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Home My WebLink About182-087 Ima.(~'roject Well History File CoverOige XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ,Z '_~ ~_dc"Jwell History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [3 Color items: [] Diskettes, No. [] Maps: [] GraVscale items: [] Other. No/Type [] Other items scannable by large scanner J~ Poor Quality Originals: OVERSIZED (Non;Scannable) [] Other: [] Logs of various kinds NOTES: [] Other BY: BEVERLY ROBIN VINCEN~ MARIA WINDY DATE:~'/¢.~ IS~ Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE; Is~ Scanning Preparation x30= + / = BY: BEVERLY ROBIN~HERYL MARIA WINDY Production Scanning Stage '1 PAGE COUNT FROM SCANNED FILE: BY: Stage 2 BY; PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~/* YES BEVER' V,NOEN S.ERYL MA,,A W,NDY IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BEVERLY ROBIN VINC~ MARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) NO ReScanned findivtdual page [,~peciel atze~tiot~] scalming c~mpieted) .NO RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/t 0/02Rev3NOTScanned.wpd STATE OF ALASKA ,.Sy~a~~~ ALASK~L AND GAS CONSERVATION COM~SION WCI 1 l~A~ADI CTIAAI AD DCf`A~1D1 CTIAI-1 DCD~IDT AIU11 1 A~`_ ~~~'~'~® "t `~ ?_009 .....,,. _.x ~:~~~~ <~it5. Commission k 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAACZS.1os zoAACZS.tto ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b. Well Class: ~ ' ®Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 4/17/2009 12. Permit to Drill Number 182-087 ' 309-034 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 05/22/1983 13. API Number 50-029-20757-00-00 - 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 06/02/1983 14. Well Name and Number: PBU 14-23 ' 1401 FNL, 2017 FEL, SEC. 09, T10N, R14E, UM Top of Productive Horizon: 2281' FSL, 2855' FEL, SEC. 04, T10N, R14E, UM g KB (ft above MSL): 72' - Ground (ft MSL): 42.06' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2475' FSL, 2913' FEL, SEC. 04, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 6510' 5859' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 674460 y- 5938921 Zone- ASP4 10. Total Depth (MD+TVD) 10440' - 9227 - 16. Property Designation: ADL 028312 ' TPI: x- 673540 y_ 5942545 Zone- ASP4 Total Depth: x- 673464 y- 5942776 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No mi I ronic an rin i f rrrl n r 20 AA 25. 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIL / SP / BHCS / GR, FDC / CNL / GR /CAL, CBL, GYRO 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-4 Surface 81' Surfa 1' 37 x P rmafros II - / " 2 1 xF n F' ' -5/ " 47# L-80 urf 7 rf 613' 1 -1/4" 50o sx ciass'G', 313 sx PF'C', & 857 sx'G' 7" 2 144 ' S' 9227' -112" 3 0 sx Cla s' ' -1/ " L- 4 1 1' 4' / 1 R 23. Open to production or inject ion? ^ Yes ®No 24. TuelNC RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): .SIZE DEPTH SET MD PACKER .SET MD 5-1/2", 17#, L-80 9434' Cut at 7000' MD TVD MD TVD 4-1l2", 12.6#, L-80 9434' - 9524' 9445' \/ ~^ ~F~ ~(I(}~ ,~, ~a~ ~~ !b~ 11 f- l1tJ 25. ACID, FRACTURE,. CEMENT SQUEEZE, ETC. ~ ` DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 9496' Set Cement Retainer 9304' P&A w/ 21.4 Bbls Class 'G' (Run 9-5/8"Tieback to -1995', Cmt w! 137 Bbls / 1.17 Yield) 6510' (TOW) Set EZSV (6546') w/ Whipstock on Top (6533') 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac uired? ^ Yes ®No 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 250.071. None ~ ~ ~p Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE , i... J ~ R~~`~ i ~ 2009 C 28. GEOLOGIC MARKERS (LIST ALL FORMATfONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested . Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 9769' 8602' None Shublik 9797' 8628' Sadlerochit 9874' 8699' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. tee/ Si d W ~~ ~ gne Title Drilling Technologist Date Terrie Hubble PBU 14-23 182-087 309-034 Prepared ey Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A rOVal NO. Drilling Engineer: John Rose, 5645271 INSTRUCTIONS GeNew-~: 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. treM 28: Provide a listing of intervals tested and the corresponding formation, snd a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • 14-23, Well History (Pre Rig Sidetrack) Date Summary 02/13/09 WELL S/I ON ARRIVAL. DRIFT W/ 4.62" G-RING TO DSSSV C~ 2,129' SLM (2,151' MD). ATTEMPTING TO PULL 5-1/2" DSSSV FROM 2,129' SLM. 02/14/09 PULLED 5-1/2" DSSSV ON DB LOCK ~ 2,129 SLM (2,151' MD). DRIFT W/ 3.63" CENT & 3.50" LIB & S/D Q 9,440' SLM (IMPRESSION OF WHAT APPEARS TO BE FILL). RIH W/ 10' x 3" P-BAILER TO 9,440' SLM (RECOVERED SMALL AMOUNT OF SAND AND PC, METAL MARKS ON FLAPPER). RIH WITH 3.625 CENT, 3' 1 7/8 STEM, 3.805 CENT AND 3.70 LIB.S/D AT 9,440' SLM. (METAL MARK ON LIB). PULLED 2.50" IBP FROM 9,439' SLM / 9,470' MD (DID NOT RECOVER RUBBER ELEMENTS OR STIFFNER RING W/IBP). ATTEMPTING TO FISH IPB RUBBER ELEMENTS &STIFFNER RING. 02/15/09 FISH PIECES OF IBP RUBBER ELEMENTS AND STIFFNER RING W/ASSORTMENT OF WIRE GRABS AND BAILERS FROM 9,488' SLM. 02/16/09 FISH PEKES OF IBP ELEMENTS. DRIFTED W/ 2.78 CENT. AND 2.66 2 PRONG WIRE GRAB TO 10,050' SLM. ROCK SCREEN APPEARS TO BE GONE. WELL LEFT S/I. DSO NOTIFIED OF VALVE POSITIONS. 02/21/09 T/I/O = 180/40/240. Temp = SI. TBG & IA FLs pre RWO. TBG FL @ 130' (4 bbls). IA FL Q surface. Integral installed on IA. SV, WV = C. SSV, MV = O. IA & OA = OTG. NOVP. 02/23/09 T/I/0=300/150/240 Injectivity Test (Pre SDTRCK) Loaded Tbg with 5 bbl meth spear, 250 bbls 1 %KCL. Slowed rate and established Injectivity rate of Vac ~ 1 bpm. 0 psi ~ 2 bpm, 370 psi ~ 3 bpm. Let well settle out. Pump back online Q 3 bpm. IA tracking with Tbg 3 bpm @ 450 psi, 2 bpm Q 300 psi, 1 bpm C~ 80 psi. FW HP's = 0/200/260. Swab, W ing, SSV =shut. Master, IA, OA =open. 03/13/09 T/IA/OA =SSV/0/0 Temp =cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RST). PPPOT-T RU 1 HP BT onto THA test void 850 psi to 0 psi. Pressured to 5000 psi for 30 minute test, 4950/ 15 minutes, 4950/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycle LDS "Standard" all were in good working and visual condition. PPPOT-IC RU 1 HP BT onto IC test void, 50 psi to 0 psi. Pressured to 3500 psi for 30 minute test, 3450/ 15 minutes, 3450/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycle LDS "Standard" all were in good working and visual condition. 03/14/09 WELL S/I ON ARRIVAL. INITIAL T/I/O = 0/125/250. MASTER OPEN, WING CLOSED, CI CLOSED, HARD LINE CLOSED, SSV CLOSED IA/OA = OTG. RU ELINE, HOT CHECK. 03/15/09 RIH, 1.56" TUBING PUNCHER /CCL. INTERVAL 9438' - 9441', CCL TO TOP SHOT = 7.6', CCL STOP DEPTH = 9430.4'. FINAL T/I/O = 0/110/190. MASTER OPEN, WING CLOSED, SSV CLOSED, HARD LINE CLOSED, CI CLOSED, IA/OA = OTG. JOB COMPLETE. 03/20/09 MU WOT 3.771" drift. PT lubricator & surface lines. Open well, RIH. 03/21/09 RIH with 3.771" drift, tagged TOL Q 9495' CTM. PU 50' to 9445', flagged pipe. POOH. OOH with drift. Cut CC, MU BHA with 3.5" WOT cement retainer. PT tool string. Go to well with lubricator. RIH w/ retainer. Find bad spot in coil Q 5114', 72% wall remaining. POOH. Freeze protect wellbore w/ water/meth. Blowdown reel w/ N2. Go to shop for pipe repair. 03/27/09 Perform BOPE test. MU 3.58" OD Weatherford cement retainer. Bullhead kill well with 310 bbls 1% KCL. RIH with 3.58" OD Weatherford cement retainer. Depth correlate at liner top. Set cement retainer mid-joint at 9496' MD. 03/27/09 Heat Uprights for CTU (Pre SDTRCK) Heated Uprights 085, 087, and 089 from 50-65°F to 120°F. Notified Coil Tubing Supervisor of Upright status, SLB in control of uprights and well upon departure. Page 1 of 2 14-23, Well History (Pre Rig Sidetrack) Date Summary 03/28/09 Attempt to circulate down backside and up IA, returns are 70% and waning. Attempt to bullhead into well, develop stem leak at IA gate valve at 1000 psi IAP. Service IA gate valve. Load IA with 230 bbls KCL, 366 bbls diesel and cap with 48 bbls 60/40 methanol/water. Load tubing with 210 bbls KCL, 196 bbls diesel, and cap with 14 bbls 60/40 methanol/water. Pump 1 %KCL down coil tubing through retainer to warm coil and cool sump. 03/29/09 Pump 241 bbls KCL down coil through retainer to warm coil and cool sump. Pump a total of 21.4 bbls 15.8 ppg class G cement as follows: Pump 9 bbls cement through retainer at 9496' MD. Unsting from retainer and lay-in/circulate 4 bbls cement in tubing and 6 bbls cement in IA, squeezing 2.4 bbls cement through leaking production packer. Built -300 psi squeeze pressure on production packer. Pull to surface keeping hole full with 60/40 methanol/water. Approximate TOC in tubing and IA is 9304' MD. RDMO. Job complete. 03/30/09 WELL S/I ON ARRIVAL. TAGGED TOC W/ 4.50" DRIFT C«J 9,355' SLM, W/ NO PROBLEMS. CMIT TxIA TO 2,160 psi (fail). WELL S/I ON DEPARTURE, NOTFIED DSO OF WELL STATUS. 03/30/09 T/I/0=1680/1660/200 Temp=Sl CMIT TxIA PASSED to 2160 psi (Pre SDTRCK) Pumped 1.2 bbls of amb meth down IA to reach 2160 psi for CMIT TxIA. Tbg gained 20 psi, IA lost 40 psi in the 1st 15 mins, T/I lost 20/0 psi in the 2nd 15 mins fora 0/0 psi loss in 30 min test. Bleed back (- 7 bbls). Final Whp's=480/470/200. Wing shut, Swab shut, SSV open, Companion shut, Master open and casing valves open to gauges. 03/30/09 WELL SI ON ARRIVAL. (ELINE JET CUT TUBING) INITIAL T/I/O = 430/650/200 PSI. RIH 4.15" SLB POWER CUTTER. TIED INTO TUBING TALLY. CUT 5-1/2" TUBING MID JOINT AT 7000'. WELL SI ON DEPARTURE. FINAL T/I/O = 300/500/200. JOB COMPLETE. 03/31/09 T/I/0=0/0/150. Temp=Sl. assist Hot Oil w/CMIT T X IA. (Post TBG Cut, Pre-RWO). Maintaining open bleed on OA. Cellar water is inflowing @ about 1 gallon per minute, top of SC is frozen and clear fluid is leaking out from the ice at the 12 O'clock position. Sample taken of SC Fluids. Bled OAP from 150 psi to 0 psi in 5 hours 30 minutes. LP gauge shows 0 psi but a whisper can be heard in the slop trailer. Cellar water is inflowing, No apparent change in flow rate. Hot Oil pressured up to 1280 psi for the combo and suddenly lost 60 psi to 1220 psi, pressure won't hold above 1240 psi now. LLR shows 1.5 bbl C~ 1500 psi. Cellar water inflow has stopped, no fluid for 2 hours. Hot oil is bleeding WHP's to 0 psi. Leaving Location, Hot Oil is in control of the well. 03/31/09 T/I/0=360/350/200 Circ. Out (RWO Prep) Pump 5 bbls meth, 752 bbls 1 % kcl, 1 bbl meth, 147 bbls diesel, 1 bbl meth down tbg taking returns up IA to 14-24 flow line. (14-24 flowing) Freeze protect hardline jumper w/1 bbls neat, 10 bbls diesel. U-tube diesel for approx. 1 hour. Bleed TxIA to 0 psi bleed OA to 100 psi turned to gas. FWHP's = 0/0/100 SV, WV = S SSV, MV = O IA, OA = OTG. DSO notified of wellhead status tags hung C~ dep. 03/31/09 T/I/0=0/80/200 temp= S/I. Post Circ CMIT TxIA to 1500 psi. Standby for DHD to bleed down OA pressure. 04/01/09 CMIT TxIA PASSED to 1400 psi. Pumped 60 bbls diesel down Tbg to reach test pressure. 1st 15 min lost T/I 40/40 psi, 2nd 15 min lost T/I 20/20 psi for a total loss of T/I 60/60 psi in 30 min. Bled back pressure. FWHP = 0/0/0 Swab, Wing =Closed. SSV, Master, IA, OA =Closed. 04/01/09 T/I/O=0/0/0 CMIT TxIA 1500 psi (pre rwo) Pumped 30 bbls DSL down IA in attempt to MIT. Pressured T/IA to 1500/1450 psi in 14 bbls. Ran LLR test for 15 min (16 bbls) (1.1 bpm ~ 1500/1450 psi). Bled WHP's to 0 psi. FWHP's = 0/0/0 Tags hung. SV, CV & WV = S/I. SSV & MV =Open. IA & OA open to gauges. 04/02/09 T/I/0= 0/0/0 Set 5 1/8 Gray k BPV thru tree pre 9ES. 1-2' ext used tagged C~ 102. No problems. 04/02/09 /I/O =BPV/0/5. Temp = SI. Monitor fluid in conductor. Fluid in conductor is frozen. There is a frozen puddle of fluid in the cellar from the 12:00 psoition to the 2:00 position extending out about 2'. SV, WV, MV = C. SSV = O. IA, OA = OTG. NOVP. Page 2 of 2 • BP EXPLORATION Page 1 of 17 Operations Summary Report Legal Well Name: 14-23 Common Well Name: 14-23 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date 'From - To Hours ~ Task Code NPT } 4/5/2009 00:00 - 08:00 8.00 MOB I N WAIT 08:00 - 11:30 I 3.501 MOB I N 11:30 - 14:30 I 3.001 MOB I P 14:30 - 17:30 ~ 3.00 MOB ~ P 17:30 - 00:00 6.501 WHSUR ~ P 4/6/2009 100:00 - 06:30 I 6.501 WHSUR I P 06:30 - 10:00 I 3.501 WHSUR I P 10:00 - 16:00 I 6.00 I W HSUR I P 16:00 - 21:30 ~ 5.50 ~ BOPSUFj P 21:30 - 00:00 I 2.501 BOPSUR P 4/7/2009 00:00 - 01:30 1.50 BOPSU~ P 01:30 - 06:30 5.00 BOPSU P 06:30 - 07:00 0.50 BOPSU~ P 07:00 - 08:30 1.50 BOPSU P 08:30 - 11:00 2.50 BOPSU P WAIT Spud Date: 5/22/1983 Start: 4/5/2009 End: 5/2/2009 I Rig Release: Rig Number: 9ES Phase Description of Operations PRE PJSM. Waiting on pad prep on DS14. Finish rigging up bridle lines, unplug top drive. Disconnect pits from rig sub. PRE Waiting on Peak trucks to separate pit module and move rig off well. PRE Pull pits away from rig sub. Move pits from DS06 to DS14. DS14 location still being prepped; leveling gravel in prep for rig arrival on DS14. Lay down derrick -13:OOhrs. PRE Move rig sub from DS06-14A to DS14-23A down Spine road. Rig on location @ 17:30hrs, 4/5/09. Lay herculite. DECOMP Lay rig mats. Jockey rig over well and raise derrick. Rig up rig floor. Rig accept @ 18:OOhrs, 4/5/09. Accept adjusted for pad prep wait time. DECOMP PJSM. Finish spotting rig over 14-23A. Bridle up and raise derrick. Spot pits and connect to sub. Take on seawater, raise cattle chute, connect kelly hose, move cuttings tank to DS14. LRHOS on location, prep for hookup to test barriers. DECOMP RU LRHOS to test IA/OA. Pressure up to 2000psi to test OA. OA bled off 50psi in first 15min, 30psi in second 15min; good test. Bleed off in second 15min can be attributed to thermal stabilization (since it's less than 50psi), resulting in a good pressure test. Pressure test IA; pump 6.8bbls to pressure to 1200psi. Once 1200psi reached, pressure started to bleed off. Pump an additional barrel with no pressure increase; failed IA pressure test. RD LRHOS. DECOMP RU DSM and pressure test lubricator to 1000psi. Pull BPV and RD DSM. RU to circulate out diesel. Reverse circulate 350psi ~ 4bpm to displace diesel from the tubing. Pump Safe-Surf-O Pill surface to surface @ 700psi C~ 6bpm. Displacement with warm seawater; monitor 13-3/8" by 9-5/8" annulus for pressure build during displacement and bleed off pressure to bleed trailer. DECOMP Set BPV with DSM; install dart valve. Test above to 3500psi and from below to 1000psi for 5min. Chart test; good. ND tree, NU BOPS and RU to test. Hanger threads 5-7/8" ACME; 19.5 turns. Noticed fresh water flowing from 20" x 13 3/8" annulus, test weight - 8.3 ppg and chlorides - 1,200, determined it is fresh water. ADW HSE advisor came out and checked for hydrocarbons. DECOMP Function test blind rams; check for debris. Install turn buckles and mouse hole. Fresh water currently flowing out of conductor pipe @ 2-4bph. DECOMP PJSM. RU riser, prep for BOP testing. DECOMP Pressure test BOPE and surface equipment to 250psi low, 3500psi high for 5min each. Chart all tests. Test witnessed by AOGCC rep Bob Noble, WSLs Amanda Rebol, Joey LeBlanc, Toolpusher Roy Hunt, and Toolpusher Charlie Henley. Test 3-1/2" x 6" variables with 4" and 5-1/2" test joints. Tested Hydril with 4" test joint. DECOMP Rig down test equipment and blow down lines. DECOMP Rig up to pull 5-1/2" completion tubing from _7000'. DECOMP PJSM. Dry rod blanking plug as per Cameron rep. Rig up DSM lubricator and extension. Test to 500 psi - OK. Pull BPV. Rig down DSM. Steam wellhead for 1 hour prior to upcoming tubing Printed: 5/4/2009 11:44:16 AM • • BP EXPLORATION Page 2 of 17 Operations Summary Report Legal Well Name: 14-23 Common Wel! Name: 14-23 Spud Date: 5/22/1983 Event Name: REENTER+COMPLETE Start: 4/5/2009 End: 5/2/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 9ES Rig Number: 9ES Date From - To 4/7/2009 08:30 - 11:00 11:00 - 13:00 13:00 - 14:30 14:30 - 15:30 15:30 - 00:00 4/8/2009 100:00 - 03:00 Hours ~I Task 'Code NP 2.50 BOPSU P 2.00 PULL P 1.50 PULL P 1.00 PULL P 8.50 PULL P 3.001 PULL I P 03:00 - 10:30 ~ 7.50 ~ PULL P 10:30 - 11:30 1.00 PULL P 11:30 - 14:30 3.00 FISH P 14:30 - 17:30 ~ 3.00 ~ FISH ~ P 17:30 - 18:30 I 1.001 FISH I P 18:30 - 20:00 I 1.501 FISH I P 20:00 - 21:00 1.00 BOPSU P 21:00 - 22:30 1.50 BOPSU P 22:30 - 00:00 I 1.501 BOPSURN I SFAL 4/9/2009 00:00 - 01:00 1.00 BOPSUFjN SFAL 01:00 - 04:00 3.00 CLEAN P i T Phase Description of Operations DECOMP pull. DECOMP PJSM. Rig up to pull tubing hanger. Back out LDS. PU landing joint. MU to hanger with 19.5 RH turns. Attempt to unseat hanger with 305k. No go. Steam well head and pump cool water down tubing. Still no go. Lay down landing joint. DECOMP Wrap wellhead in herculite. Steam for 1 hour. Make up Baker spear. Spear into hanger and pull off seat with 275k. Up weight 160k. DECOMP Circulate bottoms up at 460 gpm with 1050 psi. Rig up Camco spooler while circulating. DECOMP PJSM. Pull and lay down 5-1/2", 17#, L-80, LTC-M tubing from -7000' with control line. Up weight 160k, down 120k. Control line coming out deteriorated and in pieces. At 50 joints out control line balled up in stack. Tubing hung up at Bal-O valve with 225k up. Make up to top drive. No up and no down. Could not circulate or turn pipe. Drain stack lubricate pipe. Close bag and pressure up on IA to 2600 psi. Slack off and free up pipe. Bleed off pressure. Open Hydril and attempt to circulate - no go. Recovered 3 SS bands and 23 clamps. DECOMP PJSM. Work pipe with 25k over and full down weight. Rotate at 6 to 19 rpm with 3-4k torque. Establish circulation at 84 gpm with 200 psi. Work pipe up and pull free. Pull Bal-O valve to rig floor. Break and lay down. Pull 2 joints with no rotation or pumps. Shut down and lay down Camco spooling unit with approximately 400' of control line. DECOMP Continue to pull 5-1/2", 17#, L-80, LTC-M tubing and lay down. Recover 166 joints, 1 Bal-O valve, 3 GLM's, 25 clamps, 3 SS bands and 1 cut joint of 18.22'. DECOMP Rig down handling equipment. DECOMP PU/MU fishing grapple. Work through stack. Only able to recover a few small pieces of control line from wellhead. DECOMP Make up flat bottom mill. RIH, rotate and circulate at 40 rpm with 1.5k torque, pumping at 460 gpm with 275 psi. Up, down and RT weight 43k. Pump hi-vis sweep and recover a few small pieces of control line. Still unable to clear out stack and wellhead. DECOMP Hold safety meeting with Paul Forman to discuss decision to shut down Nabors 2ES. DECOMP Pump hi-vis sweep through secondary kill line at 575 gpm with 800 psi. RIH with mill. Push control line debris down through wellhead. Rig up stack flushing tool. Function rams and flush out stack. DECOMP Rig up to test bottom rams. Suck out stack. Make up 4" test joint and run in test plug. DECOMP PJSM. Test lower 2-7/8" x 5" variable rams to 250 psi low, 3500 psi high as per AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Roy Hunt. Test with 4" test joint. DECOMP Lock down screw on test plug would not back out. Cameron hand making repairs. DECOMP PJSM. Repair lock down screw on tubing spool. DECOMP PJSM. PU and make up cleanout BHA. PU mill, bit sub, upper mill, bumper sub, jars, 9 collars and 1 HWDP. Attempt to break circulation. Pressure up with no circulation. Printed: 5/4/2009 11:44:16 AM • • BP EXPLORATION Page 3 of 17 Operations Summary Report Legal Well Name: 14-23 Common Well Name: 14-23 Spud Date: 5/22/1983 Event Name: REENTER+COMPLETE Start: 4/5/2009 End: 5/2/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: ,Rig Name: NABOBS 9ES Rig Number: 9ES Date ~~ From - To Hours II Task Code NPT Phase Description of Operations _. _ _ _ ,__ 4/9/2009 ~ 04:00 - 04:30 ~ 0.50 (CLEAN P DECOMP POOH. Check string. No obstruction in bit. Run back in hole. 04:30 - 06:30 2.00 CLEAN P 06:30 - 08:00 1.50 CLEAN P 08:00 - 10:00 2.00 CLEAN P 10:00 - 10:30 I 0.501 CLEAN I P 10:30 - 12:00 1.50 CLEAN P 12:00 - 12:30 0.50 CLEAN P 12:30 - 14:00 1.50 CLEAN P 14:00 - 14:30 0.50 CLEAN P 14:30 - 16:00 1.50 CLEAN P 16:00 - 17:00 1.00 CLEAN P 17:00 - 20:00 ~ 3.001 CLEAN I P 20:00 - 21:30 I 1.501 CLEAN I P 21:30 - 00:00 2.50 CLEAN P 4/10/2009 00:00 - 01:00 1.00 CLEAN P 01:00 - 01:30 0.50 CLEAN P 01:30 - 02:30 1.00 CLEAN P 02:30 - 03:30 1.00 EVAL P 03:30 - 09:00 5.50 EVAL P 09:00 - 19:30 ~ 10.50 ~ EVAL ~ P 19:30 - 21:30 2.00 DHB P 21:30 - 22:00 0.50 DHB P 22:00 - 00:00 2.00 DHB P 4/11/2009 00:00 - 01:00 1.00 DHB P 01:00 - 02:00 I 1.001 DHB I P 02:00 - 03:00 1.00 DHB P 03:00 - 05:00 2.00 DHB P 05:00 - 05:30 0.50 DHB P 05:30 - 08:30 I 3.001 DHB I P 08:30 - 09:30 1.00 DHB P 09:30 - 11:00 1.50 STCTPL P 11:00 - 12:30 1.50 STCTPL P Break circulation with no problem. DECOMP PU HWDP and 4" drill pipe. RIH. DECOMP PJSM. Cut and slip 150' of drilling line. DECOMP RIH picking up 4"drill pipe to 859'. Wash and ream at 210 gpm with 100 psi, rotating at 100 rpm with 2k torque. WOB 5-20k. DECOMP Pump hi-vis sweep surface to surface at 420 gpm with 410 psi. Up weight 78k, down 73k, RT 75k. Rotate at 100 rpm with 1 k torque. DECOMP RIH picking up 4" drill pipe to 1528'. DECOMP Pump hi-vis sweep at 400 gpm with 450 psi. Up weight 87k, down 83k, RT 85k. Rotate at 20 rpm with 1 k torque. DECOMP RIH picking up 4" drill pipe to 3056'. Up weight 108k, down 103k. DECOMP Pump hi-vis sweep at 520 gpm with 825 psi. RT weight 105k. Rotate at 20 rpm with 1 k torque. DECOMP RIH picking up 4" drill pipe to 4489'. Up weight 125k, down 110k. DECOMP Pump hi-vis sweep at 520 gpm with 1200 psi. Rotate at 20 rpm with 2k torque. RT weight 120k. DECOMP RIH picking up 4" drill pipe. Tag up on tubing stub at 6987' with 20k down. Rack back 2 stands drill pipe. Up weight 165k, down 135k. DECOMP Circulate hi-vis sweep surface to surface at 515 gpm with 1350 psi. Pump dry job. Small pieces of control line back on sweeps. Seawater in and out 8.5 ppg. DECOMP POOH to 1146'. DECOMP PJSM. POOH to 31'. DECOMP Lay down mill clean out assembly. Upper string mill in gauge. DECOMP Clear and clean floor. DECOMP Hold PJSM with SCH E-Line and crew. Rig up E-line unit. DECOMP Make gauge ring and junk basket run on E-line. Pulling tight off bottom, control line debris in baskets. Re-run GR/JB. Recover 1 cup of small metal pieces. DECOMP Run USIT in corrosion mode and cement mode from 7000' to surface. Estimated top of cement at 2058'. DECOMP Lay down USIT tools. PU tools for EZSV run. DECOMP Make up GR/CCL, firing head and 9-5/8" EZSV. DECOMP RIH with 9-5/8" EZSV on E-line. DECOMP PJSM. Run and set EZSV on E-Line. Top of plug at 6546' W LM, 4' above collar at 6550'. POOH. Begin rigging down. DECOMP Test against EZSV to 3500 psi for 30 charted minutes. Continue to rig down E-line while conducting test. Test - OK. No pressure loss over 30 minutes. DECOMP PU RBP. Rig up to run plug. DECOMP Run RBP to 2160'. Set plug. DECOMP Test RBP to 2000 psi for 10 minutes - OK. No pressure loss. Displace seawater with 9.8 ppg brine at 490 gpm with 500 psi. DECOMP Pull up and dump 2200 Ibs of sand on top of RBP. Brine weight in and out 9.8 ppg. DECOMP POOH and lay down RBP running tool. DECOMP PJSM. PU and MU 9-5/8" casing cutter assembly to 10'. DECOMP RIH with cutter assembly picking up 4" drill pipe to 1059'. Printed: 5/4/2009 11:44:16 AM BP EXPLORATION Page 4 of 17 Operations Summary Report Legal Well Name: 14-23 Common Well Name: 14-23 Spud Date: 5/22/1983 i Event Name: REENTER+COMPLETE Start: 4/5/2009 End: 5/2/2009 ',Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 'Rig Name: NABOBS 9ES Rig Number: 9ES Date 4/11 /2009 ~' From - To Hours Task Code NPT .Phase 12:30 - 13:00 13:00 - 14:00 14:00 - 19:00 0.50 STCTPL P 1.00 STCTPL P 5.00 I STCTPL I P 19:00 - 21:00 2.00 STCTPL P 21:00 - 22:00 1.00 STCTPL P 22:00 - 22:30 0.50 STCTPL P 22:30 - 23:00 0.50 STCTPL P 23:00 - 00:00 1.00 STCTPL P 4/12/2009 00:00 - 01:30 1.50 STCTPL P 01:30 - 11:00 9.50 STCTPL P 11:00 - 12:30 1.50 STCTPL P 12:30 - 14:00 1.50 CLEAN P 14:00 - 15:30 1.50 CLEAN P 15:30 - 16:30 1.00 CLEAN P 16:30 - 17:30 1.00 CLEAN P 17:30 - 18:00 0.50 CLEAN P 18:00 - 18:30 0.50 CLEAN P 18:30 - 19:30 1.00 CLEAN P 19:30 - 21:00 1.50 CLEAN P 21:00 - 21:30 21:30 - 22:30 22:30 - 23:00 23:00 - 00:00 0.50 CLEAN P 1.00 CLEAN P 0.50 CLEAN P 1.001 CASE 1 P 4/13/2009 100:00 - 01:00 I 1.001 CASE I P Description of Operations DECOMP RIH to 2014'. Rig up LRS. DECOMP Locate collar at 2014'. Space out. Pull up to 1992'. Up weight 70k, down 65k. Establish rotation at 100 rpm with no flow and 1200 fUlbs torque. Shut down rotary and establish circulation at 200 gpm with 600 psi. Rotate at 85 rpm pumping at 200 gpm with 650 to 700 psi. Make cut and see pressure drop to 485 psi, rotate additional 10 minutes. Shut down. Fluid trying to U-tube up OA. Shut in. DECOMP PJSM. Pump 5 bbls diesel with LRS. Pressure test lines to 3000 psi - OK. Pump 14 bbls of 130 degree diesel down drill pipe. Shut hydril. Open annulus to outside holding tank. Pump another 131 bbls of 130 degree diesel at 2 bpm with 300 psi. Pump 40 bbl hi-vis pill followed by 40 bbl Safe-O-Surf pill. Spot in OA and shut down. Let soak while mixing another 40 bbl hi-vis pill. Pump at 126 gpm with 140 psi until diesel out of annulus. Kick pumps up to 252 gpm with 670 psi and displace pills with 9.8 ppg brine. Shut down. Monitor well -static. Brine weight in and out 9.8 ppg. DECOMP POOH and lay down cutter assembly. DECOMP Rig up casing handling equipment and 9-5/8" spear. DECOMP Make up 9-5/8" spear assembly. DECOMP RIH and engauge 9-5/8" casing with spear. Work up with 125k, 175k and 200k. Come free on 3rd pull at 200k. Pull with 122k up. DECOMP Circulate at 252 gpm with 60 psi. Rig up for pulling casing while circulating. DECOMP PJSM. Rig up to pull 9-5/8" casing from cut at 1992'. DECOMP Pull 9-5/8" casing from 1992'. Lay down 9-5/8" spear assembly. Break out joints 1-10 with 21 to 55k fUlbs. Joints 11-48 broke with 20k fUlbs. Recovered 48 full joints, one cut joint at 14.09', 10 centralizers, 1 piece of a centralizer and 1 hanger. Casing in good condition. DECOMP Rig down casing handling equipment. Clear and clean floor. DECOMP PJSM. Install wear bushing. Make up magnet assembly to 20'. DECOMP RIH and tag 9-5/8" stub at 1993'. DECOMP Pump 40 bbl Safe-O-Surf at 483 gpm with 675 psi. Up weight 75k, down 75k. Brine weight in and out 9.8 ppg. DECOMP Pull out of hole to 20'. DECOMP Lay down magneUscraper assembly, centralizer still in well bore. DECOMP PU 9-5/8" dress off assembly to 26'. DECOMP RIH to 1912'. DECOMP Wash down to 1993'. Dress off 9-5/8" stump pumping at 252 gpm with 230 psi. Rotate at 60 rpm with 1-3k torque. WOB 5-20k. Rotary weight 75k. Check stump with and without pump - OK. DECOMP Circulate BU at 588 gpm with 575 psi. DECOMP POOH with dress off assembly. DECOMP Lay down dress off assembly from 26'. Small amount of metal shavings in boot baskets. DECOMP PJSM. Rig up to run 9-5/8", 47#, L-80, Hydril 563 casing to 1993'. DECOMP PJSM. Finish rigging up to run 9-5/8", 47#, L-80, Hydril 563 Printed: 5/4/2009 11:44:16 AM • BP EXPLORATION Operations Summary Report Page 5 of 17 Legal Well Name: 14-23 Common Well Name: 14-23 Spud Date: 5/22/1983 Event Name: REENTER+COMPLETE Start: 4/5/2009 End: 5/2/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours ' Task 'Code NPT 4/13/2009 00:00 - 01:00 1.00 CASE P 01:00 - 05:00 4.00 CASE P 05:00 - 07:00 2.00 ~ CASE ~ P 07:00 - 10:00 I 3.001 CASE ( P 10:00 - 12:00 I 2.001 CASE I P Phase Description of Operations DECOMP casing. DECOMP PJSM, RIH with 50 joints of 9 5/8", 47#, L-80, Hydrill 563 casing with a free floating centralizer on joints 1-49. Average MU torque 15,800 fUlbs. DECOMP MU top drive. Rotate casing patch over casing stub while circulating at 252 gpm with 88 psi. Observe pressure increase and shut in pumps. Engauge patch. PU 30k over and set grapple. Pull test to 250k to confirm. Test casing to 1000 psi for 10 minutes - OK. DECOMP MU cement head. Pressure up in increments, 1200 psi then 1400 psi, then open ECP with 1500 psi. Relax element. Pump back up and fill packer with 1/4 bbl. Bleed off. Pressure up casing to 2000 psi, XO to cement head leaking. Shut down. Remove and change out seal. Pressue up to 2000 psi - OK. Bring pressure up to 2900 psi and open ES cementer. Establish circulation at 210 gpm with 214 psi. Pump 137 bbls and hold PJSM for upcoming cement job. DECOMP Shut down and line up for cement job. 10:00 Pump 20 bbl hi-vis spacer with red dye at 5 bpm with 160 psi. 10:04 Swap over to SCH. Pump 5 bbls water. 10:09 Pressure test lines to 4000 psi - OK. 10:15 Start 15.8 ppg, Class G, Tail cement slurry. 5 bbls away, pumping at 4 bpm with 200 psi. 20 bbls away, pumping at 5 bpm with 200 psi. 10:27, 50 bbls away, pumping at 5 bpm with 190 psi. 10:36, 100 bbls away, pumping at 5 bpm with 200 psi. 10:44, 137 bbls away, pumping at 5 bpm with 200 psi. Shut down and drop plug with positive indication plug left head. 10:45 Kick out plug with 5 bbls water from SCH. 10:47 Swap over to rig for displacement with 8.5 ppg seawater. 15 bbls away, pumping at 6.5 bpm with 192 psi. 50 bbls away, pumping at 6.5 bpm with 197 psi. 70 bbls away, pumping at 6 bpm with 407 psi. 74 bbls away, red dye back to surface. Shut in, close Hydril and divert returns from OA to cuttings tank. 80 bbls away, pumping at 4 bpm with 490 psi. 105 bbls away, pumping at 4 bpm with 780 psi. 119 bbls away, pumping at 4 bpm with 900 psi. Cement at surface. 123 bbls away, pumping at 4 bpm with 882 psi. 134 bbls away, pumping at 2 bpm with 882 psi. 137 bbls away, pumping at 2 bpm with 885 psi. Bump plug. Pressure up to 1850 psi on bump and close ES Cementer, 18 bbls cement back to surface. CIP at 11:20 hours. Printed: 5/4/2009 11:44:16 AM • BP EXPLORATION Page 6 of 17 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 'From - To 4/13/2009 10:00 - 12:00 12:00 - 13:00 13:00 - 16:00 16:00 - 17:00 17:00 - 20:00 20:00 - 21:00 21:00 - 22:00 22:00 - 23:00 14-23 14-23 Spud Date: 5/22/1983 REENTER+COMPLETE Start: 4/5/2009 End: 5/2/2009 NABORS ALASKA DRILLING I Rig Release: NABORS 9ES Rig Number: 9ES Hours ~ Task Code I NPT I~, Phase Description of Operations 2.00 CASE P DECOMP Tail Slurry 137 bbls. Number of sacks 671. Yield 1.17. No losses during cementing operations. 1.00 CASE P 3.00 CASE P 1.00 BOPSU P 3.00 WHSUR P 1.00 BOPSU P 1.00 BOPSU P 1.001 BOPSUFiP 23:00 - 00:00 1.00 CLEAN P 4/14/2009 00:00 - 00:30 0.50 CLEAN P 00:30 - 01:00 0.50 CLEAN P 01:00 - 03:00 2.00 CLEAN P 03:00 - 03:30 I 0.501 CLEAN I P 03:30 - 05:00 1.50 CLEAN P 05:00 - 05:30 0.50 CLEAN P 05:30 - 07:30 I 2.001 CLEAN I P 07:30 - 07:45 0.25 CLEAN P 07:45 - 08:15 0.50 CLEAN P 08:15 - 10:00 1.75 CLEAN P 10:00 - 12:30 2.50 CLEAN P 12:30 - 13:00 I 0.501 CLEAN I P 13:00 - 14:00 I 1.001 CLEAN I P 14:00 - 15:00 1.00 CLEAN P 15:00 - 16:00 1.00 CLEAN P Flush stack and line to cuttings box. DECOMP Remove cement head and adapter. Suck out stack and casing. Remove false bowl. DECOMP PU stack. Set slips with 85k. Make cut with WACH's cutter on 9-5/8" casing. Cut piece at 27.39'. Pull and lay down cut piece. DECOMP PJSM. Nipple down BOP stack. DECOMP Change out tubing spool with secondary packoff. Test 9-5/8" packoff to 3800 psi for 30 minutes - OK. DECOMP Nipple up BOP stack. DECOMP PJSM. PU test tools. Test BOP stack break to 250 psi low, 3500 psi high as per AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Roy Hunt. DECOMP Run in and install wear ring with an ID of 9.125". Install mouse hole. DECOMP PU and MU drill out BHA to 21'. DECOMP PJSM. MU and RIH with cleanout BHA to 665'. DECOMP RIH to 1937'. Tag ES cementer. DECOMP Drill cement closing plug from 1937' to 1940'. Pump at 560 gpm with 285 psi. Rotate at 80 rpm with 2k torque. WOB 10k. Up weight 80k, down 78k, RT 76k. RIH and tag up at 2106' on top of sand. Dry drill 2' with 10k WOB. DECOMP Rack back stand. Circulate hi-vis sweep surface to surface at 580 gpm with 270 psi. DECOMP POOH to 665'. DECOMP POOH with BHA. Lay down bit and boot baskets. Two small pieces of cement rock, one piece of control band and cement cuttings in basket. DECOMP H2S alarm and rig evacuation. High level alarm sounded. Shut in well and evacuate rig. Muster in primary safe area. Call 911 and make notifications. Safe out rig. All clear. Open well under WSL Joey LeBlanc's supervision, all OK. DECOMP Test casing to 3500 psi for 5 minutes - OK. DECOMP Make up RCJB BHA to 33'. DECOMP RIH to 2015'. DECOMP Drop ball on RCJB seat. Establish circulation at 232 gpm with 1808 psi. Up weight 77k, down weight 70k. Shut down. Rotate and work down tagging sand at 2107'. Attempt to circulate. Packoff to 2700 psi. Reverse circulate at 84 gpm with 320 psi. Attempt again to circulate the long way. Pressure up to 3300 psi. Reverse circulate at 126 gpm with 340 psi. Rubber pieces in returns. DECOMP Wash down to 2119' at 200 gpm with 1800 psi. Rotate at 20 rpm with 2k torque. Up weight 80k, down 75k, RT 80k. DECOMP Circulate 1.5 times BU at 210 gpm with 1800 psi. Rotate at 20 rpm with 1 k torque. Rubber and sand on bottoms up. Brine weight in and out 9.8 ppg. DECOMP POOH to 33'. DECOMP Clean out RCJB and boot baskets. A few pieces of centralizer, Printed: 5/4/2009 11:44:16 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: 14-23 Common Well Name: 14-23 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date From - To Houxs Task Code 4/14/2009 15:00 - 16:00 1.00 CLEAN P 16:00 - 17:00 1.00 CLEAN P 17:00 - 17:30 0.50 CLEAN P 17:30 - 18:00 0.50 CLEAN P 18:00 - 19:00 19:00 - 19:30 19:30 - 20:30 20:30 - 00:00 1.00 CLEAN P 0.50 CLEAN P 1.00 BOPSU P 3.50 BOPSU P 4/15/2009 100:00 - 01:30 01:30 - 02:15 02:15 - 03:15 03:15 - 04:00 04:00 - 04:15 04:15 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 - 08:00 08:00 - 08:30 08:30 - 09:00 09:00 - 10:00 10:00 - 10:30 10:30 - 11:30 11:30 - 14:30 14:30 - 15:00 15:00 - 18:30 18:30 - 19:30 19:30 - 23:00 23:00 - 00:00 4/16/2009 00:00 - 02:30 02:30 - 03:00 1.501 BOPSUp P 0.75 CLEAN P 1.00 CLEAN P 0.75 CLEAN P 0.25 CLEAN P 1.75 CLEAN P 0.50 CLEAN P 0.50 DHB P 1.00 DHB P 0.50 DHB P 0.50 DHB P 1.00 DHB P 0.50 DHB P 1.00 STWHIP P 3.00 STWHIP P 0.50 STWHIP P 3.50 STWHIP P 1.00 STWHIP P 3.50 STWHIP N 1.00 STWHIP N 2.50 STWHIP N 0.50 STWHIP N Start: 4/5/2009 Rig Release: Rig Number: 9ES Page 7 of 17 Spud Date: 5/22/1983 End: 5/2/2009 N'PT `~ Phase Description of Operations DECOMP rubber and sand back in basket. Due to plugging off problem and lack of cement plug material a second run will be made with RCJB. DECOMP RIH with RCJB to 2106'. DECOMP Wash down with RCJB to 2134'. Pump at 232 gpm with1800 psi. DECOMP Circulate BU at 240 gpm with 1965 psi. Sand and rubber to surface. DECOMP POOH to 33'. DECOMP Lay down RCJB. Basket empty. DECOMP PJSM. Flush stack. Pull wear bushing. DECOMP Test BOPE to 250 psi low, 3500 psi high as per AOGCC. Test Hydril to 250 psi low, 3500 psi high. Test all with 4" test joint. Test witness waived by John Crisp with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Roy Hunt. Notification within 24 hour time frame given for H2S alarms and rig evacuation to the AOGCC. DECOMP PJSM. Test BOPE to 250 psi low, 3500 psi high as per AOGCC and Hydril to 250 psi low, 3500 psi high. Test witness waived by John Crisp with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Roy Hunt. Tested all with 4" test joint. DECOMP PJSM. Rig down test equipment. Run in wear ring with and ID of 9.25". PU/MU RCJB BHA to 33'. DECOMP RIH to 2106'. Establish parameters. Pump at 85 gpm with 420 psi. Drop ball for RCJB. Up weight 77k, down 74k. DECOMP Run in and tag sand at 2136'. Dry drill to 2141'. Pump at 85 gpm and vac to 2150'. DECOMP Circulate BU at 280 gpm with 2560 psi. Small amount of sand '! and a few small pieces of rubber to surface. Seawater weight in and out 8.5 ppg. DECOMP POOH to 33'. DECOMP Lay down RCJB BHA. Baskets empty. DECOMP PJSM. PU RBP retrieval tool. DECOMP RIH to 2150'. DECOMP Wash down to 2160'. Latch up RBP. DECOMP Circulate bottoms up at 555 gpm with 615 psi. Release RBP. DECOMP POOH with RBP. DECOMP Lay down RBP. DECOMP Test casing to 3500 psi. Lost 0 psi in first 15 minutes and 30 psi in second 15 minutes due to thermal stabilization -PASS. DECOMP PJSM. PU/MU Gen 2 Window Master Whipstock and milling assembly to 1062'. DECOMP Shallow test MWD at 550 gpm with 780 psi - OK. DECOMP RIH to 6411'. DECOMP Orient whipstock slide to 60 LHS. Up weight 150k, down 130k. Recalculation of whipstock anchor shear pin assembly shows anchor pinned to high. Will POOH to re-pin. HMAN DECOMP POOH to starter mill. No whipstock slide. Left in hole. HMAN DECOMP Lay down whipstock mill assembly. HMAN DECOMP PJSM. MU and RIH with 'J' hook assembly to recover whipstock slide. HMAN DECOMP Shallow test MWD. Intermittent signals. Printed: 5/4/2009 11:44:16 AM BP EXPLORATION Page 8 of 17 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To 4-23 4-23 REENTE NABOB NABOB ~, Hours i _ R+COM S ALAS S 9ES Task PLET KA DRI Code E LLING ' NPT Start I Rig Rig I Phase - Spud Date: 5/22/1983 : 4/5/2009 End: 5/2/2009 Release: Number: 9ES Description of Operations __ _ _ _ _ __ 4/16/2009 _ 03:00 - 03:45 _ _ 0.75 STWHIP N HMAN - DECOMP RIH to 1350'. 03:45 - 04:15 0.50 STWHIP N HMAN DECOMP Attempt to test MWD again. Seeing pressure spikes and inconsistent signals. 04:15 - 04:45 0.50 STWHIP N HMAN DECOMP RIH to 2100'. Check surface equipment while running in hole and bring seawater volume up in pits. 04:45 - 06:00 1.25 STWHIP N HMAN DECOMP Attempt to test MWD with same problems encountered. Seawater weight in and out 8.5 ppg. 06:00 - 07:30 1.50 STWHIP N HMAN DECOMP POOH with whipstock retrieval assembly. 07:30 - 08:30 1.00 STWHIP N HMAN DECOMP Lay down BHA. 08:30 - 12:00 3.50 STWHIP N HMAN DECOMP Troubleshoot surface equipment and drill string. The J hook assembly diagnosed as the problem with fluctuating pressure and non-functioning MWD. 12:00 - 12:30 0.50 STWHIP N HMAN DECOMP PU J hook, whipstock retrieval assembly. 