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Home My WebLink About181-010ALAS~OIL AND WELL COMPLETION OR ," 1 (~ STATE OF ALAS GAS CONSERVATI(D ON RECOMPLE ~ FORT AND LOG 1a. Well Status: Oil ^ Gas ^ Plugged ^ Abandoned 0 fed j^ ~: '" ~kf;;, ~f? zonACZS.ios 2oanc2s.no :. GiNJ^ WINJ^ WDSPL^ WAG ^ Other^ No. of Completions: 'ij1~j~~lass: Development ^ Exploratory^~ Service ^ Stratigraphic Test^ 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 4/28/2007 12. Permit to Drill Number: 181-010 " 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 6. Date Spudded: 1/19/1981 4 13. API Number: 50-029-20545 4a. Location of Well (Governmental Section): Surface: 2909' SNL, 2195' WEL, Sec 30, T. 11 N., R.13 E. UM 7. Date TD Reached: 2/6/1981 14. Well Name and Number; PBU MP 22-31-11-13, No. 2 - Top of Productive Horizon: 1534' SNL, 3250' WEL, Sec 31, T. 11N.,R.13E.,UM 8. KB (ft above MSL}: 75.31- Ground (ft MSL): 47.31 15. Field/Pool(s): Prudhoe Bay -- Total Depth: 1932' SNL, 4070' WEL, Sec. 31, T. 11N., R.13E., UM 9. Plug Back Depth(MD+TVD): Surface 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 631,794 y- 5,452,391 Zone- 4 10. Total Depth (MD +TVD): ~ 11,230 MD, 9657 TVD - 16. Property Designation: ADL 28288 - TPI: x- 630,239 y- 5,448,486 Zone- 4 Total Depth: x- 629,919 y- 5,448,088 Zone- 4 11. SSSV Depth (MD +TVD); None 17. Land Use Permit: DNR 18. Directional Survey: Yes ~ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: (ft MSL} 20. Thickness of Permafrost (TVD): 1998' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): See previous Completion Report 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE S AMOUNT FT TOP BOTTOM TOP BOTTOM IZE CEMENTING RECORD PULLED 20" conductor Surface 110 Surface 110 36" 12 cu. yds concrete 0 13 3/8" 72# L-80 Surface 2685 Surface 2685 171/2" 3720 cu. ft Arctic Set 11 0 9 5/8" 47# L-80 Surface 10195 Surface 8800 12 1/4" 1524 cu. ft. Class G 0 plus 130 cu.ft. Arctic Set 7" 29# L-80 9687 11,228 8374 9656 8 1 /2" 420 cu. ft. Class G 0 23. Open to production or injection? Yes ^ No If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) No perforations None 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~~('~'~~~ ~Q~ ~ ~" 207 U/ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED None 26• PRODUCTION TEST Date First Production: ~ - ~~ -•------- ------~-----.-...-- ~ -. No production Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~ Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corr): 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No Q Sidewall Cores Acquired? Yes ^ No ^~ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. C014pP,L~ETiGN - 01=0 l~b~t? f •. Form 10-407 Revised 2/2007 ~ ~ ~ ~ ~~ ~~jTINUED ON REVERSE ,~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes list intervals and formations tested , , briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Top 4' 4' needed, and submit detailed test information per 20 AAC 25.071. Permafrost -Base 1998' 1998' Geologic Data previously submitted Formation at total depth: 30. List of Attachments: Operations summary and vdeilbore diagram. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: Douolas A. Cismoski Title: Wells Team Leader, Alaska Drilling and Wells Signature: Phone: 907-564-4303 Date: L'r 0 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 • Record of Plugging and Abandonment Operations BP Exploration (Alaska) Inc (BPXA) PBU MP 22-31-11-12 No. 2 PTD: 181-010 API No. 50-029-20545 Introduction and Background: This well was drilled, logged, cased and suspended in early 1981 by Sohio Alaska Petroleum Company (now BPXA). The well was never perforated or tested, but suspended in a condition that would facilitate re-entry, as the well was under consideration for use as a west end development well. The well was never used for this purpose, and BPXA elected to complete the abandonment of the well in 2007, as the remote pad on which it is located was scheduled for remediation and gravel recovery. The P&A work consisted of recovery the 200 ft. diesel cap which was placed in the well for freeze protection, setting a CIBP in the intermediate casing below the diesel/brine interface, punching the intermediate casing above the CIBP to access the arctic pack in the 9 5/8" x 13 3/8" annulus, recovery the arctic pack above the punch, and setting top plugs in both the 9 5/8" x 13 3/8" and the 9 5/8" casing. Once this work was completed, the area around the well was excavated, and all casing strings cut 4 ft below the original tundra level. A steel subsurface marker plate was installed to complete the abandonment, and the excavation backfilled. All work was inspected and approved by AOGCC representatives. Attachment I shows the final P&A condition of the well. P&A Ouerations Summary: March 4-5, 2007: Wrapped wellhead with parachute and applied heat. Serviced valves and replaced gauges. March 31, 2007: Pressure tested 9 5/8" casing to 1000 psi. Test OK. Bled off pressure. Moved in slickline unit and drifted well. Tagged top of cement plug in 9 5/8" casing at 2302 ft. POH and made up gradio tool to locate diesel brine interface. Interface found at 205 ft. Pressure tested 9 5/8" casing and 9 5/8" x 13 3/8" annulus in preparation for punch of 9 5/8" casing. April 1, 2007: Ran junk basket with 8.5" gauge ring on drift and correlation pass to 310 ft. Set Baker CIBP at 220 ft., which is 15 ft. below diesel brine interface. Pressure tested tree and 9 5/8" casing down to CIBP to 3000 psi. Repaired tree leak at flange connection, and re-tested. Test OK. Shot tubing punch in 9 5/8" casing under 1000 psi overbalance 208 -210 ft. to access arctic pack in 9 5/8" x 13 3/8" annulus. Communication confirmed. Bled off casing and annulus to zero. • Apri17, 2007: Rigged up for arctic pack flush. Pumped tota172 bbls hot diesel down 9 5/8" casing, in several cycles, taking returns up 9 5/8" x 13 3/8" annulus into open top tank. At end of job, calculated that ~ 4 bbls arctic pack remained in annulus, and is unrecoverable. Bled off pressures to zero. April 15, 2007: MIRU to set top cement plugs in 9 5/8" casing and 9 5/8" x 13 3/8" annulus. Pumped 2.5 bbls methanol spear and 100 bbls fresh water down casing and up annulus, followed by 33.6 bbls cement. Cement to surface with 28.6 bbls cement pumped. Flushed lines, rigged down and moved out. AIC starting excavation around well. April 16-25, 2007: Excavating to 6 ft. below original tundra surface around all wells on pad. Constructed ramps to access excavations. Apri128, 2007: Moved in crane, and rigged slings on wellhead. Rigged up Wachs saw and cut all casing strings 4 ft. below original tundra surface. Recovered wellhead and cut off casing from excavation. Aril 29, 2007: AOGCC representative inspected and approved top plugs. Installed steel subsurface marker plate and backfilled excavation. • ~J BP Exploration (Alaska) Inc. Well No. PBU MP 22-31-11-13 No. 2 PTD: 181-010 API No.: 50-029-20545 ATTACHMENT I Post Abandonment Condition / Subsurface marker plate 1~/ (installed 4' below original tundra surface) No Scale Cmt Plug in 9-5/8" 2500' - 2360' (140') Notes: 1. All depths are MD Cement '~'~;~' ~;~'~' Arctic Pack CaC12 Brine Drilling Mud 20" conductor @ 110' CIBP @ 220' TOC @ 2215' in 13-3/8" X 9-5l8" annulus FO Collar @ 2616' 13-3/8" L-80 @ 2685' Est. TOC approx. 5830' Cmt Plug 9490' - 9630' (140' ) Bridge Plug @ 9630' Liner Top @ 9656' 9-5/8" L-80 @ 10,195' 7" L-80 @ 11,228' (TD) , . . SARAH PALIN, GOVERNOR A'i,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Douglas Cismoski Wells Team Leader BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 ,,'Ù \D ,C6 Re: Prudhoe Bay Field, Exploration, PBU MP 22-31-11-13, No.2 Sundry Number: 307-037 ~~;,~~Nen FEs 2 6 2007 Dear Mr. Cismoski: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Encl. . . E & P SERVICES, INC. January 24, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Attention: Tom Maunder, P.E., Petroleum Engineer Re: Application for Sundry Approvals, Form 10-403 B. P. Exploration (Alaska) Inc. (BPXA) PBU MP 22-31-11-13 No.2. PTD No. 181-010 Dear Mr. Maunder: Please find attached the above referenced application and supporting documentation to plug and abandon the PBU MP 22-31-11-13 No.2 well, and install a subsurface marker plate. This work is necessary in order for the remediation of the Kuparuk 30-11-13 pad to be able to proceed during the first quarter of 2007. If you have any questions after reviewing the application, please contact the undersigned at 907 258 3446, or Douglas Cismoski at BPXA (907 564 4303). AS~incer..~ / ~. ,. ~~ I' .. .>_~ ~<---- R. C. Gardner Sr. Technical Advisor Fairweather E & P Services, Inc. Attachments cc. Douglas A Cismoski, P. E. , BPXA Chuck Stilwell, BPXA 2000 East 88th Avenue· Anchorage, Alaska 99507 . (907) 258-3446· FAX (907) 279-5740 650 North Sam Houston Parkway East, Suite 505· Houston, Texas 77060· (281) 445-5711 . FAX (281) 445-3388 ~ . ~~JDÃJ1 z/J.../!l ~ RECEIVED "'_. ..... ~. " - ,,,.~-,.._. -.--.., \~ J/.\N 2 6 2007 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 operational shuldown 0 Plug Perforations 0 Perforate New Pool 0 4. Current WeD Class: Development StraUgraphic 0 Suspend 0 Repair well 0 Pull Tubing 0 Perforate 0 Waiver 0 Stimulate 0 TIme extension 0 Re--enter Suspended Well 0 5. Permit to Drill Number: _".(, Exploratory 0 181-010 .¡ ,~~ Service 0 6. API Number:..,) 50.029-20545-00 j 8. Well Name and Number: AlasKa OiJ ~1 Gas Cons. COOlmi IOn Anchorage Other 0 Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: SP Exploration (Alaska) Jnc. 3. Address: PO Box 196612 Anchorage, AI< 99519·6612 7. If perforating, closest approach In pool(s) opened by this operation to nearest property line where ownership or landownership changes: Nt A Spacing Exception Required? Yes 0 No 0 PBU MP 22-31-11-13. No.2 j 9. Properly Designation: 10. KB Elevation (ft): 11. FieldlPool(s): ADL 28288 ./ 75.31 ft ¡ Prudhoe Sa 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): J Total Depth TVD (ft): j EffèCtive Depth MO (ft): Effective Depth TVD (ft): Plugs (measured): _ 11230 9657 2360 2360 9360-9490, 2500-2360 Length Size MD TVD Burst Intermediate Production LIner Perforation Depth MD (ft): No Perfs Packers and SSSV Type: 11020" 2685 13318" 10195 9518- 110 2685 10195 110 2686 8800 5380 6870 2670 4750 i f I I I ~ I ( I t Junk (measured): None Casing Slnictural Conductor Surface Collapse 1572 7" Perforation Depth TVD (ft): N/A No packers or SSSV Tubing SIze: No Tubing 9656 Tubing Grade: N/A Packers and SS5V MD (ft): N/A 11228 8160 Tubing MD (ft): N/A 7020 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for First Quarter, 2007 Commencing Operations: 17. Verbal Approval: Commissfon Representative: 18. I hereby certify that the foregoing ts true and correct to the best of my knowledge. Conlact Printed Name Douglas A Clsmoski Title Wells Team Leader, Alaska Drilling and Wells Signature Phone Date 5b't-YJc.3 COMMISSION use ONLY Date: 14. Weft Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas 0 o GINJ 0 Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 t l.:Y. "::f Conditions of approval: Notify Commission 80 that a representative may witness Sundry Number: :!JD 7 ., 0 g') I Plug Integrity ~, BOP Test.O Mechanical Integrity Test 0 , Location Clearance J:] '. _ \ '\. . I Other: ~\:-i~~_~'o\r S\t'...C-~ \,6cl ~\ " '0<2:- ~ ~-..)~~ ~<:> ~ \~~ ~ ~~C.I t> 'Ì ..... h \ _ ~ \ . _ _ .\ ('(' Þc~c.ç:., \~\.'\.O"'C\e!o...~~<:j~~'''~. ~\>.'Y"'. ,,~~ 'f\; ,-,b~O"",,- ~ u..:;)\. ~c;.<? ~ - [\ C"\ \ , \-~~S-, 'D\<¿ ·~,~,,~.,,~)(:)\·..e' ~Cè\\~O~ . Fonn 10~03 ~ ÕR \ G \ APPROVED BY THE COMMISSION Subsequent Fonn Required: l-\. \) Daæ: ~~/~o:t Approved by: 7~mit In Duplicate ~vv/ . . Summary of Proposed Work BP Exploration (Alaska) Inc (BPXA) P&A Program PBU MP 22-31-11-13 No.2 PTD: 181-010 API No: 50-029-20545-00 Back2round Information and Present Well Condition PBU MP 21-31-11-13 No.2 is located within the Western Operating Area ofthe Prudhoe Bay Unit on an exploration pad situated approximately 1.6 miles due south of "1]" pad, and adjacent to the road connecting "u" and "P" pads. The well was drilled, logged, cased and suspended in early 1981 by Sohio Alaska Petroleum Company (now BP Exploration (Alaska) Inc.) on behalf of other owners, as one of several "PBU MP Tract" wells that were drilled in the same general time frame as part of the process of determining ownership percentages in the Prudhoe Bay Unit. The well was suspended while being considered for use in West End development. The well was directionally drilled to a total measured depth of 11,230 ft, and is cased as follows: CASING SIZE WEIGHT GRADE DEPTH CEMENTING RECORD (MD) Conductor 20" Unknown Unknown 110ft To Surface, Volume Unknown ~ Surface 13 3/8" 72# L-80 2685 ft 3720 cu ft permafrost II cmt to surface. / Intermediate 9 5/8" 47# L-80 10,195 ft Cemented in two stages. Stage 1: 1524cu ft class "G" .,¡ Stage 2: 130 cu ft permafrost through FO@ 2616' Production 7" 29# L-80 11 ,228 ft 420 cu. ft. class "G" Liner Top@ 9630 The 13 3/8" x 9 5/8" annulus is filled with arctic pack which was placed through an FO collar at 2616 ft, and then followed by 130 cu ft of permafrost cement. While cased as a production well, the well was,.never perfor~and completed. A CIBP 1 and cement plug isolates the liner from the rest of the well, and there is a cement plug in the 9 5/8" casing at 2500' - 2360'. The well bore is filled with 9.8 ppg CaCh brine, except for the top 200 ft which is filled with diesel. There is no tubing in the well. The wellhead remains in place, as does the original cellar. Attachment I shows the present condition ofthe well. . . Proiect Obiectives / The PBU MP 22-31-11-13 No 2 well is located on the same exploration pad as the Kuparuk: 30-11-13 well which was plugged and abandoned in 1976 and the MP Tract Well 32-33-11-13 which is also suspended. BPXA now desires to remediate this pad, and removal ofthese three wells, is necessary to this objective. Following the P&A work in the two suspended wells, all three wells will be cut off 4 ft below the original tundra surface. The work described herein is scheduled for the first quarter of 2007. .; Site Access Access to the well location is via a 14 mile long secondary gravel road which branched ¡ off the primary road connecting "U" and "P" pads. A minimal amount of regrading will be necessary for this road to accept North Slope oilfield equipment required for the removal of all three wells, and the earthmoving equipment required for the follow-on pad remediation work. Eauipment and Materials The equipment spread for the well work includes the following: Trucks and support vehicles, as required. Heated wellhead enclosure Hot air heater( s) 966 Loader or equivalent Cat 240 Excavator or equivalent 2 ea 100 bbl open top tanks Wachs Saw Fuel truck, as required 3 ea light towers and generators Vacuum truck or supersucker E-line Unit 1" steel Pipe Mechanics Shop (Weld/Cut/Maintenance, etc.) Crew warm-up shelter/Office Unit 60 ton hydraulic crane Cement mixing and pumping unit Cement Hoses and lines for connecting wellhead to tanks, etc. 1 Lot, valves, fittings, tools, etc. 1 Lot, Oil spill contingency equipment Cellular telephones Air Monitor/gas detector 2 ea, trash dumpsters (scrap steel and combustible waste) . . P&A Operations Pro2ram. PBU MP 22-31-11-13 No.2 Attachment II shows the post abandonment condition ofthe well, and the detailed .¡ operations program is defined in Attachment III. The P&A work basically involves setting a CIBP below the brine/diesel interface, and ¡ then simultaneously setting a cement surface plug on top ofthe bridge plug and displacing the diesel using a water spacer ahead of the cement. The job is anticipated to require up to 5 days, not including the time required for ice road J construction. This estimate assumes 24 hour work days. No Scale . . BP Exploration (Alaska) Inc. Well No. PBU MP 21-31-11-13 NO.2 prD: 181-010 API No.: 50-029-20545 ATTACHMENT I Wellbore condition as of January 2007 (Well Suspended) Diesel: Surface to 200' (29.6 bbls) Cmt Plug in 9-5/8" 2500' - 2360' (140') Notes: 1. All depths are MD IJ~ ~~ ~~ ~~ ~~ ,,I.I ,',',1. ,t,tlt, D rnm I2ill [ill, , < < < " , < < < " , < <, Cement Arctic Pack CaCI2 Brine Drilling Mud Diesel Wellhead in place but not shown ~ ::' ««««««««« ::: ; :1: :::;:::;:;:;:;:;:;:;:;:;:;:;:;:::;:; .:' ~ ::. :;:;:;:;:;:;:;:;:;:;:;:;:;:;:;:::;:; ::: ~ ::: :;:;:;:;:;:;:;:;:;:;:;:;:;:;:;:;:;:; ::: ~ :: ~~<)~~<)<)<)<)c)c)c)c)c)<)<)<)<)<)<) ::: ~ I'. 1,1 ~ .'. III ~ ,I III § ::: 9.8 ppg ::: ~ ,', C CI ,,' I I "~"~~"~'~ -, 9i:~~,9 ~ ~ ~ ~ ~ ~ 9.8 ppg CaCI2 20" conductor @ 110' TOC @ 2215' in 13-3/8" X 9-5/8" annulus FO Collar@ 2616' 13-3/8" L-80 @ 2685' Est. TOC approx. 5830' Cmt Plug 9490' - 9630' ( 140' ) Bridge Plug @ 9630' Liner Top @ 9656' 9-5/8" L-80 @ 10,195' 7" L-80 @ 11,228' (TO) . No Scale . . BP Exploration (Alaska) Inc. Well No. PBU MP 21-31-11-13 No.2 pro: 181-010 API No.: 50-029-20545 ATTACHMENT" Post Abandonment Condition Cmt Plug in 9-5/8" 2500' - 2360' (140') Notes: 1. All depths are MD &1- -- -- -- ,1)1,', ::::::: D rom I1lliJ Cement Arctic Pack CaClz Brine Drilling Mud / :: §§§§§~~§~§§~§§§§§§::: I: ~~~~~~~~~~~~::£~~~~~::: :: I §§§§§§§§§~§§§§§§§§ : I: :.1 E£~~~E£E£:E~~E£~~~~~~~~ I: I I : I ~~E£~E£~~~~E£~~E£~E£E£~E£ ::: I. II I, ,I, " 1'1 I. .1. :' I:' ,', 9.8 ppg ',' I: :': " CaCI2 ,', 9.8 ppg CaCb :>: - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~~~~~~:;::::::::::::::::~::::::::::::::::::::::::::::::::::~:::::: .,. 9.8 ppg CaCI2 Subsurface marker plate (installed 4' below original tundra surface) 20" conductor @ 110' CIBP @ 215' TOC @ 2215' in 13-3/8" X 9-5/8" annulus FO Collar @ 2616' 13-3/8" L-80 @ 2685' Est. TOC approx. 5830' Cmt Plug 9490' - 9630' ( 140' ) Bridge Plug @ 9630' Liner Top @ 9656' 9-5/8" L-80 @ 10,195' 7" L-80 @ 11,228' (TD) . . .