 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 Page 18 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 CCL PSGT 739574 MV 81500100 0 4 1 68 GR PSGT 739574 GAPI 03100100 0 4 1 68 LIRI PSGT 739574 00000000 0 4 1 68 COIR PSGT 739574 00000000 0 4 1 68 STUN PSGT 739574 00000000 0 4 1 68 ITCR PSGT 739574 00000000 0 4 1 68 HPLI PSGT 739574 00000000 0 4 1 68 TCCR PSGT 739574 00000000 0 4 1 68 BKG1 PSGT 739574 00000000 0 4 1 68 BKG2 PSGT 739574 00000000 0 4 1 68 RIC PSGT 739574 00000000 0 4 1 68 KIC PSGT 739574 00000000 0 4 1 68 HIC PSGT 739574 00000000 0 4 1 68 SIIC PSGT 739574 00000000 0 4 1 68 CLIC PSGT 739574 00000000 0 4 1 68 CAIC PSGT 739574 00000000 0 4 1 68 FEIC PSGT 739574 00000000 0 4 1 68 SIC PSGT 739574 00000000 0 4 1 68 FERC PSGT 739574 00000000 0 4 1 68 TENS PSGT 739574 LB 16350000 0 4 1 68 TEMP PSGT 739574 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9285.000 CCL = 5462.000 GR = 648.764 LIRI = 1.494 COIR = .785 STUN = .016 ITCR = 3521.328 HPLI = 1.356 TCCR = 5047.848 BKG1 = 5.922 BKG2 = 10.434 RIC = .698 KIC = .383 HIC = .107 SIIC = .047 CLIC = .000 CAIC = .006 FEIC = .090 SIC = .073 FERC = 2.652 TENS = 1902.553 TEMP = 22.700 DEPT = 9185.000 CCL = 5462.000 GR = 52.697 LIRI = 1.409 COIR = .604 STUN = .006 ITCR = 9864.732 HPLI = 1.249 TCCR = 11767.110 BKG1 = 6.819 BKG2 = 6.206 RIC = .838 KIC = .393 HIC = .073 SIIC = .057 CLIC = .017 CAIC = .003 FEIC = .091 SIC = .097 FERC = 2.339 TENS = 3004.032 Page 19 TEMP = 23.200 DEPT = 9085.000 CCL = 5466.000 GR = 65.444 LIRI = 1.442 COIR = .620 STUN = .006 ITCR = 10531.130 HPLI = 1.242 TCCR = 11682.910 BKG1 = 7.332 BKG2 = 6.292 RIC = .901 KIC = .382 HIC = .082 SIIC = .049 CLIC = .008 CAIC = .002 FEIC = .099 SIC = .094 FERC = 2.402 TENS = 2961.117 TEMP = 23.600 DEPT = 8985.000 CCL = 5462.000 GR = 435.200 LIRI = 1.364 COIR = .612 STUN = .007 ITCR = 9817.313 HPLI = 1.288 TCCR = 12452.230 BKG1 = 6.010 BKG2 = 12.684 RIC = .788 KIC = .382 HIC = .082 $IIC = .059 CLIC = .005 CAIC = .004 FEIC = .096 SIC = .092 FERC = 2.421 TENS = 2918.203 TEMP = 24.200 DEPT = 8885.000 CCL = 5461.000 GR = 439.547 LIRI = 1.388 COIR = .606 STUN = .007 ITCR = 9773.850 HPLI = 1.238 TCCR = 13055.010 BKG1 = 7.430 BKG2 = 13.790 RIC = .749 KIC = .380 HIC = .081 SIIC = .058 CLIC = .001 CAIC = .005 FEIC = .098 SIC = .094 FERC = 2.426 TENS = 2875.288 TEMP = 24.900 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.007 --- 92/09/08 --- 1024 --- LO --- COMCEN.008 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.008 --- 92/09/08 --- 1024 --- LO --- COMCEN.007 COMMENT RECORD TYPE 232 Page 20 FILE HEADER FILE NUMBER: 08 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 02 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT 9285.0 $ 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 8865.0 03-DEC-91 2.1H 1846 03-DEC-91 9271.0 9278.0 8870.0 9276.0 300.0 NO TOOL NUMBER GR NGRT-A PSGT PSGT-A $ 114434S OO8 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 12.250 9373.0 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): DEAD CRUDE 203.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMalIZATION IN OIL ZONE Page 21 TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: $ LIS FORMAT DATA 0.0 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE DEPT F 00000000 CCL PSGT 739574 MV 81500100 GR PSGT 739574 GAPI 03100100 LIRI PSGT 739574 00000000 COIR PSGT 739574 00000000 STUN PSGT 739574 00000000 ITCR PSGT 739574 00000000 HPLI PSGT 739574 00000000 TCCR PSGT 739574 00000000 BKG1 PSGT 739574 00000000 BKG2 PSGT 739574 00000000 RIC PSGT 739574 00000000 KIC PSGT 739574 00000000 HIC PSGT 739574 00000000 SIIC PSGT 739574 00000000 CLIC PSGT 739574 00000000 CAIC PSGT 739574 00000000 FEIC PSGT 739574 00000000 SIC PSGT 739574 00000000 RECEIVED OCT 15 1992 Alask~ 011 & (~ Cons. Oommission Anchorage FILE# SIZE #SAMP REPR. 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 0 4 1 68 Page 22 FERC PSGT 739574 00000000 0 4 1 68 TENS PSGT 739574 LB 16350000 0 4 1 68 TEMP PSGT 739574 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9285.000 CCL = 5463.000 GR = 677.493 LIRI = 1.478 COIR = .730 STUN = .006 ITCR = 5893.635 HPLI = 1.314 TCCR = 7777.959 BKG1 = 5.375 BKG2 = 23.364 RIC = .758 KIC = .391 HIC = .113 SIIC = .051 CLIC = .011 CAIC = .003 FEIC = .087 SIC = .080 FERC = 2.486 TENS = 1945.468 TEMP = 25.300 DEPT = 9185.000 CCL = 5457.000 GR = 67.316 LIRI = 1.400 COIR = .601 STUN = .006 ITCR = 10270.470 HPLI = 1.245 TCCR = 11658.460 BKG1 = 8.034 BKG2 = 7.317 RIC = .881 KIC = .391 HIC = .075 SIIC = .057 CLIC = .017 CAIC = .003 FEIC = .092 SIC = .098 FERC = 2.373 TENS = 2989.727 TEMP = 26.000 DEPT = 9085.000 CCL = 5472.000 GR = 77.871 LIRI = 1.419 COIR = .615 STUN = .007 ITCR = 8810.529 HPLI = 1.253 TCCR = 10349.720 BKG1 = 6.025 BKG2 = 5.979 RIC = .851 KIC = .383 HIC = .083 SIIC = .050 CLIC = .010 CAIC = .002 FEIC = .098 SIC = .094 FERC = 2.406 TENS = 2946.812 TEMP = 26.700 DEPT = 8985.000 CCL = 5463.000 GR = 417.624 LIRI = 1.400 COIR = .618 STUN = .006 ITCR = 10051.480 HPLI = 1.262 TCCR = 12545.640 BKG1 = 8.532 BKG2 = 12.503 RIC = .801 KIC = .381 HIC = .083 SIIC = .058 CLIC = .006 CAIC = .002 FEIC = .095 SIC = .093 FERC = 2.387 TENS = 2875.288 TEMP = 27.600 DEPT = 8885.000 CCL = 5453.000 GR = 446.779 LIRI = 1.395 COIR = .594 STUN = .006 ITCR = 9936.201 HPLI = 1.277 TCCR = 13195.470 BKG1 = 7.528 BKG2 = 12.396 RIC = .753 KIC = .381 HIC = .078 SIIC = .058 CLIC = .005 CAIC = .004 FEIC = .097 SIC = .094 FERC = 2.435 TENS = 2875.288 TEMP = 28.700 Page 23 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.008 ~m~ 5 --- 92/09/08 --- 1024 --- LO --- COMCEN.009 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.009 ----~ 5 --- 92/09/08 --- 1024 --- LO --- COMCEN.008 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 09 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 03 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT $ 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 9285.0 8865.0 03-DEC-91 2.1H 1846 03-DEC-91 9271.0 9278.0 8870.0 9276.0 300.0 NO TOOL NUMBER GR NGRT-A 114434S PSGT PSGT-A 008 Page 24 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S 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): 12.250 9373.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): DEAD CRUDE 203.0 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: $ LIS FORMAT DATA 0.0 ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 Page 25 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 CCL PSGT 739574 MV 81500100 0 4 1 68 GR PSGT 739574 GAPI 03100100 0 4 1 68 LIRI PSGT 739574 00000000 0 4 1 68 COIR PSGT 739574 00000000 0 4 1 68 STUN PSGT 739574 00000000 0 4 1 68 ITCR PSGT 739574 00000000 0 4 1 68 HPLI PSGT 739574 00000000 0 4 1 68 TCCR PSGT 739574 00000000 0 4 1 68 BKG1 PSGT 739574 00000000 0 4 1 68 BKG2 PSGT 739574 00000000 0 4 1 68 RIC PSGT 739574 00000000 0 4 1 68 KIC PSGT 739574 00000000 0 4 1 68 HIC PSGT 739574 00000000 0 4 1 68 SIIC PSGT 739574 00000000 0 4 1 68 CLIC PSGT 739574 00000000 0 4 1 68 CAIC PSGT 739574 00000000 0 4 1 68 FEIC PSGT 739574 00000000 0 4 1 68 SIC PSGT 739574 00000000 0 4 1 68 FERC PSGT 739574 00000000 0 4 1 68 TENS PSGT 739574 LB 16350000 0 4 1 68 TEMP PSGT 739574 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9285.000 CCL = 5459.000 GR = 652.420 LIRI = 1.507 COIR = .695 STUN = .006 ITCR = 5944.475 HPLI = 1.270 TCCR = 7892.547 BKG1 = 8.192 BKG2 = 21.223 RIC = .753 KIC = .389 HIC = .109 SIIC = .052 CLIC = .012 CAIC = .003 FEIC = .087 SIC = .083 FERC = 2.355 TENS = 1816.724 TEMP = 29.200 DEPT = 9185.000 CCL = 5462.000 GR = 78.816 LIRI = 1.430 COIR = .602 STUN = .006 ITCR = 10128.400 HPLI = 1.256 TCCR = 11708.140 BKG1 = 6.184 BKG2 = 6.750 RIC = .865 KIC = .390 HIC = .076 SIIC = .056 CLIC = .017 CAIC = .002 FEIC = .092 SIC = .096 FERC = 2.376 TENS = 2989.727 TEMP = 29.900 DEPT = 9085.000 CCL = 5462.000 GR = 82.854 LIRI = 1.442 COIR = .609 STUN = .007 ITCR = 9920.373 HPLI = 1.264 TCCR = 11270.780 BKG1 = 7.201 BKG2 = 6.765 RIC = .880 KIC = .384 HIC = .082 SIIC = .052 Page 26 CLIC = .009 CAIC = .003 FEIC = .097 SiC = .093 FERC = 2.383 TENS = 2932.507 TEMP = 30.500 DEPT = 8985.000 CCL = 5463.000 GR = 450.809 LIRI = 1.394 COIR = .626 STUN = .007 ITCR = 9800.670 HPLI = 1.293 TCCR = 12509.500 BKG1 = 6.486 BKG2 = 12.120 RIC = .783 KIC = .383 HIC = .083 SIIC = .058 CLIC = .007 CAIC = .002 FEIC = .095 SIC = .091 FERC = 2.412 TENS = 2889.593 TEMP = 31.200 DEPT = 8885.000 CCL = 5463.000 GR = 482.931 LIRI = 1.379 COIR = .601 STUN = .006 ITCR = 9571.381 HPLI = 1.252 TCCR = 12981.000 BKG1 = 6.420 BKG2 = 13.175 RIC = .737 KIC = .380 HIC = .079 SIIC = .059 CLIC = .004 CAIC = .002 FEIC = .098 SIC = .094 FERC = 2.403 TENS = 2818.068 TEMP = 31.800 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.009 --- 92/09/08 --- 1024 --- LO --- COMCEN.010 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.010 --- 92/09/08 --- 1024 --- LO --- COMCEN.009 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 04 Page 27 RECEIVED OCT I 5 199 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9285.0 PSGT $ 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 8865.0 03-DEC-91 2.1H 1846 03-DEC-91 9271.0 9278.0 8870.0 9276.0 300.0 NO TOOL NUMBER GR NGRT-A PSGT PSGT-A $ 114434S 008 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 12.250 9373.0 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): DEAD CRUDE 203.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): Page 28 TOOL STANDOFF (IN): REMARKS: $ LIS FORMAT DATA 0.0 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 CCL PSGT 739574 MV 81500100 0 4 1 68 GR PSGT 739574 GAPI 03100100 0 4 1 68 LIRI PSGT 739574 00000000 0 4 1 68 COIR PSGT 739574 00000000 0 4 1 68 STUN PSGT 739574 00000000 0 4 1 68 ITCR PSGT 739574 00000000 0 4 1 68 HPLI PSGT 739574 00000000 0 4 1 68 TCCR PSGT 739574 00000000 0 4 1 68 BKG1 PSGT 739574 00000000 0 4 1 68 BKG2 PSGT 739574 00000000 0 4 1 68 RIC PSGT 739574 00000000 0 4 1 68 KIC PSGT 739574 00000000 0 4 1 68 HIC PSGT 739574 00000000 0 4 1 68 SIIC PSGT 739574 00000000 0 4 1 68 CLIC PSGT 739574 00000000 0 4 1 68 CAIC PSGT 739574 00000000 0 4 1 68 FEIC PSGT 739574 00000000 0 4 1 68 SIC PSGT 739574 00000000 0 4 1 68 FERC PSGT 739574 00000000 0 4 1 68 TENS PSGT 739574 LB 16350000 0 4 1 68 TEMP PSGT 739574 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 Page 29 DEPT = 9285.000 CCL = 5462.000 GR = 626.825 LIRI = 1.375 COIR = .839 STUN = .009 ITCR = 3734.176 HPLI = 1.387 TCCR = 5025.751 BKG1 = 8.999 BKG2 = 28.995 RIC = .743 KIC = .388 HIC = .119 SIIC = .060 CLIC = .019 CAIC = .002 FEIC = .083 SIC = .080 FERC = 1.986 TENS = 1745.199 TEMP = 32.200 DEPT = 9185.000 CCL = 5461.000 GR = 74.393 LIRI = 1.430 COIR = .601 STUN = .009 ITCR = 5488.030 HPLI = 1.305 TCCR = 6638.448 BKG1 = 4.406 BKG2 = 5.454 RIC = .827 KIC = .387 HIC = .082 $IIC = .055 CLIC = .016 CAIC = .002 FEIC = .094 SIC = .091 FERC = 2.413 TENS = 2961.117 TEMP = 32.700 DEPT = 9085.000 CCL = 5462.000 GR = 80.793 LIRI = 1.407 COIR = .589 STUN = .009 ITCR = 4734.977 HPLI = 1.281 TCCR = 6136.976 BKG1 = 2.810 BKG2 = 4.455 RIC = .772 KIC = .382 HIC = .090 SIIC = .053 CLIC = .007 CAIC = .003 FEIC = .096 SIC = .090 FERC = 2.514 TENS = 2932.507 TEMP = 33.400 DEPT = 8985.000 CCL = 5437.000 GR = 440.279 LIRI = 1.394 COIR = .621 STUN = .009 ITCR = 4890.602 HPLI = 1.298 TCCR = 6645.170 BKG1 = 3.163 BKG2 = 10.501 RIC = .736 KIC = .379 HIC = .089 SIIC = .058 CLIC = .001 CAIC = .004 FEIC = .095 SIC = .089 FERC = 2.555 TENS = 2875.288 TEMP = 34.000 DEPT = 8885.000 CCL = 5462.000 GR = 487.959 LIRI = 1.425 COIR = .602 STUN = .009 ITCR = 4898.500 HPLI = 1.299 TCCR = 7086.327 BKG1 = 3.790 BKG2 = 13.212 RIC = .691 KIC = .379 HIC = .085 SIIC = .056 CLIC = .002 CAIC = .004 FEIC = .097 SIC = .089 FERC = 2.478 TENS = 2846.678 TEMP = 34.600 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE --- COMCEN.010 --- 92/09/08 --- 1024 --- LO Page 30 OPTIONAL NEXT FILE NAME --- COMCEN.011 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.011 ~ 0 --- 92/09/08 --- 1024 --- LO --- COMCEN.010 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 05 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT $ 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 9285.0 8865.0 03-DEC-91 2.1H 1846 03-DEC-91 9271.0 9278.0 8870.0 9276.0 300.0 NO TOOL NUMBER GR NGRT-A PSGT PSGT-A $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: 114434S OO8 12.250 9373.0 DEAD CRUDE Page 31 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): 203.0 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: $ LIS FORMAT DATA 0.0 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F CCL PSGT 739574 MV API CODE FILE# 00000000 0 81500100 0 SIZE #SAMP REPR. 4 1 68 4 1 68 Page 32 GR PSGT 739574 GAPI 03100100 0 4 1 68 LIRI PSGT 739574 00000000 0 4 1 68 COIR PSGT 739574 00000000 0 4 1 68 STUN PSGT 739574 00000000 0 4 1 68 ITCR PSGT 739574 00000000 0 4 1 68 HPLI PSGT 739574 00000000 0 4 1 68 TCCR PSGT 739574 00000000 0 4 1 68 BKG1 PSGT 739574 00000000 0 4 1 68 BKG2 PSGT 739574 00000000 0 4 1 68 RIC PSGT 739574 00000000 0 4 1 68 KIC PSGT 739574 00000000 0 4 1 68 HIC PSGT 739574 00000000 0 4 1 68 SIIC PSGT 739574 00000000 0 4 1 68 CLIC PSGT 739574 00000000 0 4 1 68 CAIC PSGT 739574 00000000 0 4 1 68 FEIC PSGT 739574 00000000 0 4 1 68 SIC PSGT 739574 00000000 0 4 1 68 FERC PSGT 739574 00000000 0 4 1 68 TENS PSGT 739574 LB 16350000 0 4 1 68 TEMP PSGT 739574 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9285.000 CCL = 5461.000 GR = 692.119 LIRI = 1.408 COIR = .674 STUN = .014 ITCR = 3030.706 HPLI = 1.427 TCCR = 4247.377 BKG1 = 5.515 BKG2 = 24.709 RIC = .714 KIC = .389 HIC = .124 $IIC = .055 CLIC = .008 CAIC = .004 FEIC = .083 SIC = .074 FERC = 2.693 TENS = 2417.530 TEMP = 36.900 DEPT = 9185.000 CCL = 5461.000 GR = 72.986 LIRI = 1.431 COIR = .595 STUN = .008 ITCR = 5358.535 HPLI = 1.295 TCCR = 6250.828 BKG1 = 3.346 BKG2 = 4.157 RIC = .857 KIC = .389 HIC = .081 $IIC = .058 CLIC = .019 CAIC = .002 FEIC = .090 SIC = .093 FERC = 2.360 TENS = 2961.117 TEMP = 37.500 DEPT = 9085.000 CCL = 5470.000 GR = 82.440 LIRI = 1.432 COIR = .609 STUN = .009 ITCR = 5252.028 HPLI = 1.282 TCCR = 6077.477 BKG1 = 2.959 BKG2 = 5.123 RIC = .864 KIC = .380 HIC = .088 $IIC = .051 CLIC = .009 CAIC = .002 FEIC = .098 SIC = .089 FERC = 2.426 TENS = 2932.507 TEMP = 38.000 DEPT = 8985.000 CCL = 5451.000 GR = 451.296 LIRI = 1.408 COIR = .607 STUN = .009 ITCR = 4751.265 HPLI = 1.299 TCCR = 6588.598 Page 33 BKG1 = 2.986 BKG2 = 10.787 RIC = .721 KIC = .380 HIC = .090 SIIC = .057 CLIC = .003 CAIC = ..004 FEIC = .096 SIC = .090 FERC = 2.467 TENS = 2875.288 TEMP = 38.500 DEPT = 8885.000 CCL = 5462.000 GR = 465.522 LIRI = 1.435 COIR = .597 STUN = .009 ITCR = 5345.436 HPLI = 1.244 TCCR = 7441.218 BKG1 = 4.141 BKG2 = 12.599 RIC = .718 KIC = .378 HIC = .086 SIIC = .056 CLIC = .004 CAIC = .002 FEIC = .098 SIC = .093 FERC = 2.427 TENS = 2846.678 TEMP = 39.000 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.011 --- 92/09/08 --- 1024 --- LO --- COMCEN.012 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.012 --- 92/09/08 --- 1024 --- LO --- COMCEN.011 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 12 STATIONS & COMPUTED RESULTS DEPTH INCREMENT 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT 9278.0 8870.0 $ H.L.S. PULSED SPECTRAL GAMMA STATION SUMMARY STATION #1 ( 8895.00 ): TAKEN BEFORE LOGGING PASS #1 Page 34 STATION #2 STATION #3 STATION #4 STATION #5 ( 9060.00 ): TAKEN AFTER LO~GING PASS ~4 ( 9030.00 ): TAKEN AFTER LOGGING PASS #4 ( 9010.00 ): TAKEN AFTER LOGGING PASS #4 ( 8895.00 ): TAKEN AFTER LOGGING PASS #4 STATION* LIRI DEV * COIR DEV * RIC DEV * KIC DEV * HIC DEV ........ · ............ * ............ * ............ * ............ * 8895.00* 1.386 .0120' .6046 .0082* .7486 .0086* .3815 .0009* .0769 .0008 9060.00* 1.419 .0115' .6016 .0109' .7528 .0068* .3817 .0011' .0885 .0014 9030.00* 1.412 .0105' .6190 .0112' .7600 .0079* .3812 .0010' .0902 .0011 9010.00' 1.406 .0120' .6362 .0117' .7164 .0082* .3769 .0011' .0818 .0012 8895.00* 1.399 .0142' .5985 .0097* .7293 .0051' .3784 .0009* .0845 .0012 STATION* SIIC DEV * CLIC DEV * CAIC DEV * FEIC DEV * SIC DEV ........ · ............ * ............ * ............ * ............ * ............ 8895.00* .0592 .0007* .0063 .0011' .0026 .0005* .0967 .0006* .0964 .0008 9060.00* .0563 .0008* .0080 .0015' .0022 .0008* .0948 .0006* .0889 .0012 9030.00* .0597 .0008* .0054 .0016' .0028 .0007* .0937 .0007* .0892 .0010 9010.00' .0525 .0009* .0057 .0015' .0021 .0007* .1011 .0007* .0929 .0010 8895.00* .0559 .0008* .0036 .0011' .0028 .0006* .0984 .0006* .0911 .0011 $ REMARKS: THIS FILE CONTAINS COMPUTED RESULTS FOR: VSH - SHALE VOLUME SOIL - CASED HOLE OIL SATURATION PHSO - CASED HOLE BULK VOUME OIL PHSW - OPEN HOLE BULK VOLUME WATER SPHI - SONIC POROSITY = (OHDT-55.0)/(189.0-55.0) PHIE - EFFECTIVE POROSITY = SPHI * (1.0-VSH) ALSO INCLUDED IS OPEN HOLE DATA PROVIDED BY ARCO: OHGR - OPEN HOLE GAMMA RAY OHDT - OPEN HOLE DELTA T RHOB - OPEN HOLE BULK DENSITY OHSW - OPEN HOLE WATER SATURATION AVERAGE OF PASS #1 - #5 USED FOR COMPUTATIONS. OPEN HOLE GAMMA RAY & SONIC POROSITY USED TO COMPUTE VSH & PHIE. OPEN HOLE DATA HAS BEEN INTERPOLATED FROM 1 SAMPLE/FT. TO 4 SAMPLES/FT. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 72 4 1 66 1 5 1 66 1 Page 35 8 4 73 30 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 OHGR OH 739574 GAPI 00000000 0 4 1 68 OHDT OH 739574 US/F 00000000 0 4 1 68 OHSW OH 739574 % 00000000 0 4 1 68 RHOB OH 739574 G/C3 00000000 0 4 1 68 VSH CHARM 739574 % 00000000 0 4 1 68 SOIL CHARM 739574 % 00000000 0 4 1 68 PHSO CHARM 739574 % 00000000 0 4 1 68 PHSW CHARM 739574 % 00000000 0 4 1 68 SPHI CHARM 739574 % 00000000 0 4 1 68 PHIE CHARM 739574 % 00000000 0 4 1 68 GR PSGT 739574 GAPI 00000000 0 4 1 68 LIRI PSGT 739574 00000000 0 4 1 68 COIR PSGT 739574 00000000 0 4 1 68 STUN PSGT 739574 00000000 0 4 1 68 RIC PSGT 739574 00000000 0 4 1 68 SIIC PSGT 739574 00000000 0 4 1 68 CAIC PSGT 739574 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9278.000 OHGR = 44.130 OHDT = 97.600 OHSW = .124 RHOB = 2.220 VSH = .259 SOIL = 1.000 PHSO = .000 PHSW = .000 SPHI = .264 PHIE = .196 GR = 648.764 LIRI = 1.471 COIR = .764 STUN = .016 RIC = .680 SIIC = .054 CAIC = .003 DEPT = 9178.000 OHGR = 45.210 OHDT = 77.010 OHSW = .357 RHOB = 2.498 VSH = .276 SOIL = .681 PHSO = .039 PHSW = .039 SPHI = .169 PHIE = .122 GR = 27.748 LIRI = 1.428 COIR = .623 STUN = .007 RIC = .774 $IIC = .047 CAIC = .001 DEPT = 9078.000 OHGR = 30.590 OHDT = 89.000 OHSW = .214 RHOB = 2.296 VSH = .083 SOIL = .310 PHSO = .152 PHSW = .047 SPHI = .240 PHIE = .220 GR = 49.751 LIRI = 1.409 COIR = .601 STUN = .007 RIC = .803 SIIC = .054 CAIC = .002 Page 36 DEPT = 8978.000 OHGR = 29.500 OHDT = 88.110 OHSW = .231 RHOB = 2.192 VSH = .072 SOIL = .655 PHSO = .069 PHSW = .046 SPHI = .216 PHIE = .201 GR = 416.860 LIRI = 1.393 COIR = .616 STUN = .008 RIC = .751 SIIC = .057 CAIC = .003 DEPT = 8878.000 OHGR = 39.020 OHDT = 98.050 OHSW = .253 RHOB = 2.197 VSH = .185 SOIL = .448 PHSO = .110 PHSW = .051 SPHI = .246 PHIE = .200 GR = 449.313 LIRI = 1.399 COIR = .606 STUN = .007 RIC = .757 SIIC = .052 CAIC = .003 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.O12 --- 92/09/08 --- 1024 --- LO TAPE TRAILER RECORD TYPE 131 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER NEXT TAPE NAME COMMENTS: --- COMCEN --- 92/09/08 ~m~ 0 REEL TRAILER RECORD TYPE 133 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER NEXT REEL NAME COMMENTS: --- COMCEN --- 92/09/08 --- ANCH --- 739574 END OF TAPE ENCOUNTERED Page 37 * HHHH HHHH * * HHHH HHHH H H A LL LL II BBBB U U RRRR TTTTT O N N * * HHHH HHHH H H AA LL LL II B B U U R R T O O NN N * * HHHHHHHHHHH HHHH A A LL LL II BBBB U U RRRR T O O N N N * * HHHHHHI~-LHHH H H AAAA LL LL II B B U U R R T O O N NN * * HHHH HHHH H H A ALL LL II BBBB U R R T O N N * * HHHH HHHH * *HHHH HHHH L O G G I N G S E R V I C E S , I N C . * , * . * , * * LIS TAPE VERIFICATION LISTING COMPANY: ARCO ALASKA INC. WELL: DS 4-7 S/T API #: 50-029-20189-00 DATE: 02-16-92 FIELD: PRUDHOE BAY BOROUGH: NORTH SLOPE STATE: ALASKA RECEIVED . MAP, 1 2 1992 * * LOGS: HRI/BCS/DSN2 * AlaSka Oil & Cas Cons, Oommissio~ . * Page' 1 REEL HEADER RECORD TYPE 132 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER PREVIOUS REEL NAME COMMENTS: --- COMCEN --- 92/02/26 --- ANCH --- 666259 TAPE HEADER RECORD TYPE 130 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER PREVIOUS TApE NAME COMMENTS: --- COMCEN --- 92/02/26 --- ANCH COMMENT RECORD TYPE 232 TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 04-07 500292018900 ARCO ALASKA INC. HALLIBURTON LOGGING SERVICES 26-FEB-92 RUN 1 RUN 2 RUN 3 666259 J. ADDISON D. MOSTELLER JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) 27 liN 15E 90 593 Page 2 KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 51.00 50.0O 15.00 OPEN HOLE CASING DRILLER'S BIT SIZE(IN) SIZE(IN) DEPTH(FT) 1ST STRING 2ND STRING 12.250 9.625 8335.0 3RD STRING 8.500 9494.0 PRODUCTION STRING REMARKS: HRI-BCS-DSN2 RUN IN COMBINATION. DID NOT GO TO BOTTOM DUE TO HOLE CONDITIONS. TOOL STICKING ON FIRST ATTEMPT. $ FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.001 --- 92/02/26 --- 1024 --- LO ~m COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 01 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH BCS 9415.0 HRI 9442.0 DSN2 9381.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 8332.0 8335.5' 8332.0 ......... EQUIVALENT UNSHIFTED DEPTH-- $ MERGED DATA SOURCE .Page 3 PBU TOOL CODE RUN NO. PASS NO. MERGE TOP MERGE BASE $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 52 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 19 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# DEPT F 00000000 0 GR BCS 666259 GAPI 00000000 0 DT BCS 666259 US/F 00000000 0 TENS BCS 666259 LB 00000000 0 TEND BCS 666259 LB 00000000 0 SFL HRI 666259 OHMM 00000000 0 1124 HRI 666259 OflMM 00000000 0 ILD HRI 666259 OHMM 00000000 0 SP HRI 666259 MV 00000000 0 NPHI DSN2 666259 PU-S 00000000 0 FCNT DSN2 666259 CPS 00000000 0 NCNT DSN2 666259 CPS 00000000 0 CRAT DSN2 666259 00000000 0 SIZE #SAMP REPR. 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9442.000 GR = -999.000 DT = -999.000 TENS = 4927.932 TEND = 1444.057~~ SFL = 4.900 ILM = 3.570 ILD = 3.690 SP = 87.782 NPHI = -999.000 FCNT = -999.000 NCNT = -999.000 CRAT = -999.000 Page 4 DEPT = 9242.000 GR = 18.278 DT = 98.036 TENS = 4455.111 TEND = 1204.557 SFL = 19.916 ILM = 20.911 ILD = 25.250 SP = 108.493 NPHI = 27.368 FCNT = 2803.381 NCNT = 16249.710 CRAT = 6.172 DEPT = 9042.000 GR = 26.480 DT = 83.308 TENS = 4455.111 TEND = 1213.784 SFL = 20.040 ILM = 27.836 ILD = 45.386 SP = 91.921 NPHI = 20.191 FCNT = 4026.675 NCNT = 18324.980 CRAT = 4.846 DEPT = 8842.000 GR = 219.222 DT = 87.440 TENS = 4512.423 TEND = 1324.908 SFL = 5.288 ILM = 3.730 ILD = 3.779 SP = 102.032 NPHI = 47.851 FCNT = 1259.323 NCNT = 11872.170 CRAT = 10.038 DEPT = 8642.000 GR = 125.205 DT = 77.692 TENS = 4354.815 TEND = 1292.814 SFL = 5.691 ILM = 3.503 ILD = 3.662 SP = 125.977 NPHI = 36.109 FCNT = 1791.638 NCNT = 13366.650 CRAT = 7.944 DEPT = 8442.000 GR = 205.695 DT = 107.100 TENS = 4254.521 TEND = 1304.048 SFL = 3.668 ILM = 2.782 ILD = 2.840 SP = 136.975 NPHI = 38.731 FCNT = 1618.145 NCNT = 12746.250 CRAT = 8.387 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.001 --- 92/02/26 --- 1024 --- LO --- COMCEN.002 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.002 ~m 0 --- 92/02/26 --- 1024 --- LO --- COMCEN.001 Page 5 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 02 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 01 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH DSN2 8332.0 8282.