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Home My WebLink About196-179TI-W, MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001, PL M A T W E IA L U N D ER T H IS M ARK ER ~_,~._ ~_~ E REPORT ~= .~o.lq/. - 1'7 ? ~ we~ ~ =-' ~ o, an.,:i' cerumen: an pluq~-~g, well head .~.eV'~ aW ~--e ...... S UaU=S= ~ !oca=i:n,~!eaz-~nce - orc.v~$ !~ clear, c~_~e. Well hea~ c=~ o~_=: ~ .. Code q Signed STATE OF ALASKA ALASKA _~L AND GAS CONSERVATION COMk .... SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 196-179 300-114 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20163-01 4. Location of well at surface .1~i~~ 9. Unit or Lease Name 1039' SNL, 938' EWL, SEC. 36, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval , 1024' SNL, 966' EWL, SEC. 36, T11N, R14E, UM At total depth 10. Well Number 350' NSL, 1406' EWL, SEC. 25, T11N, R14E, UM 02-10A 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool RKB = 58.07' ADL 028308 17' T°ta' Depth (MD+TVD)118'10375 8903 FTI Plug Back Depth (MD+TVD)9138 8998 FTII 19' Directi°na' Survey I 20'[] Yes [] No Depth where SSSV setl 21' Thickness °f Permafr°stN/A MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD / GR 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-TING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 100' 32" 500 sx (Approx.) 13-3/8" 72# MN-80 Surface 2715' 17-1/2" 8500 sx Permafrost II 9-5/8" 47# S00-95/MN-80 Surface 8724' 12-1/4" 1500 sx Class 'G', 150 sx PF II 2-7/8" 6.5# L-80 8195' 10360' 3-3/4" 147 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 5-1/2", 17#, N-80 7971'- 8195' 8170' MD TVD MD TVD 4-1/2", 12.6#, N-80 8296' ....... ~.~_~ ~ .... ~ ¥' ...... ~_~,~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED d~._ ~...-" /.~dUi) 8250' P&A'd with 22 Bbls Class 'G', Sqzd to 500 7821' Set EZSV ~.~':,~ O~'i ~ ~;;-~ ~,0~';~;, ~,,.,.,:,,,~,~,, ~ 7821 Set Whipstock 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Not on ProductionI N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 0RI$1NAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of Sadlerochit 8473' 8473' ,_ 31. List of Attachments: Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,errieHubble ,'~~~'/' ~ Title TechnicalAssistant,l, Date 02-10A 196-179 300-114 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. ~NSTRUCTIONS 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 02-10A DESCRIPTION OF WORK COMPLETED PRE RIG WORKOVER / SIDETRACK CEMENT PLUG & ABANDONMENT Date Event Summary 10/10/1999: 4/03/2000: 5/03/2000: 5/09/2000: 5/10/2000: RIH & pushed IBP f/8990' to 9138' CTM. PPPOT-IC to 3000 psi - passed. RIH & drifted w/2.3" CENT to 9070' SLM. A CTU Cement plug was pumped to Plug & Abandon the lower wellbore prior to Rig Sidetrack Operations as follows: MIRU CTU. PT'd equip to 4000 psi. Killed well w/ SLK 1% KCL Water. RIH & tagged IBP ~ 9138' MD. Pumped 22 bbls of 15.8 ppg Class G Cement to plug & abandon the open perforations located ~: 8922'- 8927'MD 8931'- 8936'MD 8944'- 8949'MD 8957'- 8962'MD 8990'- 9010'MD 9133'-9138'MD Reference Log: BHCS 7/20/1975. (The following perforation intevals are isolated below pushed IBP ~ 9138'): 9138'-9153'MD 9165'-9180'MD 9193'-9214'MD 9258'-9266'MD (The following perforation intervals are also isolated below CIBP set 4/27/97): 9330'- 9520'MD 9658'- 9690'MD 9704'- 9908'MD 9932'- 9960'MD Placed 12 bbls of Cement behind pipe @ a max squeeze press of 500 psi. Contaminated Cement w/Biozan & cleaned out cement to 8250'. POOH. FP'dwell. RD. WOC. 5/11/2000: RIH & cut the 5-1/2" tubing ~ 7965' MD w/chemical cutter. Continued w/02-1 OB Rig Sidetracking Operations. STATE OF ALASKA ALASKA UlL AND GAS CONSERVATION COMM,oSION WELL COMPLETION OR RE[COMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 196-179 300-114 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 1 ~. 50-029-20163-01 4. Location of well at surface~"" -' 9. Unit or Lease Name 1039' SNL, 938' EWL, SEC. 36, T11N, R14E, UM ,~ Prudhoe Bay Unit At top of productive interval 1024' SNL, 966' EWL, SEC. 36, T11N, R14E, UM At total depth 10. Well Number 350' NSL, 1406' EWL, SEC. 25, T11N, R14E, UM 02-10A 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool RKB = 58.07' ADL 028308 12. Date Spudded12/27/96 113' Date T'D' Reached 114' Date COmp'' SuSp'' Or Aband'1,1 2/97 05,09,2000 115' Water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsZero 17. Total10375 Depth (MD+'rvD)118'8903 FT Plug Back Depth (MD+TVD)9138 8998 FTI' 19' Directi°nal Survey 1 20' Depth where SSSV setl 21' Thickness °f Permafr°st[] Yes [] No N/A MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD / GR 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SiZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 100' 32" 500 sx (Approx.) 13-3/8" 72# MN-80 Surface 2715' 17-1/2" 6500 sx Permafrost II 9-5/8" 47# S00-95/MN-80 Surface 8724' 12-1/4" 1500 sx Class 'G', 150 sx PF II 2-7/8" 6.5# L-80 8195' 10360' 3-3/4" 147 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 5-1/2", 17#, N-80 7971'- 8195' 8170' MD ~ ~.-~ ~-~ ~ ~.~ ~-~ ~' ~ t0ff'~,~....~.~, :.,, TVD 4-1/2", 12.6#, N-80 8296' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED dU~.~ ,.9 : £'d,'uO 8250' P&A'd with 22 Bbls Class 'G', Sqzd to 500 .,-,,:...-, . ¢*.~., ,.; .-.., .... .., ...... C,'-~m;~iar.; 7821' Set EZSV Ari¢;h~ 7821' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD Flow Tubing ~asing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE .28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. DUPLICATE Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of Sadlerochit 8473' 8473' ~o. i31. List of Attachments: Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ''~/~''~r' 2 ~ Title TechnicalAssistantlll Date 02-10A 196-179 300-114 Prepared By Name/Numbec Terrie Hubble, 564-4628 Well Number Permit No./Approval No. ~NSTRUCTIONS 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 02-10A DESCRIPTION OF WORK COMPLETED PRE RIG WORKOVER / SIDETRACK CEMENT PLUG & ABANDONMENT Date Event Summary 10/10/1999: 4/03/2000: 5/03/2000: 5/09/2000: 5/10/2000: RIH & pushed IBP f/8990' to 9138' CTM. PPPOT-IC to 3000 psi - passed. RIH & drifted w/2.3" CENT to 9070' SLM. A CTU Cement plug was pumped to Plug & Abandon the lower wellbore prior to Rig Sidetrack Operations as follows: MIRU CTU. PT'd equip to 4000 psi. Killed well w/ SLK 1% KCL Water. RIH & tagged IBP ~ 9138' MD. Pumped 22 bbls of 15.8 ppg Class G Cement to plug & abandon the open perforations located ~: 8922'- 8927'MD 8931'- 8936'MD 8944'- 8949'MD 8957'- 8962'MD 8990'-9010'MD 9133'-9138'MD Reference Log: BHCS 7/20/1975. (The following perforation intevals are isolated below pushed IBP ~ 9138'): 9138'-9153'MD 9165'-9180'MD 9193'- 9214'MD 9258'-9266'MD (The following perforation intervals are also isolated below CIBP set 4/27/97): 9330'- 9520'MD 9658'- 9690'MD 9704'-9908'MD 9932'- 9960'MD Placed 12 bbls of Cement behind pipe @ a max squeeze press of 500 psi. Contaminated Cement w/Biozan & cleaned out cement to 8250' POOH. FP'dwell. RD. WOC. 5/11/2000: RIH & cut the 5-1/2" tubing ~ 7965' MD w/chemical cutter. Continued w/02-1 OB Rig Sidetracking Operations. STATE OF ALASKA - ALASK/-, JIL AND GAS CONSERVATION COMN,,SSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: 2. Name of Operator ARCO Alaska Inc. [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1039' SNL, 938' EWL, SEC. 36, T11N, R14E, UM At top of productive interval 1024' SNL, 966' EWL, SEC. 36, T11N, R14E, UM At effective depth 786' SNL, 974' EWL, SEC. 36, T11N, R14E, UM At total depth 350' NSL, 1406' EWL, SEC. 25, T11 N, R14E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service RECEIVED ,1'.~ r, I 0 2 2000 Oil & Gas C0~s, C0mmi~im~. Present well condition summary Total depth: measured 10375 feet Plugs (measured) true vertical 8903 feet Effective depth: measured 9138 feet Junk (measured) true vertical 8998 feet Casing Length Size Cemented Structural Conductor 100' 20" Su trace 2657' 13-3/8" Intermediate Production 8666' 9-5/8" 1500 sx Class 'G', 150 sx PF II Liner 2165' 2-7/8" 147 sx Class 'G' 6. Datum Elevation (DF or KB) RKB = 58.07' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 02-10A 9. Permit Number 196-179 10. APl Number 50- 029-20163-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool IBP pushed to 9138' (10/99) CIBP set at 9298' (04/97) ORIGINAL MD TVD 12. 500 sx (Approx.) 100' 100' 6500 sx Permafrost II 2715' 2715' 8724' 8724' 8195'-10360' 8195'-8964' Perforation depth: measured 8922'- 8927', 8931'- 8936', 8944' - 8949', 8957'- 8962', 8990'- 9010', 9133' - 9138' Below IBP & CIBP: 9138' - 9960' (eight intervals) true vertical 8912'- 8916', 8920' - 8924', 8930' - 8934', 8940' - 8944', 8904' - 8914', 8939' - 8998' Below IBP & CIBP: 8998' - 8919' (eight intervals) Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80 to 8195'; 4-1/2", 12.6#, N-80 to 8296' Packers and SSSV (type and measured depth) Baker SAB packer at 8170'; Otis RQ SSSV Nipple at 2219' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation May 5, 2000 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Allen Sherritt, 564-5204 [] Detailed Operations Program [] BOP Sketch 5. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Numbec Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~--------------T~.:_..~ ~,¢-~, ~ Title Senior Drilling Engineer Conditions of Approval: Notify Commission so representative may witness Plug integrity J BOP Test I// Location clearance __ Date I Approva, NO..~0'- f/J'(-' Mechanical Integrity Test__ Subsequent form required 10- ~ (~'7~ Approvea Copy Approved by order of the Commission ORIGINAL SIGNED BY Returned Commissioner Form 10-403 Rev. 06/15/88 Robert i~. Date Submit In Triplicate d rvices rilling To: From: Subject: Reference: 02 2000 Blair Wondzell - AOGCCAj~$ka 0{[ ~ ~''' ^ ~ Allen Sherri~ A,q~or~e BP Exploration / ARCO Alaska Inc. Date: May 1, 2000 2-10B Application for Sundry Permit - P&A for Sidetrack Operations APl #50-029-20163-01 Well 2-10A was drilled with CTD in 1997 and is currently shut-in due to high GOR and failed 9 5/8" pack-off. The well is planned to be sidetracked to a new bottom hole location as a horizontal producer targeting both distributary channel and mouth bar sands in Zone 1. The sidetrack is currently scheduled for Nabors 7ES beginning around May 10m after the completion of 4-18 RWO. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. . Pre-Ria Work: * Notify the field AOGCC representative with intent to plug and abandon * 1. RU slickline and drift as required to verify ID of tubing for upcoming cement P&A. 2. RIH with CTU and perform a cement P&A using 15.8 ppg class 'G' cement with adequate cement volume to fill the 2 7/8" liner from top of IBP @ 9,138' MD to a minimum of 100' above the top perforation at 8,922' MD, plus squeeze 5 bbls to the perforations. Estimated minimum cement volume needed is 2 barrels and aggregate can be used as required to aid in plugging perfs. NOTE: Top of cement must be at a minimum of 8,822' for AOGCC compliance. Top of cement may extend up and into the tubing tail as long as it does not interfere with the upcoming tubing cutting operations. 3. Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut. 4. Liquid pack the 9-5/8"._x_ ~'~annulus to surface. Test the integrity of the cement plug and 9-5/8" casing by simultaneously pressure testing both the tubing and 9-5/8" annulus to 3000 psi for 30 minutes (tubing has a POGLM stuck at 8020' MD). Increase tubing pressure prior to the 9-5/8" annulus to avoid possibility of tubing collapse. NOTE: This step should be done prior to the tubing cut to allow additional trouble-shooting if either the cement plug or 9-5/8" casing is leaking. 5. RU E-line. Cut the 4 ~" L-80 tubing at approximately 7,900' MD. NOTE: The type of cutter to be used is at the discretion of the Wells Group. This cut will not be fished, however avoid cutting a tubing collar. 6. Displace the well to clean sea water by circulating down tubing through the tubing cut. Continue to circulate until clean sea water returns to surface. Freeze protect top 2200' MD with diesel. Test the FMC 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. . Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. Secure well. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. 14. 15. 16. 17. 18. Ri.q Operations: 1. MIRU Nabors 7ES. 2. Circulate out freeze protection and displace well to sea water. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull and lay down 5-1/2" tubing from E-line cut at -7,900' MD. Replace 9-5/8" pack off as required by hanging tubing off below storm packer after pulling the SSSV. 5. RU E-line and make GR/JB run to top of tubing cut. Set BP on E-line at -7,820' MD (set as needed to avoid cutting casing collar). Pressure test the 9 5/8" casing to 3000 psi. 6. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock, with gyro (vertical hole) as desired and set on BP. Mill window in 9-5/8" casing at -7,800' MD. POOH. 7. Kick-off and drill 8 Y2" hole from 7,800' to 8,384' at the top of the Sag River formation. Run MWD/GR LWD. No other logs are planned for this interval. 8. Run and cement a 7" 26# L-80 intermediate drilling liner. 9. Make up and RIH with a 6-1/8" directional assembly to the landing collar. 