---- Attachment III BP Exploration (Alaska) Inc. PBU MP 22-31-11-13 No.2 PTD 181-010 API No: 50-029-20545-00 Well P&A Operations Program Summary of Present Condition This well was drilled, logged, cased, and suspended in early 1981. For a time the well was under consideration for use as a west end development well, but the well was never perforated or otherwise completed for this purpose. In the 26 years that the well has been suspended, the location has often been inaccessible to service vehicles, and the condition of wellhead valves is unknown. Since this P&A program involves the use of the wing valves on the wellhead that access the 9 5/8" casing, these valves will need to be serviced or replaced before P&A operations begin. There appears to be no reason to question the integrity of the casing and downhole plugs in this well, however, pressure measurements should be made on the 9 5/8" casing and the 9 5/8" x 13 3/8" annulus before operations are started. This operations program is based on the assumption that the P&A work will be conducted under winter conditions. P&A Proeram 1. Re-grade the access road from the primary road system to the location (approximately 0.25 miles). 2. Clear snow and re-grade pad as necessary to accept P&A equipment spread. Install wellhead shelter, and rig up hot air heater. Apply heat to wellhead shelter for approximately 24 hours before starting P&A operations. Use this period to mobilize equipment to the location. 3. Thaw ice in well cellar and pump dry. This is necessary to access all wellhead valves and to provide cellar capacity. Observe and record pressures on 9 5/8" casing and on 9 5/8" x 13 3/8" annulus. Grease and service wing valves on wellhead that access 95/8" casing. Replace if necessary. Make thorough and complete diagram of wellhead. 4. Remove top flange on wellhead to access 9 5/8" casing. Make e-line run with density tool to determine diesellbrine interface, reportedly at 200 ft. 5. Make e-line run to set CIBP in mid-joint at approximately 250ft, or 10ft below diesellbrine interface, which ever is greater. Test CIBP to 1500 psi from surface. '~'='=,' ~ ~ ~ ¡ ! I ~ I i , , I ¡ ¡ ¡ i I I , ¡ ¡ I I I I I I ¡ I I ~ I ~ ~ I ! I ..D'^ 7\", oi'ff " Þ'~ · _ _.__________v..._ '..--.- "',...,~~.~=..""'~~=. - ~._....~"-,._,.~-'.,.:ç--.._,_..-.~.....:.': ¡ 8. Pump hot oil down 13 3/8" x 9 5/8" annulus. After two annular volumes, switch to pumping down 9 5/8" casing and take returns up annulus. Continue these alternate circulations until 13 3/8" x 9 5/8" annular returns are clean, or until the maximum recovery of arctic pack has been obtained. Rig down hot oil unit. ~ ü. ~ ~ ~ ¡ i I j f ¡ i i ¡ I I I I ¡ ¡ I ! I I I I 6. Rig up to punch 9 5/8" casing 5ft above CIBP. Use 4 JSPF and punch casing through a 2' intervaL 7. Rig up hot oil unit for arctic pack flush and prep to pump 1200 F diesel down the 13 3/8" x 9 5/8" annulus and out the 9 5/8" casing, as well as down the casing and up the annulus. Have sufficient tankage on site to handle maximum anticipated waste stream from both arctic pack flush and setting of surface plug. 9. Recalculate cement volume required to set surface plugs in the 9 5/8" casing, and in the 13 3/8" x 9 5/8" annulus based on the fmal setting depth of the CIBP. Rig up cementers. Have contingency string of 1" steel pipe available for placing plug in 9 5/8" casing if necessary. I I I I ~ I I i ª I ¡ ¡ , I ! ! ¡ 12. Rig up Wachs Saw. Rig up support/lifting slings, and loader or crane to support I wellhead. Cut all casing strings 4 ft below original tundra surface; Remove wellhead " and cut-off casing sections. 13. Fill any voids in annular spaces with cement and photo-document cement at surface I before installing subsurface marker plate. ~o\-\~ 3:~~~'-----t)v\-'taí'., ~ ~~~ 4 14. Weld subsurface well marker plate on outermost casing as per 20 AAC 25.120(a) (b) I and (d). Backfill excavation to top of original tundra surface, or as otherwise directed ! by BPXA Remediation Management personnel, as per 20 AAC 25.170. I I I ! ! ¡ 15. Clean up location and obtain fmallocation inspection trom AOGCC, and DNR (if required). 10. Batch mix required permafrost cement slurry volume. Retard sturry to have 4 hour thickening time. Pump down 13 3/8" x 9 5/8" annulus with 5bbl MEOH spacer followed by cement slurry. Takereturns out 9 5/8" casing wing valve to waste tan1e If perforations plug with residual arctic pack remaining in annulus, be prepared to Rill with contingency 1" open end steel pipe and complete setting surface plug, by pumping down 1" line. Leave steel pipe in place after plug is set. Rig down cementers. 11. While WOC, excavate and remove well cellar. Segregate any contaminated gravel as directed by Oasis representative. Extend excavation to 6 ft below original tundra surface. File new 10-407 report with AOGCC referencing abandoned status of well. "Ð~ ^ d'\~ \ref ' . . . ...,.,.,.... . -.'- - Notes: (1) Advise AOGCC North Slope Inspectors a minimum of 24 hours in advance of setting all plugs. (Telephone: 659~2714; Pager: 659-3607) (2) Hold safety meeting before starting anyon-site operations, and before all subsequent critical operations. ; ,:.~ ,,::'; ;:;;:~'';;-~_<"'::-':,:~~;''-~~''':'~.:,::l.,C:;;~:ê~;,·;;:::~..,...:",:;;,¡;..;¡;;;.",,~.,-. ~9vJ'l -0\ r r 1'\ \""' ¡ ! ¡ ~ ¡ , ! ~ , I ! ¡ I i ¡ f: ¡ ~ î ! , ~ f ! ¡ ! I i ¡ , ! , [ ¡ I ~ ~ ; ~ ~ I If ~ m I E ~ ì f. ! I I i r !, I t i f g I ~ .. í f ¡ ¡ , I ¡ ! I j i ¡ ¡ j i . , ¡ ! I I .' ; . Attachment III BP Exploration (Alaska) In . PBU MP 22-31-11-13 No PTD 181-010 API No: 50 29-20545-00 Well P&A Operations . .. Summary of Present Condition This well was drilled, logged, cased, and sus ended in early 1981. For a time the well j was under consideration for use as a west d development well, but the well was never perforated or otherwise completed for thi purpose. In the 26 years that the well has been suspended, the location has often been i accessible to service vehicles, and the condition of wellhead valves is unknown. Since his P&A program involves the use of the wing valves on the wellhead that access th 9 5/8" casing, these valves will need to be serviced or replaced before P &A op tions egin. There appears to be no reason to question the integrity of the casing and äo e plugs in this well, however, pressure measurements should be made on the 9 5 8" ca ng and the 9 5/8" x 13 3/8" annulus before operations are started. This operati am is based on the assumption that theP&A work will be conducted under win ('aitions. r P&APrOl!ram 'd\<:'~~ 1. d from the primary road system to the location (approximately 2. Clear snow and r grade pad as necessary to accept P&A equipment spread. Install wellhead shelter and rig up hot air heater. Apply heat to wellhead shelter for approximately 4 hours before starting P&A operations. Use this period to mobilize equipment to e location. 3. Thaw ice in ell cellar and pump dry. This is necessary to access all wellhead valves and to proy¡ de cellar capacity. Observe and record pressures on 9 5/8" casing and on 9 5/8" x 1 3/8" annulus. Grease and service wing valves on wellhead that access 9 5/8" c ing. Replace if necessary. Make thorough and complete diagram of wellhe . 4. Rem ve top flange on wellhead to access 9 5/8" casing. Make e-line run with density tool 0 determine diesel/brine interface, reportedly at 200 ft. 5. calculate cement and water spacer volumes based on exact depth of interface. ake E-line run to set CIBP at approximately 10 ft below interface. ,,' (" ,¡ . . 6. RIH with open end 1" steel pipe to bridge plug. Rig up batch mixer, pump 1 0 bbl water spacer followed by permaftost cement surface plug (volume as determined ftom recalculation in step 5 above) down 1" steel pipe. Fill 9 5/8 ásing to surface. Take diesel and spacer returns out wing valve to super-sucker Q waste tanle Note: preliminary estimate of diesel volume is 29.6 bbls). Leave ' steel pipe in place. Rig down cementers. 7. While WOC, excavate and remove well cellar. Se gate any contaminated gravel as directed by Oasis representative. Extend excava . n to 6 ft below original tundra surface. 8. Rig up Wachs Saw. Rig up support/liftin slings, and loader or crane to support wellhead. Cut all casing strings 4 ft be w original tundra surface. Remove wellhead and cut-off casing sectio 9. Fill any voids in annular before installing sub sur ce Ith cement and photo-document cement at surface er plate. 10. Weld subsurface well m r plate on outermost casing as per 20 AAC 25. 120(a) (b) and (d). Backfill exca on to top of original tundra surface, or as otherwise directed by BPXA Remediati~ anagemen: 1\sonnel, as per 20 AAC 25.170. 11. Clean up location bta~l~ati~n inspection ftom AOGCC, and DNR (if required). u1 CQ\... ~ "ftY File new 10-407 re rt with AOGCC referencing abandoned status of well. (1) Advise AOGCC North Slope Inspectors a minimum of 24 hours in advance of setting all plugs. (Telephone: 659-2714; Pager: 659-3607) (2) Hold safety meeting before starting anyon-site operations, and before all subsequent critical operations. RE: FW: Scan ITom a Xerox WorkCentre Pro . . Tom: I believe it will be at least 10 days, if not longer, before BP is ready to deal with these wells. If I hear anything more definitive I'll let you know. Regards, Bob -----Original Message----- From: Thomas Maunder lto:tom maunder@admin.state.ak. Sent: Friday, February 16, 2007 3:01 PM To: Bob Gardner Subject: Re: FW: Scan from a Xerox WorkCentre Pro Bob, The revisions look good. Any idea when the work might take place? Tom Bob Gardner wrote, On 2/16/2007 1:29 PM: Hello Tom: At long last here are the revised procedures for the Tract wells which describe the steps for the arctic pack flush. Please advise if you have any questions. Thanks, Bob -----Original Message----- From: Xerox3545@fairweather.com lto:Xerox3545@fairweather. .............·..M._........._...._........................_..._...._............ m.mm............_......... Sent: Friday, February 16, 2007 12:18 PM To: Bob Gardner Subject: Scan from a Xerox WorkCentre Pro Please open the attached document. using a Xerox WorkCentre Pro. It was scanned and sent to you Sent by: Guest [Xerox3545@fairweather.com] Number of Images;--5i------------------ Attachment File Type: PDF k \ . . h Wor Centre Pro Locatlon: Falrweat er Inc Device Name: Xerox3545 For more information on Xerox products and solutions, please visit h~t:J2,:j/~~!""'!:_~g!::9.~:",c::9r!1 1 ofl 2/16/2007 3: 14 PM Re: BP P&A's . . Doug, Any update on the P&A work? Also, I will need a revision regarding the procedure to attempt to remove the arctic pack from the depth of the surface plug. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 1/3012007 1 :49 PM: Thanks Doug. I've been out myself. Talk to you later. Cismoski, Doug A wrote, On 1/3012007 10:28 AM: I'm stepping out the door but I don't know the exact timing of the P&A's. I have a question in to the pad remediation manager for an update. 1 of 1 2/2/2007 7:55 AM .. ,_..... ~.. \'-' t-' '-"". U-., "- "- . L .-'- . Subject: Re: Kuparuk~ From: Thomas nder <tom_maunder@admin.state.ak.us> Date: Fri, 02 F 07 13:15:02 -0900 To: "Cis . Doug, I got your message. I agree that there are some issues to sort out prior to punching or cutting. What you propose with regard to removing the diesel from the well should work. Thanks for addressing these matters. Call or message with any questions. Tom Maunder, PE AOGCC Cismoski, Doug A wrote, On 2/2/2007 12:52 PM: Tom - We need to verify we have T x IA comm. This wasn't clearly defined but there is evidence that leads us to believe that the MIT-IA done early on may have been against an ice plug in the annulus. We'll know more during the upcoming pressure tests and will keep you updated. I left you a message on your voicemail, but we can shoot holes below 500' MD in the 4-1/2" tubing to circulate out the diesel if the communication isn't existent or sufficient. We will do what we can to ensure the diesel is removed. I'm waiting on a developing another revised plan until we can confirm the mechanical integrity of the tubing. My goal is to ensure we have a clear understanding of the well's mechanical condition before proceding with any further punches or cutting the tubing. Doug -----Original Message----- From: Thomas Maunder - Sent: Friday, February 02, To: Cismoski, Doug A Cc: Lou Grimaldi; Bob Gardner Subject: Re: Kuparuk 22-11-12 maunder@adrnin.state.ak.us 1 : 53 AM Doug, Thanks for responding. You are correct on the regulatory reference. What you propose looks acceptable, with one note. In the last years it has been the practice not to leave diesel in wells if at all possible. I went back and looked at the original proposal and I see where diesel was proposed in the displacement fluid to avoid it running away. I missed that the diesel would be left in the tubing. Do you have any indication of where the tubing might be communicating to the annulus? It may be that you have to tag the plug which is acceptable. Is the communication path sufficient to reverse the diesel out of the tubing? Call or message with any questions. Tom Maunder, PE AOGCC Cismoski, Doug A wrote, On 2/2/2007 10:37 AM: of4 2/16/20072:32 PM ~"'....,- ~ ,y. ~.........t-'''''''<'''''''H..:........ ~ 1 .1.:.... . . Bob and Doug, One other item has "surfaced" with regard to the upcoming work on this well. As noted in our conversations, the reported surface pressure is suspect due to the age of the well and unknowns regarding the reliability of the gage and the condition of the T check. The actual well pressure should be accurately known as the work proceeds. The present weight of fluid reported in the annulus is 9.6 ppg (if I read the drawing correct). Leaving this fluid in the well is according to the regulations so long as the hydrostatic pressure is sufficient to overbalance the reservoir pressure. See 20 AAC 25.112 (f). Call or message with any questions. Tom Maunder, PE AOGCC Bob Gardner wrote, On 1/24/2007 9:41 Ñ~: Good Morning, Tom Here are the revisions to 22-11-12. I went ahead and fixed a couple of typos in the first section as well, hence you have a completely new submittal to replace the one that was attached to the Sundry. I don't think any changes are required on the Sundry. Thanks for you help with this. Give a call if you have any questions. Regards, Bob -----Original Message----- From: Xerox3545@£airweatlier. corn Ita: Xerox] 54S@£airweather. ._--....._.........-..-....,,- ................. .. ......-..... Wednesday, January 24, 2007 10:43 To: Bob Gardner Subject: Scan from a Xerox WorkCentre Pro Sent: Please open the attached document. It was scanned and sent to you using a Xerox WorkCentre Pro. Sent by: Guest ¡Xerox354S@:Eairweat:her. com] Number of Images: 8 Attachment File Type: PDF WorkCentre Pro Location: Fairweather Inc Device Name: Xerox3545 For more information on Xerox products and solutions, please visit ht .xerox.com I of! 2/16/20072:32 PM BP EXPLORATION February 21, 1996 900 East Benson Boulevard ~~. Box 196612 ~chorage, Alaska 99519-6612 (907) 561-5111 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Designation Of Operator Suspended Wells in the PBU West End Dear Dave: I am following up my letter of September 30, 1994 in which I indicated that BPX would contact the owners of seven suspended wells in the PBU West End which BPX operated under provisions of the Prudhoe Bay Unit Operating Agreement. The wells have been suspended for between 14 and 16 years and are listed on the attachement. Chevron USA Inc., has assumed operatorship of the Chevron #23-18-11-12 well. Executed Designation of Operator forms evidencing the change in operatorship are transmitted herewith for your further action. Please feel free to contact me if you have any questions regarding this matter. Sincerely, Stu Hirsh, CPL Senior Landman CdC vED FEE) 25 1996 Gas Con-;. ,.~, ........... A,.~orsge. Suspended BP Operated MPC / Chevron Wells Well Name AP! Number I Susp. Date Term Well C 029-20356-00 04/25/79 MPC Tract Well 3-10-12 029-20483-00 10/11/80 'MPC Tract Well 11-33-11-12 029-20504-00 04/29/81 Chevron Tract Well 23-18-11-12 029-20511-00 12/24/80 MPC Tract Well 31-11-13 029-20536-00 02/20/81 MPC Tract Well 32-30-i1-13 029-20546-00 01/18/81 MPC Tract Well 22-31-11-13 029-20545-00 02/14/81 ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name of Owner Chevron U. S. A. Inc. 2. Address P. O. Box 1635 Houston, Texas 77251-1635 Attn: Manager - Non-Op. Joint Ventures 3. Notice is hereby given of the designation of operatorship of the oil and gas properties described below: Well Name andAP! Number: Chevron Tract Well #23-18-11-12 029-20511-00 Property Plat Attached r--i 4. Name of Designated Operator Address Chevron U. S. A. inc. P. O. Box 1635 Houston, Texas 77251-1635 Attn: Manager- Non-Op. Joint Ventures 5. Effective Date of Designation December 1, 1995 6. AcCeptance of operatorship for the above property with all attendant responsibilities and obligations is hereby acknowledged. . Signed ~.~ ,~/~ Title )/~¢~,,. ~ u ~,~ Date 7.The ov/%r~r hereby certifies that the foregoing is true and correct . Signed ~A-4/~ Title ¢,~ Ag u., s.¢-"~_.~ Date ' Submit in Duplicate ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name of Owner Chevron U. S. A. inc. 2. Address P. O. Box 1635 Houston, Texas 77251-1635 Attn: I~3nager- Non-Op. Joint Ventures 3. Notice is hereby given of the designation of operatorship of the oil and gas properties described below: Well Name and APl Number: Chevron Tract Well #23-18-11-12 029-20511-00 Property Plat Attached [] 4. Name of Designated Operator Address Chevron U. S. A. Inc. P. O. Box 1635 Houston, Texas 77251-1635 Attn: Manager- Non-Op. joint Ventures 5. Effective Date of Designation December 1, 1995 6. Acceptance of operatorship for the above property with all attendant responsibilities and obligations is hereby acknowledged. 7.The o~'~ hereby certifies that the foregoing is true and correct Date ~//'~//~ / ¢ Date 'L//3//.'