12:30 - 13:00 0.50 STWHIP N HMAN DECOMP Shallow test MWD at 90' with 511 gpm and 220 psi - OK. 13:00 - 15:00 2.00 STWHIP N HMAN DECOMP RIH to 2280'. 15:00 - 16:00 1.00 STWHIP N HMAN DECOMP Attempt to test MWD. Weak signal due to low pressure. Bleed down pulsation dampeners to 500 psi. Signal improved. 16:00 - 17:30 1.50 STWHIP N HMAN DECOMP RIH to 6484'. 17:30 - 19:00 1.50 STWHIP P DECOMP Displace seawater with 9.2 ppg LSND milling fluid. Pump 50 bbls hi-vis sweep followed by LSND at 563 gpm with 1060 psi. 19:00 - 20:30 1.50 STWHIP N HMAN DECOMP Establish up weight 165k, down 125k. Run in and tag at 6517'. Work string up and down with quarter turns. Good indication J hook seated in slide. Pull up. Verify EZSV top at 6533' DPM. Mud weight in and out 9.2 ppg. 20:30 - 00:00 3.50 STWHIP N HMAN DECOMP POOH to 848'. Up weight 80k. 4/17/2009 00:00 - 00:30 0.50 STWHIP N HMAN DECOMP PJSM. POOH to BHA at 370'. 00:30 - 02:00 1.50 STWHIP N HMAN DECOMP PJSM. Lay down retrieval tool BHA. Recovered whipstock slide. Slide was compressed but did not shear set screws. Change out slide. 02:00 - 05:30 3.50 STWHIP N HMAN DECOMP PJSM. Pick up new Gen 2 whipstock slide and milling assembly to 395'. 05:30 - 06:00 0.50 STWHIP N HMAN DECOMP RIH with whipstock/milling assembly. 06:00 - 06:30 0.50 STWHIP N HMAN DECOMP Shallow test MWD at 577 gpm with 750 psi - OK. 06:30 - 09:00 2.50 STWHIP N HMAN DECOMP RIH to 6507'. 09:00 - 09:30 0.50 STWHIP N HMAN DECOMP Orient whipstock slide to 44 LHS. Set on top of EZSV at 6533'. Set down 20k and set anchor. PU 10k to verify set. Set down 40k and shear slide lug. Up weight 155k, down 125k. 09:30 - 20:00 10.50 STWHIP P DECOMP Mill window at 580 gpm with 1565 psi. Rotate at 80 rpm with 5-11 k torque. WOB - 1-4k. Up weight 160k, down 125k, RT y~•~i~ 140k. Mill to 5652' MD. TOW 6510', BOW 6527'. Gauge hole to 6531'. Pump sweeps as necessary. 20:00 - 21:30 1.50 STWHIP P DECOMP Work mills through window with pumps and rotation, with pumps on, no rotation and with pumps off and no rotation. Window appears in good shape. Pump super sweep surface to surface at 580 gpm with 1647 psi. Rotate and reciprocate through window while pumping sweep. No increase in cuttings to surface. Up weight 155k, down 125k, RT 140k. Mud weight in and out 9.2 ppg. Recovered 240 Ibs of metal. 21:30 - 22:30 1.00 STWHIP P DECOMP Perform FIT to 11.1 ppg EMW with 588 psi and 9.2 ppg mud. 22:30 - 00:00 1.50 STWHIP P DECOMP PJSM. Prepare for changing out drilling line. Slip and cut drilling line. 4/18/2009 00:00 - 02:30 2.50 STWHIP P DECOMP PJSM. Slip and cut to replace drilling line. 02:30 - 03:30 1.00 STWHIP P DECOMP PJSM. Service top drive and rig. Printed: 5/4/2009 11:44:16 AM TREE = GRAY GEN 3 WELLHEAD= GRAY P~CTUATOR = AXELSON KB. ELEV = _. 72' BF. ELEV KOP = 2800' Max Angle = 39 @ 4500' Datum MD = 10060' Datum TV D = 8800' SS S~OTES: FliLITIW: HBBP PKRS HAVE 1 ~ ~2 3 REDUCED TEST PRESS. LIMITS. CONTACT ACE @ X5102 PRIOR TO PRESSURE TEST. LDL @2894' 2151' 5-1/2" DMY SSSV NIP, ID=2.625" GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-{ 2508' ~' ~~\ ~ Minimum ID = 2.625" @ 2151' ~ ~' 5-1 /2" DMY SSSV PaS~f~.'-~ ~'" " ' ...... . JET CUT (03/30/09) 7000' ESTIMATED TOP OF CEMENT (03/29/09) 9304' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2888 2886 11 CAMCO DMY RK 0 10/13/03 2 5129 4772 38 CAMCO DMY RK 0 04/14/03 3 6796 6086 37 CAMCO DMY RK 0 4 7900 6985 34 CAMCO DMY RK 0 5 8513 7489 34 CAMCO DMY RK 0 6 8579 7544 34 CAMCO DMY RK 0 7 8935 7849 28 CAMCO DMY RK 0 8 9003 7909 27 CAMCO DMY RK 0 9 9246 8126 26 CAMCO DMY RK 0 10 9315 8188 26 CAMCO DMY RK 0 9420' ~5-1/2" BAKERPBRASSY 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 9434' 9434' 5-1/2" X 4-1/2" XO TOP OF 4-1/2" TBG-PC 9434' 9438'-9441' TUBING PUNCH (03/15/09) 9445' 9-5/8" X4-1/2" BKR FHL PKR TOP OF 7" LNR 9490' 9495' 4-1/2"GLAND SUB, ID = 2.990" (TOP OF LNR) TOP OF 3-1/2" LNR- CT 9495' 9511' 4-1/2" CAMCO DB-5 LANDING NIP, ID = 3.81" CEMENT RETAINER (03/29/09) 9496' 9523' 4-1/2" BAKER SHEAROUT SUB (BEHIND CT) I4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9524' 9-5/8" CSG, 47#, L-80, ID = 8.681 " 97$2' 3-1/2" LNR- CT, 9.3#, L-80, .0087 bpf, ID = 2.992" ~~ 10029' PERFORATION SUMMARY REF LOG: BHCS ON 06/02/83 ANGLE AT TOP PERF: 22 @ 9922' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 9922 - 9924 S 06/12/83 3-1/8" 4 9980 - 10020 S 03/08/84 3-3/8" 4 10034 - 10042 S 10/08/93 3-3/8" 6 10042 - 10062 S 03/29/09 3-3/8" 1 10064 - 10076 S 10/08/93 4" 4 10138 - 10140 S 06/12/83 PBTD 10440' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10440' ICOLLAPSEDTBG (10/8/98 VIDEO LOG) I DATE REV BY COMMENTS DATE REV BY COMMENTS 06/14/83 ORIGINAL COMPLETION 02/17/09 SWC/SV PULL IBP/FISH (02/14/09) 05/19/03 GJNVTLH SET IBP 03/18/09 RRD/SV TBG PUNCH (03/15/09) 10/01/03 BHC/TLP PERF SUMMARY CORRECTIONS 03/29/09 RLM/PJC CMT RETAINER/ TOC 10/14/03 JCMITLH GLV C/O 04/02/09 JKD/SV JET CUT (03/30/09) 08/05/08 OOB/PJC COLLAPSEDTBG(10/8/98) 10/15/08 006/ PJ GRAVEL SCRN CORR (01/15/09) PRUDHOE BAY UNff WELL: 14-23 PERMfT No: x1820870 API No: 50-029-20757-00 SEC 9, T10N, R14E, 2912.73' FEL & 2801.64' BP Exploration (Alaska) J--~4-1/2" TUBING TAIL (BEHIND CT) '~ ELMD TT LOGGED 03/03/91 10009' ~ GRAVEL SCRN SET 1/15/99, ID = 1.75" 100 3-1/2" BKR SHOE • • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, March 23, 2009 4:19 PM To: 'Rose, John G (FAIRWEATHER)' -~~,,.~~~~~~::~ ~t,~ J~~ ~; r~ ~~~ Cc: Tirpack, Robert B Subject: RE: 14-23 (182-087) Sundry (309-034) Thanks John. Nothing further is needed. I will place a copy of this message in the well file. Tom Maunder, PE AOGCC From: Rose, John G (FAIRWEATHER) [mailto:John.G.Rose@bp.com] Sent: Monday, March 23, 2009 4:07 PM To: Maunder, Thomas E (DOA) Cc: Tirpack, Robert B Subject: RE: 14-23 Sundry (309-034) Tom, As our diagnostic work has indicated the Option "A" P&A to be practical for the 14-23 well, I have modified this work program to reflect that specific P&A which is on our service coil scheduled for tomorrow. Also, Step #12 of the "Rig Ops" now details the 9-5/8" tie-back work that is planned for this well. If you need any additional information, please advise. Thanks - jr Pre-Ri Work: F 1. MIT-OA to 2000 psi Com leted 12/5/08 S 2. Fish/recover the IBP in the 4-1/2" tubin at 9470' MD. DONE 2116/09. Rock screen one? S 3. Set DSSSV in SSSV nipple at 2151' MD to eliminate TxIA communication. (Optional per Jim Moore on 2/15/09 F 4. Perform an injectivity test to confirm sufficient injectivity for adown-squeeze P&A. (Option "A" below) or a balanced plug P&A (Option "B" below) if the injectivity rate is insufficient. DONE 2/23/09 NOTE: Based upon this injectivity test results of 2/23/09, please move forward with the O tion "A" P&A as detailed below. S 5. Pull DSSSV from SSSV nipple at 2151' MD. ("IF" set in Step #3) "PLUG NOT SET" this Ste does not a I . C/E 6. P&A perforations w/coil per the Option "A" details below to include PT cement to 2160 psi. F 7. Circ out, freeze protect IA and T with 2200' TVD of diesel. W 8. Perform a PPPOT -T to 5000 psi & PPPOT-IC to 3500 psi (PPPOT-IC DONE w/Passing Test on 12/11 /08 . C cle all LDS, re air or replace as needed V 9. Set a BPV and test to 2000 psi from tubing annulus (or maximum allowable up to 2000 psi . O 10. Remove well house and flow lines and level the ad as necessar . Option "A" P&A (with sufficient injectivity for down-squeeze) a. Make tubing punch at -9440' MD in the middle of the 10' 4-1/2" located just above the 9-5/8"x4-1/2" production packer at 9445' MD. b. Flush tubing out at a high rate with 290 bbls seawater. c. RIH and set Weatherford FH one-trip cement retainer in the 4-1/2" tubing at 9480'. d. At this point, the retainer is set and coil is stung in to the retainer with the tubing punch holes above the retainer. e. Turn the well over to seawater with diesel FP on both the IA and Tbg by circulating down the backside of coil thru the tubing punch at 9440' and up the IA the following: a. 88 bbls diesel b. 466 bbls seawater 3/23/2009 Page 2 of 3 c. 50 bbls diesel f. Squeeze --25 bbls of 15.8 ppg G cement below the retainer at 9480' MD which is a volume of cement equal to the cased hole volume from the base of the retainer at 9480' MD to 10,162' MD (100' below the bottom of the lowest perforation at 10,062'). (NOTES: BHP = 3250 psi at 8800' TVD, BHT = 165-175 Deg F., MAX TOC = 7250' MD) g. Un-sting from the retainer and begin laying in 10 bbls cement (or remainder of cement if unable to pump 25 bbls below retainer) 1:1 above the retainer to -9034'. Pull to safety. Shut in backside (tbg) open IA and squeeze -6 bbls cement into IA. h. Shut in IA and attempt to squeeze 1 bbl of cement past the production packer up to 1500 psi. i. Contaminate and clean out tubing to 9334' with 1.5# biozan - 2 u/d passes j. Chase to surface at 80% and FP tubing k. After cement has reached a minimum compressive strength of 500 psi, CMIT-TxIA to 2160 psi (.25 psi/ft to TVD of 9- 5/8" casing shoe at -8625' TVD). I. Drift for jet cut and tag TOC m. Assuming a good CMIT in Step "j", jet cut tubing at 7000' MD and circulate the well over to clean seawater. Proposed Drilling Rig Operations: 1. MI/RU. 2. CMIT-TxIA to 2000 psi and MIT-OA to 2000 psi to confirm barriers (both tests expected to be good). 3. Pull BPV and circulate out diesel freeze protection and displace the well to seawater. 4. Set and re-test TWC to 1,000 psi from above and below. 5. As there is path-forward wellhead work to be completed, begin monitoring process of OA. 6. Nipple down tree. Nipple up and test BOPE to 3500psi. Pull TWC lubricator. 7. R/U & pull 5%2" tubing from the cut depth at 7000' MD. 8. Test lower set of pipe rams if required. 9. PU drillpipe and make bit and scraper run to the top of the tubing stub at 7000' MD. 10. RU E-line and RIH w/GR/CCL/USIT (in cement & corrosion mode) to 7000'. (NOTE: The CCL & GR log will be used to find good KOP (a good shale / no casing collar) below the base of the WS2 and the USIT log run in the corrosion mode will be used to further evaluate the condition of the 9-5/8" casing above the window as well as identify the TOC behind the 9-5/8" casing in the OA.) 11. RIH with HES EZSV bridge plug on E-line and set at 6723' MD, as required to avoid cutting a casing collar while milling the window. Test casing to 3500 psi f/30 min and chart. 12. With 2 tested barriers down-hole, cut & pull the 9-5/8" casing from above TOC in the OA and tie-bacl cemented string of 9-5/8" casing to surface per Cameron wellhead specialist (the new casing will be hung or the existing casing spool -will require "splitting" the stack). 13. NU Wellhead/BOPE test breaks to 3500 psi. 14. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock and set on EZSV bridge plug. Shear off of whip stock. 15. Displace the well to LSND based milling fluid per MI mud program. (End Work Under Sundry Approval #309-034 /Begin Work Under PTD #209-020) John G. Rose SPX -Drilling Consultant Office 907,'564-5279 Cell 907/748-5223 FAX 907/564-4040 Home 907/243-8893 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, March 23, 2009 1:17 PM To: Rose, John G (FAIRWEATHER) Cc: Tirpack, Robert B Subject: RE: 14-23 Sundry (309-034) John, Could you provide a modified work program as originally provided with the sundry? 3/23/2009 Page 3 of 3 Email is fine. Thanks in advance. Tom Maunder, PE AOGCC From: Rose, John G (FAIRWEATHER) [mailto:John.G.Rose@bp.com] Sent: Monday, March 23, 2009 12:53 PM To: Maunder, Thomas E (DOA) Cc: Tirpack, Robert B Subject: 14-23 Sundry (309-034) Tom, To eliminate possible IA x OA communication, it has been decided to include a 9-5/8" cut & pull from above the TOC in the OA (--2000-2200' MD) and then running and fully cementing a new 9-5/8" tie-back string to surface as prep work prior to sidetracking this well. That being the case, does this a-mail provide sufficient information or would you like me to modify the previously submitted Sundry request? Also, as there will be a minimum of 2 tested barriers, we do not plan to change-out to 9-5/8" rams for this "process". Thanks - jr John G, Rose BP_A" - Drilliit, Consultaru OfJicc JOZ'~(4-52%1 CeN l0%74b'-i??3 F;1.A' 90% 5fi4-4(140 Ilomc JOi243-4813 3/23/2009 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, March 11, 2009 9:26 AM To: 'Rose, John G (FAIRWEATHER)' Cc: Hobbs, Greg S (ANC) k~A,~ ~~ Subject: RE: 14-23 (182-087) Sundry 309-034 John, Thanks for the update. Nothing further is needed. I will place a copy of this message in the file. Also, please note to include the PTD in addition to the sundry number. Call or message with any questions. Tom Maunder, PE AOGCC From: Rose, John G (FAIRWEATHER) [mailto:John.G.Rose@bp.com] Sent: Wednesday, March li, 2009 9:18 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: 14-23 Sundry 309-034 Tom, As the Sundry approval (309-034) for the P&A of the 14-23 well well included 2 options for the P&A based upon the ultimate injectivity rate to the perforations, please note the following: 1. As the injectivity test work performed on the well on 2/23/09 indicated a sufficient injectivity rate to allow the use of the Option "A" P&A to pump the P&A cement job as detailed in the original Sundry request. 2. To improve our ability to not only place cement into the perforations but also get a better cement job around the 9-5/8" x 4-1/2" production packer at 9445' MD, the Option "A" P&A plan has been modified as follows: a. move the cement retainer down the well from 9334' MD to 9480' MD and squeeze 25 bbls of cement below the packer to the perforations. b. after squeezing 25 bbls of cement below the retainer, lay 10 bbls of cement above the retainer (which will allow the cement to enter the IA above the production packer at 9445' MD through the planned tubing punch at 9440' MD) and again squeeze the cement to insure a better "seal" at that location in the well. The attached document details the "Original" Option "A" P&A plan versus the "NEW" plan for your review and please don't hesitate to call if you have any questions or concerns. Thanks - jr .i~ir» c. r,~5, R>>a~- n~~arr;;~_ C~~ns~~rau~r Cell 90~ ->,~-S?3 1~:~_A 90i ~1=-400 lfaue 90Z1d3-8h 13 3/11/2009 • "NEW" Option "A" P&A (with sufficient infectivity for down-squeeze) a. Make tubing punch at 9440' MD in the middle of the 10' 4-1/2" located just above the 9-5/8"x4-1/2" production packer at 9445' MD. b. Load the IA with 400 bbls seawater through the tubing punches at -9440', freeze protect top 2000' with 88 bbls diesel. c. Fluid pack tubing with 290 bbls seawater and 75 bbls diesel d. RIH and set Weatherford FH one-trip cement retainer in the 4-1/2" tubing at 9480'. e. Squeeze ~25 bbls of 15.8 ppg G cement below the retainer at 9480' MD which is a volume of cement equal to the cased hole volume from the base of the retainer at 9480' MD to 10,162' MD (100' below the bottom of the lowest perforation at 10,062'). (NOTES: BHP = 3250 psi at 8800' TVD, BHT = 165-175 Deg F., MAX TOC = 7250' MD) f. Un-sting from the retainer and begin laying in 10 bbls cement (or remainder of cement if unable to pump 25 bbls below retainer) 1:1 above the retainer to -9034'. Pull to safety. Shut in backside (tbg) open IA and squeeze -6 bbls cement into IA. g. Shut in IA and attempt to squeeze 1 bbl of cement past the production packer up to 1500 psi. h. Contaminate and clean out tubing to 8334' with 1.5# biozan - 2 u/d passes i. Chase to surface at 80% and FP tubing j. After cement has reached a minimum compressive strength of 500 psi, CMIT-TxIA to 2160 psi (.25 psi/ft to TVD of 9-5/8" casing shoe at 8625' TVD). k. Drift for jet cut and tag TOC I. Assuming a good CMIT in Step "j", jet cut tubing at 7000' MD and circulate the well over to clean seawater. "ORIGINAL" Option "A" P&A: a. Make tubing punch at 9440' MD in the middle of the 10' 4-1/2" located just above the 9-5/8"x4-1/2" production packer at 9445' MD. b. Make tubing punch at 9354' in the 2nd full joint of 5-1 /2" tubing above the production packer at 9445' MD. c. Circulate the well to seawater through the tubing punches at -9400' & 9354' MD. d. Set retainer in the 5-1/2" tubing just above the tubing punched holes at 9334' MD. (Note: The distance between the retainer and the top of the perforations 708'.) e. Squeeze -34 bbls of 15.8 ppg G cement below the retainer at 9334' MD which is a volume of cement equal to the cased hole volume from the base of the retainer at 9334' MD to 10,162' MD (100' below the bottom of the lowest perforation at 10,062'). (NOTES: BHP = 3250 psi at 8800' TVD, BHT = 165-175 Deg F., MAX TOC = 7250' MD) f. Un-sting from the retainer and re-circulate the tubing side to clean seawater. g. After cement has reached a minimum compressive strength of 500 psi, CMIT-TxIA to 2160 psi (.25 psi/ft to TVD of 9-5/8" casing shoe at 8625' TVD). h. Assuming a good CMIT in Step "g", drift tubing w/DMY jet cutter and jet cut tubing at 7000' MD and circulate the well to clean seawater. 14-23 P&A 1 3/11/2009 SS~Q~~ Oi~ G'~~u~N~~s ALASSA OIL AI~TD GAS COI~TSERQATIOI~T COI~IIK155IO1Q Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 1~~ ~j~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-23 Sundry Number: 309-034 L.-~ s l.~{ ` r ery Dear Mr. Hobbs: '~" °~-' ~Y ~ ~: 1r Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Cammission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair r~ DATED this ~ day of February, 2009 Encl. ' - a,a . `~~ 1 \~ ~~ a,~,o STATE OF ALASKA /r~~9 ,~ALA~ OIL AND GAS CONSERVATION COMI'~ION ~~~~IV '~ APPLICATION FOR SUNDRY APPROVAL ~,~. ED ~ Zo AAC zs.2so ~' ~~i ~Q ~I ~ ~ ~nnq 1. Type of Request: ®Abandon ' ^ Suspend ^ Operation Shutdown ^ Perforate x nsion ^ Tim e E t e RR `` Q~ j( ( '~ e t ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate L:)~~~n~elf SLs~iEh~d~~11C~~fl ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other /gnChOfag@ 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development- ^ Exploratory 182'087 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20757-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 14-23 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028312 - 72' - Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10440' ~ 922T - 10440' 9227 9470' 9524' in n h i D TVD r II r rl r ~ ~~ urf 1 / " 8' 7 In rm i 7 /" 7 1 6 7 Pr i n Liner 7" ' - 1 0' 7' 1 7 0 'n r -1/2" '- 1 1' - 4' 1 1 5 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10042' - 10062' 8855' - 8874' S-1/2", 17# t4-1/2", 12.6# L-80 9524' Packers and SSSV Type: 9-5/8" Baker'FHL' packer Packers and SSSV MD (ft): 9~5' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: , Commencin O erations: March 10, 2009 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Rose, 564-5271 Printed Name Gre b ~ Title Engineering Team Leader Prepared ey Name/Number Signature Phone 564-4191 Date ~ ~°~9 Terrie Hubble, 564-4628 Commission Use!Onl Sundry Number: ~- Conditions of approval: Notify Commission so that a representative may witness ~~ ~/h_ ~ ~ ^ Plug Integrity OP Test ^ Mechanical Integrity Test ^ Location Clearance `~,~ Other: 3~QQp ~ ,. • `'^1v ~-fl ~,.c- ~ ~y ~~ '~~OC7 s~ ~~~ ~ ~ '~t~-~ `F Subsequent Form Required: 1~j~E~ - APPROVED BY ~ / ~ A roved B : COMMISSIONER THE COMMISSION Date / Form 10-403 Revil,eli 06/2006 Submit In Duplicate r.r~» ~ •' ~ ~ ~~ • • by Gaar DS14-23 Sundry Request Well Type: Producer Current Status: This well is completed with 5-1/2" L-80 tubing and is currently shut-in. Request: Plug and abandon wellbore in preparation for Sag River sidetrack. Well History: Well 14-23 was completed in 3/84 as a Zone 4 producer with an initial rate of 5600 BOPD at 600 GOR. With gas rates a bit higher than expected and water production climbing, wellwork options were reviewed. A 7/89 PITS survey identified a channel to Z3 that explained the water production and offset CNLs indicated the top perfs were above the GOC at -8768' TVDSS. The well was squeezed in 10/89 to shut off the perfs above the GOC and the channel to Z3. A 3/91 PPROF indicated the squeezed perfs were holding and identified the interval 10034-62' MD as having a gas jet and contributing the majority of production. GORs continued to rise and made a small step change in 1/93, which prompted another PPROF. The 3/93 PPROF suggested the squeezed perfs were no longer holding and were now contributing over 80% of production. A 10/93 cement squeeze was performed to reduce water and gas production, however they ran out of cement and a drawdown test confirmed they didn't get a good squeeze. Watercut dropped for a short period of time, however the GOR remained uncompetitive post-squeeze. A 11/93 PPROF confirmed the squeezed perfs were leaking and contributing 100% of the production. A 3-1/2" coil liner was cemented over the top two leaking perforation intervals in 2/94, and a 3/94 PPROF indicated the scab was holding. The well began to produce gravel/rocks in 5/98 with some as large as 1" in diameter believed to be from the Z3 conglomerate perfs at 10064-76' MD. The well was SI in 10/98 due to risk of pipe erosion/turbine meter damage caused by the solids production. A videolog run that month clearly shows a collapsed liner at 10051' MD. A gravel screen was hung from the tail of the 3-1/2" CT liner in 1/99 and the well continued on production nearly full-time until annular communication problems began developing in 9/01 when the well failed a TIFL. After remediation attempts with DGLVs and a DSSSV, the well still failed a TIFL and was secured with an IBP on 5/19/03. A PDS caliper on 10/13/03 showed varied tubing conditions; although the overall wall loss was considered low, the caliper identified 11 joints with sections of 40-85% penetrations. A LLR (IA---T) of 3 BPM at 1600 psi was established on 10/18/03. The 10/24/03 LDL performed pumping IA-~T did not show any definitive tubing entries; temperature passes suggest the fluid flow was going past the packer and did not suggest a PC leak. A packer squeeze was deemed uneconomic at the time and the well was left SI. The well was reevaluated in mid-2008 for a packer squeeze and some preliminary diagnostics were performed. A MIT-T against the IBP failed to 3000 psi with a LLR (T-CIA) of 2.6 gpm at 3000 psi in 6/08. A 7/08 TecWel log performed pumping T->IA also suggested a leaking packer. The packer squeeze was tabled due to the possibility of converting this well to UZI (updip zone injection) and 14-23 was then chosen as the parent well for this RST target. A pre-RST CMIT-TxIA to 3500 psi performed on 12/5/08 failed w/ a LLR of 3 BPM at 1720 psi. The failing CMIT-TxIA is believed to be due to the aforementioned packer leak. DS 14 has a low incidence rate of DS14-23 Sundry Application 1 1/23/2009 • • Cretaceous/PC leaks with only one in its history, so it is not believed the failing CMIT-TxIA is indicative of a PC leak. The MIT-OA to 2000 psi passed on the same day. A PPPOT-IC on 12/11/08 passed. Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spoof in the three-ram drilling BOP stack. ~ ~~ 6~Z-, ~'}t/~ ~ ~ ~_ Scope of Work: The pre-rig work will include a P&A of the perforations with cement and making a tubing cut in prepare well for rotary rig sidetrack operations. With a rig on the well, operations will include pulling the tubing from the pre-rig cut, completing the P&A work if required, setting a whipstock and sidetracking the well to drilling the horizontal Sag objective as currently planned for the 14-23A well. MASP: 2506 psi Proposed Pre-Ria Work: 1. Load the tubing with seawater and fish/recover the IBP in the 4-1/2" tubing at 9470' MD. 2. Set DSSSV in SSSV nipple at 2151' MD to eliminate TxIA communication. 3. Perform an injectivity test which will dictate the P8~A plan to be used on this well. a. IF there is adequate injectivity into the perforations (>2-3 bpm at <1500-2000 psi), the Option "A" P&A will be performed which involves a cement down-squeeze below a retainer placed in the 5-1 /2" tubing at -9380' MD. b. IF there is NOT sufficient injectivity to the perforations (<2 bpm at >2000 psi), the Option "B" P&A will be performed which involves making tubing punches in the 4-1/2" 8~ 5-1/2" above the production packer at 9445' MD and then spotting a balanced cement plug from above a CIBP set in the 4-1/2" tubing at 9490' MD as the 1St cement plug to be placed in the well during the planned pre-rig work followed by placing a 2"d cement plug above a CIBP in the 9-5/8" casing at -9380' MD after the rig has moved on the well and pulled the 5-1/2" completion. 4. Pull DSSSV from SSSV nipple at 2151' MD. Option "A" P&A a. Make tubing punch at -9440' MD in the middle of the 10' 4-1/2" located just above the 9-5/8"x4-1/2" production packer at 9445' MD. b. Make tubing punch at -9354' in the 2nd full joint of 5-1/2" tubing above the production packer at - 9445' MD. c. Circulate the well to seawater through the tubing punches at -9400' & 9354' MD. d. Set retainer in the 5-1/2" tubing just above the tubing punched holes at 9334' MD. (Note: The distance between the retainer and the top of the perforations 708'.) e. Squeeze ~34 bbls of 15.8 ppg G cement below the retainer at 9334' MD (a volume of cement equal to the cased hole volume from the base of the retainer at 9334' MD to 10,162' MD (100' below the bottom of the lowest perforation at 10,062'))'. f. Un-sting from the retainer and re-circulate the tubing side to clean seawater. g. After cement has reached a minimum compressive strength of 500 psi, CMIT-TxIA to 2160 psi (.25 psi/ft to TVD of 9-5/8" casing shoe at 8625' TVD). h. Assuming a good CMIT in Step "g", jet cut tubing at 7000' MD and circulate the well to clean seawater. Option "B" P&A a. Set 4-1/2" CIBP in well at -9490' MD in the 4-1/2" tubing just above the 3-1/2" liner top located at -9495' MD. b. Make tubing punch at -9440' MD in the middle of the 10' 4-1/2" located just above the 9-5/8" x 4-1 /2" production packer at 9445' MD. DS14-23 Sundry Application 2 1/23/2009 • c. Make tubing punch at 9354' in the 2nd full joint of 5-1/2" tubing above the production packer at - 9445' MD. d. Circulate the well to seawater through the tubing punches as detailed above. e. Set a -8.2 bbl balanced cement plug above the CIBP in the 4-1 /2" tubing at 9490' MD which is a volume of cement equal to the tubing x 9-5/8" casing annular volume from 9445' MD up to the tubing punch in the 5-1/2" tubing at 9354' MD and the tubing volume from the top of the CIBP at -9490' MD to 200' up the tubing string to -9290' MD). f. Pull out of the balanced cement plug to above 9290' MD and re-circulate the tubing side to clean seawater. g. After cement has reached a minimum compressive strength of 500 psi, CMIT-TxIA to 2160 psi (.25 psi/ft to TVD of 9-5/8" casing shoe at -8625' TVD). h. Assuming a good CMIT in Step "g", jet cut the 5-1/2" tubing at 9172' MD in the middle of the 5th joint of the 5-1 /2" tubing (est TOC at 9290' MD) and circulate the well to clean seawater. (NOTE: The remainder of the P&A will have to be done after the rig moves onto the well and successfully pulls the existing 5-1/2" completion from the tubing cut at 9172' MD.) i. With the rig on the well, pull the 5-1/2" tubing from the cut at 9172' MD. j. PU drillpipe and make a 9-5/8" clean-out run to the top of the tubing stub at 9172' MD. k. RIH and set CIBP at -9142' MD (~30' above the top of the tubing stub.. 1. Set 200' balanced cement plug (-15 bbls) on top of the CIBP (estimated TOC at 8942' MD). m. After cement has reached a minimum compressive strength of 500 psi, CMIT-TxIA to 2160 psi (.25 psi/ft to TVD of 9-5/8" casing shoe at 8625' TVD). 5. Perform a PPPOT -T to 5000 psi & PPOT-IC to 3500 psi. 6. Cycle all LDS, repair or replace as needed. 7. Freeze protect IA and T with seawater and 2200' TVD of diesel. 8. Set a BPV and test to 1000 psi from tubing annulus (or maximum allowable up to 1000 psi). 9. Secure the well. 10. Remove well house and flow lines and level the pad as necessary. Proposed Drillina Ria Operations: 1. MI/RU. 2. CMIT-TxIA to 2000 psi and MIT-OA to 2000 psi to confirm barriers. (both tests expected to be good). 3. Pull BPV and circulate out diesel freeze protection and displace the well to seawater. 4. Set and re-test TWC to 1,000 psi from above and below. 5. As there is path-forward wellhead work to be completed, begin monitoring process of OA. 6. Nipple down tree. Nipple up and test BOPE to 3500psi. Pull TWC lubricator. 7. R/U & pull 5%" tubing from the cut depth at 7000' MD (or 9172' MD if the Option "B" P&A is required). 8. IF the OPTION "B" P&A is REQUIRED, set the CIBP in the 9-5/8" casing just above the tubing stub at 9142' MD and place 200' cement on top of the plug as detailed above. If the OPTION "A" P&A was performed during the pre-rig work, skip this step and move on to Step #9. 9. PU drillpipe and make bit and scraper run to the top of the tubing stub at 7000' MD. 10. RU E-line and RIH w/GR/CCUUSIT (in corrosion mode) to 7000'. (NOTE: The CCL & GR log will be used to find good KOP (a good shale / no casing collar) below the base of the WS2 and the USIT log run in the corrosion mode will be used to further evaluate the condition of the 9-5/8" casing above the window.) 11. RIH with HES EZSV bridge plug on E-line and set at 6723' MD, as required to avoid cutting a casing collar ~~~`1 ~ while milling the window. Test casing to 3500 psi f/30 min and chart. ~~~ 2. With 2 good barriers down-hole, split stack and change out 9-5/8" pack-offs and change-out Gray Gen 3 equipment ,,gyp to Gray New Standard equipment per Cameron wellhead specialist. "~'~~ 13. NU Wellhead/BOPE test breaks to 3500 psi and test pack-off to 3800 psi. 14. P/U and RIH with 9 s/a' Baker bottom-trip anchor whip stock assembly. Orient whip stock and set on EZSV bridge plug. Shear off of whip stock. 15. Displace the well to LSND based milling fluid per MI mud program. (End Work Under Sundry Approval #xxx-xxx /Begin Work Under PTD #xxx-xxx) DS14-23 Sundry Application 3 1/23/2009 16. Mill window in 9-`/," casing at 6700' MD, plus approximately 20' of new hole beyond middle of window and circulate well-bore clean. 17. Pull up into 9 ~/," casing and conduct a FIT. POOH. 18. M/U 8?/2" Dir/GR/Res/PWD assembly. RIH, kick off and drill the 8-%2" intermediate section to the top of the HRZ weighting-up the mud to 10.6 ppg prior to entering HRZ. Continue drilling to top of Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. 19. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. 20. After cement has reached a minimum 500 psi compressive strength, test the 9 `/," casing X 7" liner to 3,500psi for 30 minutes and record the test. 21. RU mud loggers for the planned Sag horizontal interval of the well. 22. M/U 6 1/8" Dir/GR/Res assembly. RIH to the landing collar. 23. Drill out the 7" liner float equipment and cement to just above the liner shoe and re-test the well to 3500 psi (10 min test). 24. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 25. Drill out the 7" shoe plus drill ~20' new formation; pull up into the shoe and conduct an FIT and drill ahead to horizontal landing point is Sag. 26. POOH for bit / BHA change. PU PDC bit and MWD/LWD as detailed in well plan and mad-pass build section as required by Geologist in real time before drilling lateral. 27. Drill horizontal section to planned TD, short trip as necessary. 28. Circulate, short trip, spot liner running pill. POOH. 29. Run a 4-%", 12.6#, L-80, IBT-M "slotted" production liner. POOH UD all drill pipe. 30. R/U and run 4-%2", 12.6#, 13 Cr-80, VamTop completion tubing. Land the tubing RILDS. 31. Reverse circulate inhibited seawater to the production packer depth. 32. Drop ball 8~ rod and set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. 33. Shear the DCK valve and pump each way to confirm shear. 34. Set a TWC and test to 1000 psi from above and below. 35. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. Pull TWC w/lubricator. 36. Freeze protect the well to 2,200' TVD with diesel. 37. Install BPV and secure the well. 38. Rig down and move off. Post-Ria Operations: (S-Riser Modification will be Reauiredl 1. MI / RU slick line. 2. Pull the ball and rod / RHC plug from landing nipple below the production packer. 3. Install gas lift valves. 4. Install well house and instrumentation. Estimated Pre-rig Start Date: 03/10/2009 Estimated Spud Date: 04/10/2009 Drilling Engineer: John Rose (907) 564 - 5271 Production Engineer: Olivia Bommarito (907) 564 - 4096 Geologist: Daniel Schafer (907) 564 - 5098 ATTACH: Current Well Schematic Post P&A Well Schematics (2) DS14-23 Sundry Application 4 1/23/2009 TRff = 'GRAY GEN 3 DATE REV BY COMuEiJTS DATE REV BY COMuBJTS 08N4/iS OW6INAL COMPlffr10N 10/14!03 JCMTLH GlV GO 02/13/03 JlG/TLH PULL BP 06/18/06 RCT/PJC SETS-1/2" SSSV 04/14/03 JJ/KAK GLV GO 05/28/07 JM:RLH PE4~IlNR CORR6CTI0NS 05/13/03 JJ/KAK GLVGO 08/058 OOB/PJC COLLAPS®TBG(10/8/98) 05/19/03 GJMTLH SET BP 10/15/08 006! P GRAVEL S(:RN CORRECTION (0' 10/01!03 BHGTLP PB2F SUMMARY CORRECTIO PRUDHOE BAY UNIT WELL: 14-23 PERMfT No: 1820870 API No: 50-029-20757-00 SEC 9, T10N, R14E, 2912.73' FEL b 2801.64' FNL 1P Btpbration (Alsska) TREE= ~ GRAYGEN3 WELLHEAD = GRAY 14-23A P8cA This ~ w it be preformed ~ there is adqua~ injecbvily ACTUATOR = AXELSON ~~ ~~ into the perforatbns to accomrodate a cement dow n- KB ELEV = 72' Option A squeeze bebw a retainer set n the 5-1/2" tubing. BF. ELEV KOP = 2800' Max Angb = 39 ~ 4500' Datum MD = 10060' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 2.625" ~ 2151' 5-1 /2" DMY SSSV Jet Cut 5-1/2" Tubing at -7000` MD' Cement retainer in 5-1/2" Tubing at -9334` MD Tubing Punch in 5-1/2" Tubing at -9354' MD 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, D = 4.892" 9434' TOP OF 4-1 /2" TBG-PC 9434' Tubing Punch in 4-1/2" Tubing at -9440` MC TOP OF 7" LNR 9490' TOP OF 3-1/2" LNR - CT 9495' I4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, D = 3.958" 9-5/8" CSG, 47#, L-80, D = 8.681" - CT, 9.3#, L-80, .0087 bpf, D = 2.992" ~-{ 10029' PERFORATION SIJM~MRY REF LOG: BRCS ON 06/02/83 ANGLE AT TOP PERF: 22 ~ 9922' Note: Refer to Production DB for historical pert data SQE SPF INTEF2VAL Opn/Sqz DATE 4" 4 9922 - 9924 S 06/12/83 3-1/8" 4 9980 - 10020 S 03/08/84 3-3/8" 4 10034 - 10042 S 10/08/93 3-3/8" 6 10042 - 10062 O 11 /10/93 3-3/8" 1 10064 - 10076 S 10/08/93 4" 4 10138 - 10140 S 06/12/83 PBTD 10440' 7" LNR, 29#, L-80, .0371 bpf, D = 6.184" 10440' _• " 9420' 5-1/2" BAKER PBR ASSY ' ' 9434' 5-1 /2" X 4-1 /2" XO ." ' 9445' 9-5/8" X 4-1/2" BKR FHL PKR /~ ~ ~" 9470' BKR IBP (05/19/03) 9495' 4-1/2"GLAND SUB, D = 2.990" (TOP OF LNR) 951'1' 4-1/2" CAMCO DB-5 LANDNG NIP, D= 3.81" 9523' 4-1/2" BAKER SHEAROUT SUB (BEIiIND CT) 9524' FISH: NOT NOTED 9524' 4-1/2" TUBING TAIL (BEHIND CT) r-~ _...._. ~. ...............,..,,... ~' ~. . GRAVEL SCRN SET 1/15/99, D = 1.75" ~ 3-1 /2" BKR SHOE DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/1N83 ORIGINAL COMPLETION 10/14/03 JCANTLH GLV GO WELL: 14-23 02/13/03 JLG/TLH PULL IBP 06/18/06 RCT/PJC SET 5-1/2" SSSV P62Mff No: 1820870 04/14/03 JJ/KAK GLV GO 05/28/07 JMGTLH PERF/LNR CORRECTIONS API No: 50-029-20757-00 05/13/03 JJ/KAK GLV GO 08/05/08 OOB/PJC COLLAPSED TBG (10/8/98) SEC 9, T10N, R14E, 2912.73' FEL 8 2801.64' FNL 05/19/03 GJM/TLH SET IBP 10/15!08 DOB/ PJ GRAVEL SCRN CORRECTION (0111 5/99) 10/01/03 BHC/TLP PERF SUMMARY CORRECTq 01/14/09 JGR Post Pre-Rig Work f/Rotary ST BP Expbratbn (Alaska) TREE= ~ GRAY GEN 3 WQLHEAD= GRAY ACTUATOR= AXELSON KB. ELEV = 72' BF. ELEV = Knp = aeon' Max Angle = 39 ~ 4500' Datum MD = 10060' Datum TV D = 8800' SS I 13-3/8" CSG, 72#, L-80, D = 12.347" ~ This ption w iN be util¢ed F there is not adequate 14-23A P&A infectivity into the perforations to accommodate a cement Option "B" dow n-squeeze procedure and w * be done w ith the rip on the w eN after puNing the 5-1 /2" completion. 200` of 15.8 ppg Class GCement - TOC 8942' MDR Cement retainer in 9-5/8" Casing at 9142' MDR Jet Cut 5-1/2" Tubing at 9172' MD-- Tubing punch in 5-1/2" tubing at 9354' MDR Est. TOC in 9-5/8"x5-1/2" Annulus at 9354' MDR PC, 17#, L-80, .0232 bpf, D = 4.892" ~ 9434' TOP OF 4-1/2" TBG-PC 9434' Tubing punch in 4-1/2" tubing at 9440' MDR 5-1/2" Tubing Stub at 9172' MD Est. TOC in 5-1/Z" Liner at 9290` MD 9420' S-1/2" BAKER PBR ASSY 1~ . ~ ~ 9434' S-1/2" X 4-1/2" XO ' 9445' 9-5/8" X 4-1/2" BKR FHL PKR ~ 4-1/2" CIBP -9490` MD TOP OF 7" LNR 9490' 9495' -i4-1/2"GLAND SUB, D = 2.990" (TOP OF LNR) TOP OF 3-1/2" LNR - CT 9495' ~ 9511' 4-1/2" CAMCO DB-5 LANDNG NIP, D = 3.81" 9523' 4-t/2"BAKERSHEA ROUT SUB (BEHIND CT) 12.6#, L-80, .0152 bpf, D = 3.958" 9-5/8" CSG, 47#, L-80, D = 8.681" ~ ~ 3-1/2" LNR - CT, 9.3#, L-80, .0087 bpf, D = 2.992" ~ PERFORATION SL11v~MRY REF LOG: BHCS ON 06/02/83 ANGLEATTOP PERF: 22 ~ 9922' Note: Refer to Productbn DB for historical perf data S¢E SPF INTERVAL Opn/Sqz DATE 4" 4 9922 - 9924 S 06/12/83 3-1/8" 4 9980 - 10020 S 03/08/84 3-3/8" 4 10034 - 10042 S 10/08/93 3-3/8" 6 10042 - 10062 O 11/10/93 3-3/8" 1 10064 - 10076 S 10/08/93 4" 4 10138 - 10140 S 06/12/83 PBTD 10440' 7" LNR, 29#, L-80, .0371 bpf, D = 6.184" 10440' 9524' FISH: NOT NOTED 9524' 4-112" TUBNJG TA N_ (BEHNVD CT) 10009' 10029' DATE REV BY COMMENTS DATE REV BY COMMENTS 06114183 ORIGINAL COMPLETION 10/14/03 JCMrTLH GLV GO 02/13/03 JLGlTLH PULL BP 06/18/06 RCT/PJC SET 5-1/2" SSSV 04/14/03 JJ/KAK GLV GO 05/28/07 JMC/TLH PERF/LNR CORRECTIONS 05/13/03 JJ/KAK GLV GO 08/05/08 OOB/PJC COLLAPSEDTBG(10/8/98) 05/19/03 GJMITLH SET N3P 10/15/08 008/ PJ GRAVEL SCRN CORRECTION (0' 10/01/03 BHC/TLP PERF SLNUMARY CORRECTIO 01/14/09 JGR Post Pre-Rig Work f/Rotary ST GRAVEL SCRN SET 1/15!99, D= 1.75" ~ 3-1/2" BKR SHOE PRUDHOE BAY UNR WELL: 14-23 PERMIT No: 1820870 API No: 50-029-20757-00 SEC 9, T10N, R14E, 2912.73' Fa 8 2801.64' FNL /15/99) BP Expbration (Alaska) Date: January 30, 2009 To: File , •~ ~) From: Jane Williamson - : /~ Subject: PBU 14-23 ;/ BP has requested approval to plug-back Prudhoe well 14-23 - Ivishak Zone 4 for later sidetrack targeting the Sag River. The well has TxIA leak and a rig workover is required. It has not produced since 2002. The well produced at 300 BOPD, 97% WC, and 30 Mscf/stb at the time of S/I. Nearby Ivisak wells are not producing well. As they have been unable to produce this well, it's difficult to determine whether this well would have any remaining reserves, however, my projections suggest about 500 MBD remaining in this well if it were able to regain production at rates in 2002. There is a need for Sag River wells in the area. Other Sadlerochit wells may drain any reserves remaining here. Tom, you should double check their analysis of where the T/IA leak is coming from. I recommend approval of this sundry request. ~~,~~~~ ~ -~ ~~ Q~r~~ ~ ~or~ g~J ~4z~ / Oil R~e(PD) (E6Ud) ~~` 105 Wier Gt (% ) c~ i al R9io(MdA~tl > PPT.PRESS ,- Ges Rate (PD) (Mtf/d ) 10' ,~ ~; ~' J _ h_ _ ~ "~ ] ~~i', 10 ' ' . a ., r ti ~~; ~., I ~ ;~r~,~ „~.rn~ toZ .