10. Test the 9-5/8" casing and 7" liner from the landing collar to surface to 3000 psi for 30 minutes. 11. Drill out 6 1/8" hole from 8,384' to TD of 11,640' in Zone 1. Run MWD/GR/Res/DEN/NEU real time LWD. 12. Run and cement a 4 ~", 12.6# L-80 IBT-Mod solid production liner throughout the 6-1/8" well bore. 13. Test the 4-1/2", 7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 3000 psi for 30 minutes. Displace well to clean sea water above liner top. POOH LD DP. Run 4-1/2", 12.6# L-80 IBT-Mod completion tying into the 4-1/2" liner top. Set packer @ -8480' MD and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. Set BPV, nipple down the BOPE. Nipple up and test the tree to 5000 psi. Freeze protect the well to -2200' and secure well. Rig down and move off. Estimated Pre-rig Start Date: Estimated Spud Date: 05/5/00 05/10/00 Allen Sherritt Operations Drilling Engineer 564-5204 RI= c VED I"!;',,Y 02 2000 Alo,,ka ~1 & Gas Cons, ~ Anchor~e ARCO ALASKA, INC. SSSVNIP Tubing-NPC FO @ 2408' Casing FO @ 2642' Casing Gas Lift Mandrel 1 8020' 2.34 MIN ID = 5-1/2" AVA POGLM POGLM SLS NOGO PBR PKR xo OTHER Tubing-NPC Liner-CT XO XO NIP SOSUB TTL 8729'-8735' 9-5/8 Window (milled 12/26/96) Perf Perf Frac Zone 1 IBP CIBP LC Float A Prudhoe Bay 02-10! 02-10A APl: 500292016301 SSSV Type: Odg Compltn: 1/13/97 Last W/O: 1/17/97 Ref Log Date: 7/20/75 Annular Fluid: Diesel/10.6 CAC12 Reference Log: BHCS Last Tag: 9138' CTM Last Tag Date: 10/10/99 RKB: 58 ft TD: 10375 ftKB Max Hole 98 deg @ 9382 Angle: Angle @ TS: dog @ Angle @ TD: 96 deg @ 10375 Rev Reason: Depth Note re: POGLM holes (kak) Last Update: 2/29/00 Well Type: PROD Depth Annotations Depth Comment 2408 FO @ 2408' 2642 FO @ 2642' 4311 4311 -4312.5' POGLM Holes. 5-22-97 POGLM pulled 8020 8020' 2.34 MIN ID = 5-1/2" AVA POGLM 8729 8729'-8735' 9-5/8 Window (milled 12/26/96) Safety Notes Date Note 2/24/00 TROUBLE WELL - FTS, T x IA communication, POGLM #2 stuck in tubing. Holes at 8020', ? IA x OA Communication to gas. OA x Form Communication, water and small amounts of gas bubbling in Cellar. General Notes Date Note 3/24/77 TTL ELM @ 8278: ELM TT (Behind CT Liner) FRAC ZNI/DATA FRAC 04/29/97; 05/06/97 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 2219 2219 SSSVNIP 8020 8020 POGLM 8078 8078 SLS 8106 8106 NOGO 8145 8145 PBR 8170 8170 PKR 8195 8195 XO 8195 8195 OTHER 8199 8199 XO 8200 8200 XO 8232 8232 NIP 8293 8293 SOSUB 8296 8296 'I-I'L 9138 9000 IBP 9298 8997 CIBP 10293 8971 LC 10358 8966 Float Casing Strings - All Size Weight Grade 9.625 47.00 MN-80/SOO-95 2.875 6.40 L-80 13.375 72.00 MN-80 Tubing Strings - All Size Weight Grade 5.500 17.00 N-80 4.500 12.60 N-80 Gas Lift Mandrels/Valves Stn MD TVD Man Man Mfr Type 2 8020 8020 AVA DWP 1. Scale04~24~97 Perforations Interval TVD 8922-8927 8912-8916 8931-8936 8920-8924 8944-8949 8930-8934 8957-8962 8940-8944 8990-9000 8961-8967 9000- 9010 8967- 8972 9133-9153 9000-9002 9165-9180 9003-9003 9193-9213 9003-9002 9198-9214 9003-9002 9258-9266 8999-8998 9330- 9520 8994-8976 9658-9690 8979-8981 9704-9908 8982-8980 9932-9960 8980-8981 Stimulations & Treatments Interval Date Type 9133 - 9960 5/6/97 Frac Zone I Description 5-1/2" Otis RQ SSSV Nipple 5-1/2" AVA-DWP POGLM (Set 03/10/97) 5-1/2" Otis XA Sliding Sleeve 5-1/2" otis XN Nipple 5-1/2" BOT PBR Assembly 9-5~8" x 5-112" Baker SAB Packer Crossover 5-1/2" x 4-1/2" (Behind CT Liner) 4-1/2" G Seal Sub Crossover 4-1/2" x 3-1/2" Crossover 3-1/2" x 2-7~8" 4-1/2" otis X Nipple (Behind CT Liner) 4-1/2" BOT Shearout Sub (Behind CT Liner) 4-1/2" Tubing Tail (Behind CT Liner) 4-1/2" IBP pushed to 9138' CTM 10110199 CIBP (Set 04127197) Att'd Mill 02/15/98 2-7/8" Baker Landing Collar 2-7~8" Davis Lynch Float Shoe Top Btm Feet Description 0 8729 8729 Casing 8195 10360 2165 Line>CT 0 2715 2715 Casing Top Btm Feet Description 0 8195 8195 Tubing-NPC 8195 8296 101 Tubing-NPC ID 4.562 2.34O 4.562 4.455 0,000 0.000 0,000 3.000 2,441 2,441 3.813 0.000 0.000 0,000 0.001 2.441 0.000 Zone VMfr VType VOD Latch Port TRO Date Vlv Run Commenl CA SBK0-DF 1.0 BK 0.440 0 6/29/97 (1) Status Feet~PF Date Type Comment O 5 4 4/11/98 APERF O 5 4 4/11/98 APERF O 5 4 4/11/98 APERF O 5 4 4111198 APERF O 10 4 10/31/97 APERF O 10 4 10/31/97 APERF O 20 4 5~5~97 APERF O 15 4 1/15/97 IPERF O 20 4 5~5~97 APERF O 16 4 1/15/97 APERF O 8 4 1/15/97 IPERF O 190 4 1115197 APERF O 32 4 1/15/97 IPERF O 204 4 1/15/97 IPERF o Comment 02 2000 Alaska Oil & Gas Cons. C0mmi io Anch.0r e TREE: FMC Gen I - 5M L-80 WELLHEAD: FMC - 5M 13 3/8", 72 Cf/fi, MN-80 2,10B Proposed Completion 2715' I Liner Top at I +/-7650' I Window Milled from Whipstock Top of Window at +/- 7800' MD Bridge Plug set at +~-7820' MD 9-5/8", 47 Cf/fi, L80, BTC 18724' TOC at +/-8822' MD Top Perforation at +/-8922' MD GL Elevation = 30.2' Nabors 7ES RKB: 59.5' 4-1/2" 'X' Landing Nipple with 73.813" seal bore. I 2200' 4-1/2" x 1-1/2" Camco 'MMG' Gas Lift Mandrels with handling pups installed above and below. l i (or ljt above packer) GAS LIFT MANDRELS . Size Val_v__e T_ype 1-1/2" RP Shear 1-1/2" DV 1 - 1/2" DV 4-1/2" 12.6Cf L-80, IBT Mod Tubing 9-5/8" x 4 1/2" Baker'S' Production Packer ". @ -7500' MD 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" WireLine Entry Guide spaced-out into liner top. BAKER 9 5/8" x 7" ZXP Liner Top Packer 'Hydraulic Liner Hanger Horizontal Sidetrack into Zone 1 Sands ~ ,I PRUDHOE BAY UNIT WELL: 2-10B APl #: 50-029-20163-02 Date 5/1/00 Revised by JAS Comments proposed completion PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 01/21/99 RUN RECVD 96-179 96-179 96-179 96-179 96-179 96-179 96-179 MWD SRVY R 8679-9886 PB1 MWD SRVY R 8679-10375 MWD SRVY ~/Y 9085-10375- MWD SRVY ~'SPERRY 8679-9886 PB1 ~sP-MD ~8783-10375 NSP-TVO ~'~517-8909 SPERR SPERR FINAL FINAL 02/12/97 02/12/97 03/21/97 05/14/97 05/14/97 05/28/97 05/28/97 96-179 NGP-TVD ~'8717-8893 PB1 FINAL 05/28/97 96-179 NGP-MD ~8783-9885 PB1 96-179 8005 ~-3,6-9 SPERRY GR/ROP FINAL 05/28/97 06/20/97 96-179 96-179 96-179 8006 ~B-~-P E RRY GR/ROP PB1 GA~ LIFT-SPIN/ ~TEMP/PRES 3500-8300 ~,~ 10-407 - r 'CoMPLETIO DATE Are dry ditch samples required? yes ~~d received? ,, Was the well cored? yes ~ ~alysis & description received? Are well tests re~ired? yes n93~: Received? Well is in compliance ~-~ ZWftial CO~ENTS 1-3 06/20/97 FINAL 09/29/97 1 11/21/97 // ? ?/ ye s--~-~ ye~.no~.. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11584 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 11/2O/97 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL RF Sepia Disk Tape D.S. 2-10A 97520 TDTP ~Z:~' ~,,,/~c~ 970822 I I 1 D.S. 3-23 97519 TDTP "~'~ "':)~'_r~J"/~ ,~ 970824 1 I 1 D.S. 11-25 97507 TDTPBORAX 7~ ~;'/~G 970911 I I I SIGNED: _ DATE= ~ 0V ~- ! '~99'[ · ~ J · ,- ~' -, ~.,, . .., ~;,.~' ~ . Please sign ~nd return one copy of this transmittal to Sherrie ~t the ~bove eddress or f~x to (907) 562-652~.' Th~n~ou. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11362 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 9/22/~7 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL RF Sepia Disk Tape 70' o~Jo D.S, 2-05 PRODUCTION PROFILE 970820 I 1 D.S. 2-7 DEPTH DETERMINATION LOG 97071 0 I 1 D.S. 2-10A GAS LIFT SURVEY 970724 I 1 D.S. 4-18 PRODUCTION PROFILE 97081 3 I 1 D.S. 7-22 PRODUCTION PROFILE 97081 7 I 1 D.S. 7-25 PRODUCTION PROFILE 970704 I 1 D.S. 7'26 PRODUCTION PROFILE 97081 9 I 1 D.S. 9-01 PRODUCTION PROFILE W/DEFT 970807 I 1 D.S. 9-7 PRODUCTION PROFILE 970709 I 1 D.S. 11-13A PRODUCTION PROFILE 97082 0 I 1 D.S. 13-13 GAS LIFT SURVEY 970723 I 1 D.S. 14-07 PRODUCTION PROFILE W/DEFT 970827 I 1 D.S. 14-10 PRODUCTION PROFILE W/DEFT 97081 4 I 1 D.S. 14-20 PRODUCTION PROFILE W/DEFT 970705 I 1 D.S. 14-24 PRODUCTION PROFILE LOG 970702 I 1 D.S. 14-28 FULL SUITE PLW/PSP 97081 7 I 1 D.S. 14-28 DIGITAL ENTRY FLUID TOOL W/PSP 970817 I 1 D.S. 16-2 I llC.~ INJECTION PROFILE 970820 1 1 D.S. 17-14 PRODUCTION PROFILE 97081 6 I I -/8 .o~6 /'70 ~c~. 15o SIGNED: ~~ DATE: Please sign and return one copy of this transmittal to Sherrle at the above address or fax to (907) 562-6521. Thank ~EP 2 9 1997 .~daska Oil & Gas C,o~s. WELL LOG TRANSNHTTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 02-10A & 02-10A PB 1, June 25, 1997 AK-MW-60209 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Fan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 2 LDWG formatted Discs with verification listings. APl#: 50-029-20163-01 & 50-029-20163-70. 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company CI I~! I I_1_ I ~J G WELL LOG TRANSI~HTTAL To: State of Alaska May 28, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs D.S. 02-10A & 02-10APB1, AK-MW-60209 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Tan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DSO2-1OA: ~- l'~ 2" x 5" MD Gamma Ray Logs: 50-029-20163-01 2"x 5" TVD Gamma Ray Logs: 50-029-20163-01 DS 02-10A PBI: 2"x 5" MD Cramma Ray Logs: 50-029-20163-70 2"x 5" TVD Gamma Ray Logs: 50-029-20163-70 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Siiverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ri I~! I I_1_1 N G May 6, 1997 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data 2-10A, 2-10A PB 1 Dear Ms. Taylor: The distributed MWD surveys for this well had an error (Feb. 10, 1997). The Sub-Sea TVD and TVD were incorrect. Please destroy the previous data delivered and replace it with this corrected information (May 5, 1997). Enclosed is one hard copy of the above mentioned file(s). Well 2-10A MWD survey Tie-In point at 9,082.62', Window point at 9,095.00' and a Projected survey at 10,375.00'. Well 2-10A PB1 MWD survey Tie-In point at 8,679.00', Window point at 8,734.00' and a Projected survey at 9,886.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA AL~-,,_,KA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~ GAS 2 Name of Oper, ator 7 Permit Number ARCO Alaska, Inc 96-179 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20163-01 4 Location of well at surface i ~ '- 9 Unit or Lease Name ~ .... ~-:: '"'~ ~~ r PRUDHOE BAY UNIT 1039' FNL, 938' FWL, Sec 36, Tll N, R14E UM At Top Producing Interval 10 Well Number 102~4'FNL, 958'FWL, Sec36, TllN, R14E UM },/_~ '~:¢.,~, 2-10A 4926' FNL, 3874' FEL, Sec 25, TllN, R14E UM '- : - .... ' PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL 58' RKBI ADL 28308 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 12/27/96. 1/12/97. 1/16/97. N/A feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional SurveyJ'~ 120 Depth where SSSV set I 21 Thickness of permafrost 10375' MD / 8903' TVD 10293' MD / 8910' TVD YES ~ NO D 2219' feetMD 22 Type Electric or Other Logs Run MWD; GR. 23 CASING, LINER AND CEMENTING RECORD SE'FI-lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'rTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94 # H-40 Surf 100' 32" 500 Sx (approx) 13-3/8" 72 # MN-80 Surf 2715' 17-1/2" 6500 Sx Permafrost II 9-5/8" 47# SOO-95 Surf 8724' 12-1/4" 1500 Sx Class G & 150 Sx PF II & MN-80 2-7/8" 6.5# L-80 I 8195' 10360' 3-3/4" 30 Bbls 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) 9165 - 9180' MD (Zl); 8941 - 8942' TVD; at 4 spf. 5-1/2" 8195' 8170' 9198 - 9214' MD (Zl); 8941 - 8940' TVD; " 4-1/2" 8296' 9258 - 9266' MD (Zl); 8938 - 8937' TVD; " 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 9330 - 9520' MD (Zl); 8932-8915'TVD; " DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED 9658 - 9690' MD (Zl); 8918 - 8920' TVD; " N/A 9704 - 9908' MD (Zl); 8921 - 8919' TVD; " 9932 - 9960' MD (Zl); 8919 - 8919' TVD; " 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) N/A I Packoff Gas Lift Mandrel installation pending to initiate flow. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO N/A TEST PERIOD ¢ _ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. - 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. *Note: 2-1OA Coil Tubing Sidetrack Drilling Operations summary attached. * This 10-407 submitted as directed per 10-401 approved 11/18/96 (issued Permit # 96-179). Form 10-407 !.;,-,, '~u§'Fmt'm dutbkcate Rev. 7-i-80 ORIGINAL CONTINUED ON REVERSE SiDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 8473' 8472' N/A 31. LIST OF A'I-rACHMENTS Summary of 2-10A Coil Tubing Sidetrack Drilling Operations. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~, ' ~ Title Enqineerinq Supervisor Date ~- ,~.Z~ - ~"7 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 ORIGINAL 2-10A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING I 2/23/96: M IRU Nabors 3S. I 2/24/96: RU pipe shed. Loaded & strapped 2-7/8" pipe to shed. PT BOPS. Placed rig on standby. I 2/25/96: MU & RIH w/milling BHA. I 2/26/96: Tagged cement plug & milled a pilot hole from 8673' to 8724' MD. POOH w/BHA. I 2/27/96: RIH w/window milling BHA & began milling a window from 8724' through 9-5/8" casing to 8727' MD. 12/28/96: Milled window to 8729.5' MD. POOH w/BHA. RIH w/milling BHA & resumed window milling. I 2/29/96: Milled window to 8732' MD. POOH w/BHA. I 2/30/96' RIH w/finishing mill & completed window milling to 8735' MD, then continued drilling formation to 8780' MD. Backreamed window & circulated Hi-Vis sweep. 