~'¥' Submit ih Duplicate BP EXPLORATION BP Exploration (Alaska)Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 16, 1995 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Designation Of Operator Suspended Wells in the PBU West End Dear Russ: ! am following up my letter of September 30, 1994 in which I indicated that BPX would contact the owners of seven suspended wells in the PBU West End which BPX operated under provisions of the Prudhoe Bay Unit Operating Agreement. The wells have been suspended for between 14 and 16 years and are listed on the attachement. Mobil Oil Corporation, operator of the Mobil Phillips Chevron Joint Venture, have decided to assume the rights and obligations of operator of six of the wells. Executed Designation of Operator forms evidencing the change in operatorship are transmitted herewith for your further action. We only recently learned that the 18-11-12 well was drilled sole account for Chevron. Consequently, we are in the process of contacting them relative to their plans for the well and will advise you according when we find out. Please feel free to contact me if you have any questions regarding this matter. Sincerely, Stu Hirsh, CPL OCT 1 9 1995 Senior Landman Alaska Oil & Gas Cons. Commission Anchorage Suspended BP Operated MPC / Chevron Wells Well Name APl Number Susp. Date Term Well C ' 029-20356-00 04/25/79 MPC Tract Well 3-10-12 029-20483-00 10/11/80 MPC Tract Well 11-33-11-12 029-20504-00 04/29/81 Chevron Tract Well 18-11-12 029-20511-00 12/24/80 MPC Tract Well 31-11-13 029-20536-00 02/20/81 MPC Tract Well 32-30-11-13 029-20546-00 01/18/81 MPC Tract Well 22-31-11-13 029-20545-00 02/14/81 o_ . OCT 9 1995 Nas~ Oil.& Gas Cons. Commission ~chorage ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name of Owner. Mobil Oil Corporation 2. Address P. O. Box 650232 Dallas, Texas 75265-0232 3. Notice is hereby given of the designation of operatorship of the oil and gas properties described below: Well Name and APl Number: MP Tract Well 3-10-12 Well Name and APl Number: MP Tract Well 11-33-11-12 Well Name and AP! Number: Well Name and APl Number: Well Name and APl Number: Well Name and APl Number. MP Tract Well 31-11-13 MP Tract Well 32-30-11-13 MP Tract Well 22-31-11-13 Term Well C 029-20483-00 029-20504-00 029-205 ~. ~-00 029-20536.00 029-20546-00 029-20545-00 029-20356-00 Property Plat Attached r'l 4. Name of Designated Operator Address Mobil Oil Corporation P. O. Box 650232 Dallas, Texas 75265-0232 5. Effective Date of Designation OCT t 9 199,5 August 1, 1995 Gas Cons. Commis,~ ~chorage 6. Acceptance of operatorship for the above property with all attendant responsibilities and obligations is hereby acknowledged. 7.The owner hereby c~'rtifi(~ that the foregoing is true and correct ° - k/ Signed~.~-A Title Submit ih Duplicate 0il ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name of Owner Mobil Oil Corporation 2. Address P. O. Box 650232 Dallas, Texas 75265-0232 3. Notice is hereby given of the designation of operatorship of the oil and gas properties described below: Well Name and APl Number: Well Name and. AP! Number:. MP Tract Well 3-10-12 MP Tract Well 11-33-11-12 029-20483-00 029-20504-00 Well Name and APl Number: MP Tract Well 31-11-13 029-20536-00 Well Name and AP! Number: Well Name and APl Number: Well Name and APl Number'. MP Tract Well 32-30-11-13 MP Tract Well 22-31-11-13 Term Well C Property Plat Attached I'"I 029-20546-00 029-20545-00 029-20356-00 4. Name of Designated Operator Address Mobil Oil Corporation P. O. Box 650232 Dallas, Texas 75265-0232 5. Effective Date of Designation 0CT 1 9 1995 August 1, 1995 '.-, ~ohorag, 6. Acceptance of operatorship for the above property with all attendant responsibilities and obligations is hereby acknowledged. SignedkJ~,,~ '~_0.__ '~.,,-,....~-~ Title E.~,.4~E,~- 6- ,/~O,,i,~'o¢,.bate ~ / Z(,,/'~ 7.The owner hereby certifi~ that the foregoing is true and correct ' ' Signedt~3,A.~ .ritle~t6~E,¢,/~,, ,&-o,,ll.$'o P'"SubmitDate ~/'Z, fcifl Duplicate/~l r MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David,~~ DATE: Chairrna"n THRU: Blair Wondzell, --~~ FILE NO: P. I. Supervisor ,~o1~ FROM: John Spaulding,Q~. SUBJECT: Petroleum Insp. i)~,~-¢t~ October 2, 1994 2991jbbd.doc Suspended Wells Inspection North Slope, Alaska October. 1,2&3, 1994,.: I accompanied Marian Sloan BPX representative on an inspection tour of BPX suspended wells at various North Slope locations. Travel was by pickup and helicopter. Marian Sloan Informed me that BPX is drafting a program with reasons for leaving wells listed below as suspended, this program will be available to the AOGCC in the very near future Oct. 1,1994 Y-22A / PBU / PTD 88-115; well head on configuration, no pressure on tubing or annulus, area very clean, well is located on a producing drillsite. S-10A / PBU / PTD 91-123; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. U-01 / PBU / PTD92-11; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. Z-32A / PBU / PTD 93-113; wellhead on configuration, no pressure on tubing, 750 psi on inner annulus, 0 pressure on outer annulus, area clean, well is located on producing drillsite. Chevron 18-11-12 / PTD 80-108; wellhead on configuration, no pressure on tubing or annulus, area clean. MP 22-31-11-13 / PTD 81-10; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. MP 32-30-11-13 / PTD 80-152; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. Oct. 2, 1994: A-01 / MPU / PTD 79-40; wellhead is removed with casing hanger still on, area clean, well is located on a active drillsite. A-03 / MPU / PTD 83-01; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a active drillsite. B-02 / MPU / PTD 81-142; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite, C-16 / MPU / PTD 85-116; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. N-O1B / MPU / PTD 84-13; wellhead on configuration, no pressure on tubing or annulus, area clean with timbers covering the cellar area and well guard around the wellhead. No Point #1 / MPU / PTD 94-27; wellhead on configuration, area clean, unable to land helicopter to check wellhead for pressures, No Point #1 is scheduled to become part of the F- pad construction at MPU. NW Milne #1 / MPU / PTD 91-145; wellhead on configuration, area clean, island is suffering from severe-erosion on the North side. Oct. 3, 1994: Sag Delta 31-11-16 / PTD 69-14; wellhead on configuration, area clean, has wooden location marker, no pressure on tubing or annulus. Sa,q Delta #3 / PTD 76-80; wellhead on configuration, area clean no pressure on tubing or annulus. Sag Delta #4 / PTD 77..-15; wellhead on configuration, area clean, no pressures on tubing or annulus. Sag Delta #2A / PTD 77-69; wellhead on configuration, no pressures on tubing or annulus, timbers and cellar box material, reserve pit open. Sag Delta #5 / PTD 80-129; no wellhead; bell shaped affair was covering the supposed well surface location, area clean. Sag Delta #8 / PTD 80-121; wellhead on configuration, timbers and well guard, island is eroding. · Alaska Island #1 / PTD 81-119; unable to land, area appeared clean from the air, marker post visible on South side of island. Niakuk #4 / PTD 84-200; wellhead on configuration, concrete river weights, cellars open, island eroding. · Niakuk #5 / PTD 85-27; wellhead on configuration, concrete river weights, cellars open, island eroding. Location Clearances; Niakuk #lA / PTD 76-28; area is clean, no visible marker post, island is eroding as planned. .~..iakuk #2A/PTD 76~-79;...area-i.s-clean;-.no.visible-marker--post; .island... is-eroding as planned. I recommend that the AOGCC consider Niakuk lA & 2A for final abandonment and location clearance. , Summary.: I inspected locations of 28 BPX suspended wells. I also inspected 2 wells for final abandonment and location clearances. ALASKA OIL AND GAS CONSERVATION COMMISSION // WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501.3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 August 15, 1994 Steve Horton, Drlg Mgr BP Exploration (Alaska) Inc P O Box 196612 (MB12-1) Anchorage, AK 99519-6612 Re: Suspended Wells Compliance with regulations Dear Mr. Horton: BP Exploration and the predecessor Sohio companies have several suspended wells as shown on the attached lists: BP SUSPENDED WELLS PRIOR TO 1980 and BP SUSPENDED WELLS SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above, or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as r~uire~by 20 AAC 25.110(e), must have well site inspections is ye ~rlo.~9 snow covering the locations. David W.(Johnston ~ ~ Chairman .~.~ Attachments c: Blair Wondzell bew/1 lbpsusp 8/15/94 BP SUSPENDED WELLS SINCE 1980 PAGE 1 AUGUST 1994 PERMIT 79-0040-0 80-0066-0 80-0092-0 80-0108-0 80-0121-0 80-0129'0 80-0139-0 80-0152-0 81-0010-0 81-0119-0 81-0142-0 83-0001-0 84-0013-0 84-0200-0 85-0027-0 85-0110-0 88-0115-0 90-0140-0 91-0123-0 91-0145-0 92-0011-0 93-0113-0 94-0027-0 API NUMBER 029-20376-00 029-20483-00 029-20504-00 029-20511-00 029-20519-00 029-20527-00 029-20536-00 029-20546-00 029-20545-00 089-20018-00 029-20662-00 029-20891-00 029-21053-02 029-21217-00 029-21290-00 029-21364-00 029-21558-01 029-22096-00 029-20765-01 029-22231-00 029-22244-00 029-21924-01 029-22450-00 WELL WELL WELL NAME CLASS STATUS MILNE POINT UNIT A-01 EXP SUSP PRUDHOE BAY UNIT 3-10-12 DEV SUSP PBU MP 11-33-11-12 i DEV SUSP PRUDHOE BAY UI~IT TR 18-11-12 DEV SUSP SAG DELTA 8 EXP SUSP SAG DELTA 5 EXP SUSP PRUDHOE BAY UNIT 31-11-13 DEV SUSP PBU MP 32-30-11-13 I DEV SUSP PBU MP 22-31-11-13 2 DEV SUSP ALASKA ISLAND I EXP SUSP MILNE POINT I/NIT B-02 DEV SUSP MILNE POINT T/NIT A-03 DEV SUSP MILNE POINT U~IT N-01B DEV SUSP NIA~fUK 4 EXP SUSP NIAKUK 5 EXP SUSP MILNE POINT I/NIT C-16 DEV SUSP PRUDHOE BAY UNIT Y-22A DEV SUSP PT MCINTYRE P2-59 EXP SUSP PRUDHOE BAY UI~IT S-10A DEV SUSP NORTP~WEST MILNE I EXP SUSP PRUDHOE BAY U~IT U-01 DEV SUSP PRUDHOE BAY LTNIT Z-32A DEV SUSP NO POINT i DEV SUSP STATUS DATE 4/15/S0 10/11/80 4/29/81 12/24/80 4/15/01 4/13/81 2/20/81 m/me/s1 2/14/81 6/08/82 5/27/82 12/10/83 4/27/84 2/17/85 4/10/85 10/27/93 10/29/88 12/22/90 11/06/91 3/30/92 3/16/92 8/31/93 4/08/94 SECT 23 33 33 07 27 36 05 30 30 11 19 23 30 25 25 10 33 14 35 25 18 19 06 TWP 13N 11N 11N 11N 12N 12N 10N 11N 11N 10N 13N 13N 13N 12N 12N 13N 11N 12N 12N 14N 11N 11N 13N RNG 010E 012E 012E 012E 016E 015E 013E 013E 013E 022E 011E 010E 010E 015E 015E 010E 013E 01AR 012E 009E 013E 012E 010E MER U U U U U U U U U U U U U U U U U U U U U U U $/lS/94 PERMIT 69-0014-0 69-0104-0 70-0060-0 71-0015-0 75-0058-0 76-0028-0 76-0079-0 76-0080-0 77-0015-0 77-0069-0 78-0102-0 API NUMBER 029-20011-00 029-20047-00 223-20006-00 029-20099-00 029-20176-00 029-20156'01 029-20180-01 029-20233-00 029-20245-00 029-20234-01 029-20356-00 BP SUSPENDED WELLS PRIOR TO 1980 AUGUST 1994 WELL WELL WELL NAME CLASS STATUS SAG DELTA 31-11-16 EXP SUSP PRUDHOE BAY U~IT 33-12-13 DEV SUSP KEMIK Lr~IT I DEV SUSP PRUDHOE BAY UNIT H-01 DEV SUSP SAG DELTA 33-12-16 EXP SUSP NIAKUK 1-A EXP SUSP NIAKUK 2-A EXP SUSP SAG DELTA 3 EXP SUSP SAG DELTA 34633 4 EXP SUSP SAG DELTA 28337 2-A EXP SUSP PRUDHOE BAY UNIT TERM C DEV SUSP STATUS DATE 4/28/69 12/20/69 6/17/72 6/22/71 4/28/76 4/30/76 3/30/77 3/23/77 3/22/78 12/27/77 4/25/79 SECT 31 33 17 21 04 26 26 35 35 10 03 T~4P 12N 01N 11N 11N 12N 12N 12N 11N R~G 016E 013E 020E 013E 016E 015E 015E 016E 016E 016E 012E PAGE MER U U U U U U U U U U U STATE Of ALASKA ADr. 28288 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspendi ' 'Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 3. Address P. 0. Box 196512, Anchorage, Alaska 99519-6612 4. Location of well at surface 2909' SNL, 2195' WEL, Sec. 30, TllN, R13E, UM At top of productive interval At effective depth At total depth 1932' SNL, 4070' WEL, Sec. 31, TllN, R13E, UM 5. Datum elevation (DF or KB) feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number PBU MP (22-31-11-13)No o 2 8. Permit number 81-10 9. APl number 50-- 029-20545 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 11230 feet 9657 feet Effective depth: measured true vertical 11188 feet 9620 feet Casing Length Structural Conductor Insulated Surface Intermediate Production Liner Perforation depth: measured None true Vertical Size 20" 13-3/8" 9-5/8" ,, Tubing (size, grade and measured depth~I°ne Packers and SSSV (type and measured depth) Plugs(measured) 2500'-2360' 56 cu. ft. Arcticset I plug 9630' -9490' 9-5/8" retainer 58 cu. ft. Junk (measured) Class G cement plug Cemented Measured depth True Vertical depth 12 cu.yds, concrete 3720 cu.ft. Arcticset II 1524 cu.ft. Class G; 130 cu.ft. Arcticset I 420 cu.ft. Class G i10'MD 2585'MD 10195'MD 11228'MD None 12'At[~t::;(~neesr~sexcensxon' .DescriDtiOnunoer ~3rn~ ~fk._pqoDR~l)~l,~e,~?~d operations program [] BOP sketch [] 13. Estimated date for commencing operation Reason for extension: This suspended well is being considered for future use 14. If proposal was verbally approved as a Hurl State observation well. Name of approver Date approved 15. I hereby certify that the foregoing is true and cOrrect to the best of my knowledge Signed ~), ~. C/~J~6~- Title Division Drillinq Engineer Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance "/,-.5'7 ~ Approved by ~'~ LIN~JE Form 10-403 Rev 124-85 Commissioner the commission Date Sul;/mit in' triplicate ALASK IL AND GAS CONSERVATION COM "'' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator Standard Alaska Production Company 3. Address 6. P. 0. BOX 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 7. 2909' SNL, 2195' HEL, Sec. 30, TllN, R13E, UM At top of productive interval 8. At effective depth At ~o¢§~lel~L, 4070' INEL, Sec. 31, TllN, R13E, UM 5. Datum elevation (DF or KB) KBE = 75.31' AMSL feet~..~ Unit or Property name Prudhoe Bay Unit Well number PBU HP(22-31-11-13)No.2 Permit number 81-10 g. APl number 50- 029-20545 10. Boom' Prudhoe Bay 0i 1 Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11230 9657 11188 9620 feet feet feet feet Pm~)~n~e__~S~)cJ) 56 CU. ft. Arcticset I Plug 9630'-9490' 9-5/8 Retainer- 58 cu. ft. Junk(measured) Class G Cement Plug Casing Length Structural Conductor Insulated Surface Intermediate Production Liner Perforation depth: measured None true vertical Size 20m, 13-3/8" 9-5/8" 11 Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) Cemented Measured depth True Vertical depth 12 cu. yds. concrete 110'MD 3720 cu. ft. 'Arcticset II 2685'MD 1524 cu. ft. Class G; lO195'MD 130 cu. ft. Arcticset I 420 cu. ft. Class G 9687'-11228'MD None OCi'2 2 !986 Ala~a 0il & Gas Con~,.:'. ,'*-,,-o',, 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] Request extension under 20 AAC 25.170(b) 1,2,3,4 13. Estimated date for commencing operation Reason for extension' This suspended well in being considered for future use as a 14. If proposal was verbally approved Hurl State observation well. Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed q~'~ ¢. C.~. (~ Title Division Drilling Engineer Commission Use Only Date Conditions of approval Notify commission so representative may witness [ Approval No. ~ [] Plug integrity [] BOP Test [] Location clearance ~ /~ AFp~.ove8 Co9'¥ Approved by( _<-/. ~~~ Commissioner Form 10-403 Re~-l-8~ f / / ' by order of [~,~~. the commission Dat S'ubrr~ in triplicate SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 July 22, 1985 Mr. C.V. Chatterton Alaska Oil & Gas Conservation Commission. 3001 Porcupine Drive Anchorage, AK 99501 RE- 1985 LOCATION INSPECTION Dear Mr. Chatterton' In compliance Fores 10-403, wells. These status. with. State Regulation 20 AAC 25.170, attached are Sundry Notices and Reports on Wells, for the following notices request that the wells remain in suspended BP 41-33-12-1 3 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP (22-31-11-13) No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta /fl (33-12-16) Sag Delta #2A (10-11-16) Sag Del ta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta #5 (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #lO Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 Ni akuk #4 Niakuk #5 Mr. C.V Chatterton July 22, 1985 Page 2 Sag Delta #11 is now ready for final inspection of the abandoned well. Please advise the undersigned which day during the week of August 19-23 is acceptable for your field inspector to accompany our representative for this annual location inspection trip. Very truly yours, RSA/~,RM/sh 72285:0530N Attachments cc' Well File #17 R.S. Allan Acting SAPC Drilling Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO'MMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Sohio Alaska Petroleum Cc~pany 7. Permit No. 81-10 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20545 4. Location of Well At surface: 2909' SNL, 2195' WEL, Sec. 30, TllN, R13E, UPM I 6 . Lease Designation and Serial No. ADT, 28288 5. Elevation in feet (indicate KB, DF, etc.) KBE = 75.31' AMSL 9. Unit or Lease Name Prudhoe Bay Unit 12. 10. Well Number PBU MP 22-31-11-13 No. 2 11. Field and Pool Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Request extension under SUBSEQUENT REPORT OF: (Submit in Triplicate) 20 AA_C 25.170 (b) 1,2,3 (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] ~Stimulation i'-) Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [~[ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for ..: use in West End development. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~'' ~ . ~ DistrictTitle Drilling Engineer The sDace below for Commission use R. H. Reiley Conditions of Approval, if any: Approved by. COMMISSlONER Date Approved Co~y J~eturr~ By Order of the Commission Date Form 10-403 Rev. ?-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 July 10, 1984 - Mr. C. V. Chatterton Alaska Oil & Gas Conservation Cc~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Re: 19 84 I/]CJtTION INSP~TI~ Dear Mr. Chatterton: In compliance with state .Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices and Reports on Wells, for the following wells. These notices? request that the Wells remain in suspended status o BP 41-33-12-13 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP 22-31-11-13) No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 · (35-12-16) Sag Delta 34633 #4 sag Delta #5 (36-12-15) sag Delta #7 sag D~lta #8 Sag Delta #9 Sag Delta #10 Niakuk #lA (26-12-15) Niakuk #ZA (23-12-15) Alaska Island #1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Sohio Alaska Petrole~a ~y 81-10 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20545 4. Location of Well At surface: 2909' SNL, 2195' 9~EL, Sec. 30, TllN, R13E, UPM 5. Elevation~ _in75feet. 31{indicate' ~KB' DF, etc.) II 6. Lease DesignatiOnaDT, 28288and SerialNo.~_...~iC.~-/~ 12. 9. Unit or Lease Name Prudhoe Bay Unit = 10. Well Number PBU MP 22-31-11-13 No. 2 11. Field and Pool Prudhoe Bay Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Request extensic~ under SUBSEQUENT REPORT OF: (Submit in Triplicate) 20 ARC 25.170 (]3) 1,2,3 (Submit in Duplicate) Perforate [] Alter Casing [:::] Perforations [] Altering Casing [] Stimulate [] Abandon [] ~timulation [] Abandonment [] Repair Well [::] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for use in West End develo[m~.nt. RECEIVED J U L ! 0 ]984 Alaska 0il & Gas Cons. Commission Anchorage % ( ~Lf/~ ~, { O ~ V · . District Drilling Engineer Signed ~ ""---%d Q ~'~"''--"'~ Title The space below for Commislion use Conditions of Approval, if any: Suspended status is extended until September, 1985. ~! LIltIIIE C. $111lii Ely Order of Approved by, COMMISSIONER the Commission Returned Form 10-403 Rev. 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate ME TO: T~RU: FROM: M,. RANDUM State of Alaska AL A OIL AI~D CAS CONSE~VATION COMI~ISSICN C. V. ~.~rton / DATE: August 25, 1~83 ~ ~ ~¢~.~'"" FILE NO: 108A:F6 I~nnie C. S,th Commissioner ~ TELEPHONE NO~ SUBJECT: Inspection on Sohio's Susponded I~cations Listed Below. ,..~ ~,~ ~ .~,¢~.. - .~.,.~(.~..n..day, August_ 8, 1983: I traveled, this date with ~ike Dinger, SohiO's representative to look at the suspended locations listed below: Chevron Tract Well PBU ~?PC Tract Well ~1 ~'iPC Tract Well PBU MP ~ 2 MP Tract Well 23-1S-11-12 4 3-31-11-13 11-33-11-12 3-i 0-12 22-31-11-13 32-30-11-13 Attached to this report are pictures of well heads, drilling pads, reserve pits and a copy of the AOCCC surface suspension location, report. It is my recommendation to the Commission that the akove loca- tions ~ accepted in regards to location cleanup, well sign placem..ent, and pit conditions. Attachments · Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator ~ ~'~(C~ _. " Date Suspended Address ~ ]E:;)~.{ . ~ -(~l'Z. ~i,~J'~e/'4~' -,,~_~.. ~~Z Surface Location of weii P~rmit No. ~;~;~ J9~9 Ft. F ~ L, ~Ft. F ~ L API No. 50 ~'~' sec.~, T~ ~, R~ ~ , ~ M. -unit ~or Lease Nam~=6~9_& Field & Pool ~ ~~[~-~ Z Condition of Pad ~.~.~ ~, Condition of Pits Well head - Ail outlets plugged No Well sign - Attached to well head ~ No Attached to well.guard Yes No Attached to Information correct No Cellar - ~,,~~?~d Yes No Rat Hole ..... No Covered Yes No WaterWell - Plugged off Capped Open Explanation O__pe_~n~ Yes No Covered Yes No Photographs taken to verify above conditions Yes No Exp la na ton Work to be done to be acceptable This well and location is (acceptable) suspended for the period of Inspected by: g/t Date :_ ~ '" % ~'x~ (~D~P~pgt~le) to be classified as 19 thru 19 . _ Revised 8/24/82 SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6.612 ANCHORAGE, ALASKA 99502 July 21, 1983 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Cc~ssion : 3001 Porcupine Drive Anchorage, Alaska 99501 1983 LOCATION INSPECTION Dear Mr. Chatterton: In compliance with State Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices and Reports on Wells, for the following wellS. These notices request that the wells remain in suspended status. BP 41-33-12-13 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) HP Tract Well (32-30-11-13) PBU MP 22-31-11-13, No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta #5 (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Del'ta #10 Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 Mr. C. V. Chatterton July 21, 1983 Page Two Water Injection Well GC - lB (13-11-13) .is also now ready for final inspection of the abandoned well site. Please advise the undersigned which day during the week of August 8th is acceptable .for your field inspector to acCompany our representative for this annual location inspection trip to the above-named well sites. Very truly yours, R. H. Reiley District Drilling Engineer encs cc: Well Files #17 SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER r-~ 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 81-10 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20545 4. Location of Well At surface:. 2909' SNL, 2195' WEL, Sec. 30, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 75.31' AMSL 6. Lease Designation and Serial No. ADL 28288 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number PBU MP 22-31-11-13 NO. 2 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Request extension under SUBSEQUENT REPORT OF: (Submit in Triplicate) 20 AAC 25.170 (b) 1,2,3 (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for future West End development. Approved Copy RetUrned ¢-/.Z,, 8:% RECEIVEO JUL 2 11,9 3 Oil & Gas Cons. Commission Ancho:'~g~ 14. I hereby certify that the foregoing is true arid correct to the best of my knowledge. Signed v- _~ Title ' The space below for Commission use R. [-l".~". -Reiley Conditio,s of Approval, if anvThis location ~ms inspected by our representative on August 8, 1983 and clean up was found satisfactory for a suspended location. A subsequent inspection will be necessary by A~gust 1984. ORIGINAL $1GNEB By Order of Approved by JJV !J~J~ll: I~ eMI?il COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANDUM Thru: TO: FROM: ) state of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION c: DATE: November 9 1982 .re rtOnCha , ~[~ ~d%/, FILE NO: 108/A Lonnie C. Smith Commi s si one r DO ug 'All'lO S Petroleum Ins~ctor TELEPHONE NO: SUBJECT: Inspection of Sohio's Suspended Locations Listed Below Friday, August 27, 1982 - I traveled this date to Prudhoe Bay ~ere -i met Jer~segar, Sohio representative, and conducted the second clean-up inspection on the locations listed below. Attached to this report are pictures of well heads, reserve pits, drilling pads and a copy of the Form 10-403. I recommend to the Commission that the following locations be accepted in regard to location clean-up, well sign placement, and pit condition. PBU MP 2 2.31--11-13, No. 2 Term, Well B (22-20-11-13) Term Well C (34-03~1.I~*%2) MPC Tract Well 21-03~i~2 MPC 11-33-11-12 ~ Getty State No. 1 (2-10-13'~)~,. PBU MP 43-31-11-13 , West Sak 25645 #9'-,(3-11-9) West Sak 25548 #11 (36-12-.8.) West Sak 25655 #14 West Sak 916 (31-36-13-08) West Sak #17 (44-26-13-09) Kuparuk State 22-11-12 'Sag ~.Delta #.5 (36-12-15) Sag Delta 91"q. 33-12-16) No pictures, ran out of film Sag Delta ~2A '(10-11-16) ~" " " " " " Sag Delta 93 (35-12-16) Sag Delta #4 (34633) Sag Delta #7 Sag Delta #8 Sag Delta #9 '::# Sag Delta #10 MP Tract Well 32-30-11-13 Niakuk #lA (26-12-15) Niakuk ~2A (23-12-15) Chevron Tract Well, (23-18-11-12) In summary, I inspected the above listed suspended locations for clean-up, well signs, and pit conditions. 02-00IA(Rev.10/79) Susp~ '~ed Well and Location Repo ? 20 AAC 25, ARTICLE 2 FILE INFORMATION: Addre s s Date Suspended Surface Location of Well Permit No. ~~ ~. ~ s~ ~., z/~ ~. W_,/~ ~ ~ ~ ~o. ~o-- ~Z~-~ ~~'~ Sec.~, T // ~, R~ _~ , ~ M. Unit or Lease Name' Wel 1 No. ~ Condition of Pits Well head - Ail outlets plugged ~ No Well sign - Attached to well head Yes ~ Attached to well guard ~ No Attached to Information correct ~ No Cellar - Opened ~Q No Rat Hole Fi 1 led Ye s No Covered Yes No WaterWell - Plugged off Ope n Exp la na ti on Open Fil led Covered Ye s Ye s No No No Photographs taken to verify above conditions~ No Exp la naton Work to be done to be aCceptable /'~<?' ~,"~} C This well and location is (~ suspended for the period of ~'Z7- Inspected by:_ Da te: ~nacceptablel to be 19~Z thru classified as 19 ~_~. Revised 8/24/82 SOHIO ALASKA PETROLEUM COM~ ~'~:'' TELEPHONE (907) 265-0000 , MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 July 30, 1982 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commi!SSion 3001 Porcupine Drive Anchorage, Alaska 99501 " Dear Mr. Chatterton: In compliance with State Re~c~lation 20 AAC 25.170, attached are Forms 10-403; Sundry Notices and Reports on Wells, for the following wells. These notices request that the wells remain in suspended status. BP 41-33-12-13 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU ~P 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP 22-31-11-13, .No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 'Sag Delta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 .#4 Sag Delta #5 (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #10 Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 ALASKA · AND GAS CONSERVATION C ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I-I COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum C~mpany 81-10 3. Address 8. APl Number Pouch .6-612, Anchorage, Alaska 99502 50-029-20545 4. Location of Well At surface: 2909' SNL, 2195' WEL, Sec. 30, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 75.31' AMSL I 6 . Lease Designation and Serial No. ADL 28288 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number PBU MP 22-31-11-13 No. 2 11. Field and Pool SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] [] Abandonment I-] [] Other [] 12. Check ApprOpriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: ~est e.~teTtsion l.l~der (Submit in Triplicate) 20 AAC 25.170 (b) 1,2,3 Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for future West End development. Clean-up to date: a) Major structures have been removed. b) Loose debris has been removed. c) Pad is level and graded. t £CEIvED S~t~se~ueet VC~k Bet~ff~t Alas~ Oil & Gas Cons. C°m~iSs[on Approved "'o~y Return,?d 14. I hereby certify that the fo_zegoing is true and correct to the best of my knowledge. Conditions of Approval, if any: A clean-up ±nspect±on w-~[! be necessary by Au§ust 1983. Approvedby BY l.~['!'!~ [[. S~IITB COMMISSIONER theComm,ssion Date Form 10-403 Rev 7-1 80 Submit "Intentions" m Tru31~cate and "Subsequent Reports" ~n Dupl,cate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 October 28, 1981 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 At%n: Mr. H. H. Hamilton Re: Term Well B (22-20-11-13) Sec. 18, TllN, R13E, UM. Term'Well C (34-03-11-12) Sec. 03, TllN, R12E, UM. PBU MP 43-31-11-13 Sec. 05, T10N, R13E, U~. MP Tract Well Sec. 30, TllN, R13E, UM. ~ Sec. 30, TllN, R13E, UM. Kuparuk 22-11-12 Sec. 23, TllN,-R12E, UM. Gentlemsn: In response to your request dated October 21, 1981 re subject wells, attached find amended Form 10-407's in duplicate for the following: Term Well B (22-20-11-13) Sec. 18, TllN, R13E, UM. Term Well C (34-03-11-12) Sec. 03, TllN, R12E, UM. PBU MP 22-31-11-13 Sec. 30, TllN, R13E, UM. Also attached are copies of Form 10-407's as submitted which do show' the following wells as plugged and suspended: PBU MP 43-31-11-13 Sec. 05, T10N, R13E, UM. MP Tract Well (32-30-11-13) Sec. 30, TllN, R13E, UM. Kuparuk 22-11-12, Sec. 23, TllN, R12E, UM. was completed as an observation oil well and this Recompletion Report, Form 10-407, was sut~tted to you under separate cover October 27, 1981. Very truly yours, ~District Drilling Engineer encs cc: Well Files #17 RECEIVED OCT 2 9198; 0ii & Gas Cons. Colnmissio. Anchorage ' ~ ~/ STATE OF ALASKA ~ .'~,'~,~ ALASKA .__ AND GAS CONSERVATION C ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG" 1. Status of Well,. ~,,,~I,i11~; Classification of Service Well OIL'[~j~ )~-/" GAS [] SUSPENDED [~ . . ABANDONED [] SERVICE [] ... 2. Name of Operator 7. permit Number Sohio Alaska Petroleum Company 81-10 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20545 4. Location of well at surface 9. Unit or Lease Name 2909 ' SNL, 2195 ' WEL, Sec. 30, TllN, R13E, UPM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1534 ' SNL, 3750 ' WEL, Sec. 31, TllN, R13E, UPM PBU MP 22-31-11-13 NO'~ 2 At Total Depth 11. Field and Pool · 1932' SNL, 4070' WEL, Sec. 31~ TllN, R13E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Serial No. P::L"~5.O~ Oil Pool KBE = 75.31' AMSL/ ADL 28288 12. Date Spudded 13. Date I.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of CompletiOns 1/19/81 2/6/81 2/14/81 feet MSLI None 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost l1230'MD 9657'TVD ll188'MD 9620'TVD YES ~ NO [] none feetMD 1998' .., 22. Type Electric or Other Logs Run DIL/BHCS/GR/SP/%~I, FDC/CNL/NGT/Cal, P~T, CBL/VCL/GR/CCL, seismic velocity & crfro surveys 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING ·SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" T_nsulated Conducto:' surface 110' 36" 12 cu.yds. :concrete 13 3/8" 72~ L-80 Surface 2685' 17' 1/2" 3720 cu. ft. Arcticset II _ 9 5/8" 474 L-80 Surface 10195, 12 1/4" 1524 cu. ft. Class G: 130 cu. ft. Arcticset I 7" 299 L-80 9687' 11228' 8 1/2" 420 cu. ft. Cla$~. G . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD . .4nterval, sizeand number) SIZE . DEPTH SET (MD) pACKER SET (MD) , ' None · None ' 26. .ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ., '2500' - 2360, 56 cu. ft~ Arcti~Set I Dlud 9630' - 9490' 9 5/8" retainer - 58'c~,f~. .... : , ~ . ..... Class G cement plug . .. · 27. PRODUCTION TEsT Date First Productipn, :. I Method.of OPera~bon (FI,owing, gas lift, etc.) , I Date of Test Hours Tested PRODUCTION FOR OI L-BBL G/~s-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIQD: ~ .... ,,~ Fl°wTubing Casing Pressure C .A, LCULATED 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. -. . None RECEIVED OCT 2 9 98! , . ... Naska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION 'FESTS , ,. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Subsea Sag River SST. 10235' 8728' Shublik 10259 ' 8748 ' Ivishak 10376 ' 8845 ' · . 31. LIST OF ATTACHMENTS Well History (Well Logs, Directional Surveys previously submitted 3-7-81) · 32. I hereby certify that the foregoing is true and correct to the best of my knowledge (Amended t~±s date to ~.d£cate Sus~z~ded Status) S,gned Tit,eDistr[ct Drilling Date IO° 2~' ~i~l R.H. Reile¥ I% Enaineer INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24.~;'1f 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.). I~em 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng 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". PBU MP'22131-11-]3~ NO o 2 WEL~ HIS~0RY Spudded well' at 0500 hours, January 19, 1981o Drilled 17 1/2" hole to 2690'. Ran 68 jts. 13 3/8" 72~ L-80 Buttress casing to 2685'. Cemented with 3720 cu. ft. ArcLicset II cement. Installed and tested BOPEo Cleaned out to 2642', tested .casing to 3000 psi, okay. Drilled out to 2706'., ran leak-off test' to 0.74 psi/fto · gradient. Directionally drilled 12 1/4" hole to 10196'. Ran open hole logs. Ran 265 jts. 9 5/8" 47~ L-80 Buttress casing to 10195'. Cemented in two Stages: Ist stage with 1524 cu. ft. Class G cement. Cleaned out to 10095'. Tested casing to 3000 psi, okay. Drilled out to 10217', performed formation cc~petency test to 13.5 ppg. t~4. Directionally drilled 8 1/2" bole to 11230'. Ran open hole logs. Ran 39 jts. '7" 29# L-80 Buttress liner to 11228'. Cemented with 420 cu. ft. Class G cement. Stuck pipe after reversing out cement. Ran free point and baCked off at 8936'. RIH to 8927', tested 7" liner to 3000 psi, okay. Screwed into fish at 8936', recovered entire fish. Cleaned out to 11188', tested 7" liner to 3000 psi, okay. Ran CBL, seismic velocity surveys and gyro. Set EZ Drill at 9630'~ laid cement plug consisting of 58 cu. ft..Class G cement from 9630' to 9490'° Opened FO, set RTTS packer at 2564', Arctic Packed to surface follow,ed by 2nd stage cement in 9 5/8" x 13 3/8"-annulus consisting of 130 cu. ft. Arcticset I through FO cementer. at 2616'. This was followed by laying second cement plug coDsisting of 56 cu. ft~ Arcticset I from 2500' to calculated top of 2360'. Displaced hole with 9.8 ppg. CaC12. Displaced top 200' of hole with diesel, installed and tested adaptor flange and single master valve to 3000 psi, okay. Released rig at 0600 hours, February 14, 1981. NOTE: Suspension of PBU MP 22-31-11-13 No. 2 witnessed and approved by Harold Hawkins of Alaska Oil & Gas Conservation Commission February 13, 1981. 