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ # REm~Ks: $ # LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 32 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 31 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS DEPT F GRCH DSN2 666259 GAPI NPHI DSN2 666259 PU-S FCNT DSN2 666259 CPS API CODE FILE~ 00000000 0 00000000 0 00000000 0 00000000 0 SIZE 4 4 4 4 ~SAMP REPR. 1 68 1 68 1 68 1 68, Page 6 NCNT DSN2 666259 CPS 00000000 0 4 1 68 CRAT DSN2 666259 00000000 0 4 1 68 TENS DSN2 666259 LB 00000000 0 4 1 68 TEND DSN2 666259 LB 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 8332.000 GRCH = 102.951 NPHI = 52.136 FCNT = 1139.131 NCNT = 11550.340 CRAT = 10.796 TENS = 4182.881 TEND = 1290.007 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.002 --- 92/02/26 --- 1024 --- LO --- COMCEN.003 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.003 --- 92/02/26 --- 1024 --- LO --- COMCEN.002 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 03 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 02 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH HRI 9465.0 8332.0 Page 7 BCS 9465.0 DSN2 9465.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 8332.0 8332.0 16-FEB-92 PLS-II 2.1J 0500 16-FEB-92 1145 16-FEB-92 9494.0 9465.0 8282.5 9454.0 1800.0 TOOL NUMBER DSN2 BCS HRI $ DUAL SPACED NEUTRON FULL WAVE SONIC 2 HIGH RES. INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): LIS FORMAT DATA 108829 02 6BA23 8.500 8335.0 8332.0 LSND 9.60 37.0 5.4 152.0 .320 · 120 .210 .079 .470 .176 THERMAL SANDSTONE 2.65 8.500 0.0 57.0 152.0 57.0 152.0 57.0 152.0 Page 8 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 80 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GR BCS 666259 GAPI FDSN DSN2 666259 CPS NDSN DSN2 666259 CPS NPHI DSN2 666259 DECP NRAT DSN2 666259 C/C DT BCS 666259 US/F ITT BCS 666259 HDRS HRI 666259 OHMM HMRS HRI 666259 OHMM HDCN HRI 666259 MMHO HMCN HRI 666259 MMHO DFL HRI 666259 OHMM SP HRI 666259 MV TENS BCS 666259 LB DLOD BCS 666259 LB TT21 BCS 666259 TT22 BCS 666259 TTll BCS 666259 TT12 BCS 666259 API CODE FILE# SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9465.000 GR = NDSN = 13909.660 NPHI = DT = 88.800 ITT = HMRS = -12345.000 HDCN = DFL = -12345.000 SP = DLOD = 636.098 TT21 = TTll = 407.000 TT12 = 126.981 FDSN = 1961.587 .342 NRAT = 7.550 .000 HDRS = -12345.000 -12345.000 HMCN = -12345.000 -999.000 TENS = 2879.044 604.800 TT22 = 430.800 588.200 DEPT = 9365.000' GR = 85.468 FDSN = 2935.910 Pag~.~ 9 NDSN = DT = HMRS = DFL = DLOD = TTll = 15967.280 NPHI = 73.304 ITT = 9.122 HDCN = 12.284 SP = 1148.393 TT21 = 412.300 TT12 = .252 .000 85.948 90.452 546.800 556.400 NRAT = HDRS = HMCN = TENS = TT22 = 5.791 11.635 109.627 4469.439 399.000 DEPT = NDSN = DT = HMRS = DFL = DLOD = TTll = 9265.000 GR = 16971.070 NPHI = 101.780 ITT = 4.489 HDCN = 4.693 SP = 1294.820 TT21 = 442.200 TT12 = 24.177 .279 .000 208.984 108.337 670.700 644.600 FDSN = NRAT = HDRS = HMCN = TENS = TT22 = 2853.333 6.333 4.785 222.759 4670.029 466.900 DEPT = NDSN = DT = HMRS = DFL = DLOD = TTll = 9165.000 GR = 16830.700 NPHI = 94.136 ITT = 14.076 HDCN = 23.954 SP = 1164.439 TT21 = 388.600 TT12 = 70.176 .254 .000 48.685 88.324 638.600 548.700 FDSN = NRAT = HDRS = HMCN = TENS = TT22 = 3082.532 5.813 20.540 71.043 4369.144 433.500 DEPT = NDSN = DT = HMRS = DFL = DLOD = TTll = 9065.000 GR = 16997.790 NPHI = 97.884 ITT = 13.493 HDCN = 10.239 SP = 1214.987 TT21 = 449.400 TT12 = 24.835 .264 .000 72.327 102.065' 661.300 640.800 FDSN = NRAT = HDRS = HMCN = TENS = TT22 = 3000.653 6.031 13.826 74.111 4498.095 458.800 DEPT = 8965.000 NDSN = 18514.050 DT = 89.816 HMRS = 30.517 DFL = 69.387 DLOD = 1267.140 TTll = 452.700 GR = NPHI = ITT = HDCN = SP = TT21 = TT12 = 23.489 .179 .000 .050 83.222 616.000 628.100 FDSN = NRAT = HDRS = HMCN = TENS = TT22 = 4450.098 4.430 20000.000 32.769 4483.767 434.200 DEPT = 8865.000 NDSN = 13155.930 DT = 85.652 HMRS = 8.368 DFL = 10.737 DLOD = 1308.460 TTll = 474.500 GR = NPHI = ITT = HDCN = SP = TT21 = TT12 = 106.702 .429 7.000 128.017 103.964 631.000 646.600 FDSN = NRAT = HDRS = HMCN = TENS = TT22 = 1527.215 9.172 7.811 119.507 4512.423 465.400 DEPT = NDSN = DT = HMRS = 8765.000 GR = 12800.340 NPHI = 101.332 ITT = 6.222 HDCN = 334.409 .403 .000 148.866 FDSN = NRAT = HDRS = HMCN = 1574.955 8.654 6.717 160.728 Page 10 DFL = 8.919 SP = 112.738 TENS = 4440.783 DLOD = 1308.861 TT21 = 688.800 TT22 = 486.100 TTll = 446.700 TT12 = 649.000 DEPT = 8665.000 GR = 215.435 FDSN = 1353.522 NDSN = 12135.430 NPHI = .449 NRAT = 9.546 DT = 86.492 ITT = .000 HDRS = 3.721 HMRS = 3.642 HDCN = 268.739 HMCN = 274.538 DFL = 6.274 SP = 124.115 TENS = 4397.800 DLOD = 1328.118 TT21 = 735.900 TT22 = 515.600 TTll = 503.200 TT12 = 631.800 DEPT = 8565.000 GR = 156.044 FDSN = 1597.004 NDSN = · 13189.050 NPHI = .406 NRAT = 8.793 DT = 101.960 ITT = .000 HDRS = 4.099 HMRS = 3.966 HDCN = 243.933 HMCN = 252.122 DFL = 6.704 SP = 136.215 TENS = 4326.160 DLOD = 1301.239 TT21 = 692.500 TT22 = 421.300 TTll = 491.200 TT12 = 631.200 DEPT = 8465.000 GR = 150.697 FDSN = 1562.326 NDSN = 12920.470 NPHI = .407 NRAT = 8.805 DT = 98.808 ITT = .000 HDRS = 2.567 HMRS = 2.486 HDCN = 389.537 HMCN = 402.273 DFL = 3.074 SP = 133.767 TENS = 4297.504 DLOD = 1318.089 TT21 = 692.500 TT22 = 425.000 TTll = 501.200 TT12 = 621.500 DEPT = 8365.000 GR = 159.581 FDSN = 1259.323 NDSN = 12191.460 NPHI = .493 NRAT = 10.308 DT = 89.828 ITT = 7.000 HDRS = 1.576 HMRS = 1.601 HDCN = 634.450 HMCN = 624.741 DFL = 2.229 SP = 139.630 TENS = 4182.881 DLOD = 1272.756 TT21 = 627.000 TT22 = 449.100 TTll = 438.000 TT12 = 619.700 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.003 --- 92/02/26 --- 1024 --- LO --- COMCEN.004 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME --- COMCEN.004 Page 11 VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME ------ 5 --- 92/02/26 --- 1024 --- LO --- COMCEN. 003 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 04 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: 1 PASS NUMBER: 01 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH HRI BCS DSN2 $ LOG HEADER DATA DATE LOGGED: 9465.0 8853.0 9465.0 8853.0 9465.0 8853.0 SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 16-FEB-92 PLS-II 2.1J 0500 16-FEB-92 1145 16-FEB-92 9494.0 9465.0 8282.5 9454.0 1800.0 TOOL NUMBER DSN2 BCS HRI $ DUAL SPACED NEUTRON FULL WAVE SONIC 2 HIGH RES. INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 108829 02 6BA23 8.500 8335.0 8332.0 LSND 9.60 37.0 Page 12 ~UD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR-THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): LIS FORMAT DATA 5.4 152.0 .320 .120 .210 .079 .470 .176 THERMAL SANDSTONE 2.65 8.500 0.0 57.0 152.0 57.0 152.0 57.0 152.0 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 80 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 7g 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GR BCS 666259 GAPI FDSN DSN2 666259 CPS NDSN DSN2 666259 CPS NPHI DSN2 666259 DECP NRAT DSN2 666259 C/C DT BCS 666259 US/F ITT BCS 666259 HDRS HRI 666259 OHMM HMRS HRI 666259 OHMM API CODE FILE~ SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 ~SAMP REPR. 