~ _~ I 10 y j .~ 0 10 -: 10~-- ------ ------- -- ---- --- -----------~_~-_----------__._---__.--- 1984 g5 86 61 gg 8g 90 91 92 4i 94 95 ~ 97 ~ 99 200D 01 02 03 04 O6 O6 07 OB DATE VUxl6ng Fastest Paarre0ers ~ 10000 Phase :Oil Case Nacre Case1 b 0 `'~ Di 0.0998618Ae. qi 245.1656tl/d ti :12!31/XIfXi to :12131/2012 Fire) Rafe 99.9547 hhl/d } Cun Prod 8584.31 Mhhl 1000 •y ; : • ' Cun Dale :0531/2003 ~ ti Reserves 532148 Mhd Reaa~es Dafe : 12/dt/Z012 a ~ e ~ EUR 9116.46 Mttl a 500 ~ • S . ` ' • ~ jf Forecast Ended By :Rafe p • Sf • ti DB Forecast Dale :Not Sai~ed a • ~ • Reserve Type Nme m ~ _ 100 50 10 198485 ffi 87 86 89 90 91 92 93 94 95 96 97 98 99200001 02 03 04 O5 06 07 OB 09 t0 11 12 DATE STATE OF ALASKA ~~~y''"~8 ALA OIL AND GAS CONSERVATION COM~SION ~~ r. REPORT OF SUNDRY WELL OPERATIONS ~~~ ~ ~ ~~~~~ ~~ 1. Operations Performed: , _ . _ ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ^ Pufi Tubing ^ Perforate New Pool ^ Waiver ®Other , ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Exte Cancel 10-403; Planned Rig nsion Workover Not Conducted 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ~ ^ Exploratory 182-087 ~ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20757-00 ~ 7. KB Elevation {ft): 72, , 9. Well Name and Number: PBU 14-23 - 8. Property Designation: 10. Field /Pool(s): ADL 028312 ' Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 10440' ~ feet true vertical 9227' - feet Plugs (measured) 9470' Effective depth: measured 10082' feet Junk (measured) 9524' true vertical 8892' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 20" 81' 81' 1490 470 Surface 2508' 13-318" 2508' 2508' 5380 2670 Intermediate 9782' 9-5/8" 9782' 8613' 6870 4760 Production Liner 950' 7" 9490' - 10440' 8346' - 9227' 8160 7020 Scab Liner 534' 3-1/2" 9495' - 10029' 8351' - 8843' 10160 10530 Perforation Depth MD (ft): 10042' - 10062' Perforation Depth TVD (ft): 8855' - 8874' 5-1/2", 17# / 4-1/2", 12.6# L-80 9524' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" Baker'FHL' packer 9445' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~~~ ~~~ {~ ~ ~ 20D8 . . Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ^ Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ G1NJ ^ WINJ ^ WDSPL 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: Contact Katrina Cooper, 564-4212 306-403 Printed Name Terrie Hubble Title Drilling Technologist - a7 Freparetl By Name/Number: Signature Phone 564-4628 Date Terrie Hubble, 564-4628 Form 10-404 Revised 04!2006 Submit Original Only S AFL. J~JL 2 9 2008 ~'~~~ ~1R1(~I~01~1 VELLHEAD = GRAY ACTUATOR = AXELSON :B. ELEV..- 72' SF. ELEV = :OP = 2800' flax Angle = 39 @ 4500' ~ )atum MD = 10060' Yatum TV D = 8800' SS ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" I ~ 14 2 3 SAFEfY NOTES: FHUTIW: HBBP PKRS HAVE RED TEST PRESS. LIMITS. CONTACT ACE @ X PRIOR TO PRESSURE TEST. LDL @2894' 2151' S-1/2" DMY SSSV NIP, ID = 2.625" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2888 2886 11 CAMCO DMY RK 0 10/13/0 2508' 2 5129 4772 38 CAMCO DMY RK 0 04/14/0 3 6796 6086 37 CAMCO DMY RK 0 4 7900 6985 34 CAMCO DMY RK 0 5 8513 7489 34 CAMCO DMY RK 0 6 8579 7544 34 CAMCO DMY RK 0 7 8935 7849 28 CAMCO DMY RK 0 8 9003 7909 27 CAMCO DMY RK 0 9 9246 8126 26 CA MCO DMY RK 0 10 9315 8188 26 CAMCO DMY RK 0 • Minimum ID = 2.625" @ 2151' 5-1 /2" DMY SSSV 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" TOP OF 4-1/2" TBG-PC TOP OF 7" LNR TOP OF 3-1/2" LNR - CT -1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9420' -~5-1/2" BAKERPBRASSY 9434' g434' S-1/2" X 4-112" XO 9434' 9445' 9-5/8" X 4-1/2" BKR FHL PKR 9470' BKR IBP (05/19/03) 9490' 9495' 4-1/2"GLAND SUB, ID = 2.990" (TOP OF LNR) 9495' 9511' 4-1/2" CAMCO DB-5 LANDING NIP, ID = 3.81" 9523' 4-1/2" BAKER SHEAROUT SUB (BEHIND CT) 9524' -{FISH: NOT NOTED 9524' 9524' 4-1/2" TUBING TAIL (BEHIND CT) 9782' 9508' ELMD TT LOGGED 03/03/91 9800' ESTIMATED TOC (02/12/94) -1/2" LNR- CT, 9.3#, L-80, .0087 bpf, ID = 2.992" ~ 10029' PERFORATION SUMMARY REF LOG: BHCS ON 06/02/83 ANGLE AT TOP PERF: 22 @ 9922' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 9922 - 9924 S 06/12/83 3-1/8" 4 9980 - 10020 S 03/08/84 3-3/8" 4 10034-10042 S 10/08/93 3-3/8" 6 10042 - 10062 O 11/10/93 3-3/8" 1 10064 - 10076 S 10/08/93 4" 4 10138 - 10140 S 06/12/83 PBTD 10440' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10440' 10029' ~-~ 3-1/2" BAKER SHOE 10082' I-I GRAVEL SCRN SET 1/15/99, ID = 1-3/4" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 06/14/83 ORIGINAL COMPLETION 10/14/03 JCM/TLH GLV C/O WELL: 14-23 02/13/03 JLG/TLH PULL IBP 06/18/06 RCT/PJC SET 5-1/2" SSSV PERMff No: 1820870 04/14/03 JJ/KAK GLV C/O 05/28/07 JMGTLH PERF/LNR CORRECTIONS API No: 50-029-20757-00 05/13/03 JJ/KAK GLV GO SEC 9, T10N, R14E, 2912.73' FEL & 2801.64' FNL 05/19/03 GJMITLH SET IBP 10/01/03 BHGTLP PERF SUMMARY CORRECTION BP Exploration (Alaska) RE: 14-23 Integrity . . Subject: RE: 14-23 Integrity From: "Chebul, Josh M" <josh.chebul@bp.com> Date: Mon, 14 May 200710:33:18 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> \~.~-(J~'1 Thanks for the super-prompt reply. My apologies for the old schematic, I guess the correct one that shows cement hasn't been uploaded yet. Yes, it was cemented in place. I'll make sure in future documents the applicable schematic is included. Thanks, Josh From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, May 14, 20079:41 AM ~GANNED JUL 1 0 2007 To: Chebul, Josh M W Subject: Re: 14-23 Integrity Josh, The key is having integrity after the work. Although the drawing doesn't show it, I presume the CT liner has been cemented in. If that is the case, it seems that successfully accomplishing your proposal should re-establish integrity. So far as any steps, you need to submit a sundry for the work and a witnessed MIT will need to be performed once the well is back in operation. Call or message with any questions. Tom Maunder, PE AOGCC Chebul, Josh M wrote, On 5/14/2007 9:21 AM: Tom- In December and January, you and I exchanged some e-mails regarding a plan to rig workover and convert to WAG injection well 14-23 in Prudhoe Bay. That project has been delayed until late 2008 because a concurrent project has been deferred. In lieu of working the well over today, we would like to set a patch that simulates a liner top packer to restore integrity to the well. It is currently shut in because of a packer leak. Could you review the attached schematic and advise if the state considers the following make-up acceptable, and what steps we need to pursue with the state if so: 4.5" KB packer inside tubing at -9485'; Blank pipe from -9490'-9500'; and 3.5" KB packer inside liner at -9500'. This means the IA would be blocked from communication from the formation by cement behind the liner and from the tubing by the new packers. Upon setting the patch, we would pressure test the IA to 3000 psi. «14-23.pdf» Please review and contact me with any questions. Thanks, Josh Chebul lof2 5/14/200711:19 AM . . SARAH PALIN, GOVERNOR AI~~1iA OIL Al'WD GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 .' __",Wit',·",,,, Dave Reem Drilling Engìneer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 5CANNED JAN 1 '120D7 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU 14-23 Sundry Number: 306-403 \I{¡'J: ö t 1 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, o Chai DATED this /6 day of January, 2007 Encl. " ~' ~ pJoÝAœf(;J~~XtEOFALASKA ~/r~ ~de,RECEIVED o~ , 1)1 A~ OIL AND GAS CONSERVATION COM.ION ~ APPLICATION FOR SUNDRY APPR~ALlgcember 20,2006 '.6. 20 AAC 25.280 Alaska Oil and Gas Conservation Commission Operational shutdown 0 Perforate 0 -~ Other 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Convert to WAG Perforate New Pool 0 Re-enter Suspended Well 0 Iniector 4. Current Well Class: 5. Permit to Drill Number: Development 0 Exploratory 0 182-0870 ' Stratigraphic 0 Service 0 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: 1. Type of Request: ADL 28312 12. Total Depth MD (ft): 10440 Total Depth TVD (ft): 9227 Length Casing Structural Conductor Surface Intermediate Production 81 2508 9782 Suspend 0 Repair well 0 Pull Tubing 0 50-029-20757-00 8. Well Name and Number: PBU 14-23 No 0 10. KB Elevation (ft): 11. FieldlPool(s): 72 Prudhoe Bay Field I Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10082 8892 Plugs (measured): Junk (measured): 9470 9524 Size TVD Burst Collapse 1490 470 5380 2670 6870 4760 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 81 2508 9782 81 2508 8613 Liner 950 7" 29# L-80 9490 - 10440 8346 - 9227 8160 7020 Scab Liner 534 3-1/2"CT 9.3#L-80 9495 - 10029 8351 - 8843 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10042 - 10062 8855 - 8874 5-1/2" 17# /4-1/2" 12.6# L-80 / L-80 9434/9524 Packers and SSSV Type: Packers and SSSV MD (ft): 9-5/8" Baker FHL Packer /5-1/2" DMY SSSV Nipple 9445/2151 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 10/1/2007 16. Well Status after proposed work: Commencing Operations: Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Dave Reem Title Contact David Reem, 564-5743 l-:r~ Ght.bJ sr..,. 13 Signature Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3OLi-4oð Plug Integrity 0 BOP Test ø( Mechanical Integrity Test )!1, Location Clearance 0 Other: Y GD 0 ç><i, \SO V .~ c:.þ- Approved by: Form 10-403 Revised 06/2006 RBDMS BFL JAN 200ì APPROVED BY THE COMMISSION Date: /,.It ,.dr- IGINAL Submit in Duplicate õ . . December 15,2006 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 9950 I Dear Winton: RE: Sundry Notice for 14-23 --- Conversion trom Production to WAG injection well. BP Exploration Alaska, Inc. proposes to convert well 14-23 to a WAG injection well after abandoning the current perforations. The tubing will be changed out to assure the mechanical integrity of the tubing, and a CMIT - TxIA pressure test will be done both before and after the tubing has been replaced to assure the mechanical integrity of the production casing. Because the current packer is leaking, the first CMIT - TxIA will only test to 1000 psi to confirm integrity; the rig will test to the required 4000 psi prior to setting the new packer. After this has been completed, new perforations will be added in the Sadlerochit. Step Type Procedure 1. S Drift & Tag IBP 2. C PuIlIBP, Investigate Fish, Squeeze perforations, MITOA, CMIT-TxIA to 1000 psi 3. 0 Pull TBG, Run new TBG, CMIT-TxIA to 4000 psi 4. C RST from TD-9600', Add perforations from 9878-9918' MD and 9930-9960' MD Preliminary engineering work is underway to convert the surface facilities of 14-23 to water and gas injection service. The objective of the conversion is to provide pressure support to current producers, improve volumetric sweep efficiency, and mobilize and capture remaining oil saturation in Updip Zone 4. This program is consistent with a larger regional strategy to manage and develop the GDWFI area in a manner that considers the maturity of the waterftood areas, the maturing of the GD process, and the possible impact of gas sales on overall recovery. The plan is to begin injection (MI followed by water) in late 2007 as outlined in the latest UZI development plan. Included are the scanned Cement Evaluation Log (06/24/1983), a Borax RST log (07/24/1998), the current wellbore schematic, and the proposed schematic. Squeeze jobs have targeted 9922- 10140 (10/13/1989 & 10/8/1993). A 3-1/2" Coil Tubing Scab Liner was cemented trom 9495' to 10029' (2/11/1994) to isolate leaking Squeeze Perfs. The Borax RST log indicates that there is no channel above 10020 ft. The nearest offset wells are 14-41, 14-19PB1, 14-43, and 14-20. The nearest bottomhole location belongs to 14-41 at a distance of 1266 ft; none of the others are within 1320 ft of 14-23. . . If you have any questions, please call me at 564-5673. Since ely, /l / P // uaca~/ DS 14 Production Engineer . . 2112194 W4J41: API1t: DS '.,..23 ~RèV. -Ii?< ¡tJ. f- ~.: 4nf93 3.5" Scab Liner Completion Date: Workovtr Type: LiIIÐtIGSO ';';:" ;ž "Av"3~and" Surqpry: '7'-;K tJ A scab liner ~ion ...,u comp/llt«J CII 14·23 placing 534' of 3.5" FL4S /inf( from tubing tall to 10029' md. Wïth (" sand (;(JWring fhè op.n ~.. 15 bbJs of LARC wa, PlJtnpÐd placing 2 BBP rø 1000 psi IHvjng 2 bbIt 01 LARC W· if? rh, JiMr (ilst. TOC 9800' md). Approximat(fy 9 bbls 01 LARC was c.irctJtalsd into thfJ annulus ~ ". 1,.lrtg ¡?, squHZS þ{iI'foradoM. POsl rqz tag was 980'1' md, leaving 226'10 drìH orA. PO$f drilVFCO ptOduclion is 500 8OPD. .J tooo BWPO, IBOO GOR doWfl /rcm over 20000 GOR. ~:5::- . ~pb Cvervl4rwlSummal'}': ;$ ~~ Pre ¡ob sand p~t ....s comp¡.tfþ(j 10 ptOtBCl ttJø ptHtoratiorts, PosI $and dump tag ....as rOO33' md (9' 0".' ~ perfS). I~.y pøsI sattd was 0.75 BPI.( 1500 psi. ~:;: ~ CTU (2- coilJ was RU on .2/1o.11snd rlNl in :t534' of 3.S-liller (9.2#$ FL4S joinl«i p;p.) WJYh 3.S· ~ shoø tMd i;¿ coI4f 'GS' tith ntdc ~f1I COtMy«l with hydrau6c GS COol Thø /In., was RfH (pfessure depIoytHJ with 200 ¡ui WUP) W MId landed CII 1M ItÏpfM with the fish "d. Ch6dc "alves WfHØ hoIdlfÞ(} ¡Ifhi" I1.mning liMr. as was piJrnptJd oft and v' CTU W41S POOH. ¡:~ 2" CT Will RU on 2/t2 with sting., usl sssembfy. CT w.u RIH circu14tittg IGOoF fHwafofl. Onœ al Ñ'l9 ~, th. .~ stingel Wà$ stabb«J in ths fi$sJt fI.øc. AIl.r bfHdirIg dowt) IJJÐ CT. th9 did vaNfi ...,.e pIIf 011 ust by putnptlfg :git do_ IÞø baclcsithl with a dH1erøntíaf b9fWHt1 the CT IIId backsid9 of 1500 psi and hokiinrJ. SIW wss <;itcuJated fti, down OT up bllClt.ide fAt,hittg IJfty remaining gas tram tho "~. 285 bbI$ of w circulated 111M ,w~ to ¡It pumping 65 bb#s ~ dcnvn bac:/t.sid. In 1.3 BPM, , SOD psi. ,}, PumpiÞd 15 bbJ$ LARe with 39 bbls StW disptaoøment leaving 2 bb/s in lint( (.$1. TOC in Dr 98()(f rnd}. Cem8flt ~Ù was circutated inlo place at -2 BPM taking rerums al SOO psi With cmI at top of pM' in SIInfJlus. dtok. St. PIaC6d ;~ ·0.5 SSP to 1000 psi and toøI< fÐturn$ IayjrJg in emt in th6 ..ntlu.vs with (lIpPrDx.} 2 SBP " '000 psi tqUHI. .j prHSUfe. Afttr $ min "'-$itation and bIeedoll to 850 psi WHP, pumped lip sqz 10 7000 psi with backsid. af7dCT 1~ both Increasing. CT wa,s quICkly bled 10 0 psi S'iating the ball ch9Ckllalvfs. W.th WHP 700 p$Ï snd CTP 100 psi. h pvntp{Kl1.op WHP to 1000 psi wifh only 0.3 bbls pumped with $light blHdofi Aft., bumbírlø CT up to 300 psi, CT ¡¡i WU Ufl$RIIIg from fish ~ 1M PC:)QH t;;n;ulating .t 750 p$i WHP. ;'Í-' Post #in« tag wu 9807' rnd, righr on targfH "allÍlfg 226' to dr/1J out. Sqz was PT'd to 2000 psi. ::r< .; ;".;0 ,~ ¡~ DI8CUfJ'donlReconunendatio.u: "* ~; Squeeze ptÐSSCJ(' MV« held slNdy at '000 psi. This is susptidffld to N csuud by T K 9 communícatleJrt and fJM$ ~~ ¡,: ..as wspec:fttd to be on th8 artlJ(tls. .. .::~ ~;~ "'; ~~¡,; .', ~~.. '. JJ.n; ~-t./ . ., . lÞ Data: 3/24/94 'i} Signed: "';. -¥ee: '¡¡'J. L. Ce.wvey, ATO·15t2 (page 1 only) ¡~. Coop8rJlance, PRS 24 ~, SUr\'eìllance Engineet .~^' WorkOYer Engine.. " ZWO!kovllr,J.l ,~.~ }._-~!"- .. .~:.:'~>' ~':~~~::¡Ï:~,'~~~,;;r~;,:~L.j;:::::~~:::,'~:;~::,;r:~'~~";ø:~··:~~, ~-..., {·.r i to!: .'" ).' !L·.I:/· ..<, v~ \~" ,....: T -. -"''0' .., .:;: ..:~ BORAX Log 07/24/1998 CRUDE Pass 1/ BORAX Pass 3 OVERLAY . . TREE" GRAY GEN3 WEllHE'AD .. <>MY 14-23 SAFETYNOTES: FHLITIW: HBBP PKRS HAVE ACTUATOR .. AXElSON REDUCED TEST PRESS, UMITS. CONTACT ACE@ KB. ELEV .. 12' X5102 PRIOR TO PRESSURE TEST. lDL@2B94' Sf. 8.ËV " KOP= 2800' 2151' H5-112" DM'( SSSV NIP. D" 2.625"1 Max Angle = 39 @ 4500' ~ Datum Me " 10060' Datum lYO '" 8800' S$ GA.S LIFT MANDRB..S 5T MD lYO DE\! TYPE VlV LA.TCH !'ORT DATE 1 2888 2886 11 ~MCO [)MY RK 0 10/13103 I 13·3/8" CSG, 72#. l·60. D = 12.347" 2508' -µ ~ 2 5129 4772 38 CAMCO [)MY RK 0 04114/03 ~ 3 6796 6086 37 ~.MCO [)MY RK 0 .4 1900 6985 34 ~MCO OM'( RK 0 5 8513 7489 34 ~MCO [)MY RK 0 Minimum ID = 2.625"@ 2151' 6 8579 7544 34 ~MeO DMV RK 0 7 8935 7849 28 CAMeo OM'( RK 0 5.112" DMY SSSV 8 9003 1909 21 CAMeo DMV RI< 0 9 9246 8126 26 CAMCO [)MY RK 0 10 9315 8188 26 CAMCO DMV RK 0 ~ ~ !---i 9420' 5·1!2"BAKERPBRASSY I 15-112" TaG-PC. HII.l-80, .0232 bpf. ID ..4.892" 9434' J.... ~ 9434' HS-112"X4·112" XO I I TOP OF 4·112" TaG-PC 9434' ~ 9445' 9-5/8' X 4-1/2" BKR FHL f'KR I 8 tX V .-I 9470' BKRIBP(05l19103) I TOPOF7"I.NR 9490' II!I!:::':!!II ~ 9495' 4-112' G LAND S1.8, ID" 2.990" (TOP OF lllFt) I , p¡¡q ITOPOF 3-112" lNR - CT 9495' v"'" 9511' 4·1/2"CAMCODB·5LAIII)NGI'F, 1D=3.81" I - ..,... I 9523' H4-112" BAIŒR Sl-EAROUT SUB (BEHII'DCT) I -. 9524' I- FISH NOT NOiED I 4.112" TBG·F'C, 12.6#.l-80, ,0152 bpf, ID.. 3958" 9524' I 9524' I- 4-1f2" T\JÐNG TAL (BEHII\D en I 9-518" CSG, 41#. L.80, 10 =8.681" 9782' ~ ... i 95GS' H EI.MD 1T LOGGED 03103191 I I ESTIMATED TOC 9800' I I 3-112" lNR- CT, 9.3#.l-80,0087 bpf. ID.. 2.992" 10029' L. ÆRFORA T()N SUMMARY '" REF lOG: BHCS ON 06102183 ~ ANGlE AT TOP PERF: 22@9922' 10029' H 3-112" BAKER SHOE I Note.: Refer to Ftoouctbn DB for hìs1Ofica! perf data [)o~ SIZE SPF INTERVAL OpnlSqz C\<\.TE 4" 4 9922 - 99.24 S 06112183 3-118" 4 9980 - 10020 S 03fOðl84 II 3·3/8" 4 10034 - 10042 S 1 010819~ 3-318" Ii 10042 - 10062 0 11/10193 3-318" 1 10064 - 10076 S 10108I93 .t" 4 10138" 10140 S 06112183 I raID H 10440' I '. 10082' -J GRAVe.. SCRNSEi' 1/15199,10" 1.3/4" ! 7·l~, 29#. L-80, .0371 bpf, ID '" 6.184" 10440' . DATE Æ'lBY COMMENTS C\<\.TE RENBY COMIIIEmS PROOI1OE SAY UNIT 06114/83 ORIGINAL COMPLErION 10114103 JCMITlH GlV C/O WELL; 14-23 02113/03 JlGItIh I'Ut..L IBP 00/18106 RCTIPJC $ET5-112" 5SSV ÆRMIT No: ''u120870 04/14í03 .IJ/KA K GlV ClO API No: 50-029-20757-00 05113103 JJJKAK GlV CJO SEC9, T1ON. R14E. 2912.73' Fa. & 2801.64' FNl 05/19103 GJWTLH SET taP 101'01/03 B/-ICITlP PERF SUMt.NI.RY CORRECTK)N< BP Exploration (Alaska) '" . ) ... . . 1REE'" GRAYGEN3 WELLHEAD" GRAY 14-23 PROPOSED ACTUATOR.. AXELSON KB. EI..EV .. 72' SF. El.Ðt " KOp· 2800' 1-14-1/2" liES 'X' NIP Ð" 3.813" I Max Angle '" 39 @ 460(1' DetumW" 100e0' Datum lYD :: 8600' 55 I 13-3/8" CSG, 12#, L-80, ID" 12.347" 2508' -µ ~ I Minimum ID = 2.625" @ 9495' ~ 1'14-112" HËS 'X' NIP 0" 3,813" I 3·112" COIL TUBING LINER ~ 8 --I 9-tîI8")< 4·112" SAKe( 53 PKR 10 '" 3.87:>00 I -t4-1!2·ÆS'X'~gpID"'3.a13" I 14.11:~" T8G, 12611, [,·IJO, 0152 bpI, I[Þ 3958" I -I4-HZ'MUlESHœ I ~ l - 9420' -i5·112' BAKERF9RASSY I !5-112"TBG-PC.17I1. L-80, .0232bpf.ID..4.892" 9434' '--- .-""" 9434' -¡ 5·112" X 4- 112" XO I ITOÞOf 4· 112" TIm-pc 9434' .A 9445' -{9-518" X 4-112'" BKRFHI.. R<R I ~ ~ ,/'" IroPOf 1" LNR 9490' I ~ - 949fr 1-14-112" G LAND SUB, 10:: 2.990" (TOPOF LNR) I ,.;, I TOP OF 3-112" LNR- CT 9495' I ~ 9511' 1-14-112" CAMCO 08-5 LAIÐNG NIP, ID" 381" I I 9523' 1-14.112" BAKER Sl-EAROUT sua (BEHN:I CT) ! .14-1t:!" TaG-PC, 12.6#, l-80, .0152 bpt.lO- 3.958" 9524' I H4-1i2"T1.I9ING TAL (SEHWCT) I 9524' I 9·5f8" CSG, 47#,l-80,1O = 8.681" 9782' þ- .... .. 9508" HELM[) TT lOGGED 03(\)3/91 I I ESTIMATED TOC 9800' pm 3-112" LNR· CT, 9.3#, l-80. ,0061 bpf. 10 '" 2.992" 10029' "- ~TION SUMMARY '" REF LOG: BHCS ON 00102183 ANGLE AT TOP PERF: 22 @ 9922' 10029' H 3,,112" BAKER SHOE I 1Ibte-: Refer 10 A'oduction tEl for hÎ$IO/ic;t1 perf dalOil II SIZE SPF INTER\! AL OpnfSqz DArE 2" 6 9878· 9918 ,....,. I) 9930 996(; L I 4" 4 9922 - 9924 S 00112/83 3<1/8" .$, 9980 - 10020 S OJID8J84 3<3f8" 4 10034 - 1 0042 S 10108/93 3..318" 6 10042 - 1 0062 S 11110.'93 3-3f8" 1 10064 - 10076 S 10108193 4" 4 10138 - 10140 S 00112/83 ~ 10440' 1 10082' 1-1 GRAVEl $CRN$ET 1/15199, 10..1·314" I "":.,; I 7" LtIR, 29#, L-OO, .0311 bpi. 10 '" 6.184" 10440' . DATE ÆVBY COMMENTS DATE RE.VBY CO!.IwENTS PRUDHOEBA Y lHT 06114/83 ORIGINAL COMPLETION 10/14103 JOHTlH GLV C/O WEll: 14-23 02113103 .)loru!) I'UL l iBÞ 00118106 RC'fiPJC SET 5-112" SSSV PERMIT' No: '1820870 04114103 J.1IKAK GlV C/O 11 t09106 FVF~ PROf-USfO Cût\lH.FllON API No: 50.029-20757.00 05113103 JJiKAK Gl V C/O SEC9. T10N, RIllE 2912.73' FE!.. & 280HW FNl 05119103 GJM'TlH SET IBP 10101103 BHCfTlP PERF SUMW,RY CORRE~ 8P Exploration (Alaska) FW: 14-23 workover/conversion . . Tom- I don't know how professionally you need the data you mentioned, but if this e-mail doesn't suffice, please let me know! Things you mentioned as lacking include: descriptiveness in workover steps; workover fluid weight; proposed BOP test pressure; BHP & MASP data/calculations; proposed workover date; and proposed POI date. The first three are covered in the attached "Scope of Work" document provided by Dave Reem. The last three are discussed below: «14-23 AOGCC Scope of Work.zIP» BHP and MASP Data The BHP in 14-23 was most recently measured as 3,355 psi at 8,800'SS on 10/14/1998. Offset wells studied in that timeframe have declined on average 140 psi in reservoir pressure since then. The expected current BHP is 3,210 psi. The only injector in the region, 14-01A, has been shut in since fall of 2005, meaning the well has had no pressure support. Note: the attached "Scope of Work" document calculates tubing MASP based on 3250 psi BHP and returns a figure of 2370 psi. The MASP of this well for each of the annuli falls under general injection guidelines of 2000 psi as maximum IA operating pressure and 1000 psi as maximum OA operating pressure. Proposed Timeline The technical package for this workover has been issued to partners, but it has not been approved yet. As such, the well is not on the rig schedule, so proposed dates of the workover and the POI date are expected to change. As mentioned in the application, the conversion is part of the WW3E project. The project has been deferred until 2008, but this well is long-term shut in and can have value before the goals of WW3E are met. The workover tentatively begins on 10/1/2007 and lasts ten days. The goal is to have surface equipment hooked up and the well online within thirty days of the rig's departure. The POI date is thusly scheduled for 11/10/2007, but the schedule is not concrete. Please let me know if there is any other data you need. Thanks for contacting me regarding this matter. Regards, Josh Chebul -----Original Message----- From: Reem, David C Sent: Tuesday, January 02, 2007 10:27 AM To: Chebul, Josh M Subject: FW: 14-23 workover/conversion lof2 1110/20078:24 AM FW: 14-23 workover/conversion . . Josh, pis see Tom's note on what we have lacking on the 14-23 project. -----Original Message----- From: Thomas Maunder fmailto:tom maunder@admìn.state.ak.us] Sent: Wednesday, December 27,20067:34 AM To: Reem, David C Subject: Re: 14-23 workover/conversion Dave, Would you please pass this message on to Joshua. My attempt to figure out his eddress didn't work. Thanks, Tom Thomas Maunder wrote, On 12/26/2006 3:36 PM: > Joshua, > I have received the packet for the workover/conversion of 14-23. Well > put together, but it seems there should be a little bit more of a > descriptive procedure for the workover than the 4 steps given on the > first page of your letter. Information should also include BHP/MASP > data/calculations, vorkover fluid weight and proposed BOP test > pressure. A date of 10/1/2007 is given for the commencement date. Is > that for injection or for doing the workover? > Thanks in advance for reply. Call or message with any questions. > Tom Maunder, PE > AOGCC > Content-Description: 14-23 AOGCC Scope of Work. ZIP 14-23 AOGCC Scope of Work. ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 20f2 1/10/20078:24 AM . . OS 14-23 Rig Workover -- Producer-to-Injector Conversion Scope of WOrk[pcl]: Pull 5-%" L-80 completion, run 4-%" L-80" premium connection stacker-packer" completion. MASP[pc2]: 2370 psi Well Type: Ivishak Producer (current) converting to Ivishak WAG injector (proposed) Estimated Start Date: mid- 2007 P k re-rtQ [ reD wor [[uc31: 0 1 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. S 2 Drift 5-1/2" L-80 tubing for composite plug/chem. cutter. PulllBP from tubing tail. E 3 Set 5-1/2" Weatherford WRP in tubing tail. Chemically cut 5-1/2" tubing in middle of 1st full joint above FHL packer. F 4 Circulate well with seawater and freeze-protect with diesel thru the cut. CMIT TxlA to 4000 psi. MITOA to 2000 psi. Bleed WHPs to 0 psi. 0 5 Set a BPV in the tubing hanç¡er. 0 6 Remove the wellhouse & flow line. Level the pad as needed for the riq. Proposed Procedure[pc4] 1. MIRU. NO tree. NU BOPE with 3-1/2" x 6" VBR pipe rams. Pressure test to 4000 psi. Annular preventer tested to 3500 psi. Circulate out freeze protection fluid and circulate well to clean kill weight brine through the cut. 2. Pull and LD 5-%" tubing string to the cut. 3. Dress off 5-1/2" tubing stub and scrape 9-5/8" casing. 4. Retrieve the WRP from the old tubing tail. 5. Run 4-%", 12.6#/ft, L-80 TC-II stacker packer completion with Baker S-3 packer. Position packer -90' above the 5-1/2" tubing stub. 6. Displace the IA to packer fluid and set the packer. 7. Test tubing and IA to 4000 psi. Freeze protect to 2200' MD. 8. Set BPV. NO BOPE. NU and test tree. RDMO. Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 10/31/03 NO. 3017 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color ( Well Job # Log Description Date Blueline Prints CD H-19B 1 c~ ~ L~ ,MEM PPROF & IPROF LOG 09/29/03 H-27A ~)~'~ ~ O( MEM PPROF & IPROF LOG 10/0t/07 D.S. 1-10 ~ ~--~ ~ PSP LDL 10/25103 JX-0= D.S. 14-23 .1~'O~ PSP LDL 10124103 D.S. 4~2~ q ~ - I ~ LDL J0/22103 GNI-02 [~_~'~ TEMP PROFIL~SBHP SURVEY 10/08103 D.S. 6-~6 i~O~O~ LDL 10/12107 PI-18A ~-~~ PROD PROFILE W/DEFT 10/15/07 D.S. 5-28A ~ ~ [~% LDL 10/14/03 D.S. 12-20 [~1~ LDL 10/21/03 2-321SN-03 t ~ ~ ~'~, LDL 10125107 Z-39 ~~ ~ 10563105 RST-SIGMA 09122103 =LEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd..,~¢,.!~,~.: .'~ .',,'¢. ..... "" ~,'~'"%.?. ~ ~'~¥,~i~ ..... .,~;.~" '~;~ Anchorage, Alaska 99508 ..~, .~:;~.,~ .-~-! .... Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ACID TREATMENT Operation shutdown_ Stimulate _X Plugging_ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development mX Exploratory__ Stratigraphic__ Service__ 4. Location of well at surface 1403' FNL, 2016' FEL, Sec. 09, T10N, R14E, UM At top of productive interval 3000' FNL, 2863' FEL, Sec. 04, T10N, R14E, UM At effective depth 2805' FNL, 2922' FEL, Sec. 04, T10N, R14E, UM At total depth 2805' FNL, 2922' FEL, Sec. 04, T10N, R14E, UM 12. Present well condition summary Total depth: (asp's 674460, 593892~ (asp's 673520, 5942582) (asp's 673456, 5942776) (asp's 673456, 5942776) measured true vertical 10440 feet Plugs (measured) 9227 feet Effective depth: measured true vertical 10440 feet Junk (measured) 9227 feet Casing Length Conductor 81' Surface 2472' Production 9746' Liner 950' Scab Liner 534' Perforate _ Other _ 6. Datum elevation (DF or KB feet) RKB 72 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-23 9. Permit number / approval number 182-087 10. APl number 50-029-20757-00 11. Field / Pool Prudhoe Bay Oil Pool Gravel SCRN Set @ 10082' (01/15/1999). Size Cemented Measured Depth True Vertical Depth 20" 375 sx PF II 117' 117' 13-3/8" 1500 sx Fondu, 400 sx 2508' 2508' PF 'C' 9-5/8" 500 sx Class 'G', 313 sx PF 'C' 9782' 8613' 7" 300 sx Class 'G' 9490' - 10440' 8346' - 9227' 3-1/2" 11 bbls LARC 9495' - 10029' 8351' - 8843' Perforation depth: measured Sqzd Perfs 9922'-9924', 9980'-10020', Open Perfs 10034'-10062', 10064'-10076'. true vertical Sqzd Perfs 8743'-8745', 8797'-8835', Open Perfs 8848'-8874', 8876'-888.7'. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 5-1/2", 17#, L-80 TBG-PC @ 9434' MD; 5-1/2" x4-1/2" XO ~.~9434',~ ....... ' ........ ' ,,";.': ....... F:"~% 4-1/2" 12.6#, L-80 TBG-PC @ 9524'. '.,, ..."....,."' . ....... ~,. ", ...~.-..:.' 9-5/8" x 4-1/2" Baker FHL Packer @ 9445'. 5-1/2" Camco BAL-O SSSV Nipple @ 2151' MD. ,.,,.~..~...,-'..,, .?"...~. :':'~'~ ;..' ~";, ~'¥"i,':.',~ ,. ,~,., ..~ 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure . .,, 14. Prior to well operation 02/28/2003 Subsequent to operation 03/11/2003 Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 195 4865 6558 232 4964 7475 Casing Pressure Tubing Pressure 555 443 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. Title: Technical Assistant Date Mamh 17, 2003 DeWar/ne R. Schnorr Prepared b~/DeWar/ne R. Schnorr 564-5,~Z4 R B DM $ B F [ I Form 10-404 Rev 06/15/88 · ORI¢INAL SUBMIT IN DUPLICATE 02/12/2003 02/13/2003 02/13/2003 02/19/2O03 02/19/2003 02/20/2003 03/03/2003 03/04/2003 03/05/2003 03/08/2003 03/12/2003 14-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ACID: ACID: ACID: ACID: ACID: ACID: ACID: ACID: ACID: SCALE REMOVAL; TUBING WASH / PICKLE LOAD WELL TO SECURE ACID TREATMENT SSSV C/O OR STROKE SSSV C/O OR STROKE BRUSH / BROACH; SSSV C/O OR STROKE ACID TREATMENT DRIFT/TAG; SSSV C/O OR STROKE SSSV C/O OR STROKE ACID: AC-TIFL TESTEVENT --- BOPD: 318, BWPD: 7,778, MCFPD: 6,960, AL Rate: 0 02/1 2/03 02/13/03 02/13/O3 02/19/03 02/19/03 02/20/03 03/03/03 O3/O4/O3 EVENT SUMMARY MIRU UNIT #9. PREFORM WEEKLY BOP TEST. SHUT-IN WELL AND PREP TO LOAD IA. LOAD IA AND TUBING. BH 25 BBLS 12% HCL WITH ADDITIVES DOWN TUBING. LET SOAK FOR 30 MINUTES. SWAPPED TO COIL AND PUMP 50 BBLS ACID WHILE RIH AND RIClP. ACROSS SSSN AT 2151'. LOAD IA THEN PUMP AT LOWER RATE WHILE COIL DOES TUBING ACID TREATMENT. DISPLACE ACID FROM TUBING WITH 110 BBLS SEAWATER AND 250 BBLS DEAD CRUDE. RDMO. NOTIFY DSO TO POP WELL AFTER GL SPOOL IS RIGGED UP. DRIFT FOR DSSSV. SAT DOWN @ 3' SLM W/4.55 GUAGE RING. DISCOVERED SCALE ON TUBING WALL @ 25' SLM. BEGIN BROACHING. STARTED W/3.625" BROACH. WORK UP TO 3.75". FREEZE PROTECT TUBING AND FLOWLINE. EIGHT BBLS OF METHANOL, 75 BBLS OF CRUDE, 5 BBLS OF METHANOL PUMPED DOWN FLOWLINE. EIGHT BBLS OF METHANOL & 65 BBLS OF CRUDE PUMPED DOWN TUBING. BROACHING TO 4.125 OD, MADE IT TO 94' SLM. DECIDED TO RDMO NEXT LOCATION. <<< WELL POP >>> FULLBORE TUBING ACID FOR SL TO SET DSSSV. PUMPED 50 BBLS DAD ACID DOWN TUBING PUMPED 20 BBLS 50/50 DIESEL/XYLENE MIXTURE. <<< WELL RELEASED TO DSO >>> DSSSV, MIRU,TAKE CONTROL & EXERCISE SSV, PURGE CONTROL LINES. <<< JOB IN PROGRESS >>> Page I 03/05/03 03/06/03 03/12/03 (" 14-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS SET 5-1/2 CA-DSSSV @ 2131' SLM (69" OAL - 2.75" MIN ID - 3 SETS PKG). <<< FLOWING >>> T/I/0=500/1220/860 TIFL FAILED POST DSSSV C/O. BLED IA FROM 1420 PSI TO 870 PSI IN 1.5 HRS. THE IA FL STARTED AT 5970' AND ROSE TO SURFACE IN 1.5 HOURS. <<< WELL TO BE POP >>> TESTEVENT--- BOPD: 318, BWPD: 7,778, MCFPD: 6,960, AL Rate: 0 Fluids Pumped BBLS 2 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 2 TEST) 75 METHANOL 59 60/40 METHANOL WATER 10 DIESEL 1382 CRUDE 333 SEAWATER 75 12% HCL ACID 13.5 36% HCL ACID 14.3 XYLENE 0.1 SURFACTANT F 103 - 4 GAL 0.2 NONEMULSIFYING AGENT W54 0.2 SLUDGE & EMULSION PREVENTOR W60 - 9 GAL 0.8 DISPERSING AGENT U74 - 32 GAL 0.3 INHIBITOR CORROSION A261 - 11 GAL INHIBITOR A153 - 11# INHIBITOR A179 8# IRON STABILIZER L58 - 38# 1955.4 TOTAL Page 2 Drill Sitm: 14 Well: 23 RECEIVED ,or ,994 011 & ~ta$ Cons Com",',~'~-' ' - " ~0m-;u, -"~~ov 14 13:31:07 K-VALe. DESIGN DOME SET PRESSURE: 275 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 3-20 PSIG K-VALVE CLASS (A,B,C): A COMMENTS: K-valve desiqn Dost GLTS, and using new reoulrements to test in well durinq~normal operation. CC: ENGINEERING FILE / COORDINATOR PRB 24 (WITH ATTACHMENTS) J.C. SMART / M.G. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) FS 3 DS SuD PRB13 (COVER ONLY) DS 14 Enq ATO 15 (WITHOUT ATTACHMENTS ) STATE OF ALASKA (COVER ONLY) DESIGNED BY: MMM The selected action kev is not available for this screen Drill Site: 14 Well: 23 CK LGR FTP OIL 83 4000 330 83 3533 249 83 2478 240 83 2504 255 84 2520 208 84 3506 226 84 2519 223 60 3024 248 69 3007 240 67 3007 267 WELL TEST DATA Mon Nov 14 13:31:13 1994 GOR GLR L IQ PWF P I SEPARATOR DATE SEL TEMP PRES 494 79.7 1198 1879 2444 1414 1.13 124 255 11/13/94 Y 157 80.0 3100 5120 785 139 83.3 3587 3556 837 193 86.4 2691 2115 1429 119 78.6 1926 4935 557 164 75.5 2068 5722 672 157 74.0 2371 4778 605 147 78.0 619 4656 669 437 77.3 1147 1815 1932 370 75.9 1203 2247 1536 0 0.00 108 241 10/31/94 0 0.00 103 235 10/30/94 0 0.00 112 246 10/17/94 0 0.00 93 201 09/14/94 0 0.00 108' 219 09/04/94 . 0 0.00 91 219 09/03/94 0 0.00 108 214 08/17/94 0 0.00 136 214 08/03/94 0 0.00 130 225 07/22/94 ESC=EXIT~ Fi=HELP; F3=DESIGN; F4=DISTRIBUTION LIST; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; SSSV DEPTH (MEAS): 2151 FTP @ CLOSE (PSIG): 320 PRESS ADJUSTMENT: 12 TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP TEMP, PI PROF' USES BE TEMP AND WELL PI WPS C= ..16164e-3 N= 1.000000 NEW C= ..96830e-3 ENTERED N= 1.000000 STATE OF ALASKA ALASK-~IL AND GAS CONSERVATION C ~A4MISSION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well 1. Operations performed: 5. Type of Well Development Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1401' FNL, 2017' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2280' FSL, 2417' FWL, Sec. 4, T10N, R14E, UM At effective depth RECEIVED I 0V 2 1 1994 Alaska Oil & Gas Cons. Comndssion ~chora~'~ At total depth 2475' FSL, 2358' FWL, Sec. 4, T10N, R14E, UM Perforate Other 6. Datum of elevation(DF or KB) 72 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-23 9. Permit number/approval number 82-87 10. APl number 50 - 029-20757 11. Field/Pool Prudhoe Bay Oil Pool ,, ,, feet 12. Present well condition summary Total depth: measured 10440 feet Plugs(measured) Sandplug @ 10063' MD (10/12/94) true vertical 9227 feet Elective depth: measured 10063 feet true vertical 8874 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 375 sx PF II 81' 81' Surface 2436' 13-3/8" 1500 sx Fondu & 400 sx PFC 2508' 2508' Production 9710' 9-5/8" 500 sx CIG & 313 sx PFC 9782' 8613' Liner 950' 7" 300 sx CIG 10440' 9227' Scab Liner 534' 3-1/2" 11 bbls LARC 10029' 8842' Perforation depth: measured 10042-10062' true vertical 8855-8873' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9434' MD; 4-1/2", 12.6~, L-80, PCT tail @ 9524' MD Packers and SSSV (type and measured depth) Baker FHL packer @ 9445' MD; 5-1/2", Camco Bal-0 SSSV @ 2151' 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 In!ection Data, OiI-Bbl Gas-Md Water-Bbl Casing Pressure 119 229 438 --- · 510 // 611 2011 --- 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X...~_ Gas..._ Suspended..._ Service Tubing Pressure 208 304 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ '~ ~ Title Engineering Supervisor Form 10-40~l.,Rev 06/15/88 SUBMIT IN DUPLICATE KRF cc: KZ, JWP 14-23 DESCRIPTION OF WORK COMPLETED FULLBORE ACID STIMULATION TREATMENT 9/26~94: RIH & tagged PBTD at 10079' MD. 10/11/94 - 10/12/94: Made Dump Bailer runs & dumped a total of 200 lbs of 20/40 mesh sand to spot an isolation sandplug across the squeezed perforations located at: 10064 - 10076' MD (Z4) 10138 - 10140' MD (Z4) Ref. Log: BHCS 6/2/83. Made a final top of sandplug tag at 10063' MD. POOH w/bailer. Rigged down. 1 0/1 6/94: MIRU & PT equipment to 4500 psi. Pumped a Fullbore Acid Stimulation Treatment for cement damage removal, through the open perforations located above the sandplug at: 10042 - 10062' MD (Z1B) Ref. Log: BHCS 6/2/83. Pumped: a) 35 bbls 1% NH4CI Water @ 4.3 bpm, followed by b) 33 bbls Xylene @ 5.3 bpm, followed by c) 64 bbls 12% HCI w/10% Xylene @ 5 bpm, followed by d) 30 bbls 9% HCI - 1% HF w/10% Xylene @ 5 bpm, followed by e) 100 bbls 1% NH4CI Water @ 4.5 bpm, followed by f) 100 bbls 1% NH4CI Water w/5% Musol @ 5 bpm, followed by g) 215 bbls Crude Displacement, followed by h) 10 bbls Diesel, followed by i) Shutdown. Rigged down. Placed the well on production w/gas lift & obtained a valid production welltest. RECEIVED NOV 2 1 1994 Ala{)ka Oil & Gas Cons. Commission Anch0ra;:, ~ GeoQuest 500 W, Inlemati~nal Airlift Re)ad An~horage, AK 99518-1199 ATTN: Sherrle NO. 8993 Company: Naeka Oil & em Gone Comm , Attn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 10/13/94 field: Prudhoe Bay Well Log Description· BL RR Sepia RF Sepia Mylar D.S. 11-16 ST #1 ~1~(._, - I 'E)~ ~EAK DETECTION (10-4,94) 1 1 D.S. 14-01A c{ "~ _ Ic1~- .-~ DUAL BURST TDT-P (10-3-94) 1 1 D.S. 14-16 ~" J~"'l DUAL BURST TDT-P (10-4-94) 1 1 D.S. 14-23 ~'- ~2--- ~ "~ GAS LIFT SURVEY (10-5-94) 1 1 D.S. 14-37 ~__,o, , ~ - , u, PERFRECORD(10-5-94~) 1 1 D.S. 15-8A ~ ~ -- ! ~-~ ? GR-CX~L (10-2-94) 1 1 nd retum one copy of this transmittal to at the above address. Thank you.- DATE: Drill Site: 14 Well: 23 Tue Apr 12 20:17:27 1994 K-VALVE DESIGN DOME SET PRESSURE: FTP @ CLOSE (PSIG): K-VALVE CLASS (A,B,C): 195 PSIG @ 60 DEG F 238 PSIG B COMMENTS: CC: ENGINEERING FILE / COORDI PRB 24 (WITH ATTACHMENTS) J.C. SMART / M.G. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) Fausett/Piggot, PRB 13 (COVER ONLY) This well was recently swithched to LP from HP so this design is for LP service. It should dump by opening _ the choke and flowin~ to depressured separator or thru~ drain to another wel~s flowline. · / R J Reints NTS) DESIGNED BY: L A Boughton The selected action key is not available for this screen ARCO Alaska, Inc. Date: Apr 14, 1994 P.O. Box 100360, .chorage, AK Transmittal #: 94034 99510,~ ~, Subject- From/Location: Telephone: To/Location: ARCO Cased Hole Finals John-E. DeGrey/ATO-1529 (907) 263-4310 Distribution Well iLog Date i Number~ (M-D-Y) c~.. 