0CF 91981 Alaska Oil & ~as COns.'Comm, , Anchorage ~S$ion~ October 21, 1981 Mr. P. R. Judd Manager Dril ling Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Re: Term Well B (22-20-11-13) Sec. 18, TllN, R13E, UM. Term Well C (34-03-11-12) Sec. 03, TllN, R12E, UM. PBU MP 43-31-11-13 Sec. 05, T10N, R13E, UM. P .22-31-11-!3__~. Sec 30, TllN, R13E, UM. Kuparuk 22~-11-12 Sec 23, TllN, R12E, UM. Dear Mr. Judd: We are returning the approved Form 10-403's (SUNDRY NOTICES) granting an extension of clean-up time for subject wells, con- sidering these wells as suspended wells. The presently held Form 10-407's (WELL COMPLETION REPORTS) do not properly convey that these wells are in a suspended status since they also indicate an oil or service status. It is requested that you submit Form 10-407 for each of the above listed wells with the Item 1 (STATUS OF WELL) marked as "suspended" if this is to be the desired classification. Sincerely, Lonnie C. Smith/~~'/ Commissioner Enc lo sure s LCS/JKT ~be 02 (.K) IB IRev STATE of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION T©= ~Hoy le H. Hami lton/~/#~ Chairman Thru: Lonnie C. Smith Commissioner FROM: Bobby Foster~~ Petroleum Inspector O~T~ September 11, 1981 FILE NO TELEPHONE NO: SUBJECT: Inspection of SOHIO's Suspended LoCations LiSted Below Monday August 31 Thru Wednesday September 2: I traveled to Prudhoe Bay Monday August 31, 1981 where I met with Jack Barr, Judy.Golding and Jerry Stegar, Sohio representatives and discussed the upcoming location inspection. Attached to this report are pictures of well heads, reserve pit, drilling pad, and a copy of surface suspension report. It is my recommendation to the commission that the following locations be accepted in regard to location clean-up, well sign placement, and pit 'condition. Mobil Phil lips Mobil Phil lips Mobil Phil lips Chevron Tract West Sak West Sak West Sak West Sak Mobil Phil lips Mobil Phil lips Mobil Phil lips Term wel 1 Term wel 1 Getty State Niakuk Niakuk Ni akuk Niakuk Sag Delta Sag Delta Sag Delta Sag Delta Sag Delta Sag Delta Sag Delta 21-03-11-12 11-33-11-12 22-11-12 23-18-11-12 #9 #11 #16 #17 22-31-11-13 43-31-11-13 32-30-11-13 B C #1 #1 #la #2 #2A #1 #2 #2A #3 #4 #5 #8 In summary, I inspected the above listed suspended locations for ' clean-up, well signs, and pit conditions. , 20 A,~ ;ih FILt'] INFOI~HATION: ' ,, _ ,,, 20 AAC 25.120: WEI.L ~['~J" ~.IA}<E}..I.,.' ' · Dia. Ste~l Post (4"Min.) ,~'~] , Height Above Final Grade Level-(4 Top of Harker Pipe Closed with' Cement Plug Set: On Well }lead , On Cutoff Casing Distance Below Final Grade Level Side Outlets:' All Valves and ~,;[pples Removed All Openings Closed ~ , With Blinds / Screw Cap Welds , In Concrete Pl~g F t. in. , With Cement , Other -- (List ~,q~ere Different from File Information) Operator ~/~J Unit or l,ea~e Name Well Number , Surface Location of WelL: Ft. F L, Ft., F 1,, .Sec , T , R 20 AAC 25.170: LOCATION CLEAt'S-UP L · Filled In Liners Removed or Bur\ed SURFACE OF PAD AND/OR 1,OC~VEI()b:: Rough , smooth ~ ,-Contoured , Flat Other , Debris Removed , Compacted CLEAN UP OF PAD AtII)/OR I,OCA'I'I~)N' ; Clean , Pipe Scrap , Iron Scra1 Paper ~, Other , Wood , Hud , Cement SURROUN1) IN.D AREA: Wooded , Brush Sand , Other , Tundra ~, Grass , Dirt , Gravel CONI)I'FION SURP,()UNI) [,N(; AP, Iq,,\: Clean u./, Trash from Site Other , Tree~'; and/or Brush from Clearing Site ACCESS ROAD: Dirt , Gravel l-//, Ice , Otl~cr CONI)[TION ACCESS ROAD AND S[IRR[)Ii~'I)I_?4t;- ~ Clean /, Rough ~, Smooth ,--"~' , Trasl~'from Ol~erations ._, Trees and/or Brush from Clearing Road __, Spoil from Clearing Road Other t RE~D\IN1NG TO BI:. DONE: ~, RECOH~-Ii';NI) AP1 RO\.AL OF ~1': Yes 05/26/81 No Final Inspection SOHIO ALASKA PETROLEUR4 COR,1PANY August 17, 1981 Mr. Lonnie Smith Alaska Oil & Gas Conservation Cora~i2sion 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: In con~oliance with State Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices & Reports on Wells, for the following wells. These notices request that the wells remain in suspended status. Term Well B.(22-20-t1-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-t1~12) MPC Tract Well (21-03-10-t2) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State %1 (02-10-13) MP Tract Well (32-30-11-13) PBUMP 22-31-11-13, No. 2 West Sak 25645 #9 West Sak 25548 ~11 West Sak 25655 #14 West Sak %16 West Sak #17 Kuparuk State 22-11-12 Sag Delta %1 (33-12-16) Sag Delta %2 (10-11-16) Sag Delta %2A (10-11-16) Sag Delta %3 (35-12-16) Sag Delta 34633 04 Sag Delta %5 (36-12-15) Sag Delta 07 Sag Delta %8 Niakuk %1 (26-12-15)-abandoned Niakuk ~iA (26-12-15) Niakuk ~2 - abandoned Niakuk ~2A (23-12-15) Niakuk ~3 (13-12-15) Mr. Lonnie Smith August 17, 1981 Page Two We would like to have your field inspector present sometime during the week of August 31 - September 4 to accompany our representative for final location inspection of the follc~ing wells: Challenge Island #1 Reindeer Island Stratigraphic Test #1 West Sak #4 Kemik Unit ~2 West Kuparuk State 3-11-11 Hurl State 5-10-13 Socal-Mobil 33-29E (29-12-11) Kuparuk State 33-11-12 Kuparuk 9-11-12 MPC 7-11-12 Kuparuk State 21-11-12 MPTract Well 13-15-11-12 PRJ:JLG: ja Attachments cc: Well Files CC# 37,291 Yours very truly, P. R. Judd Manager · Dr illing STAi'E OF ALASKA .ALASKA O~L AND GAS CONSERVATION COMMISSION SUkDRY _.)TICES P. PORT TELLS DRILLING WELL [] COMPLETED WELL I-I OTHER 2. Name of Operator Sohio Alaska Petroleum Company 3. Address PouCh 6-612, Anchoraqe, Alaska 4. Location of Well At surface: 7. Permit No. 81-10 8. APl Number 99502 so- 029-20545 9. Unit or Lease Name Prudhoe Ba~v Unit 10. Well Number 2909' SNL, 2195' WEL, Sec. 30, TllN, R13E, ~ 11. Field and Pool Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 75.31' AMSL I ...ADL 2828R 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' Request extension under SUBSEQUENT REPORT OF' PBUMP 22-31-11-13 NO. 2 (Submit in Triplicate) 20 AAC 25.170 (b) 1,2,3 (Submit in Duplicate) Perforate O Alter Casing [] ~ Perforations E~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other E] Puli Tubing [] Other [:~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for future West End development. Clean-up to date: a) Major structures and installations have been removed. b) Loose debris has been removed. c) Pad is level and graded. ° 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~ The space below for Commission use R.H. R~ey Alaska Oil ~ ~ ": 0 198! u85 0017, App,'oriel Ccpy iii?ti?o~.~ S. Coin,,. ~:e urnecl '~ -/' ' . , .~ . 101't Tit,eDistrict Drillinq Enqineer Date Conditions of Approval, if any: This suspended location ~as inspebted by our representative on 09/02/81 and the clean-up ~as found to be acceptable. Approval is given to lea~ the pits open, the ~11 head on, and the cellar open. This approval is given until 09/02/82. A subsequent inspection will be necessary by mid-stmm~r 1982. ~~ By Order o! Approved by " 0[~J~'!l~h~rL S~I;N[D COMMISSIONER the Commission Date ~ Form 10-403 Rev. 7-1-80 i~Y L~H~;E C. SMITll Submil "intentions" in Triplicate and '"Subsequent Reports" in Duplicate -,r~A OIL AND GAS UUi,,bERVA i ION GOMMISSION DRILLING WELL [] Name of Operalor Sohio Alaska Petroleum Co,.mpany '3. Add,ess pOUch 6-612, Anchoraqe, Alaska 4. Location of Well At surface: COMPLETE'DWELL [] OTHER 99502 7. Permit No. 81-10 8. APl Number so- 029-20545 9. Unit or Lt~a,~e Name __, Pzudhoe_Ba~v ' Un i 10. Well Number 2909' SNL, 2195' WEL, Sec. 30, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) }<BE = 75.31' AMSL , , 12. 6. Lease Designation and Serial No. ADL 28288- PBU ~ 22-31-11-13 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box T© Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Request extension under SUBSEQUENT REPORT OF: (Submitin Triplicate) 20 AAC 25.170 (b) 1,2,3 (Submit in Duplicate) Perforate O Alter Casing [] ~ 'Perforations [] Altering Casing Stimulate [] Abandon -' [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs 'Made [] · Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitled Form 10-407 for each completion.) No. 2 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for future West End development. Clean-up to date: a) Major structures and installations have been removed. b) Loose debris hasbeen removed. c) Pad is level and graded. ' 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. b~ ~ [J~'~~~e~ow for Commission use R- H- ~J~- TideDiStrict Drillinq Enqineer Signed The space ey Condilion, o! Approval, if any: This suspended location Ks inspected by our representative, on 09/02/81 and the clean-up %~s found to be acceptable. Approval is given to leave the pits open, the ~11 head on, and the cellar open. This approval is given until 09/02/82. A subsequent inspection will be necessary by mid-summer 1982. / / ,,, , By O,der o, ~/~7//d~/ Approved by" J]Ei ~ .ii, fir S [ ~[i iii CO;,~MiSSION ER the Commi,s;on Date Form 10-403 Rev. 7-1 ..80 Subm,~ "ln~m,ons" ,n T, iplicate and "Subsequent Repo,t$" in Oupl,ca~e SOHIO ALASKA PETROLEUM COMPANY ARCO - -:: 111 "C" STREET ;HORAGE, ALASKA HONE (907) 265-0000 AIL: POUCH 6-612 TO: C~t't~ _ - f 3';~"FAN~ )RAGE, ALASKA 99502 I 4 ENG .,. . . __ leO.r: '~ .... J · #' '754' REFERENCE: OHIO FINAL DATA . The following material is being"submitted 'herewith, Please acknowledge receipt by signing a copy of this letter and returning it to this office'.'-- · MP TRACT WELL (22)'31-11-'13 FDC 2/7/81 #2 2" & 5" 2/7/81 #2 2" & 5" 19 Carol Krieter Development Geol.ogy Well Records SOHIO ALASKA, pETFIOIEUM COMPA,~--w-~ f!ixl~- ! '~ TO: STATE ': ....... STAT TEC ~ 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 ,Date: 3/26/81 # 689 REFERENCE: OHIO DATA ~/The following material is being submitted herewith, Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- MP TRACT WELL (22) 31-11-13 Magentic LIS Tape #61406 2/6/81 91-3 19 Naska Oil & Gas Cons. Commission Anchorage Carol Krieter Development Geology Well Records, HQ 4-5 SOHIO ALASKA PETROLEUM COMPANY March 6, 1981 3111 'C" STREET ANCHORAGE, ALASK.~ TELEPHONE (907) 265-0( MAIL: POUCH 6-612 ANCHORAGE, ALASKA 9! Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: PBU MP 22-31-11-13 No. 2 Enclosed, in duplicate, is Form 10-407, Completion Report, for the above-named well together with the Well History, Well Logs, and Directional Surveys. RHR: ja Enclosures cc: Well File ~17 Yours very truly, District Drilling Engineer RECEIVED MAR - 9 1981 Alaska Oil & Gas Cons. Commission Anchoraoe WELL COMPLETION OR RECOMPLETION REPORT AND LOG t. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] ,.SERVICE []- 2. Name of Operator ' ' 7. Permit Number - ' Sohio Alaska Petroleum Company 81-10 3, Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50~29-20545 4. Location of well at surface 9. Unit or Lease Name 2909' SNL, 2195' WEL, Sec. 30, TllN, R13E, UPM- Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1534' SNL, 3750' WEL, Sec. 31, TllN, R13E, UPM PBU MP 22-31-11-13 No. 2 At Total Depth 11. Field and Pool 1932' SNL, 4070' WEL, Sec. 31, TllN, R13E, UPM . Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 75.31' AMSLI ADL 28288 12. Date Spudded 13. Date T,D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 1/19/81 2/6/81 2/14/81I feet MSLI one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. SepthwhereSSSVset I 21. Thickness of Permafrost 11230'MD 9657'TVD 11188'MD 9620'TVD YES [] NO []I none feet MDI 1998' 22. Type Electric or Other Logs Run DIL/BHCS/GR/SP/TTI, FDC/CNL/NGT/Cal, RFf, CBL/VDL/GR/CCL, seismic velocity & gyro survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTIN~G RECORD AMOUNT PULLED 20" Conductc,r Surface . 110, 36- 12 cu.yas, concrete 13 3/8" 72~ L-80 Surface 2685' 17 1/2" 3720 cu. ft. ArcticsE~t II 9 5/8" 47~ L-80 Surface 10195.' 12 .1/4" 1524 cu,ft. Class G;130cu. ft. Arcticse 7" 29~ L-80 9687' 11228' 8 1/2" 420 cu.ft. 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) none 26. ' ACID, FRACTURE, CEMENT SQUEEZE, E'TC. "" DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED -. ' 2500' '2360'.. 56 cu.ft. Arcticset I Dlua 27. ' PRODUCTION TEST ,, , Date First Production. . I Method of Operatibn..(Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L~BBL GAS-MCF WATER-BBL cHoKE SIZE GAS-OIL RATIO TEST PERIOD I~ FIo~v,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. None E C E I V E D . Alaska Oil & Gas Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ; ' 30. GEOLOGIC MARKERS FORMATIO~ ¥ , .. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Subsea Sag River SST. 10235' ':8728' Shublik 10259' 8748' Ivishak 10376 ' 8845' · 31. L,ST OF ATTACHMENTS Well History, Well Logs, Directional Surveys 32. ~ hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~ Title District Drillinq Date ~-- _ R.H. Reilev -'~ Enqineer -, % 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 e!evation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. i[em 16 and 24: If this well is completed fer. 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 PBUMP 22-31-11-13, No. 2 WELL HISTORY Spudded well at 0500 hours, January 19, 1981. Drilled 17 1/2" hole to 2690'. Ran 68 jts. 13 3/8" 72# L-80 Buttress casing to 2685'. Cemented with 3720 cu. ft. Arcticset II cement. Installed and tested BOPE. Cleaned out to 2642', tested casing to 3000 psi, okay. Drilled out to 2706', ran leak-off test to 0.74 psi/ft. gradient. Directionally drilled 12 1/4" hole to 10196'. Ran open hole logs. Ran 265 jts. 9 5/8" 47# L-80 Buttress casing to 10195'. Cemented in two stages: 1st stage with 1524 cu.ft. Class G cement. Cleaned out to 10095'. Tested casing to 3000 psi, okay. Drilled out to 10217', performed formation competency test to 13.5 ppg. ~4. Directionally drilled 8 1/2" hole to 11230'. Ran open hole logs. Ran 39 jts. 7" 29# L-80 Buttress liner to 11228'. Cemented with 420 cu.ft. Class G cement. Stuck pipe after reversing out cement. Ran free point and backed off at 8936'. RIH to 8927', tested 7" liner to 3000 psi, okay. Screwed into fish at 8936', recovered entire fish. Cleaned out to 11188', tested 7" liner to 3000 psi, okay. Ran CBL, seismic velocity Surveys and gyro. Set EZ Drill at 9630', laid cement plug consisting of 58 cu.ft. Class G cement from 9630' to 9490'. Opened FO, set ~ packer at 2564', Arctic Packed to surface followed by 2nd stage cement in 9 5/8" x13 3/8" annulus consisting of 130 cu.ft. Arcticset I through FO cementer~ at 2616'. This was followed by laying second cement plug consisting of 56 cu. ft. Arcticset I from 2500' tocalculated top of 2360'. Displaced hole with 9.8 ppg. CaC12. Displaced top 200' of hole with diesel, installed and tested adaptor flange and single master valve to 3000 psi, okay. Released rig at 0600 hours, February 14, 1981. N(Ti~: Suspension of PBUMP 22-31-11-13 No. 2 witnessed and approved by Harold Hawkins of Alaska Oil & Gas Conservation Con~nission February 13, 1981. Controlled Drilling Consultants" P.O. BOX 1189 PALMER, ALASKA 99645 PHONE 376-5423 Mr. Brian Rose Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, AK 99502 February 13, Magnetic Single Shot Survey Job No. 0281-06-81 Well Tract Well (22-31-11-13) Prudhoe BaY Field~ North Slope, Ala~_a2181 to 2~06-81 Date of Surveyl Dear Mr. Roses Please find enclosed the 'Original' and six (6) copies of our Magnetic Single-shot Survey on the above well. The method used in calculating'this survey was radius of curvature. The depth interval of the survey was 2685 to 11,230. Thank you for giving us this opportunity ~to be of service. Yours very truly, Controlled Drilling Consultants Direct4onal Supervisor ' COMPLETION REPORT .._$OM.Z O_ALASKA_ PET_R OL, EUM ~4AGNETIC SINGLE SHOT SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION CO,vpUTED. FOR CDC .._BY .... FM_LINDSE~_..G.ASSOC, 10 FEB 81 WEL_L___Z2T31-11-1 ~__ K B ELEV 75.31 RECORD Of SURVEY TRUE _,ME_AS._DR I.ff_T__V ER T I CA L DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES CLOSURES DOG LEG SEVER l TY SECT I~./ DISTANCE ANGLE DEG/IOOFT D M S DISTANCE 0 0 ~0' '-0'00 ....... -75;31 N 0'60E-' ........... -0'-'-60 S 0.00 W 0.00 S 0 0 0 W 0,000 0.00 .ASSUMED..VERTICAL_TO.~26~5. 2685 0 0 2685.00 2609.69 N O.OOE __2803..__2___45 .... 2802,95__2727.64__._$!7.00E ......... 2895 5 15 2894,72 2819,41 S 8.00E 5,96 2986 6 ~0 2985,24 2909.93 S12.00W 15.22 3979.__8._ 15__30.77_,_~3___3092.,. 16. S2.0 ~90~ ' ~_~.769 .... 3172 10 15 3169.25 3093.94' 'S22,00W 40,6~ 3265 13 30 3260.25 3184.94 S16,00W 58,73 0.00 S 0.00 W 0.29 N 1.94 E 0,00 S 0 0 0 W 0,000 1.96._ N._81_30___0_ E ___2.,352 2,719 1,402 1,890 2.152 3.512 3,33 E 3,01 E 0.27 W 5,63 W 11.86 W 0,00 3.98 12.50 24e27 6,83 S 29 11 40 E 15,52 S 11 11 1 E 26.69 S 0 35 37 W 41,03 S 7 53 24 W 59,91S 11 24 59 W _3358_15_45...3350,23__3274,92 ...... S15,00W ..... 81,35_ S ....... 18,13_._.W ............. 83,.35_S._12 33 56 W 3480 18 15 3466.89 3391,58' SlS,00W 115.81S 27.36 W 118.99 S 13 17 42 W 39,18 58.20 2.049 3605 22 0 3584.24. 3508.93 S19.00W __3700__26____0 361!._0_~_ ~95.70____$~7,00W 3825 29 45 3781,48 3706,17 S15,00W 3949 33 0 3887,34 3812.03 S20.OOW ~043 35 0 3965-26 3889,95 S20.OOW 4136 38 0 ~0~0,01 3964,70 .$20,00W 4336 40 45 419~,60 4119,29 &ISeOOW 156.92 S 39,93 W 193,66 S 51,87 W 161,92 S 14 16 41W 200.49 S 14 59 41W 249.82 S 67.97 W 258.91 S 15 13 17 W 311,37 S 87.38 W 323,40 S 15 40 34 W 360.76 S 105.36 W 375.83 S 16 16 49 W 412,74 S 12~.27 W ~31,04 S 16 45 26 W 532.68 S 165,57 W 557e83 $ 17 16 1 W 3,033 4.230 3.026 2,881 2.128 3.226 1,~0 5274 41 ~5 4905.17 4829,86 Slg,00W 1114,16 S 357.3~ W 1170,06 S 17 46 57 W 0,332 5743 42 0 5254.38 5179,07 S22.00W 1407.36 S 466,96 W 1482.81S 18 21 21W 0,291 _5959_32_30 5414.27 ..... 5338.96__ S21.00W !5~2.48...S .......... 520.19...W 1627...84....S.~8._38._~!' W ..... 0~3..13 6419 42 0 5754.77 5679.46 S20.OOW 1832.18 S 628.50 W 1936,98 S 18 56 2 W 0.146 1~9.00 __1~7~_3~ ...... 255,02 ~18.97 371.32 552.53 853,45 1160,35 1472.33 1617.26 1925.52 ................ i~.,.~ . . SOH !0 WELL SINGLE SHOT SURVEY 10 FEB 81 RECORD OF SURVEY · __..TRUE .................................................................. DOG_LEG ~EAS. DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L O S U R E S SEVERITY DEOTH ANGLE DEPTH SEA DIREC DISTANCE ANGLE DEG/IOOFT ................ D_..M ....... DEG, ............................................................................................. D ......... M ..... $ SECTION DISTANCE 6892 40 15 6111,06 6035,75 S20,OOW 2124,50 S 734,90 W 2248,02 S 19 4 53 W 7_364_37_3_0 ........ 6478.,48___6403,17 .... $2.2.,00~ ..... 2~.0.1,._02 S__841,05 W__2544,07 S 19 18 17 W 7838 33 45 6863.70 6788.39 S22.00W 2656.97 S 9~4,46 W 2819.84 S 19 34 6 W 8334 32 30 7279.08 7203,77 522,00W 2908.27 S 1045,99 W 3090,66 5 19 46 54 W ___8.~_93._33._~5 .....7412.24 ..... 7336,93 .......S22,00W .... 2988,83 .... S ..... 1078..54_..W ..... 31~7..48._$..!9_50_.32 W 8716 34 45 7596,57 7521,26 $30,00W 3101,54 S 1133,51W 3302,18 S 20 4 32 W 8967 38 0 7798e63 7723e32 S32,00W 3229,12 $ 1210,17 W 3448,44 S 20 32 39 W 946.1_36_45 .... 8.191.,20.__8!15.,89___S3.6,00W__~.4~!.,~7__S ,,,!.3!!,~1 W 3740,66__S._2~_3_6_~6. w 9859 35 15 8513,18 8437,87 S39,00w 3663,24 $ 1520,21 w 3966,15 $ 22 32 16 w 11170 27 30 9631,63 9556,32 s41,Oow 4185,68 s 1958,59 w 4621,25 $ 25 4 34 w 0,370 0,603 0,79% 0,252 0,786 1,249 1,330 0,385 0,453 0,592 2235,34 __25~0.' 