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 Page 13 HDCN HRI 666259 MMHO 00000000 0 4 1 68 HMCN HRI 666259 MMHO 00000000 0 4 1 68 DFL HRI 666259 OHMM 00000000 0 4 1 68 SP HRI 666259 MV 00000000 0 4 1 68 TENS BCS 666259 LB 00000000 0 4 1 68 DLOD BCS 666259 LB 00000000 '0 4 1 68 TT21 BCS 666259 00000000 0 4 1 68 TT22 BCS 666259 00000000 0 4 1 68 TTll BCS 666259 00000000 0 4 1 68 TT12 BCS 666259 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9465.000 GR = 135.034 FDSN = 1933.471 NDSN = 14177.580 NPHI = .355 NRAT = 7.807 DT = .000 ITT = .000 HDRS = -12345.000 HMRS = -12345.000 HDCN = -12345.000 HMCN = -12345.000 DFL = -12345.000 SP = -999.000 TENS = 2922.028 DLOD = 768.083 TT21 = .000 TT22 = .000 TTll = .000 TT12 = .000 DEPT = 9365.000 GR = 83.252 FDSN = 3046.664 NDSN = 16182.360 NPHI = .245 NRAT = 5.655 DT = 73.068 ITT = .000 HDRS = 13.450 HMRS = 11.206 HDCN = 74.351 HMCN = 89.235 DFL = 11.744 SP = 185.326 TENS = 4627.046 DLOD = 1233.843 TT21 = 553.800 TT22 = 409.800 TTll = 400.800 TT12 = 550.200 DEPT = 9265.000 GR = 22.575 FDSN = 2798.318 NDSN = 17088.170 NPHI = .287 NRAT = 6.502 DT = 101.776 ITT = .000 HDRS = 5.070 HMRS = 5.000 HDCN = 197.227 HMCN = 200.007 DFL = 5.043 SP = 171.831 TENS = 4498.095 DLOD = 1213.784 TT21 = 671.200 TT22 = 467.300 TTll = 435.800 TT12 = 638.500 DEPT = 9165.000 GR = 68.179 FDSN = 3082.414 NDSN = 16774.750 NPHI = .253 NRAT = 5.794 DT = 86.992 ITT = .000 HDRS = 24.374 HMRS = 15.471 HDCN = 41.027 HMCN = 64.637 DFL = 23.400 SP = 122.676 TENS = 4612.718 DLOD = 1245.878 TT21 = 616.800 TT22 = 438.200 TTll = 391.000 TT12 = 562.700 DEPT = 9065.000 GR = 25.421 FDSN = 2802.911 NDSN = 16468.360 NPHI = .276 NRAT = 6.256 DT = 97.676 ITT = .000 HDRS = 13.481 HMRS = 13.676 HDCN = 74.181 HMCN = 73.120 DFL = 10.508 SP = 102.358 TENS = 4426.455 DLOD = 1212.580 TT21 = 661.500 TT22 = 461.100 Page z-: TTll = 449.900 TT12 = 641.000 DEPT = 8965.000 GR = 24.404 FDSN = 3774.080 NDSN = 17217.090 NPHI = .204 NRAT = 4.857 DT = 89.580 ITT = .000 HDRS = 511.738 HMRS = 46.931 HDCN = 1.954 HMCN = 21.308 DFL = 68.946 SP = 84.594 TENS = 4426.455 DLOD = 1257.913 TT21 = 615.700 TT22 = 434.100 TTll = 452.600 TT12 = 629.100 DEPT = 8865.000 GR = 99.988 FDSN = 1472.303 NDSN = 13105.180 NPHI = .448 NRAT = 9.477 DT = 84.272 ITT = .000 HDRS = 8.015 HMRS = - 8.643 HDCN = 124.764 HMCN = 115.696 DFL = 22.660 SP = 95.896 TENS = 4483.767 DLOD = 1291.210 TT21 = 630.500 TT22 = 467.400 TTll = 472.100 TT12 = 640.000 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.004 ~m 0 --- 92/02/26 --- 1024 --- LO --- COMCEN.005 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.005 ~m 0 --- 92/02/26 --- 1024 --- LO --- COMCEN.004 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 05 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 02 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 15 DSN2 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 8332.0 8282.5 16-FEB-92 PLS-II 2.1J 0500 16-FEB-92 1145 16-FEB-92 9494.0 9465.0 8282.5 9454.0 1800.0 TOOL NUMBER DSN2 BCS HRI $ DUAL SPACED NEUTRON FULL WAVE SONIC 2 HIGH RES. INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): LIS FORMAT DATA 108829 02 6BA23 8.500 8335.0 8332.0 LSND 9.60 37.0 5.4 152.0 .320 .120 .210 .079 .470 .176 THERMAL SANDSTONE 2.65 8.500 0.0 57.0 152.0 57.0 152.0 57.0 152.0 ****************************************************************************** Page 16 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 32 4 1 66 1 5 1 66 8 4 73 30 9 4 65 .liN 11 2 79 31 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS DEPT F GR DSN2 666259 GAPI FDSN DSN2 666259 CPS NDSN DSN2 666259 CPS NPHI DSN2 666259 DECP NRAT DSN2 666259 C/C TENS DSN2 666259 LB DLOD DSN2 666259 LB API CODE FILE# SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 8332.000 GR = NDSN = 11550.340 NPHI = TENS = 4182.881 DLOD = 102.951 FDSN = 1139.131 .521 NRAT = 10.796 1290.007 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.005 --- 92/02/26 --- 1024 --- LO ****************************************************************************** TAPE TRAILER RECORD TYPE 131 SERVICE NAME DATE ORIGIN OF DATA --- COMCEN --- 92/02/26 --- ANCH Page 17 TAPE NAME --- 0 TAPE CONTINUATION NUMBER --- 1 NEXT TAPE NAME --- COMMENTS: ****************************************************************************** REEL TRAILER RECORD TYPE 133 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER NEXT REEL NAME COMMENTS: --- COMCEN --- 92/02/26 --- ANCH --- 666259 ****************************************************************************** END OF TAPE ENCOUNTERED * ALASKA COMPUTING CENTER * * * * ....... SCHLUMBERGER ....... * COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO : ARCO ALASKA, INC. : D.S. 4-7 ST1 : PRUDHOE BAY : NORTH SLOPE : ALASKA : 50-029-20189-00 : 95292 LIS Tape Verification Listing Schlumberger Alaska CompuSing Center 5-SEP-1995 12:43 **** REEL HEADER **=* SERVICE NAME : EDIT DATE : 95/09/ 5 ORIGIN : FLIC REEL NAME : 95292 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, PRUDHOE BAY, D.S. 4-7 ST1, API #50-029-20189-00 **** TAPE HEADER SERVICE NAME : EDIT DATE : 95/09/ 5 ORIGIN : FLIC TAPE NAME : 95292 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, PRUDHOE BAY, D.S. 4-7 ST1, API #50-929-20189-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 4-7 ST1 API NUMBER: 509292018990 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 5-SEP-95 JOB NUMBER: 95292 LOGGING ENGINEER: SIMMONS OPERATOR WITNESS: J.JULIAN SURFACE LOCATION SECTION: 27 TOWNSHIP: 11N RANGE: 15E FNL: FSL: 99 FEL: 593 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 51.09 DERRICK FLOOR: 50.00 GROUND LEVEL: 15.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9.625 8342.9 2ND STRING 7.000 9464.0 3RD STRING 5.599 3902.0 PRODUCTION STRING 4.500 8114.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) 47.99 29.00 17.00 12.69 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWO TOOL CODE: BCS LDWG CURVE CODE: OR RUN NUMBER: PASS NUMBER: DATE LOGGED: 16-FEB-92 LOGGING COMPANY: HALLIBURTON BASELINE DEPTH GRCH 5-SEP-1995 12:43 EQUIVALENT UNSHIFTED DEPTH NPHI 88888.0 9229.5 9229.0 9208.5 9207.0 9195.0 9176.5 9176.0 9138.5 9116.5 9116.0 9088.0 9086.5 9068 0 9067 5 9042 5 9033 0 9032 5 9015 5 9014 5 9003 0 9002 5 8999 0 8998 5 $ REMARKS: 88888.0 9229.5 9207.0 9195.0 9176.5 9138.5 9116.5 9088.5 9068.0 9043.5 9032.5 9016,0 9003.0 8998.5 100.0 88888.5 9229,5 9209.0 9195,0 9176.5 9116.5 9088.5 9068,5 9043,5 9032,5 9016,0 9002,5 8998,5 99.5 The depth adjus%men%s shown above reflec% cased hole GR %o open hole GR and cased hole NPHI %o open hole GR. All o%her CNTD curves were carried wi%h %he NPHI shif%s. PROPER WELL NAME AND API NUMBER WAS VERIFIED BY SANDY LEMKE OF ARCO 5-SEP-95. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-i995 i2:43 FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shif%ed and clipped curves for each pass in separa%e files. PASS NUMBER: DEPTH INCREMENT: 0.5009 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9259.9 8995.9 CNTD 9272.0 8995.9 $ CURVE SHIFT DATA - PASS TO PASS(~EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: # EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: This file con%ains CNTD Pass shif%s were applied %o %his da%a. $ LIS FORMAT DATA No pass %o pass PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 l 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-199S 12:43 PAGE: SET TYPE - CHAN NAME SERV UNIT SERVICE AP1 AP1 AP1 API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 5~6130 00 000 00 0 1 1 1 4 68 NPHI CNTD PU-S 50613~ 00 000 00 0 i 1 1 4 68 NRAT CNTD 5~6130 00 000 00 0 1 1 1 4 68 CRAT CNT~ 506130 00 000 00 0 ! 