01-09A ! 04-02-94 ??"5~ 01-11~! 03-25-94 ~--I~. 01-33 !03-28-94 i 03-27-94 103-22-94 '75-'z51 03-01 i To'el Type i Run, i Scale i,/' Perf Record i 1, 5" i TDT-P i 1, 5" !z" TDT-P i 1, 5" t¢ Perf Record i 1, 5" i- Leak Detection i 1, 2" ,, 7~-2,ct i 03-02 c~...{0i 04-44 ;l~{'-:Sff i 04-45 v'7-z { o5-o ~Z,-liq, 1 06-19 ~-I~ ~ 07-08 ~-G~ 07-23 ~5'-7G! 09-01 7~ 09-02 7~-5~. 09-03 31-~O~ 09-19 ~%-Z~ 09-27 b- ~0~ 11 ;.04 11-24A ,i 03-22-94 .L. Bridge Plug i . 1, 5" 03-18-94 ? .Leak Detection i 1 5" 03-27-94 !,/ Bridge Plug i, 1 5" 03-27-94 1~" Bridge Plug ! 1 5" Sch Sch Sch . ! Sch Sch Sch Sch Sch Sch 03-29-94 03-29-94 !,/ CNTG 03-10-94 1 5" Sch ,, ,, , Sch Sch 1~-'57..I 14-03 ~?'--~;~. 1 14-23 !..v/14-28 3~- I 7... ~,. 14-28 1,14-28 ~5- lcJZ.;. 14-35 ~Z.-t 5~ 16-04A ~-7_q3 16-18 ~.- ~oZ i 16-28 -73 i 18-08 03-13-94 !v USIT 03-29-94 !.,- USITCement 03-14-94 1,/ Prod profile ] 03-18-94 !,/ Per~ Record 1-. Perf Record 04-03-94 ~., 03-21-94 !,~ Bridge Plug 03-30-94 i,,' Prod Profile 03-17-94 i~ Prod Profile 03-29-94 !,- Prod Log 04-01-94 iv' Perf Record 03-16-94 i/ Prod Log 03-22-94 ,' Perf Record 03-16-94 ," Patch setting 03-29-941,/' Perf Record 1 5" 1 5" 1 5" 1 5" 1 5" , ,, 1, 1 "&5" SCh ! 5II Sch Sch Sch Sch Sch Sch 1, 5" Sch : 1, 1 "&5" Sch Sch 1~ 5II Sch 1, 5" Sch 1~ 5II I t 5II Sch 03-18-94 1.- Prod Profile ~ 1, 1"&5" 13-20 03-15-94 i-' Leak Detection i 1, 1"&5" ~ 03-28-94 i '- CNL 03-19-94 i '/ Prod Profile ! 1, 1"&5" 03-15-94 !..' Leak Detection i 1, 5" ~ 03-28-94 iv' Patch Setting i 1, 5" 03-21-94 !/ ...B..ridge Plug iv' CNL Sch Sch Sch 1, 5" Sch Sch Sch Sch 1, 5" Sch 03-17-94 1 5" 03-15-94 iv- Perf Record i 1 5" Sch 03-14-94 i/Leak Detection i 1, 2"&5" Sch 03-14-94 i ~ Perf Record ~ 1 5" Sch ; 03-20-94 iv' TDT-P i 1, 5" Number of Records: 38 ARCO Alaska, inc. Is a Subsidiary of Atlanl]cRIchfleldCompany STATE OF ALASKA ~., ' ALASKA(. AND GAS CONSERVATION C(~" /IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown , Stimulate ,...=. Plugging ~ Perforate X ' 6 ) Pull tubing __ Alter casing __ Repair.__ 3( 2. Name of Operator 15. Type o_f Well . 6. Datum of elevation(DF or KB) ARCO Alaska. Inc. I U~x~Ve~,~ x 72 RKB 3. Address I Stra~raphic 7. Unit or Property ' ' .P.O. Box 100360~ Anchorage~ AK 99510-0360 ~ servia Prudhoe Bay Unit 4. Location of well at surface 1401' FNL, 2017' FEL, sec. 9, T10N, R14E, UM At top of productive interval 2280' FSL, 2417' FWL, Sec. 4, T10N, R14E, UM At effective depth At total depth 2475' FSL, 2358' FWL, Sec. 4, T10N, R14E, UM 12. Present well condition summary Total depth: RECEIVED MAR 30 1994 Alaska 0il & Gas Cons. Commission Anchorage 8. Well number 14-23 9. Permit number/approval number 82-87 10. APl number 50 - 029-20757 11. Field/Pool PnJdhoe Bay Oil Pool measured 10440 feet true vertical 9227 feet Plugs(measured) PBTD Tag @ 10071' MD (3/5/94) Effective depth: measured 10071 feet true vertical 8881 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 375 sx PF II 81' 81' Surface 2436' 13-3/8" 1500 sx Fondu & 400 sx PFC 2508' 2508' Production 9710' 9-5/8" 500 sx CIG & 313 sx PFC 9782' 8613' Liner 950' 7" 300 sx Cl G 10440' 9227' Scab Liner 534' 3-1/2" 11 bbls LARC 10029' 8842' Perforation depth: measured 10042-10062' true vertical 8855-8873' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9434' MD; 4-1/2", 12.6#, L-80, PCT tail @ 9524' MD Packers and SSSV (type and measured depth) Baker FHL packer @ 9445' MD; 5-1/2", camco BaI-O SSSV @ 2151' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaae Production or Injection Data OiI-Bbl ~ Gas-Md Water-Bbl Casing Pressure Prior to well operation .. 1314 . 17739 5218 -- Subsequent to operation 531 888 911 -- 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations __ Oil_)L.. Gas ~ Suspended ...._ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. .Si~lned Title Engineering Supervisor Form 10-404 Rev 06/15/88 Tubing Pressure 474 216 , SUBMIT IN DUPLICATE 1109/8 GSS cc: JED, JWP 14-28 (' RECEIV[D DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE & CTU CONVEYED SCAB LINER INSTALLATION MAR 3 0 1994 ~t~ska 0il & Gas Cons. Commissi 9/18/93: RIH & tagged PBTD at 10194' MD. Anchorage 10/8/93: MIRU & PT equipment. Loaded wellbore w/Seawater & RIH w/CT to reciprocate an acid wash across the open perforation intervals located at: 10034 - 10062' MD (Z4) 10064 - 10076' MD (Z4) Ref Log: BHCS 6/2/83. Pumped 40 bbls 12% HCL w/10% Xylene @ 2.1 bpm, followed by 40 bbls 6% HCI - 1% HF @ 2.3 bpm, followed by 100 bbls 1% NH4Cl Water Flush. Continued pumping 32 bbls Latex Acid Resistive Cement to squeeze the perforations (listed above). Placed 20 bbls of cement behind pipe at 700 psi maximum squeeze pressure, held for 1 hour. Contaminated cement w/biozan & jetted cement from wellbore down to 10190' MD. POOH w/CT & Rigged down. 11/10/93: Reperforated: 10042 - 10062' MD (Z4) Ref Log: BHCS 6/2/83. 2/7/94: MIRU & PT equipment to 4000 psi. RIH w/CT & fluid packed the wellbore w/Seawater. Tagged bottom at 10203' MD, then pumped Gelled Sand Slurry containing 20/40 mesh sand, to place a sand plug across the open perforation interval (above). Made a final top of sand plug tag at 10018' MD. POOH w/CT. Rigged down. 2/8/94: RIH & tagged top of sand plug at 10033' MD. 2/10/94 - 2/11/94: MIRU CTU & PT equipment. Loaded wellbore w/Seawater, then MU & RIH w/CT conveyed Scab Liner assembly, consisting of 3.5" Baker Shoe & Collar w/check valves, followed by 17 joints of 3.5" L-80 Liner, followed by two 3.5" pup joints & 4.5" G landing sub (534' total assembly length). Hung the liner assembly by the DB Nipple at 9511' MD. Disconnected from assembly top & POOH w/CT. RD. 2/12/94: MIRU CTU & PT equipment. Loaded the wellbore w/Hot Seawater, then RIH w/CT & stung into liner top. Pumped 15 bbls of Latex Acid Resistive cement, through the check valves, to cement the Scab Liner in position from 9495' - 10029' MD, while simultaneously isolating the leaking squeezed perforation intervals located at: 9922 - 9924' MD (Z4: Sqz'd) 9980 - 10020' MD (Z4: Sqz'd) Ref Log: BHCS 6/2/83. Attained 750 psi maximum squeeze pressure & placed an estimated 2 bbls of cement behind pipe. Unstung from liner top & POOH w/CT leaving about 2 bbls cement in the liner. Rigged down. 2/21/94 - 2/22/94: MIRU & RIH w/CT mounted drilling assembly & drilled through hard liner cement& cleaned out the sand plug to 10085' MD, to uncover the open perforation interval (above). POOH & rigged down. Placed well on production w/lift gas & obtained a valid welltest. Note: Oil rate decreased by 783 BOPD, but the decrease in the gas rate provided an incremental rate benefit of 1404 BOPD, resulting in a net oil benefit of 621 BOPD. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 01-04-94 REFERENCE: ARCO CASED HOLE FINALS 4-30SzF 5-06 5-12 5-31 6-12A 6-18 9-os lS-~8 ~4-02 14-04 14-23 14-31 15-08 16-07 16-~0 17-13 ~'~-lq I 18-23A 18-29A 11-23-93 11-20-93 11-27-93 11-19-93 11-11-93 11-22-93 11-13-93 11-20-93 11-20-93 11-17-93 11-13-93 11-27-93 11-27-93 11-27-93 11-28-93 11-12-93 11-17-93 11-16-93 11-20-93 11-16-93 11-15-93 11-16-93 11-16-93 11-12-93 11-21-93 11-13-93 11-13-93 11-20-93 11-17-93 11-23-93 Pelf Record_ l~?~f ~'~l~%CZ~/.~ l_Run 1.5" 8ch Prod Profile/~t~l~ <,ll~ _~1 . oliun 1, 5"~/~/?0 - '~"~o O Sch Prod Profile [6~,3/'l'tmi2~'f/%~f;~un 1, ~' '~ -q550 Sch Inj Profile/~,n)'Te,m?t??ef~i (:c Run 1, 5" iZi~-- ~ZqTC Sch Leak Detect/GR/f~n}¥im.?}~f,~Run 1. ~' 7~ -i~-~oqc~ 8ch Prod Profile/~f~~ eaS/~amRun 1, S' ~ ~ --i ~5 Sch Perf Record l/t~0~-17_-~q'O Run 1, ~' Sch SBT/GR/CCL )01~0-ilq~ R~ 1, ~' Atlas GR/CCL [~Q] i~cq~-i~7~i~ R~ 1, 5" Atlas CNL[Ci~ ~E'~'7~ --~a~L.~C R~ 1, 5" Sch Perf Record ei~C ~i ~,c ~ R~ 1, 5" Sch Perf Record ' Sch Perf Record ~o:~85' '~ikC~i ~ R~ 1, 5" Sch Perf Record ~ 5~-- ~¥~ R~ 1, 5" Sch Perf Record %,~- !~:' R~ 1, ~' Sch Packer Set~ng Rec R~ 1, ~' g~?c .... ~SC ~ Sch Perf Record i ~i C ~ l~5 0 R~ 1, 5" Sch TBG Cutter ~00 - ~0~eO R~ 1, ~' Sch Packoff GLM ~ A~o '~ R~ 1, ~' Sch Sch ~' Detect [~ Perf Record ~~ t O~i ~ ' R~ 1, 5" ' Sch Perf Re~ord ~? :~ R~ 1. ~' Sch USIT~°C~olor~ ~'~?~ R~ 1, ~' Sch Perf Record ~-~5~ R~ 1, ~' Sch Please sign and return the attached copy as receipt of data. . CEIVE.. Have A Nice Day! John E. DeGrey AT0-1529 APPROVED '.,.~. :~ '"-',~ ~°fi~e/b/~ Trans# 94004 , # CENTRAL FILES # CHEVRON # BPX # STATE OF ~t.&SKA # PHILLIPS # ANO8 GEOLOGY # EXXON # MOBIL * The corrected APl# for 18-29A is 50-029-22316-01 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-2-93 REFERENCE: ARCO CASED HOLE FINALS 1-3 10-31-93 1-4 11-5-93 ~-16 11-5-93 ~1-22 .11-7-93 ~.1-26 10-31-93 ~~1-28 11-6-93 ~-30 10-31-93 - 10-1'/'-93 3-3o ~~-4 11-4-03 - 11 11-8-93 -21 10-18-93 11-2-93 -23A ~~-29 11-4-93 10-~0-~ ~0-7 10-25-~S ~-4~ ~ ~- ~-~3 --50 1- ~~1-12 1- 11-9-93 16ST 11-8-93 ~2-16A 10-26-93 ~ 12-16A 11-8-93 ~12-16A 11-8-93 1- -o3 ~~14-2 11-7-93 ~-~L14-4 11-6-93 ~~__~.~14-23 11-10-93 18-29A 10-19,93 q~l~n and return the attached copy. as RECEIVED B Y__ff~~___~ Have A Nice Day! 6onya Wallace ATO-1529 # CENTRAL FILES # CHEVRON #BPX # STATE OF ALASKA Perf Record 10~{i{ ?.-ilO07, Run 1, ~' Sch Perf Record ~T~-~'~-~ Run 1, 5" Sch Prod Profile ~t~0~7t--w~}f2t%!f~e~)Run 1, ~* -o-10q.G~ Sch Prod Profile/<~o~}'Temf)?~$/~c~Run 1, ~' I~O~[~O Sch D~ Brat T~P 11~00--[160~ R~ 1, ~' Sch Peri Record ~9 ~ 0 ~l 0~Z~ R~ 1, ~' 8ch Peff Record ~0-~Sl~ R~ 1, ~' Sch Completion Record ~0~z~ R~ 1, ~' Sch USIT (~m~lm~m~ Color R~ 1, ~' 5~0~0taO Sch Peff Record ~5~ ~Z~S R~ 1, ~' Sch T~ Patch Record R~ 1, ~' ~50-7;~ Sch CoUar (Packer ~t) . R~ 1, ~' ~0~V~-t0q~ Atlas D~ B~st TDTP i~0~{~0oO R~ 1, ~' Sch Pe~ Record ~0~q~0 R~ 1, ~' Sch Pe~ Record l~~tt~ R~ 1, ~' Sch ~od ~offie [St~a ira~}~]ii~R~ 1, 1"~" ~l~-~ Sch IBP Set ~0 ~ ~ R~ 1, ~' Sch Le~ Detect]50t0}~}~ ~ 1, 1" ~~ Sch Pe~ Record ~[ ~ ~~ R~ 1, ~' Sch Peff Record 115 ~0 ~ 1~ R~ 2, ~' Sch ~ Detect ~0~[~0 R~ 1, 1'&5' Sch USIT [~aT~[~]Color R~ 1, ~' ~ ~{~ Sch Pe~ Record ~ ~9 ~ R~ 1, ~' Sch L~er/Jewe~/~U R~ 1, ~'~0-~60~ Sch ~ Detect (~}~ait~ , .~ 1' ~'~" 0- ~o Sch ~od ~offie ]~ ~e)e~~~ 1, 1"~" o-~z~ Sch TBG ~cher 2v~-a95o R~ 1, ~' Sch Pe~ Record ~0 ~0~ R~ 1, ~' Sch receipt of data. ) Trans~ 93145 ~//~- t MOBIL The correct APl# for 3-20A is 50-029-20980-01. T_his log was ran on 4-11 not the sidetrack and the correct API# is 50-029-20286-00. The correct API# for 9-7 is 50-029-20223-00. T_his log was ran on 12-16A and the correct API# is 50-029-20899-01. he correct API# for 18-29A is 50-029-22316-01. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-30-93 REFERENCE: ARCO Inflatable mp ~etting ~un I' W' Sch Dual Burst TDTP (Borax) Run 1, [~' 5ch Production Run 1,.~* Sch Static Press/Temp Run 1, fi' ~ch Perf Record Run 1, ~' ~ Tubing Cutter Run l, W' Atlas Production Run 1, 2'&5~ Sch Static Pressure/Temp Run l, [~* 8ch Peri Record Run 1, ~' Sch PFC/COL (packer Sett~ _ ~un 1, ~' Atlas Dua~ aurst TDTP/Temp (tknax! lhm 1, W Sch Production Run 1, ~' Sch Dual Burst TDTP (Borax) Run 1, [~' Sch Dual Burst TDTP (Borax) Run 1, [~' ~ch Production Run 1, ~' Sch 8BL/GR/CCL lhm 1, ~' Atlas SaL/~~ Run 1, ~' Atlas Run 1, ~' Atlas ~.~ A~I-X0 3-29-93 ~;,/C,R/CCL Please sign and return tl~ attached copy a~s receipt of data~ RECEIVED BY__~~-~ Have A Nice Day! Sonya Wallace ATOo 1529 # CENTRAL FILES # CHEVRON D&M # CLINT CHAPMAN # EXXON MARATHON # MOBIL RECEIVED APPROVED ~'/:' ' __ ~¥ 0 e 199~ Tr~__ns# 9305 # PHILLIPS R~D ~ BPX ~ STATE OF ~~ ARCO .~l~_sk~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 04--22-93 REFERENCE: -14 3-13-93 Prod~n Log 1~ 1, 5" Sch 3-15-93 Production Log Run 1, 5" 3-1493 Spin/Temp/Gradio/Press Run 1, ~' Sch 3-14-93 CBT Color Run 1, 5" Sch 3-14-93 USIT (Cement & Corrosion) Color Run 1, [~' 8ch 3-16-93 PeffRecord Run 1, ~" 8ch 3-14-93 Ttl])~ Ctfl; Record l~m 1. ~' Sch 3-~2-93 Perf Record R~n L ~' Sch 3-18-9:3 Per/Record R~m L ~' Sch 3-13-93 CR ~OR. Run L 2'8~' Sch 3-14-93 Tubing Cut Record Rnn 1, 3-12-93 Production Log Run 1, ~' · Sch 3-15-93 Leak Detect Run 1, :~'8~'. Sch 3-19-93 Production Log Run 1, ~' Sch 3-17-93 Tie-In GR/C(~ l~m 1, ~' Sch 3-17-93 Inj Prof/Spin/Temp/Press Run 1, ~' Sch 3-17-93 Production Log Run 1, ~' Sch 3-20-93 PITS Run 1, [~' Sch 3-16-93 Production Log l~_m 1, ~' Sch 3-11-93 Perf Record Run 1, [~' Sch 3-12-93 Press/Temp Run 1, [~' Sch Please sign s_nd return the attached copy as receipt of data. RECEIVED BY_~_~~Z~_~ Have A Nice Day! Sonya Wallace APPR OVED__.,~J~ ATO-1529 Trans# 93048 # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHILLIPS PB WELL FILES # BPX # STATE OF ALASKA * The correct APl# for 1-5ST is 50-029-20076-00. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE ~3-29 ~---'~3-29 ~3-31 ~3-31 ., -9 5-25 6-4 ~i4-23 /16-14 ~6-14 ~~S-17 10-17-92 PSGT - Computed Results Run 1.5" 10-17-92 PSGT Run 1.5" 1-25-93 PSGT - Computed Results R~_m 1.5" 1-25-93 PSGT R~_m 1.5" 2-19-93 PSGT - Computed Results Run 1.5" 2-19-93 PSGT R~_m 1.5" 7-24-93 PSGT - Computed Results R~_m 1.5" 7-24-92 PSGT R~_m 1.5" 2-18-93 PSGT - Computed Results Rim 1.5" 2-18-93 PSGT R~_m 1.5" 2-21-93 PSGT - Computed Results R~_m 1.5" 2-21-93 PSGT Rim 1.5" 1-24-93 PSGT'- Computed Results R~_m 1.5" 1-24-9.3 PSGT Run 1.5" 8-2-92 TMD Run 1.5" 12-28-92 TMD R~_m 1.5" 12-9-91 TMD Run 1.5" 8-1-92 TMD R~_m 1.5" 9-17-92 PSGT - Computed Results R~_~_n 1.5" 9-17-92 PSGT R~_~n 1.5" 8-17-92 TMD R~_m 1.5" Please sign and return th~ attached copy as receipt of data. RECEIVED __ _ Have A Nice Day! onya ATO- 1529 CENTRAL : CLINT CHAPM~_, EXXO # MOBIL APPROVED_ffffff___ Trans# 93047 # PHI!.~ PB WELL FILES # BPX # STATE OF ALASKA * The coreect APl# for 14-23 is 50-029-20757-00. ARCO ,~IASk~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-7-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS ~ --~~17 10-17-92 ----3-29 ~1~ 1-25-93 ~3-31 ~l~ 2-19-93 ~q-~O~ ~3-32 5~ 4-25-93 ~q-~0~-33 ~al 7-24-92 90-~ .4-2 ~al 2-18-93 ~ ~4-4 ~o 2-21-93 ~~--4-9 ~~ 1-24-93 ~--11-1 5~ 4-21-92 ~~11-18~9 4-14-92 ~ ~~4-12 ~4-24-92 ~~. ,,'~4-23 ~~2-~-0~ 4-37 4.13- 2. 3 .~ ~16-14 ~ ~z 9-17-92 ~al a ~ 6-2 ~ ~ 7-23-92 PSGT PSGT PSGT PSGT PSGT PSGT PSGT PSGT PSGT PSGT PSGT TMD PSGT PSGT PSGT R~m 1 Job#L84611-X HI~ Run 1 Job#L92001-8 HLS R~m 1 Job#L92012-8 HLS R~m I Job~679~6 ~. R~m I Job~72~3 ~ R~ I Job~L92011-7 ~ R~ I Job~L92013-9 ~ R~ I Job~320~7 ~. R~m I Job~679~4 ~ R~m 1 Job~6795-3 ~ R~ I Job~6797-5 ~ R~I Job~L73961-8. ~ R~ I Job~67942 ~ R~m I Job~460~8 ~ R~ I Job~472~2 ~ Please sign and return t~e attached copy. as receipt of data. RECEIVED BY__~_~' Have A Nice Day! R Sonya Wallace APPROVED_ ATO-1529 APR 1 9 '-199t' Trans# 93045 Alaska-011'& GasG0ns. G0mm~ssj~ll CItEVRON Bo~ ~~ # MOBIL # PHILLIPS PB WELL FILES R&D # BPX : # STATE OF ALASKA TEXACO Drill Site: 14 Well: 23 K-VALVE DESIGN Tue Mar 23 09:11:00 1993 DOME SET PRESSURE: 750 PSI~ @ 60 DE~ F FTP @ CLOSE (PSIS): 1000 PSI~ K-VALVE CLASS (A,B,C): A COMMENTS: Squeeze perfs broke down recently. This new design is for current high got production. As well is testing over marginal ~OR, well will likely remain SI. (If produced, well would have to be choked back a .) CC: ENGINEERIN~ FILE / COORDINATOR PRB 24 Larry Bacak ATO (WITH ATTACHMENTS) (WITHOUT ATTACHMENTS) J.C. SMART / M.G. SHOEMAK~ PRE 20 (WITHOUT ATTACHMENTS) J.E. FAUSETT / C.W. SHUMWAY PRB 13 DESIGNED BY~-.~D (COVER ONLY) Drill Site: 14 Well: 23 K-VALVE DESIGN Sat Nov 14 16:15:36 1992 DOME SET PRESSURE: FTP @ CLOSE (PSIG): K-VALVE CLASS (A,B,C): 325 PSIG @ 60 DEG F 300 PSIG B COMMENTS: This k-valve may be d~mped (possibly) by use of the drain header and full open choke. __. ~. CC: / W.D. COOPER J.C. SMART / M.G. SHOEMAKE J.E. FAUSETT / C.W. SHUMWAY ENGINEERING WELL FILE PRB 24 PRB 20 PRB 13 T.L' RUT ATO 1578 STATE OF ~SKA (COVER) DESIGNED BY:.-~ RECEIVED NOV 1 9 1992 Alaska Oil & Gas Cons. Commission Anchorage Drill Site: 14 Well: 23 Sat Nov 14 15:32:05 1992 K-VALVE DES I GN SSSV DEPTH (MEAS): 2151 FTP @ CLOSE (PSIG): 300 PRESS ADJUSTMENT: 123 TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: SEP COML CK LGR FTP OIL %WTR GOR GLR LIQ. PWF PI TEMP PRES DATE SEL 83 0 438 1406 79.7 9224 1863 6958 1606 3.47 166 0 11/10/92 Y CONDITIONS AT CLOSURE: 83 0 300 1468 79.7 9224 1863 7268 1453 3.47 166 0 WELL TEST @CLOSE TEMPERATURE @ SSSV: 179 179 PRESSURE @ SSSV: 660 535 DOME SET PRESSURE: 325 PRIOR DESIGNS: DATE: .08/22/91 SET PRESSURE: 285 FTP @ CLOSURE: 275 04/08/91 190 205 Ol/Ol/81 o o TEMP: LINEAR LINEAR NA .. ESC=EXIT; Fl=HELP; F2~WELL TESTS; F4=DISTRIBUTION; F5=SENSITiVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; WPS C= ..64679e-3 N= '. 1.000000 NEW C= ..65263e-3 ENTERED N= 1.000000 Drill Site: 14 Well: 23 SENSITIVITY TABLE Sat Nov 14 15:41:08 1992 P.I. 3.47 3.47 3.47 3.47 %WTR 80.0 85.0 80.0 85.0 GOR 9300 9300 10000 10000 LGR 0 0 0 0 FTP 1 438 660 658 663 658 FTP 2 ' 300 535 518 543 523 FTP 3 100 399 361 414 369 ENTER VALUES FOR PRODUCTIVITY INDEX, WATER CUT, GAS-OIL RATIO, LIFT GAS RATE, AND FLOWING TUBING PRESSURE 1, 2, or 3. PRESSURES AT THE SSSV WILL BE CALCULATED FOR EACH GROUP OF ITEMS ENTERED. ESC=EXIT; Fl=HELP; F2=WELL TESTS; F3=DESIGN; F4=DISTRIBUTION LIST; F6=CHECKLIST; F10=ACCEPT; -~'DATE' 9-6-9~ REFERENCE' ARCO CASED HOLE FINALS i-9- 8-i7-9i PROD PROFILE RUN i, 2-5- 8-8-9i TEMPERATURE RUN t, 2-26- 8-8-9i PROD PROFILE RUN i, ~\~'~--'.f-SS- 8-3-9i GR-COLLAR RUN t, 4-2%- 8-i0-9i F'II'S RUN i , . .~\--5-32- 8-i ~-9i JEWELF<Y RUN i, 7-7A- 8-9-9i PROD PROFILE RUN i, 7-i f~- 8-4-9i TEMPERATURE RUN t, 7-2~' 8--i8-9i PROD PROFILE RUN i, 7-28- 8-i-9i TEMF'ERATURE RUN i, 7-2,c~' 8-3-9i F'ERF BREAKDOWN/HF'FM/TEMP RUN i, 9-6- 8-2-9i LEAK DETECT RUN t, 9-? 8-i9-9i PITS RUN i , 9-i7-- 8-4-9i INJ PROFILE RUN t, ii-2-' 8-9-9i INJ PROFILE RUN i, ii-,q~' 8-4-9t LEAK DETECT RUN t, i i-24'- 8-4-9i F'IT$/HF'FM RUN i , t2-3~ 8-i4-9i LEAK DETECT RUN t, i2-8B-- 8-9-9i PROD F'ROFILE RUN i, * iS-S- 8-ii-9i F'ROD PROFILE RUN t, iS-ii-' 8-ii-9i PROD F'ROFILE RUN i, !S-J2- 8-i5-9i PROD F'ROFILE R'UN t, i3-t4- 8-i6-9i PROD F'ROFILE RUN i, t4-23"- 8-it-9i PROD PROFILE RUN i, i5-25-- 8-i4-9i F'ERF BREAKDOWN TREATMENT RUN i, i6-i- 8-i6-9i INJ F'ROFILE RUN t, i8-S-- 8-i6-9i LEAK DETECT RUN i, · 5" 5" 5" 5" 5' 5" 5" 5" 5' 5" t "&5" S" 5' 5" 5' 5" 5' 5" 2"&5' 5" 5' 5' CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO PLEASE SIGN AND RETURN 'THE ATTACHED COPY AS RECEIF'¥ OF DATA. HAVE A NICE DAY! SONYA WALLACE ATO-i 529 APPROVED 'I'RANS~ 9 DISTRIBUTION CENTRAL. FILES ..-'"' PHILLIPS CHEVRON F'B WELL. FILES D & M R & D EXTENSION EXPLOR. ATION ~ BF'X EXXON ~ STATE OF ALASKA MARATHON TEXACO MOBIL * THE CORRECTED AF'I~ FOR i S-3 IS 5~-~29--2¢,325. Drill Site: 14 Well: 23 K-VAL%~ DESIGN Tue Aug !3 08:57:49 1991 DOME SET PRESSURE: 285 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 275 PSIG K-V3J.~VE CLASS (A,B,C): B Post wel!work design. Gor increasing. Attempt K-Valve test by using drain system. CC: C.P. Fk~4ER / W.D. COOPER K.M. FJENNEDY / L.D. LASH J.E. FAUSE~3T / C.W. SHUMWAY ENGINEERING WELL FILE PRB 24 PRB 20 PPJ~ 13 M. O. JOHNSON ATO 1552 STATE OF ALASKA (COVER) DESIGNED BY: KARA Printing contents of current screen - wait for message to clear I::',0, BOX ~0036(:;' ' ,.~ Nt..l"lt. RAG E ALASI( A 995 'i () REFERENCE' ARCO CASFD FlOl_li.". FINAL.,? i -- 7., C', 4 -'- a -. o i ,-_"~-' i 6 a-i. ,. "--~' i -z_ i '? -4-- i 3. -' o i ~,.'~ ~r..... 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O * i"l-'tI$ IS A I) L.IPLIC':ATE OF" TI-tE L.O[; YOLJ AI_REAI) Y RECEIVELD, EXCEF"I' TH£:' AF:'I~: I,? COF;..'RFZC:TFD. F'L.[.:'~A,S'E THROW THE F'F;:EVIOU,':.¢ COPY WII'FI THE WRON6 API:I,': AWAY, R Er !::' !~ R E" N C ii:': A R C 0 C A ;:.:.' Er D H (] L E F I N A L. S' ~ ...i I'.~ :¼:1; .... 'i :.-' i .... ':? ~ COL. I..AR/ F."E.I',,F'"'" RLIF,~.. '~ , 'i-',;~5 2-2'7---':?'I F'RODUCTION F'ROF'II.~E! l:,~lJ/-,~ ~ , I .... 3 f:;, 3--"?'-- 9 i I::' R 0 D LJ C i" I 0 N F:'F;: 0 F-' I L. E ~, R LJ1%4 I , Z~"- i ZJ"" t '7'-? t COI..LAI'~'./F'EI:;:F i:;:I...IN t , ,'!. ..... i %;' 2"" 2 8""':? t I N,J F:' f;.'. ("l F' I L. E'E R U N i , ..,. .... "'" "~ .." 'l .... i ':;..."::: ,.:: .... 't 6....91 COLLAI-,.., F.I:'.I-,..! RUN i , ':t'..; .... ! :~:i: :~,--.. ':..7.-' .... 9 t I'-:' F;.'. 0 .~) L.! C T ]] 0 i'..! F:' F;: 0 F' I I... E F:.'. [..I i".! i , '7' .... ~,..:"'- ,..';'; ........,°"...:';~. i '1" liE. I'.'i I::' li'] R A 'F [J R E t:,: I..I ¢,~ 'i , :i;'""'-.? :~!;--.-",:' .... 9 t I... Iii] A K .~) E T E C T ]i 0 N !:;..' O N 'i , :i 2 .'-,...":> ,";;, .... ...- ,-':q: .-- ~::',. t I N ,J t::' R 0 F:' Z L i::' t;: U t--~ i , · i 2 .... i 't :.:"':; ..... i .... 9 'i t::' R 0 D I..I C'i" ]; 0 N I::' R 0 f:' I L. ti:' Fi.: O N 'i , i ';,-'J:.'- "'2 't :$ .'"/.,'-"':..;' 'i I N...! I::' R 0 I::' i I... IF.' I:;: O ¢.4 I , · i ~'~;-.- ":~ A ':r ..... i r:~.....::~ i I... E A K ])l:'i;'T' E!] c"r I 0 Fi I:;~ g i'-! i · ,,.,,.. ....~ ;z . . . ¢,~.' i L'~..- 'Z~ :;.~ .... :i ,':.il'-- 9 t C 0 L. L A F,.: / I::' Ii;. I;,,' F I~.'. U ~"4 :i , t 4 .... 4 Z:'.4-.- 't <.) .'.. ".:? t I::' I:;: 0'~) g C T I 0 t'.~ P R 0 F I I... Ei~ R g i"4 'i , t ,."~. .... 'i 2 ~'~-.. 'i (/) .-- 9 'l J li'] W ii'" L.l:;.'. Y I:;: U i',~ i , ,1_ ~'/'i~'~ .... i?. :].", ..... ,,::')--9t F:'RODUC'i"IOJ", F:'R",f:'II...E i:;:gJ'4 a~// i 4 ..- '~:.'. :L'~,''''~ ,?..; ..- ~:.~ ..- 9 i I".' R 0 D IJ C T I 0 N F' R 0 I::' :[ I.. E !:;,' U N t , i..,. ':~' ... ~.. :~] ..... I 9 -... 9 i e I::¢ I ..~'. H ~ N A L.. ¥',S' [ ..,¢, I:;: O iq t , · ~ 6..-t 5 ~':~..-8..-9t i_E.r.P~I( DETECTION I:;:UNI , t 6"-''~ · ....4 :;:~""9""9'1' I...EAK DE'T'E.r. CTZON RUN t, 'i 8 .... t 6 5~"" 8'"'"? t F' R 0 D g C T 10 N F:' R 0 F I L I'k". R U N I., .; t:;.' II ....- ...'.. · '.:;.' . ~.i:" c,~ u .: ~.:.~ , 1 "&5" A T' L. ~'..~ ,.~ (SAM(](] A'i" !._ A ~':; C A H ~Z; A 'i' I... g C A d C 0 C A i"i Il; (Z. A f,i :]]]: [:; A r",.. t.; 0 ~':~ T' C A ;ii; C A t'J "J: C ¢:'~ i,t C 0 C ~'-':i ~',i tL.' 0 A '!" I... A,S' C A i~ C 0 C A r.'i C 0 ,%' I (]; N A N I) I:~ E'T' LJ R N T I..tE A T T A C;I-.IE D (]; 0 F' Y A ;S' F~.'.Ei CEil I P'T' 0 F:' O A"I' A ~, .S'I..IAI:;.'.ON W I L...%'ON A 'T' 0 '-. t '.L; 2 9 Drill Site: 14 Well: K-VALVE DESIGN Thu Mar 21 16:51:06 1991 DOME SET PRESSURe: 190 PSIG @ 60 DEG F FTP @ CLOSE (PSIG}: 205 PSIG K-VALVE CLASS (A,B,C): B K.M. KENNEDY / W.S. WILDER PRB 20 J.P. WINTERS / C.W.. S~TUMWAY PRB 13 ENGINEERING WELL FILE M.O. JORNSON ATO 1552 STATE OF ALASKA (COVER) DESIGN'ED BY: KARA Printing contents of current screen - wait for message to clear RECEIVED APR ? i991 Alaska Oil & (~as Cons. 5'Ommissio~,~ Anchorage PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well: 14-23 Comments: Pulled K-Valve for State bench test Redesign for current flowing conditions B catagory well. RECEIVED OCT 1 6 1990 Alaska 011 & ~as Cons. Colt~lssion Date: 1 0/3/90 Previous K-valve Settings: Production Data: ROR = 2020 BOPD CFR -- BOPD Swing Well (very high or Iow GOR) ..............No Design Parameters: Design parameters are based on (Mark one of these) XXX Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. Set Pressure, psig 205 205 570 @ 9 0 deg. choke @ deg. choke Choke Priority Well ..................... Date 1 0/3/90 7/6/9O 3/6/90 Actual Well Test ..... Date of Test .................... 9/15/90 Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used of the parameters, mark which program... 2150 BOPD 3 5 percent 3290 scf/stbo 0 mscfpd 2138 scf/stbl 240 psig 143 deg. F Temp. @ SSSV ............. Pressure @ SSSV ....... Pressure Adjustmen to get some xxx PH2 PH3 PRUDHYD Other 162 deg. F 349 psig 36 psig Calculated Dome Set Pressure = 184.8 psig @ 60 deg. F IActual Dome Set Press. 185 FTP at K-valve Closure = 205 psig @ 60 deg. F psig @ surface I cc: Ferguson /'Farme~X Wilder / Kennedy (2 copies) ~ State of Alaska ~.~. Well File cc: D.S. Engnr. J. Michels ATO 1554 D.S. Supvsr. Shumway/Winters PRB#15 Prepared by D. Kara Tit-ill Sit~: 1.4 Wett' 213 ( LiFT :SAS iHJEE:TiOH PL!-:T F:i TEHF: i_-:: :::--;i.3 F: ]]ATE SEL _ 650 ' ' 9' F'LOt,.! TEf"IP .... CASE- PRES; -- -'--- TUBE .. '5 I '". ='RES ..... MEAL=; BERTH 2151 "'1""1 IT',r- ~_:1'] ,--. ,--. ~ : ,_, ,-, =. ,- r,, E.=,.=, CR:_;E F:'RESS 1059 162 LGF: ! 0 0 ..... 71 .~ i..-1 ......... Pi.,.IF 802 0 _ . GLR 2138 ,--. 0 i LGR 0 0 . -G LR 0 F i=HELF' ;. F..~=t'lCINBBELS; :,iCii. iL i_GR FTP 01L ,"-;:HTR ; GF; '}LF: ~ i E.! F'P-tF ;::'i TEMF' E::.--:;GF: DATE :--;EL i::'H2 I · il · ...... FLOW TEMP = .... ,'-CnSE F', :ES - , TUBE PRE'S ..... 'T ;,.,:.T_', '.-..' 1 F, ! MEAS T..~EPTH 2151 C A :E; E i:::' R E K-: :s: I 'T,'Ei.,iF:E F:A T L;F;E ..:,13 059 i ,S2 LGR E~ LGF: I .3 ! L '.";.' ! ::: A F.~ F'HF 74,'2- ~3 G L F: '-:..' 13 8 El LGF: 2 LGR 3 LGF: G E~ F 1 =HELP..". FS=MRNBREL:--;; , ,t 13 - EJ ,k~ F4=RATES ~ F-5-~WL' TESTS-- ..... WRL ~$T REPL~T ............... TESTED ~TES -:XPEC~ AAN) .... AA/(i- ~ TOTAL ~!~ F~ TOT~ TE~T ........ F~ -~-~--~ __ ~ T~ C~ E~ ~ ~ OiL ~ OAS ~ }, ~ ~ ~ OIL C~ ., C~ POS ~_ ~ ~__ S~D BPD ~S~ ~ W~ ,~/B...~tB ~ S~D_.~/B 230~5C~C~ 83 1~ ~4 ~ 2~ I~ 6~7 .0 CM ~7 216~ 9.0 2~7 :)~6) ~NRY6 -9.~ ' -23 0~0t ~i~d' ' ~ '~ 2~- i~7 2t~ i2"~2 ~+ 0 ~- 3t~2+ 20i5 8.0 2~2 2426 37-E ~ ~.~ .- -23 07-27 08~ :~ 147 2~3 ~ 20~- ~- ~99 0 37 24~ I~ 8.0 2415 2273 47 E R N -23 07~)6 0~1 ~ 1~ 2~ 21~ ~- 21~ 5451 0 47 ~2+ i210 4,0 3167 I~ -2'3 ~7 2!06 ~" ~~" ~---31~+ i27~ 61~ ' '0-- ~ ..... 1~2+ I~- 8,1 '27t6-- 1~4 ..... -23 ~2 0731 71 14~ ~ ~7 ~ I(~ ~627+ 0 ~ I~+ 141~ 6.7 2~ I1~ · :30I~40i~ ~ 1~ ~ 787 ~9 4~ 3747 0 13 t~ I~ :1,~ ~ 12I~ 16HR -23 12-2~ 01~ ~ I~ ~ 7~ ~- ~+ 35~- 0 16 121~+ 1024 8,0 4~)1 9~ ..... ....... ..................... -2'312 07-06-90 ~ 44.00 PRODUCTION HEAIER Il 06-07-90 2100- '-,--J~, 00 ..... -'{MX} ....... PRO[I(I;TION 5EP~AT~ --- PROI~JCTION SEPARATOR PROI)UCTION. HEADER 0:0 PRODL~TI~ .... SEPARATOR ....... PROI)EX~TI~ ~ PROI)UCTI~ I~.ADER. PROI~CTION SEPAP~TOR PRODUCTION hEAI1ER ..... PROIIX~TIO~ J~F. AZ)ER 4,0 PROI)U~TION HF. AI)ER ........ ...PflOiMJCTION HEAj)ER. : O-ZJ3~O ~ ..-.,n=, :: --TEST~.:~, RATES ...... :XPEC~ ~ DATE TiY: ~ SEP ~ S~ OiL i~-Z3 09-Oi'"ii~ ~ i~ 2~ 199 2i~ i2~2 .i~+ 0 ~ ~i62+ 20i5 8.0 i~2 242~ ~?-E RN-~-5.~ :~-~ 07-27 ~ :~ I~7 2~3 2~ 202~ ii~6- 4599 0 37 2425 i~ 8.0 2415 ~73 47 E R N ~ 3.~ :.~- :451 0 47 2272+ !2!0 ~,0 3167 !9~ ~ E D N 3,~ i4-Z2 06~7 2!0~ 82 !52 ~ 2~ $i53, i2YO+ ~:5:+ 0 29 :952+ :3~2 9.1 27!6 ii74 '1~ E R N G -- 3,~ .... 14~ ~2 0731 71 14~ ~ 207 2~+ iO~ 5~27+ 0 25 i8~+ 141I 6.7 2~ ll~ ~ E R-N 6 2.~ i~-~3 05-~8 0~ ~. i~_. ~ 203 244~ 6~ 26~- 0 _ ~ 10~ ~ 8.0 314~ i~ 17 E.R.~.E~.~ ....... 14-~ ~-11 I~I ~ 1~ Y'B~ ~ 21!3 5~ 3i67 0 21 14'~+ 1I~ 6.9 29B6 1170 i7 E R N G 2.~ i4-2'3 02-24 2!26 ~ 137 821 793 2352- ~7b 2743- i4-23 01-29 233I b7-. · I~- b51 228 2733- 425- :3'947- ..~-~ 0i~4 01~ ~ 1~ ~ 787 i:~') 475 ~7~7 .~Q 14-23 12-24 01~ ~ 1~ ~ 7~ i~- 563+ ~ S~T DATA ~:~ ::~RY - ~ ?~T :~2S o:~, _., LOC 0 17 1166 970 5.3 33 1277 13ERN6 2.~ 0 13, i444+ i}.50 ~.i 414t i~9 13-E R-N-~ ..... ~25 . - 0 13 i~9 i0~3 ii,? 2968 :219 16NRN8 ' 2,~5 0 16 1219+ 1024 '5,0 4'5)1 '..:'~ 3 E R N G ..... 2,~ PRODUCTION HEAIiER PRODUCTION SEPARATOR P~K~JCTION SEPARATOR PRO~TION ~J~DER 0.'0 PRODUCTION SEPARATOR PROII~CTI ~i rEA[ER PRODUCTION HEADER ..... PRODUCTION SF. PAP~TOR PRODUCTION HEADE~ F.~'ROF. i~CT I ON HEADER 4.0 PRODUCTION ~r. ADER ....-.::':.:::..'::: . :.,. · :PROraTION HEADER M .T~..~ OR DUtD NP~IE FII4.0G / El~ ~l'~ T~IN] - 35 DRY PLOT 3 7 Z80,00. 1 PSIG P_~iG Q~ t~. RVG. R~. I~: 18:13 ~ 3...- UPDRTE MIN/MRX IN ~TR B~E 9 - OI~LRY PLOT FOR ..... : .... =:-:.:~.--_;L..~.- OISPLRY GROUP I~TION .... -,'.- G~,OATE~.TI~ ~ PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well: 14-23 Comments: Pulled K-Valve for State bench test Redesign for current flowing conditions B catagory well. Date: 1 0/3/90 Previous K-valve Settings: Production Data: ROR = 2020 BOPD CFR = BOPD Swing Well (very high or iow GOR) .............. No Design Parameters: Design parameters are based on (Mark one of these) XXX Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. Set Pressure, psig Date 205 1 0/3/90 205 7/6/90 570 3/6/90 @ 90 deg. choke @ deg. choke Choke Priority Well .....................No Actual Well Test ..... Date of Test .................... 9/15/90 Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used of the parameters, mark which program... 2150 BOPD 35 percent 3290 scf/stbo 0 mscfpd 2138 scf/stbl 240 psig 143 deg. F to get some xxx PH2 PH3 PRUDHYD Other Temp. @ SSSV ............. 162 deg. F Pressure @ SSSV ....... 349 psig Pressure Adjustmen 36 psig Calculated Dome Set Pressure = 184.8 psig @ 60 deg. F IActual Dome Set Press. 1 85 FTP at K-valve Closure = 205 psig @ 60 deg. F psig @ surface I cc: Ferguson / Farme~,,,~\ Wilder/Kennedy (2 copies) State of Alaska Well File cc: D.S. Engnr. J. Michels ATO 1554 D.S. Supvsr. Shumway/Winters PRB#15 Prepared by D. Kara PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well: 14-23 Date: 7/6/90 Comments: The well was recently switched from HP to LP production. ROR is set at 90°. New design will account for CL pressure swings. Should be a Catagory B well by dumping to depressurized separator. Previous K.valve Settings: Set Pressure, psig Date 570 3/6/90 700 I 1/10/89 Production Data: ROR= 2400 CFR = N/A Swing Well (very high or Iow GOR) .............. Design Parameters: Design parameters are based on (Mark one of these) XXX XXX Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. BOPD @ 90 deg. choke BOPD @ deg. choke No Choke Priority Well ..................... no Actual Well Test ..... Date of Test .................... 7/6/90 Flowing, Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used of the parameters, mark which program... 2460 BOPD 4 7 percent 2270 scf/stbo 0 mscfpd 1210 scf/stbl 230 psig 159 deg. F Temp. @ SSSV ............. Pressure @ SSSV ....... Pressure Adjustmen to get some xxx PH2 PH3 PRUDHYD Other 175 deg. F 377 psig 22 psig Calculated Dome Set Pressure = 208.0 psig @ 60 deg. F IActual Dome Set Press. ! 205 FTP at K.valve Closure={ 21 0 psig @ 60 deg. F i psig @ surface I CC': Ferguson/Farmer Wilder / Kennedy (2 copies) State of Alaska cc: D.S. Engnr. Jeff Michels D.S. Supvsr. Shumway/Winters Prepared by D. Kara RECEIVED JUL 1 0 1990 Alaska 0il & Gas Cons. ~omm'tssJot~ Anchorage 'f ................................................................. i- .................................................. i t i l 1 I I I I ! F: i-..I" ' lc: iq., ~' 'F'i T'l ~' i::, 'T' H i ! i I TV!) :2 :!. 5 !. 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I:.., , ,,, { T F-: I',1 I::, ' I'"' d:,'---: F-' ~, a, F-" ,-: 'T' i 'r" i': I:;, I:;,i:::' :;: LiF"i- GA:.'.:.'; iHJECTiOH PLOT L i':i~: F"i" P i'] i L ,%i,JT R Gi_-iF;: G L Fu: L i ii:! F:i,JF F' i C :-'--:G F" iiA T E :::;E L. E C T 2 J. 5! Ii:,t i 'fl i " i i....Gi::;: 2 i ~'::ii:;' ":~; L ............................ ~- ....................... I ............................................................................ ................. ! ........................................... .~ ............ L G i:':: (3 ,:3 t ~ ; i i ~ .., i...~'.1 I,~,i I, ,. 1I ! " ....1 ..... " ';'!t~ ~t .-. -, ' *'. ~ ,'. :t'~' j' t F:' t ..... ..-t r... I ,--', i.... -,.":: , t ~...~1'..~ ~t-,. -.-, :..., ~ ;').~!;i i i ........................................ t-:")l .~. . I ':>'i~.~ ............................ i .?-,~.:~ i ..................... i- ....................... ' ..................... ~ .......................... ...- ,,:-~..'! · '?'~% ' ~ J,~..,r.~ F:',"! ..... F;',¢;~TE;S ~, F:'5:::::i.,.il .... TI'.:.'" :;"F::!: i::' ! ~'" h I T i t"!P ' ............ c' ,:;:,,:; r.-- P t::;'I::: c: T 1 I 'r.:: I:' t;:, ~;, I::' c: ,~ WT44,14-23,12 07-~}6-~ 0449 WELL TEST REPORT TESTED RATES ..... ~'XPECTED .... AUG AUG AUG TOTAL LIFT F[~M TOTAL TEST FORK T T A F ORIFC WELL DATE TI~ ~ EqEP FI'P SEP OIL WTR [~qS GAS ~ ~ OLR LENGTH OIL GOR % S Y L L DIA NO, C1.'lliP POS ~ TEST PRES STBI) BPI) M'.E4~FD MS[:FD WTR .%FIB ~F/B HnURS STBD SCFiB W'FR T P L G INCHES 14-2:.3 07-(}6 0301 ~ 158 - 2~ 211 23')9- 2105,+ 545i 0 47 2272+ 1210 4.0 3167 i965 2) E D N O 3.~' 14-23 06-07 21~ 82 I52 ~0 204 3153+ "1270+ 6i-55+ 0 29 i952+ 13')2 8. i 2716 1174 22 E R Y 0 3.50 !4-2'3 06-02 0731 71 149 36,9 207 ~8~+ IO~X')+ 5427+ 0 25 1883+ I41I 6.7 2589 1154 22 E R N G 2.75 14-23 05~25 0~4 57 1~ 3?3 2~3 244~ 690 2633- 14-23 04-II i341 ~3 1~ 796 7-/.5 2113 55~ 3167 14-23 02-24 2126 83 137 821 7'~3 2352- 476 2743- 14-23 01-29 2~31 67 135 651 22~ 2733- 42~.~- 3947- !4-23 01-04 0106 ~ 144 850 787:3049 475 3747 14-23 i2-24 0146 ,~ 144 840 780 2953- 563+ 3~¢~- 14-23 il-26 0121 82 149 8'~ 6q)6 4647+ 146+ 459)+ 14-23 ii-08 ~26 60 1~ 879 861 4111+ 86+ 3374+ !4-23 11-05 2246 49 118 918 245 2761- 63+ 2035- 0 22 1077 840 8.0 3149 !238 17 E R N O 2.25 0 21 14'~+ 11~ 6.9 23% 1170 i7ERNG 2.00 0 17 1166 970 5.3 ~3 1277 i3E RNG 2.50 0 13 1444+ 1250 6.1 414i 1229 i3 E R N G 3.25 0 13 1~9 1(~ 11.9 2968 1219 i6NRNG 2.75 0 16 i21~+ i024 8.0 4~I ')90 3 E R N G 2.25 0 3 9K~ 9./:,0 11.9 39~3 818 2 E R N G 2.75 0 2 821 8(~ 1.6 2881 742 2 E D N G 1.75 0 2 737 721 7.9 ~ 858 0 E R N O 2.75 WELL SHAKE-OUT DATA WELL ENTRY PERCENT PERCENT I-iC~ PER LEE: SAMPLE NO. NO. DATE TIME WATER SOt. I[G MILLION ENTERED BY TAKEN FROM 14-23 i2 06-07-'.~ 2100 28,(Xl 0.00 11 05-28-~ 0100 28,00 10 02-24-90 2~JO 14.00 0.00 9 12-24-~ 0100 12,00 0.(~ 8 10-16-89 2300 1.00 0.10 7 09-10-89 2200 56.00 6 t~-~}6-89 0900 68,(~ O,(Q 5 08-28-8~ 1001 53,00 0,(~ 4 08-~-89 0300 5~,00 0,00 3 07-05-89 1.30~3 15,(E) 2 11-15-88 23~ ~2,00 0,(:10 PRODL~:TION SEPARAT~ PROB93TION SEPARATOR PRO[t~TIE~ HEADER 0,0 PRODLb3TI[~4 SEPARATOR PRO)£TION HEADER PRODi.~TION HEADER PRO[~UCTI6~ SEPARATOR PRODUCTION HEADER PROEEICTION HEADER 4,0 PRODL~TION HEAE~ER PRO~JCTION HEADER 1 11-0.9-88 i000 19,00 0,00 10,0 PRO[~JCTION SEPARATOR $$ STATE OF ALASKA AND GAS CONSERVATION ALASi~" MMISSION REPOR'I OF SUNDRY WELL OPERATIONS 1. C~rations 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 4. Location of well at surface 1401' FNL, 2017' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2280' FSL, 2417' FWL, Sec. 4, T10N, R14E, UM At effective depth At total depth 2475' FSL, 2358' FWL, Sec. 4, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 72 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-23 9. Permit number/approval number 82-87/9-729 10. APl number 50 - 029-20757 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10440 feet 9227 feet Effective depth: measured 10400 feet true vertical 9189 feet Casing Length Size Conductor 81' 20" Sudace 2436' 13-3/8" Production 9710' 9-5/8" Liner 950' 7" Plugs(measured) Junk(measured) Cemented 375 sx PF II Measured depth 81' 1500 sx Fondu & 400 sx PF 'C' 2508' 500 sx CI 'G' & 313 sx PF 'C' 9782' 300 sx C,'G' True vertical depth $1' 2508' 8613' 9227' Perforation depth: measured 10034-10062'; 10064-10076' true vertical 8847-8873'; 8875-8886' ' IAV 0'819 0 & 8as Cons. CommisSior~ Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9434' MD; 4-1/2', 12.6~, L-80, PCT tail @ 9524' MD Packers and SSSV (type and measured depth) Baker FHL packer @ 9445' MD; 5-1/2", Camco Bal-0 SSSV @ 2151' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment 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 1450 7975 1800 -- 4OOO 320O 100 Tubing Pressure 1861 666 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 Date Form 10-404 Rev 06/15/88 338 D. C. Reem SUBMIT IN DUPLICATE DS 14-23 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR WATER & GAS SHUT-OFF 10/1/89: MIRU CTU & stimulation equipment. PT equipment to 4000 psi. RIH w/CT and pumped 200 bbls of crude, then washed perforations: 9980 - 10020' MD Ref. Log: BHCS 8/2/83. 10036 - 10056' MD Pumped the following treatment: 11 bbls of Meth - Water, followed by, 30 bbls 12% HCI w/10% Xylene, followed by, 32 bbls 12-3% HCI-HF, followed by 32 bbls 12% HCI. Flushed w/5 bbls of Diesel and 25 bbls of Meth - Water. POOH. RD. 10/5/89: A cement squeeze and same day cleanout were performed as follows: MI RU CT & Cementing Equipment. PT equipment to 4500 psi. RIH w/CT and fluid packed wellbore w/seawater. Pumped 47 bbls cement, squeezing perforations: 9980 - 10020' MD Ref. Log: BHCS 8/2/83. 10036 - 10056' MD Placed 5 bbls of cement behind pipe at 2000 psi squeeze pressure. Pumped 316 bbls of 2# Biozan and 160 bbls of 1/2# XCD to contaminant cement and circulate out returns. POOH and displaced CT w/135 bbls of 60/40 Meth - Water. Rigged down. ,, 10/8/89: MIRU, and RIH to tag bottom at 10391' MD. POOH. Rigged down. 10/14/89: Repedorated: 10036 - 10056' MD Ref. Log: BHCS 8/2/83. Added perforations: 10034 - 10036' MD 10056 - 10062' MD 10064 - 10076' MD Ref. Log: BHCS 8/2/83. Flowed well and obtained a valid production test. pRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-W®ll- 14-23 Date- I 1/10/89 Comments: Well was squeezed. Production rates have changed. K-valve design is changed accordingly. Previous K.valve Settings: Set Pressure, psig Date 1650 4/20/89 1750 3/14/88 Production Data: ROR = 4440 BOPD CFR = N/A BOPD Swing Well (very high or Iow GOR) ..............No @ 90 deg. choke @ deg. choke Choke Priority Well ..................... no Design. Parameters- Design parameters- are based on (Mark one of these) Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. XXX Actual Well Test ..... Date of Test .................... I 1/8/89 Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used of the parameters, mark which program ... 4111 BOPD 2 percent 821 scf/stbo 0 mscfpd 804 scf/stbl 879 psig 133 deg. F to get some PH2 PH3 xxx PRUDHYD Other Temp. @ SSSV ............. 170 Pressure @ SSSV ....... 1252 Pressure Adjustmen 150 deg. F psig psig Calculated ,Dome Set Pressure = FTP at K-valve Closure 77 5 698.0 psig @ 60 deg.F I"s g 60 deg. F I I Psig @ surface I CC: Vacant/Farmer Wilder / Kennedy (2 copies) state of Alaska cc: D.S. Engnr. KEITHFERGUSON D.S. Supvsr. ShumWay/Winters Prepared by K. Wysocki ot98 Naska Oil & Gas Cons. 