3077,00 3163.75 3289,14 3~37,20 3961,97 4621,25 THE FOLLOWING INFORMATION IS EXTRAPOLATED TO TD 11230 27 30 9684.85 9609,54 S~l.OOW 4206,59 $ 1976,76 W 4647.90 $ 25 10 11W 0,000 4647,90 DOTTOM HOLE CLOSURE 4647,90 FEET AT S 25 10 ll W SOH 10 WELL .uV~EAS U R ED_D E P_TH__A N D_O_tH E R_ D A TA_E.0 L I~ V E RY~_EVEB_Z0.0_E EE_T__0 F__~_UB_::S.F-~k_D_F~_/JJ., ......... ........................................................... TRUE MEASURED VERTICAL DEPTH DEPTH · SUB MD-TVD VERTICAL SEA DIFFERENCE CORRECTION TOTAL COORDINA.TE5 FEB 81 175 175. 100 275 .......................... 275' .......... 200 375 375. 300 475 475, 400 5_75 575, , ', .... 5.00 675 675. 600 775 775. 700 _875 .875, ...... 800 .... 975 975, 900 1075 1075. 1000 1L7_5 11_7.5_. . ,LI.10_0 .... 1275 1275. 1200 1375 1375. 1300 _1475 1575 1575. 1500 1675 1675. 1600 .1.7!5 ___ 1_7__75, .... IZ.O_O 1875 1875. 1800 1975 1975. 1900 _2075__ _2075_. 2000__ 2175 2175, 2100 2275 2275e 2200 23_7_5 2375 ,__2300 0 0 .0 0 0 0 0 0 0 0 0.00 S 0._00 $ 0.00 S 0.00 S 0.00 S 0.00 W 0._..00__W_... 0,00 W 0.00 W 0,00 W 0 0.00 0 0,00 .0 0.00 0 0,00 0 : 0,00 0 0,00 S S 5 S $ $ 0 0 0 0 0 ,00 W ,00 W . O0__W. ..... ,00 W ,00 W · 00 W 0 0 0 .0 0 0 0.00 $ 0,00 S 0.00 $ 0.00 S 0.00 S 0.00 S 0,00 W 0.00 W 0.00 W 0.00 W 0,00 W 0,00 0.00 0.00 · 00 W · 00 W ,00 W 0.00 0,00 0.00 0,00 W- 0,00 W 0,00 W 2475 2475. 2400 2575 2575. 2500 2675 2675e 2600 . 2775 2775. 2700 2876 2875, 2800 2976 2975. 2900 3077 : 3075, 3000 3178 3175. 3100 3280 3275. 3200 3384 3375, 3300 3459 3475, 3400 3595 3575. 3500 0.00 0.00 0.00 0.62 4.30 14.12 25.40 41,65 62.14 3 88.28 118.51 153.41 S S $ 0,00 W 0,00 W 0,00 W 1,19 E ~3,04 E 3..~_20 E 0.17 W 6.03 W 12.83 W 19.99 W 28,09 W 38,75.'W h~,EASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTHe 10. FEB_Si TRUE ........ _M~ASURED VERTICAL DEPTH DEPTH SEA DXFFERENCE VERT ! CAL CORRECTXON TOTAL COORDINATES 3705 3675, 3600 3818 3775, 3700 3935 3875. 3800 4055 3975, 3900 4181 4075e 4000 4311 4175, 4100 4442 4275. 4200 4574 4375, 4300 4705 ..................... 4475, .......4400 4836 4575, 4500 4968 4675. 4600 5~ol ..... 47.75. ...... 47oo 5234 4875, ~800 5368 4975° 4900 29 42 59 79 105 135 16'7 lg8 __230 261 292 325 .~. 358 392 9 13 17 20 26 30 195,67 S 52,48 W 246,48 S 67,07 W 304,07 S 84,78 W 36?,26 $ 107,72 W 438,99 S 133,71 W 517.23 S 160,51 W 32 31 32 31 31 33 33 34 598,41 $ 186,93 W 680,10 S 213,47 W 769~_5 ..... 239~!1_w 8~1,~3 S 265,91 W 923,10 S 292e78 W 1005.71 S 320,$0 W 1089,00 $ 348,71 W 1173,26 S 378e04 W 5502 ................ 5075., ..... 5000 5636 5175. 5100 5771 5275. 5200 5_99_6 5375, 5300 461 35 495 34 530 35 6042 5475, 5400 .. 566 36 1257,23 S 408,66 W 13~0,85 S 440,57 W 1424,75 5 473,97 W 1509.12 S 507,30 W 1594e64 S 540,12 W 6177 __6312 6446 6580 63_L3 6845 6976 7105 ....................... 6275. 7233 6375, 7360 6475. 74~ 6575, 5575. 5500 5675, 5600 5775, 5700 5875, 5800 5975, 5900 6075, 6000 6175. 6100 601 671 704 737 769 80O 6200 .......829 6300 857 6400 884 6500 909 35 1679,88 S 572,29 W 35 1764,85 $ 603,85 W 35 1849,14 $ 634,68 W 33 1933,10 S 665,24 W 33 2015,24 S 695e14 W 32 2095,97 $ 724,52 W 31 2175.12 S 753,50 W 29 2251.96 S 782,42 W 28 2326,49 $ 811.31W 27 2398,75 S 8~0,13 W 25 2468e73 $ 868,41 W 7609 6675, 6600 933 7731 6775, 6700 955 78.52 6875, .... 6800'_ ...... 976 7972 6975, 6900 996 8092 7075, 7000 1016 24 22 21 2O 20 2536,24 S 895,68 W 2601,36 $ 921.99 W 2664,15 $ 947,36 W 2725,67 S 972,21 W 2786.~9 S 996,79 W SOHIO WELL ,_MEASURED _DEP TH_AND_OTHER_DATA_FOR~ 5VE~RY_E_V_EN 10 FEB 81 TRUE HEASUREO .............. VERT! CAI,'- sUB ....... H'D=TVD- DEPTH DEPTH SEA DIFFERENCE VERT I CAt. CORRECTION TOTAL COORDINATES 8211 7175· 7100 1035 19 _8329 ............. 7275.._. 720.0 ..... 1054 ...................... 19 8449 7375. 7300 1073. 19 8569 7475. 7400 1093 20 8690 7575.,_____750.0. _ 1_1.1,.4 .......... Z.1 ~ 8813 7675 8938 7775 9064 ..... 7875 9190 7975· 9316 8075· _9441 ......... 81.~5,____ 9566 8275 9689 8375 9812 ................... 8475 9935 8575 10056 8675 __1.0_176 8775 10296 8875 10414 8975 10531 ................. 9075 10648 9175 10764 9275· ........ 1087~ ..... ~37~.· .. 10993 9475. 11106 9575. 11219 ............... 9675. · 7600 1137 23 · 7700 1162 25 . ..... 7800__1188_. 26_ 7900 1214 26 8000 1240 26 8100 .....126~ 25 · 8200 1290 25 · 8300 1313 23 · ..... 8400 .... 1337 ................... 24 · 8500 1359 22 · 8600 1380 21 · 8700 1400 20 · 8800 1420 20 · 8900 1438 18 · ....... 9000__1455 17 · 9100 1472 17 9200 1488 16 9300____1503 9400 1517 14 9500 1530 13 9600 1543 13 2846.61 5 1021,08 W 2905.7 2966,10 5 1069.36 W 3027.76 5 1095.36 W _3~8.66 $ !!~24 W 3149,99 $ 1161,92 W 3214·02 S 1200·78 W 3279,48_5 ....... 1242~_1.1_.W.. 3343,83 5 1284,38 W 3406·69 S 1327·30 W 3467,97__S,__1370.79 W 3527.86 S 1414·81 W 3585·95 $ 1458e99 W 3642.06 $ 3697.06 S 1547,65 W 3750.24 $ 1591,03 W __380!_,~! S 163.3_,~h_W 3852,07 S 1674.90 W 3900·78 S 1715·42 W 39~8,.04 5 3993·89 $ 1793·67 W 4038e33 $ 1831e41 W' 4081.40 5__1868.2_5_W 4123·12 S 4163,50 S 4202.75 S 1904.19 W 1939.23 W 1973e43 W 10 FEB 81 ,INTERPOLATED VALUES FOR EVEN 1000 FEET Of MEASURED DEPTH. ............................... TRUE. MEASURED VERTI (gAL SUB DEPTH DEPTH .SEA TOTAL ¢OORDINATES 1000 1000. 924. 0.00 $ 0,00 W 2000 2000, 192/+. 0.00 S 0.00 W 3,000 .................. 2999. ........ 2923. ................. 16.80._S .......... 2.65 .... E /+000 3929. 3854. 337.85 $ 5000 4699. /+6240 9/+2082 6000 5444, 5369. 1568,34 S 7000 6193. 6118. 2189.55 S 8000 6998. 6923. 2739.97 S 9000 ........ __7824 · ........ 7749e 3246e31 $ 10000 8628. 85 5:~. 3725.73 S 11000 9481, 9406. 4125.42 $ 97,02 W 299,33 W 530,09 W 758,87 W 977,99 W ~ 220.96 W 1571.01 W 1906.25 W IZ TA'L-F... Vl E' ' SOHIO ~LAsKA;PETRO TVD = 9685, TMD= 11,230 t ~ ! ': .............. ~ ~ ......... j ; ' , 1 i , - - ! i l-;-'~-' ~17"~..;_-I..'~ ;i i . .'~i"~ !; :,,/~, I February 17, 1981 Mr. Gary Plisga Sohio Alaska Petroleum Company 3111 C. Street Anchorage, Alaska 99503 Re: Our Boss Gyroscopic Survey Job No. Boss-16748 ~?~-~'-~,~' MP.Track We11-22-31-11-13 #2 (SEC30 TllN R13E) Wildcat Field North Slope, Alaska Date of Survey: February 12, 1981 Operator: Blaine Baertsch Dear Mr. Plisga: Please find enclosed the "Original" and seventeen (17) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. ~' Thank you for giving us this opportunity to be of service. Yours very truly, SPERRY-SUN, INC. Ken Broussard District Manager KB/kc Enclosures Alaska Oit & Gas Cons. Commission Anchorage SOHIO ~LASKA PETROLEUM COM, PANY --q~,-2-~-z~i-ll-i3 sec 3o TllN Ri"3E WILDCAT FIELD ALASKA TRUE MEASURED VERTICAL DEPTH DEPTH SPERRY-SUN WELL SURVEYING -ANCHORAGE9 ALASKA COMPUTATION DATE FEBRUARY 17, 1981 ._S._y.._B..,~EA . C OURSE VERTI C/~.L INCLIN-ATION DEPTH DEG MIN : .. ] ::DATE<..OF'SURVEY FEBRUARY 119 1'=)81 BOSS GYROSCOPIC SURVEY dOB NUMBER BOSS-16748 KELLY BUSHING ELEV, = 75,31.FT, '"-i'T'~?'':~ ..... '-~ ......... :' ':.-'~.- ::...': ~OPER ATOR SC H D[RECTZON SEVERZTY RECTANGULAR COORD[NATES VERTICAL DEGREES DEG/[O0 NORTH/SOUTH EAST/~EST SECTZON 0 100 200 100, 200. O0 00 O0 -75,31 24.69 12A.69 30 ~0 50 299.99-- 224.g8 399.99 324,6P 499.,99 424.68 599.99 :524.68 6OO 7O 80 699.99 '624.68 · 799.98 72q'67 °0 O0 10 899.98 824.6'7 999.98 924,67 099.97 1024.66 12 lq O0 O0 O0 199,97 299.96 . 399.94 . . 1.124,66 .1224.65 132A.63 50 60 70 1499,93 1599,91 1699,90 1800 1900 17'99,90 1899.90 lA2A.62 152q.~0 ~62~,5~ · 182~.59 192A.5P 2000 1999.89 10 20 ~0 2099.89 2199.89 2299,89 2024;'58 2124.5~ 2224.58 2q 25 26. O0 O0 O0 2359.88.. 2~99.88 2599.87 232~ .57 2424.57 252Q.56 2700 2699.87 262¢.56 2800 2799.82 272~.51 2900 2899.59 282~.28 3000 2999 o o N o. o E '-. o. o o i~'. .,: i?i~i::::;:~'5 "w -. o o o 2~ N 5~.6o u ' .~ o 1.~ N 85.79 u' ' .27 ,98 · : ....... ....... .,.. ....................... .. :,-.. .... . ......:.;.....':..L:'./:,:L,L..>..:: ::.;:.. :.:. 0 19 N 76.50 W .05 .60 N 1.5~ 0 15 N 70.70 ~ .08 .74 N 2.02 0 23 N 72.29 W ,~ .92 N 2.55 ~ .18 . 09 .... '. :'~. ~:~1'.,.~ 1 .:.N.::~.;.:::.~?.:.~;.:::: ::::::::::::::::::::::: ~, 12 · '. '. , . ~ ., ::....., ..:.L L .c .:.'.: .':... ,. : .. ~ 0 ~ '~ .... 6,~;'79"'u ...... ,zs... 2.0~ N 5.29 U --.25 0 26 N 61,60 ~ ,~2 2,~0 N 6,09 ~ ,23 fl 30 N 62,29 U .06 2,79 N 6,83 c , o '~' $'~Tgd''''~' ....... ,32 -"~ :.':' 3'- ~ :. " - :~ :~::..A8N ..... .':~ 7'55:.: C 55 N 59'89 W .27 ' "/:'~.'~:~:?':::'::~":~:;~S'8';~:-N'}~::' ~: :.:8',O::W ':~.' -.85 ......... ~ ..... , :. ,.~.~ .............. :.. :..: ..... ;:.;....:.:..~..:.......:. .; ,., }. :.. :. t , 0 58 N ~. 0 W .13 7.25 N 10.70 W -2.3'~ 0 51 N 51. 0 ~ .16 8.3~ N 11.87 ~ -2.90 O A1 N 53.39 bi .17 9.17 N 12.9q W -3.23 0 · 22 ...... ,.,-...:-~.~;~r.~::__~ ................. ~'33 ~7.~:'.~:~' 0 26 N 77. 60 W · 12~ ;.:::~-9','9'0' .';N.~L~;~:~;~ ~L::~:~:'::· .:::.: ' ~3.33 o25 .... .... ......... ..o5 . - 0 18 S 87. O W ,14 10.05 N 15,76 W -2,52 0 2~ S 86,79 ~ .10 10.02 N 16.37 ~ -2.65 0 33 S 65,50 W ,23 9.80 N 17,15 W -2.13 ' 0 27'"-:77:F/~':-72'7"-~-~"]~'~ ......... ~-3'4~'.~:~.": :]::'::::: 7' 7.'~~: W~':.~::...:.. :'~' - 1" ~ 7 0 41 S 28"10 E .54 6.76 N 18.35 W 1.13 2 25 S 10.69 E 1.77 4.16 N 17,67 W 3.25 5 11 S ~,10 E 2'80 2,~3 S 16.96 W 9,00 & 5q S 16,50 W 2,'~ 12,70- S ~ I8.~ W SOHIO ALASKA PETROLEUM MP-22-31-11-15 WILDCAT FIELD ALASKA SEC 30 MEASURED VE DEPTH D ............ s~ERRY-suN-''' WELL-~'~.rr~'~Y'iNG COMPANY "' COMPANY T i i'N "R 13-E TRUE SUB'SEA COURSE couRsE DOG'LEG· RTICAL VERT'iCAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES EPTH DEPTH DEG MIN. DEGREES BEG/lO0 NORTH/SOUTH EAST/WEST . . ~ ... 'i . : ?:i':i !'D:~iTEiiii!:~OF::iSuRvEY;FKBRuARy 11, 1981 COMPUTATION DATE BOSS GYROSCOPIC SURVEY FEBRUARY 179 1981 dOB NUMBER BOSS-16748 KELLY BUSHING ELEV. = 75.31 FT. VERTICAL SECTION 6200 6300 6400 650 660 670 5582.8 . ,..5507.55 5656'37 ?..:: 5581,06 5730.20 :' 5654.A9 5804,48 5729'~"17 ' 41 49 S 19,39 W ,42 1896,94 S 656,51 W 2001,27 5879,10 580.3.79 41 39 S 19.39 W ,17 1959,73 S 678,S2 W 20.%7,67 __5954°06 5878,75 ~1 1~ S 19,39 W ,41 2022.16 S 700,60 W 2133,68 6029,36 : 5954~0"~ ' ' ~1 3 . 1., 0 ~.. ~:..,32 2199,30 ~1 81.98 G) 06.67 39 50 S : 2328' 10 6 59 S 18,29 W ,53 2266.66 S 78~,92 W 2391,11 6 21 S 17.89 W ,68 2~26,06 S '803,34 W 2~53,32 6 56 S 17,~9 W ,81 238A,70 S 822,00 W 2514,54 ~656.98 ~7 ~' S,;16'89~ ~ ~ .::'" '.~9 ':': :2692-37 ............... 1.. ,,¢;-.. ~ .... ;~, , ...... ,.. ~-- . . :... :.'..:..'...:- -. :::.'::..:.::.:.:,:.'..,.'..":.;.::~ ..:'. . .-, ... :.. :'.7:: :. · '., . ', ..... ~__. 5 S 17, 0 W ,70 2611,58 S 890,72 W 27~9,98 680 690 700 7100 259.42 6184.11 38 7200 337.49 6262.18 38 7300 416.30 6340,99 37 7400 6420.53 37 7500 6500.79 36 7600 '.: 6581,67 35 7700 6738.45 66~'~';1~ ....... 35 7800 6820.88 6745.57 33 7900 6904.40 6829.09 32 8000 6988.38 6913.07 32 8100 7072,49 6997.18 32 8200 7156.63 7081.32 32 8300 7240,91 7165,60 32 8400 7325,24 7249.93 32 8500 7409.00 7333,69 33 8600 7491,22 7415,91 35 8700 7572,96 7497.65 3~ 8800 765~.56 7579.25 36 9000 7813.15 7737.84 39 9100 7890.66 7815.55 39 --9200 7968 2665,76 S 907.08 W 2806.18 2718,40 S 922,97 W 2860,80 2914.71'~;--- .2R2 Z'.i;:W ':::; : 2968,~1 ::::::::::::::::::::::::::::::::::::::::::::: 2925.58 S 984,93 W: 3075,~7 2976.92 S 1000,78 ~ 3128,88 3028,88 S 1017.62 W ~183,2¢ 3240,02' 3297.60 5555,50 ........ 29 $ 28.19 W 1.50 2 S 29.50 W 1.75 20 S 31.10 W 1,05 3239.89 S 1113.57 W 3415.01 3294.12 S 1143.46 W 3476.66 3348.67 S 1175.34 W 3539.40 34'02'70::181 1208.12 W 3602.03' · · ., : 50 S 16,60 W 1-28 53 S 17. 0 ~," .98 '511~ .......... 'S':~ 1-6 ;'.~'97-w- 37 · S 16,39 ~7 :S 16-39 20 S 17, 0 U .55 39 S 17,29 W ,35 33 S 18,60 W 1.15 · ~ ANCHORAGE~ ALASKA ., ' ' ~' ~ DATE OF suRVEy FEBRUARY i SOHIO ALASKA PETROLEUH COMPANY ~ · .i .::. . :,'-'F,'P': 2 2 - 51 - 1 1 - 1 3 S ~'t~-~-6--t"i-i'~--'R 13E C OMPU T A T'i"ON-~DA'T£'~ ~ B-O'SS ..... G¥'~-OSC'OPI C' "S UR v E ¥ WILDCAT FIELD FEBRUARY 17, 1981 dOB NUMBER BOSS-16748 ALASKA KELLY ~,USHING ELEV. = TRUE DEPTH DEPTH 11, 1981 j 75,31 FT, ..................... .'; ', ;. :;',: ,?: !.:,: OPERATO R:'B ~ A;!I NSi;::ii:'B,?A;SiR T'S'~C~ ' - SE';'I . .;:'DOG'LEG`:. SUB SEA COURSE COUR '" ' "::' : ~ --VEE'T]:i~'AL ....... ]:'NCL INA T ION ....... D]:RECTI'O~":-S1KVERq:TY-~-"~A-NGU'I' AR' ..... CO'gAl} !NAI'E'$ ....... ~'L-RTTC'AL' DEPTH DEG H[N DEGREES DEG/[O0 NORTH/SOUTH EAST/~EST SECTION 3100 5098.09 3200 5196.51 3300 3293.95 3400 3390.34 5500 3~85 3600 3579 3700 3670 3800 5759 3900 .380'5 ~000 3929 ~100 4010 4200 4088.54 /+013.23 3c.. 57 S 17.60 W 3.02 ~+51.12, S 153.06 W q7/+.71 ~ 3 0 0 .~ 1 ~ 4 ~8 ..... ~0-89 ;'~ 7 q 0 4 0 S 1~ · 1 ..... ~' · · · :.· 8~ 5 1 2:6::::::::::::::::::::::::::::::::::::::: :.:-i::Z:2...:.~ 5::.:::W::..:: ..... :: · .: 55. · 0 ~ ~700 ~q67,75 q3~2.~ ~0 27 S 1R,29 W .32 760.98 S 253.95 W 799,07 ~800 ~5~.72 ~68.~1 qO 40 S 18.69 W ,3~ R22.65 S 27~.56 W 863,8~ ~ 9 0 ¢ ~ ~ 1 9; 5 6 ~-~ ~'; ~-5 ............... ~ 0 "~ 2' 'S 1'8 ,-g~ U . :.::,: .-07~ :: 9 9 ~ '0 ~ 5100 4770.1~ q69~.83 ~1 35 S 19. 0 ~ '~' :.:. 1059 5'rO-O'~~-~~'~--~'~W~'gZ53 ..... a'i'" ~S .... S 18,79 U ....... :::'%'1'9 ...... '":: .... .rI7~'5 5300 n919.15 ~8~3.84 a2 16 S 18.69 u .55 1135.12 S 381.S0 u 1192.9~ 5~00 ~992.86 ~917.55 ~2 ~5 S 18.69 ~ .~7 1199.13 S ~02.97 ~ 1260.27 5~~ ": '- '~ ~ ~f';'I'7 .............. 4'2 '": "2 S-',":-" S'" 1-9';'6 0 ~ W : · ~9~ :'. i 276 5777~ O 6':::5 :.::: :::::::::::::::::::::::::::: I6:::::~ W:.:.':::::: : ' I5 2 7 · ~ 5 6000 5435.66 5360.35 q2 21 S 20.29 W .20 1579.3~ S 5~2.10 ~ 16~.~1 6100 5509,3F~4?fl';"07 ~2 ..... 38 -': .... S:;20-;T'~ .~-~6:~:.Z,::~g ". 56.5-~ --173i.86 · 56 3~+10.25 19 7 S 15.50 W 2.70 118.37 S 51.35 W 129.03 .20 3503.89 21 55 S 15.79 W 2.81 152.12 S 60.81 W 163.75 · ~ 3 3 5~5 ~'I j- .... 2 6" -~i:::~'.:':'::~"T-i'~-~:'~'~6:::~ '~""~7'--~'4'-~-4 5 ':. '179~I.~'~57i.%S ~::~/::~:?::'//:::: ~:.71'". 8 ~.: :W::::-. ~04 ' ~ 6 : : : ::':':: :::::::::::::::::::::: 25 o. 22 · 01 3683.70 2B 55 ' S 16. O. W': :::'::': 2.57 '30 ' :3769.99 31 ~6 ' S 17"69 .U ':::-'":.:. :: 2.99 W:" 300.~0 .04-- 385'3,73 3q '~27 ........... S-~1'~"2~9"'~'' .................. ~-"7i 3'36727"~'"'~':'~"::'~'~:~'': ................ :':':":1:16"0~":'~ ............ 3'5~g .23 393~.92 56 56 S 17.79 U 2.50 391.89 S 13~.16 W 412.85 SOHIO ALASKA PETROLEUM COMPANY WILDCAT FIELD ALASKA TRUE MEASURED V 'F~-I'-i-~ A L DEPTH DEPTH · ANCHORAGE, ALASKA : :'.;:~i<: ':<.: i>~ ; : · ' ' ' FEBRUARy 11, 1981' ..... C 0 M P U'T ~'TI ON"D'A"T E -~-~G Y'R 0 SCO Pi'C ' 's uf{ VE Y FEBRUARY 17, 19...P,! JOB NUMBER BOSS-IG748 KELLY BUSHING ELEV. = 75.31 FT. ............... : ..... : ---': .... T .............. : .... ~ .... .~ .:. :~~~-R::~!BL:A1NEi B'A'~'.~ ' coursecou :sE' . : ' SUB-SEA VE"R-T I'~ AL "I NCL'i NA TI ON 'D I R~C'TI ON ......... SEvER'ITY"~R~-A:~6~:O'E'A'R~" ~' ~~A'~'E S ...... DEPTH DEG MIN DEGREES DEG/iO0 NORTH/SOUTH EAST/NEST SECTION 9300 80q6,05 7970.74 9qO0 8124.80 80,49.q9 9500 820q.$8 8129,57 --9600 --8286.16 --821'~'~'85 9700 8367.89 8292.58 9800 8~49.q7 837~.16 9900 8530.65 8455,3q 10000 8611,79 8536,48 10100 8693.13 8617,82 10200 E774.75 869'9"~q 10300 10~00 10500 10600 10700 10800 10900 11000 F-"'lllO0 I 11175 8857.28 8781,97 R940.68 8R65.37 -- ~'O'~Z~. 69' i '--~'9~-9 '. '3'8 ..... 9109"36~' 905q.05 9194.83 ':',9119.52 9367,58 9292.27 5454.6~ 9379.32 95'~ii'6 ....... 9' ~'g6",' 8-5 5608,30 9532,99 9657,01 9581,70 35 35 34 33 33 32 31 30 30 20 29 "28 27 27 . 3'8' ~:3.."? ......... ~ 3'f';-~/9- ~:",'~777,;~-9~'-~ii~;II..S'<'T~ :I'2'410;98..'-TW~ .. 3~-~-2 'l 37 27 S 32.19 W..:: ~ ..:~:'~ ' 1~2.73."6~ :W.~<:~:~ :3725.0 ......... ~'~ .... ~ ....... s ~:'~"."~-~ ..... ~ ....r;~'~"~~;o'~'s · ...... ~'z'~'~8~"5~'"w ~ 35 z2 s ~.~ ~ .~ 3~s3.~0 s z~72.07 u 35 27 S 55,50 W .58 3700,72 S 1406.03 ~ 3954.29 36 0 ......... ~-~'5~'~'0~T¥;'' ~':;"~"'~i'::rjS"~"'~T~7~4:8';~.2t;,~;<.S~?<-<. ~,39~;94.:;:'W:?.' · V~f'1,42 49 S ~0,39 W 1.80 3932.65 S 1578.70 W 4235.89 8 S 39.50 W .85 3974.9~ S 161~.1~ ~ 4288.81 '" 3 3 ~-" 3'9";' 2 9'-'~T ....... :'-'~=; 6.~.~..~ :~ ::~.~'3'~ 0 ;~9 9 ........ ~ 2 s ~.'2 9~' u . ~ 5' .' .,, 3~ 2. z 8 ,.~ s 3~.'~0 ~ .- ' .~"~': '~.2.z2 .0 s ~.~ u .s~ .z77.2~ s z777.5~ ~ .5~.~0 16 S 58.10 W .50 ~2,5.85 S 1808.16 W ~587.,7 ~l S 37'10 W l' ~ '17 :' ':~ < ~668.36~ HORIZONTAL DISPLACEMENT : 4693.21 FEET AT SOUTH, 23 DEG, 32 MIN. WEST AT MD = 11230 Lc. u LA T I 0 N P R 0 C E D UA-~'~- 'XiR E- B.. A'S E O '- 0'~' T Fi-E 'U ~-E"-O F T H R E E ..... DTI~.-~!:~O~TAL..i:./R:-AiD.:I.USi:i' OF/. CUR VA TU R E'.:N E .TH 0 D · LSOHIO ALASKA pETROLEUM c9~2,6.NY' P-22-31-1i-13 SEC 30 TllN R13E WILDCAT FIELD ALASKA · ANCHORAGE" ALASKA ........ COMPUTATION DATE 'FEBRUARY 17, 198! DOB NUMBER B0SS-16748 KELLY BUSHING ELEV, = 75.31 FT, TRUE SUB MEASURED VERTICAL VERT CEPTH DEPTHL ... ~ 'DE :. i~.__ 0 0.00 -75 1000 999.98 ~2 2000 1999.89 192 3000 2999.0A 292 AO00 5000 6000 7000 9000 [ 10000 -SEA TOTAL ICAL RECTANGULAR COORDINATES MD-TVD VERTICAL A~.G7 2.40 N G.O9 t.t .02 .02 ~+.58 10.02 N 15J12 W ,11 .08 :3.73 12.70 S 18,3/+ W .96 .85 3 o ~85 556 6181,98 610 6988.38 691 7815,15 773 8611 ,:79 ' 85~3 11000 9Z~:54.63 :/. 9379.32 · 11230 9657,;0'1 ,,. ;....9~_8.!..70' 6.67 2206.63 S 763.95 N 818.02 253.68 3°07 2770.3~+ S 938.75 I,~ 1011.6,2 193.59 7.8~. 3294.12 S llA, 3.A. 6 W 1186.R5 175.23 ~ 2 1 5.8 5':,:: S :.:': .:~:.: 1::8 0 8'.16 ..~ THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVaTURr METHOD. WILDCAT FIELD FEBRUARY 17~ 1981 JOB NUMBER BOSS-167~8 ALASKA KELLY BUSHING ELEV. = 75.31 FT. MEASURED 0 --75 ZNTERPOLATED VALUES FoR EVEN 100 FEE'T OF SUB i SUB -SEA VERTICAL D'EPT TRUE VERTICAL DEPTH 175 ;'75 475 575 1075,3.1 1175.31 1375,31 1.475,31 i575"'7~i ~6.75,31 TOTAL RECTANGULAR COORDINATES 675 775 875 ~75 1075 1175 [7'75-31 MD-TVD VERTICAL 7'~'$-I 0 ;~'0 0 "' ',l 3 "N= ..................................... ;'1"'8'~'''w · u u -- 175.31 100.00 .51 N .8fl ~ .00 .00 2175.31 200.00 .57 N 1.41 W .01 .00 3 ? 5 ~' 3'i ~'~'0~2~ 0 ......... "70~'-:'N:T~"~:']"~ T':~":-:T~'I-;"9'~'~'' ' :: '~..: .;'.~'' 0 O .~:: .~: ~ : 575' 3 z ' :. :' '5 o o. o o z. o 6 N' ':. :;-.'~/~., 3':00 ~:::' :;;:' :' .:.:., ~: ~WS~-z .... ~ -'~'o';o o ............ z. 29' N''''-'''~''~:'3';''5~'-' ~':-" '"--- ...... :":::"""'",~ ......... :' ...... :: '~': ''~ ..... :"' O1 Do ~75,~1 700,00 1,~ N ~,~0 ~ ,02 ,00 675.31 800.00 1,95 N 5.07 W .02 ,00 900;00 ..... 2.31' N' . - ..::.: :. 1. · :.... . · .. ~ .............. 1~00.00 5.57 N 9.23 ~ .05 .01 1~00.00 6.95 N 10.~1 W .07 .02 .............................. ;~. ~;.~;.~...~.~.~.~.~ ~.~. ;~ ........ ~.....: . >1': 6~.}::'...:'::::..'~.::::~C-..: ~.~:;'?-:.?::.f'(':~.;::';';-.::.:.:'Z:.'}:....'S . .~:~ ::':, ::':, ;;, . ' 1275 1375 1475 l 1675 1775 l "l [ SOHIO MP-22-31-11-13 WILDC~.T FIELD ALASKA ........ -- ~ P E R R Y - S U N W E L L S U R V E Y I N ,.q C O'M P/~ N Y i~ :: ~ ~:..ili:i!ii~?i!!!i'i<.i:i]::. :~::. P A 3 E ANCHORAGE, ALASKA 'i.' ' ' . : ALASKA PETROLEUP. COMPANY · i. iii~::i/~: .:ii:.iDA~.-61:iOF;i?SURVEy FEBRUARY'11, 1981 SEC 30 TllN R13E COMPUTATION DATE FEF. RUARY 17,~ 1981 dOB NUMBER BOSS-167q8 KELLY BUSHING ELEV. VALUES FOR EVEN ::ZOO? FEET OF;"~:O~S;~EA DEpT . .-. __.___=_,____iNTi;..RPOLATE. D = 75.31 FT. ' MEASURED TRUE sUB-SEA VERTIC~,L VERTICAL DEPTH 1875 DEPTH . ".DEPTH 1975 2075 2175 1975.31 1900.00 2075.31 2000,00 2175.31 2100.00 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL '~ 0 R T H / S 6'-0'~i:" ~i~ A S T/W E S T.: ~ D I F F E R E 'N.C!Ei:!iili!:!!i;~i~i:~ORii~EC i~;iION::!i ~:i:: ?i::!.ii::!:! iii:i.:i :-'::! ::~ !/:. ~::::.....: .... · ,, · 86 . N. ~ · 1 · 19 ~ . .~ ., .I:O:::~,~.::'~..~;..i.~'!~i.~:,?.~?:.'~:~','¥, 00 · ~.. .. ~ '. 10.00 N 1~,9~ W ,11 ,00 lO,OG N 15,63 W ,11 ,00 10.03 N 16,20 ~,! ,11 ,00 2275 2375 2q75 2575 2575,31 2500.00 2675 2675.51 2600.00 2775 2775.31 2700.00 2875 2875.31.,.' : 2800,00 2976' 2975,31 · ' 2900.00 3076 3075'.31':':: : $000,00 3178 3175.31 3100'~'00 · 31 ." .-~' 2 ~ 00 · 00 ., · 2 N' ..~ ...... ..~.. 3, 7 · 68 ~, :'. 3,~2.1~:~:~i?:.<:~..~¥.i~:~-:~!~:;;:':'!:,~::~.~..?~.~..~¥.:..?~i,00 :?'..- ~. 7.93 N 18.37 ~ -12 .00 7.02 N 18,~9 W .13 .01 5-18 N 17.86 W .16 ,03 7. 99 S 27 '97 W 3.07 1'~ 3200,00 58.70 S 35.21 W 5.q6 2.39 ~300.00 8q.63 S 42.19 W 9.02 3.56 ~600.00 ~ ............. . ......................... , ...... ~.~J. .................... ~, . :..:.: .......:..:...:,.:.;:;.:.:: ::.:...:.,.:.:g:~ ..:.::.:....... ::;.:-:.. ::.::.:. :.:., :, ,, 3280 3275.31 338~ 3375.31 3¢89 3~75'31 5595 3575'31 37 05 3675'2 I ALASKA PETROLEIJN MP-22-31-11-13 WILDCAT FIELD ALASKA ME~SU --DE P T H 3 COMPANY SEC 30 TllN R13E INTERPOLATE2 VALUES U~ R Y COMPUTATION DATE FEBRUARY 17~ 198~ dOB NUMBER BOSS-1G7~8 KELLY BUSHING ELEV, = 75.31 ................. ~ . .. ~ .' ~.:~:~: :::~::~ ~.OPE'.R',A::T:O R' B E A:I NE :'~B A~~ .... ' TRUE SUB-SEA TOTAL RED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ' . D ¢_.'p' T H .. D'E"P'TH ...... N 0 ~. T H / S O'U T H' .......... £~S'T7gE S'T:'-T-UTF FE.:~E'N c ~.~ :4.::;:::~:.:~.:~'~:.c0 R ~:E G:::~ t 0 N':: ':.:-: ~5 ~:~7'5~-i'--~"o"o";"oo ..... ~o2'5~ s ...... '-':~""-~"o-~'~'~ ....... ~ ..................... ~+056 3975.31 3900 .'00 4182 4075.31 4000.00 4~1~ '4.i.?'~,~1 4ioo.oo ~q~6 4275.31 ~200.00 q578 ~375.31' ' ~300.00 PAGE 8 - --~709 4~75o31 4~'0'0.00 46el ~575.31 4500.00 4975 4675.31 Q600.O0 --5-i-0' ~ 4:7 ?:5 ,~T-----~?-O' o'. 0 o' 5240 ~875,31 4gO0.O0 5376 4976.31 4S00.00 '5'53.1 -5 0-0"/'5 .-T3I ......... 5'0 0 0 · o 0 5647 5175.3~ 5100.00 5783 5275.31 5200.00 --5 S 1-~-----~"r5%.-~-1 ....... 53 00.00 6053 5475.31 5400.00 6189 5575.3:]. 5500.00 366.98 S 12.6.16 U 81.06 20.86 4a0.67 S 149,74 %4 107.51 26.45 5'2 1 ,'27:'-~?--~:"~i'-75-','7:7' "¢, ............ '~ ..... .. ..r ........... .... ....... ~..:....?.......:-.. ' ...... ' .. .. ~o~.5~:s:': ':-:2o~.~1 ~ .1 : -: 7 ~ 7. ~ 0 .... s: ....... ::~ ...... ~-~2'53; ~s" u' ................ l";~i:::' :':~"':'::::":': .... ' :: 848.35 S 283.26 ~ 256.33 31.71 930.02 S 311.02 W 298.~0 32.06 013 ' 20 '],'S "~' ': :'"'~3'3 9, 75 T Y-~"-'-'""~~..;:~.::.?~:~.;:.:~:::~;.~.'./-=============================== ~;'2:1:: .'::' · .:. z ~ ~. 7 ~. s . ~ ~ 7.7~ ~ .:o o:; 7::9:::~]; ~ '~ ~:. ~.~ :::}~:~'::~ ~:: :.~:. ~:;::.~ 5'2'7 ::']~. ~ ~ 7 o' ~'~ s ..... : ...... ~e 7; ~-~ .... u ...... ' ............ :-~"~'~;'~s'~''''~': ......... ~?':'~'~' ~'::~:'~'~ ;~'~":" ''~'' :': ~ '- 1~57.07 S ~59.~9 W ~72.52 55.87 11, 1981 FT. SOHIO ALASKA PETROLEUM COMPANY 30 TllN .... R13E MP-22-31-11-13 SEC WILDCAT FIELD ALASKA COMPUTATION DATE FEBRUARY 17, 1981 PAGE FEBRUARY 11, 1981 dOB NUMBER BOSS-16748 KELLY BUSHING ELEV. : 75,31 FT, INTERPOL.AT~ED .VALUES FOR EVEN 100. FEET OFiSUB"SEA ~'Di~~;'~ '~L :'~? ".' : : . :' MEASURED DEPTH 6325 6460 TRUE VERTICAL 6594 6728 <'UP..-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD NORTH/SOUTH EAST/WEST;.'~!'r:.'D.IFF ..... 1872,32 S 647,84 1956,55 S 677,50 2039,73 S 706,7~ DE.PTH DEPTH '5 o0.oo 5775.31 5700,-00 5875.31 5800.00 5975,31 5900,00 VERTICAL 685,55 35,1~ 719,62 34,07 752.95 33.33 6860 6991 7120 6075,31.~ .6175',,31:'~ . 6275.31 7248 6375.31 6000.00 610.0.00 6200,00 6300.00 7374 7499 6~75,31 6575,31 6675,31 6775,31 6875,31 6975,31 7075,31 7175.31 7622 7745 7~65 7984 8103 8222 6400,00 6500,00 6600.00 6700-00 6800,00 '-~6'~""0o 7000,00 7100.00 8340 8~59 8580 · 7275,31 72 . 7575'$1 : 73 7A7'5,31 '. ': 7q O0.OO 00.00 00,00 · .: 2354J48~S 812,50 u 872,88 2427,82 s 835,35 ~ 898,98 2~99.2S S 856.75 U 929.7! 2636.~9 s~::'.::::..:!::898'27 w : -.~ 2700.41.s '~!:;;:'9i'7i. 48 'V 2762,26 S 936,31 ~! 1009,13 2823,91 g 954,72 ~! 1029,04 2885,56 S 972,86 W 1046,91 3071,79..~S i-:'i:'1032.,83 W 27,75 26.10 24,73 19.08 18.91 18,87 l SOHIO ALASKA PETROLEUM COMPANY WILDCAT FIELD ALASKA sPERRY-SUN 'WELL SURVEYI .... ANCHORAGE, ALASKA . ':i : '::""::"" ''" 'c '': ~' ':'~'~ '':~':''''' ' ' · '~i.::DATE:'~OF.:i SURV'E'Y F"EBRUAR Y C 0 MP U'T'AT FEBRUARY 17, 1981 dOB NUMBER BOSS-16748 KELLY BUSHING ELEV. = · . 1981 7.5.31 · :~' . F :: ~:i-:::' :. ' · :"F. INTER.P.?LATED VALUES FOR:'EVEN i0:'0 :FEET oF' 'SUB.SEA' ;;'.: ~::!:i;::...... :..-: ':;: ;:i; ":: . FT. MEASURED 8702 ~T-5 ........ 8951 9080 9209 9337 9463 9586 TRUE SUB..-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL D E P'T FI: D rfP-TH ...... 7775.31 7700.00 3267,51 S 1128,47 g' 1176,06 25,70 7875,31 7800.00 3337.90 S 1168.8~ .6{ 120~,85 28,78 ~ ~ .......... . 7975,31 .' 7.00 · 00 3407,65 S: . ..: :: 12 11,1 ~ ~ 12 5 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :'.9:'~':'0.:5 ::;:.:: :::.::...:::..:: ,::".:.:': : .. ~: o~ ~ ~.~:l .~ :..::'.:.. .:o oo .'o o ~ ~ :5 · ~' s.::.:: L. :::::::::::::::::::::~ ~. ~o:u' .: ~:~::Si::: ~::::~::~::?.::::.'i '. ~ i :5 · ~.:l' .: ::.' :: :~': o o. o o 8:~T3i ~"~'D'D";'O"O ...... 3600.79 S ..........--i'-~S4";-1 ~ ~ i-3'r-F;:'q;"3::':"::"'::"'::'::":':::" ........ :'~"~"::':::""',"3;"5~:::':":":: ............... :':: 9709 9831 S9~5 10078 10200 '~I'D32T~ lOaql 8375.31 8300.00 8475.31 8400.00 e$75,~ 86o0.oo ~ .. B775'31:::.: 8700.00 8975.31 8900.00 10559 9075.31 9000.00 --1-O-~7'K------~ITS-F3I----'~I"O-O'; 0 0 10793 9275,31. 9200,00 10908 9375.31 9300,00 .. 3658.12 S 1375,18 k,' 1333.77 22,35 3715,70 S 1416.71 k..' 1356.42 22.64 3 7 7 A., 61" "~ '" 77::' ~-~:-Sff~'7'-f'-'~J' '15 7:9:;:::85::i.!":.~:::.':.~.i'~:~::...:..::..:::,: ~-:::;': :':.:L :2' ~:' ~ ~ ::::':: ~ ~ ~ ~ ~. i ~ s ::: i5~ ~. ~ o :::::: ========================= ~ ~:'::~ o:':., . ~ ~ ~:- ~ 5- s .... :'::'"'I:s~:~';~--'~-'~ .... :::::::::::::::::::::::::::::::: ........ : ................ ~ 3992.38 S 1628.50 W 1~66.05 19.65 40ql,75 S 1668,92 W lq8~,66 18.62 4 0 8 9 "2 7 'S ........ :~.11'~'0'7 ;"G'l' '7~ 1':5~'~19~. ' ':::" ~::': ::7' ';' -' ~29 ~:3~.~o s ' ::::.IJA~.~s'~ :: . ' :: : : :::: :: :::: ::::::: :: ':::. I ~OHIO ~LXISKA PETROLEUM COMPANY vP-22-31-11-13 WILDCAT FIELD ALASKA, ..SEC 30 TllN R13E INTERPOLATED spERRY SUN WELL SURVEYING COMPANy'--".' :'~::''::I:'' ' '' PAGE 11 ANCHORAGE, ALASKA _ i. F'ZBRu~Ry 11, 1981 COMPUTATION DATE FEBRUARY 17~ 1~81 JOB NUMBER BOSS-167A8 KELLY BUSHING ELEV. = 75.31 FT. VALUES 'FOR ......... E.V..EN .... 1.0..O...._F_EET OF SUB-SEA': DEPTH MEASURED DEPTH 11023 11137 11230 TRUE VERTICAL DEPTH 9~75.31 9575.31 9657.01 SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL .... D'~'IS-Y H' 'i ........ N'oR 'T H- / S'0'0 T H '~ c' :i.~-ii' ;-i~'T~;§:;f';) Q ~'~-T'i ........ D'i F F E ~. I :::~ ' .. ': ~,, o o.'O o ,+ ~. 2'+. ~7' .s ..~. ~. ~ ~ ~. ~ ~ ~, ~ 5,~ ~ :;, _~.,.~: 9500.00 4268.33 S 18q-R.7~ !.t 1562.41 1~.01 9'581.70 A302.55 S 187~6~ ~ 1572,99 10.58 THE --CALCULATION PROCEDURES USE THE NEAREST 20 F-OOT.i MD t TRUE NORTH I. Sohio Alaska Petroleut Company Boss-16748 Well: MP-22 (SEC31TllN R13E) Wildcat Field North Slope, Alaska Survey Date: February Operator: Blaine Bae~ Horizontal ProjectiOn . Scale 1" = 1000' 11, 1981 tsch SURFACE LOCATION )9SNL2195WEL Check Form for timely compliance with our regulations. Operator, Well Name and Number Reports and Materials to be received by: Date Completion Report Well History Samples R~ui,~d Yes Date Received Mud Log Core Chips Core De~ription Registered Survey Plat Inclination Survey ....... ~ Directional Survey ~/~ ~ .......__~ - ~ - gl Dril 1 Stem Test Reports Logs Run Yes .... , ~_1~?t.~ Digitized,,. Log Data Remarks ~K SOHIO ALASKA PETROLEUM COMPANY Alaska Oil & Gas Conservation Cont~ission 3001 Procupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton ANCHORAGE, ALAS TELEPHONE (907) 265 MAIL: POUCH 6-61 ANCHORAGE, ALASKA' March 4, 1981 STAT TEC-- 'PBUMP 22'31-11-13NO, 2 Gentlemen: Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the ~-named well for the month of February. 1981. Yours very truly, R. H. Reiley District Drilling Engineer encs cc: Well File 917 RECEIVE Alaska Oit & G~s Cons. Commission Anchorage MOI4T'HLY REPORT OF..DRI.LLI'NG*AND.WORKOV.ER.OPERATIONS 1. Drilling well Workover operation [] 2. Name of 0perator Sohio Alaska Petroleum Co~.~.y 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of Well atsurface 2909' SNL, 2195' WEL, Sec. 30, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 75.31' AMSL ADL 28288 7. Permit No. 81-10 8. APl Number 50- 029-20545 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. PBU MP 22-31-11-13 No. 2 , , 11. Field and Pool Prudhoe Oil Pool For the Month of February ,19__ 81 12. Depth au end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at month-end: 11,230' Footage drilled : 1,216 ' Ran 265 jts. 9 5/8" 479 L-80 Buttress casing to 10195'. Cemented in two stages: Fir., stage with 1524 cu.ft. Class G cement. Tested casing at 10095' to 3000 psi, ok. Ran 39 7" 299 13, Casing or liner run_aqd quant.(ties of cement. Bdttress lzner ~o 11228' 420 cu. ft. Class G cement. Tested liner at 11188' to 3000 psi, ok. Laid cement plug consisting of 58 cu. ft. Class G cement 9630' to 9490". Arctic packed to surface, followed by 2nd stage cement in 9 5/8". x 13 3/8" annulus consisting of 130 cu. ft. Arctic Set I through FO cementer at 2616'. This was followed by laying second cE~Qent plug of 56 cu. ft. Arctic Set from 2500' to calculated top of 2360'. 14. Coring resume and brief description None 15. Logs run and depth where run ~-13C/~~/~- 11,219' RF~ - 11,045' CBL/VDL/G~CCL - 11,182' Seismic velocity survey Gyroscopic survey MAR - 9 198] Alaska 0il & Gas Cons. Oommissiori Anchorage jl 6. DST data, perforating data, shows of H2S, miscellaneous data j Displaced hole with 9.8 ppg CaC12. Displaced top 200' of hole with diesel, installed and tested adaptor flange and single master valve to 3000 psi, ok. Released rig at 0600 hours 2-14-81. 1 17. I hereby certify that The foregoing is true and correct to the best of my knowledge. NOTE-Report on this form is required for each%calendar month, regardless of thJStatus of o~rations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-i-80 SOHIO SOH10 PETROLEUM COMPANY Division of Sohio Natural Resources Company AP,C;O SOHIO—BP ALASKA PRODUCTION DIVISION 0-,evron ------------- Exxon Getty TO: 113 i mobil SFO/UNIT/STATE: 9PAE SFO 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 3/9/81 #654 REFERENCE: SOH.IO FINAL DATA material is being submitted herewith. Please acknowledge receipt by signing / ,/hp,yf,llowing Co 0 f this letter and returning it to this office:— SFO/UNIT/STATE: Z44PB—,&*w4 CNL 11/21/80 #3 (—Marathon) E-2 CNL 12/8/80 #6 F-4 CNL 2/13/81 #6 J-3 CNL 11/21/80 #1 MP Track Well(13)15-11-12 CNL 2/20/81 #3 D-15 Spinner Flowmeter 2/19/81 #1 Y-3 Spinner 2/14/81 #1 SFO/UNIT/�Trickwell(22)31-11-13 FDC/CNL -2/1/81 & 2/7/81 #1&2 STATE: MP Trackwell(22)31-11-13 FDC 2/1/81 & 2/7/81 #1&2 5"(see remarks 5" on this set 5" of loss.) 511 511 51' 511 211 211 RECEIVED Carol Krieger Well Records DATE `19 J- SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company soHIo-BP ALASKA PRODUCTION DIVISION ~ ...... -.;. ,_ _ TO: SFO/UNIT/STATE: REFERENCE: SOHIO DATA ~e fo~owing material is bei.g submitted copy of this letter and returning herewith. Please acknowledge receipt by signing a it to this office:- SFO/UNIT/STATE: f/638C Logs on MP Track Well (22) 31-11-13: (Final) NGR Spectroscopy RFT FDC/CNL FDC BHCS 1/20/81 , · 1/20/81 , 2/1/81 & 2/6/81 MP Track Well (22)31-11-13(~2)Gyroscopic Survey MP Track Well (22)31-11-13 2/7/81 2/7/81 211181 & 2/7/81 211/81 & 2/7/81 2/1/81 & 2/6181 92 91 91&2 91&2 #1,2&3 91,2&3 511 5" 2" & 5" 2" & 5" 2/12/81 Magnetic Single Shot Survey 1/2.1-z/6/81 ~. : Carol Krieter Well Records ,,- E IVED RECEIVED DATE Alaska 131 & Gas Co~s. Comi_ssi~ SOHIO ALASKA PETROEEUM COMPANY February 24, 1981 3111 'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Con~ission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: MP Tract Well (22-31-11-13) No. 2 Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. RHR:ja Enclosures cc: Well File 917 Yours very truly, R. H. Reiley District Drilling Engineer ~ .,, STATE OF ALASKA ';;:~ ALASKA elL Al~,t D GAS CONSERVATION CO~MIS~ION SUNDRY NOTICES AND REPORTS ONWELLS 1. DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchoraqe, Alaska 4. Location of Well At surface: 99502 7. Permit No. 81-10 8. APl Number 50-029-20545 9. Unit or Lease Name Prudhoe Bay Unit , 10. Well Number 2909' SNL, 2195' WEL, Sec. 30, TllN, R13E, UPM 11. Field and Pool Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 75.31' AMSL I ADL 28288 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] t Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) PBUMP 22-31-11-13 No. 2 (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Well suspend~ pending installation of production equipment. The program is as follows: 1. 2. FE~ 2 5 1981 Alaska Oil &eas Cons. Set EZ Drill at 9630' and lay cement plug from 9630' to 9490'. AnChorage Arctic Pack and 2nd stage cement 9 5/8" x 13 3/8" through FO at 2615'. 3. Lay cement plug from 2500' to 2360'. 4. Displace hOle from 2360' to 200' with 9.8 ppg. CaC12 and from 200' to surface with diesel. 5. Install and test adaptor flange and master valve. 6. Move rig off location. Note: Suspension of PBUMP 22-31-11-13No. 2 withes and aP rovedb H~3roldHawkins, of Alaska Oil & Gas Conservation Comnission 2-13-81. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed__ Title District Drilling_ Engineer Date 2- The space below for Commission use % ; Conditions of Approval, if any: ~ ~Pproved Copy By Order of Approved by COMMISSlQNER the Commission Form 10-403 Rev. 7-1-80 Returned Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY February 19, 1981 MAIL:POUCH6-612 ANCHORAGE, ALASKA9 3111 "C" STREET % [ CO~,?~;,~'~-'I ANCHORAGE, ALASK [ ~_~ ~!i',?: TELEPHONE (907)26§-0 ~._,_ CONFIDENTIAL ~ , 3 G::Q~ Alaska Oil & Gas Conservation Conmission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: PBU Well 22-31-11-13, No. 2 Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of January, 1981. RHR: ja Enclosures cc: Well File ~17 Yours very truly, R. H. Reiley District Drilling Engineer . ,. STATE Or: ALASKA ALASKA AND GAS CONSERVATION Cr ' MISSION MON'I'HLY REPORT UF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~; Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 81-10 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20545 4. Location of Well at surface 2909' SNL, 2195' WEL, Sec. 30, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 75.31 ' AMSL ADL 28288 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. PB Unit 22-31-11-13, No. 2 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of. January ,19 81 ~12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at month end: 10014 ' Footage drilled: 10014 ' ~ Spudded well at 0500 hours, 1/19/81. 13. Casing or liner run and quantities of cement, results of pressur9 tests Ran 68 jts. 13 3/8" 72# L-80 Buttress casing to 2685'. Cemented with 3720 cu.ft. Arcticset II cement. Cleaned out to 2642', tested casing to 3000 psi, okay. Performed leak-off test to 0.74 psi/ft, gradient at 2706'. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/BHCS/GR/SP/T~I @ 2686' 16. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED _ ..' . TITLE District Drilling EngineerDATE ~._'-% ~ ~ NOTE--Rep~rm is required for each cale~ar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and G~ssion by the 15th of th~ucceeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 , DATE / -- RIG WELL TEST ACCUMULATOR VOLUME TEST TYPE: r-]~LY I-IFLANGE UP E~CA~I~IG SET LAST CASING: PRESSURE'& PERFORMANCE TESTS: sol~~ ALASKA PETROLEUM COMPANY BOP EL ZUIPMENT TEST REPORT t)B,OP STACK--LIST ALL ITEMS TOP TO BOTTOM, I~IANUFACTU4qIER, ~AND TYPE SIZE OF RAMS, ETC. ACCUMULATOR ACCUMULATOR ONLY TEST TEST & PUMPS UNIT PRESSURE TIME CLOSING CLOSING RECHARGE TIME TIME TIME ANNULAR '~...~--~ 0 ,-~" ~ t'~,., ~ ,..~ c / ~ ~ e c. , PIPE RAM ,: ~O~ O ,&~,~ ~, ~ ~ ~ /~.~,e ~ ] PIPERAM ':'~ ~o~ ,.~,~.. ~ ~ /~ c. CHOEE MANIF. ~OO .~ ~, TEST TOOL: ~G, ~CUP ~PACKER KELLY COCK' ¢1 .~:.C~ ~ ¢) .~; ~, CASING TESTED: ~ ~ ~ .~ FT. TO ~¢¢~.':; PSI. " ACCUMULATOR RECHARGE: ~jO O PSI BEFORE TEST, KELLY VAL~E ~2 :~ ~ ~ -~; ,~., ;..,;~ / ~ O O PSI AFTER CLOSING ALL BOP~S, INSIDE BOP - ...... '" . ...... / ~~~ e. MIN. RECHARGE TIME. ., BOP DRiEL .SEC. KELLy HOSE ~,~o O I O ~ ~ ~ TRIP DRILL SEC. STAND PIPE ' ,~,..~,~ ~/~ ~, ~ NITROGEN PRECHARGE: 1. ~/oo 2. .... ' .... · - 4. 