12/31/96: POOH & dropped BHA w/31 joints downhole. & POOH w/fish. RIH w/spear & latched fish at 7760' MD. Jarred fish free 1/1/97: Laid down fish. RDMO pipe shed. MIRU CTU. Circulated ball through CT. 1/2/97: MU & RIH w/milling BHA. Drilled 3.75" build section from 8780' to 8900' MD w/FIo-Pro. 1/3/97: Continued drilling to 8920' MD. to 9107' MD. POOH w/BHA. POOH w/BHA. RIH w/drilling BHA. Completed drilling build section RIH w/drilling BHA & continued drilling horizontally to 9260' MD. 1/4/97: Drilled to 9517' MD. POOH w/BHA. RIH w/drilling BHA & drilled through shales to 9700' MD. Backreamed tight hole sections w/periodic wiper trips to window. 1/$/97: Continued drilling shales to 9885' MD, then wiper tripped to 8600' MD. Reamed back downhole through tight spots to 9830' MD, but couldn't ream back to bottom. Saw increase in shaker shale & PU to 9400' above sloughing hole section. Made troughing passes from 9395' to 9410' MD & started an openhole sidetrack at 9410' MD. 1/6/97: Oriented & attempted to openhole sidetrack; couldn't kick off. POOH w/BHA. MU & RIH w/drilling BHA. 2-10A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING 1/7/97: Attempted openhole sidetrack at 9410' MD; couldn't kickoff. 9395' and 9410' MD. Made Iow side troughing passes between 1/8/97: Continued attempts for openhole sidetrack at 9410' MD; no success. RIH looking for sidetrack point; decided lower hole was to shaley for sidetrack. PU to 9090' MD, then oriented & started openhole sidetrack at 9095' MD. Drilled new 3.75" sidetrack build to 9191' MD. Backreamed & POOH w/BHA. 1/9/97: Tested BOP & cut/reheaded CT. RIH w/drilling BHA & drilled from 9191' to 9454' MD. 1/10/97: Continued drilling to 9872' MD. Displaced well to new FIo-Pro & made periodic shorf trips to sweep hole. I/1 I/97: Continued drilling to 10211' MD. 1/12/97: Drilled 10250' MD. POOH w/BHA. RIH w/drilling BHA & resumed drilling to 10375' MD. POOH. 1/13/97: RIH w/drilling BHA. Attempted to drill on from 10375' MD; could not make progress. TD well at 10375' MD. POOH w/BHA. MU & RIH w/2-7/8" blank liner assembly. Landed liner at 10360' MD. Released from liner. I/1 4/97: Circulated mud then pumped 30 bbls of 15.7 ppg Cement to set liner assembly from 8195' to 10360' MD. Bumped plug & POOH displacing well from FIo-Pro to Seawater. PT liner lap to 1500 psi; no pressure loss. PU & RIH w/perforation guns. 1/15/97: Shot initial perforation intervals at: 9165 - 9180' MD (Zl) 9198- 9214' MD (Zl) 9258 - 9266' MD (Z l) 9330 - 9520' MD (Z l) 9658- 9690' MD (Z l) 9704 - 9908' MD (Z1) 9932 - 9960' MD (Zl) Used 2-1/8" carriers & shot all pedorations at 4 spf at 180 degree phasing. POOH w/perf guns. ASF. 1/16/97: RIH w/nozzle & circulated CCH from 8000' w/Crude. RD CTU. ND BOPS. NU & PT tree. Released rig. Attempted to place the well on production. Packoff Gaslift Mandrel installation is pending to initiate flow. SPE .'-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC PBU / 2-10A 500292016301 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 5/97 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN DATE OF SURVEY: 011397 MWD SURVEY JOB NUMBER: AK-MW-60209 KELLY BUSHING ELEV. = 58.07 FT. OPERATOR: ARCO ALASKA INC COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9082.62 8991.61 8933.54 78 13 9095.00 8993.21 8935.14 86 56 9102.46 8993.82 8935.75 83 40 9140.59 8998.54 8940.47 82 5 9172.44 9000.96 8942.89 89 12 N 3.66 W .00 197.87N 41.61E 192.92 N 6.26 W 73.52 210.09N 40.55E 203.05 N 4.72 W 48.54 217.49N 39.84E 209.16 N 5.07 W 4.24 255.18N 36.61E 240.45 N 4.72 W 22.38 286.80N 33.90E 266.70 9200.42 9000.27 8942.20 93 35 9230.42 8998.20 8940.13 94 18 9262.34 8996.39 8938.32 92 11 9290.64 8994.96 8936.89 93 35 9319.47 8992.82 8934.75 94 55 N 3.31 W 16.48 314.70N 31.94E 290.07 N .68 W 9.06 344.61N 30.90E 315.64 N .20 E 7.16 376.47N 30.77E 343.36 N 5.30 E 18.67 404.69N 32.12E 368.64 N 8.46 E 11.85 433.23N 35.56E 395.21 9350.34 8990.05 8931.98 95 21 9381.59 8986.46 8928.39 97 49 9411.67 8982.85 8924.78 95 58 9439.29 8980.33 8922.26 94 28 9471.52 8977.39 8919.32 95 58 N 10.93 E 8.10 463.53N 40.74E 424.17 N 16.73 E 20.05 493.66N 48.15E 454.07 N 17.43 E 6.54 522.20N 56.92E 483.25 N 19.36 E 8.83 548.29N 65.60E 510.25 N 22.70 E 11.32 578.24N 77.12E 542.01 9505.79 8974.61 8916.54 93 20 9539.99 8973.38 8915.30 90 47 9578.37 8973.58 8915.51 88 35 9611.54 8974.43 8916.36 88 30 9659.27 8976.92 8918.85 85 31 N 25.16 E 10.51 609.46N 90.97E 576.01 N 25.16 E 7.46 640.39N 105.50E 610.09 N 26.75 E 7.07 674.89N 122.29E 648.40 N 32.72 E 17.99 703.67N 138.73E 681.54 N 29.56 E 9.09 744.46N 163.38E 729.17 9689.04 8979.17 8921.10 85 46 9721.59 8980.50 8922.43 89 33 9754.59 8980.60 8922.53 90 5 9784.89 8980.32 8922.25 90 58 9816.99 8979.36 8921.29 92 27 N 30.61 E 3.62 770.14N 178.26E 758.85 N 27.98 E 14.14 798.50N 194.16E 791.37 N 25.34 E 8.16 827.99N 208.97E 824.33 N 22.35 E 10.29 855.70N 221.22E 854.49 N 18.84 E 11.87 885.73N 232.50E 886.20 9844.64 8978.44 8920.37 91 19 9877.29 8977.87 8919.80 90 41 9907.52 8977.85 8919.78 89 22 9944.92 8978.37 8920.30 89 1 9972.17 8978.83 8920.76 89 1 N 17.25 E 7.07 912.00N 241.06E 913.30 N 18.84 E 5.23 943.03N 251.17E 945.31 N 23.24 E 15.21 971.24N 262.02E 975.22 N 20.94 E 6.22 1005.88N 276.08E 1012.31 N 20.77 E .62 1031.35N 285.78E 1039.26 10005.14 8979.14 8921.07 89 54 10033.59 8978.79 8920.72 91 29 10066.42 8977.81 8919.74 91 55 10095.87 8976.80 8918.73 92 1 10123.79 8975.83 8917.76 91 55 N 22.88 E 6.93 1061.94N 298.04E 1071.94 N 26.04 E 12.42 1087.84N 309.81E 1100.29 N 31.14 E 15.59 1116.64N 325.51E 1133.09 N 30.61 E 1.82 1141.90N 340.62E 1162.51 N 29.91 E 2.53 1166.00N 354.68E 1190.41 ORIGINAL SPE :-SUN DRILLING SERVICES ANCHOR3~GE ALASKA PAGE ARCO ALASKA INC PBU / 2-10A 5oo292o163o1 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 5/97 DATE OF SURVEY: 011397 MWD SURVEY JOB NUMBER: AK-MW-60209 KELLY BUSHING ELEV. = 58.07 OPEKATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10156.39 8974.81 8916.74 91 40 N 30.96 E 3.32 1194.10N 371.18E 10186.27 8973.76 8915.69 92 22 N 29.91 E 4.22 1219.84N 386.31E 10215.27 8972.40 8914.33 92 59 N 28.15 E 6.43 1245.17N 400.36E 10247.87 8971.03 8912.96 91 50 N 27.10 E 4.78 1274.02N 415.46E 10280.37 8969.93 8911.86 92 1 N 24.46 E 8.14 1303.27N 429.59E 1222.98 1252.84 1281.80 1314.36 1346.77 10310.22 8968.42 8910.35 93 46 N 22.70 E 8.33 1330.58N 441.51E 10340.32 8965.86 8907.79 95 58 N 24.10 E 8.65 1358.11N 453.42E 10357.04 8964.13 8906.06 95 53 N 25.70 E 9.53 1373.19N 460.42E 10375.00 8962.34 8904.27 95 35 N 25.20 E 3.21 1389.32N 468.10E 1376.43 1406.26 1422.84 1440.67 THE CALCULATION PROCEDURES A_RE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1466.06 FEET AT NORTH 18 DEG. 37 MIN. EAST AT MD = 10375 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 29.30 DEG. TIE-IN SURVEY AT 9,082.62' MD WINDOW POINT AT 9,095.00' MD PROJECTED SURVEY AT 10,375.00' MD SPE .'-SUN DRILLING SERVICES ANCHOR-AGE ALASKA PAGE 3 ARCO ALASKA INC PBU / 2-10A 500292016301 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 5/97 DATE OF SURVEY: 011397 JOB NUMBER: AK-MW-60209 KELLY BUSHING ELEV. = 58.07 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9082.62 10082.62 10375.00 8991.61 8933.54 8977.26 8919.19 8962.34 8904.27 197.87 N 41.61 E 91.01 1130.51 N 333.87 E 1105.36 1014.35 1389.32 N 468.10 E 1412.66 307.31 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA INC PBU / 2-10A 500292016301 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 5/97 DATE OF SURVEY: 011397 JOB NIIMBER: AK-MW-60209 KELLY BUSHING ELEV. = 58.07 FT. OPER3ATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9082.62 8991.61 8933.54 9122.62 8996.07 8938.00 197.87 N 41.61 E 91.01 237.45 N 38.18 E 126.55 35.54 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPE ARCO ALASKA INC PBU / 2-10APB1 500292016370 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 5/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 8679.00 8678.47 8620.40 8734.00 8733.45 8675.38 8771.92 8771.14 8713.07 8783.02 8782.05 8723.98 8798.59 8797.27 8739.20 8836.69 8834.03 8775.96 8861.94 8857.95 8799.88 8900.59 8893.41 8835.34 8931.22 8919.87 8861.80 8961.57 8943.27 8885.20 8979.12 8955.02 8896.95 9001.12 8967.74 8909.67 9027.67 8979.81 8921.74 9058.47 8988.88 8930.81 9082.62 8991.98 8933.91 9108.69 8991.60 8933.53 9117.37 8990.86 8932.79 9146.97 8988.52 8930.45 9174.94 8987.17 8929.10 9202.54 8986.45 8928.38 9235.79 8985.30 8927.23 9268.04 8983.37 8925.30 9300.99 8981.15 8923.08 9330.77 8979.85 8921.78 9362.42 8978.68 8920.61 9393.74 8977.36 8919.29 9422.59 8976.50 8918.43 9459.77 8975.82 8917.75 9492.69 8974.98 8916.91 9518.42 8973.88 8915.81 9550.27 8971.85 8913.78 9591.50 8968.75 8910.68 9621.07 8966.75 8908.68 9652.14 8964.94 8906.87 9680.57 8963.30 8905.23 '-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE DATE OF SURVEY: 010697 MWD SURVEY JOB NUMBER: AK-MW-60209 KELLY BUSHING ELEV. = 58.07 OPERATOR: ARCO ALASKA INC FT. COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 1 0 2 0 9 55 10 59 13 32 S 88.00 W .00 15.02N 25.30E N 37.04 W 2.99 15.77N 24.24E N 13.68 W 21.45 19.48N 23.07E N 11.75 W 10.06 21.45N 22.63E N 5.12 E 28.08 24.72N 22.49E 25.48 25.62 28.28 29.78 32.56 16 57 20 23 26 22 34 0 44 54 N 15.14 E 11.30 34.53N 24.34E N 18.13 E 14.10 42.27N 26.67E N 20.07~ E 15.60 56.74N 31.71E N 13.91 E 26.89 71.47N 36.12E N 8.82 E 37.44 90.36N 39.81E 42.02 49.91 65.00 80.00 98.28 5O 58 58 21 67 30 78 13 87 0 N 7.41 E 35.10 103.25N 41.64E N 4.77 E 34.94 121.09N 43.53E N .56 E 37.20 144.67N 44.59E N 3.66 W 37.18 174.04N 43.76E N 6.65 W 38.41 197.87N 41.61E 110.42 126.90 147.98 173.19 192.91 94 39 95 10 93 52 91 40 91 19 N 8.76 W 30.44 223.68N 38.11E N 8.24 W 8.45 232.23N 36.84E N 6.83 W 6.49 261.48N 32.97E N 5.95 W 8.47 289.24N 29.86E N 4.72 W 4.63 316.71N 27.29E 213.72 220.55 244.16 266.85 289.55 92 94 93 91 92 38 13 31 29 43 N 1.20 W 11.30 349.89N 25.58E N 2.84 E 13.43 382.07N 26.04E N 4.07 E 4.29 414.88N 28.02E N 6.00 E 9.40 444.51N 30.63E N 9.52 E 11.77 475.85N 34.90E 317.64 345.93 375.52 402.64 432.05 92 6 91 19 90 47 92 6 92 48 N 10.75 E 4.38 506.65N 40.41E N 12.16 E 5.60 534.91N 46.13E N 13.56 E 4.03 571.15N 54.40E N 15.67 E 7.56 602.99N 62.71E N 16.02 E 3.04 627.71N 69.73E 461.61 489.05 524.70 556.53 581.53 94 28 94 9 93 35 93 4 93 31 N 17.96 E 8.03 658.10N 79.01E N 19.40 E 3.57 697.05N 92.18E N 22.60 E 10.96 724.59N 102.75E N 23.41 E 3.09 753.14N 114.87E N 23.41 E 1.55 779.18N 126.15E 612.58 652.98 682.17 713.00 741.24 ..~ SPE~ -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC PBU / 2-10APB1 500292016370 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 5/97 DATE OF SURVEY: 010697 MWD SURVEY JOB NUMBER: AK-MW-60209 KELLY BUSHING ELEV. = 58.07 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9711.79 8961.38 8903.31 93 31 N 21.65 E 5.63 807.96N 138.09E 9744.64 8959.37 8901.30 93 31 N 19.19 E 7.47 838.68N 149.52E 9775.54 8957.38 8899.31 93 52 N 17.43 E 5.80 867.95N 159.21E 9804.32 8955.35 8897.28 94 13 N 15.67 E 6.22 895.47N 167.39E 9836.37 8953.33 8895.26 92 59 N 12.86 E 9.55 926.47N 175.27E 772.18 804.56 834.83 862.83 893.71 9857.12 8952.30 8894.23 92 43 N 11.80 E 5.26 946.71N 179.69E 9886.00 8950.93 8892.86 92 43 N 11.80 E .00 974.95N 185.59E 913.54 941.05 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 992.46 FEET AT NORTH 10 DEG. 46 MIN. EAST AT MD = 9886 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 29.30 DEG. TIE-IN SURVEY AT 8,679.00' MD WINDOW POINT AT 8,734.00' MD PROJECTED SURVEY AT 9,886.00' MD SPE}- -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC PBU / 2-10APB1 500292016370 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 5/97 DATE OF SURVEY: 010697 JOB NUMBER: AK-MW-60209 KELLY BUSHING ELEV. = 58.07 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8679.00 9679.00 9886.00 8678.47 8620.40 8963.40 8905.33 8950.93 8892.86 15.02 N 25.30 E .53 777.74 N 125.52 E 715.60 715.07 974.95 N 185.59 E 935.07 219.47 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPEt -SUN DRILLING SERVICES ANCHO~GE ALASKA PAGE ARCO ALASKA INC PBU / 2-10APB1 500292016370 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 5/97 DATE OF SURVEY: 010697 JOB NUMBER: AK-MW-60209 KELLY BUSHING ELEV. = 58.07 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8679.00 8678.47 8620.40 15.02 N 25.30 E .53 8758.71 8758.07 8700.00 17.60 N 23.56 E .64 .11 8862.10 8858.07 8800.00 42.38 N 26.72 E 4.03 3.39 8984.35 8958.07 8900.00 107.48 N 42.10 E 26.28 22.25 9019.00 8976.29 8918.22 136.75 N 44.42 E 42.71 16.43 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operati~'t~s performed: Operation Shutdown__ Stimulate Plugging__ Perforate_X Pull tubing__ Alter casing __ Repair well__ Other_X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 58' RKB 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorace, AK 995100360 Service__ Prudhoe Bay Unit .. 