'Anchorage ARCO ALASKA, INCA F'.O. BOX i0~360 ANCHORAGE, ALASKA 995 ~ ~ DATE' REF ERENCE' ARCO CASED HOLE FINALS i-4 t0-t3-89 F'RODUCTION PROFILE i -6 t 0-22-89 CNL-GR ~ -6. t 0-2~ -89 F'DK-i ~(~/GR/CCL t_i6 ~-~6-89 PRODUCTION PROFILE i--t7 i~-t9-89 F'ERF RECORD t -23 t ~-2~-89 CNL-GR i-"~.., t~-t,~-8~. , PRODUCTION PROFILE t-26 t~-t5-89 F'RODUCTION PROFILE i-29 i~-t4-89 F'RODUCTION F'ROFILE 2-5 i e-i 8-89 CNL 0_. ~ ' ~ i~ ~' i~'-i6-89 I'EMP ~URVEY 2-25 i ~-25-89 . CNL-GR '" 8-23-89 4'"3~ i CNL-GR ~4-32 't ~-23-89 PDK-t egVGR/CCL ~7-'i3 i~-t6-89 PRODUCTION F'ROFILE ~9-5 t()-it-89 PRODUCTION F'ROFILE 9-i6 1~-ii-89 INJECTION PROFILE ti-t2 t~-'7-89 F'RODUCI'ION PROFII_E t i-t5 t e-t 3-89 TEHP i4-23 t~-i4-89 COMPLETION RECORD i6-ii te-i3-89 LEAK DETECTION ~t 6-2() t e-4-89 TEMF' i7-4 tB'-i4-89 PRODUCTION F'ROFILE t8-i 6 9-t 8-89 PIT~ - F'I..E:ASE: I GN AND REI'UR RUN t , 5 · RUN t, 5' RUN t , 5" RUN I , 5' RUN i, 5 · RUN t , 5' RUN i, 5 RUN i, 5 RUN t, 5" RUN 2, RUN t , 5" RUN i , 5 RUN t , 5" RUN i, 5 · RUN 1, ~.," RUN RUN t , 5 · RUN RUN RUN i , 5 · · RUN RUN RUN RUN t, 5 · N THE ATTACHED COF'Y AS RECEIF'T [:iF' DATA. RECEIVED BY ___ HAVE A NICE DAY! SALI_Y HOFFECKER ATO- i 529 CAMCO A'FLA~.~ ATLA:~.' CAMCO $CH ATLAS .,,.~MCO CAMCO CAMr::o SCH CAMCO ATLAS ATLA,S' ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO ~CH CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILE~ CHEVRON D&M EXTENSION EXXON MARATHON MOBIL . '~FIF' CORRECTED AP l$ ** THE CORRECTED AF'I.$ *** THE COR. RECTED AF'I$ PHILLIPS 'il' PB WELL FILES R & D EXPLORATION ~ ~ BPX '~ STATE OF ALASKA . :C IV F 0 Fi:._"- ..~'~ ~ Z Z 5"'e - e" "'"~, - "~ ~ 7 ~' ~..' S~ 0/1 & aS CONS. Commissio~ FOR i4-23 IS 5~-q)29-2~75'~ · .., .. . A h ,.,_nc_ora,e FOR i 6-i t IS 5()-(.)29-.,.0.:>t 6 ARCO Alaska, Inc.! Prudhoe Bay =ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 18, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-23, Permit No. 82-87 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DCR/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 14-23)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA O J{ I 6 ~/~ ~:~ L ALASKA¢' ,L AND GAS CONSERVATION C~ 'MISSION APPLICATION FOFI SUNDRY AF ROVAL$ 1. Type of Request: Abandon Suspend Operation shutdown Alter casing Repair well Plugging Change approved program Pull tubing Vadance 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development X Exploratory _ Stratigraphic Service 4. Location of well at surface 1401' FNL, 2017' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2280' FSL, 2417' FWL, Sec. 4, T10N, R14E, UM At effective depth At total depth 2475' FSL, 2358' FWL, Sec. 4, T10N, R14E, UM Re-enter suspended well Time extension Stimulate Perforate X Other X 6. Datum of elevation(DF or KB) 72 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-23 9. Permit number 82-87 10. APl number 50 - 029-20757 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10440 feet Plugs(measured) 9227 feet Effective depth: measured 10400 feet true vertical 9189 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 375 sx PF II 81' 81' Sudace 2436' 13-3/8" 1500 sx Fondu & 400 sx PF 'C' 2508' 2508' Production 9710' 9-5/8" 500 sx CI 'G' & 313 sx PF 'C' 9782' 8613' Liner 950' 7" 300 sx CI 'G' 10440' 9227' Perforation depth: measured 9980-10020'; 10036-10056' ~.:: i~::i~:: :? i, ,i~::!~i~i~ true vertical 8797-8834'; 8849-8867' ! :::.!'q:~ ::'.;ii ,!i:: ~i:.i~.i~ i:/~:~'~: t'~,., ~ ~'~':, '~"~. ;: ~'~, ,, ~.:,,,~, ,,,,,,, Tubing (sizo, grade, and moasurod dopth) 5-1/2", 17~, L-80, PCT ~ 9434' MD; 4-1/2", 12.~, L-80, PCT tail ~ 9524' MD Packers and SSSV (type and measured depth) Baker FHL packer @ 9445' MD; 5-1/2", Camco Bal-0 SSSV @ 2151' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation I September 1989 16. If proposal was verbally approved Oil ~ Gas Name of approver Date approved Service 17. I herebyp~rtify that the foregoing is true and correct to the best of my knowledge. Signed ~ ,~~,4,4~_..~ Title 15. Status of well clasSification as: Suspended Operations Engineering Manager Date FOR COMMIRRION URI= ONLY 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 Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Approved Copy <~eturned ~, Date Form 10-403 Rev 06/15/88 156 D. C. Reem, 265-1353 SUBMIT IN TRIISLICATE D.S. #14-23 CTU WSO/GSO Cement Squeeze PRELIMINARY PROCEDURE Objective: The purpose of this workover is to shut off excess water and gas production. 1. RU slickline. Surge well and tag bottom. 2. RU CTU and acid equipment. Acid wash the perforations. 3. Flowback acid load and production test the well. 4. RU CTU and cementing company. Squeeze off perforations with a maximum squeeze pressure of 3000 psi. The perforations to be squeezed are as follows (Ref BHCS dated 6/2/83)' Perforation Interval Zone 9,980'-10,020' 4 10,036'-10,056' 4 5. Maintain 3000 psi squeeze pressure for one hour. 6. Dilute cement remaining in wellbore with mud. 7. Jet out diluted cement. Cleanout wellbore to PBTD. 8. Shut well in for one week. 9. Perforate the well as folloWs (Ref BHCS dated 6/2/83): Pre-squeeze perf$ Comments 9,980'- 10,020' Above GOC 10,036'-10,056' channel dn Post-squeeze perfs Zone SPF 10,034'-10,062' 4 FSD 10,064'-10,076' 4 LSD Comments Add/Re-perf Add Perf 10. Return well to production. Current Status: Producing on cycle with a +90% shut-in factor. Estimated Reservoir Temperature: 223OF Estimated Reservoir Pressure: 3700 psi ,5 4 2 COILED TUB~Nt~ UNIT BOP EgU ! PHENT I. ~K)00 PSI 7" WELLHEAD CONNECTOR FLANGE 2. ~)00 PSI 4 1/16" PIPE RAMS 3. ~)00 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. ~X)0 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 H]REL ]NE BOP EOU] PHENT 1. ~)000 PSI 7" WELLHEAD CONNEC10R FLANGE 2. 5000 PSI WIRELIN[ R&US (VARIABLE SIZE) .3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 't/6" FLOW TUBE PACK-OFF AF.:CC~ ~':~ ASk'.A, :[NC:~ F'. cO. E:(3X i :7)0'3;69 ANCHORAGE, ALAS,'KA DATE' -7-i9-89 REFERENCE' ARCO CASED HOLE FINALS S-i7 6-27-89 MI INJECTION F'ROFILE SURVEY RUN i, i '.-'-'-', 7- i 5--89 COLLAR/PERF. RUN t S--.28 '?-2-89 F'RODiiCTION PRfiF']:LE SURVE'Y' n'UiU, 'i4-4 6-29-8':? F'RODUC"7'[f'iN F'ROF;[LE SURVEY I-;:.UN 'i 4-5 6-30-89 PITS RUN i 4-23 7'-i -89 F':['rS, I:;:1 IN_ . i , ';;.' °..,- ...... · , -...~ , i 4-.~,.'~ ." -" ..:; - t¢ ',F'PODUCTION F:'ROF"ILE RUN i i a - :=. ~ ,'"' "" - '"'"' P R 0 '~ f" . .... ........ :~'-,::U-~-;, DUCT.~ dN F'I;:OF'ILE ~:UI;:VEY RI li'-.J i ;:~ i4-:$9 7.-i -89 PRODUCTION PROFT. i_E RUN i ~"" -. t5-i 6-29-89 LEAK OETECT'_[ON RUN i, t" i '.5:-t ;::;6-28-89 L. EAK DETECTION I:;:UI~. i , i " i5-26 6'-28.-,99 LEAK DETEC, T ION ' ,, RUN tt3--i8 7-3-89 GR/CCL RUN i, 5-" t 8-21 7-3-89 GR/CCL I.... J N A~E SIGN AND ""' ' ., "' RETURN THE ATTAC:HED C:OF'Y AS' RECEIPT OF DATA RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-t529' CA?ICO C: A H C O r'A,MCO~_. CAMCO CAHCU C; A M C 0 CAMCO C A M C 0 CAMCO CAMCO DISTRIBtJTION ~ CENTRAL FILES' ~,- .CHEVRON D & M ... EXTENSION EXPLORATION ~ EXXON : MARATHON . ~ ~ MOBIL · .. F'H II_LIF'$ F'B WELL. FILES R & D ~ BF'X · ..'"' ,?~'¥A'I'E OF ALASKA :.": TEXACO A N C H II l:i1. A ,l'; E.: A I... A :!'.:.' !( A D A ')" E' · i ;:? -- j 4 .- [~, 7 R I::: !::' I.!: k' F.-: N C !.:.: · · HAVE A N :1: I:.'.t!!: DAY !Alaska 0il I Gas Cons. Commissloll % Anchorage t::' IE f'.; [; Y B Ii!; i9. N E 'T' T A '!' 0 .... i.="., .,..'"' 9. 'T' I:~' A N $ :~: ;~.~'7 6 8 :.:~ /~ A I::' F:' R 0 V I:!: .'[.) ....................................................................................i !.~[~) [.~ :l' ,? T' F;..' I P, !..I T '[ 0 N t-, r: I-4 AF;.'.CO ALASKA, 'J'NC,. ANCHORAGE, AI...A..~'K A 995~0 '2..- t A t t -27-87 CNI... RIJN '" ':) t t -..,:.. ,' -. 8 ? r.'. N I... F~'!.I N ,:.- ,... "~ .... . ~.;--t 0 ~ t --26---'87 CNL FL'lIN 6 .... :~ 'i t -'- 2 '3 '-' 8 '7 C N. 1... R I.l N. 6-'7 ~ t .... 27--87 CNI.,. RUN 6 -- '-'),... t 1 t - ":',:.., ''~' '-' ...,,c) .'7 C N I... R U N. I 4-'-'2S t t -25--87 C.'.NI... RUN ~ 4.-..S~ ~ ~-.2.5-.87 C.'.BK RUN ,.. F:: T F:' qr' ., I- I... E:. A,.... E:..? I (.'; N A N D R r:!' T I..I R N 'T I--! I:i: A l' 'T' A C I--I I!.". D C 0 F:' Y A [I r.:' D A T A F;.'. E C E .1, V E D B Y .............. ,.., D I ,S' T R I B 1.1'1" I f') N .~ C. Fi ,?CH .x'; C.. I--I ~'CI..I ,.~ C,H · ,.'"' r::.. E N 'l' R A I... F I I.. E ,.'-;' -,,.'"' F:' F .I I I... I... I F' ,.? "" CI"IEVF;~ON PB WEr, L I... F.I.I...1= .... I) & H R &. D · ,."~' E X 'T' E N ,...~' I f.I. N E X F' I... 0 .... R A 'lr' I 0 iq .,,.-"- ,¢,., A F:' C · 11:E X X C) N ~: ,?'l' A'I" E .r.)F: A I... A,~ K A MARATHON '"' · .,,. l' E X A C 0 H 0 B I I... . ~ STATE Of ALASKA :0(' ~ " ALASKA ,LAND GAS CONSERVATION C v~MISSION 'WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REV I SED OIL ~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number : ARCO Alaska, Inc. 82-87 .... 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20757 ...... 4. Location of well at surface 9. Unit or Lease Name 1401' FNL, 2017' FEL, Sec.9, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2280' FSL, 2417' FWL, Sec.4, T10N, R14E, UM 14-23 At Total Depth 11. Field and Pool 2475' FSL, 2358' FWL, Sec.4, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 72' RKB ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 05/22/83 06/02/83 08/09/83 N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10440 'MD ,9227 'TVD 10400 'MD ,9189 'TVD YES [~X NO []I Nipple @ 2157feet MD 1900' (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91 .5# H-40 Surf 81' 30,, 375 sx PF II · 13-3/8" 72.0# L-80 Surf 2508' 17-1/2" 1500 sx Fondu + 400 sx PF "C" 9-5/8" 47.0# L-80 Surf 9782' 12-1/4" 500 sx Class G & 313 s~ PF "C" 7" 29.0# L-80 9490' : ' 10440' 8-1/2" 300 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9980' - 10,020'MD w/4 spf 5-1/2" 9524' 9445' 10,036' - 10,056'MD w/4 spf ,._ 8797 ' - 8868 'TVD. 26, ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 10,315' - 10,317 100 sx Class G 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I F1 owl ng Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 3/25/84 4.2 TEST PERIOD I~ 980 619 0 55I 631 ......... Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 951 N/A i24-HOUR RATE ~ 5600 3536 0 27 28. CORE DATA ........ BriefNonedeScription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chi!ps.~R ri C ,,4FIV ~ D MAR o 5 !98 Alaska Oil & Gas Cons. Commission A:}chorage Form 10-407 Rev. 7-1-80 GRU13/WC08 CONTINUED ON REVERSE SIDE Submit in duplicat NAME Top Sadlerochit O/W Contact Base Sadlerochit MEAS. DEPTH 9874' 10,271' NOT REACHE TRUE VERT. DEPTH 8698' 9068' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None 32. ' I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item .16, and in item 24 show the producing intervals for only the interval reported in item 27., Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. / Post Office~,. . 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: November 4, 1985 Reference: ARCO CH Finals ~-~'29 Spinner 10-13-85 Run 2 5" Camco ~-~-i8 Spinner 10-26-85 1 5" Camco x'~l-2 Spinner 10-25-85 1 5" Camco '/1-4 Spinner 10/17-18/85 1 5" Camco ~~t'4-23 spinner 10-24-85 1 5" Camco Please sign as recei~pt of data. Received by Pam Lambert ATO 14 29C Trans 396 Anchorage Chevron Phillips. D & M ' PB Well Files Expl. Services R & D Ext. Exploration Sohio Exxon .... State°f Alaska' Marathon Texaco Mobil ARCO Alaska, In(._ Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 1, Reference: 1984 ARCO Pressure Data DoS. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. D.S. -- ._ D.S. D.S. D.S. D.S. D'S. D.S. D.S. D.S. D.S. D.S. 1-4 --~ 3-15-84 PBU/CDBR Otis 1-25 -~-"- 5-25-84 PBU/CDBR Camco 1-26 ..... 5-30 -84 PBU/CDBR GO 3-19 ~---' 5-25-84 PBU/CDBR Camco 3-22f' 6-29-84 PBU Camco 3-23 --- 5-24/25-84 CDBR GO 6-17--~ 6-16-84 Static Survey GO 7-7A ~--'~'~ 6-15-84 Static Survey GO 7-13'-~ 6-14-84 Static Survey GO 7-14`/. 6-14-84 Static Survey GO 7-16~-' 6-30-84 PBU GO 7-16~-- 7-2-84 PBU/CDBR GO 9-8~ 6-20-84 Static Survey Camco 9-18J 6-20-84 Static Survey Camco ~ 6-21-84 Static. Survey Camco 12-16~- 5-19-84 CDBR 12-17-~ 5-20-84 CDBR 13-33-~ 6-22-84 PBU/CDBR Camco 14-8~/~ 6-28-84 Static Survey Camco 14-23 ~----5-16- 84 CDBR 14-24~ 5-17-84 CDBR 14-25 5-18-84 CDBR 14-32" 5-20-84 CDBR 14-33~ 4-29/30-84 CDBR 14-34~ 5-19-84 CDBR /P/lease ~ data. sign and return the attached copy as receipt of Kelly McFarland ~ATO-1429F DISTRIBUTION Trans. 9290 dhevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob i 1 Oil ~ Cu~/s Hob iI E & P a/TChorage'C°rnrnissior Phillips Prudhoe Bay Well Files R&D Carolyn Smith Sohio State of Alaska ARCO Alaska. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 July 13, 1984 Reference: ARCO Cased Hole Finals D.S. 1-26 '-/ 5-30-84 D.S. 3-23" 5-24-84 D.S. 13-29'~/ 6-1-84 D.S. 14-22 5-27-84 . D.S. 14-23~'~ 5-17-84 D.S. 14-28 ~ 5-28-84 D.S. 17-5''~ 5-24-84 CFS/Flowmeter CFS /F 1 owme te'r CFS/Flowmeter CFS/Spinner CFS / Sp inner CFS/Spinner Collar/Perf Log Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" GO //Please sign and return the attached copy as receipt of data. Friday the 13th is back again, have a safe one! Kelly Mc Far land ATO-1429F Trans. #268 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mobil ~ / .::: .. M~bil P illips ~,/ ..... ~L'. ~-.''( Prudh°e Bay We'll'Files. ~~ State of Alaska ARCO Alaska, I~(' Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 · July 10, '1984 Reference: ARCO Pressure Data D.S. 1-26 .-"'j 5-20-84 Stat ic D S 3-23~ 5-24-84 PBU D.S. 12-16'' 5-20-84 PBU D.S. 12-17,· 5-20-84 PBU D.S. 13-3~'~ 5-27-84 PBU f 5-27-84 Common Data Base Report D.S.,14-23/~ 5-16-84 PBU D.S. 14-24 ..... 5-17-84 PBU D.S. 14-25 ~"5-17-84 PBU D.S. 14-32 ?~5-20-84 PBU D.S. 14-34r'5-19-84 PBU GO GO DA Otis Camco GO Camco GO GO Camco P~~leas sign and return the attached copy as receipt of data. Have a Nice Day! Kelly McFarland ATO- 1429F Trans. #261 DISTRIBUTION CheVron D:":'&i: M,~ Drilling Exp. Services Ext. Exploration Marathon . Mob i I Mobil E & P Phillips Prudhoe Bay Well Files R & D Carolyn Smith :~.s..tace..of Alaska ARCO Alaska, Inc( Prudhoe Ba~, .--ngineerinD Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 16, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 14-5 DS ].4-2 ~, DS 14-24 DS 14-25 DS 14-34 Permit No. 78-64 Permit No. 82-87 Permit No. 83-91 Permit No. 83-102 Permit No. 83-133 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/la Enclosures cc: SOHIO Alaska Petroleum Co. File PI(DS 14-5,23,24,25,34)W4-3 RECEIVED APR 2 01984 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. ts a Subsidiary of AtlanflcRIchfleldCompany . , STATE OF ALASKA WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILXIX-I GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number / ARCO Alaska, Inc. 82-87 / 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-20757 4. Location of well at surface 9. Unit or Lease Name 1401' FNL, 2017' FEL, Sec.9, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2280' FSL, 2417' FWL, Sec.4, T10N, R14E, UM 14-23 At Total Depth 11. Field and Pool 2475' FSL, 2358' FWL, Sec.4, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool 72' RKBIADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 05/22/83 06/02/83 08/09/83I 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 10440'MD,9227'TVD 10400'MD,9189'TVD YES ~[] NO [] ~lipple ~ 2157 feet MD 1900' (APPR0X) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 81' 30" Cmtd w/375 sxs PF II cmt 13-3/8" 72.0# L-80 Surf 2508' 17-1/2" Cmtd w/1500 sxs Fondu + ~00 sxs PF "C" cmt 9-5/8" 47.0# L-80 Surf 9782' 12-1/4" Cmtd w/500 sxs "G" cmt + 313 sxs PF "C" cmt 7" 29.0# L-80 9490' 10440' 8-1/2" Cmtd w/300 sxs "G" cmt 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) 5-1/2" 9524' 9445' 9980-10020' MD 4 spf 10036-10056' MD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8797~8868' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE GAS-OILRATIO 3-25-84 4.2 'TEST PERIOD ~ 980 619 0 55 631 Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 951 NA 24-HOUR RATE ~ 5600 3536 0 27 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ' · 'RECEIVED APR2 01984 A/ask~ 0Il & Gas ~ons. Comrn~sion Anehnr.~ . Form 10-407 Submit in duplicate Rev. 7-1-80 DRN/WC25 CONTINUED ON REVERSE SIDE NAME Top Sadlerochit O/W Contact Base Sadlerochit MEAS. DEPTH 9874' 10271 ' Not Rea, TRUE VERT. DEPTH 8698' 9068' hed Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NONE 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supPly for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23,:.. Attached supplemental records for this well should show the details of any multiple stage cement- ing and.the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 ARCO Alaska, Inc/ Post Office'~,...,x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 2, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: ~!?DS 14-23 DS 14-24 DS 14-25 Permit No. 82-87 Permit No. 83-91 Permit No. 83-102 Attached are Subsequent Sundry Notices for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File PI(DS 14-23)W1-3 PI(DS 14-24)W1-3 P1 (DS 14-25)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK[ . IL AND GAS CONSERVATION . IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-87 3. Address 8. APl Number P.O. BOX 100360, Anchorage, Alaska 99510 50- 029-20757 4. Location of Well 1401' FNL, 2017' FEL, Sec. 9, T10N, R14E, UM 2280' FSL, 2417' FWL, Sec. 4, T10N, R14E, UM 2475' FSL, 2358' FWL, Sec. 4, T10N, R14E, UM 5. Elevationinfeet(indicateKB, DF, etc.)72, RKB I 6. LeaseDesignationandSerialNO.ADL 28312 12. Check AppropriateBoxTolndicate NatureofNotice, Report, or NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 14-23 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Other Data SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 3/8/84. RU perf unit, pressure test equipment. RIH w/gun #1, shot 10036-10056' MD, 4 spf, (20' Ref: BHCS 6/2/83), flowed well, SI well, POH, all shots fired. RIH w/gun #2, flowed well, shot 10000-10020' MD, 4 spf (20' Ref: BHCS 6/2/83), SI well, POH, all shots fired. RIH w/gun #3, flowed well shot 9980-10000' MD, 4 spf, (20' Ref: BHCS 6/2/83), SI well, POH, all shots fired. RD and secured well. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~a~_/~, ~~"/~~ Title Regional ~.ngineer The space below for Commission use Date . q/q/~q I Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 360 Anchoracj~ aska 99510 Telephone ~=,,7 277 5637 April, 2, 1984 Reference: ARCO Pressure Data D.S. 3-10v~/3-18-84 D S 3-15 ~, 3-18-84 D S 3-18 3-18-84 D.S. 4-5z~' 3-17-84 · D.S. 4-16~'' 3-9-84 D.S. 9-1=~'x~ 3-18-84 D.S 9-6J 3-18-84 D.S. 9-10 '~' 3-19-84 D.S. 11-2~' 3-17-84 D.S. 13-27'~' 3-4-84 D.S. 13-28 j 3-5-84 --3-5 -84 D.S. 13-29~ 3-12-84 D.S. 14-23~ 3-10-84 D.S. 14-24 3-10-84 D.S. 14-25 ?z' 3-11-84 Static Survey Static Survey Static Survey Static Survey PBU _. Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey PBU Data Sheet Static Survey Static Survey Static Survey Static Survey Camco Camco Otis Camco Camco Otis Camco Camco Otis DA DA DA Otis Otis Otis P~~lease sign and return the attached copy as receipt of data. HAVE A-HAPPY EASTER! Kelly McFarland ATO-1429F Trans. # 112 DISTRIBUTION Chevron D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay Well Files R & D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc.( Prudhoe Ba~'~ ,~ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 24, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: 14- 23 DS 14-24 DS 14-25 Permit No. 82-87 Permit No. 83-91 Permit No. 83-102 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmh Attachments cc: Sohio Petroleum File 100.0 RECEIVED JAN2 5 ]984 0il & Gas Cons. Commillloll Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlanflcRichfieldCompany STATE OF ALASKA ALASKA~ ,.AND GAS CONSERVATION C{ ,VIlSSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-87 3. Address 8. APINumber P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20757 4. Location of Well 1401' FNL, 2017' FEL', Sec. 9, T10N, R14E, OM 2280' FSL, 2417' FWL, Sec. 4, T10N, R14E, UM 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 14-23 2475' FSL, 2358' FWL, Sec. 4, T10N, R14E, UM 5. Elevationinfeet(indicateKB, DF, etc.)72, RKB I 6. LeaseDesignationandSerialNO.ADL 28312 12. Check AppropriateBoxTolndicate NatureofNotice, Report, orOtherData 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 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. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to a tank for clean-up and production. 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 Perforated Intervals: BHCS 6/2/83 RE£EJVED JAN2 5 1984 Alaska 0il & Gas Cons. Comn 9970-10026' MD (56') 10036-10056' MD (20') SubseqUent Work Beported 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ._~/~~_~~'~,,~ Title Regional Engineer The space below for Commission use Conditions of APproval, if any: Approved Returned By Order of the Commission Date 6RIGINkL SIGilE9 BY LIJNHIE C. Sh11Tii Approved by COMMISSIONER issio] Form 10-403 Rev. 7-1-80 Submit "lntentibns" in Triplicate and "Subsequent Reports" ir] Duplicate , · /r" STATE OF ALASKA Il ~~'~/F~-'~ ALASKA'_iL AND GAS CONSERVATION C{ ~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number // ARCO Alaska, Inc. 82-87 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20757 4. Location of well at surface 9. Unit or Lease Name 1401' FNL, 2017' FEL, Sec.9, T10N, R14E, UM !L©CA;-!©NS" Prudhoe Bay Unit At Top Producing Interval Surf.~ 10. Well Number 2280' FSL, 2417' FWL, Sec.4, T10N, R14E, UM 14-23 At Total Depth 11. Field and Pool 2475' FSL, 2358' FWL, Sec.4, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 72' RKBI ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 05/22/83 06/02/83 08/09/83,'1 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 10440'MD,9227'TVD 10400'MD,9189'TVD YES IXl NO [] INipple ~ 2157 feet MD I 1900' (APPR0×) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" , 91.5# H-40 Surf 81' 30" Cmtd w/375 sxs PF I I cmt 13-3/8" 72.0# .L-80 Surf 2508' 17-1/2" Cmtd w/1500 sxs Fondu + bOO sxs PF "C" cmt 9-5/8" 47.0# L-80 Surf "9782' 12-1/4" Cmtd w/500 sxs "G" cmt + 313 sxs PF "C" cmt 7" 29.0# L-80 9490' 10440' 8-1/2" Cmtd w/300 sxs "G" cmt 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) NONE 5-1/2" 9524' 9445' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. ~ DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL.USED N/A ' 27. N/A PRODUCTION TEST Date First Production I MethOd of Operation (Flowing, gas lift,~etc.) Date of Test Hours Tested TEsTPRODUCTIONpERIOD FORi~ OI L-BBL GAS-MCF WATER-BB L CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED' .~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATEI~ · ~. 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submi s NONE · NOV- Alaska 0it & Gas Cons, O0mmis2i0~ Anchorage . ~ · Form 10-407 Submit in duplicate Rev. 7-1-80 DRN/WC25 CONTINUED ON REVERSE SIDE NAME Top Sadlerochit O/W Contact Base Sadlerochit MEAS. DEPTH 9874' 10271 ' Not Rea~ TRUEVERT. DEPTH 8698' 9068' hed Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NONE 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Drilling Engr. Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for i~jection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16~ and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-. ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 DS 14-23 DRILLING HISTORY NU 20" diverter lines. Spudded well @ 1530 hrs, 05/22/83. Drld 17-1/2" hole to 2520'. Ran 63-jts 13-3/8", 72.0#/ft, L-80, BTC, csg w/FS @ 2508'. Cmtd 13-3/8" csg w/1500 sx Fondu and 400 sx PFC cmt. ND 20" diverter system. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & t0' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 7822'. Ream 7755'-7822'. Drld to 8471', tight hole, work pipe free. Wash & ream 8321'-8471'. Con't drlg 12-1/4" hole to 9790' (05-31-83). Ran 247 jts 9-5/8", 47#/ft, L-80, BTC csg w/FS @ 9782'. Cmtd 9-5/8" csg w/500 sx Class G cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & form to 9795'. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10440' (06/02/83). Ran DIL/BHCS/SP/GR, DIL failed, rerun fr/10432'-9766'. Ran FDC/CNL/GR/Cal fr/10432'-9766'. Stuck tool, work WL, strip over WL. Work pup jt dwn over fish, work WL & DP to engage fish. RU T-bar & pull WL out of rope socket. RecoVered logging tool. Arctic packed 9-5/.8" x 13-3/8" annulus w/50 bbls PFC cmt & 127 bbls AP. Ran 23 jts 7"' 29#/ft, L-80 BTC lnr fr/9490'-10440'. Cmtd 7" lnr w/300 sx Class G cmt. Repair drawworkS. Drld cmt to 9490'. Wash & ream 9490'-9560'. Drld cmt to 10400' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to 9.6 ppg NaC1. Ran CBL#I, tool failed. Run CBL#2 fr/10400'-9300', poor bonding. Ran CET fr/10386'-9480'. CET indicated channelling of 7" cmt job. Perf 10138'-10140' w/4 spf. Set cmt ret @ 10100'. RIH w/stinger, PU 3-1/2" & 5" DP. Stab into ret. Sqzd perfs' w/lO0 sx Cl'ass G cmt. Perf 9922'-9924' w/4 spf. Run jnk bskt gauge ring to 9915'. Set ret @ 9900'. Sqzd perfs w/lO0 sx Class G. LD 11 jts 3-1/2" DP. Drl on ret 9911'-9913'. Drl ret & hard cmt to 9924', wash to 10041'. Drld & washed 10111'-10400'. Run CBL #2. Set RTTS @ 10116', pressure tst, no pressure loss..Reset RTTS & press tst 7'~; leaked. Reperf 9922'-9924' w/4 spf. RIH w/EZ drl & set @ 9880'. Sqzd perfs ~/100 sx Class G cmt. Washed to 9820'. Drld cmt to 10400' PBTD. Run CBL #3 fr/10260'-9298'. RIH w/csg scrapers & bit. Wash last 200' to btm. Retest 9-5/8" and 7" @ 1800' psi - ok. Ran 5-1/2" completion assy w/tail @ 9524' & pkr @ 9445'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Secured well & released rig @ 1900 hrs, 06/14/83. CSM/DH16 07/07/83 Eastman/ Whipstock A PETROLANE COMPANY REPORT of SUB-SURFACE D IREC TI ONA L SURVEY ~RCO ALASKA, INC. COMPANY D.S. 14, Well Number: 23 WELL NAME Prudhoe Bay, North .Slope, Alaska LOCATION .... " JOB NUMBER A0883R0350-PZ SURVEY BY PEFFERKORN/JAHN TYPE OF SURVEY DATE SIGMA-Gyro 09-AUG-83 OFFICE Ancho=age, A'laska AIRC:(" " "" .... ~-d....~.::,l....A I NC ,, lEI '.E: .1. ~.'1 ~ t,;! E I _ L_ N tel: :2: :.E: .'.:.'i; .'[ f.":.i PlA -'"' f]~ Y F,,: Ct ,_l f.Ef B N I.'.] -" ~-'~ () F~: :;:.: :~: IF(('.) :::.: 50 F' Z ti}E; ][ I::;I"I~':;-....C~YF:O-, 0 .... ~ ()::3C~() FID-, :E:;IJRVEYOR C'; ;F. I'gl"l~'~ :300 I',10," 27.1., F;'F:d-)DE NO: C'.,;::,~ I:::' CH:;t E: F; i[ (:;I-FI": N/.:,:3 3:3E '.F;L.II:?ME¥ 'l-r.'.~t.:::E;l",l F:F;tOP'I HELL. H!EF'~!.:) I::;~EF;fLII:.I OF ,]!;r.,l'.:_:.'; ,.~:j:l._ll:::.:V[-?~' O1'-,1 ~.'J :F: --- ,J I. JN---:~::3 I.] .... ~ ..... · '~ .......... ... E:.t.~ I i[ I_.~-.,I... ::;[i:'l'":T.~ I."_'IN C;ALLE:LII..ATED ][ N F'L~NE F~F PRFIPI-~::;~L DT_REF..':T'[ON: N ~.0 DEG. 22 I't]:N. 14 REC:FIRD OF L--;LIRVEY R~_F~:[I..I:3 OF C:I_IRV~TLIRE I"IETHOI_"~ Eastman DATE: October 17, 1983 (907) 563-3650 P. O, Box 4-1970~Anchorage, Alaska 99509-1970 S'~' INC ARCO ALASKA, . PoO. Box 360 Anchorage, Alaska 995119 Well Number: D.S. 14, Well No: 23 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: SIGMA-Gyro Date: 09-AUG-83 . ~t~on: Radius of Curvature Method of Compu~-~ ~; Surveyor/Driller: ,JAHN/PEFFERKORN Job Number: A0883R0350-PZ Attn: Mr BILL CON.=DON De~r Mr.~ Congdon,. We are enclosing the original and eight copy/copies of the SIGMA-Gyro survey run on the ao~ve men.~_~one~ well. To date, tb,= ...... following distr;bution has been accomplished: A. 8 copy/copies delivered to drilling for in-house dis~'ribution. "~ 0 copy/copies for note(] oil company representattv; C 3 cc)~.}ies for E/W n~-~-m.~,~:~n~- l! f~les · , r ......... ......... we _ We wish to take this opportunity to thank you for using Ease. man Whi~st©ck and look forward to be~n.~ c~ s~rvice in t~uture. TOM JO Distri~t~chnica! Coordinator cc/fi~ Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO ALASKA INli:::, [)S 14.~ WELL_ r,.IO: 2:F: L:.:IGMA'-GYRO F::, t:.~:i...iD H Cl E ..., ..... - ...... BA ~., Ixlt3RTH SI_Cd::'E.~ ALA.:,b..~.~ P A G E.:. 1',.I 0. · 'I-RLiE MEA'.:::I_IFdE[) DF,'IF::'T DRIFT COI_IRSE VIER'f'ICAL VERTICAL DIF-F:'I"H ANf3LE DI.F:?.I!:_'.'I.'%'T'IOI"~ LEI'-.IG"I"H DEPTH SEC'FION TVD C'O 0 I:;.'. 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E: 4 100. :25'.:.:' 9.83 10 C). :26,'.-? 9 ,, 7 E.: 100. 2 79. 9.. ,z,.~:'-' '-' 100. 2:E:97.81 21.41 S 1.:::1 E :P2.8C) S 1. :.-.-:7 E: · ':":' ~'S E: :7:.: P]:E: E 16.02 S 8.81 E ,. ,, C) :::6 N I 3 '-~-' E': 2:1,45 S :3 :BO E ':.:.':2 ,, 8 4 S :3 2 7 E 2: :.'..::,. i'-:.', 2 E: ,:.,o ...':: 9. E 18.2'.T~ S 28 4'? E 1....,':', 97] N 88 :::C) E c:). 4.8 C). 12 ::-::. 5.7.":1. 4,., 49 DS :1. 4: WI=L.L I',10: 2:.7.: '.B i GMA-..-.r.~YR("~ F:'F;.2.1DHCILE BAY., IqOI:=(TH '.:3L_L')PE., AL~'.=;K~ J 0 B NO: A 0 :--:8:3 R () 350 P Z r_'; Ft MI::' I_I'T A'T' 101',i -I" I M E D A T [= (')'7 ', 42: 4/=, .1. '7-.0C'1'-:=::"=': TRUE HIEASI...IFi.'EL] DRIFT DRII::'T COL.IF;?.;E VF;R'T'TCP, L. VERTIfZ:AI_ SI_IBSEA _ :. _ I DEP'I-H "r I i": 0 R D I N A T E S Ii ! g;'TAI',ICE ri I REC"F I ON F-;EVER I "t DEP]"H AI'qEiL_IE D I RECT T ON t_EI'IATI--- :'.:;El:: f"lN TVI"I _ (:1 F'E E T 13 M I3 FI I=' E E 'T' F E E 'T F E E T F E E'T F' E E T F ["': [.": T [) H I3 G/! ()()I:" 31()(), 15 19 hi 0 1.1. 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I}'.::; .!.4, WELl.._ NO: 23 SIGMA-GYRO .._lOB NO: AOF..:::F:3F(O350F:'Z F:'F:;.rlJDHOE BAY, NORTH SLOPE-, ALASi<A '.:Ji; '[ GMA'.--E'iYRO, ()-10:3()() hlD.., L;UF;:.VF"]YOR: ,_IAIqN/PEFFERI<ORr:I.-, DATE] RUN: ,:'~,'.-7.'-AUG-:E::3 SI(}MA :300 hiE): 271:, PROBE NO: 0/_:".4 t:::'f')t::;,'l~i:'.ii]; :[ GFI"F: hi../.:.:_:: 3:3E S LIIR V I< Y T A K lei: N F" RI21Ff t..,.IE L L I'"IE ~ ][.-.i I:';,'E:F;~I...II',.t I]IF I:i;M'..:.]; Fj;!..II:;..'MEY I~11",,I REC:FIRD OF INTERPOLATED '.=;URVEY AI::;.~CO ALA'.'SI<A I NC, DS 14, WELL. I',10: 55=: SIGMA-Ci;YF~6~ I='F:,'LIEIHOEi; BAY, I',IORTH SI_OPE:'~ AI_ASKA J(:ilB NO: A() 883 R ()35 OF::' Z COMF::'IJ'TAT I 'T' I M E f.) A'T' E () 7: 45: .1. 5 17 ...- 0 C T.-8 F:'AOE IqCI ~- ...................... MP~Rt:::ER ................. TRUE SLIBSEA .............................. COBE .................... MEA'.:SUI::;~E[I VE:RTZCAL MD-TVD VERTIC:AL. R E=. C T ~ N (!; LI L A R C: L 0 S IJ R E VF:RTICAL. ........................... NAME .................. fi!EF:'TH DEF:'TH DIF'F DEF'TI.4 C: 0 0 Fi D I N A T E S DISTANC[= DIREC"f ION "I"H!CI<IqES;:E; TOP S;AG RIVER TOF::' '.:3HUBL. :1: I-::: "r o F:'S A l) L.. E R 0 CI.41 T (} / 0 iii: 0 N"I" A C"I- TOF' ';':ONtF 3 F' E E T F' E E 'T' F:' E E'T' F E E ]" F El E T F E E T 1] FI 976'P.0() 8601.11 .1.167.'? 8529. 11 364-2.91 N 834.84 W 9797.00 8626.91 i 1 '2' 0. i 8554.91 :36P;:3. :39 N 8:"":7.7 () W ¢87q.. 00 8698.20 I I '7'5.8 8626.20 :3681.28 N 84,/.:',. 07 9894 ,, 0("~ 87 .1. 6.71 1177 ,, :3 8644.71 :'5:68:=:. 51 N 848.2:.'4. 1.4 100:.=.i:6. ()() 8895.37 11 !¢0,, 6 8823.37 :3755.75' N 86:=:. 87 W H()'T' 'T'f.}F:' ZCII',IIE 2 11111 / I/...I C I:)N'T'A C'T' 101 ,'.'::,Zl. ,, 0() 8968 ,, 14 1 ] 'P5.9 88'P6. 14 .37:E:2.61 N 877.05 W :1. ()171 ,, 00 8'P74. ,S'7 .1, 1 'F'6. :3 8'P02.67 :.37:L'-':.'::;. 02 N ::2,'7'7.78 W 1 C)27 .1.. (")() 9068 ,, 2() .1. 202.8 :=:996.20 :=:8.1. 8.88 N 88:=:. 08 W 37:37. :35 N 12 54 W 374-8.20 N 1:2 55 W :3'7'77. '-'"- .,::.:, N 1:2 57 W :37:!ii:4.,79 N 12 5 '7 W :3854.94 iq .1. :2: 2 W :.38 8::.':. 96 N 1:3 ":":":'.=; 4.7 N 1:.5: :3920.78 N 1:3 DS 1 4_. WELL NO~ 23 S.[GHA-GYRO ~ALE } IN.-- ~O['FEET P~DHOE BAY NORTH- SLOPE ALASKA .......................... z ............................ ~ ..................................................... j .... ~_~_~_. I.ND_[CA~R ~ .~ ........ . . . ................... :. ...... ,.__~ ............ ~. ............ '__~,.~ .............. ~..:.'._:.' ..... }'::.~_:..,2:::.2.:~:.sr~'~.....:~.: .................. :__.' .... 22: . ' _ _ ~ ......... NORTH ~87~. 8~' ~ST ~-. 2~ ............... ._ ~. ' ' .: '~. ::_._...;_::_.'-_'-'~_'~' '.~':_.: :-:" ;~'."::~"_.: .... -':~.::~'::.:-:::'-~:~'-.:-_'-::":'-( .... .:::'~.-'~.':-:..-:-.~' .~"'::.:.'.:."_z'.: .... :-.'.::_ :....-r: .................. i .......... ' ............. ~ ............... ~ ............. ~ ....................................... ~ ..................... ....................... : .......... : ............ L .................................. = ......................... ~ .............. ................................................... ~ ............................ : .................................................................. ...... ~ ......................... ~ ............ ~ ..............., ~-~e~ , ~ · ............................. _ _ ~ ........... ~ ....... ........... : ............... ~ .... ..... ........................ ; ............................. ~ ........................ t ................. ~ ........... ~ ~ ................... ......... [ [= .......................................... ¢ ........ ¢- I ' '-;, ..... ~ .---I ............ f~~ .... ~ ¢---' ~ '- ' ~ ............ 2000 .............. 4~00 6000 _ 8000 . 1 0000 I 0 2000 VERTICAL SECTION 4000 20OO CLOSURE, 3980-18 N 13; 8 46 W Eastman Whipstock A PETROLANE ~PANY REPORT of SUB-SURF,4CE DIRECTIONAL SURVEY JUN 2 ~ .!~83 Alaska Oil & Gas Cons. COmmission Anchorage ARCO ALASKA, INC. COMPANY D. S. 14, Well Number' 23 WELL NAME Prudhoe Bay~ North Slope, ,,,Alaska LOCATION JOB NUMBER CDC A-0583-022 TYPE OF SURVEY Directional Single Shot DATE 13-JNN-83 SURVEY BY A. CHAPHAN (CONTOLLED DRILLING CONSULTANTS) OFFtCE ALASKA ARCO ALASKA~ · I NC. ~ DS 14, WELL NO: 23 DSS (CDC) PRUDHOE BAY, NORTH SLOPE, ALASKA DSS, 0~731 MD,..DRILLED-BY: A CHAPMAN~ (CONTROLLED DRILLING CONSULTANTS) RIO: PARKER 176 CDC JOB NO: A~0583=022 ! ....... .................... . .......................... RECORD-OF-SURVEY RADIUS OF CURVATURE METHOD ARCO ALASKA, INC. DS 14, WELL NO:· 23 DS.S (CDC) F'RI. JDHrjE BAY, NORTH SLOPE, ALA;_-,KA COMPUTAT I ON TIME ......... : ........... DATE 0: 22: 52 13-JUN-83 PAGE-NO.'° I ................................................... TRUE NEA.z, URE£ DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R E: L O S LI R E DEPTH FEET i 2508. 2582. 2705. 2828. DOGLEG ANGLE DIRECTION LENGTH DEPTH SECTION TVD C O O R D I N A T E $ DISTANCE DI7-(EC:TION SEVERITY D · M · D M ..... FEET .... FEET ........ FEET ........... L-FEET- ............................... FEE~ ...................... FEET--- ............ D ~-- M.-. DG/~10AF'[' 0 0 0 0 O. O. O0 O. O0 -72. O0 O. O0 O. O0 O. O0 0 0 0.00 0 0 0 0 ...... 2508.- 2508.00 ......... 0.00 2436.00 ........ 0.00 ............ 0.00 ................... 0.00 ........ 0 0 0.00 1 15 S 1 0 W 74. 2581.99 -0.7~ 2509.99 0.81 S 0.01 W 0.81 S 1 0 W 1.68) 3 15 N 43 0 E 123. 2704.c,9 -2.80 2&32 89 2.21 S 3.4~ E 4 10 S 57 25 E 3 46 9 30 N 23 0 E 123. 2827,07 7.'08' 2755.07 .................... ~.~18--N ............. 10,8~-E .......... t'4'~22 .... N-4~ 4~ E ,-. 5,:32 ~"¢~.=-,1. 1~'.:, 15 N -=, 0 E 123. 2947. 63 29. 08 2875.&,3 32.&,2 N 16.70 E 36. ~k4 N 27 ~:, E 4~&. 3044. 14 45 N 3 0 E ...... 93. 3037.87 ...... 50.87 2965.87 ............. 55.0&-N ........... 18.27-'E ...... 58.01 ..... N 18 31:3~.. 15 30.N 4 0 W 92. 312~,.68 74.51 3054.b8 79.05 N 18. Ob E 81.09 N 12 52 E 2.14 3228. 17 30 N 9 0 W 92. 3214.89 100.57 3i42.8~ 105.00 N 15.10 E '10~.08 N 8 Ii E 2.66 3.319. 20 30 N 12 "O'W ..... 91~ ........ 3300~92 ............1~0-'19 ......... ~228~'92 ...........1~4.'13--N ......... 9~.70-"E ........ t'~4~-48 N' 4' 8'E ....... 3.47 :3444. 23 0 N 14 0 W 12~[~:.~3~17.0t~ .... :~1.7~..~:~,~:~.8~.t]:[~.~ 17~.-5 N 0.72 W 179.2~ N 0 14 W 2.09 3719. :32 0 N 16 0 W l~::~:~J 36/-~o.~ ~3,1~. ~ee.~ 301.8~,N ~ ~1 W 303.84 N 6:36 W .15 ~:~ - -%~ ' :~ - ' / '~ 79 W .372 33 N 8 9 W '- 15 .3843. 35 45 N 14 0 W 12{;~:::~ 37&,3. 41 ~2~::~:~,~11~1,~~~:~ ~. . 493.3. 37 30 N 14 0 W 527. 4623.13 1039.67 -4551.13 1015.55 N ~26.15 W 1040.43 N 12 33 W 0.41 5424. 38 0 N 14 O-W ..... 4~1~. .... S011.-36~' 1339.~ ..... 4~3~..36 ..... 1307.22--N ...... 298.87--W ...... 1~40,~9~ ...... N.-12 G3 W ..... 0.~10 57&,3. 38 0 N 14 0 W 33~. 5278.4~ 1547. ~5 520~. 4~ 1509.73 N 34~. 36 W 154~. &,2 N 13 2 W O. 00 ~,287. 38 0 N 14 0 W 524. 5~91.41 1869.91 5~19.41 1822.75 N 427.41 W 1872.1~ N 13 i2 ~ 0.00 &,530. 38 ........ 0 N-t2 ..... 0~. W----.24~ ........ S882.~ ~0 ...... 2019~5--5810~,-~0 ..... I~68,~t--N ....... 461-~ 0~~~-~~N-t3 7053. 37 0 N 13 0 W 523. &,297.81' 2337.4~ 6225.81 227'~.33 N 52~.~7 W 2340.14 N 13 ~ ~ 0.22 7583. 34 30 N 13 O- W ........ ~30. .... ~727.~2 ..... 264~..-80 ....... 66~,..~2 .........2~81..03.-N ........ ~99-.6~.-W---2~4~.~ ...... Nt3-, ~ W ........... 0.47 7738. 33 15 N 14 0 W 155. ~85~.~0 2733.0~ 6784.60 26~5.03 N 61~.79 W 2736.1~ N 13 :3913. 28 15 N 11 0 W 1175. 7866.08 3333.15 77~4.08 3251.31 N 749.76 W 3336.63 N 12 5~ W 0.44 ~731. 23 1~ N 18 0 W ......818. 8&.O2.&.2 ...... 3&,87.27 .... 8530.~2 ...... 35~5.04--N ......... 838.66-W 3691-.5~N .-13~-. 8 W ....... 0.7i~ . FINAL C:LOSURE .... DIRECTION: ............ N..-.13--DEGS ....... 7.-..~IN$-,5~-~EC$-W DISTANCE: 3691.5~ FEET DRIFT CHART'S RELATED DATA FILE ARCO ALASKA, INC. -I~. ~ ~-~ [7 14, WELL NO: 2~ (CDC),- PRUDHOE BAY, NORTH SLOPE, ALASKA SURVEY FILE NUMBER 1727 BOTTOM HOLE ASSEMBLY VALUES USED FOR DEPTH ARE MD DEPTH DESCRIPTION 80.00 2520.00 3938.00 5863.00 7822.00 8471.00 9790.00 ' -. .,~. ~ ~ '?~ AS~EMB~ %~.~, . ANGLE BUIL[, ASSE~~ ANGLE BUILD ASSEMBLY ANGLE BUILD W/ ~. PT DRILLING DAYS ...................... VALUEG...USEDFOR---.DEPTH.ARE-MD DAY .... DEPTH 1 2 3 4 5 6 7 8 9 10 1 $20. 2520. O0 3292. O0 · ·- 3-9."24_8.00 6.030. O0 7235 · 00 8310. O0 8725.00 9625. O0 ...... ~ 9790;, O0 DEPTH 1452.00 ~ ~ ~ 0 00 35(}8.00 3938.00 5868.00 6617.00 7822.00 7822.00 8471.00 9790.00 DEPTH 1452.00 2520.00 3508.00 3938.00 6617.00 6617.00 7822.00 8471.00 9790.00 WEIGHT ON BIT WEIGHT-IS,GIVEN.PER IO00-POUND$ VALUES USED FOR DEPTH ARE MD WEIGHT 65.00 60.00 .