1 1 4 68 NCNT CNTD CPS 506130 00 000 00 0 1 ! 1 4 68 FCNT CNTD CPS 506130 00 000 00 0 1 1 1 4 68 CFTC CNTD CPS 506130 00 000 00 0 1 1 1 4 68 CNTC CNTD CPS S06130 0~ 000 00 0 1 1 1 4 68 GRCH CNTD GAPI 506130 00 000 00 0 1 1 1 4 68 TENS CNTD LB 506130 00 000 00 0 1 1 1 4 68 CCL CNTD V 506130 00 000 00 0 1 1 1 4 68 GR BCS GAPI 506130 00 000 00 0 1 ! 1 4 68 ** DATA DEPT. 9300.~00 NPHI.CNTD -999.250 NRAT.CNTD NCNT.CNTD -999.25~ FCNT.CNTD -999.250 CFTC.CNTD GRCH.CNT~ -999.250 TENS.CNTD -999.250 CCL.CNTD DEPT. 8940.000 NPHI.CNTD -999.250 NRAT.CNTD NCNT.CNTD -999.250 FCNT.CNTD -999.250 CFTC.CNTD GRCH.CNTD -999.250 TENS.CNTD -999.250 CCL.CNTD -999.250 CRAT.CNTD -999.250 CNTC.CNTD -999.250 GR.BCS -999.250 CRAT.CNTD -999.250 CNTC.CNTD -999.250 GR.BCS -999.250 -999.250 39.444 -999.25e -999.250 82.512 ** END OF DATA **** FILE TRAILER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 0~1C~1 DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 5-SEP-1995 12:43 PAGE: 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 SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9259.0 8997.0 CNTD 9272.0 8997.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: I EQUIVALENT UNSHIFTED DEPTH. BASELINE DEPTH GRCH CNTD 88888 0 9263 5 9251 5 9239 5 9237 5 9235 5 9233 5 9231 5 9227 5 9223 5 9219.5 9215.5 9211.5 9199.5 9197.5 9195.5 9193.5 9191.5 9185.5 9181.5 9169.5 88888.5 9238.0 9233.5 9197.5 9194.0 9186.0 9181.5 9169.5 88888.5 9264.0 9252.5 9240.5 9236.0 9232.5 9228 0 9223 0 9220 0 9216 5 9212 0 9200 0 9195.5 9192.0 LIS Tape Verification Listing Schlumberger Alaska Compu%ing Center 5-SEP-1995 12:43 PAGE: 9167.~ 9165.5 9163.5 9159.5 9157.5 9153.5 9133.5 9129 5 9125 5 9121 5 9103 5 9099 5 9091 5 9087 5 9083 5 9079 5 9075 5 9071 5 9067 5 9063 5 9059 5 9055 5 9051 5 9047 5 9045 5 9043 5 9041 5 9037 5 9035 5 9033 5 9031 5 9029,5 9027.5 9023,5 9012,5 9006.5 $ 9165.0 9157.9 9153.5 9133.5 9139.0 9126.5 9122.0 9046.0 9041.5 9037.5 9034,0 9029.5 9168.0 9164.5 9160.0 9104.0 9101.0 9094.0 9089.5 9085.0 9081.5 9077.5 9072.5 9068.5 9065.0 9061.0 9056.5 9053.0 9049.0 9044.5 9036.5 9032.0 9028.0 9025.0 9014.0 9006.5 100.0 REMARKS: This file con%ains CNTD Pass #2. The dep%h shif%s shown above relec% GRCH pass #2 %o GRCH pass #1 and NPHI pass #2 to NPHI pass #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Cen~er 5-SEP-~995 Z2:43 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 ~4 65 FT 15 66 68 16 66 1 0 66 I PAGE: SET TYPE - CHAN *, NAME SERV UNIT SERVICE API AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 506130 00 000 00 0 2 ~ I 4 68 0000000000 NPHI CNTD PU-S 506130 00 000 00 0 2 1 I 4 68 0000000000 NRAT CNTD 506130 00 000 00 0 2 1 I 4 68 0000000000 CRAT CNTD 506130 00 000 00 0 2 1 ! 4 68 0000000000 NCNT CNTD CPS 506130 00 000 00 0 2 1 I 4 68 0000000000 FCNT CNTD CPS 506130 00 000 00 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 506130 00 000 00 0 2 1 I 4 68 0000000000 CNTC CNTD CPS 506130 00 000 00 0 2 I 1 4 68 0000000000 GRCH CNTD GAPI 506130 00 000 00 0 2 I 1 4 68 0000000000 TENS CNTD LB 506130 00 000 00 0 2 1 1 4 68 0000000000 CCL CNTD V 506130 00 000 00 0 2 1 I 4 68 0000000000 ** DATA DEPT. NCNT.CNTD GRCH.CNTD DEPT. NCNT.CNTD GRCH.CNTD 9272.500 NPHI.CNTD 31.570 NRAT.CNTD 5.190 CRAT.CN'rD 3063.197 FCNT.CNTD 614.260 CFTC.CNTD 610.682 CNTC.CNTD -999.250 TENS.CNTD 1200.000 CCL.CNTD 0.000 8997.000 NPHI.CNI'D 19.217 NRAT.CNTD 3.610 CRAT.CNTD 4628.736 FCNT.CNTD 1188.042 CFTC.CNTD 1209.239 CNTC.CNTD ~2.836 TENS.CNTD [[85.000 CCL.CNTD 0.000 5.233 3366.329 3.648 4764.393 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 12:43 PAGE: ** END OF DATA **** FILE TRAILER ***, FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9259.0 8997.0 CNTD 9272,0 8997.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH Pass NUMBER: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH CNTD 88888.0 88888.0 88889.5 9263.5 9265.0 9259.5 9261.0 9255.5 9258.0 9251.5 9252.5 LIS Tape Verifica%ion Lis%in9 Schlumberger Alaska Compu~in9 Cen~er 5-SEP-1995 12:43 PAGE: 9247.5 9243.5 9237.5 9235.5 9231.5 9223.5 9219.5 9215 5 9211 5 9209 5 9207 5 9205 5 9187 5 9185 5 9183 5 9181 5 9165 5 9163 5 9161 5 9159 5 9139.5 9135.5 9133.5 9131,5 9129.5 9127,5 9123.5 9119.5 9111.5 9109.5 9105.5 9103 5 9101 5 9099 5 9097 5 9095 5 9093 5 909! 5 9083 5 9079.5 9075 5 9069 5 9067 5 9065 5 9063 5 9061 5 9059.5 9057 5 9053 5 9047 5 9045 5 9043 5 9041 5 9035 5 9027 5 9237.5 9209.5 9206.0 9186.0 9181.5 9165.5 9162.0 9134.0 9130.5 9110.5 9105.5 9102.5 9098.5 9095.0 9071.0 9066.5 9063.0 9058.5 9054.0 9046.5 9042.0 9249.0 9244.5 9236.5 9232.0 9224.0 9219.5 9217.0 9212.5 9208.0 9188.0 9184.5 9164.5 9160.0 9140.0 9135.5 9131.5 9128.0 9124.0 9119.5 9111.5 9105.0 9101.0 9097.5 9094.0 9086.0 9081.5 9077.0 9069.0 9064.5 9061.0 9049.0 9044.5 9036.0 9028.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 12:43 9023.5 9025.0 9~12.S 9~14.0 9006,0 9~06.5 9~2.~ 9~2.0 $ REMARKS: This file contains CNTD Pass #3. The depth shifts shown above relect GRCH pass #3 %o GRCH pass #1 and NPHI pass #3 %o NPHI pass #1. $ LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB -, TYPE REPR CODE VALUE 1 66 9 . 2 66 9 3 73 44 4 66 5 66 6 73 7 65 8 68 9.5 9 65 FT 11 66 23 12 68 13 66 14 65 FT 15 66 68 16 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 506130 99 990 99 9 3 1 1 4 68 0900009009 NPHI CNTD PU-S 506130 09 900 09 0 3 1 1 4 68 0000000099 NRAT CNTD 596130 99 000 09 0 3 1 1 4 68 0900000090 CRAT CNTD 5~613~ 99 0~0 09 9 3 1 1 4 68 0000000009 NCNT CNTD CPS 596130 09 000 00 0 3 1 1 4 68 0000000090 FCNT CN'T'D CPS 5~6130 O0 000 90 9 3 1 1 4 68 0000909000 CFTC CNTD CPS 596130 09 000 99 9 3 1 1 4 68 0000000099 CNTC CNTD CPS 506130 09 909 09 9 3 1 1 4 68 9000000009 GRCH CNTD GAPI 506139 09 000 0~ 9 3 1 1 4 68 0090000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 12:43 PAGE: ___ NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS CNTD LB 506130 00 000 00 CCL CNTD V 506130 00 000 00 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 DATA DEPT. 9273.500 NPHI.CNTD 29.040 NRAT.CNTD 4.609 CRAT.CNTD NCNT.CNTD 3151.515 FCNT.CNTD 696.970 CFTC.CNTD 650.090 CNTC.CNTD GRCH.CNTD -999.250 TENS.CNTD 1205.000 CCL,CNTD 0.000 4.927 3341.375 END OF DATA ** **** FILE TRAILER ,*** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE .: 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 5 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 CNTD 1, 2, 3, $ REMARKS: The arithmetic average of passes 1,2 & 3 was computed after all depth shifts and clipping was applied. LIS Tape Veri{ication Listing Schlumberger Alaska Compu%ing Cen%er 5-SEP-1995 12:43 PAGE: 12 $ LTS FORMAT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 1 ** SET TYPE - CHAN ,* __ NAME SERV ID UNIT SERVICE API ORDER # LOG API aPI AP1 FILE NUMB NUMB TYPE CLASS MOD NUMB SAMP ELEM SIZE REPR CODE PROCESS (HEX) DEPT NPHI CNAV NRAT CNAV CRAT CNAV NCNT CNAV FCNT CNAV CFTC CNAV CNTC CNAV GRCH CNTD TENS CNTD FT 506130 00 PU-S 596130 99 596139 99 596139 99 CPS 596139 99 CPS 596139 99 CPS 596139 09 CPS 596139 99 GAPI 596139 99 LB 596139 99 999 99 9 4 999 99 9 4 1 099 99 9 4 1 999 99 9 4 1 999 99 9 4 999 99 9 4 1 099 99 0 4 999 99 9 4 1 999 99 9 4 090 99 9 4 1 1 4 68 4 68 4 68 4 68 4 68 4 68 4 68 4 68 4 68 4 68 9990999999 9999999999 ** DATA DEPT. 9272.599 NPHI.CNAV 39.975 NRAT.CNAV NCNT.CNAV 3152.964 FCNT.CNAV 637.869 CFTC.CNAV GRCH.CNTD -999.259 TENS.CNTD 1189.999 4.977 624.141 CRAT.CNAV CNTC.CNAV 5.162 3352.589 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 12:43 PAGE: 13 DEPT. 8994.509 NPHI.CNAV NCNT.CNAV -999.250 FCNT.CNAV