4. Location of well at surface: 8. Well number: 1039' FNL, 938' FWL, Sec 36, T11N, R14E, UM. 2-10A Attop of productive interval: 9. Permit number/approval number: 1024' FNL, 958' FWL, Sec 36, TllN, R14E, UM. 96-179 At effective depth: 10. APl number: 50-029-20163-01 At total depth: 11. Field/Pool: 4926' FNL~ 3874' FEL, Sec 25, T1t N, RI4E, UM. Prudhoe Bay Oil Pool 12. Present wel! condition summary Total Depth: measured 10375 feet Plugs (measured) CIBP Set at 9298' MD (4/27/97). true vertical 8903 feet Effective Depth: true measured vertical 8993 9298 feet feet Junk(measured) ORIGINAL Casing Length Size Cemented Measured depth True vertical depth Conductor t00' 20" 500 Sx (approx) 100' 100' Surface 2657' 13-3/8" 65CX) Sx Permafrost II 2715' 2715' Production 8666' 9-518" 1500 Sx CIG & 8724' 8724' 125 S× PF II Liner 2165' 2-7/8" 30 Bbls CIG 10360' 8964' Perforation Depth measured 8990 - 9010'; 9133 - 9153'; 9165 - 9180'; 9193 - 9214'; 9258 - 9266'; [Isolated below Bridge Plug: 9330 - 9520'; 9658 - 9690'; 9704 - 9908'; 9932 - 9960'] true vertical 8904 - 8914'; 8939 - 8941 '; 8941 - 8942'; 8941 - 8940'; 8938 - 8937'; [Isolated below Bddge Plug: 8932 - 8915'; 8918 - 8920'; 8921 - 8919'; 8919 - 8919'] Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 8195' MD; 4-1/2", 12.6#, N-80, NPCT @ 8296' MD. .. .,' . iPackers and SSSV (type and measured depth) Baker SAB Packer @ 8170' MD; Otis RQ SSSV @ 2219' MD. , /-. ' ' ', 13. Stimulation or cement squeeze summary : ,, .,. v. Intervals treated (measured) see attached , · ',L' Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data Oit-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 Subsequent to operation 1066 61 0 241 15: AEachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily' Report of Well Operations _X Oil _X Gas __ Suspended __ Service __ t 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~ '~1~. ~ Titte: Engineering Supervisor Date //"¢-¢7 Form 10-404 Rev 06/!-5/88 SUBMIT IN DUPLICATE 2-10A DESCRIPTION OF WORK COMPLETED POGLM & CIBP INSTALLATIONS, PERFORATING, & HYDRAULIC FRACTURE TREATMENT 3/8/97: RIH w/tubing puncher & punched 5 holes in the 5-1/2" tubing at 8024 - 8026' MD for POGLM. 3/10/97: RIH w/AVA DWP POGLM & set across the circulation holes at 8020 - 8035' MD (seal to seal). POOH. MITIA to 1500 psi; passed. Rigged down. 4/27/97: MIRU CTU & PT equipment. RIH w/HES CIBP & set in the 2-7/8" liner at 9298' MD (top), to isolate the lower open perforation intervals located at: 9330 - 9520' MD (Z1) 9658 - 9690' MD (Z1) 9704 - 9908' MD (Z1) 9932 - 9960' MD (Z1) 4/29/97: Attempted a Hydraulic Fracture Treatment as follows: MIRU & PT equipment to 8300 psi. Pumped Pre Frac Breakdown & Scour stage fluids through the open perforation intervals located above the CIBP at: 9165- 9180' MD (Z1) 9198- 9214' MD (Zl) 9258- 9266' MD (Z1) Pumped Breakdown: a) 250 bbls 20# Pre Pad Gel @ 25 bpm, followed by b) Shutdown. ISIP @ 2200. Pumped Datafrac: c) 123 bbls 30# Crosslinked Gel @ 25 bpm, followed by d) 50 bbls 20# Flush @ 5 bpm, followed by e) 142 bbls 20# Flush @ 25 bpm, followed by f) Shutdown. Pumped Scour: g) 50 bbls 30# Crosslinked Scour w/2 ppg proppant @ 25 bpm, followed by h) WB Flush volume. Prepared to pump 40# Frac Pad. Well locked up. Shutdown. Bled down well. RD. 4/30/97: RIH w/CT & jetted a proppant fill cleanout w/biozan to top of CIBP. 5/4/97: Added perforations: 9133- 9153' MD (Z1) 9193 - 9198' MD (Zl) Reperforated: 9198- 9213' MD (Zl) 2-10A DESCRIPTION OF WORK COMPLETED POGLM & ClBP INSTALLATIONS, ADD PERFS, & HYDRAULIC FRACTURE TREATMENT 5/6/97: Pumped a Hydraulic Fracture Treatment as follows: MIRU & PT equipment to 9300 psi. Pumped Fracture treatment using 20/40 mesh proppant through the open perforation intervals located above the ClBP (listed above). Pumped Breakdown: a) 250 bbls Pre Pad @ 25 bpm, followed by b) Shutdown. ISIP @ 2500. Resumed pumping Datafrac: c) 142 bbls Crosslinked 40# Gel @ 5 - 25 bpm, followed by d) Shutdown. ISIP @ 2746. Resumed pumping Fracture Treatment: e) 36 bbls Crosslinked Pad @ 25 bpm, followed by f) 218 bbls Crosslinked Slurry w/proppant in 2 to 12 ppg stages, followed by g) 192 bbls 20# Flush @ 20 - 25 bpm, followed by h) Shutdown. Placed a total of 47,561 lbs of proppant into the formation. Rigged down. 5/7/97: RIH w/CT & jetted a proppant fill cleanout w/biozan to ClBP at 9298' MD. 5/22/97: RIH w/puncher & punched 7 holes in the 5-1/2" tubing at 4311 - 4312.5' MD for POGLM. w/AVA DWP POGLM & set across circulation holes at 4306 - 4316.5' MD (seal to seal). POOH. POOH. RIH RD. 10/12/97: MIRU & PT equipment. Pumped a Fullbore Frac Gel Residue Breaker Treatment through the open perforation intervals located above the ClBP (listed above). Pumped 80 bbls of EZ Clean Mix w/injected N2 at 1 - 1.5 bpm, followed by 35 bbls KCl Water Flush, followed by 140 bbls Crude Flush, followed by 20 bbls Diesel, followed by Shutdown. Shut in well. Rigged down. 10/31/97: RIH w/perforation guns & shot 20' of perforations as follows: Added Perforations: 8990 - 9010' MD Used a 1-11/16" carrier & shot the perfs at 4 spf at zero degree phasing at balanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/lift gas & obtained a valid welltest. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown__ Stimulate__ Plugging __ Perforate_X Pull tubing__ Alter casing __ ~ (, Repair well __ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feat): ARCO Alaska, Inc. Development_X 58' RKB 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ iAnchora~te, AK 99510-0360 Ser~ce__ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1039' FNL, 938' FWL, Sec 36, T11N, R14E, UM. 2-10A At top of productive interval: 9. Permit numbedapproval number: 1024' FNL, 958' FWL, Sec 36, T11N, R14E, UM. 96-179 At effective depth: 10. APl number: 50-029-20163-01 Attotal depth: 11. Field/Pool: 4926' FNL, 3874' FEL, Sec 25, T11 N, R14E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 10375 feet Plugs (measured) CIBP Set at 9298' MD (4/27/97), true vertical 8903 feet Effective Depth: measured 9298 feet Junk (measured) true vertical 8993 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 10(7 2(7' 500 Sx (approx) 10(7 10(7 Surface 2657' 13-3t8" 6500 Sx Permafrost II 2715' 2715' Production 8666' 9-5/8" 1500 Sx CIG & 8724' 8724' 125 Sx PF II Liner 2165' 2-7/8" 30 Bbls Cl G 10360' 8964' Perforation Depth measured [Isolated below IBP: 8922 - 8927'; 8931 - 8936'; 8944 - 8949'; 8957 - 8962'; 8~- 9010'; 9133- 9153'; 9165- 9180'; 9~93- 9214'; 9258- 9266'] [Isolated below CIBP: 9330 - 9520'; 9658 - 9690'; 9704 - 9908'; 9932 - 996(7] 8904 - 8914'; 8939 - 894~ ': 8941 ~ 8942'; 8941 - 8940': 8938 - 8937'] [Isolated below CIBP: 8932 - 8915'; 8918 - 8920'; 8921 - 8919'; 8919 - 8919'] 'UCbo.. Tubing (size, grade, and measured depth)5-1/2", 17#, N-80, NPCT @ 8195' MD; 4-1/2", 12.6#, N-80, NPOT @ 8296' MD. .... Packers and SSSV (type and measured depth) Baker SAB Packer @ 817(7 MD; Otis RQ SSSV @ 2219' MD. ..~ 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 881 7725 0 - 238 Subsequent to operation Shut In - - 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations _X Oil _X Gas M Suspended __ Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. --- Title: Engineering Supervisor Date Form 10-404 Rev 061¢15/88 SUBMIT IN DUPLICATE~.~ 2-10A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 2/13/98 - 2/15/98: MIRU CTU & PT equipment. RIH w/milling BHA to CIBP set in the 2-7/8" liner at 9298' MD (set 4/27/97). Attempted to mill out the CIBP. Milled down to top slips of CIBP, then stalled & stuck the BHA. POOH w/stuck BHA. RIH w/milling BHA to resume milling. Stuck BHA again. Suspected milled slips & cast iron junk resulted in stuck BHA. Fished & POOH w/BHA leaving most of the CIBP still set in place. RD. 4/11/98: MIRU & PT equipment. RIH w/perforating guns & shot 20' of perforations as follows: Added perforations: 8922-8927' MD 8931 -8936' MD 8944- 8949' MD 8957-8962' MD Used 1-11/16" carriers & shot all perfs at 4 spf at 0 degree phasing. POOH w/guns. ASF. RD. 4/16/98: RIH & set an inflatable bridge plug in the 2-7/8" liner at 8220' MD. The well is Shut In. IA x OA communication problems are being evaluated. [::l I:t ICI-- I N G SI~Ft~JI C E S February 11, 1997 AOGCC Lori Taylor 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 2-10A Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 2-10A MWD survey Tie-In point at 8,679.00', Window Point at 9,095.00' and a Projected survey at 10,375.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company February 11, 1997 AOGCC Loft Taylor 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 2-10A PB 1 Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 2-10A PB1 MWD survey Tie-In point at 8,679.00', Window Point at 8,734.00' and a Projected survey at 9,886.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. !" L'.. 'i /5 " : 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company MEMORANDUM State of Alaska TO: David J o h Q~i~ Chairman Alaska Oil and Gas Conservation Commission DATE: January 12, 1997 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor GE8JAKEE.DOC ¢'.,, SUBJECT: Gas Detector's Nabors 3ES FROM: Lou Grimaldi, Petroleum Inspector Sunday, January 12, 1997; This is a follow-up on Chuck Scheve's (A.O.G.C.C.P.I.) report on the problem's with Nabor's rig #3ES gas detection system. Chuck had found problems with this system during a routine witnessed BOPE test (see AE9KAIEE.DOC/XLS) on January 9 1997 and had given the rig some leeway in the form of a few hours to get personnel to the rig to bring these systems into compliance. A problem with one of our trucks necessitated my doing a follow-up on this job. I stopped by the rig on my way to a plug verification on another well in the other end of the field. I arrived at the rig on 1/11/97 at 0830 hours which was approximately 48 hours after Chuck witnessed the above mentioned BOP test. I spoke with Jeff Hupp (Arco rep.) who informed me that he thought the gas detection systems were repaired but advised me to speak to the rig personnel to confirm this. I went to the cellar and found the H2S detector that Chuck had found during the BOP test disabled had been replaced and was in its burn-in cycle. I went up to the rig floor and spoke with the rig rep. who informed me that although a electrician had worked late into the previous evening the gas detectors had still not been completely calibrated or tested. I informed him that they were not in compliance and had exceeded the allowed time for repairs given by Chuck. I informed Jeff Hupp that I had another rig waiting on me and would return within four hours to check on their progress, if the system was not up and running I would require well workover operations to be stopped. I returned to the rig at approximately 1300 hrs. I found the rig electrician just finishing his checks on the methane detectors. I was told that the new H2S sensor in the cellar could not be accurately calibrated until 24 hrs. after installation but should be fairly accurate being that it was the new type known as the "Smart sensor". I had the electrician take the H2S sample gas and start testing the system. The detector in the 'cellar was close enough that I felt confident it would provide more than adequate protection. The other three stations failed their test and it was obvious that these sensors in all probability would have to be changed. GE8JAKEE.DOC page 1 of 2 MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission David Joh~s~i? DATE: January 9, 1997 Chairman THRU' BlairWondzell, ~ FILE NO: P. i. Supervisor ,[t~ ae9kaiee.doc FROM' ChuckScheve; ~ ~ SUBJECT: Petroleum Inspector CTU -BOPE Test Nabors 3S PBU DS 2-10 ~ PT~~-''- ~(¢-- (-~ c./, Thursday January 9, 1997: I traveled to ARCO's DS 2-10 Well and witnessed the BOPE test on the Dowell CTU rigged up on the Nabors 3S Rig. As the attached AOGCC BOPE Test report shows there were 2 failures. The gas detection systems had not been calibrated since 11-10-96 ( two months ) and couldn't be tested at this time because of a lack of test gas. The H2S detector in the cellar was disabled. I was told that personnel would be on location this afternoon to perform the calibrations and I requested a call to allow witness of these calibrations and tests. Friday January 10, 1997: Not having heard from the rig I traveled back to Nabors Rig 3S to check the status of the gas detectors. ! was informed that the personnel that was to do the calibrations and repairs had been detained on another rig but would be there this date. Saturday January 11, 1997: Due to one truck being down Lou Grimaldi went to the rig to check on the gas detectors. Reference Lou's report ge8jakee. The gas detection system on this rig does not receive the maintenance required to ensure reliable operation. This rig does not have the personnel qualified to calibrate or repair the gas detectors, instead they rely on people from other rigs who have other priorities. Summary: i witnessed the BOPE test on ARCOs DS 2-10A being drilled by Doweli/Nabors rig 3S test time 3.5 hours :2 Failures. Attachment: ae9kaiee.xls cc Bruce Smith STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION ,Coil Tubin_g Unit BOP____E ?est Report OPERATION: Drlg: X Workover: Drlg Contractor: Nabors/Doweli Rig No. Operator: Arco Well Name: 2-10A Casing Size: 5 I/2 Set @ 8,278 Test: Initial Weekly x Other 3ES PTD # Rep.: Rig Rep.: Location: Sec. DATE: 1/9/97 96-79 Rig Ph.