-60.00 60.00 60.00 60.00 60.00 50.00 .......... 60. 40. 150. ..................... 80. O0 O0 90.00 130.00 ' 130.00 : ..... : ....................... 130.00 130.00 130.00 .................................................................................................................................................................................................................... 100.00 110.00 I I I -!-T!'K --I -F- LI! Jill _L! I I I t ~ I I I ! ' ! " t I '' ' i I i ~ ~ I i I ~ 1 I u' ' ' , , , ~ [ ~ t ~ ~ :~ .~ . ~ ....... ~-:-~.. , ,,, ~ I I I I t ' i I L [ ' L .... ~ ~ ~ ~' i~.~'s~'~'~ l III 1.~ J i J.I[I l: " l.J il i J J I =,J I [ .... i .... L ~ ~ J I J i i J :J 'J: ·['- ' ''J ....... ']' ,"~ ........ [,. .! ], .:~.~ I l i I I ~ :':.-~ ~.:l" F t-~ ' -'i:,:..?: :'~. 'L ' I' :.J.~ .~.'.F'=:~ :-". ;,.: .¥ ~ ~.1' ~,L..',-:~ :.: r :i-t 'L.:~,:" ~ [ I II ~ · ~ i ~ J , ,- t ~.~ L~ ~ ~ . . .' ~ :' . : ' ' ., ~..~ :...:.... :~' ~: . ' ' ' ~".~'.'~:.i~ = ;. ~.~ .... :'r ~" ' ~ '::: ~''' ' "f' ~ ~'~:.~ t' F F , ...... ~ ~ ~ ~ i ~ ~ ~ ~ i ~ ~ ~ ~ ~ t ~ ~ ~ I ~ ~ ~l ~ L... '~ ~ ' -" ! [ L J ~ i I [ i ! t L t I I ~ I [ J ,~ ! 1 .[ i [ " .... , , ~,. , : ' Suggested form to be inserted in each "Active" well folder to d~eck for timely compliance with our regulations. · ' ' OPerator, Well-Name- and Number -- Reports and Materials to be received by: ~'-~ Date Required Date Received Remarks Ccmpletion Report Yes /'1 -- ~ ~- ~ ~ Z~ ¢~' _ Well History Yes / t- -.. Samples /////~,~ __fl. -.'PI , . , ,.. Core De sc rip tion ,/~:/~.,~ .... ~ O"~~ , ........ ,.'~egistered. Survey Plat /~'~ 'Inclination Survey ~//~ Directional Survey / Drill Stem Test Reports -'~t~/'~e PrcddctiOn Test Reports - ..--------- , ~'- · Inc. ,-,,c~$Ka, Post O~tce ~,,~x 360 A.~,c,",oraoe.[ ska 99510 Teicpnone 907 277 5637 September 27, 1983 Reference' Arco Cased Hole Finals D.S. 1-19 'i'' 7-16-83 CFS D.S. 1-22¢/' 8-12-83 CFS D.S. 6-3 ~" 7-27-83 CFS D.S. 6-21 '~/ 7-30-83 CFS D.S. 14-23 J 8-10-83 Collar Log Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" GO Run t 5" Camco sign and return the attadhed copy as receipt of data. Kelly McFarland ATO-1429F Trans. ~/ 540 D&M Dallas Dri!!in~ Getty Marathon Mokil DISTRIBUTION North Ge ol'o~y Phillips Prudhoe Bay R & D Carcline Sro! t~. Sohio State of Alaska ARCO Alaska, Inc. Post Office Box 360 Anchora(::e. Alaska 99510 Teiecnor',~ ?07 ?77 August 15, 1983 Reference' Arco Cased Hole Finals D.S. 1-23 6-17-83 D.S. 14-23 6-13-83 6-11-83 6-8-83 6-27-83 6-9-83 6-8-83 6-8-.83 6-12-83 6-27 -83 6-9-83 Perforating Record Run 1 5" $ch CBL after squeeze Run 11 5" Sch CBL after squeeze Run 9 5" Sch GR/CCL Run 2 5" $ch Temperature Log Run 2 5" $ch Perforating & Retainer Setting Record Run 3 5" Sch CET Run 2 5" Sch CBL Run 1 5" $ch Perforating Record Run 10 5" Sch CET Run 2 5" Sch Perforating & Retainer Setting Record Run 8 5" Sch · ~~ease sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 468 Chevro~ D & M Dallas Drilling Exxon Ge try Marathon Mobi I DISTRIBUTION Caroling Smith Sohio State of Alaska ARC, O ,Alaska, InC. l~' " Post Office 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 July 13, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Monthly 'Report of Drilling & Workover Operations Dear Mr..Chatterton: Enclosed are Monthly Reports of Drilling and Workover Operations for the following: . DS 14-24DS 13-27 DS 3-19 Pingut State #1 South Point State #I and Well Completion or Recompletion Reports and Logs for: DS 7-24 DS 13-'28 Also enclosed are revised Well Completion or Recompletion Reports and Logs for: DS 1-25 DS 13-29 DS 7-25 Sincerely, M. A. Major Area Drilling Engineer MAM/CSM34: sm Enclosures ARCO Alaska. Inc. is a Subsidiary ~f AtlanticRichfieldComr~any STATE OF ALASKA 2 " ; 'ALASKA('" .. AND GAS CONSERVATION C~~ MISSION M #THLY REPORT OF DRILLING AND WORKOVER OPERATIO 1. Drilling well [~]X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-87 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20757 9. Unit or Lease Name FEL, Sec. 9, TION, R14E, UN Prudhoe Bay Unit 4. Location of Well 1401' FNL & 2017' at surface 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 72' RKB ADL 28312 10. Well No. DS 14-23 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool June 83 For the Month of. ,19__ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded ~ 1530 hfs, 05/22/83. Drld 17-1/2" hole to 2520'. Ran, cmtd & tstd 13-3/8" csg. Brld 12-1/4" hole to 9790'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 10440'. Ran logs. Ran, cmtd & tstd 7" lnr. Repair drawworks. Ran CBL #1 and #2; Ran CET. Perf 10138'-10140'; sqz perfs. 'Perf 9922'-9924'; 'sqz perfs. Reperf 9922'--9924'; .sqzd perfs. Ran CBL #3. Ran 5-1/2" compl assy. Secured well & tel rig ~ 1900 hfs, 06/14/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressur9 tests 20", 91.5#/ft, H-40, weld conductor set @ 81'. Instld w/375 sx PF II cmt. 13-3/8" 72#/ft, L-80 BTC csg w/FS ~ 2508'. Cmtd w/1500 sx Fondu & 400 sx PF "C" cmt. 9-5/8", 47.0#/ft, L-80 BTC csg w/FS ~ 9782'. Cmtd w/500 sx Class G cmt. 7", 29.0#/ft, L-80 BTC csg fr/9490'-10440'. Cmtd w/300 sx Class G cmt. SEE DRILLING HISTORY · 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SP/BNCS/GR fr/10432'-9766' FDC/CNL/GR/Cal fr/10432'-9766' CBL #1, tool failed CBL #2 fr/10400'-9300' CBL #3 fr/10260'-9298' CET fr/10386'-9480' '16. DST data, perforating data, shows of H2S, miscellaneous data Perf 10138'-10140'; sqzd w/100 sx Class G cmt. Perf 9922'-9924'; sqzd w/100 sx Class G cmt. Reperf 9922'-9924'; sqzd w/100 sx Class .G Cmt. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ Area SIGNED TITLE DATE .:. ~ ~.L"; .~? ~ ...... .,, . NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed' in d~Jp~ icate w th the Alaska Oil and Gas Conservation Commission by t{~,~tlNRPIt~e succeeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 Submit in duplicate DS 14-23 DRILLING HISTORY NU 20" diverter lines. Spudded well @ 1530 hrs, 05/22/83. Drld 17-1/2" hole to 2520'. Ran 63 jts 13-3/8", 72.0#/ft, L-80, BTC, csg w/FS @ 2508'. Cmtd 13-3/8" csg w/1500 sx Fondu and 400 sx PFC cmt. ND 20" diverter system. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 7822'. Ream 7755'-7822'. Drld to 8471', tight hole, work pipe free. Wash & ream 8321'-8471'. Con't drlg 12-1/4" hole to 9790' (05-31-83). Ran 247 jts 9-5/8", 47#/ft, L-80, BTC csg w/FS @ 9782'. Cmtd 9-5/8" csg w/500 sx Class G cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & form to 9795'. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10440' (06/02/83). Ran DIL/BHCS/SP/GR, DIL failed, rerun fr/10432'-9766'. Ran FDC/CNL/GR/Cal fr/10432'-9766'. Stuck tool, work WL, strip over WL. Work pup jt dwn over fish, work WL & DP to engage fish. RU T-bar & pull WL out of rope socket. Recovered logging tool. Arctic packed 9-5/.8" x 13-3/8" annulus w/50 bbls PFC cmt & 127 bbls AP. Ran 23 jts 7" 29#/ft, L-80 BTC lnr fr/9490'-10440'. Cmtd 7" lnr w/300 sx Class G cmt. Repair drawworks. Drld cmt to 9490'. Wash & ream 9490'-9560'. Drld cmt to 10400' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to 9.6 ppg NaC1. Ran CBL#i, tool failed. Run CBL#2 fr/10400'-9300', poor bonding. Ran CET fr/10386'-9480'. CET indicated channelling of 7" cmt job. Perf 10138'-10140' w/4 spf. Set cmt ret @ 10100'. RIH w/stinger, PU 3-1/2" & 5" DP. Stab into ret. Sqzd perfs w/lO0 sx Class G cmt. Perf 9922'-9924' w/4 spf. Run jnk bskt gauge ring to 9915'. Set ret @ 9900'. Sqzd perfs w/lO0 sx Class G. LD 11 jts 3-1/2" DP. Drl on ret 9911'-9913'. Drl ret & hard cmt to 9924', wash to 10041'. Drld & washed 10111'-10400'. Run CBL #2. Set RTTS @ 10116', pressure tst, no pressure loss. Reset RTTS & press tst 7"; leaked. Reperf 9922'-9924' w/4 spf. RIH w/EZ drl & set @ 9880'. Sqzd perfs w/lO0 sx Class G cmt. Washed to 9830'. Drld cmt to 10400' PBTD. Run CBL #3 fr/10260'-9298'. RIH w/csg scrapers & bit. Wash last 200' to btm. Retest 9-5/8" and 7" @ 1800' psi - ok. Ran 5-1/2" completion assy w/tail @ 9524' & pkr @ 9445'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Secured well & released rig @ 1900 hms, 06/14/83. ~E[E IVE~) CSM/DH16 O7/O7/83 JUL 18 !983 Oi! & Gas C~:,ns, Com~'~is,:'~ ARCO Alaska, Inc. /~' Post Office Boa, 0 Anchorage. Alaska 99510 Telephone 907 277 5637 June 28, 1983 Reference: Arco Open Hole Finals D. $. 14-23 6-3-83 6-2 -83 6-2 -83 DILL 6 - 3 -@ 3 CDL 6 - 3 -83 CDL/CNL 5" GO Run 1 2" & 5" Run 1 2" & 5" Run 1 2" & 5" Run 1 2" & 5" se sign a/%d return the attached copy as receipt of data. Kelly McFa~land ATO-1429D Trans. ~ 397 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS CAROLINE SMITH ARCO Alaska. ARCO Alaska, Inc. [~ ' Post Office Box~ ..0 Anchorage, Alaska 99510 Telephone 907 277 5637 June 28, 1983 Reference: Arco Magnetic Tape w/Listing D.S. 14-23 6-24-83 OH tape w/LAsting # 228621 i GO ,. e ~ign and return the attached copy as receipt of data. Kelly MCFarland ATO-1429D Trans. # 395 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS CAROL I NE SM I TH .ARCO Alaska mc. :s a Subs,alar¥ ,of &t!.~ntic~,icnf~e!c 2c "":." ARCO Alaska, Inc. .~ Post Office B( 60 Anchorage, AlasKa 99510 Telephone 907 277 5637 June 20,' 1983 Reference: Arco Di=ectional Data D.S. 7.-24 4-30-83 D.$. 14-23 6-13-83 Magnetic Survey Di~ectional' Single Shot Teleco EW /P~~ease sign and return the ~attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 369 NORTH GEOLOGY EXXG~ska Oil & Gas Co,Ts. C°mlnissio[i MOB I L Anchorage R & D DRILLING GETTY PHILLIPS D & M SOHIO ~'.~STATE'OF'ALASKA MARATHON DALLAS CHEVRON CAROLINE SMITH STATE OF ALASKA ALASKA (~". AND GAS CONSERVATION CO( ~llSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1Z Drilling wel,~ ................... Workove--'------~ ~'~ ..... 2. Name of operator ..... ~-~ --- - ARCO Alaska, Inc. 82-87 ~.. ~-- 8. APl Number ~- - P. 0. Box 360, Anchorage, AK 99510 50 029-20757 4. Location of Well 9. Unit or Lease Name atsurface 1401' FNL & 2017' FEL, Sec. 9, T10N, R14E, UN Prudhoe Bay Unit ?E. ~iT ~o. --- DS 14- 23 11. Field and Pool Prudhoe Bay Fi eld '5. Elevation infect (indicate KB, DF, etc.) I 6. Lease Designation andSerial No. Prudhoe Bay 0i 1 Pool 72' RKBI ADL 28312 For the Month of. May ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded ~ 1530 hfs, 05/22/83. Drld 17-1/2" hole to 2520'. Ran, emtd & tstd 13-3/8" csg, Drld 12-1/4" hole to 9790'. Running 9-5/8" csg as of 05/31/82. SEE DRILLING HITTORY 13. Casing or liner run and quantities of cement, results of pressur9 tests 20" 91 5#/ft, H-40, weld conductor set ~ 81' Instld w/375 sx PF II cmt '13-3/8" 72#/ft, L-80 BTC csg w/FS ~ 2508'. Cmtd w/1500 sx Fondu & 400 sx PF "C" cmt. 9-5/8", 47.0#/ft, L-80 BTC csg w/FS @ 9782'. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run None 16. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED Alaska 0ii & Gas ~,;o~s, ~,om,~isslo 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ Area Drill in, Engineer ~/,z/t/~ ~ SIGNED TITLE DATE NOTE--Report on 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 ~l'~eMl~f ~he succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 DS 14-23 DRILLING HISTORY NU 20" diverter lines. Spudded well @ 1530 hrs, 05/22/83. Drld 17-1/2" hole to 2520'. Ran 63 jts 13-3/8", 72.0#/ft, L-80, BTC, csg w/FS @ 2508'. Cmtd 13-3/8" csg w/1500 sx Fondu and 400 sx PFC cmt. ND 20" diverter system. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 7822'. Ream 7755'-7822'. Drld~to 8471', tight hole, work pipe free. Wash & ream 8321'-8471'. Con't drlg 12-1/4" hole to 9790' (05-31-83). Ran 247 jts 9-5/8", 47#/ft, L-80, BTC csg w/FS @ 9782' as of 05/31/83. CSM/DH16 06/07/83 RECEIVED 5 1 83 & uas (:~.';t'IS Post Office BoxY00360( ARCO Alaska, Inc. .Anchorage, Alaska 99510 Telephone 907 276 1215 June' 13, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501, SUBJECT- Monthly Report of Drilling & Workover Operations Dear Mr. Chatterton' Enclosed are Monthly Reports of Drilling and Workover Operations for the following' DS 7-24 DS 14-23 DS 13-28 DS 13-29 DS 13-27 South Point State #1 Pingut State #1 Sincerely, M. A. Major Area. Drilling Engineer MAM/CSM' tw CSM/31 Enclosures Also enclosed are Well Completion or Recompletion Report and Log for the following wells' DS 1-25, DS 13-29, and DS 7-25. RECEIVED ARCO Alaska, Inc. ix a Rubsid~a~y ol AtlanticRichfieldCompen¥ Alaskt~ Oil & Gas gons, (.;or,~ml~slon ' MEMORAI OUM Stat of Alaska ALA~ OIL AND GAS CONSERYATION COMMISSION C. erton DATE: Hay 26, 1983 Ch ~r~[[~'~ ' ~,~ FILE NO: T~RU: Lonu~e C. Smith FROM: Commissioner Bobby Fos ter-i~. Petroleum Inspector TELEPHONE NO: SUBJECT: ~itness BOPE Test On ARCO's DS 14-23 Sec. 9, T10N. R14E U~I Permit #82-87 Tuesday~ l~ay 24, 1983: The BOPE test began at 8:30 a.m. ~--nd'-'was ~'O:n'~lUde"d a"t ~i1:00 a.m. As the attached BOPE inspection report shows there ~ere three failures, A flange on the choke manifold leaked, the check valve leaked and an outside valve on the lower mud cross leakedo The flange vas tightened and tested. The other tvo failures are to be repaired, tested and the AOGCC office notified. In summary, I ~rltnessed the B.OPE test on ARCO's DS 14-2.3, Attachment: Don Breeden notified me on 5/25/83 that the repairs had been comp let ed. 02-00IA(Rev. 10/79) STATE OF ALASKA ALASKA OI c -GAS fDNSERVATION CCMMISSION B.~ .E. Inspection Report Well _ ~'~- ~' 1..~/'- 2 ~ Permit # ~ -- ~ . ~tion: Sec q T/OX~q~ M 0 _ /~as~g .Set ~il ~nq ~n~a~or ~~~-Rig gT~ - Repre~ntat ive~'~ .~~?~ '' ~tiOn, ~nera~ ~~ "' , AC~U~R SYS~M Well Sign Ceneral Housekeeping ,.,~ Rig BOPE Stack '" '!" °. '", Pressure Blind.~s' ve~~.~ ~oke ,~ne V~ ~ H.C.R. Vale, , - / ~ ~e~ Valm.' ~ "ull Charge Pressure__~_~/~ ~ ps'ig ~essure After Closure/~ O' psig Pump incr. clos. pres.' 200 ps ig -- min~sec. Full Charge Pressure Attained: __~__min_~sec. Controls: Master~_ Remote L~P Blinds switch cover Kelly and Floor/ Safety Valves · Upper Kelly / Test Pressure Lower Kelly /_ Test Pres sure (' Ball Type /. Test Pressure Ins ide BOP / Test Pres sure Choke Manifold_~~est Pressure No. flanges A~juStable Chokes Hydrauically operated choke ../ Test Results: Failures~ "~ Test Time:~ ~/~-/hrs. , _ Repair or Replacement of failed equipment to he made within_ days and Inspector/C_a~nis~ion offic~ not. if, ied. - ., ~_ ,9 /~ , Distribution orig. - AO&GCC cc - Operator cc - Supervisor May 9, 1983 Mx. }~rk A. Major Area Drilling Engineer ARCO Alaska, Inc. ?. O. Box 360 Anchorage, Alaska 99510 Ret Prudhoe Bay Unit DS 14-23 ARCO Alaska, Inc. Permit No. 82-87 Sur. Loc. I401'~,L, 2017'FEL, Sec. 9, T10M, R14E, UM. Btmhole Loc. 2584'~L, 2513'FWL, Sec. 4, T10N, R14E, Dear Mr. Mai or: Enclosed is the approved revi~ed application for permit to drill the.above referenced well. The provisions of the cover letter, dated June 7, 1982, accompanying the original approved permit are in effect for this revision. V~y--.truly y~ur,s, / /.,., .... : t/" ,:~ f,~? ....... .......... /~' ~ · / ./' ,',' ,..'..~.. ..., C. V. Chattert~ ~atr~n of ,.... ORDER OF TME Alaska Oil and Gas Conservation Commission Enclosure: ce~ Depart~ent of Fish & Game, Habitat Section wig encl. Department of Envtron~ntal Conservation w/o encl. be ARCO Alaska, Inc. ~ Post Office B% 360 Anchorage, Alaska 99510 Telephone 907 277 5637 lqay 3, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 14-23, Permit to Drill (Revised) Dear Mr. Chatterton' Due to a change in the bottomhole location, we are resubmitting our application for Permit to Drill DS 14-23. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we expect to spud this well on May 15, 1983, your prompt approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JG2L63-sm Enclosures ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany .0 1883 Alaska Oil & Gas Cons. O~mmissio,,~ Anchorage g, STATE OF ALASKA ~O(i ALASKA -AND GAS CONSERVATION C ,,vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~Q[ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I--I SINGLE ZONE [X]X MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1401' FNL, 2017' FEL, Sec. 9, TION, R14E, UN At top of proposed producing interval 2344' FSL, 2578' FWL, Sec. 4, TION, R14E, UN At total depth 2584' FNL, 2513' FWL, Sec. 4, TION, R14E, UN 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 72' RKB ADL 28312 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 9. Unit or lease name Prudhoe Bay Unit 10. Well number 14-23 11. Field and pool Prudhoe Bay Field Prudhoe Bay 0il Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 5 mi. NE of Deadhor~e miles 2513' ~ TD fr/ADL 28313 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 10514'MD, 9241 'TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2600 feet. MAXIMUM HOLE ANGLE 35 oI (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed well feet 18. Approximate spu~ date ~ _ ~60 _psig~ 9241 ft. TD (TVD) SIZE Hole I Casing ~0" I 20" 17-1/2" / 13-3/8" 12-1/4" / 9-5/8" / 8-1/2"/ 7" Weight 91.5# 72# 47# 29# Proposed Casing, Liner and Cementing Program 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 Welded L-80 . BTC L-80 BTC L-80 BTC SETTING DEPTH 2470' 9728' MD TOP TVD Length 80' 30' I 30' 30' I 30' 29' ~ 29' I I 1057' 9457 ' 18377' I MD BOTTOM TVD 110' 110' 2500'12500' 9757'18622' 10514 '~! 9241 ' QUANTITY OF CEMENT (include stage data) 375 sx Permafrost II 2300 sx Fondu+400sx PF , 500 sx G 1st stage 300 sx PF 1, 2nd stage 400 sx Class "G" cement ARCO Alaska, Inc., proposes to directionally drill this well to 10514'MD (9241'TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8", 5000 psi, RSRRA BOP stack will be installed. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#, L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A separate Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be used on this well. DS 14-23 will be 185' away from DS 14-20 at the surface.. There are no closer wellbores anywhere down hole. RECEIVED 23.' hereby certify that the foregoing is true and correct to the best of my knowledge MAY 0 5 ! 83 SIGN ED ~ TITLE Area ~j~4.~.~rl~t, ~.,~llq [:r, mrnle~AZE 5/Y/;~ 5 The space below for Commission use Anchorage Samples required []YES ~NO Permit number APPROVED BY Form 10401 Submit in triplicate Rev. 7-1-80 CONDITIONS OF APPROVAL Mud log required Directional Survey required I APl number []YES ~.bI.O [~YES r-INO Approval date; SEE COVER LETTER FOR OTHER REQUIREMENTS .COMMISSIONER DATE _~_¥ 9, !983 by order of the Commission PRO : 4UU . . I0 13-5/8" BOP STACK O! AM / .o PREVENTER BLINORAMS Accumulator CaDacit7 Test 1. Check and ftll accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, t~en close all units simultane- ously and record the time and pressure remaining after all units are closed with Charging pu, p off. 4. Record aa IADC report. (The acceptable lower limit ts 45 seconds closing time and 1200 psi remaining pressure. PIPE RAMS I)RILLII~ SPOOL PIPE RAMS ~3-$/8' 80P Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. ~. Check that all hold down screws are fully retracted. Mark running Joint with predeter- mined plug seating depth. Run test plug on dr111 ptpe and seat in wellhead. Run in 'd~m scr~. 3. Close annular preventbr and chokes and bypass v&lves on mantfoldo 4. In each of the following tests, ftrst hold a. 250 psi 1oN pressure test for a mtntmum of '3, mtnutes, then test at the high pressure. 5. Increase presure to(~'~0~ and hold for a minimum o~ 3 minutes,~ pffessure to zero. 6. Open annular preventer and close ptpe rams. Increase pressure and hold for at least 3 minutes. 8lead pres- sure to zero. 7. Close valves dtrectly upstream of chokes and open chokes. Increase pressure to SO00 psi & hold for at least 3 minutes. Bleed pressure tO zero. 0gan top set of ptpe rams then close bottom set of ptpe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. Test remaining untested mantfold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. Bleed pressure to zero. Open* bottom set of pipe 11. Back off running Joint and pull out of hole. Close blind rams and test to 5000 psi for at least3 minutes. IZ. Bleed pressure off all equipment. O~en blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drill lng position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with 15. Check operation of Oegasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- v i sor. [7. Perform complete Bore test once ~ week"~,u:',~, c~SCO~ functional ly operate Bore daily Rev. S/13/81 SURFACE HOLE D IVERTER ARCO ALASKA SYSTEM INC'. SCHEMATIC ~/~, IO" HYD. OPR. BALL VALVE V~ELL BORE (SEE DETAIL) mo" HYD. OPR. BALL VALVE /' ,//' )ALL 90° TURNS ARE "TEE" ~'~ I CUSHION I I ~LL RESERVE PIT AREA NOTE' FLC~ INE DRILLING RISER 20" 2000 PSI WP ANNULAR PREVENTOR Valves on diverter lines open automati- cally when the annular preventer is closed. -- DR ILL ING SPOOL 20" OONDUCTOR PIPE I O" HYDRAULIC OPERATED BALL "DETAIL" 2o26olor June 7, 19//2 ~4r. ~.lark A. Major Area Drilling Engineer ARCO Alaska, Inc. .P.O. Box 360 Anchorage, Alaska 99510 Re: Prudhoe Bay Unit DS 14-23 ARCO Alaska, Inc. Permit No. 82-87 Sur. Loc, 1401~FNL, 2017'FEL, Sec. 9, T10N, R14B, ~i. Btmhole Loc. 2857'FSL, 2793*FEL, Sec. 4, T10N, R14E, U~. Dear Mr. Major: Enclosed is the approved application for permit to drill the above referenced well. ?~ell samples and a ~d log are not required. A continuous directional survey is required as per 26 AAC 25,050(b)(5). If available, a tape containing the digitized lofg information sha.ll be submitted on all 1o~s for copying except experimental logs, velocity surveys and dipmeter surveys. ~any rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS. 16.05.8'70 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). prior to cemmencing operat ions y~u ~ay be contacted by the ltabi tat Coordinator Office, Department .of Fish and Gau~e. Pollution of any waters of the State is prohibited by AS 46, Chapter 3,~ Article ? and the reg~lat.ions promulgated thereunder (Title 1~, Alaska Administrative Code, Chapter 70) and by /he l~ederal Water Pollution Control Act, as amended. Prior to coam~enoing operations you may be oontaeted by a representative of the Department of Envirorm~ental Conservation. To aid us in scheduling~ field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a representative of the C~ission may be present to witness Mr. Mark A. Major Prudhoe Bay Unit DS 14-23 -2- June ?. 1982 testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a wi tness present. Very tl'uly yours, ~C. V. Chatterton Chairman of aB~ynd ORD£~ OF TH~ COM~;o~. Gas conse~vatlon ~~ssion Alaska Oil Eric 1 o sure cc: Department of l~ish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enel. C~C~ be ARCO Alaska, Inc.[~ Post OfficeB~. J60 Anchorage, Alaska 99510 Telephone 907 277 5637 May 28, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 14-23, Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill DS 14-23 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's posi- tion to the nearest well drilled; a sketch and description of the BOP equipment and testing procedures; and a sketch of the surface diverter. Since we estimate spudding this well on June 12, 1982, your prompt approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JG: 1 lm Enclosures GRU1/L6 JU~. 21582 Oil & ~as Cons. ARCO Alaska~ ~nc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ,LAND GAS CONSERVATION C ,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC L_~ REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, AK 99510 4. Location of well at surface 9. Unit or lease name 1401' FNL, 2017' FEL, Sec. 9, TION, R14E, UM Prudhoe Bay Unit At top of proposed producing interval 10. Well number 2409' FSL, 2568' FWL, Sec. 4, TION, R14E, UM Drill Site 14-23 At total depth 11. Field and pool 2857' FSL, 2793~FEL, Sec. 4, TION, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.)I6. Lease designation and serial no. Prudhoe 0il Pool 71' RKBIADL 28312 12. Bond information (see 20 AAC 25.025) I' ederal Insurance Co Type St atewide Surety and/or number 8088-26-27 Amount $500 ~ 000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or compl.eted 6 Mi NE Deadhorse miles 2712 feet 14-11 well 1154 (~ St~I'I~CC'~feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 10499'MD,9244' TVD fe.,.t 2560 06/12/82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 372~ psig@____Surface KICK OFF POINT 2600 feet. MAXIMUM HOLE ANGLE35 ° I (see 20 AAC 25.035 (c) (2) 45r~3 ._psig@~ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 30 20 94# H-40 Welded 110 0 I 0 110 ~ 110 275sx PF II to surf 17-1/2 13-3/8 72# L-80 Butt 2600 0 0 2600I 12600 2300sX ASIII+4OOASI 12-1/4, 9-5/8 47# L-80 Butt 9763 0 , 0 9763 18641 250sx G 1st Staqe S00-95 ~l I 300sx PFI, 2nd Stage 8-1/2 7 29# L-80 Butt 1036 9463 8395 10499 119244 400sx Class G cement 22. Describe proposed program: ARCO Alaska, Tnt., proposes to dlrectionally dr111 this well to 10,499' MD (9244' TVD) to produce the Sadlerochit zone. Logs w111 be run across~_.~ected intervals. A 13-5/8" 5000 psi, RSRRA BOP stack will be installed and tested to~00~..~si, The BOP equipment w111 be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#, L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. A non-freezing fluld will be left in all uncemented annuli withln the permafrost interval, The packer w111 be set above the Sadlerochit. A separate Sundry Notice will be submitted when the well ls to be perforated. ECEiVED 23. I hereby certify that the foregoing is true and correct to the best of my knowledge ~'~' --'~ SIGNED TITLE Area Urlll~ ~!~(~~__~ DATE The space ~uL;'r/0j'~ ..... °~#O/1 CONDITIONS OF APPROVAL Samples required Mud Icg required Directional Survey required I APl number []YES ~O [-~YES [~JXIO [~YES [-iNOI 50- O ~,,~ Permit number Approval date ~'~-°°7 .~:~0'~J~/82~ / ~ _.--.- SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ~//~~~~~/~~/'~ ,COMMISSIONER DATE _Tl ln,~ ~ /~ / by order of the Commission Form 10-401 GRU6/B18 / Submit in triplicate Rev. 7-1-80 '-~-~' "~' .~--i'i~ ' ~ ~,~ ~,~,u.~. JUN-29~']982 ~aska Oil & ~as Cons.~~ss~on ~. ,- ,... ~ SURVEYING IN THE STA'~,E OF .~% n'~ ~.~ MADE BY ME, z~.~ T;4AF *'' ,- ...... ~-,--'--- AR= CORRECT, AS Mr / / RIVER; ; . , --. . 13-5/8" BOP STACK DIAGRAM ANNULAR PREVENTER BLIND RAMS PIPE RAMS SPOOL PIPE RAMS Accumulator Capacity Test 1. Check and -fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit-is 45 seconds closing time and 1200 psi remaining pressure. · 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer, and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a.250 psi low pressure test for a minimum of 3~ minutes, then test at the high pressure. 5. Increase presure to 3000 ~si and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. 9. Test remaining untested manifold valves {if any} with 5000 psi upstream of valve and zero pressure downstream. " 10. Bleed pressure to zero. Open bottom set of pipe rams o 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. Rev. -' SURFACE HOLE D TVERTER ARCO ALASKA SYSTEM INC'. SCHEMATIC WELL (BORE RESERVE PI'T · AREA NOTE: FLOWL INE DR ILL lNG RISER 20" 2000 PSI WP ANNULAR PREVENTOR ~~~u" O%VERTER LINE Valves on diverter lines open automati- cally when the annular preventer 'is closed. -- DR ILL SPOOL , '20" CONDUCTOR PIPE I0" HYDRAULIC OPERATED BALL VALVES "DETA IL" 2026010203 CHECK LIST FOR NEW WELL PERMITS Company ,,, ,~~ Lease & Well No. /& ~ IT~ APPROVE DATE (4) Casg ~;~.//'gt'o (12 thru 20) 13. 14.· 15. 16. 17. 18. 19. 20. YES NO Is the permit fee attached .......................................... Is well to be located in a defined pool ............................ 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 and is well bore plat included ............... Is operator the only affected party ................................. Can permit be approved before ten-day wait ........ .. ................. Does operator have a bond in force .................................. Is a conservation order needed ................... Is administrative approval needed ................................... 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 .... ................ Will surface casing protect fresh water zones .......... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore .............. Is old wellbore abandonment procedure included on I0-403 ............ Is adequate well bore separation proposed ........................... REMARKS (5) (21 thru 24) 21,. 22. 23. 24. Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating -Test to .26"~ psig . Does the choke manifold comply w/API RP-53 (Feb.78) ............. ' ..... (6) Add: ~~ ~_~~.-~ 25. Additional requirements · Additional Remarks: Geology: Engineering: HWK~ LCS BEW ~ WVA ~ J KT RAD 3AL~--~MTM~. _ rev: 01/13/82 ~ ~ INITIAL ' - 'GEO. UNIT '" 0~'/0'~F POOL CLASS STATUS AREA NO. SHORE CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. )?)~. ~ ITEM APPROVE DATE (1) Fee (2) Loc thru 8) 1 Is the permit fee attached 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line ................. 'I 4. Is well located proper distance from other wells .................... 5. Is suffiCient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included ....... , ....... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... (3) Admin"~~~-./~ ~-3-~3 9. (9/~hru ~ 1) 10. 11. 12. i3. 14. 15. 16. 17. 18. 19 20. 21. 22. 23. 24. · (4) Casg ~ (12 thru 2~)' (5) BOPE (21 thru 24) ( 6 ) Ad d: ~ff~.~. ~5'/O'/F.~ 2 5. YES NO REMARKS Does operator have a bond in force .................................. ~:t.- Is a conservation order needed ...................................... Is administrative approval needed ................................... 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............... ...... Will surface casing protect fresh water zones ..'---.'..-.''...-o--.- Will all casing give adequate safety in collapse, tension and burst.. ~t Is this well to be kicked off from an existing wellbore ...~ .......... Is old .wellbore abandonment procedure included on 10-403 ............ · Is adequate well bore separation proposed ............................ Is a diverter system required ......... ' ............................. , ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sUfficient pressure rating - Test to o~-ooc> psig ..~.~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: o ~z rev: 12/06/82 "" INITIAL IG~O, UNIT ON/OFF' .pOOL ........ qVSSll STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. .. No special effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... * COMPANY NAME : ARCO ALASKA, INC. WELL NAME : DS !4-23 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : $002920?5?00 REFERENCE NO : 99078 RECEIVED ~!AR O~ ~ ~ & Gas Co,s. commission LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: **** REEL HEADER **** SERVICE NAM~ : EDIT DATE : 99/02/22 ORIGIN : FLIC REEL NAME : 99078 CONTINUATION # : PREVIOUS REEL .. COMMFIFr : ARCO ALASKA,DS 14-23, PRUDHOE BAY, API# 50-029-20757-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/02/22 ORIGIN : FLIC TAPE NAME : 99078 CONTINUATION # : 1 PREVIOUS TAPE : COMFLENT : ARCO ALASKA, DS 14-23, PRUDHOE BAY, API# 50-029-20757-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 14-23 API NUMBER: 500292075700 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 22-FEB-99 JOB NUMBER: 99078 LOGGING ENGINEER: VETROMILE OPERATOR WITNESS: SHUMWAY SURFACE LOCATION SECTION: 9 TOWNSHIP: iON RANGE: 14E FNL: 1401 FSL: FEL: 2017 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 72. O0 DERRICK FLOOR: 71. O0 GROUND LEVEL: 42. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8.500 7.000 10440.0 2ArD STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASUREDDEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 24-JUN-83 LOGGING COMPANY: GEARHART BASELINE DEPTH .............. 88888.0 10057.0 10042.5 10041.0 10032.0 10027.0 10025.5 10024.0 10020.5 10014.5 10011.0 10009.5 10008.0 10001.5 9986.0 9984.5 9977.0 9976.5 9975.5 9970.5 9966.0 9959 0 9955 5 9954 0 9953 0 9951 0 9947 0 9934 5 9923 0 9920 5 9917 5 9917 0 9908 0 9905 5 9899 5 9898.5 9895.5 9894.O 9882.5 9879.5 9878.5 9876.0 9875.5 9872.0 9869.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH RST .............. 88889.0 88889.0 10026.5 10022.5 10011.0 9987.5 9978.0 9976.0 9970.5 9967.5 9959.5 9956.5 9953.5 9947.5 9924.5 9921.5 9917.5 9904.5 9901.0 9895.5 9881.0 9878.0 9873.5 9870.5 10058.0 10044.5 10043.5 10035.0 10029.0 10026.5 10016.5 10014.0 10010.5 10004.0 9987.0 9979.5 9969.0 9956.5 9953.5 9938.0 9919.5 9911.0 9901.0 9898.5 9885.5 9881.0 9877.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 9865.5 9867.5 9865.0 9867.5 9863.0 9866.0 9858.0 9860.5 9857.5 9860.0 9857.0 9858.0 9855.5 9856.0 9850.0 9851.5 9848.0 9849.5 9845.0 9846.5 9844.0 9846.5 9841.5 9842.5 9843.5 9839.5 9842.5 9837. $ 9839.0 100.0 101.5 103.0 $ REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON ARCO ALASKA'S DS 14-23 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS GAlV~IA RAY, ALSO BASE PASS #1 SIGMA AND THE BCS GAM~A RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ PAGE **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: I EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: DEPTH INCREMENT: 0.5000 FILE SUM~Lau~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10041.0 9835.5 RST 10061.0 9837.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. REF~aJ~fS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1185993 O0 000 O0 0 1 t 1 4 68 0000000000 NBAC RST CPS 1185993 O0 000 O0 0 t 1 1 4 68 0000000000 FBAC RST CPS 1185993 O0 000 O0 0 1 t 1 4 68 0000000000 SBNA FIL CU 1185993 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1185993 O0 000 O0 0 t t 1 4 68 0000000000 SBFA FIL CU 1185993 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1185993 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1185993 O0 000 O0 0 1 1 1 4 68 0000000000 IP~T FIL 1185993 O0 000 O0 0 1 1 1 4 68 0000000000 CIRNFIL 1185993 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1185993 O0 000 O0 0 I 1 1 4 68 0000000000 BSALRST PPK 1185993 O0 000 O0 0 1 I 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: NAM~ SERV UNIT SERVICE API API API API FILE NUFIB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELI~ CODE (HEX) SIBF RST CU 1185993 O0 000 O0 0 1 1 1 4 68 TPHI RST PU-S 1185993 O0 000 O0 0 1 1 1 4 68 SFFC RST CU 1185993 O0 000 O0 0 1 1 1 4 68 SFNC RST CU 1185993 O0 000 O0 0 1 1 1 4 68 SIGM RST CU 1185993 O0 000 O0 0 1 1 1 4 68 DSIG RST CU 1185993 O0 000 O0 0 1 1 1 4 68 FBEF RST UA 1185993 O0 000 O0 0 1 1 1 4 68 CRRARST 1185993 O0 000 O0 0 1 1 1 4 68 GRCH RST GAPI 1185993 O0 000 O0 0 1 1 1 4 68 TENS RST LB 1185993 O0 000 O0 0 1 1 1 4 68 CCL RST V 1185993 O0 000 O0 0 1 1 1 4 68 GR BCS GAPI 1185993 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 10070.000 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT.FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST -999.250 CRRA.RST GRCH. RST -999.250 TENS.RST -999.250 CCL.RST -999.250 GR.BCS DEPT. 9820.000 NBAC. RST -999.250 FBAC. RST SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF.FIL SIBF.RST -999.250 TPHI.RST -999.250 SFFC.RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF.RST GRCH. RST -999.250 TENS.RST -999.250 CCL.RST -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC.RST -999.250 CRRA.RST -999.250 GR.BCS -999.250 -999.250 -999.250 -999.250 -999.250 19.600 -999.250 -999.250 -999.250 -999.250 -999.250 92.300 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 99/02/22 MA3f REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01COI DATE : 99/02/22 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 10041.0 9831.5 RST 10061.0 9832.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888 0 10057 0 10041 0 10033 5 10032 5 10026 5 10024 0 10023 0 1001I 5 10009 5 10008.0 10004.0 10000.0 9986.0 9977.0 9974.5 9968.0 9957.5 9951.5 9949.5 9946.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88889.0 88889.0 10034.5 10025.0 10011.0 10007.0 10002.0 9987.5 9975.0 9967.5 9950.5 9948.0 10058.0 10043.5 10035.5 10029.0 10026.5 10014.0 10010.5 9979.5 9971.0 9960.0 9954.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE 9941.0 9944.0 9939.0 9939.5 9934.5 9938.0 9933.0 9935.5 9922.5 9924.5 9921.0 9922.0 9917.5 9920.0 9914.5 9917.0 9910.5 9913.5 9905.5 9908.5 9902.5 9904.5 9898.5 9901.5 9897.0 9898.0 9895.0 9898.5 9892.5 9895.5 9883.0 9885.5 9879.5 9881.0 9878.5 9881.0 9876.0 9878.0 9872.0 9873.5 9869.5 9871.5 9869.0 9870.5 9866.0 9867.5 9865.0 9867.5 9864.0 9866.5 9863.0 9865.5 9860.5 9860.5 9857.5 9860.0 9855.0 9856.0 9849.0 9851.5 9847.0 9848.0 9845.0 9846.5 9844.0 9847.0 9841.5 9843.5 9840.0 9842.5 100.0 101.5 102.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 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 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1185993 O0 000 O0 0 2 1 1 4 ,68 0000000000 SBFA FIL CU 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1185993 O0 000 O0 O, 2 1 1 4 68 0000000000 BSALRST PPK 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1185993 O0 000 O0 0 2 I 1 4 68 0000000000 SFNC RST CU 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 CRRA RST 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1185993 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: ** DATA ** DEPT. 10061 SFNA.FIL 23 IRAT. FIL 0 SIBF. RST 25 SIGM. RST 19 GRCH. RST -999 DEPT. 9831 SFNA.FIL -999 IRAT. FIL -999 SIBF. RST -999 SIGM. RST -999 GRCH. RST 194 000 NBAC.RST 126 SBFA.FIL 538 CIRN. FIL 667 TPHI.RST 294 DSIG.RST 250 TENS.RST 2713 357 35 835 1 172 27 270 0 169 1330 000 FBAC. RST SFFA. FIL CIRF. FIL SFFC. RST FBEF. RST CCL. RST .500 NBAC.RST -999.250 FBAC. RST .250 SBFA.FIL -999.250 SFFA.FIL .250 CIRN. FIL -999.250 CIRF. FIL .250 TPHI.RST ~-999.250 SFFC.RST .250 DSIG.RST -999.250 FBEF.RST .977 TENS.RST -999.250 CCL.RST 3847.845 SBNA.FIL 21.725 TRAT. FIL 2.106 BSAL.RST 19.349 SFNC.RST 36.226 CRRA.RST -0.009 -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC. RST -999.250 CRRA.RST -999.250 47. 