GRCH.CNTD -999.250 TENS.CNTD -999.250 NRAT.CNAV -999.250 CFTC.CNAV 1185.000 -999.259 CRAT.CNAV -999.250 CNTC.CNAV -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER FILE NAME : EDIT .004 SERVICE : FLIC VERSION · 001C01 DATE : 95/99/ 5 MAX REC SIZE : Z024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 5 MAX REC SIZE : ~024 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 SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTD 9272.0 $ 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): 8995.0 9-AUG-95 CP42.2 943 9277.0 9275.0 8998.0 9272.0 NO g-AUG-g5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 3.2:43 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CNTD CNTD CCL CNTD CNTD GR $ TELEMETRY MODULE TELEMETRY CARTRIDGE COLLAR LOCATOR COMP. NEUTRON CART. COMP. NEUTRON GAMMA RAY ATM-AA 277 ATC-CB 442 CAl-U CNC-DA 3.46 CPSC-A-795 CGRS-A-864 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 8342.0 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): 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): 27000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO HLS BHC LOG OF 2-3.6-92. THREE PASSES LOGGED OVER INTERVAL AT 30 FPM, LOGGED ON SANDSTONE MATRIX GOC PICKED AT 9065' $ LIS FORMAT DATA PRODUCED FLUIDS -34.0 THERMAL SANDSTONE 2.65 PAGE: 3.4 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 12:43 PAGE: 3.5 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 44 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 506130 00 000 00 0 5 3. 3. 4 68 0000000000 NPHI PSI PU 506130 00 000 00 0 5 1 1 4 68 0000000000 RTNR PS1 506130 00 000 00 0 5 3. 3. 4 68 0000000000 TNRA PS1 506130 00 000 00 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 506130 00 000 00 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 506130 00 000 00 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 506130 00 000 00 0 5 1 3. 4 68 ~000000000 CFTC PSI CPS 506130 00 000 00 0 5 1 1 4 68 0000000000 GR PS1 GAPI 506130 00 000 00 0 5 3. 1 4 68 0~00000000 TENS PS1 LB 506130 00 000 00 0 S 1 1 4 68 0000000000 CCL PS1 V 506130 00 000 00 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9285.000 NPHI.PSZ 30.512 RTNR.PS1 4.857 TNRA.PS! RCNT.PS1 3292.978 RCFT.PS1 677.966 CNTC.PS1 3480.204 CFTC,PS1 GR.PS1 16.188 TENS.PS1 850.000 CCL.PS1 0.000 ** END OF DATA ** 5.106 657.167 LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 5-SEP-1995 12:43 PAGE: 16 **** FILE HEADER FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 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: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTD $ LOG HEADER DATA 9272.0 8997.0 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 9-AUG-g5 CP42.2 959 9277.0 9275,0 8998.0 9272.0 NO 9-AUG-95 TOOL NUMBER CNTD CNTD CCL CNTD CNTD gR TELEMETRY MODULE TELEMETRY CARTRIDGE COLLAR LOCATOR COMP. NEUTRON CART. COMP. NEUTRON GAMMA RAY ATM-AA 277 ATC-CB 442 CAL-U CNC-DA CPSC-A-795 CGRS-A-864 LIS Tape Verification Listing Schlumberger Alaska Computing Center ~-SEP-1995 12:43 $ 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): 8342.0 PRODUCED FLUIDS -34.0 THERMAL SANDSTONE 2.65 BLUELINE ~OUNT 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): 27000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO HLS BHC LOG OF 2-16-92. THREE PASSES LOGGED OVER INTERVAL AT 30 FPM. LOGGED ON SANDSTONE MATRIX GOC PICKED AT 906~~ LIS FORMAT DATA PAGE: 17 DATA FORMAT SPECIFICATION RECORD ,, ** SET TYPE - 64EB ,, TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 12:43 PAGE: TYPE REPR CODE VALUE 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 APl AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT . 506130 00 000 00 0 6 1 1 4 68 0000000000 NPHI PS2 PU 506130 00 000 00 0 6 1 1 4 68 0000000000 RTNR PS2 506130 00 000 00 0 6 I I 4 68 0000000000 TNRA PS2 506130 00 000 00 0 6 1 I 4 68 0000000000 RCNT PS2 CPS 506130 00 000 00 0 6 1 I 4 68 0000000000 RCFT PS2 CPS 506130 00 000 00 0 6 I I 4 68 0000000000 CNTC PS2 CPS 506130 00 000 00 0 6 1 I 4 68 0000000000 CFTC PS2 CPS 506130 00 000 00 0 6 I 1 4 68 0000000000 GR PS2 GAPI 506130 00 000 00 0 6 I ! 4 68 0000000000 TENS PS2 LB 506130 00 000 00 0 6 I I 4 68 0000000000 CCL PS2 V 506130 00 000 00 0 6 I I 4 68 0000000000 ** DATA DEPT. 9283.500 NPHI.PS2 RCNT.PS2 3172.243 RCFT.PS2 GR.PS2 14.500 TENS.PS2 DEPT. 8997.000 NPHI.PS2 RCNT.PS2 4628.736 RCFT.PS2 GR.PS2 12.836 TENS.PS2 33.204 RTNR.PS2 614.622 CNTC.PS2 855.000 CCL.PS2 19.217 RTNR.PS2 1188.042 CNTC.PS2 1185.000 CCL.PS2 5.161 TNRA.PS2 3352.604 CFTC.PS2 ~.000 3.610 TNRA.PS2 4764.393 CFTC.PS2 0.000 5.426 595.766 3.648 1209.239 END OF DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE TRAILER ***, FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 95/~9/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 5-SEP-1995' 12:43, PAGE: 19 · ~,, FILE HEADER ,*~, FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 5 MAX REC SIZE : 1~24 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header da%a for each pass in separa%e files; raw background pass in las% file PASS NUMBER: 3 DEPTH INCREMENT: ~.5~00 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTD $ LOG HEADER DATA 9272.0 8997.0 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 g-AUG-95 CP42.2 loll 9277.0 9275.0 8998.0 9272.0 100.0 NO 9-AUG-95 TOOL NUMBER CNTD CNTD CCL CNTD CNTD TELEMETRY MODULE TELEMETRY CARTRIDGE COLLAR LOCATOR COMP. NEUTRON CART. COMP. NEUTRON GAMMA RAY ATM-AA 277 ATC-CB 442 CAL-U CNC-DA 146 CPSC-A-795 CGRS-A-864 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 12:43 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 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): 8342.0 PRODUCED FLUIDS -34.0 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): 27000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO HLS BHC LOG OF 2-16-92. THREE PASSES LOGGED OVER INTERVAL AT 30 FPM. LOGGED ON SANDSTONE MATRIX GOC PICKED AT g065' $ LIS FORMAT DATA PAGE: 20 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verifica%ion Lis%lng Schlumberger Alaska Computing Cen%er 5-SEP-1995 12:43 PAGE: 21 TYPE REPR CODE VALUE 3 73 44 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT. 506130 00 000 00 0 7 1 1 4 68 0000000000 NPHI PS3 PU 506130 00 000 00 0 7 1 1 4 68 0000000000 RTNR PS3 506130 00 000 00 0 7 1 1 4 68 0000000000 TNRA PS3 506130 00 000 00 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 506130 00 000 00 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 506130 00 000 00 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 506130 00 000 00 0 7 I I 4 68 0000000000 CFTC PS3 CPS 506130 00 000 00 0 7 I 1 4 68 0000000000 GR PS3 GAPI 506130 00 000 00 0 7 1 I 4 68 0000000000 TENS PS3 LB 506130 00 000 00 0 7 1 1 4 68 0000000000 CCL PS3 V 506130 00 000 00 0 7 1 I 4 68 0000000000 ** DATA ** DEPT. 9282.500 NPHI.PS3 27.098 RTNR.PS3 4.457 TNRA.PS$ RCNT.PS3 3092.937 RCFT.PS3 693.928 CNTC.PS3 3268.789 CFTC.PS3 GR.PS3 22.781 TENS.PS3 785.000 CCL.PS3 0.000 4.686 672.639 END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE TRAILER FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 5-SEP-~995 12:43 PAGE: 22 TAPE TRAILER SERVICE NAME : EDIT DATE : 95/09/ 5 ORIGIN : FLIC TAPE NAME : gS2g2 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, PRUDHOE BAY~ D.S. 4-7 ST1, API #50-029-20189-00 REEL TRAILER SERVICE NAME : EDIT DATE : 95/09/ 5 ORIGIN : FLIC REEL NAME .: 95292 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC~ PRUDHOE BAY, D.S. 4-7 STI~ API #50-029-20189-00 't ? 7 ? 77'?'7 ?77777'?7 '/7 17 // 'i i I 1 77 !7 77 7-7 7 i777 17'! 17 17 1'7't ?'17'? ? 77 l? ?7 77 ] '7 t t'1 17 ?1 77 CCrd(' ~,~ fi C(.(_ C I.-'i:'f~P ~kP.:p: U U Pi_)DI.) H fi Uk.iO P.s_[., LEts C ~',.: (,.i I:,, f.