# 448-1334 Jeff Hupp Roger Smith 36 T. 11N R. 14E Meridian UM BOP STACK: Coil Tubinq Unit: Pipe/Slip Rams Pipe/Slip Rams Blind Rams Reel Isolation Valve Deployment: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Test Test Quan. Pressure P~ Pressure P/F 250-350(; P 250-3500 P 250-3500 P 250-3500 P 250-3500 P 250-2500 I 250-3500 I 250-3500 2!250-3500 p. CHOKE MANIFOLD: Quan. No. Valves 13 No. Flanges Manual Chokes Hydraulic Chokes 1 26 250-350C P 1 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Bti's: Functioned Functioned P 2800I 2300 minutes 15 I minutes 15 Yes Remote: 4 ~, 2000 average Psig. MUD SYSTEM: '~=ual Alarm MISC. INSPECTIONS: Trip Tank Location Gen.: OK Pit Level Indicators Housekeeping: OK Meth Gas Detector 4 F Permit to ddll: YES H2S Gas Detector 4 F Standing Order Posted YES sec. sec. Yes Well Sign Drl. Rig OK Hazard Sec. YES Number of Failures: 2 ,Test Time: 3.5 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within I days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: H2S detector in cellar defeated,last callibration 11-10-g6, no test gas on location. Distribution: odg-Weil File c- Oper./Rig c - Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: W'rtnessed By: Chuck Scheve Form Revised 116/97 DA. ctboptst ._r TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 18, 1996 Erin M. Oba Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Prudhoe Bay Unit 2-10A ARCO Alaska, Inc. Permit No. 96-179 Sur. Loc. 1039'FNL, 938'FWL, Sec. 361 T11N, R14E, UM Btmnhole Loc. 4751'FNL, 3543'FEL, Sec. 25, T11N, R14E, UM Dear Ms. Oba: Encloscd is the approved application for permit to redrill the above refcrcnccd well. Thc pcrmit to redrill docs not cxempt you from obtaining additional pcnnits rcquircd by laxv from other govcrmncntal agcncies, and does not authorizc conducting drilling opcrations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling nexv hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures cc; Department of Fish & Game, Habitat Section w/o encl. Department of Enviro~m~ental Conservation w/o encl. STATE OF ALASKA ALAdKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill M Redrill X lb. Type of Well Exploratory__ Stratigraphic Test _ Development Oil Re-EntryM Deepen _ Service _ Development Gas __ Single Zone x__ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 58' 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28308 Prudhoe Ba¥/Prudhoe Bay Oil 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1039' FNL, 938' FWL, Sec 36, T11N, R14E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1024' FNL, 958' F-WL, Sec 36, TllN, R14E, UM. 2-10A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 4751' FNL, 3543' FEL, Sec 25, T11N, R14E, UM. October 7, 1996 $2O0,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) property line No Close Approach 10695' MD / 8968' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 8450' MD Maximum hole angle 94° Maximum surface 3000 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4 LB0 FL4S 2500' 8210' 8209' 10695' 8968 25 bbls , 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9110 feet Plugs(measured) PBTD tagged at 8965 MD (9/2/96). true vertical 9109 feet Effective depth: measured 8965 feet Junk (measured) true vertical 8964 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 100' 20" 500 Sx (approx) 100' 100' Surface 2657' 1 3-3/8" 6500 Sx PF II. 271 5' 2715' Production 9037' 9-5/8" 1500 Sx CIG & 150 Sx PF II 9095' 9094' Perforation depth: measured 8951 - 8960'; 8966 - 8974'; 9000 - 9010' true vertical 8950 - 8959'; 8965 - 8973'; 8999 - 9009' 20. Attachments Filing fee ~ Property plat __ BOP Sketch ~ Diverter Sketch _ Drilling program Drilling fluid program m Time vs depth plot_ Refraction analysis M Seabed report _20 AAC 25.050 requirements · 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~. ~i~I~,..5 '~ ~,~.{ . signed % , Titlle Engineering Supervisor Date :' Commission Use Onl~/ .Perm~N~mbe~/ I APl number I Approval date ~1 See cover letter for ,~p 50-O,Z,~-, ,,;~..-O//,~"',.~- <:3 ! ! / ,-' / ~ -'~' other require~l~.,.rs.~'-' Conditions of approval Samples required ._.Y e s ,~ N o Mud Icg requi~e~l~ Y e s ~ N o Hydrogen sulfide measures ~ Y e s N o Directional survey required ~ Yes N o Required working pressure for BOPE 2M; 3 M ' 5 M ' I 0 M; I 5 M~T~ 3500 p~it for CTU ..... r~'., ~ D "~/ :I::)¥ b"' o Other:-- '~' ....ririninni~gr;e(~-"' · ¢).. '" L~;'.vld W. Johnston by order of--.~ Approved by Form 10-401 Rev. 7-24-89 '¢Lu~'ii l'n triplica DS 2-10A CT Sidetrack and Completion Intended Procedure Objective' Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 2-7/8" cemented liner. Intended Procedure: Cement squeeze the current perforations and plugback the existing completion to ~ 8420' md. Mill window in 9-5/8" casing at--8450' md. Drill 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight ( 8.9 ppg Flo Pro as drilling fluid). Directionally drill 3-3/4" x 2000' horizontal well to access Zone lB reserves. Build angle to ~94°. · Run and cement 2-7/8" liner to TD. · Perforate selected intervals. · Return well to production. September 26, 1996 DS 2-10A PROPOSED CTD COMPLETION 5-1/2" Tubing 2219' 5-1/2" Otis RQ SSSV Nipple (4.562" ID) 5-1/2" Otis Sliding Sleeve 8078' 5-1/2" Otis XN 8106' 9-5/8" Baker SAB Pkr. 8170' 4-1/2" Otis 'X', 8232' 3.813" ID 4-1/2" Tubing tail 8296' 4-1/2" GS FN on top of liner @ +8210' Window Cut in 9-5/8" casing with CT. ~ 8450' - 8455' 3-3/4" Open hole Original perforations cement sqz'd. 2-7/8" FL4S liner TD @ +_ 10700' 9-5/8" Casing Shoe @ 9095' Sent Dy: F~CU 2;:L--× A~ASKA gO7 552 4452 Cg,,'25,'g6 !_4:36 Job :58 Page 2 I 2-10svv _~'25:g6 3 2', PM ARCO 2-10 A $;OEI'J~,CK ~ I~I~,EPAI~ED FOR $TE'V'E WARD'{PE~-~RCO~*sEPT.2$~-~6 V~RTICAL SECTI~)I~I USED .29.34" RELAT:VE TO TRUE NORTH : ;RKB ~OTE i 83B7.0J 1.0: ' 58.07' RKB · PJS & E,%' REL TO'TRUE NORTH; ASP C, OORD A~ REL. TO GRID NORTH ~, '" . · , . · . m~ ~ ~ VS. ~i ~.W 8~: Turn ~, ASP Y~ A~ X Com~t~ .............. ~ _ ~: ~ ~ ~ ~. ~1~: d~ ~l~ ft. ft ~--~~ ......... 0.¢: '~ '~ ~.2; 00: o.0 0_0:5~79.5 68~.8-~. T~EIN~Y ............... 8670.0: 5.3 347 "' '87oo.o; 8.3 ~ s~ 8740.0 7 8 *~ 5: 87go.o J ' 7.8 I 5 . ..~ 88~'D,0! 23 8~ I 5 ~784.1J 39.0: ~3~' 00 59501~.5:687720.7 ...... : .................... oz '6~-~9Y~.'~' ~7mo.:. ~ 8880.0~ 356- ~O~ 47.6 I 51 ~.2j a~.?: 8970.0' ~.6 ~.0~ ~.8 ~0: 656 ~.0~ 71.6 "~' ...... ~.~ '9i~.0~ ' ~s: ....... s~.OI 2~.5 9180.0; or" 5950179.51' -i.5i -2.31 - .~ a' -3.Oi '~7: 3.1 2.5 '6.8~ 21.1; 1 0' ~.0 ~O 59.~181 0 ~1.11 -1 3: '3-?' 20 1; 2.1- 47.~- --~-~- ~.0~ ~11_0~ 06; 2! ~- '~.3~ 2.7 M.4 ~.O ~185.5~ ~~.8~ ~0~ ' -24.3' :8.81 3.1 24~67 4.0: ~sJ 73 ~' ~e.71 3.5' ~47:, 4.0 ~ig~.0 t' ~.2j ~o.3 ~= De.s] =o.o~ o al ~0.0 ~e6.5~ ~.3j 172- ~a- 19.01 20.0. C.Di 20.0 ~4.0J ~a.~t ~00 a OF-~O.O ~,~ 20.0 ~.~! '~'~- ~e.0 ~;.51 ~.0 'bL3~ ~0.0' ~.0~ 2t.0~ ~O0'' ~b~ "~55 5~.0. ~:.61 20,0 0.0' ~o. ' 5~7.O: 2;_3~ 20.0: o.u: ~u.u .... ~ - _. · . ................... 23.7J 20.0 0.~ 20 O 5~7.0~ ~4.4~ 20.0 0.31 2~.2 20.0~ O.OI 2~ o ~.5 25.91 20.0;. . 5.0i' ~.~ ~75.0 ~.~ ....~p.o~. o.o~ mo 6B7719.6, i ................... I - 68.'/718 6 §8771{~ ~ 3. D~III TGT. FOR 2'20' ~8T'/'14 8 687713 1 68,'r71, 6 687710 5 687709.7 ............. 687709.~ ~ 6877~.S, 607708..~ 4. BUILD AND ~ 687708.9 ' 68~.~ ...................... "6S..~oa.~, 68770,8,.g: ................. 6877'08.g. ..... ......... 687708 9. ·., 68770g.0 687709.0 6~770g. 1 657709 '~- 6,E,770,G. 't "~ ................. 6~7709 s 'T-' .................. 6,5770~.I r ' ~877~.1:5. ~ .... , 4 5 5950535.0 4 5 5950585.0 4.5 5950S~.0 "4 5 5950625.0 4.5 4_5 5950684.51 4 5 5950714.0; 4.5 5950743.5i ,5 687710.5: ' ~i'77'~ 2.3' 687717.~! 687721.6: 68/-726.1: 68773!.4. 687737.3: Se-~ :y: ::CM 0RI,£× ALASKA 937 562 4452 Cg/25/g6J''37 ~;2 458 :ace 3'4 * ;Os~ 9/25G6 .3.2' pM ~-~; .... ~.8 28.11 ~,O~ 7328 7~2 128.61' 0_0 ~] ~.5~ ~.0~ ~7r~.~!~['OE~IBIM - ~ ~3 24.3; 8~.9~ 7~7 ~2.4; '-1~ ~.0 2.2{' 2.41 ~.5~ ~7~.3 .... ~-~ -~-~;. ~4,e~ ~.Z' 815 7 , ~7;: 'm ' 1~'7: 1.0 2.:[ ....... ~:Z'F~--~imT.5'_ ............... ~.~ ..... .... . _ - .; ........... g~o= ~g~ 25.6' ~ ~.71 ~a 1755' ~ 0 2 2: 2.4 ~1~.5 ~7~4..~ g~.ol 9~ 21 262 ~sa 8~.6i g~3 a, 1~.6: ~.0 22: 2.4'---~,0 ~7~.6 ~0_0: 51;5~ 269. ~8.1 ~.~i ~.6 2~.0'-- 1.0 22. J7~'~1~.0 ~7~4. "- .... ~0: 91.7: 27.~ ~.3 ~6~ ~7.~' 215.7' 1.0 22 2.4 ~11~.0 ~7~2.4 ......... ~- ~_0 282~ ~B.3i ~6~ ~.8; '~g. 7 1;0~" 2~' 2.4 ~11~.b- ~7~.8: ;'- ~ '' ~ ¢~:oi .......... ~ , --- ~0 ~.3 ~ ~.6' ~0~! 1.~' 2.2. . ...~ .... 9~0.01 ~2_S 29,5i 8~23.9 10255 ;~.3! 25S.51 ~ ci 2,2 ~0J ;2~; ~' ~.4 1~.4 'C72.31 "273.51 ~ C: 2.2 ~0i- - 9321 ~.8~ ~D.9 1~3 ~8.~i 288:7~' 1 C- 22 ~bT' ;~71 32.1 8~7.3' ~.~ ~140~ 3~.0J ~.O 2.2 1~0~ ~0- ~.8. 8~15.21 1174 7' -~1245. ~.0; 0.~ 2.2 I~.4: ~1- ~.9~ ~14 g: 11~1 '!781; ~3&4i 0.9 ~.~' .. _ 10!~_0 ;3 4 ~.9: 8911.3' 12~ 0 12~ g ~.7: -{~ - 5.~. . 1~1~.0 ~.1 ~7.~ ~.5~ ~.4 -IZ479; ~7.7 10~.0 ~ 7 ~.3: 8~.0~ 1~.7~ 12714 ' 1~.0 ~.4 ~.9~ ~.?' ~ s. ~3~' 4~.B' 2.4j 595'12'165i §8,'r92"'3.4i .... 2.4l 5~5"m~2.si ~s7'~7.ei ....... .. '" ~41 5~s1~2o.~ ~.~! ' i 2 4: 5,"'~,'m3,~ si e8/997.~1 ......... ; ............... 2.4! 595;1::)50.0i 5879<719.817., MIDPOINT 5.5; 57 5951491.0i 6~81D3.5~ 5.5! "5.?'i 5g~1513.5. t~B12~3.6; : s.5'; ..... 5.7 ~o34.o 5.5! S.7' 5g6~ 6~2,0 688280.9 551 5.7' - ~)4,51 s~lg.o 5.5i 5.7 ~1~.5 ~.7. 5.5~ 5.7 ~1~1.0 ~.3, . . DR/IX AilCO A~ INC. 2-10 IDIR~C"IIOtIkl ~IIDE1RA,CK PHLIDHO~ EI~¥ I I II I I III I II NORTH REL. TO -RUE N. :T'r.J~(,Ol Mall ..,. iiillllll I 1600 810,0 8500- ~ " 8700 .... J I , 8900 : ~ ,~oo_--I 2d0ORTR ~~ 1200---I " 600 " ,., I'" Vertical Section Scale I inch ' 200 ft Departure Scale I inch ' 600 ~ 8 PLANE OF VERT SECTn 26.35° REL. TO TRUE NORTH I--4 ..' 'D d~ C T Drilling Wellhead Detail ~ CT Injector Head Meth&nc~ Injection Oti~ 7" ~ Quick Connect Alignment Guide Flang~ 7-1/16', 5M Ram Type DuaJ ~' ~l~l~J Gate BOPE FI~ Fire Resistant ManuaJ Valve Kelly Hose To Dual \ Cho'~M~.,to~ \ \ ~ Stuffing Box (Pack-Off), 10,000 psi Wc~dng Pressure i 5.000 psi worldng pressure I ,iT c._29, (3.$.) Cutters or Combination Cutter/Blinds Slip/Pipe rams Manual Valves Drilling spoo~ 7-1/16', 5M by 7-1/16'. 5M ,Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16' ID with Pipe/Slip Rams 0.4,58' ($.$') Manua~ Master Valve 2' Pump-In ~Tubing Hanger 9-5/8" Annulus 13-3/8' Annulus Fire Resistant Kelly Hose to Flange by Hammer Up 1/4 Turn Valve on DS Hardline 10' from Tree 60~40 I Trplx I ! Shop Fuel Boller,~ Water Mud Pump Room Pipe rack Ext. Ext, Preferred Major Equipment Layout for CT Drilling in DS 2-10A Dowell Drilling Equipment Trailer ....... ,~...-,L AND GAS CONSERVATION CC APPLIC¢ _'ION FOR SUNDRY Ar- ,, ,- OVALS 1. Type of Request: A~n X~ Suspena-- Opera,on s~utaown __ Alter ca~ing Repair well Pluggir'4j X Change approved program Pull tubing Variance 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Exploratory, Slra[~jrapt~c Serwce 4. Location of well at surface 1039' FNL, 938' FVVL Sec 36, T11 N, R 14E, UM. At top of productive interval 1024' FNL, 958' FWL, Sec 36, T11 N, R 14E, UM. At effective depth At total depth 1024' FNL, 958' FWL, Sec 36, T11N, R14E, UM. Re-enter suspencle~3 well Time extension Stimulate Per/orate Other 6. Datum of elevation(DF or KB) 58' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 2-10 9. Permit number -75-31 10. APl number 50 - 029-20163 11. FielOPool ' Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9110 feet 9109 feet Effective depth: measured 8965 feet true vertical 8964 feet Casing Length Plugs(measured) Fill Tagged at 8965' MD (9/2/96). Junk(measured, ORiGiNAL Size Cemented Measured depth True vertical depth Conductor 100' Surface 2657' Production 9037' Perforation depth: 20" 500 Sx (approx) 13-3/8" 6500 Sx PF II 9-5/8" 1500 Sx Ci G & 150 Sx PF II measured 8951 - 8960'; 8966 - 8974'; 9000 - 9010' 100' 100' 2715' 2715' R EiVED SEP 2 6 1996 Alaska 011 & (~a6 Cons. Commission true vertical 8950 - 8959': 8965 - 8973'; 8999 - 9009' Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 8195' MD; 4-1/2% 12.6¢¢, N-80, PCT @ 8296' MD. Packers and SSSV (type and measured depth) BaJ<er SAD Packer @ 8170' MD; Otis RQY SSSV @ 2219' MD. '13. Attachments Description summary of pr .oposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation September 30, 1996 ' 16. If proposal was verbally approved Name of aDprover Date aDOroved 15. Status of well classification as: Oil X Gas..._ Suspended Service 17. I hereby certify that the foregoing is true and correct .*o the best of my knowledge. Signed '~_,,/.~ '~. ~ T'rtle Engineering Supervisor FOR COMMI~;~;IQN U~;E ONLY Conditions of approval: Notify.Commission so representative may witness Plug integrity 4,"' BOP Test t.,"/ Location clearance Mechanical Integrity Test Subsequent form required 10- /,(0'7' ADproyed by order of the Commissioner Form 10403 Rev 06/15/88 Original Signea u~ David W. Johnston SLW cc: JWP. Approv~~ioner Returned Date /¢ ';-76 SUBMIT IN TRIPLICATE · WELL PERMIT CHECKLIST COMPANY W LLNAUE ? "2~-/"4:~;2 PROGRAM:expEldev red se D wellbomsegF'iann. disposalpamreq FIELD&POOL ~. ~O/',.3"',~, INITCLASS ',~'J /-,c~ GEOLAREA ~c~.~,,,~_ UNIT# ',-//~']~ ON/OFFSHORE ADMINISTRATION 1. Permit fee attached ....................... 1 NI'-Y- J~ 2. Lease number appropriate ................... I!t N 3. Unique well name and number ................. 4. Well iocsted in a defined pool .................. 5. Well located proper distance from ddg unit boundary .... 6. Well located proper distance from other wells ......... ~'YI 7. Sufficient acreage available in drilling unit. .......... l.~i N 8. If deviated, is wellbore plat included .............. N 9. Operator only affected party .................. Y] 10. Operator has appropriate bond in force ............ '~I~NN 11. Permit can be issued without conservation order ...... ., , 13. Can permit be approved before 15-day wail ........ N ENGINEERING ..... REMARKS DA -GEOLOGy APPR · 14. Conductor s~ing provided ................... Y N 15. Surface casing protects all known USDWs .......... Y N ~ 'L,.-- 16. CMl' vol adequate to circulste on conductor & surf csg .... Y N 17. CMl' vol adequate to tie-in long string to surf csg ....... Y N 18. CMT will cover a~l known productive horizons ........ .(~ N 19. Casing designs adequate for C, T, B & permafrost. ..... L~ N 20. Adequate tankage or reserve pit. ............... 21. If a re-drill, has a 10-403 for abndnmnt been approved .... Y~ N 22. Adequate wellbore separation proposed ............ L.YJ N 23. If diverter required, is it adequate ................ ~ ~"'~"~ 24. Ddlling fluid program schematic & equip list adequate .... ~ ,N, 25. BOPEs adequate ........................ ~ N 26. BOPE press feting adequate; test to ~ ~ psig.,~ N 27. Choke manifold complies w/APl RP-53 (May 84) ...... 28. Work will occur without operation shutdown ......... 'A~, N 29. is presence of H2S gas pmbsble .............. ~ N 30. Permit can be issued w/o hydrogen sulfide measures ..... Y -N,//'., 31. Dats presented on potenl~aJ overpressure zones ....... Y~ /~-~v ,~' 32. Seismic analysis of shallow gas zones ............ ./'Y N 33. Seabed condition survey (if off-shore) .......... ./. Y N 34. Contact name/phone for weeld¥ progress repo~,... ,,/... Y N leXP lorator~ ono'J GEOLOGY: ENGINEERING: COMMISSION: JDH ~ JDN" v TAB . Comments/instructions: - A.'~-OR~ my 4,96 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 simp!ify 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 * ****************************** * ............................ ....... SCHLU~i~ERGER ....... * ****************************** NOV 2 1 1997 Oil & Gas Oor~, Commissk:,~ COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 2 - IOA FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-20163-01 REFERENCE NO : 97520 MICrOFiLMeD Date * ALASKA COMPUTING CENTER * , . ****************************** * ............................ * ....... SCHLUMBERGER ....... * ............................ * ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAFiE : D.S. 2 - iOA FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-20163-01 REFERENCE NO : 97520 'LIS Ta~e Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/11/18 ORIGIN : FLIC REEL NA_NiE : 97520 CONTINUATION # : PREVIOUS REEL : CO~NT : ARCO ALASKA INC, D.S. 2-10A, PRUDHOE BAY, 50-029-20163-01 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE : 97/11/18 ORIGIN : FLIC TAPE NAM~ : 97520 CONTINUATION # : 1 PREVIOUS TAPE : COF~IENT : ARCO ALASKA INC, D.S. 2-10A, PRUDHOE BAY, 50-029-20163-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D. S. 2 - I OA API NUMBER: 500292016301 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 18-NOV-97 JOB NURiBER: 97520 LOGGING ENGINEER: ELMORE OPERATOR WITNESS: MARTIN SURFACE LOCATION SECTION: 36 TOWNSHIP: 1 IN RANGE: 14E FArL : 1039 FSL: FEL: 938 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 58. O0 DERRICK FLOOR: GROUND LEVEL: 24. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 625 10591 . 0 47. O0 2ND STRING 7. 000 11470. 0 29. O0 3RD STRING 4. 500 10461 . 0 12.60 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (M~ASURED DEPTH) 'LIS Tap'e Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 07-AUG-76 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888 0 9012 5 9002 5 8987 5 8985 0 8984 5 8977.0 8969.0 8962.0 8941.0 8933.5 8929.0 8928.5 8925.0 8924.0 8919.5 8919.0 8915.0 8893.0 8891.5 8877.0 8873.5 8861.5 8830.5 8824.0 8809.5 8809,0 8797.0 8796.5 8772.0 8762.0 8749.5 8746.0 8740.5 8738.5 8727.0 871 O. 5 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88898.0 88889.0 8994.5 8987.5 8973.0 8946.0 8934.0 8930.5 8922.5 8885.0 8883.5 8870.5 8830.0 8807.0 8793.5 8761.0 8745.0 8739.0 8726.5 8711.5 101.0 9013.5 9002.0 8991.0 8987.5 8972.5 8946.0 8937.5 8934.0 8930.5 8922.0 8916.0 8884.0 8871.0 8857.0 8830.0 8821.5 8807.0 8793.0 8770.0 8760.5 8750.0 8737.0 8726.0 99.0 The depth adjustments shown above reflect cased hole GR to open hole BCS GR and cased hole SIGM to open hole GR. Ail other TDTP curves were carried with the SIGM shifts. $ $ PAGE: 'LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: **** FILE HEADER **** FILE NA~E : EDIT .001 SBRVICE : FLIC VERSION : O01CO1 DATE : 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUAiBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~mlARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9005.0 8699.0 TDTP 9030.0 8699.0 $ CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP REMARKS: This file contains TDTP Pass #1 (Base Pass #1). pass to pass shifts were applied to this data. $ LIS FORMAT DATA No ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 'LIS Tap~e Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~E 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 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 SIGMTDTP CU 1119507 O0 000 00 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 SBHFTDTP CU 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 TClVD TDTP CPS 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 GRCHTDTP GAPI 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 1119507 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9031.000 SIGM. TDTP 24.654 TPHI.TDTP 37.127 SBHF. TDTP SB~N. TDTP 48.216 SIGC. TDTP 1.507 SIBH. TDTP 111.626 TRAT. TDTP SDSI.TDTP 0.342 BACK. TDTP 54.716 FBAC. TDTP 15.216 TCAN. TDTP TCAF. TDTP 9301.605 TCND.TDTP 22372.926 TCFD. TDTP 6593.002 TSCN. TDTP TSCF. TDTP 1706.545 INND. TDTP 819.689 INFD. TDTP 357.129 GRCH. TDTP TENS.TDTP 1270.000 CCL.TDTP 0.000 40.319 1.892 27186.590 4940.951 -999.250 _ LIS Tape Verification Listing Schlumberger Alaska Computing Center 18~NOV-1997 13:12 PAGE: DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 9000 000 38 760 0 188 28648 000 5588 000 1273 188 SIGM. TDTP 15.331 TPHI.TDTP 29.433 SBHF. TDTP 29.455 SIGC. TDTP 1.496 SIBH. TDTP 61.914 TRAT. TDTP 2.008 BACK. TDTP 63.049 FBAC. TDTP 15.813 TCAN. TDTP 73669.000 TCND. TDTP 35818.250 TCFD. TDTP 12122.750 TSCN. TDTP 14369.250 INND.TDTP 792.328 INFD. TDTP 365.297 GRCH. TDTP 23.375 CCL.TDTP 0.000 DEPT. 8698.000 SIGM. TDTP 11.631 TPHI. TDTP 16.324 SBHF. TDTP 38.162 SBHN. TDTP 45.640 SIGC. TDTP 1.255 SIBH. TDTP 76.852 TRAT. TDTP 1.598 SDSI.TDTP 0.206 BACK. TDTP 128.593 FBAC. TDTP 24.288 TCAN. TDTP 37003.859 TCAF. TDTP 18476.832 TCND. TDTP 24029.848 TCFD. TDTP 8324.012 TSCN. TDTP 7304.731 TSCF. TDTP 3647.411 INND. TDTP 791.693 INFD. TDTP 309.554 GRCH. TDTP -999.250 TENS. TDTP 1250.000 CCL. TDTP 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFi~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 2 DEPTH INCREMEiFr: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9005.0 8698.0 TDTP 9030.0 8698.0 $ 'LIS Tap'e Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: CURVE SHIFT DATA - PASS TO PASS(M~ASUREDDEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GR PASS ~ER: 1 BASELINE DEPTH 88888.0 9026.5 9017.0 9009.5 9002.5 8987.0 8985.5 8985.0 8981.5 8978.0 8973.0 8941.0 8933.5 8925.0 8919.0 8900.0 8891.5 8891.0 8876.5 8873.5 8868.5 8862.0 8855.0 8836.5 8830.5 8809.0 8804.0 8801.5 8799.5 8786.0 8785.5 8762.5 8762.0 8757.0 8727.0 100.0 $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88897.5 88888.5 9027.0 9018.5 9010.0 9002.0 8990.5 8987.5 8994.5 8985.0 8979.5 8946.0 8938.5 8922.0 8895.0 8884.0 8870.5 8866.0 8854.5 8830.0 8807.0 8798.5 8783.0 8761.0 99.0 8984.0 8946.0 8930.0 8922.0 8884.0 8871.0 8857.5 8835.0 8830.5 8807.0 8801.5 8796.0 8782.5 8760.5 8756.0 8726.0 99.0 REMARKS: This file contains TDTP Pass #2 (Base Pass #2). The depth shifts shown above relect GRCH Pass #2 to GRCH Pass #1 and SIGM Pass #2 to SIGM Pass #1. $ LIS FORMAT DATA 'LIS Tap'e Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 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 ** NA~4E SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELM CODE (HEX) DEPT FT 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMTDTP CU 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 SBHFTDTP CU 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 SBP~NTDTP CU 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 SIBHTDTP CU 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 TCANTDTP CPS 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 TSCNTDTP CPS 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1119507 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: ** DATA ** DEPT. 9030.500 SIG~.TDTP 25.355 TPHI.TDTP 38.189 SBHF. TDTP 42.105 SBHN. TDTP 47.962 SIGC. TDTP 0.916 SIBH. TDTP 110.374 TRAT. TDTP 1.896 SDSI. TDTP 0.394 BACK. TDTP 166.853 FBAC. TDTP 45.831 TCAN. TDTP 30113.434 TCAF. TDTP 10038.785 TCND. TDTP 21811.531 TCFD. TDTP 6431.105 TSCN. TDTP 4790.659 TSCF. TDTP 1633.730 INND. TDTP 808.243 INFD. TDTP 337.412 GRCH. TDTP -999.250 TENS. TDTP 1240.000 CCL.TDTP 0.000 DEPT. 9000.000 SIGM. TDTP 15.580 TPHI.TDTP 29.901 SBHF. TDTP 28.642 SBH~.TDTP 38.334 SIGC. TDTP 1.521 SIBH. TDTP 60.117 TRAT. TDTP 2.014 SDSI.TDTP 0.191 BACK. TDTP 162.340 FBAC. TDTP 40.956 TCAN. TDTP 71824.000 TCAF. TDTP 27526.000 TCND. TDTP 35403.000 TCFD. TDTP 11945.750 TSCN. TDTP 14220.000 TSCF. TDTP 5449.500 INND. TDTP 783.787 INFD. TDTP 368.813 GRCH. TDTP 104.438 TENS. TDTP 1258.047 CCL. TDTP 0.000 DEPT. 8700.000 SIGM. TDTP 11.727 TPHI.TDTP SBHN. TDTP 49.636 SIGC. TDTP 1.291 SIBH. TDTP SDSI.TDTP 0.234 BACK. TDTP 210.603 FBAC. TDTP TCAF. TDTP 17605.563 TCND. TDTP 23883.953 TCFD. TDTP TSCF. TDTP 3474.193 INND. TDTP 803.498 INFD. TDTP TENS. TDTP 1235.000 CCL. TDTP 0.000 16.518 89.383 40.000 8090.110 299.081 SBHF. TDTP TRAT. TDTP TCAN. TDTP TSCN. TDTP GRCH. TDTP DEPT. 8697.000 SIGM. TDTP 11.290 TPHI.TDTP 15.850 SBHF. TDTP SBHN. TDTP 44.923 SIGC. TDTP 1.442 SIBH. TDTP 73.501 TRAT. TDTP SDSI. TDTP 0.233 BACK. TDTP 213.872 FBAC. TDTP 36.610 TCAN. TDTP TCAF. TDTP 18552.078 TCND. TDTP 23988.418 TCFD. TDTP 8390.922 TSCN. TDTP TSCF. TDTP 3669.999 INND. TDTP 798.693 INFD. TDTP 301.563 GRCH. TDTP TENS. TDTP 1245.000 CCL.TDTP 0.000 37.610 1.604 35782.094 7061.060 28.656 37.741 1.587 36967.016 7312.868 29.688 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 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 SU~f~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8972.0 8700.0 TDTP 9028.0 8700.0 $ CURVE SHIFT DATA ~ PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GR PASS NUM~ER: 1 BASELINE DEPTH 88888.0 9017.0 9002.0 8994.0 8987.0 8981.5 8964.5 8959.5 8951.0 8943.0 8941.0 8933.5 8927.0 8925.5 8919.0 8915.5 8900.0 8891.5 8886.5 8876.5 8873.5 8867.0 8865.5 8861.0 8857.0 8852.5 8849.5 8836.0 8830.5 8823.5 8820.5 8816.0 8809.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88893.5 88889.5 8965.0 8957.5 8946.0 8938.5 8930.5 8922.5 8895.0 8883.5 8881.0 8870.5 8864.5 8855.0 8848.0 8830.0 8820.0 8814.5 9018.5 9002.0 8996.5 8990.5 8984.5 8968.5 8948.5 8937.5 8930.5 8922.0 8917.0 8884.5 8871.0 8860.0 8857.0 8850.0 8835.0 8830.5 8821.5 8807.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: 10 8806.5 8804.0 8804.0 8801.5 8799.5 8796.0 8794.5 8792.0 8785.5 8782.5 8779.5 8778.0 8762.0 8761.0 8761.5 8761.0 8745.5 8745.0 8726.5 8726.5 100.0 100.0 99.0 REMARKS: This file contains TDTP Pass #3 (Base Pass #3). The depth shifts shown above relect GRCH Pass #3 to GRCH Pass #1 and SIGMPass #3 to SIGMPass #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 C~SS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 1119507 O0 000 O0 0 3 1 I 4 68 0000000000 TPHI TDTP PU-S 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18~NOV-1997 13:12 PAGE: 11 NAFiE SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SBHF TDTP CU 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 TCANTDTP CPS 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 TCAFTDTP CPS 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 TSCNTDTP CPS 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1119507 O0 000 O0 0 3 1 1 4 68 0000000000 * * DA TA * * DEPT. 9029.500 SIGM. TDTP 30.773 TPHI.TDTP 42.095 SBHF. TDTP 38.616 SBHN. TDTP 46.826 SIGC. TDTP 0.810 SIBH. TDTP 104.757 TRAT. TDTP 1.820 SDSI.TDTP 0.514 BACK. TDTP 237.773 FBAC. TDTP 73.355 TCAN. TDTP 25622.273 TCAF. TDTP 8092.572 TCND. TDTP 18985.609 TCFD. TDTP 5256.168 TSCN. TDTP 3239.450 TSCF. TDTP 1075.636 INND.TDTP 765.869 INFD. TDTP 332.459 GRCH. TDTP -999.250 TENS.TDTP 1250.000 CCL.TDTP 0.000 DEPT. 9000.000 SIGM. TDTP 14.833 TPHI.TDTP 28.458 SBHF. TDTP 29.035 SBHN. TDTP 41.031 SIGC. TDTP 1.281 SIBH. TDTP 71.453 TRAT. TDTP 1.992 SDSI.TDTP 0.183 BACK. TDTP 254.807 FBAC. TDTP 75.058 TCAN. TDTP 73738.000 TCAF. TDTP 28768.000 TCND. TDTP 35173.250 TCFD. TDTP 11989.500 TSCN. TDTP 14123.750 TSCF. TDTP 5510.250 INND.TDTP 789.914 INFD. TDTP 362.394 GRCH. TDTP -999.250 TENS. TDTP 1281.813 CCL.TDTP 0.000 DEPT. 8700.000 SIGM. TDTP 11.541 TPHI.TDTP 16.118 SBHF. TDTP SBHN. TDTP 48.470 SIGC. TDTP 1.367 SIBH. TDTP 84.514 TRAT. TDTP SDSI.TDTP 0.234 BACK. TDTP 267.277 FBAC. TDTP 53.834 TCAN. TDTP TCAF. TDTP 17873.945 TCND. TDTP 23832.703 TCFD. TDTP 8031.359 TSCN. TDTP TSCF. TDTP 3425.769 INND.TDTP 793.159 INFD.TDTP 301.221 GRCH. TDTP TENS. TDTP 1250.000 CCL.TDTP 0.000 DEPT. 8699.000 SIGM. TDTP 11.539 TPHI.TDTP 16.239 SBHF. TDTP SBHN. TDTP 47.449 SIGC. TDTP 1.346 SIBH. TDTP 82.417 TRAT. TDTP SDSI.TDTP 0.220 BACK. TDTP 268.799 FBAC. TDTP 53.757 TCAN. TDTP TCAF. TDTP 18505.512 TCND. TDTP 24094.637 TCFD. TDTP 8232.781 TSCN. TDTP TSCF. TDTP 3548.013 INND. TDTP 794.389 INFD.TDTP 309.363 GRCH. TDTP TENS.TDTP 1250.000 CCL.TDTP 0.000 35.176 1.591 36155.156 6929.595 39.313 34.654 1.597 37554.313 7200.190 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: 12 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE . 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFiE : EDIT .004 SERVICE : FLIC VERSION . O01CO1 DATE : 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NLrMBER: 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 NUM~ERS 1, 2, 3, TDTP The arithmetic average of passes 1, 2 & 3 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOVel997 13:12 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 ** NAFiE SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNPNAV CU 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 TCAFPNAV CPS 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 TCND PNAV CPS 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD PNAV CPS 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 INNDPNAV CPS 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1119507 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: 14 DEPT. 9031.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBI{N. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 54.716 FBAC. TDTP 15.216 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD. PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999.250 DEPT. 9000.000 SIGM. PNAV 15.246 TPHI.PNAV 29.261 SBHF. PNAV 29.041 SBHN. PNAV 39.371 SIGC. PNAV 1.432 SIBH. PNAV 64.488 TRAT. PNAV 2.004 SDSI.PNAV 0.187 BACK. TDTP 63.049 FBAC. TDTP 15.813 TCAN. PNAV 73069.688 TCAF. PNAV 28311.168 TCND.PNAV 35461.289 TCFD.PNAV 12018.131 TSCN. PNAV 14236.242 TSCF. PNAV 5515.365 INND. PNAV 788.598 INFD.PNAV 365.464 GRCH. TDTP 23.375 DEPT. 8698.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC.PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 128.593 FBAC. TDTP 24.288 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND. PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD. PNAV -999.250 GRCH. TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFIBER: 1 DEPTH INCREM~Ff: 0.5000 FILE SG?4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: 15 TDTP 9030.0 $ 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): 8699.0 22 -AUG- 97 44.2 1730 22 -AUG- 97 10292.0 0.0 8700.0 9050.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~IA RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS TDT SET 396 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 10591.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WEL~ (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE 20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 1200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: 16 REMARKS: TIED IN TO SWS GR LOG DATED 8/7/76. ALL LOGGING PASSES LOGGED AT 1800 FPH FROM 9050'-8700'. FIELD PICK GOC= 11005', FIELD PICK GAS UNDERRUNS= 10056'-1 TOTAL FLUIDS PUMPED: 1% KCL DURING B/LINE PASSES 537 BBL. 5.5/5.5/2.0 BPM BORAX PASSES: 270 BBL BORAX. 1 BPM FLUSHED WITH 72 BBL OF SEAWATER AFTER BORAX PASSES. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 88 66 1 0.5 FT 11 0 FT 68 1 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 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PS1 CU 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 SBH~PS1 CU 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PS1 CU 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PS1 CU 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PS1 CU 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 BACK PS1 CPS 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: 17 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) TCANPS1 CPS 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 TCAFPS1 CPS 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 TCND PS1 CPS 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD PS1 CPS 1119507 O0 000 O0 0 5 1 I 4 68 0000000000 TSCNPS1 CPS 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PS1 CPS 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 INND PS1 CPS 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 INFD PS1 CPS 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1119507 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9050.000 SIGM. PS1 30.917 TPHI.PS1 39.939 SBHF. PS1 SBP~V. PS1 47.870 SIGC. PS1 1.739 SIBH. PSl 109.918 TRAT. PS1 SDSI.PS1 0.754 BACK. PSi 50.293 FBAC. PS1 15.489 TCAN. PS1 TCAF. PS1 5258.354 TCND. PS1 18983.520 TCFD. PS1 5131.831 TSCN. PS1 TSCF. PS1 990.196 INND.PS1 797.730 INFD. PS1 325.836 TENS. PSi GR.PS1 64.875 CCL.PS1 0.000 DEPT. 9000.000 SIGM. PS1 15.395 TPHI.PS1 29.727 SBHF. PS1 SBH~.PS1 38.320 SIGC. PS1 1.485 SIBH. PSl 60.045 TRAT. PS1 SDSI.PS1 0.191 BACK.PSI 62.617 FBAC. PS1 15.998 TCAN. PS1 TCAF. PS1 28301.906 TCND. PS1 35770.219 TCFD. PS1 12056.215 TSCN. PS1 TSCF. PS1 5520.917 INND.PS1 794.493 INFD.PS1 360.501 TENS.PSI GR.PS1 21.016 CCL.PS1 0.000 DEPT. 8700.000 SIGM. PS1 11.598 TPHI.PS1 16.314 SBHF. PS1 SBHN. PS1 46.829 SIGC. PS1 1.268 SIBH. PS1 80.991 TRAT. PS1 SDSI.PS1 0.202 BACK. PSi 128.607 FBAC. PS1 24.292 TCAN. PS1 TCAF. PS1 18293.152 TCND.PS1 23967.871 TCFD.PS1 8233.352 TSCN. PS1 TSCF. PS1 3607.556 INND.PS1 793.347 INFD.PS1 295.884 TENS. PSi GR.PS1 12.281 CCL.PS1 0.000 DEPT. 8698.000 SIGM. PS1 11.190 TPHI.PS1 15.997 SBHF. PS1 SBHN. PS1 44.687 SIGC. PSl 1.465 SIBH. PS1 73.188 TRAT. PS1 SDSI.PS1 0.185 BACK. PSi 133.597 FBAC.PS1 23.749 TCAN. PS1 TCAF. PS1 18523.500 TCND.PS1 24152.629 TCFD.PS1 8319.648 TSCN. PS1 TSCF. PS1 3655.848 INND. PS1 810.548 INFD.PS1 306.130 TENS. PSI GR.PS1 13.031 CCL.PS1 0.000 42.522 1.766 15846.438 2965.264 1280.000 29.548 2.016 73277.234 14294.357 1255.000 36.005 1.599 36692.758 7236.104 1260.000 34.008 1.597 37081.203 7318.446 1250.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: 18 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE . FLIC VERSION · O01CO1 DATE : 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENOY4BER 6 RAW CORVES Curves and log header data for each pass in separate files; raw background pass in last file PASS--ER: 2 DEPTH INCREMENT: 0.5000 FILE SU~rlARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9030.0 8698.0 TDTP LOG HEADER DATA DATE LOGGED: 22-AUG-97 SOFTWARE VERSION: 44.2 TIME LOGGER ON BOTTOM: 1730 22-AUG-97 TD DRILLER (FT) : 10292.0 TD LOGGER (FT) : O. 0 TOP LOG INTERVAL (FT) : 8700.0 BOTTOM LOG INTERVAL (FT) : 9050.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER CGRS TDT SET 396 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: 19 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10591.0 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 20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 1200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED IN TO SWS GR LOG DATED 8/7/76. ALL LOGGING PASSES LOGGED AT 1800 FPH FROM 9050'-8700'. FIELD PICK GOC= 11005', FIELD PICK GAS UNDERRUNS= 10056'-1 TOTAL FLUIDS PUMPED: i~ KCL DURING B/LINE PASSES 537 BBL. 5.5/5.5/2.0 BPM BORAX PASSES: 270 BBL BORAX. 1 BPM FLUSHED WITH 72 BBL OF SEAWATER AFTER BORAX PASSES. $ LIS FORMAT DATA ** 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 18-NOV-1997 13:12 PAGE: 20 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 PT 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 1119507 O0 000 00 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 SBt{NPS2 CU 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS2 CPS 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 TCAFPS2 CPS 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 TCND PS2 CPS 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PS2 CPS 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 TSCNPS2 CPS 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 INNDPS2 CPS 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS2 CPS 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1119507 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9050.000 SIGM. PS2 29.262 TPHI.PS2 38.050 SBHF. PS2 SBHN. PS2 50.995 SIGC. PS2 2.159 SIBH. PS2 125.356 TRAT. PS2 SDSI.PS2 0.807 BACK. PS2 174.012 FBAC. PS2 66.996 TCAN. PS2 TCAF. PS2 5625.313 TCND. PS2 18727.086 TCFD.PS2 5122.530 TSCN. PS2 TSCF. PS2 1073.948 INND. PS2 794.200 INFD.PS2 335.569 TENS.PS2 43.418 1.716 15829.566 2991.574 1280.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: 21 GR.PS2 439.000 CCL.PS2 DEPT. 9000.000 SIGM. PS2 SBHN. PS2 37.872 SIGC.PS2 SDSI.PS2 0.192 BACK. PS2 TCAF. PS2 27103.375 TCND.PS2 TSCF. PS2 5366.699 INND.PS2 GR.PS2 117.875 CCL.PS2 DEPT. 8700.000 SIGM. PS2 SBH~V. PS2 49.700 SIGC. PS2 SDSI.PS2 0.235 BACK. PS2 TCAF. PS2 18273.070 TCND.PS2 TSCF. PS2 3610.255 INND.PS2 GR.PS2 27.609 CCL.PS2 DEPT. 8697.000 SIGM. PS2 SBHIV. PS2 46.065 SIGC.PS2 SDSI.PS2 0.218 BACK. PS2 TCAF. PS2 18464.930 TCND.PS2 TSCF. PS2 3657.939 IiVND.PS2 GR.PS2 29.406 CCL.PS2 O. 000 15.626 TPHI.PS2 30.095 SBHF. PS2 28.496 1.527 SIBH. PS2 58.058 TRAT. PS2 2.019 161.510 FBAC. PS2 40.957 TCAN. PS2 71071.828 35260.445 TCFD. PS2 11860.645 TSCN. PS2 14072.828 783.103 INFD. PS2 365.517 TENS.PS2 1260.000 0.000 11.606 TPHI.PS2 1.176 SIBH. PS2 210.224 FBAC. PS2 24085.781 TCFD. PS2 798.260 INFD.PS2 0.000 16.285 SBHF. PS2 90.297 TRAT. PS2 39.453 TCAN. PS2 8290.465 TSCN. PS2 301.578 TENS.PS2 38.582 1.597 36816.016 7273.831 1235.000 11.332 TPHI.PS2 15.889 SBHF. PS2 37.424 1.612 SIBH. PS2 77.260 TRAT. PS2 1.587 211.495 FBAC. PS2 36.609 TCAN. PS2 36798.797 24022.102 TCFD.PS2 8338.736 TSCN. PS2 7289.914 815.563 INFD. PS2 292.704 TENS.PS2 1220.000 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE~ER **** FILE NAPIE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE1VUf4~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUAiBER: 3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: 22 DEPTH INCREF~ENT: 0.5000 FILE SUM~L%~Y VENDOR TOOL CODE START DEPTH TDTP 9028.0 $ LOG HEADER DATA STOP DEPTH 8700.0 DATE LOGGED: SOFTWARE VERSION: TIM~ 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): 22-AUG-97 44.2 1730 22-AUG-97 10292.0 0.0 8700.0 9050.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAF~A RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS TDT SET 396 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 10591.0 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 20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: 23 FAR COUNT RATE HIGH SCALE (CPS): 1200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED IN TO SWS GR LOG DATED 8/7/76. ALL LOGGING PASSES LOGGED AT 1800 FPH FROM 9050'-8700'. FIELD PICK GOC= 11005', FIELD PICK GAS UNDERRUNS= 10056'-1 TOTAL FLUIDS PUMPED: 1~ KCL DURING B/LINE PASSES 537 BBL. 5.5/5.5/2.0 BPM BORAX PASSES: 270 BBL BORAX. 1 BPM FLUSHED WITH 72 BBL OF SEAWATER AFTER BORAX PASSES. $ 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 O. 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 ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 SIGMPS3 CU 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 SBP~VPS3 CU 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS3 CU 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: 24 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~3 SAMP EL~ CODE (HEX) TRAT PS3 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS3 CPS 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 TCAFPS3 CPS 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PS3 CPS 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PS3 CPS 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 TSCNPS3 CPS 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 INND PS3 CPS 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS3 CPS 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1119507 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9050.000 SIGM. PS3 31.482 TPHI.PS3 36.371 SBHF. PS3 SBH~.PS3 48.614 SIGC. PS3 0.637 SIBH. PS3 113.591 TRAT. PS3 SDSI.PS3 0.519 BACK. PS3 329.921 FBAC.PS3 119.709 TCAN. PS3 TCAF. PS3 8623.141 TCND. PS3 17745.160 TCFD.PS3 4869.577 TSCN. PS3 TSCF. PS3 983.828 INND.PS3 779.389 INFD.PS3 331.553 TENS.PS3 GR.PS3 629.500 CCL. PS3 0.000 DEPT. 9000.000 SIGM. PS3 15.393 TPHI.PS3 28.952 SBHF. PS3 SBH~V. PS3 41.905 SIGC. PS3 1.373 SIBH. PS3 75.324 TRAT. PS3 SDSI.PS3 0.200 BACK. PS3 250.872 FBAC. PS3 74.395 TCAN. PS3 TCAF. PS3 27060.824 TCND. PS3 34531.617 TCFD. PS3 11639.854 TSCN. PS3 TSCF. PS3 5190.335 INND. PS3 792.470 INFD.PS3 357.043 TENS.PS3 GR.PS3 370.500 CCL.PS3 0.000 DEPT. 8699.500 SIGM. PS3 11.618 TPHI.PS3 16.366 SBHF. PS3 SBH~.PS3 48.318 SIGC. PS3 1.370 SIBH. PS3 85.155 TRAT. PS3 SDSI.PS3 0.218 BACK. PS3 270.180 FBAC. PS3 55.120 TCAN. PS3 TCAF. PS3 18713.824 TCND. PS3 24175.762 TCFD. PS3 8295.277 TSCN. PS3 TSCF. PS3 3589.743 INND.PS3 781.127 INFD. PS3 311.633 TENS. PS3 GR.PS3 38.594 CCL.PS3 0.000 41.807 1.667 26344.254 2762.651 1245.000 28.142 1.987 69874.609 13402.131 1270.000 33.339 1.601 37925.844 7275.050 1250.