078 1. 022 10.217 19. 754 I. 921 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS RST 1, 2, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: 10 REFzAPJ<S: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF BASE PASSES 1 & 2. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA RSAV CU 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA RSAV CU 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA RSAV CU 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA RSAV CU 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT RSAV 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT RSAV 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNRSAV 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF RSAV 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 BSALRSAV PPK 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RSAV CU 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RSAV PU-S 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RSAV CU 1185993 O0 000 O0 0 3' 1 1 4 68 0000000000 SFNC RSAV CU 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: 11 NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD~ SAMP EL~4 CODE (HEX) SIGM RSAV CU 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RSAV CU 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RSAV UA 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 CRRARSAV 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 GRCHRST GAPI 1185993 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10061 . 000 NBAC.RST 3294. 118 FBAC.RST 4109. 874 SBNA.RSAV 46. 729 SFNA.RSAV 23.960 SBFA.RSAV 36.001 SFFA.RSAV 21.978 TRAT.RSAV 0.999 IRAT.RSAV O. 541 CIRN. RSAV 1 . 135 CIRF.RSAV 2. 079 BSAL.RSAV 10. 850 SIBF.RSAV 25. 886 TPHI.RSAV 25. 458 SFFC. RSAV 19. 634 SFNC.RSAV 20. 482 SIGM. RSAV 19. 544 DSIG.RSAV O. 649 FBEF. RSAV 40.152 CRRA.RSAV 1 . 912 GRCH. RST - 999.250 DEPT. 9835.500 NBAC. RST -999.250 FBAC.RST -999.250 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV -999.250 IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV -999.250 BSAL.RSAV -999.250 SIBF.RSAV -999.250 TPHI.RSAV -999.250 SFFC. RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF.RSAV -999.250 CR~.RSAV -999.250 GRCH. RST 60. 685 ** EArD OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01COI DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: 12 FILE HEADER FILE NUMBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREFiE2Fr: 0. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... RST 10085.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAF~ZA RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : STOP DEPTH 9784.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 24 -JUL-98 8C1-205 10440.0 10074.0 9830.0 10060.0 TOOL NUMBER CGRS-A RST-S 8.500 10440.0 CRUDE/BORAX THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: 13 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): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): RI~4ARKS: LOG TIED INTO SLB TND DATED 3 APR 1997 TWO CRUDE PASSES WERE LOGGED WITH 337 BBL AWAY AT 5 BBL/MIN. CRUDE PASSES LOGGED WITH 1 BBL/MIN PUMPING THREE BORAX PASSES WERE LOGGED WITH 80 BBL AWAY AT 5 BBL/MIN. BORAX PASSES LOGGED WITH 1 BBL/MIN PUMPING FIRST BORAX PASS HAD 170 BBL CRUDE AWAY @520 PSI FIRST PASS HAD 25 BBLS BORAX BEHIND PIPE SECOND BORAX PASS HAD 181 BBL CRUDE AWAY @ 500 PSI THIRD BORAX PASS HAD 191 BBL CRUDE AWAY @ 475 PSI BEFORE PUMPING WHP 1400 PSI IA 900 PSI/OA 400 PSI TADDED TD AT 10074 ' THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: 14 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 CS PS1 F/HR 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 TENS PS1 LB 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 NPHVPS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 NPDE PS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 NSCE PS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 CRRA PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 NSCR PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 AQTMPS1 S 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 CHV PS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 CPSV PS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 CP2V PS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 CM2V PS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 RCFR PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 RCLC PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 RCRC PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 RCAK PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 RTDF PSI 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 FPHVPS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 FPDE PS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 FSCE PSl V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 FSCR PSl 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 AQTF PS1 S 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SF6P PS1 PSIG 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 HVPV PS1 V 1185993 O0 000 O0 0 4 1 I 4 68 0000000000 BMCU PS1 UA 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 GDCU PSI MA 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 EXCU PS1 UA 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 NBEF PS1 UA 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF PS1 UA 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 NPGF PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 FPGF PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 BSTR PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 BSPR PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 MARC PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 XHV PS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 XPSV PS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 XP2V PS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 X~I2V PS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 EXFR PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 RXLC PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 RXRC PS1 1185993 O0 000 O0 0 4 1 I 4 68 0000000000 RXAKPS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SHCU PS1 MA 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL PSl PPK 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL SIG PPK 1185993 O0 000 O0 0 4 I 1 4 68 0000000000 CIRNPS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF PSl 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: 15 NAME SERV UNIT SERVICE API API API API FILE NUF~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) ....................................................................................... CIRNFIL 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG PS1 CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC PS1 CPS 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC PS1 CPS 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA PS1 CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA PS1 CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA PS1 CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA PS1 CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA SIG CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA SIG CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA SIG CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA SIG CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1185993 O0 000 O0 0 4 i 1 4 68 0000000000 SBFA FIL CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF PSl CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC PS1 CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC PS1 CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PS1 CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF SIG CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM SIG CU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT SIG 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 GR PS1 GAPI 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 RDIX PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 CRNI PS1 IfHZ 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 CRFI PS1 KHZ 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 CTM PS1 DEGC 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 XTM PS1 DEGC 1185993 O0 000 O0 0 4 I 1 4 68 0000000000 TAV PS1 1185993 O0 000 O0 0 4 ~ 1 4 68 0000000000 FICU PS1 AMP 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 CACU PS1 AMP 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 BUST PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 BUSP PSi 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 RSXS PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PS1 PU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI SIG PU 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 CCLC PS1 V 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 RSCS PS1 1185993 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: 16 DEPT. 10070.000 CS.PS1 NPDE. PS1 1459.313 NSCE. PS1 AQTM. PS1 1.102 CHV. PS1 CM2V. PS1 -12.191 RCFR.PS1 RCAK. PS1 2.000 RTDF. PSI FSCE. PS1 1.643 FSCR.PS1 HVPV. PS1 163.644 BMCU. PS1 NBEF. PS1 21.392 FBEF. PS1 BSTR.PS1 50.679 BSPR.PS1 XPSV. PS1 5.071 XP2V. PS1 RXLC. PS1 0.000 RXRC. PS1 BSAL.PS1 16.309 BSAL.SIG CIRN. FIL 1.071 CIRF. FIL IRAT. PS1 0.522 IRAT.FIL SFFA.PS1 22.723 SBNA.PS1 SFFA.SIG 0.349 SBNA.SIG SFFA.FIL 22.689 SBNA.FIL SFNC. PS1 20.509 SFFC. PS1 SIGM. SIG 0.310 TRAT. PS1 GR.PS1 80.752 RDIX. PS1 CTM. PS1 99.609 XTM. PS1 CACU. PS1 2.428 BUST. PSI TPHI.PS1 25.247 TPHI.SIG DEPT. NPDE. PS1 AQTM. PS1 CM2V. PS1 RCAK. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR. PS1 XPSV. PS1 RXLC. PSt BSAL.PSt CIRN. FIL IRAT. PS1 SFFA.PS1 SFFA.SIG SFFA.FIL SFNC. PS1 SIGM. SIG GR.PS1 CTM. PS1 CACU. PS1 T£HI.PS1 9820 000 1460 916 1 102 -12 182 0 000 1 879 163 463 15 448 68 619 5 074 0.000 82. 998 0.704 0.396 26.727 0.768 26.454 25. 057 0.586 54.248 100.586 2.414 31.093 CS.PS1 NSCE. PSI CHV. PS1 RCFR.PS1 RTDF. PS1 FSCR.PS1 BMCU. PS1 FBEF. PS1 BSPR.PS1 XP2V. PS1 RXRC.PS1 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS1 SBNA.SIG SBNA.FIL SFFC.PS1 TR~ T. PS1 RDIX. PS1 XTM. PSi BUST. PS1 TPHI.SIG 2390. 2. 203. O. O. 0 85 39 1 12 0 6. 2 0 47 3 49 20 0 9309 98 3 0 2466. 2 203 0 0 -0 79 41 1 12 0 3 1 0 70 5 62 23 0 14854 98 3 1 731 TENS.PSi 677 CRRA.PS1 156 CP5V. PS1 000 RCLC. PS1 000 FPHV. PS1 009 AQTF. PS1 525 GDCU. PS1 942 NPGF. PS1 143 MARC. PSi 083 3~42V. PS1 000 RXAK. PS1 322 CIRN. PS1 081 DSIG.PS1 524 NBAC. PS1 802 SBFA.PS1 145 SBFA.SIG 610 SBFA.FIL 234 SIGM. PS1 988 TRAT. SIG 000 CRNI.PS1 598 TAV. PS1 000 BUSP. PS1 807 CCLC. PS1 393 TENS.PS1 692 CRRA.PS1 519 CP5V. PS1 000 RCLC. PS1 000 FPHV. PS1 291 AQTF. PS1 234 GDCU. PS1 289 NPGF. PS1 104 MARC. PSi 085 XI~2V. PS1 000 RXAK. PS1 250 CIRN. PS1 779 DSIG. PS1 394 NBAC. PS1 051 SBFA. PS1 196 SBFA.SIG 928 SBFA.FIL 491 SIGM. PS1 984 TRAT. SIG 000 CRNI. PS1 233 TAV. PS1 000 BUSP. PS1 077 CCLC. PS1 1368 000 1 867 5 079 0 000 1413 575 1 322 59 801 0.998 0.000 -12.356 1.000 1.079 0.894 3605.828 40.728 3.462 37.223 20.284 0.015 430.976 95.021 3.000 0.001 1276.000 2.673 5.084 0.000 1413.575 0.661 59.654 1.00i 0.000 -12.377 0.000 0.696 1.803 2516.578 45.318 5.564 45.830 23.483 0.025 458.813 94.979 3.000 0.037 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P.PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC.PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 FICU. PS1 RSXS.PS1 RSCS. PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRA T. FIL CRFI. PS1 FI CU. PS1 RSXS. PS1 RSCS.PSI 1485.597 -0. 062 12. 056 0.000 1383. 897 176.390 64. 702 1.000 201. 062 0.000 41. 695 2.090 4224. 814 25.235 O. 442 24. 347 27. 781 2.203 O. 990 230. 820 2.211 8878. 000 8463. 000 1485. 597 -0.517 12. 092 0.000 1386.415 1 77. 055 66. 782 O. 994 200.986 0.000 46. 503 1. 736 3388. 875 30.534 1. 059 29. 512 51.986 1. 226 O. 992 1 71. 666 2.184 8878. 000 84 63. 000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: 17 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/22 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: 2 DEPTH INCREMENT: 0.5000 FILE SUlV~IARY VENDOR TOOL CODE START DEPTH RST $ LOG HEADER DATA DATE LOGGED: 10087.0 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9779.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMFiA RAY RST RESERVOIR SATURATION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 24 -JUL- 98 8Cl -205 10440.0 10074.0 9830.0 10060.0 TOOL NUMBER ........... CGRS-A RST- S 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: 18 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 10440.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE/BORAX NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: LOG TIED INTO SLB TND DATED 3 APR 1997 TWO CRUDE PASSES WERE LOGGED WITH 337 BBL AWAY AT 5 BBL/MIN. CRUDE PASSES LOGGED WITH 1 BBL/MIN PUMPING THREE BORAX PASSES WERE LOGGED WITH 80 BBL AWAY AT 5 BBL/MIN. BORAX PASSES LOGGED WITH 1 BBL/MIN PUMPING FIRST BORAX PASS HAD 170 BBL CRUDE AWAY @520 PSI FIRST PASS HAD 25 BBLS BORAX BEHIND PIPE SECOND BORAX PASS HAD 181 BBL CRUDE AWAY ® 500 PSI THIRD BORAX PASS HAD 191 BBL CRUDE AWAY @ 475 PSI BEFORE PUMPING WHP 1400 PSI IA 900 PSI/OA 400 PSI TADDED TD AT 10074' THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FOR2W3~T DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: 19 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS2 F/HR 1185993 O0 000 O0 0 5 1 I 4 68 0000000000 TENS PS2 LB 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 NPHVPS2 V 1185993 O0 000 O0 0 5 1 I 4 68 0000000000 NPDE PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS2 S 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CPSV PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS2 1185993 O0 000 O0 0 5 1 ! 4 68 0000000000 RCAK PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 FPHVPS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 FPDE PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 FSCR PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS2 S 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SF6P PS2 PSIG 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 HVPV PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 BMCU PS2 UA 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: 20 NAME SERV UNIT SERVICE API API API API FILE AU3M~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) GDCU PS2 MA 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 EXCU PS2 UA 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 NBEF PS2 UA 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF PS2 UA 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 FPGF PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 - BSTR PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 MARC PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 XHV PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 XPSV PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 X~2V PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 RXFR PS2 1185993 O0 000 .00 0 5 1 1 4 68 0000000000 RXLC PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 RXRC PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 RXAKPS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SHCU PS2 MA 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL PS2 PPK 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL SIG PPK 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CIRlVPS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 1185993 O0 000 O0 0 5 i 1 4 68 0000000000 CIRF FIL 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG PS2 CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS2 CPS 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC PS2 CPS 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA PS2 CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA PS2 CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA PS2 CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA PS2 CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA SIG CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA SIG CU 1185993 O0 000 O0 0 5 1 I 4 68 0000000000 SBNA SIG CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA SIG CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 1185993 O0 000 O0 0 5 1 ! 4 68 0000000000 SIBF PS2 CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC PS2 CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC PS2 CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS2 CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF SIG CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM SIG CU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT SIG 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT FIL 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS2 GAPI 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: 21 NA~E SERVUNIT SERVICE API API API API FILE NUMB NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUTIB SAMP ELE~ CODE (HEX) ....................................................................................... RDIX PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PS2 KHZ 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CRFI PS2 KHZ 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CTM PS2 DEGC 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 XTM PS2 DEGC 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 TAV PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS2 AMP 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CACU PS2 AMP 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 BUST PS2 1185993 O0 000 O0 0 5 1 i 4 68 0000000000 BUSP PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 RSXS PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS2 PU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI SIG PU 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 CCLC PS2 V 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 RSCS PS2 1185993 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS2 AQTM. PS2 CM2V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 BSTR.PS2 XPSV. PS2 RXLC. PS2 BSAL.PS2 CIRN. FIL IRAT. PS2 SFFA.PS2 SFFA.SIG SFFA.FIL SFNC. PS2 SIGM. SIG GR.PS2 CTM. PS2 CACU. PS2 TPHI.PS2 10070.000 1462.213 1.102 -12.182 0.000 1 728 162 565 18 262 47 041 5 076 0 000 13 313 1 097 0 515 23.194 0.507 22.773 20.596 0.310 154.774 100.098 2.438 28.243 CS.PS2 1823.490 TENS.PS2 1330.000 NPHV. PS2 NSCE.PS2 2.697 CRRA.PS2 1.885 NSCR.PS2 CHV. PS2 203.883 CPSV. PS2 5.074 CP2V. PS2 RCFR.PS2 0.000 RCLC. PS2 0.000 RCRC. PS2 RTDF. PS2 0.000 FPHV. PS2 1423.341 FPDE. PS2 FSCR.PS2 -0.346 AQTF. PS2 0.661 SF6P. PS2 BMCU. PS2 59.667 GDCU. PS2 59.706 EXCU. PS2 FBEF. PS2 34.426 NPGF. PS2 0.995 FPGF. PS2 BSPR.PS2 1.008 MARC. PS2 0.000 XHV. PS2 XP2V. PS2 12.080 X~I2V. PS2 -12.361 RXFR.PS2 RXRC.PS2 0.000 RXAK. PS2 0.000 SHCU. PS2 BSAL.SIG 4.889 CIRN. PS2 1.103 CIRF. PS2 CIRF. FIL 2.064 DSIG.PS2 0.433 FBAC. PS2 IRAT. FIL 0.513 NBAC. PS2 3265.493 SFNA. PS2 SBNA.PS2 46.245 SBFA.PS2 37.929 SFNA. SIG SBNA.SIG 3.092 SBFA.SIG 5.022 SFNA.FIL SBNA.FIL 50.121 SBFA.FIL 36.303 SIBF. PS2 SFFC. PS2 20.346 SIGM. PS2 20.342 SIBF. SIG TRAT. PS2 1.030 TRAT. SIG 0.016 TRAT. FIL RDIX. PS2 17925.000 CRNI.PS2 433.501 CRFI.PS2 XTM. PS2 98.438 TAV. PS2 94.936 FICU. PS2 BUST.PS2 3.000 BUSP. PS2 3.000 RSXS. PS2 TPHI.SIG 0.795 CCLC. PS2 0.001 RSCS.PS2 1491.700 -0.279 12.121 0.000 1387.139 177.280 42.845 1.006 201.064 0.000 54.286 2.074 3944.924 24.200 0.419 24.028 26.739 1.697 1.033 229. 961 2.152 8878. 000 8463.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-FEB-1999 14:14 PAGE: 22 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/02/22 ORIGIN : FLIC TAPE NAME : 99078 CONTINUATION # : 1 PREVIOUS TAPE : COM~fENT : ARCO ALASKA, DS 14-23, PRUDHOE BAY, API # 50-029-20757-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/02/22 ORIGIN : FLIC REEL NAME : 99078 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA,DS 14-23, PRUDHOE BAY, API# 50-029-20757-00 * ALASKA COMPUTING CENTER * , , ****************************** . ............................ * ....... SCHLUMBERGER ....... . , ............................ . ****************************** RECEiV u MAY ,~0 Alaska Oil & Ga~ ~,~s. Corr~mi~$ior~ Anchorage COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D. S. 14-23 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292075700 REFERENCE NO : 97232 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 **** REEL HEADER **** SERVICE NAM~ : EDIT DATE : 97/05/28 ORIGIN : FLIC REEL NAM~ : 97232 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, D.S. 14-23, PRUDHOE BAY, 50-029-20757-00 PAGE: **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/05/28 ORIGIN : FLIC TAPE NAME : 97232 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, D.S. 14-23, PRUDHOE BAY, 50-029-20757-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: D.S.14-23 API NUMBER: 500292075700 OPERATOR: ARCO Alaska, Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 28-MAY-97 JOB NUMBER: 97232 LOGGING ENGINEER: R.Walsh OPERATOR WITNESS: D. Cismoski SURFACE LOCATION SECTION: 9 TOWNSHIP: ION RANGE: 14E FNL: 1401 FSL: FEL: 2017 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 72.00 DERRICK FLOOR: 71.00 GROUND LEVEL: 42.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) .............................................. IST STRING 9.62'5 9782.0 47.00 2ND STRING 8.500 7.000 10440.0 29.00 3RD STRING 5.500 9524.0 17.00 PRODUCTION STRING 3. 500 10029. 0 9.30 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. 88888.0 10046.0 10028.5 10026.0 10010.5 10009.0 10000.5 9987.0 9986.5 9979.0 9977.0 9975.0 9973.0 9956.5 9956.0 9952.0 9949.0 9936.5 9923.5 9913.0 9900.5 9900.0 9880.5 9880.0 9873.0 9872.5 9867.0 9857.5 9855.5 9851.0 100.0 $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. 88889.0 88889.0 10047.0 10047.0 10029.0 10029.0 10026.5 10026.5 10011.0 10011.0 10001.5 10001.5 9987.5 9987.5 9980.5 9980.5 9978.0 9978.0 9975.5 9975.5 9973.0 9973.0 9956.5 9956.5 9953.5 9953.5 9951.5 9951.5 9938.5 9938.5 9924.5 9924.5 9913.5 9913.5 9901.5 9901.5 9881.5 9881.5 9873.5 9873.5 9867.5 9867.5 9858.0 9858.0 9856.0 9856.0 9852.0 9852.0 101.0 101.0 REMARKS: CONTAINED HEREIN IS THE TDTP DATA ACQUIRED ON ARCO ALASKA INC. WELL D.S. 14-23. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #1 GRCH TO GR.BCS; AND PASS #1 SIGM TO GR.BCS. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 28-MAY-1997 09:12 PAGE: FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: I DEPTH INCREM~: 0.5000 FILE SUF~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10055.0 9848.0 TDTP 10057.0 9848.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. REMARKS: THIS FILE CONTAINS TDTP PASS #1. THERE WERE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 PAGE: TYPE REPR CODE VALUE .............................. 5 66 6 73 7 65 8 68 O.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 .............................. ** SET TYPE - CHAN ** ....................................................................................... 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 100725 O0 000 O0 0 1 1 1 4 68 SIGM TDTP CU 100725 O0 000 O0 0 I 1 1 4 68 TPHI TDTP PU-S 100725 O0 000 O0 0 1 1 1 4 68 SBHF TDTP CU 100725 O0 000 O0 0 1 1 1 4 68 SBHN TDTP CU 100725 O0 000 O0 0 1 1 1 4 68 SIGC TDTP CU 100725 O0 000 O0 0 1 1 1 4 68 SIBH TDTP CU 100725 O0 000 O0 0 1 1 1 4 68 TRAT TDTP 100725 O0 000 O0 0 1 1 1 4 68 SDSI TDTP CU 100725 O0 000 O0 0 1 1 I 4 68 BACK TDTP CPS 100725 O0 000 O0 0 1 1 1 4 68 FBAC TDTP CPS 100725 O0 000 O0 0 1 1 1 4 68 TCAN TDTP CPS 100725 O0 000 O0 0 1 1 1 4 68 TCAF TDTP CPS 100725 O0 000 O0 0 1 1 1 4 68 TCND TDTP CPS 100725 O0 000 O0 0 1 1 1 4 68 TCFD TDTP CPS 100725 O0 000 O0 0 1 1 1 4 68 TSCN TDTP CPS 100725 O0 000 O0 0 1 1 1 4 68 TSCF TDTP CPS 100725 O0 000 O0 0 1 1 1 4 68 INND TDTP CPS 100725 O0 000 O0 0 1 1 1 4 68 INFD TDTP CPS 100725 O0 000 O0 0 1 1 1 4 68 GRCH TDTP GAPI 100725 O0 000 O0 0 1 i 1 4 68 TENS TDTP LB 100725 O0 000 O0 0 1 1 1 4 68 CCL TDTP V 100725 O0 000 O0 0 1 1 1 4 68 GR BCS GAPI 100725 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 10415.000 SIGM. TDTP SBHN. TDTP -999.250 SIGC. TDTP SDSI.TDTP -999.250 BACK. TDTP TCAF. TDTP -999.250 TCND. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 TPHI. TDTP -999.250 SIBH. TDTP -999.250 FBAC. TDTP -999.250 TCFD. TDTP -999.250 INFD. TDTP -999. 250 SBHF. TDTP -999. 250 TRAT. TDTP -999. 250 TCAN. TDTP -999. 250 TSCN. TDTP -999. 250 GRCH. TDTP -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 TENS. TDTP -999.250 CCL. TDTP -999.250 GR.BCS DEPT. 9800.000 SIGM. TDTP -999.250 TPHI. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP TENS.TDTP -999.250 CCL. TDTP -999.250 GR.BCS 26.000 -999.250 SBHF. TDTP -999.250 TRAT. TDTP -999.250 TCAN. TDTP -999.250 TSCN. TDTP -999.250 GRCH. TDTP 38.700 PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10055.0 9844.0 TDTP 10057.0 9844.0 $ 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 28-MAY-1997 09:12 BASELINE DEPTH .............. 88888.0 10046.0 10033.5 10028.5 10028.0 10025.5 10024.5 10023.0 10015.0 10012.0 10009.5 1O0O8.0 10002.0 9998.5 9998.0 9995.5 9994.0 9988.0 9986.0 9979.5 9977.5 9976.5 9974.5 9973.5 9969.0 9962.5 9960.5 9958.0 9955.0 9954.0 9952.0 9948.5 9937.5 9935.0 9932.5 9926.5 9926.0 9922.5 9918.0 9911.5 9909.0 9902.5 9900.0 9899.5 9896.0 9893.5 9883.0 9879.0 9872.0 9870.0 9869.0 9866.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88889.0 88889.0 10047.0 10034.5 10030.0 10029.5 10026.5 10026.0 10025.5 10024.5 10017.0 10014.0 10010.5 10011.0 10003.5 10000.0 10000.0 9995.5 9994.5 9990.0 9987.5 9980.5 9979.5 9978.0 9975.5 9974.5 9969.5 9963.0 9962.5 9960.5 9956.0 9956.5 9954.0 9952.0 9939.0 9938.0 9935.0 9928.5 9928.0 9924.5 9920.0 9912.5 9910.5 9905.5 9901.5 9901.5 9898.0 9895.0 9885.0 9881.0 9881.0 9873.0 9871.5 9870.5 9867.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 9866.0 9864.0 9857.0 9855.0 100.0 $ 9858.0 9856.0 101.0 9867.0 9864.5 100.5 REMARKS: THIS FILE CONTAINS TDTP PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH; AND PASS #2 SIGM TO PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 .14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 100725 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 100725 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 100725 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 100725 O0 000 O0 0 2 1 1 4 68 0000000000 SBHNTDTP CU 100725 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 100725 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 100725 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 100725 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 PAGE: NA~E SERV UNIT SERVICE API API API API FILE NUF~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) ....................................................................................... SDSI TDTP CU 100725 O0 000 O0 0 2 1 1 4 68 BACK TDTP CPS 100725 O0 000 O0 0 2 1 1 4 68 FBAC TDTP CPS 100725 O0 000 O0 0 2 1 1 4 68 TCANTDTP CPS 100725 O0 000 O0 0 2 1 1 4 68 TCAF TDTP CPS 100725 O0 000 O0 0 2 1 1 4 68 TCND TDTP CPS 100725 O0 000 O0 0 2 1 1 4 68 TCFD TDTP CPS 100725 O0 000 O0 0 2 1 1 4 68 TSCN TDTP CPS 100725 O0 000 O0 0 2 1 1 4 68 TSCF TDTP CPS 100725 O0 000 O0 0 2 1 1 4 68 INND TDTP CPS 100725 O0 000 O0 0 2 1 I 4 68 INFD TDTP CPS 100725 O0 000 O0 0 2 1 1 4 68 GRCH TDTP GAPI 100725 O0 000 O0 0 2 1 1 4 68 TENS TDTP LB 100725 O0 000 O0 0 2 1 1 4 68 CCL TDTP V 100725 O0 000 O0 0 2 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 10058. 000 SIGM. TDTP 15. 659 TPHI. TDTP 44.272 SBHF. TDTP SBHN. TDTP 44. 494 SIGC. TDTP O. 343 SIBH. TDTP 47.125 TRAT. TDTP SDSI. TDTP O. 206 BACK. TDTP 163. 307 FBAC. TDTP 33. 258 TCAN. TDTP TCAF. TDTP 12939. 660 TCND. TDTP 26621 . 398 TCFD. TDTP 7046.158 TSCN. TDTP TSCF. TDTP 2748. 959 INND. TDTP 2136.244 INFD. TDTP 314. O17 GRCH. TDTP TENS. TDTP 1640. 000 CCL. TDTP O. 000 DEPT. 9844.500 SIGM. TDTP 13.250 TPHI. TDTP 27.105 SBHF. TDTP SBHN. TDTP 55.150 SIGC. TDTP O. 000 SIBH. TDTP 68. 077 TRAT. TDTP SDSI. TDTP 0.168 BACK. TDTP 166.574 FBAC. TDTP 31.735 TCAN. TDTP TCAF. TDTP 13616. 773 TCND. TDTP 24417. 859 TCFD. TDTP 6908. 922 TSCN. TDTP TSCF. TDTP 2895. 834 INND. TDTP 2335.317 INFD. TDTP 257. 539 GRCH. TDTP TENS. TDTP 1670. 000 CCL. TDTP O. 000 35.781 2.273 38619.320 8204.459 -999.250 42.395 1.889 32882.695 6993.054 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 28-MAY-1997 09:12 PAGE: FILE HEADER FILE NUM~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMM~ARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10055.0 9842.0 TDTP 10057.0 9842.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH 1005 ............................ 88888.0 88889.5 88889.5 10050.0 10051.5 10046.0 10047.0 10033.0 10034.5 10030.0 10031.5 10028.5 10029.5 10028.0 10028.5 10025.5 10026.5 10026.5 10023.5 10025.0 10024.5 10015.0 10017.0 10012.5 10014.5 10009.5 10010.5 10008.5 10011.0 9998.5 10000.0 9991.5 9993.0 9991.0 9991.5 9988.5 9990.0 9986.5 9987.5 9985.5 9987.0 9979.5 9980.0 9978.5 9980.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 9974.0 9974.5 9966.5 9966.5 9962.5 9963.0 9958.5 9959.0 9955.5 9956.5 9955.0 9956.0 9952.0 9954.0 9949.0 9951.5 9942.0 9944.5 9939.0 9940.5 9936.0 9938.0 9927.0 9928.0 9923.5 9924.5 9919.0 9920.0 9915.5 9915.5 9914.0 9915.0 9912.0 9912.5 9909.5 9910.5 9900.5 9901.5 9900.0 9901.5 9896.5 9897.5 9880.0 9881.0 9879.5 9881.0 9873.0 9873.5 9870.5 9871.5 9867.0 9867.5 9866.5 9867.0 9864.0 9864.5 9858.0 9859.0 9857.0 9858.0 9851.5 9852.0 9850.0 9851.5 t00.0 100.5 101.5 $ REMARKS: THIS FILE CONTAINS TDTP PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #3 GRCH TO PASS #1 GRCH; AND PASS #3 SIGM TO PASS #1SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 PAGE: TYPE REPR CODE VALUE .............................. 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) O0 000 O0 0 3 1 1 4 68 0000000000 DEPT FT 100725 SIGM TDTP CU 100725 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 100725 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 100725 O0 000 O0 0 3 1 1 4 68 0000000000 SBHNTDTP CU 100725 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 100725 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 100725 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 100725 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 100725 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 100725 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 100725 O0 000 O0 0 3 1 1 4 68 0000000000 TCANTDTP CPS 100725 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 100725 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 100725 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 100725 O0 000 O0 0 3 1 1 4 68 0000000000 TSCNTDTP CPS 100725 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 100725 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 100725 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 100725 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 100725 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 100725 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 100725 O0 000 O0 0 3 1 1 4 68 0000000000 11 ** DATA ** DEPT. 10058.500 SIGM. TDTP 16.192 TPHI. TDTP 43.805 SBHF. TDTP 32.899 SBHN. TDTP 44. 631 SIGC. TDTP O. 341 SIBH. TDTP 47. 437 TRAT. TDTP 2. 242 SDSI. TDTP O. 215 BACK. TDTP 180.162 FBAC. TDTP 42. 547 TCAN. TDTP 3 9803 . 836 TCAF. TDTP 13375. 633 TCND. TDTP 26146. 457 TCFD. TDTP 6945. 901 TSCN. TDTP 7974 . 035 TSCF. TDTP 2679.585 INND. TDTP 2074.449 INFD. TDTP 306.833 GRCH. TDTP -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center TENS. TDTP 1650. 000 CCL. TDTP 28-MAY-1997 09:12 0.000 PAGE: DEPT. 9842.500 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 88.688 TENS.TDTP -999.250 CCL. TDTP -999.250 12 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3, TDTP $ REMARKS: THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... 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 100725 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 100725 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 100725 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 100725 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNPNAV CU 100725 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 100725 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 100725 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 100725 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 100725 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP cPS 100725 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 100725 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 100725 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF PNAV CPS 100725 O0 000 O0 0 4 1 1 4 68 0000000000 TCNDPNAV CPS 100725 O0 000 O0 0 4 1 1 4 68 0000000000 TCFDPNAV CPS 100725 O0 000 O0 0 4 1 1 4 68 0000000000 TSCNPNAV CPS 100725 O0 000 O0 0 4 I 1 4 68 0000000000 TSCF PNAV CPS 100725 O0 000 O0 0 4 1 1 4 68 0000000000 INND PNAV CPS 100725 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 100725 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 100725 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center ** DATA ** 28-MAY-1997 09:12 DEPT. 10058.000 SIGM. PNAV 15.178 TPHI.PNAV SBHN. PNAV 44. 039 SIGC. PNAV 0. 649 SIBH. PNAV SDSI. PNAV 0 . 260 BACK. TDTP 135. 832 FBAC. TDTP TCAF. PNAV 13045.432 TCND.PNAV 26498.430 TCFD.PNAV TSCF. PNAV 2694.814 INND. PNAV 2144.892 INFD.pNAv 43. 752 SBHF. PNAV 46.100 TRAT. PNAV 25. 983 TCAN. PNAV 6993 . 208 TSCN. PNAV 313. 528 GRCH. TDTP PAGE: 14 35.261 2.268 38976.797 8051.104 -999.250 DEPT. 9849.000 SIGM. PNAV 13.061 TPHI.PNAV 22.774 SBHF. PNAV 43.465 SBHN. PNAV 58.367 SIGC. PNAV 0.000 SIBH. PNAV 73.189 TRAT. PNAV 1.746 SDSI.PNAV 0.174 BACK. TDTP 144.366 FBAC. TDTP 25.396 TCAN. PNAV 32177.094 TCAF. PNAV 14671.445 TCND. PNAV 23077.582 TCFD.PNAV 7047.701 TSCN. PNAV 6635.765 TSCF. PNAV 3028.400 INND.PNAV 2320.753 INFD.PNAV 258.528 GRCH. TDTP 40.625 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCRE~IENT : O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... TDTP 10084.5 9846.0 $ LOG HEADER DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 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): 3-APR-97 CP 44.2 1030 3-APR-97 10062.0 10076.0 9850.0 10069.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY $ TOOL NUFIBER ........... TNC-P 141 TND-P 78 TNG-P 21 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 10440.0 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) : 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 WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Tied into SWS CBL dated il-JUN-1983 file 3. Ran log to determine GOC depth and to evaluate possible resaturation and under-run. PAGE: 15 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 PAGE: 16 Possible GOC at 9064' Represents 46' of possible resaturation from previous GOC of 10010' (logging 4-7-93) Possible underrun indicated from 10028' to 10042' Inelastic counts support conclusion while porosity does not. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** 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 100725 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 100725 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 100725 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PS1 CU 100725 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNPS1 CU 100725 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PS1 CU 100725 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PS1 CU 100725 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 100725 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PS1 CU 100725 O0 000 O0 0 5 1 1 4 68 0000000000 BACK PS1 CPS 100725 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 100725 O0 000 O0 0 5 1 1 4 68 0000000000 TCANPS1 CPS 100725 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF PS1 CPS 100725 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUM~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CI.d~S MOD NU3tB SAMP EL~Vl CODE (I-IE~) TCND PS1 CPS 100725 O0 000 O0 0 5 1 1 4 68 TCFD PS1 CPS 100725 O0 000 O0 0 5 1 1 4 68 TSCNPS1 CPS 100725 O0 000 O0 0 5 1 1 4 68 TSCF PS1 CPS 100725 O0 000 O0 0 5 1 1 4 68 INND PS1 CPS 100725 O0 000 O0 0 5 1 1 4 68 INFDPS1 CPS 100725 O0 000 O0 0 5 1 1 4 68 TENS PS1 LB 100725 O0 000 O0 0 5 1 1 4 68 GR PS1 GAPI 100725 O0 000 O0 0 5 1 1 4 68 CCL PS1 V 100725 O0 000 O0 0 5 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 17 ** DATA ** DEPT. 10084.500 SIGM. PS1 12.892 TPHI.PS1 39.665 SBHF. PS1 SBHN. PS1 44.911 SIGC. PS1 1.521 SIBH. PS1 48.073 TRAT. PS1 SDSI.PS1 0.326 BACK. PSI 175.719 FBAC.PS1 44.134 TCAN. PSl TCAF. PS1 16696.207 TCND. PS1 27219.953 TCFD.PS1 7460.796 TSCN. PS1 TSCF. PS1 3015.231 INND. PS1 2232.974 INFD.PS1 376.305 TENS.PSI GR.PS1 77.000 CCL. PS1 0.000 DEPT. 9846.000 SIGM. PS1 12.410 TPHI.PS1 24.154 SBHF. PS1 SBHN. PS1 58.572 SIGC. PS1 0.000 SIBH. PS1 74.685 TRAT. PS1 SDSI.PS1 0.153 BACK. PSi 144.853 FBAC. PS1 26.332 TCAN. PS1 TCAF. PS1 15695.814 TCND.PS1 24339.480 TCFD.PS1 7266.808 TSCN. PS1 TSCF. PS1 3226.362 INND. PS1 2376.467 INFD. PS1 251.360 TENS.PSI GR.PS1 27.656 CCL.PS1 0.000 37.529 2.208 47299.859 8542.059 1115.000 45.716 1. 820 35509. 719 7299. 221 1640. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER **** FILE NAFIE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 28-MAY-1997 09:12 PAGE: 18 FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 10119.0 9840.5 TDTP $ 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 ......................... TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : 3 -APR- 97 CP 44.2 1030 3-APR-97 10062.0 10076.0 9850.0 10069.0 1800.0 NO TOOL NUMBER TNC-P 141 TND-P 78 TNG-P 21 10440.0 Produced Fluids LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 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): 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): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REg~RKS: Tied into SWS CBL dated Il-JUN-1983 file 3. Ran log to determine GOC depth and to evaluate possible resaturation and under-run. Possible GOC at 9064' Represents 46' of possible resaturation from previous GOC of 10010' (logging 4-7-93) Possible underrun indicated from 10028' to 10042' Inelastic counts support conclusion while porosity does not. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #2. $ LIS FORMAT DATA PAGE: 19 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 PAGE: TYPE REPR CODE VALUE .............................. 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) O0 000 O0 0 . 6 1 1 4 68 0000000000 DEPT FT 100725 SIGM PS2 CU 100725 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 100725 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 100725 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNPS2 CU 100725 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 100725 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 100725 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 100725 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 100725 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 100725 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 100725 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS2 CPS 100725 O0 000 O0 0 6 1 1 4 68 0000000000 TCAFPS2 CPS 100725 O0 000 O0 0 6 1 1 4 68 0000000000 TCNDPS2 CPS 100725 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PS2 CPS 100725 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS2 CPS 100725 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 100725 O0 000 O0 0 6 1 1 4 68 0000000000 INNDIPS2 CPS 100725 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS2 CPS 100725 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 100725 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 100725 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 100725 O0 000 O0 0 6 1 1 4 68 0000000000 2O ** DATA ** DEPT. 10119.000 SIGM. PS2 12.221 TPHI.PS2 39.166 SBHF. PS2 SBHN. PS2 60.212 SIGC. PS2 1.396 SIBH. PS2 79.981 TRAT. PS2 SDSI.PS2 0.299 BACK. PS2 206.789 FBAC. PS2 59.419 TCAN. PS2 TCAF. PS2 16838.590 TCND.PS2 26818.012 TCFD.PS2 7406.722 TSCN. PS2 TSCF. PS2 3010.725 INND.P$2 2214.030 INFD.PS2 306.812 TENS. PS2 GR.PS2 99.750 CCL.PS2 0.000 DEPT. 9840.500 SIGM. PS2 12.443 TPHI.PS2 21.941 SBHF. PS2 SBHN. PS2 57.962 SIGC. PS2 0.000 SIBH. PS2 73.227 TRAT. PS2 SDSI.PS2 0.179 BACK. PS2 169.488 FBAC. PS2 ~30.442 TCAN. PS2 TCAF. PS2 15413.330 TCND.PS2 24359.895 TCFD.PS2 7657.412 TSCN. PS2 TSCF. PS2 3276.189 INND. PS2 2299.468 INFD.PS2 270.722 TENS. PS2 47.722 2.128 46364.539 8289.938 1675.000 41.496 1.747 33725.570 7168.558 1705.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center GR.PS2 92.938 CCL.PS2 28-MAY-1997 09:12 0.000 PAGE: 21 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE · 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 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 SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 10083.0 9840.0 TDTP $ 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 3 -APR-97 CP 44.2 1030 3-APR-97 10062.0 10076.0 9850.0 10069.0 1800.0 NO TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY $ TNC-P 141 TND-P 78 TNG-P 21 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 10440.0 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) : 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 WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Tied into SWS CBL dated Il-JUN-1983 file 3. Ran log to determine GOC depth and to evaluate possible resaturation and under-run. Possible GOC at 9064' Represents 46' of possible resaturation from previous GOC of 10010' (logging 4-7-93) Possible underrun indicated from 10028' to 10042' Inelastic counts support conclusion while porosity does not. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #3. $ LIS FORMAT DATA PAGE: 22 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 09:12 PAGE: 23 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100725 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 100725 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 100725 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 100725 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPS3 CU 100725 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS3 CU 100725 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 100725 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 100725 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 100725 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 100725 O0 000 O0 0 7 1 i 4 68 0000000000 FBAC PS3 CPS 100725 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS3 CPS 100725 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PS3 CPS 100725 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PS3 CPS 100725 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PS3 CPS 100725 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS3 CPS 100725 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 100725 O0 000 O0 0 7 1 1 4 68 0000000000 INNDPS3 CPS 100725 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS3 CPS 100725 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 100725 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 100725 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 100725 O0 000 O0 0 7 1 1 4 68 000000000~ LIS Tape V~rification Listing Schlumberger Alaska Computing Center ** DATA ** DEPT. 10083.000 SIGM. PS3 SBHN. PS3 57.300 SIGC.PS3 SDSI. PS3 0.690 BACK. PS3 TCAF. PS3 17741.883 TCND.PS3 TSCF. PS3 3207.076 INND. PS3 GR.PS3 346.250 CCL.PS3 DEPT. 9840.000 SIGM. PS3 SBHN. PS3 56.306 SIGC. PS3 SDSI.PS3 0.205 BACK. PS3 TCAF. PS3 14616.965 TCND. PS3 TSCF. PS3 2944.506 INND.PS3 GR.PS3 138.750 CCL.PS3 28-MAY-1997 09:12 18.283 TPHI.PS3 1.709 SIBH. PS3 238.485 FBAC.PS3 26403.957 TCFD.PS3 2185.100 INFD.PS3 0.000 14.667 TPHI.PS3 0.000 8IBH.PS3 181.944 FBAC. PS3 23693.641 TCFD.PS3 2324.586 INFD.PS3 0.000 43.798 76.177 119.153 7651.130 350.037 22.724 69.283 37.303 7277.104 257.541 SBHF. PS3 TRAT. PS3 TCAN . PS3 TSCN. PS3 TENS. PS3 SBHF. PS3 TRAT. PS3 TCAN. PS3 TSCN. PS3 TENS.PS3 PAGE: 24 42.388 1.993 45301.609 8188.855 1070.000 41.704 1.716 32130.051 6472.420 1700.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/2~ FiAXREC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/05/28 ORIGIN : FLIC TAPE NAME : 97232 CONTINUATION # : 1 PREVIOUS TAPE : COm~_lFf : ARCO ALASKA INC, D.S. 14-23, PRUDHOE BAY, 50-029-20757-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/05/28 ORIGIN : FLIC REEL NAME ~: 97232 CONTINUATION # : PREVIOUS REEL COI~ENT : ARCO ALASKA INC, D.S,. 14-23, PRUDHOE'~, ~0-029-20757-00 HA L L/BUR TON L O~GIIVG S~R VlC~S,/NC. Halliburton Company LIS TAPE VERIFICATION LISTING LDWG FORMAT Page i REEL HEADER RECORD TYPE 132 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER PREVIOUS REEL NAME COMMENTS: --- COMCEN --- 93/03/27 --- ANCH --- 739618 ****************************************************************************** TAPE HEADER RECORD TYPE 130 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER PREVIOUS TAPE NAME COMMENTS: --- COMCEN --- 93/03/27 --- ANCH ------ 0 ****************************************************************************** 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 DS 14-23 500292075700 ARCO ALASKA INC. HALLIBURTON LOGGING SERVICES 27-MAR-93 L73961-8 KILLINSWORTH K. MORRIS 09 10N 14E 1404 2017 72.00 71.00 42.00 CASING DRILLER'S CASING Page 2 BIT SIZE(IN) SIZE(IN) DEPTH(FT) WEIGHT (LB/FT) lST STRING 13.375 2508.0 72.00 2ND STRING 12.250 9.625 9782.0 47.00 3RD STRING 8.500 7.000 10440.0 29.00 PRODUCTION STRING 8.500 5.500 9434.0 17.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: BCS PBU CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH TMD EQUIVALENT UNSHIFTED DEPTH 9799.5 9839.5 9900.0 9955.5 10010.0 10062.0 10133.0 10185.0 10245.5 $ REMARKS: 9800.0 9840.0 9900.5 9956.0 10010.5 10062.5 10133.5 10185.5 10246.0 TIED INTO BHCS LOG DATED 23-JUN-83. TUBING/CASING VOLUME TO TOP PERFORATIONS: 238.32 BBLS. $ ****************************************************************************** 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 --t~ 0 --- 93/03/27 --- 1024 --- LO ****************************************************************************** COMMENT RECORD TYPE 232 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 Page 3 PBU TOOL CODE START DEPTH STOP DEPTH TMD 10244.5 9799.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH TMD $ 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 i 66 0 3 2 79 68 4 1 66 1 5 1 66 1 8 4 73 60 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 DEPT F SGFN TMD 739618 CU SGFF TMD 739618 CU SGBH TMD 739618 CU NSBF TMD 739618 CPS FSBF TMD 739618 CPS NTMD TMD 739618 CPS FTMD TMD 739618 CPS RTMD TMD 739618 CRNF TMD 739618 PHIT TMD 739618 PU SGFM TMD 739618 CU SIGQ TMD 739618 RSBF TMD 739618 SGIN TMD 739618 CU API CODE FILES 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 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 #SAMP REPR. 1 68 1 68 i 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 I 68 1 68 1 68 i 68 Page 4 SIGC TMD 739618 00000000 0 4 1 68 GRCH TMD 739618 GAPI 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 10244.500 SGFN = 18.673 SGFF = 16.311 SGBH = 69.620 NSBF = 101.606 FSBF = 16.588 NTMD = 16388.840 FTMD = 2910.282 RTMD = 5.631 CRNF = 6.065 PHIT = 31.160 SGFM = 15.213 SIGQ = .986 RSBF = .808 SGIN = 13.237 SIGC = 1.149 GRCH = -1.000 DEPT = 10044.500 SGFN = 20.064 SGFF = 16.495 SGBH = 65.733 NSBF = 96.387 FSBF = 9.859 NTMD = 15011.310 FTMD = 2697.649 RTMD = 5.565 CRNF = 5.940 PHIT = 29.307 SGFM = 16.675 SIGQ = .980 RSBF = .898 SGIN = 14.916 SIGC = 1.118 GRCH = 47.896 DEPT = 9844.500 SGFN = 21.768 SGFF = 17.155 SGBH = 70.137 NSBF = 115.051 FSBF = 12.947 NTMD = 19824.570 FTMD = 3957.817 RTMD = 5.009 CRNF = 5.450 PHIT = 22.448 SGFM = 18.284 SIGQ = .988 RSBF = .506 SGIN = 16.764 SIGC = 1.091 GRCH = 77.016 ****************************************************************************** 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 --- 93/03/27 --- 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 --- 93/03/27 --- 1024 --- LO --- COMCEN.001 ****************************************************************************** COMMENT RECORD TYPE 232 Page 5 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 TMD 10245.5 9799.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH TMD THIS FILE CONTAINS EDITED DATA FOR PASS #2. NO PASS TO PASS DEPTH SHIFTS REQUIRED. $ 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 68 4 1 66 1 5 i 66 1 8 4 73 60 9 4 65 .lIN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 i 66 1 0 I 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F SGFN TMD 739618 CU SGFF TMD 739618 CU SGBH TMD 739618 CU NSBF TMD 739618 CPS FSBF TMD 739618 CPS API CODE FILES SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 #SAMP REPR. i 68 1 68 1 68 1 68 1 68 1 68 Page 6 NTHD THD 739618 CPS 00000000 0 4 i 68 FTMD TMD 739618 CPS 00000000 0 4 i 68 RTMD TMD 739618 00000000 0 4 1 68 CRNF TMD 739618 00000000 0 4 1 68 PHIT TMD 739618 PU 00000000 0 4 1 68 SGFM TMD 739618 CU 00000000 0 4 1 68 SIGQ TMD 739618 00000000 0 4 1 68 RSBF TMD 739618 00000000 0 4 i 68 SGIN TMD 739618 CU 00000000 0 4 1 68 SIGC TMD 739618 00000000 0 4 1 68 GRCH TMD 739618 GAPI 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 10245.500 SGFN = 18.626 SGFF = 16.109 SGBH = 71.918 NSBF = 115.810 FSBF = 17.805 NTMD = 16252.200 FTMD = 2892.195 RTMD = 5.619 CRNF = 6.086 PHIT = 31.474 SGFM = 15.163 SIGQ = .985 RSBF = .795 SGIN = 13.180 SIGC = · 1.150 GRCH = -1.000 DEPT = 10045.500 SGFN = 19.832 SGFF = 17.578 SGBH = 60.908 NSBF = 111.284 FSBF = 11.832 NTMD = 18426.610 FTMD = 3220.593 RTMD = 5.721 CRNF = 6.034 PHIT = 30.701 SGFM = 16.429 SIGQ = .981 RSBF = .533 SGIN = 14.634 SIGC = 1.123 GRCH = 45.088 DEPT = 9845.500 SGFN = 20.192 SGFF = 16.230 SGBH = 69.131 NSBF = 128.038 FSBF = 14.994 NTMD = 19920.400 FTMD = 4240.762 RTMD = 4.697 CRNF = 5.134 PHIT = 18.332 , SGFM = 16.438 ? SIGQ = .983 RSBF = .591 SGIN = 14.645 SIGC = 1.122 GRCH = 69.991 ****************************************************************************** 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 --- 93/03/27 --- 1024 --- LO --- COMCEN.003 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION --- COMCEN. 003 --- 93/03/27 Page 7 MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- 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 TMD 10245.5 9799.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH--- BASELINE DEPTH TMD THIS FILE CONTAINS EDITED DATA FOR PASS #3. NO PASS TO PASS DEPTH SHIFTS REQUIRED. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 I 66 0 3 2 79 68 4 1 66 1 5 1 66 8 4 73 60 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 i 66 1 0 i 66 0 Page 8 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 SGFN TMD 739618 CU 00000000 0 4 1 68 SGFF TMD 739618 CU 00000000 0 4 i 68 SGBH TMD 739618 CU 00000000 0 4 i 68 NSBF TMD 739618 CPS 00000000 0 4 i 68 FSBF TMD 739618 CPS 00000000 0 4 1 68 NTMD TMD 739618 CPS 00000000 0 4 1 68 FTMD TM/) 739618 CPS 00000000 0 4 1 68 RTMD TMD 739618 00000000 0 4 1 68 CRNF TMD 739618 00000000 0 4 i 68 PHIT TMD 739618 PU 00000000 0 4 i 68 SGFM TMD 739618 CU 00000000 0 4 1 68 SIGQ TMD 739618 00000000 0 4 i 68 RSBF TMD 739618 00000000 0 4 i 68 SGIN TMD 739618 CU 00000000 0 4 i 68 SIGC TMD 739618 00000000 0 4 1 68 GRCH TMD 739618 GAPI 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 10245.500 SGFN = 18.877 SGFF = 15.811 SGBH = 72.107 NSBF = 131.048 FSBF = 18.730 NTMD = 16226.960 FTMD = 2874.816 RTMD = 5.645 CRNF = 6.114 PHIT = 31.904 SGFM = 15.426 SIGQ = .986 RSBF = .732 SGIN = 13.483 SIGC = 1.144 GRCH = -1.000 DEPT = 10045.500 SGFN = 20.160 SGFF = 17.321 SGBH = 64.226 NSBF = 122.373 FSBF = 13.917 NTMD = 18684.250 FTMD = 3296.409 RTMD = 5.668 CRNF = 6.025 PHIT = 30.570 SGFM = 16.774 SIGQ = .981 RSBF = .554 SGIN = 15.031 SIGC = 1.116 GRCH = 50.805 DEPT = 9845.500 SGFN = 20.274 SGFF = 16.155 SGBH = 68.753 NSBF = 136.260 FSBF = 15.819 NTMD = 19359.100 FTMD = 4115.285 RTMD = 4.704 CRNF = 5.134 PHIT = 18.336 SGFM = 16.545 SIGQ = .989 RSBF = .581 SGIN = 14.767 SIGC = 1.120 GRCH = 77.653 ****************************************************************************** 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 --- 93/03/27 --- 1024 --- LO --- COMCEN.004 Page 9 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.004 --- 93/03/2? --- 1024 --- LO --- COMCEN.003 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 04 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 TMD 01,02,03 GRCH, NSBF AND FSBF ARE TAKEN FROM PASS #1 DATA. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 I 66 0 3 2 79 68 4 i 66 1 5 1 66 1 8 4 73 60 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 Page 10 DATUM SPECIFICATION BLOCKS= MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 SGFN PNAV 739618 CU 00000000 0 4 i 68 SGFF PNAV 739618 CU 00000000 0 4 i 68 SGBH PNAV 739618 CU 00000000 0 4 i 68 NSBF PNAV 739618 CPS 00000000 0 4 I 68 FSBF PNAV 739618 CPS 00000000 0 4 i 68 NTMD PNAV 739618 CPS 00000000 0 4 1 68 FTMD PNAV 739618 CPS 00000000 0 4 1 68 RTMD PNAV 739618 00000000 0 4 1 68 CRNF PNAV 739618 00000000 0 4 1 68 PHIT PNAV 739618 PU 00000000 0 4 1 68 SGFM PNAV 739618 CU 00000000 0 4 1 68 SIGQ PNAV 739618 00000000 0 4 1 68 RSBF PNAV 739618 00000000 0 4 1 68 SGIN PNAV 739618 CU 00000000 0 4 1 68 SIGC PNAV 739618 00000000 0 4 1 68 GRCH PNAV 739618 GAPI 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 10244.500 SGFN = 18.767 SGFF = 16.030 SGBH = 71.474 NSBF = 101.606 FSBF = 16.588 NTMD = 16324.210 FTMD = 2902.119 RTMD = 5.625 CRNF = 6.085 PHIT = 31.464 SGFM = 15.311 SIGQ = .985 RSBF = .779 SGIN = 13.350 SIGC = 1.147 GRCH = -1.000 DEPT = 10044.500 SGFN = 20.319 SGFF = 17.303 SGBH = 62.459 NSBF = 96.387 FSBF = 9.859 NTMD = 17170.050 FTMD = 3044.212 RTMD = 5.636 CRNF = 5.967 PHIT = 29.718 SGFM = 16.942 SIGQ = .978 RSBF = .684 SGIN = 15.223 SIGC = 1.113 GRCH = 47.896 DEPT = 9844.500 SGFN = 21.956 SGFF = 17.535 SGBH = 70.342 NSBF = 115.051 FSBF = 12.947 NTMD = 20047.070 FTMD = 4060.399 RTMD = 4.938 CRNF = 5.385 PHIT = 21.580 SGFM = 18.397 SIGQ = .989 RSBF = .478 SGIN = 16.894 SIGC = 1.089 GRCH = 77.016 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE --- COMCEN.004 --- 93/03/27 --- 1024 --- LO Page 11 OPTIONAL NEXT FILE NAME --- 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 --- 93/03/27 --- 1024 --- LO --- COMCEN.004 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 05 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 TMD 10253.0 $ 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 9800.0 09-DEC-91 DLS 4.01 0815 09-DEC-91 10440.0 10268.0 9800.0 10250.0 900.0 NO TOOL NUMBER GR GAMMA RAY TMD PULSED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: 106312 106312 8.500 10440.0 SEAWATER/CRUDE Page 12 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): 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8. 500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 10110.0 BASE NORMALIZING WINDOW (FT): 10140.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5725 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 27000 TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW 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 I 66 0 3 2 79 80 4 i 66 1 5 i 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 SERVICES UNITS DEPT F SGFN TMD 739618 CU API CODE FILE# 00000000 0 00000000 0 SIZE #SAMP REPR. 4 1 68 4 1 68 Page 13 SGFF TMD 739618 CU 00000000 0 4 i 68 SGBH TMD 739618 CU 00000000 0 4 I 68 NSBF TMD 739618 CNTS 00000000 0 4 1 68 FSBF TMD 739618 CNTS 00000000 0 4 1 68 NTMD TMD 739618 CNTS 00000000 0 4 i 68 FTMD TMD 739618 CNTS 00000000 0 4 i 68 RTMD TMD 739618 00000000 0 4 1 68 CRNF TMD 739618 00000000 0 4 1 68 PHIT TM]) 739618 DECI 00000000 0 4 1 68 SGFM TMD 739618 CU 00000000 0 4 i 68 SIGQ TMD 739618 00000000 0 4 1 68 G4ER TMD 739618 00000000 0 4 1 68 RSBF TMD 739618 00000000 0 4 1 68 ABTN TMD 739618 00000000 0 4 1 68 SGIN TMD 739618 CU 00000000 0 4 1 68 SIGC TMD 739618 00000000 0 4 I 68 GR TMD 739618 GAPI 00000000 0 4 i 68 CCL TMD 739618 MV 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 10253.000 SGFN = 27.210 SGFF = 39.580 SGBH = 79.552 NSBF = 113.353 FSBF = 62.278 NTMD = .000 FTMD = .000 RTMD = .000 CRNF = 1.703 PHIT = -999.000 SGFM = 24.263 SIGQ = .981 G4ER = .023 RSBF = .668 ABTN = 14508.000 SGIN = 23.631 SIGC = 1.027 GR = -1.000 CCL = -1.000 DEPT = 10153.000 SGFN = 19.185 SGFF = 16.915 SGBH = 69.656 NSBF = 89.418 FSBF = 9.297 NTMD = 15984.340 FTMD = 3033.887 RTMD = 5.269 CRNF = 5.697 PHIT = .258 SGFM = 15.749 SIGQ = .983 G4ER = .015 RSBF = .801 ABTN = 27247.060 SGIN = 13.854 SIGC = 1.137 GR = 33.147 CCL = 10.530 DEPT = 10053.000 SGFN = 20.665 SGFF = 17.547 SGBH = 66.575 NSBF = 95.910 FSBF = 9.820 NTMD = 15004.440 FTMD = 2683.799 RTMD = 5.591 CRNF = 5.979 PHIT = .299 SGFM = 17.307 SIGQ = .983 G4ER = .011 RSBF = .803 ABTN = 25892.910 SGIN = 15.642 SIGC = 1.106 GR = 40.819 CCL = 10.501 DEPT = 9953.000 SGFN = 21.765 SGFF = 18.088 SGBH = 69.168 NSBF = 103.464 FSBF = 11.578 NTMD = 19499.550 FTMD = 3818.448 RTMD = 5.107 CRNF = 5.529 PHIT = .235 SGFM = 18.469 SIGQ = .988 G4ER = .001 RSBF = .474 ABTN = 21340.060 SGIN = 16.977 SIGC = 1.088 GR = 31.544 CCL = 11.761 Page 14 DEPT = 9853.000 SGFN = 21.320 SGFF = 17.248 SGBH = 73.083 NSBF = 111.120 FSBF = 13.413 NTMD = 18708.400 FTMD = 4048.899 RTMD = 4.621 CRNF = 5.127 PHIT = .182 SGFM = 17.398 SIGQ = .987 G4ER = .020 RSBF = .648 ABTN = 28252.500 SGIN = 15.747 SIGC = 1.105 GR = 63.480 CCL = 11.138 ****************************************************************************** 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 --- 93/03/27 --- 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 --- 93/03/27 --- 1024 --- LO --- COMCEN.005 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 06 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 TMD LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): 10254.0 9800.0 09-DEC-91 DLS 4.01 0815 09-DEC-91 10440.0 10268.0 9800.0 Page 15 BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 10250.0 900.0 NO TOOL NUMBER GR GAMMA RAY TMD PULSED NEUTRON $ 106312 106312 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 10440.0 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/CRUDE 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERM/tL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 10110.0 BASE NORMALIZING WINDOW (FT): 10140.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5725 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 27000 TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #2. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i 1 66 0 Page 16 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 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE DEPT F 00000000 SGFN TMD 739618 CU 00000000 SGFF TMD 739618 CU 00000000 SGBH TMD 739618 CU 00000000 NSBF TMD 739618 CNTS 00000000 FSBF TMD 739618 CNTS 00000000 NTMD TMD 739618 CNTS 00000000 FTMD TMD 739618 CNTS 00000000 RTMD TMD 739618 00000000 CRNF TMD 739618 00000000 PHIT TMD 739618 DECI 00000000 SGFM TMD 739618 CU 00000000 SIGQ TMD 739618 00000000 G4ER TMD 739618 00000000 RSBF TMD 739618 00000000 ABTN TMD 739618 00000000 SGIN TMD 739618 CU 00000000 SIGC TMD 739618 00000000 GR TMD 739618 GAPI 00000000 CCL TMD 739618 MV 00000000 ******************************************* DATA RECORD TYPE 0 FILE~ SIZE #SAMP 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 1 0 4 i ********************** REPR. 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 DEPT = 10254.000 SGFN = 23.568 SGBH = 74.931 NSBF = 121.811 NTMD = .000 FTMD = .000 CRNF = 1.528 PHIT = -999.000 SIGQ = .990 G4ER = .014 ABTN = 13969.990 SGIN = 20.200 GR = -1.000 CCL = -1.000 SGFF = FSBF = RTMD = SGFM = RSBF = SIGC = 21.541 26.679 .000 21.275 .518 1.053 DEPT = 10154.000 SGFN = 19.357 SGBH = 71.322 NSBF = 103.439 NTMD = 15588.810 FTMD = 3002.742 CRNF = 5.646 PHIT = .251 SIGQ = .985 G4ER = .009 ABTN = 26751.450 SGIN = 14.061 GR = 38.960 CCL = 10.193 SGFF = FSBF = RTMD = SGFM = RSBF = SIGC = 16.609 10.700 5.192 15.930 .802 1.133 Page 17 DEPT = 10054.000 SGFN = 20.136 SGFF = 17.267 SGBH = 61.286 NSBF = 108.042 FSBF = 12.530 NTMD = 18449.440 FTMD = 3159.159 RTMD = 5.840 CRNF = 6.165 PHIT = .327 SGFM = 16.749 SIGQ = .984 G4ER = .010 RSBF = .500 ABTN = 20108.870 SGIN = 15.002 SIGC = 1.116 GR = 47.081 CCL = 10.260 DEPT = 9954.000 SGFN = 21.890 SGFF = 18.819 SGBH = 67.456 NSBF = 117.765 FSBF = 12.958 NTMD = 19334.890 FTMD = 3760.526 RTMD = 5.142 CRNF = 5.537 PHIT = .236 SGFM = 18.601 SIGQ = .991 G4ER = .009 RSBF = .475 ABTN = 21888.360 SGIN = 17.128 SIGC = 1.086 GR = 44.811 CCL = 10.351 DEPT = 9854.000 SGFN = 21.817 SGFF = 17.761 SGBH = 71.281 NSBF = 125.628 FSBF = 15.012 NTMD = 18628.810 FTMD = 4006.740 RTMD = 4.649 CRNF = 5.124 PHIT = .182 SGFM = 18.093 SIGQ = .990 G4ER = .007 RSBF = .617 ABTN = 27245.680 SGIN = 16.546 SIGC = 1.094 GR = 76.791 CCL = 11.019 ****************************************************************************** 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.O06 --- 93/03/27 --- 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 --- 93/03/27 --- 1024 --- LO --- COMCEN.006 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: RAW CURVES 07 Page 18 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 TMD 10254.0 $ 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 9800.0 09-DEC-91 DLS 4.01 0815 09-DEC-91 10440.0 10268.0 9800.0 10250.0 900.0 NO TOOL NUMBER GR GAMMA RAY TMD PULSED NEUTRON $ 106312 106312 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.5O0 10440.0 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/CRUDE 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 10110.0 BASE NORMALIZING WINDOW (FT): 10140.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 Page 19 FAR COUNT RATE HIGH SCALE (CPS)= 5725 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 27000 TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #3. $ 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 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 i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILES SIZE #SAMP REPR. DEPT F 00000000 0 4 I 68 SGFN TMD 739618 CU 00000000 0 4 i 68 SGFF TMD 739618 CU 00000000 0 4 i 68 SGBH TMD 739618 CU 00000000 0 4 1 68 NSBF TMD 739618 CNTS 00000000 0 4 1 68 FSBF TMD 739618 CNTS 00000000 0 4 1 68 NTMD TMD 739618 CNTS 00000000 0 4 1 68 FTMD TMD 739618 CNTS 00000000 0 4 1 68 RTMD TMD 739618 00000000 0 4 i 68 CRNF TMD 739618 00000000 0 4 1 68 PHIT TMD 739618 DECI 00000000 0 4 1 68 SGFM TMD 739618 CU 00000000 0 4 i 68 SIGQ TMD 739618 00000000 0 4 i 68 G4ER TMD 739618 00000000 0 4 1 68 RSBF TMD 739618 00000000 0 4 1 68 ABTN TMD 739618 00000000 0 4 1 68 SGIN TMD 739618 CU 00000000 0 4 i 68 SIGC TMD 739618 00000000 0 4 1 68 GR TMD 739618 GAPI 00000000 0 4 1 68 CCL TMD 739618 MV 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 Page 20 DEPT = 10254.000 SGFN = 23.598 SGFF = 22.796 SGBH = 68.217 NSBF = 137.808 FSBF = 34.349 NTMD = .000 FTMD = .000 RTMD = .000 CRNF = 1.276 PHIT = -999.000 SGFM = 22.715 SIGQ = .991 G4ER = .003 RSBF = .522 ABTN = 13953.980 SGIN = 21.853 SIGC = 1.039 GR = -1.000 CCL = -1.000 DEPT = 10154.000 SGFN = 19.261 SGFF = 15.971 SGBH = 71.115 NSBF = 120.047 FSBF = 12.215 NTMD = 15639.100 FTMD = 3027.858 RTMD = 5.165 CRNF = 5.617 PHIT = .247 SGFM = 15.829 SIGQ = .986 G4ER = .016 RSBF = .781 ABTN = 26257.680 SGIN = 13.945 SIGC = 1.135 GR = 49.328 CCL = 10.775 DEPT = 10054.000 SGFN = 20.448 SGFF = 17.625 SGBH = 61.889 NSBF = 122.771 FSBF = 14.104 NTMD = 18756.070 FTMD = 3231.592 RTMD = 5.804 CRNF = 6.135 PHIT = .322 SGFM = 17.078 SIGQ = .982 G4ER = .012 RSBF = .500 ABTN = 20401.510 SGIN = 15.380 SIGC = 1.110 GR = 55.823 CCL = 11.008 DEPT = 9954.000 SGFN = 22.277 SGFF = 18.778 SGBH = 70.555 NSBF = 126.538 FSBF = 14.418 NTMD = 19366.020 FTMD = 3723.096 RTMD = 5.202 CRNF = 5.645 PHIT = .251 SGFM = 19.010 SIGQ = .986 G4ER = .012 RSBF = .449 ABTN = 21135.990 SGIN = 17.598 SIGC = 1.080 GR = 48.963 CCL = 11.127 DEPT = 9854.000 SGFN = 22.251 SGFF = 17.908 SGBH = 75.817 NSBF = 133.406 FSBF = 15.719 NTMD = 18267.340 FTMD = 3914.071 RTMD = 4.667 CRNF = 5.216 PHIT = .194 SGFM = 18.533 SIGQ = .987 G4ER = .013 RSBF = .590 ABTN = 26458.880 SGIN = 17.051 SIGC = 1.087 GR = 77.073 CCL = 11.744 ****************************************************************************** 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 --- 93/03/27 --- 1024 --- LO ****************************************************************************** Page 21 TAPE TRAILER RECORD SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER NEXT TAPE NAME COMMENTS: --- COMCEN --- 93/03/27 --- ANCH ~m~ 0 TYPE 131 ****************************************************************************** REEL TRAILER RECORD TYPE 133 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER NEXT REEL NAME COMMENTS: --- COMCEN --- 93/03/27 --- ANCH --- 739618 ****************************************************************************** END OF TAPE ENCOUNTERED Page 22 COMPUT£R DIRECT DIGITAL LOGGING PROCESSED ANALYSIS Company ARO0 ALASKA INC. Well DS 14-23 Field PRUDHOE BAY · County NORTH SLOPE Statm ALASKA CLIENT FORMAT DATA TAPE LOG I NF ORMAT"I ON STANDARD FO~RMAT (.L., I, S, DePths:: :..:9655 ;.~0 to 1 04.54. O0 Name: DS, 14-23 Date: 24 dUNE, 1983 Time: 4:06 PM FRI. Page: 1 : _ L, I, S, TAPE RECORDS REEL HEADER $~rvice name; &GSFOI m--m--m-- Previou~ HEADER Da~e: 83706724 Origin: Commentz: mmm-- RECORDS Rmel name: 228621 Page Continuation #: 01 TAPE HEADER Smrvicm name: &GSF01 Da~e: 83706?24 Origin: Prmviou~ tape: Commentz: Tape name: 228621 Continuation #: 01 EOF FILE HEADER File name: &GSF01.001 Maximum length: 1024 HEADER RECORDS Service name: Yer~ion #: Date: type: LO Previouz ?ile: Pagm MN£M CH WN FN .COUN STAT CTRY SECT TOWN RANG EKB EDF EgL PD LNF RUN LCC SON LUN FL LUL EN~I WITN DD DL TLI BLI TCS TLAB BHT MRT MT MSS MVIS RM RMF MFST MF~S RMC MCaT MCSS I NFORMAT I ON RECORDS CONTENTS UNIT ARCO ALASKA INC. . ............... D~ 14w23 ................ PRUDHOE BAY ................ NORTH SLOPE ..................................... ALASKA ....... ....... · ....... ...' ............. USA ..... , ........... ............. 9ttllll%lIlltiIIlllllIlIItlIlllllll II I-IllllllIlIIII .......................................... : ...... :... i4E .................................................... 72.000 ................................................. 71.000.., ............ 42.000 ............... SL KB ................... llltllllll,lIilllllll 30 ................... 228621 ............. .......... .o t. sLOP . NORTH SLOPE . HITT . NC CULLOU~H . 10440.000 ............ 10436.000 ............ 9766,000 ............. i0432,000 ............ i500,000 ............ 2350,000 ............. 197,000 .............. LIGHOs FLOWLINE . 41 .000 1 .. 660 ............ , , , , 1 , 480 ................ 69.900 ............... NEAs .......... 2.140 71.300 ............... NEAs .......... TYPE CATG SIZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 O O 20 65 0 0 20 65 0 0 20 65 0 0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 0 3 2 65 0 0 2 79 0 0 2 79 0 0 JO 65 0 0 lO 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 1 4 68 DEGF 0 I 4 68 O 2 20 65 0 2 20 65 CP O 2 4 68 OHMM O 2 4 68 OHNM 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHHM 0 2 4 68 DEGF 0 2 4 68 O 2 12 65 Pag~ CO IENT RECORDS This LIS tape was written by Gearhart Industries Wireline Services. All curve and tool mnemonics used are those which most clozely match Gearhart curve and tool mnemonics, GEaRHaRT TO SCHLU~BEROER MNEM SERVICE UNIT NNEM SERVICE UNIT DEPTH FEET DEPT FT TEN DIL/BCS MV TENS DILBCS NV SP DIL/BC$ MV SP DILBCS MV GR DIL/BCS GAPI GR DILBCS GAPI ILD DIL/BCS OHMM ILD DILBCS ONMM ILM DIL/BCS OHMM ILM DILBCS OHMM LL3 DIL/BCS OHMM LL8U DILBCS OHMM DELT DIL/BCS US/F DT DILBCS US/F AMPS OIL/BCS MV AMPL DILBCS MV CILD DIL/BCS MMHO CILD DILBCS MMHO Page DATA ENTRY BLOCKS ENTRY ENTRY BLOCK LEGEH~ ~*** TYPE DESCRIPTIOH 0 Terminator ( no more entriez > FORNAT SPECIFICATIONS TYPE SIZE CODE 0 1 66 Pag~ DATA FORMAT SPEC I F I CAT IONS 8LOuKv · ~ DATUH SPECIFICATION SER¥ICE~SERVICE API API API API FILE MNEH ID ORDER # uNIT LOG TYPE CLASS MOD # DEPT 2~86~1 'FT 0 0 0 0 0 TENS DILBCS ~@~ MY 0 0 0 0 0 ~P DILB~S ~862! MV 0 ~ 0 0 0 ~R DILBCS 2~8621 ~API 0 3~ 0 0 0 ILD DILBCS 2~8621 OHMM 0 12 46 0 0 ILM DILBCS' ~8'6~1 ONMM 0 1~ 44 0 0 LLSU DILBCS 2~86~ ONMM 0 22 8 0 0 DT DILBOS ~86~ ,US?F 0 5~ J~ 0 0 AMPL DILBCS ~8621 'MY 0 53 J 0 0 OILD DILBCS ~862~ MMHO 0 68 4~ 0 0 PRC # SIZE LVL~SMPL RC 4 0 I 68 4 0 1 ~8 4 0 1 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 I ~8 4 0 1 68 4 0 i ~8 PROCESS INDICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Pag~ DEPT AMPL TENS CILD SP 1 0454,000 193.400 10.000 1000.000 0,000 DATA 0.000 RECORDS ILD ILH LLSU 1 .000 I, 000 ,861 DT Page_ 0.000 1 0354,000 158,100 1 0'254. 000 177.400 1 0154. 000 170,300 1 0054. 000 155,000 -I .000 481 .948 -2. 000 09. 901 1 . 000 34.674 -2. 000 28. 973 28. 900 25,900 2,075 2, :399 4,831 91.700 25,600 14,400 9. 099 1 0.965 17,179 92. 700 22,400 19.200 28,840 29.512 28,51 0 84,300 1.5. I O0 16,700 34,514 28,907 28. 642 92,900 9954,000 186.200 9854,000 124.200 9754,000 142.400 0.000 24,660 -1.000 23.605 O. 000 50.350 24,000 19.400 40,551 33,419 36.898 86,900 44,800 66.500 42.364 56.234 28,642 65.800 121:, 800 50,000 19.861 100000. 020 , 601 56,000 :~mmm FILE TRAILER File name: &~SFOl.O0~ Maximum length: TRAILER RECORDS SerVice name: Yer~ion #: Film type: LO Next ¢ile: Date: Page FiLE HEADER Fil~ name: &GSF01.002 HEADER RECORDS S~rvic~'nam¢: Maximum l~ngth: 1024 Fil~e type: LO Previouz Pag~ 10 CN WN FN COUN STAT CTRY SECT TOWN RANG EKB EDF EGL PD LMF DMF RUN LCC SON LUN FL LUL EN~I WITN DD DL TLi BLI TCS TLAB BHT MRT MSS M¥IS RM RMF MF.T MFSS RHC MCST MCSS CONTENTS ARCO 'ALASKA INC, DS i 4-2.3 PRUDHOE BAY NORTH SLOPE · ALASKA , USA . 0'3 1 ON ................. , 14E .................. 72. 000 ............... 71 ,000 ............... 42. 000 ............... ~L I I I I I ti · I m i I · m I I I ii I · · 30 ................... 2286Ri ............. 761P_ NORTH SLOPE . NORTH SLOPE . HITT . NC CULLOU~H . i 0440. 000 ............ 1 0436. 000 ............ 97~. 000 ............. 1 043~, 000 ............ l~O0.O00 ............. ~350, O00 .............. 197. 000 ............... 1~7. 000 ............... LI~NOS . . FLOWL I NE . . 41 .000 ................ 1 ·660 ................. I .480 ................. 69.g00 NEAS ........... ~.140 7i .300 ................ HE~S INFORMATION · m t · m · · · I · I · i · I I ! m I · I Il I t II · , i i m I I , I I I II ii I I$ ·$ ,ii ,I II iImImli III'mill lliiliI IlsmI. iI iIISimI isilllI IlI'IIII llI'IlII iiiiiII 1,151t·1 lllIl, ll I illllII I iIIIIlI I iIIlIII I iiIIIII I iiIlIII I I, iIIlII I IilIiII i IlIIIII I iIaiiII I IaIIIII i iaiIlII · IIIItII · IIIII. II I III'lItII! I'lllI, IIIl Iil~IItIIl I~lI. II. IIII ilIIIIlII iIIIiIIII IIIIIlIIl lIIItIIII IIIIIIIII mtttmtiiII · I · · · i I I I i · I I · I m I I · $ · I I · I II , I · I I I i · i · I , m I I ! · I l , I I II I mi III · mi II I ii I III. I II· I II I II II · i· II I i ii I II I ·ii I I ii IlII ilII Iii, IIII iIii IIIl IIII IIlI IIII IIlI IIiI' IIII tIII IlIl IliI RECORDS UNIT TYPE CATG SIZE CODE III-- III! III-- Im--I III-- ......... 0 0 ......... 0 0 ......... 0 0 ......... 0 0 .......... 0 0 ......... FT 0 ......... FT 0 ......... FT 0 ......... 0 ......... 0 0 ......... 0 0 ......... 0 0 ......... 0 0 ......... 0 ......... 0 0 ......... 0 0 ......... 0 0 ......... FT 0 ......... FT 0 ......... FT 0 ......... FT 0 ......... HR 0 ......... HR 0 4 DEOF 0 "i ...... · Oe F 0 II IIIImI ......... 0 0 .......... CP 0 ......... ONMM 0 ......... OHMM 0 ......... DEGF 0 2 ......... OHHH 0 2 ......... DEGF 0 2 .......... 0 2 40 65 40 65 40 65 20 65 20 65 , 20 65 2 65 3 65 3 65 4 68 4 68 4 68 2 65 2 65 2 65 2 79 2 79 10 65 10 65 20 65 20 65 20 65 20 65 4 6S 4 68 4 68 4 68 4 68 4 68 20 65 20 65 4 68 4 68 4 68 4 (;8 12 65 4 68 4 6S 12 65 Page 11 COMMENT RECORDS Thi~ LIS ~ape was written by ~earhar~ Indu~trie~ Wireline Services, All curve and tool mnemonics'used are tho~ which most closely match ~arhart curve and.tool mn~monicz. OEARHART TO SCHLUMBEROER MNEM SERVICE UNIT MNEM SERVICE' UNIT DEPTH FEET DEPT FT CNDO~ CDL/CNS ~ DOL NPHI .FDCCNL PU TEN~ CDL?CNS MV TENS FDCCNL MV 0R~ CDL/CNS ~API OR FDOCNL ~API XCAL~ CDL?CNS IN CALl FDCCNL IN YCAL! CDL/CNS IN CAL~ FD~CNL IN FCDLI CDL/CNS CPS FFDL FDCCNL CPS NCDL! ODL?CNS CPS NFDC FDCCNL CPS RHOB~ CDL?CNS ~?C3 RHOB FDCCNL 07C3 DRHO~ CDL/CNS ~/C3 DRHO FDC~NL ~/C3 CHS~ CDL/CNS ~ LI~E NPHI FDCCNL PU FCNS~ CDL/CNS CPS FCNL FDCCNL CPS NCNS! CDL/CNS CPS NCNL FDCCNL CPS CNSS~ CDL?CNS ~ SAND NPNI FDCCNL PU Page 12 DATA ENTRY ****************************** **** ENTRY ~0~ ~£GEND **** ****************************** TYPE DESCRIPTION 0 Terminator ( no'more-entri~ ) FORMAT SPECIFICATIONS TYPE SIZE CODE IIl~ I~mm.~m,~ 0 1 66 Pag~ DATA FORMAT SPECI F I CA T IONS DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE APl AP1 API' API FILE ID ORDER # UNIT LOG TYPE ~LASS MOD # DEPT 22862~ FT' 0 0 0 0 0 NPNi FDCCNL 228621 PU 42 68 TENS FDCCNL 22862~ MV 42 0 0 0 ~R FDCCNL 22862~ ~API 42 31 O 0 CALl FDCCNL 228621 IN 42 28 0 0 CAL2 FDCCNL 22862~ IN 42 0 0 0 FFDL FDCCNL 228621 CPS 42 0 0 0 1 NFDC FDCCNL 22862~ CPS 42 0 0 0 1 RHOB FDCCNL 22862~ G/C3 42 35 DRHO FDCCNL 22862~ G/C3 42 39 0 0 1 NPHI FDCCNL 22862~ PU 42 68 2 0 I FCNL FDCCNL 228621 CPS 42 0 0 0 1 NCNL FDCCNL 22862~ CPS 42 0 0 0 NPHI FDCCNL 228621 PU 42 68 3 0 PRC # SIZE LVL SNPL RC 4 0 I 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 I 68 4 0 I 68 4 0 1 68 4 0 1 68 PROCESS iNDICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Pag~ 14 J~- ~ A J~J U li ~ DATA RECORDS Page 15 DEPT NPH I TENS GR {3AL I CAL2 FFDL NFDC RHOB DRHO NPH I FCHL NCNL NPH I i0454,000 -i.663 0,000 0.000 0.000 0.000 72.100'~' 6~.500 2, 1 08 -1 , 085 O. 000 O, 000 O. 000 4,000 0354,000 18,701 3. 000 24,200 8. 290 8. 340 460. 400 528. 1 O0 2,265 . 027 2.1 ,700 349,700 359. 200 25;,700 1 0254,000 18. 000 4. 000 118,000 IB,SO0 8,520 494,300 515o 900 2,230 , 024 21 , 0-00 377,900 3'83,400 25,000 1 0154,000 13,699 1 , 0:00 20,1 O0 8,320 8,37'0 494,1 O0 531 . 1 O0 2,234 , 027 i6,690 486,400 4.41 ,900 20.&90 1 0054,000 17,850 1 , 000 2l ,2:00 8. 450 lB, 420 495,700 524. 300 2,232 , 023 20,:850 359,900 3'59,500 24,850 '3954,000 15,511 -2,000 17. 700 2,283 , 024 1:8.51 0 394.800 8/'460 8,460 44'3,400 512. I O0 3'77,.400 22,51 0 9854,000 4,353 4,000 65,800 2,602 . Ot 7 6. 940 888,700 8;<330 8. 920 .259. 900 441 .200 573, OOO 1 0,940 9~754,000 50, 021 1 , 000 46'._300 8,560 8.75;0 149,70'0 93,400 I , 7.58 -1 , 154 49,220 82..300 1:29,000 53,220 File name: ~GSFOI,002 Maximum length: 1024 TRAILER RECORDS Verzion #: Film type: LO Date: Page · '~oo~eo~//O *********************************~ .......... ,, ,'"""'"~""'*..., .................... '. ,..' '~.'.'~;... ~ ..'.."'.~. ~.i ."..... ? .'.'.' .'... ,,~,:, :.'.:'.. ~........ , .'~ .:.'. ,'" , /~,,L.*~---~CHI.~'UI~.B.I~.~.GE, R,~,~.~.;,~'~.?~';': .'..:' ":....." ':':'.' .'. ?: '..:' ~.:"? ": .. :...:..',. '. :'.'" ." .'.i .". i..." ." !'.~' :..': .' :"": '"" '"" .... .., ...~. ,~:..:..~.~.:.:..?,:..~:~?.~'~; , , .;' .~'.' :.:.' ... ..........:..~.~....~',:.,..,..~.; ..'..' .... . .~f~v~~¢:~- ....................... 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