~ (; i--' P k~' h: U i,j g D ~ fi g Li L C ,'-: M (. t~- ~: t< [! U i) I) H H (J C] b CCCC [','~ ~,,i C(:CC t-- iq h' i.,,' U U i.~ !J J'~[)DL) H ~ f)l)O k, Lgb, L .~ ,.3 ,'[' A I4. 'l -t i.t;"-,Pt-~ l-..,qi, iIO'791,t~lUS/l JUb ,,~Hj.P SF~J. If)b8 L)A]'J~, O~-b:--(.JV-80 17'30'33 "~&I'Af~I':'~ i.:,'-jl-,.H k"(.:x,t, [.1(~'?()?~fil()%/.i ~jUf-~ 5t41.[[:~ bLw. !f,,t:,8 DA]'i-', O~-?~,._JV-80 ii:30:33 f.-!(jNI.'T'I')F ~,,-~,"-; F 1,1 ~)t' 'ti) ,hi,.J'--d,'-). 1 it _i I l I i i L t .[ Ii 1.1'. II I1 [I.IJ_!i iii_Iii 1 J.l T '.[ ] t ltltjl}iti tJlJl.Jtiij[J I ~tj ij tit! {j(J l~[j l: (] fiji J [~i JUt il [Jljljlj[jij 17:~0:33 PC(.:(: PCCC 1.1 i i.J.i il Ii i 1 Jllill li/ili. ¥¥ ieba hATe-. 17:3u:i9 I 7: 3 0: 3 3 UA'It:,: a0!111 2 DATP~: 80111/ 2 ~URF-9289/ } ~,~ [.' (jI-{['4A I .I-' b. C 0 [{ D aI'[;A!".iI1C [~].CHf' J.- H [II)HLJh 151 t 1. GAP C,/C CVS, GAl-, C/C 0 ~'2 42 4z 4i2 q2 42 . ~z 0 ~8 ~4 ~4 42 ~4 ~4 A P 1. © 3 l 1 92 93 0 i t~8 0 i ~S 0 1 o.s 0 1 68 0 1 e, 8 0 I ~ 8 RT',QoO, j . )( i'd(- i,l G 14 k C PJ_J, ~U( fJ L; t~ (-' p~ [, t'.J ( i",: L, t, Ci,t); {~k iq i~ k C ?.~ l., ii C +4 .I, - 9 -9 -'9 -9 32. 16.3h2 3,2.70r.i 76,362 50. ? 65 ! F,. ~3.22~ 4. 7. ~ .3 .~ 72.~44 1 3 . t;., i,) (} ] B. 5 ]. 4 8 ;; 05. (.' ~ 2 7 i . 200 b 'l. 200 37.752 9 q. 250 9g. 25'~) q9.2b() ':~ 9..Z 5 ") i~i:~i [ G t:< P C ~.-: L l- C l'-~ L, ? C 44 GR G? 6 C i'4 P ti I P C N _b 30. 460 42.1 77 3O. 460 42.1 O0 7'! 42.560 15.3,00 81 .08! I 4.7O0 ]. 5,4':)O ] 4r-- Hi',,") '17. 400 2;'). 200 ! ~ 7.28(-) 12e.500 5 %. 7 70 1 ~. '-~ 40 7:1.100 lo2.1.62 47.66n,, Z8.4O0 39.~97 -, 99'¢. -999,250 - c; 9-;9. 250 -,999. 250 ~' ':~. 250 -99Q,.250 [4 h L b~ijl'4 lC ,, tx-:. A {QPtJ i Jq.PH i r,~ P A 'i' N Ph i i",' R A i' F.~Ph i i_, U E 3.334 9. t.,, 60 3.33~ 29.660 3.288 31.900 3.150 30.9 ,i 0 2. Ib.B' 15. 260 2.352 ~7.8 00 3.e5o 43,500 2.1 42 !3 4.034 49. '? 20 -999.250 -999,250 -999.250 -999.250 N 14 A T ~ C N .b i'4 C N b r,~ R A '1 i4 C cJ .b NH Ai i,,; C N b i~ R A T i,~ C N b {',i R A T N C ¢,i I., i~ R A VAbUt', 251.394 25 .i. 394 3.124_ 2b0,542 3.2.3o` 1o8 3ii.¢54 Z.210 31~.318 2,334 2 0 '7. o 3 ~ 3.900 34 ?..i 9 0 153.i5.3 4.13-4 -99~.250 -~Y9.250 -999.250 t-: t' (_ I i t, i.)~-~ -' 1, i~ ;'i I. P 1.1,['_ ']Pf~.[l,l~i' 8011!.1 ] 1. (_~00':')00 7777777 t71 O0000u 1 J OOO00u 7/1777'/1'!77 uOOOOu I ill O0 OU 7'1 O0 O0 I ! l i O0 O0 77 O0 O0 11 O0 O00O 77 OO 0000 I 1 O(-) 0000 7:-1 O{) 0000 I 1 00 00 0 O 77 00 00 o 0 1. I 00 00 (20 '17 00 00 0 O I 1 0000 O0 7 7 OOUO O0 1. 1 00(}0 O0 77 0000 O0 1. I 00 O u 77 00 00 I I O0 OO 77 O0 O0 / I I 111 000o00 7'7 OuO000 tllll 1. 000000 71 000000 i7 I717'1'177 17-1'77777 17 7 'I 77 77 :11 17 77 1! 77 77 -I 7 t? 'i t 222222 222222 22 22 22 22 22 22 22 22 2222222222 Z222222222 *blAt-,'l* l.~bP~t~ FCAb ll()/u/,t)0502] dub 8ttlP 6b;(a. ~()5 PAl,:t~ 20-JUL-80 1~130:59 /q(~t, ii']'lJb LSv~,,.% Fl,lOh~41 APie-.80. *81Atil* LIShl-< P('Ab 110701,~0502J dUB 8HIE' St{0. e,()5 DA'L'I~.; 2U-dUb-80 1B.'30:59 i 1 11 Ii Ii llil.[l .!.I] 11 I 6O50ATL 20,-',j {I.b_- ~0 18:23:04 ~5C H L, b £4 ~k,~ Gi:,H C Lit4 Pi.j'l~ ] N G l 0'? r} 1, Ot)SU 2 F:[.. I-_ I, tIP.AUEk 80/ 7/18 JUN Eb,CU~ D- b.I. L~ T U / 5. FbUll) CRUDP_.IRUN TtqRi:.E e, 0502 12o75 2?O1-Ti)/CASli',~G ~ TUBING l'bG OUI-,:F.-SIt3/F:.LRC.~ED WI"i'H ~0360 L, ioGGLD 4-23-/7/ w [-',1.. I, I, t:L i'J C L J F: A N SEC, C(I[I ~I'A ',,; '1 [.:; A 1_,: Gl,.; J: J.l.I ['t:.: ~[ L['" -}- {~'~ P {-J I"( ,L"I A ~r I f'l: _- h. LC b i--':. O AT'bAN'[ .I C i:).8. 4- 7 PP. UDHi. JE 15i-, 11['~ 2'/ N . AI.,A,SKA i~ ICi-tF .LLLD CU. ~ J. Zh i t!~,411.8 APl APl APl .APl FIL, W~, 5 [ZL PROC O 4 0 0 I 68 0 4 0 0 I o 8 0 4 0 0 1 e~ u o '~ 0 0 1 08 0 '1 0 0 I 68 0 '4 0 0 I 6 ~ o 4 0 0 I 68 0 't 0 0 1 08 O ~ o 0 i O8 0 4 0 0 i 08 0 4 0 0 1 0 g o 4. 0 0 1 o 8 0 '~ 0 0 1 6 ~ 0 4 {'} 0 i o 8 0 4 0 0 1 08 0 4 0 0 i 08 0 ~ 0 0 i ~ 8 0 4 0 0 1 68 0 q 0 0 l 68 0 4 0 0 1. 68 0 4 0 0 I b 8 L)EP 1 91 ~_ ()() o 0 0 :} 9o 0 (). ~}0 0 H g U 0.0 0 0 N C i,~ b 1" C N b [",1C [,~ 1~ ~ 1,' tt I i' C ~'J 1.: [q C H L, 1- C N [, [ C lq b NC a l~ GH p r:c N i, GH f C i',.I i, (j I-, NCNb (; t-4 F Cml~ J.',! C iu L: vA ? 7 l 22 1 1 22 2 1 i .400 e.94l 9. gO0 O, 000 400 b.941 O. 35e~ 0 o i) 000 000 :~. 300 0.017 6.924 1 . 3.000 15 ~8 1.5 218 251 113 15 251 20 112 .15 122 1_75 '13 41 134 29 12 1 , .805 .~340 .0 [4 o .iO0 .361 20o .6~5 .040 100 394 .80o .98~ .398 .5bO .545 .461 .758 .92o · 400 7.700 b.439 0.978 5.28O 4.700 ~ CHb m 1< A T aPitl NRAT NPH il r~pid I ~'C i'1 i_~ l~ F', a I' N P H I m };, A T NP.HI G~ NAAT i~PHl :'~ l~ H 1 N 'F, A T VAi:UL 28.4~0 57.200 22~.b09 -99q.O00 0.000 22 ~J.509 -999. 000 0.000 900 ! 3.t000 o 'l 7 ~!.022 28.0b0 31.720 14.900 230.373 3.178 28.240 2o6.409 2.308 13.940 lb.bDO 18.800 271.128 2. t84 15.280 48.520 115.200 1'12.887 3.~40 44.800 l 7.320 ?o. 100 288.288 2.344 15.22O N~AI' ~PHi NCNb NRA'[: NPNI ~PHI ~RA'i NP~I NPH 1 NCNb NAA1 NPHi f,~RA T m RAf i~Pni hPldi NCNb NIqA1 [~PH i N~AI NPHi r~CNb VAbUL 3.186 29.980 Z9.2i9 -999.000 0.000 29.980 29.219 -999.000 0.000 3.47i 29.420 33.025 09.069 3.120 3.384 30.380 3.3.i5b o5.~37 3.104 2.45o i 5. 900 24.297 I I i. 909 2.23-1 2.402 17.594 110.253 2.322 4.200 48.140 50.bSb i2.900 4.154 2.434 19.2b0 -999.250 117.11/ 2.244 NCNb N R A 1: NCNb N C N b GH FC Nb NC Nb NRA£ F Cb. Ih NCNb iq i'( A NCNb NCNb F'Ci,~b NCNb NCNb ~ C [",i i.,. NCNb fq AA 1' FCNb NC NL N C hi b NRAi NCNb VAbUL 09.069 -999.00u -999.000 O.0OO 09.009 3.2Wb -999.000 -9~9.000 0.000 3.2i0 14.900 21i.92~ 07.363 3.320 i5.900 222.z22 Dll. ?u2 1i2.398 Z.332 15.100 11~.259 lob.lOb 2.~02 2o.5o0 4.2b0 1~1.800 lbb.594 42.042 i15.401 2 t2.500 11~.972 L.,le (.,P, Gl,', t,41.-: n L -9 -9 Ab 39 44 · '] o2 o4 ,,9 (j 0 47 0!) 99 i 4. 500 25.69? 0.0{)0 '? 4. 900 j '~. ?~)~ 99. 25. 25u 250 25O 0 (.] o 250 250 r C N b f,~P H I. VAbUE bl .720 i04.247 5.082 b 0 · '400 45.820 0. 000 0o000 3.99b 21 .~00 -999.2b0 -999.250 -999.250 -999.250 -99925.000 N P H 1 -JqCN b NRAi NCNb N P,A i' .N P .H J i~CNb VALUk 5.112 6'1.'140 -999.250 i. 9./3~ 5.100 ~.218 -5.000 -9~9.250 Jl.317 -999.250 -999.250 -999.250 -999.250 2.300 NN ['.MUN lC NCNb NRA1: GR NCNb l~ k A 'r GM NC[~L NCNb GR NCNb VAbU~ i9.7~a} ~i .bOo j 9. ~()5 33.033 O.OoO 1 ~;9.987 -999.250 -9~W.250 -999.250 -999.250 -99~,2b0 .~ .LI~E JI4AJL, P? 1' A P J~ Oj 8O/ '/-i !77!?i77 777 t ? 777'?'7 7i ?7 71 77 17 7'7 77 Ii !7 7? '! 7 17 5555655555 5555~$ 555555 55 55 -55 55 55 555555 555555 G (..:, G c-., ~t ii b !- ', ~", r,_~ t:'t:~.' ? }q P: F:,. A tj U L)i/,'[) D H ii LJi30 -~5fX.',l ~ tt,'5.'r;r. 1-'(:/~] I_'l_Ol,,)'t,b;lO'lbj ~it.!b iSiii. P ~LO. 4f, 45 OAi:L 27-'-!.~DV-79 ,I".!'}!-! ]. Ilij.-' ~¥'..[) ,,I,i OJ-. 3q dill,- /':~. }'~-~'l~ttl',t t.~51-}", t'C~I.~ !.tO?O/,5tO-!5J ~.iiJb ~'.SHj[.:' ~Sh,(::~. ~,h45 i)ATL 27--i,;LiV.-'!9 1-'4:3i:i7 !,iijK, J }Jib dA'bi ..K.[,1 (,j.,~ 1, dlJl_,--']].. (b,j.',a,~']'-{, ii j i i] J1 lj i.i J[ .[ l ii. I! ']ii'!'!"l I j i"l' ~_II! i1' ii(i 'i' -I [.j [ I J_] iJji 'i' I I I' ii '1' !)l)l Ii J( Lt i..! ! I,._j I i.i i-:iq H,J j.;: h', h' ? i~ H 14 j4 . . Iff 791!.i12i E _1 j.,!, rik ,fi ')j-.i.-: .;,~2 ;) 32 3 9_3 A P .- . . ;'"' w F' H I 020 3 i. ! 80 i r>. 920 1 ,12. l-ciO - 9} U) q 2 5. o 00 tx B A i' i,.~ k A T VAbUE 3.962 -999. ~50 iq C iq L, i:.~ C iq L, iX C ..i',i b N C i'q [~ V A L; U ~ 226.941 229.515 2~i.855 lib. Bbi -99~.2b0 tr ! _1,1:' ! t /", i l,ht-' ,'s'i'i.,,L'~.""~ l' LC i-;, i.C.hP Lk.t.,L) C'L~. 1 I ( '1 (JtJl, .50O 70.5 40 -5. 000 -99925. o0o f,i K A i ,'4 R A 1 3.2u2 3.3'78 2.378 .$. 106 ~.322 0.0 0 0 0.00 0 M i,~ g iq!j N lC N C w L, N C iq b ':'~ C N b V Ab (.j k: 22u. 50~_, Z2~.509 2',bb. 551 705 I 03.3~9 U.UUO ;:.!k..X~l' btL[' C 79/1