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-NOV-1997 13:12 PAGE: 25 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 97/11/18 ORIGIN : FLIC TAPE NA14E : 97520 CONTINUATION # : 1 PREVIOUS TAPE : COf4F~ENT : ARCO ALASKA INC, D.S. 2-10A, PRUDHOE BAY, 50-029-20163-01 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 97/11/18 ORIGIN : FLIC REEL NAME : 97520 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, D.S. 2-10A, PRUDHOE BAY, 50-029-20163-01 Sperry-Sun Drilling Services LIS Scan Utility Fzi Jun 20 08:03:19 1997 Reel Header Service name ............. LISTPE Date ..................... 97/06/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Services Tape Header Service name ............. LISTPE Date ..................... 97/06/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-60209 A. WORTHINGT BASS/KARA 02-10A PB1 500292016370 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 19-JUN-97 MWD RUN 2 MWD RUN 3 AK-MW-60209 AK-MW-60209 A. WORTHINGT A. WORTHINGT BASS/KARA BASS/KARA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: MWD RUN 4 AK-NSq-60209 A. WORTHINGT BASS/KARA 36 liN 14E 1039 938 58.10 .00 GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2715.0 9.625 9037.0 2.875 3.750 9886.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUNS 1 THROUGH 4 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 4. DEPTH SHIFTING/CORRECTION OF HWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND DOUG KNOCK OF ARCO ALASKA, INC. ON MAY 7, 1997. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9885'MD, 8893'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name. i ........... STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8755.5 9858.5 ROP 8783.0 9884.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 8783.0 8920.0 2 8920.0 9107.0 3 9107.0 9520.0 4 9520.0 9885.0 MERGED I~AIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8755.5 9884.5 9320 2259 8755.5 ROP 9.02 851.1 62.0594 2204 8783 GR 19.07 814.03 95.3877 2207 8755.5 Last Reading 9884.5 9884.5 9858.5 First Reading For Entire File .......... 8755.5 Last Reading For Entire File ........... 9884.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8755.5 ROP 8783.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8892.5 8919.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (Oh-MM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Speci[±cation Block sub-type...0 03-JAN-97 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 8920.0 8783.0 8920.0 9.9 26.4 TOOL NUMBER NGP 325 3.750 3.8 Flo-Pro 8.70 .0 9.2 7.0 .000 .000 .000 .000 65.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 1 A_~PI 4 1 68 ROP MWD 1 FT/H 4 1 68 0 1 4 2 8 3 First Last Name Min Max Mean Nsam Reading Reading DEPT 8755.5 8919 8837.25 328 8755.5 8919 GR 19.07 192.07 57.4828 275 8755.5 8892.5 ROP 16.35 120.43 75.0821 273 8783 8919 First Reading For Entire File .......... 8755.5 Last Reading For Entire File ........... 8919 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SU~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8893.0 9081.0 ROP 8920.5 9107.0 $ LOG HEADER DATA DATE LOGGED: 03-JAN-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 9107.0 8920.0 9107.0 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHN94) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 34.0 94.7 TOOL NUMBER NGP 325 3.750 3.8 Flo-Pro 8.70 .0 8.6 7.4 .000 .000 .000 .000 56.2 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8893 9107 9000 429 8893 GR 22.61 814.03 84.1479 377 8893 ROP 9.02 851.1 61.4576 374 8920.5 Last Reading 9107 9081 9107 First Reading For Entire File .......... 8893 Last Reading For Entire File ........... 9107 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9075.5 9494.0 ROP 9100.5 9519.5 $ LOG HEADER DATA DATE LOGGED: 04-JAN-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9520.0 TOP LOG INTERVAL (FT) : 9107.0 BOTTOM LOG INTERVAL (FT): 9520.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 90.7 MAXIMUM ANGLE: 95.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE ~D CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): TOOL NUMBER NGP 228 3.750 3.8 Flo-Pro 8.80 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM : FLUID LOSS (C3) : RESISTIVITY (OHM>4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 9.2 6.3 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 54.0 First Name Min Max Mean Nsam Reading DEPT 9075.5 9519.5 9297.5 889 9075.5 GR 52.9 115.78 78.6434 838 9075.5 ROP 16.22 1043.64 82.1287 839 9100.5 Last Reading 9519.5 9494 9519.5 First Reading For Entire File .......... 9075.5 Last Reading For Entire File ........... 9519.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9490.5 9858.5 ROP 9500.5 9884.5 $ LOG HEADER DATA DATE LOGGED: 05-JAN-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9885.0 TOP LOG INTERVAL (FT) : 9520.0 BOTTOM LOG INTERVAL (FT): 9885.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 92.7 MAXIMUM ANGLE: 94.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 228 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo-Pro 8.90 .0 8.6 5.7 .000 .000 .000 .000 60.9 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9490.5 9884.5 9687.5 789 9490.5 GR 55.97 183.59 134.024 737 9490.5 ROP 14.53 2508.88 132.66 769 9500.5 Last Reading 9884.5 9858.5 9884.5 First Reading For Entire File .......... 9490.5 Last Reading For Entire File ........... 9884.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/06/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/06/20 Origin ................... STS Reel Name ................ UNKNOWN Scientific Technical Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Scientific Technical Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Fri Jun 20 08:59:12 1997 Reel Header Service name ............. LISTPE Date ..................... 97/06/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Services Library. Tape Header Service name ............. LISTPE Date ..................... 97/06/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPA~NY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW- 60209 A. WORTHINGT BAS S / KARA Date l' 3--O! 02-10A 500292016301 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 20-JUN-97 MWD RUN 2 MWD RUN 3 AK-MW-60209 AK-MW-60209 A. WORTHINGT A. WORTHINGT BASS/KARA BASS/KARA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: , MWD RUN 6 AK-MW- 60209 A. WORTHINGT BAS S / KARA MWD RUN 7 MWD RUN 8 AK-MW-60209 AK-MW-60209 A. WORTHINGT A. WORTHINGT BASS/KARA GOODRICH/HUP JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: MWD RUN 9 AK-MW-60209 A. WORTHINGT GOODRICH/HUP 36 llN 14E 1039 dUN 20 1997 ~SL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 938 58.10 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 9. 625 9037.0 2ND STRING 5. 500 8195.0 3RD STRING 4.500 8296.0 PRODUCTION STRING 3.750 10375.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUNS 1,2,3,6,7,8, AND 9 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 4. MWD RUNS 4,5, AND 10 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). THESE RUNS CONTAIN NO VALID DATA AND ARE NOT PRESENTED. 5. ONLY GA/VfMA RAY DATA (SGRD) IS UTILIZED FROM MWD RUN 3. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND DOUG KNOCK OF ARCO ALASKA, INC. ON MAY 7, 1997. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10375'MD, 8904'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8755.5 10348.5 ROP 8783.0 10375.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 8783.0 8919.0 2 8919.0 9092.0 3 9092.0 9092.0 6 9092.0 9191.0 7 9191.0 10097.0 8 10097.0 10251.0 9 10251.0 10375.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8755.5 10375 9565.25 3240 8755.5 GR 19.07 814.03 82.6381 3187 8755.5 ROP 2.96 2567.38 68.017 3185 8783 Last Reading 10375 10348.5 10375 First Reading For Entire File .......... 8755.5 Last Reading For Entire File ........... 10375 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8755.5 ROP 8783.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8892.5 8919.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: 03-JAN-97 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 8919.0 8783.0 8919.0 9.9 26.4 TOOL NUMBER NGP 325 3.750 3.8 Flo-Pro 8.70 .0 9.2 7.0 .000 .000 .000 .000 65.6 .3 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8755.5 8919 8837.25 328 8755.5 GR 19.07 192.07 57.4828 275 8755.5 ROP 16.35 120.43 75.0821 273 8783 Last Reading 8919 8892.5 8919 First Reading For Entire File .......... 8755.5 Last Reading For Entire File ........... 8919 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUmmARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8893.0 ROP 8920.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 9081.0 9107.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OPIM~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 03-JAN-97 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 9092.0 8919.0 9092.0 34.0 94.7 TOOL NUMBER NGP 325 3.750 3.8 Flo-Pro 8.70 .0 8.6 7.4 .000 .000 .000 .000 56.2 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 ROP MWD 2 FT/H 4 1 68 Name Min Max Mean Nsam DEPT 8893 9107 9000 429 GR 22.61 814.03 84.1479 377 ROP 9.02 851.1 61.4576 374 First Reading 8893 8893 8920.5 Last Reading 9107 9081 9107 First Reading For Entire File .......... 8893 Last Reading For Entire File ........... 9107 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HF~ADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9075.5 9092.0 $ LOG HEADER DATA DATE LOGGED: 04-JAN-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 90.7 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 9092.0 9092.0 9092.0 MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE 7~qD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: M3ATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 95.2 TOOL NUMBER NGP 228 3.750 3.8 Flo-Pro 8.80 .0 9.2 .0 .000 .000 .000 .000 54.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 First Name Min Max Mean Nsam Reading DEPT 9075.5 9092 9083.75 34 9075.5 GR 58.78 95.42 70.5209 34 9075.5 Last Reading 9092 9092 First Reading For Entire File .......... 9075.5 Last Reading For Entire File ........... 9092 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9090.5 ROP 9090.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : STOP DEPTH 9164.5 9191.0 09-JAN-97 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 9191.0 9092.0 9191.0 82.1 89.2 TOOL NUMBER NGP 325 3.750 3.8 Flo-Pro 9.00 .0 9.1 FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5.0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 63.3 First Name Min Max Mean Nsam Reading DEPT 9090.5 9191 9140.75 202 9090.5 GR 48.31 185.11 81.7381 149 9090.5 ROP 2.96 1800 143.218 202 9090.5 Last Reading 9191 9164.5 9191 First Reading For Entire File .......... 9090.5 Last Reading For Entire File ........... 9191 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9160.5 10070.0 ROP 9190.5 10097.0 $ LOG HEADER DATA DATE LOGGED: il-JAN-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10097.0 TOP LOG INTERVAL (FT) : 9191.0 BOTTOM LOG INTERVAL (FT) : 10097.0 BIT ROTATING SPEED {RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.5 MAXIMUM ANGLE: 97.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 228 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMS4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT I~J~X CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo-Pro 9.30 .0 9.3 5.0 .000 .000 .000 .000 65.6 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .3 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9160.5 10097 9628.75 1874 9160.5 GR 44.51 152.04 79.7953 1820 9160.5 ROP 17.3 1116 54.0688 1814 9190.5 Last Reading 10097 10070 10097 First Reading For Entire File .......... 9160.5 Last Reading For Entire File ........... 10097 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW I~WD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10065.5 ROP 10090.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OH/H) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 STOP DEPTH 10223.5 10250.5 12-JAN-97 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 10251.0 10097.0 10251.0 91.7 93.0 TOOL NUMBER NGP 325 3.750 3.8 Flo-Pro 9.20 .0 9.0 5.3 .000 .000 .000 .000 65.6 .3 Name Service Ozder Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10065.5 10250.5 10158 371 10065.5 GR 84.56 121.05 100.02 317 10065.5 ROP 24.1 2113.93 87.2402 321 10090.5 Last Reading 10250.5 10223.5 10250.5 First Reading For Entire File .......... 10065.5 Last Reading For Entire File ........... 10250.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Coraraent Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10224.5 10348.5 ROP 10251.0 10375.0 $ LOG HEADER DATA DATE LOGGED: 13-JAN-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10375.0 TOP LOG INTERVAL (FT): 10251.0 BOTTOM LOG INTERVAL (FT): 10375.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 91.8 96.0 TOOL NUMBER NGP 325 3.750 3.8 Flo-Pro 9.20 .0 9.0 .3 .0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 AAPI 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 65.6 First Name Min Max Mean Nsam Reading DEPT 10224.5 10375 10299.8 302 10224.5 GR 91.53 136.35 108.649 249 10224.5 ROP 10.6 2567.38 128.626 249 10251 Last Reading 10375 10348.5 10375 First Reading For Entire File .......... 10224.5 Last Reading For Entire File ........... 10375 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/06/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/06/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File