1200 5. ~ZOo 6. /~0~ '7. CHOKE 'LINE ~00 ~~ 9. ~_~ 10. ~0011 ~o~012. KILL LINE ~ ,~ ~ 0 ~ ~ ~ 14. ~15. ~16. EQUIPMENT CHECKLIST CIRCULATING HEAD ON FLOOR INSIDE BOP ON FLooR & SUBS KELLY VALVES ON FLOOR & SUBS SPARE KELLY VALVE PVT SYSTEM OPERATING FLOW SENSOR OPERATING STROKE COUNTER OPERATING TRIP TANK LOCKING SCREWS ON BOP & ALL VALVES OPERATE EASILY. REMOTE STATION OPERATING. BOP HANDWHEELS AVAILABLE GAS SNIFFER OP£RATING BARITE ON HAND ~ / ~' ~,'~'~- SACKS GEL ON HAND ,3,,¢"' 7 SACKS WATER ON HAND '~ f.,J~¢.~ BBL SURFACE MUD VOLUME ~ BBL HYDRAULIC OIbON HAND ~' DRUMS NITROGEN BACKUP SYS. ~ NO. OF BOTTLES HOOKED UP, At '' ~ I0PSI . . -~/NITROGEN / Alaska Oil a ~as Con.~ MALFUNCTIONS & COMMENTS (ITEMIZE ALL LEAKS, MALFUNCTIONS, MISSING EQUIPMENT ETC. AND ACTION TAKEN.) SUPERVISOR: TO BE COMPLETED AND PUT ON FILE FOR EACH BOP TEST. AK Form 5800-3 (1 2/79) Initiated by: DR-JV January 23, 1981 Mr. R. H. Reiley District Drilling Engineer SOhio Alaska Petroleum Company Pouch 6- 612 Anchorage, Alaska 99502 Re: PBU MP 22-31-11-13 No. 2 Sohio Alaska Petroleum Company Permit No. 81-10 Sur. Loc.: 2909'SNL, 2195'WEL, Sec 30, TllN, R13E, UPM. Bottomhole Loc.: 1944'SNL, 4064'~L, Sec 31, TllN, R13E, UPM. Dear Mr. Reiley: Enclosed is the approved application for permit to drill the above referenced well. This permit replaces the permit No. 80-151 issued on December 29, 1980 with a December 18, 1980 approval date. Since this well was spudded before a change in bottomhole locations was requested, and a new permit was required, permit No. 80-151 is declared null and void. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digi- tized log information shall be submitted on all logs for copy- ing except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder Mr. R. ~. Reiley PBU MP 22-31-11-13 No. 2 -2- January 23, 1981 (Title 18, Alaska .Administrative Code, Chapter ?0) and by the Federal mater Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance, of this permit to dril 1. To aid us in scheduling field work, we would appreciate your this office within 48 hours after the well is s . we would also. like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casinq shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Hamilton Chairman of Alaska Oil & Gas Conse~ation C~mission Enclosure =cc Department of Fish & Game, Habitat Section w/o eno1. Department of Environmental Conservation w/o/enc1. Department of Labor~ Supervisor, Labor Law Compliance Division w/o eric1. ]~RR: be SOHIO ALASKA PETROLEUM COMPANY January 21, 1981 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 CONFIDENT~ Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: PBUMP 22-31-11-13, No. 2 Further to our verbal conversation of January 20, 1981, we propose to drill Well PBUMP 22-31-11-13, No. 2. Enclosed are the following documents, in triplicate, together with our check for $100.00 to cover the permit filing fee. le e e e Be Application for Permit to Drill, Proposed Drilling Program Outline, Surveyor's Plat showing well location, Blowout Prevention diagram, Directional Plan. RHR:ja Enclosures Yours very truly, R. H. Reiley District Drilling Engineer cc: Well File 917 RECEIVED JAN? 1981 Alaska 0ii & Gas Cons. Commission Anchorage ) STATE OF ALASKA ALASKA C., AND GAS CONSERVATION CO~, ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of uvork. DRILL [] REDRILL [] DEEPEN [] 1 b. Type of well 5. Name of operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 99502 EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I-] SINGLE ZONE [] MULTIPLE ZONE [] 4. Location of well at surface 2909' SNL, 2195' WEL, Sec. 30, TllN, R13E, UPM At top of proposed producing interval 1450' SNL, 3850' WEL, Sec. 31, TllN, R13E, UPM At total depth 1944' SNL, 4064' WEL, Sec. 31, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF etc.) Est. ~BE = 73' AMSL 6. Lease designation and serial no. ADL 28288 9. Unit or lease name PBU MP 22-31-11-13 10. Well number No. 2 11. Field and pool Prudhoe Bay Prudhoe Oil Pool 12. Bond information (see 20 AAC 25.025) Type Blanket surety and/or number Safeco Ins. 2975387 Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line NW of Deadhorse 13 miles east of ADL 28264 2093 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease llll0'MD 9530'TUb feet 2491 -19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2800feet. MAXIMUM HOLE ANGLE 39 O l (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed well 30--11--13 3100feet 18. Approximate spud date January 18, 1981 333U ,. psig@_ Surface 4390 ..psig@ 8900 ft. :X~(TVD) 21 SIZE Proposed Casing, Liner and Cementing Program Hole, I Casing Weight 26"120" 94# 17 1/2/13 3/8 72# [2 1/4/ 9 5/8 47# 8 1/2/ 7 29# / 22. Describe proposed program: CASING AND LINER Grade C )upling Length K-55 80' L-80 i~tt.I 2680' L-80 utt.I 9980' L-80 utt.I 1630' SETTING DEPTH MD TOP TVD Surface Surface Surface 9460' i8250' MD BOTTOM TVD 1101 110 2680~ 2680 99801 8650 11110I 9530 I I QUANTITY OF CEMENT (include stage data) 8 cu.yds, concrete 3720 cu.ft.-Arcticset 1430 cu.ft. Class G 310 cu.ft. Class G w/18% salt See attached proposed drilling program outline. RECEIVED JAN2 3 1981 Alaska 0il & Gas Cons. Commission Anchorage 23. I hereb¥~rtify tha~t the for~is t,,j~rect~ ~~"~~ / ~'"~-- to the best of my knowledge SIGNED % -- ~ ~ ~ TITLE District Drillinq Engine6~TE ~~eelowfor DC mmissionuse ~ CONDITIONS OF APPROVAL Samples required Mud log required []YES [~O []YES [~O Permit number Approval date ~/-/o 12-/.-18/80 APPROVED BY.~ Directional Survey required I APl number [2~YES []NO I 50-- O 'L..~ - 7,..C,.~..~"'~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMM ISSl ON ER DATE by order of the Commission J_~n~_ry 23~ 1981 Form 10-401 Rev. 7-1-80 Submit in triplicate PROPOSED DRILLING & CCMPLETION PROGRAM PBU MP 22-31-11-13, No. 2 Dry bucket 26" hole to 80' below ground level and cement 20" conductor to surface using 8 cu.yds, concrete. , Drill 17 1/2" hole to 2700'. Run open hole logs. Cement 13 3/8" 729 L-80 Buttress casing to surface using 3720 cu. ft. Arcticset II cement. Blowout Prevention Equipment consists of 5000 psi W,P. pipe rams, blind rams, and annular preventer from 13 3/8" casing point to T.D. Maximum possible bottom hole pressure is 4390 psi at 8800' TVDss (based on original reservoir pressure). Maximum possible surface presSure is 3330 Psi based on a gas col.umn to surface from 8600' TVDss and an oil column to 8800' TVD. Directionally drill 12 1/4" hole to 8650' TVD. Run 9 5/8" 47# L-80 Buttress casing to 8650' TVD and cement first stage with 1430 cu.ft. Class G cement. 9 5/8" casing will be hung at surface. Drill 8 1/2" hole to T.D. at 9530' TVD. Cement 7" liner to 500' inside the 9 5/8" casing shoe with 310 cu.ft. Class G cement with 18% salt. If well is productive, the well will be suspended. 9 5/8" x 13 3/8" annulus will be cemented with 130 cu.ft. Permafrost cement preceded by Arctic Pack through FO cementer at 2600'. Tubing and production packer assembly will be run to 8200' TVD. A subsurface safety valve with dual control lines will be placed at 2080'. Displace tubing to diesel. Install and test Xmas tree. Suspend for perforating subsequent to rig release. Details of proposed perforations to be submitted on Sundry Notice to follow. If unproductive, well will be plugged and abandoned. GK:ja RECEIYED 1/21/81 3/%1%!2 1981 ~aska Oil & Gas Cons. Commission Anchorage 23 PROPOSED _J.~MP TRACT WELL --~--~,~ '~ml ,~' I LAT. = 70° 16'40.?e" 0 ~) ~ ', LONG.'-148°55'55.8~' = ~,5o' t I ~ ~ROPOSE~ ~ I 35 BOTTOM HOLE( LOCATION ~ t I --t 28 I 1 I ' _~ ._L .... _L_ __ I T. II N. T. ION. SCALE; I"= IMILE CERTIFICATE OF SURVEYOR 1 hereby certify that I om properly registered to practice land surveying in the State of Alaska and that this plat represents o )ocotion survey of the we)lpod shown and the well su per v i s ion thereon. This survey was made by me or under my and oil dimensions and other details ore correct. Bottom h°ieER Iocotions ore furnished by ~hers. CEIVE- D~ te SURVEYOR u. a Gas Cons. ~chomge P R OPOSE D MP TRACT WELL (22-31-11-13) Locoted in SE I/4 PROTRACTED SEC. 30, T liN, R 13 E,U .MIA. T MERIDIAN, AK. Surveyed for SOHIO ALASKA PETROLEUM CO. REVISED PROPOSED BHL, REVISED (21-31-t1-13) TO REVISED PROPOSED SUR LOC. REVISED PROPOSED SUR. LOC. P.J.R. I/2-0/81 D H.O 12./22./80 D.H.O 17/5/80 Surveyed by E M. LINDSEY I~ ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502West Northern Lights Boulevard Box 4-081 Anchorage AIosko B.O.P. STACK CONFIGURATION · 1:5 5 TRIPLE RAM STAr,, _ 5000 PSI WP DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS CHECK KILL LINE DRILLING SPOOL GATE GATE GATE CHOKE LINE HYDR. ASST. GATE PIPE RAMS RECEIVED JAN2 $1.981 Alaska Oil & Gas Cons. Commission Anchorage December 29, 1980 Mr. R. R. Reiley District Drilling Engineer Sohio Alaska Petroleum Company Pouch 6- 612 Anchorage, Alaska 99502 Re: PBU MP 21-31-11-13 Well No. 1 Sohio Alaska Petroleum Company Permit No. 80-151 Sur. Loc.: 2909'SNL, 2195'~.~EL, Sec 30~ TIlN~ RI3E, UPM. Bottomhole Loc.~ 1088'SNL, 2989'WEL, Sec 31, TllN, Ri3Er UPM. Dear Mr. Reiley: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated December 18, 1980, accompanying the original approved permit are in effect for. this revision. Please note the change in well name and number in accord with our telephone communication of December 23, 1980. Very truly yours, Hoyle H. Hamilton Chairman of Alaska Oil & Gas Conservation Commission Enc lo sure cc: Department of Fish & Game, Habitat Section W/o encl. Department of Environmental Conservation w/o/encl. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 December 23, 1980 CONFIDENTIAL Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Enclosed are the following documents, in triplicate, showing the corrected surface and total depth locations of the above-referenced well. The check to cover the filing fee was previously submitted with the original documents. 1. Application for Permit to Drill, 2. Proposed Drilling Program Outline, 3. Surveyor's plat showing well location, 4. Blowout Prevention Equipment Diagram, 5. Pad map showing well course. RHR: ja Enclosures cc: Well File %17 Yours very truly, District Drilling Engineer RECEIVEO DEC 2 9 1980 AMMm 011 & Gas Cons. Commlss/on Anchorage ALASKA ~.. STATE OF ALASKA ~' -,~ AND GAS CONSERVATION CO,,~ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of well at surface 2909' SNL, 2195' WEL, Sec. 30, TZZN, R13E, UPM (Corrected) At top of proposed producing interval 700' SNL, 2900' WEL, Sec. 31, TllN, R13E, UPM At total depth 1088' SNL, 2989' WEL, Sec. 31, TllN, R13E, UPM (Corrected) 5. Elevation in feet (indicate KB, DF etc.) Est. KBE = 73' AMSL I 6 . Lease designation and serial no. ADL 28288 9. Unit or lease name 10. Well number : __-i--. / 11. Field and pool Prudhoe Bay PrudhGe Oil Pool 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number Safeco Ins. 2975387 Amount $200,000o00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed NW of Deadhorse 13 miles 2093 ' east of ADL 28264 feet we1130--11--13 310(~eet 16. Proposed depth (MD & TVD) 10440 'MD 9540'TVD feet 17. Number of acres in lease 2491 19. If deviated (see 20 AAC 25.050) KICK OFFP01NT 2800 feet. 21 20. Anticipated pressures MAXIMUM HOLE ANGLE 30 o (see 20AAC25.035(c) (2) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH 18. Approximate spud date February 15, 1980 3~U psig@. Surface 4390 .psig@ 8900 ft. ~ {TVD) QUANTITY OFCEMENT''' 'Hole :8 1/2 Casing Weight Grade 20" 94# K-55 13 3/fi 9 5/fi 72~ 47~ L-80 L-80 7 29# L-80 22. Describe proposed program: Coupling Length 80 /Butt' / 2680 /Butt. 1 9 10 ]Butt. / 1530 MD TOP TVD Surface Surface Surfalce 1 18200 8900 M D BOTTOM TV D ll0! ll0 , 2680, ~1 2680 94101 8650 i' (include stage data) 8 CU. yds. concrete 4650 cu.ft. Arcticset 1350 cu.ft. Class G; 130 cu.ft. Arcticset 290 Cu.ft. Class G w/18% salt See attached proposed drilling program outline. RECEIVED DEC2 9 1980 ~ 011 & Gas Cons. Cemmt~n Anclmrage 23. I hereb,~,~rt~ng ~rect to the best of my knowledge SIGNED~ I ~~~/%~ .- ~- ~'~ ~ ~~ ~ TITLE District Drilling Engine~TE ~' ~.~- ~O The space below for Commission use ~ CONDITIONS OF APPROVAL Samples required I--lYES ~UO Permit number APPROVED BY Mud log required /' Directio/~l Survey required I APl number []YES ~].NO [~YES-- []NO 50-- O'?.--~ - ~._ o .5-~'.~-'- // I Approval dat~ /~/~/~'o / SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE Dec6mber 29, 1980 by order of the Commission Form 10-401 Rev. 7-1-80 Submit in triplicate P~POSED DRILLING TRACT ~]ELL (21-31-11-13) Dry bucket 26" hole to 80' below ground level and cement 20" conductor to surface using 8 cu.yds, concrete. Drill 17 1/2" hole to 2700'. Run open hole logs. Cement 13 3/8" 72~ L-80 Buttress casing to surface using 4650 cu. ft. Arcticset II cement. Blowout Prevention Equipment consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer from 13 3/8" casing point to T.D. M~mximum possible bottomhole pressure is 4390 psi at 8800' TVD ss (based on original reservoir pressure). Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVD ss and an oil column to 8800' TVD. Directionally drill 12 1/4" hole to 8650' TVD. Run 9 5/8" 479 L-80 Buttress casing to 8650' TVD and cement first stage with 1350cu.ft. Class G cement. 9 5/8" casing will be hung at surface. Drill 8 1/2" hole to T.D. at 9540' TVD. Cement 7" liner to 500' inside the 9 5/8" casing shoe with 380 cu.ft. Class G cement and 18% salt. If well is productive, the well will be suspended. 9 5/8" x i3 3/2" will be cemented with 130 cu. ft. Permafrost cement preceded by Arctic Pack through FO cementer at 2600'. Tubing and production packer assembly will be run to 8150' TVD. A subsurface safety valve with dual control lines will be placed at 2080'. Displace tubing to diesel. Install and test Xmas tree. Suspend for perforating subsequent to rig release. Details of proposed perforations to be submitted on Sundry Notice to follow. · If unproductive, well will be plugged and abandoned. ~OTL% & Ge~ C4)11S, COmmis~inr~ t I 25 6 PROPOSED MP I'RACT WELL I --~---~'----~d~ LAT. : 70° 16'40.78" 0 ~1 / i LONG.= 148°55'55.8~' X = 631,9~4 t Y = 5,952,591 J 'o I R I 29 I I 80TTOM HOLE ~ 28 LOCATION 31 I ~ ......... IT.IIN. t'~:~~T' lION' ~II I I I ~ I I I SCALE: I"= IMILE CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered to ,,~_,~ OF 4/. -tt! ~_':....""...;.?,s,._'~, practice land surveying in the State of Alaska and that this plat _~._x~.~,. ii. -',.. ~ ~' ~~ ',~'~ re presents a locations urvey of the well pad shown and the we II ~W~'49T~ ~ thereon. This survey was made by me or under my supervision ~.,.~,.,.,~.~,.,.~.....~.,,~~ and all dimensions and other details are correct. Bottom hole ~~[~~.~,~ locations are furnished others. '~ ~ KENNETHB.~ENKINS ~ by ~. ~ 3661- S ~ ~ ~. ~...~/~ ~ ~..~- ~; su"v~o~ REt E iVE D REVISED PROPOSED SUR. LOC. REVISED PROPOSED SUR. LOC. DEC2 9 Nmlm 011 & Gas D.H.O IZ/22/80 D.H.O 12/5/80 180 PROPOSED MP TRACT WELL (21-:51-11-13) ACTED SEC. 30, T liN, R 15 E,UMIAT MERIDIAN Surveyed for SOHIO ALASKA PETROLEUM CO. Surveyed by F.M. LINDSEY I~ ASSOC. LAND E~ HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-08 Anchorage Alaska 5000 PSI DRILLING ! ! ANNULAR PREVENTER ]. J PIPE RAMS BLIND RAMS 1 1 KILL LIHE CHECK GATE GATE · DRILLING SPOOL PI PE RAMS I I 4"' CHOKE LINE GATE HYDR,- ASST. GATE o : RECEIVED D£C2 9 011 & 13 as Cons. Comml~ion 33 I i 0 0 OkJ December 18, '1980 l~lr. R. H. Rei ley District Drilling Engineer Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Re: Prudhoe Bay Unit MP (32-30-11-13) Sohio Alaska Petroleum Company Permit No. 80-151 Sur. Loc.: 2909'$~ 2195'WEL, Sec 30, TllN, R13E, UPM. Bottomhole Loc.: 1069'SNL, 1552'~L, Sec UPM. De ar Mr. Reiley: Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on ali logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by .the Federal Water Pollution Control Act, as amended. Prior to Mr. R. lt. Reiley -2- Prudhoe Bay Unit kip (32-30-11-13) December 18, 1980 c~ncing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant' to AS 38.40, Local Iiire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We WOuld also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is dri I led. In the event of suspension or abandonment, please give this office adequate advance notification so that we mat have a witness present. Very truly Tours, Enc I osure cc~ Department of Fish & Game, Habitat Section w]o encl. Department of Environmental Conservation Department of Laborl Supervisor, Labor Law Compliance Division w~o encl. HHH ~ b e SOHIO ALASKA PETROLEUM COMPANY December 17, 1980 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: MP Tract Well (32-30-11-13) Enclosed are the following documents, in triplicate, along with our check for $100.00 to cover the permit filing fee. 1. Application for Permit to Drill, 2. Proposed Drilling Program Outline, 3. Surveyor ' s plat showing well location, 4. Blowout Prevention Equipment and Diverter System Diagrams, 5. Pad map showing well course. RHR:ja Enclosures cc: Well File #17 Yours very truly, R. H. Reiley District Drilling Engineer RECEIVED DEC 1 7 1980 Naska Oil & Gas Cons. Commission Anchorage .% STATE OF ALASKA ALASKA O ')AND GAS CONSERVATION CO,, ")IlSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of well at surface 2909' SNT., 2195' W~EL, Sec. 30, TilN, Ri3E, UPM At top of proposed'producing interval 1350' SNL, i650' W~gL, Sec. 30, TllN, Ri3E, UPM At total depth i069' S1~%, 1552' WEL, Sec. 30, T~N, P~13E, UP~.'I 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. est. KBE = 73' A~LSL I ADL 28288 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number Safeco Ins. 2975387 13. Distance and direction from nearest town 14. Distance to nearest property or lease 13 mi. from. Deadhorse miles 3322' east of ADL 28264 16. Proposed depth (MD & TVD) 17. Number of acres in lease 10000lMD 96001r1~]~ feet 2491 19. If deviated (see 2~t ~AAC 25.050) 120. Anticipal ;sures KICK OFF POINT ,D00 feet. MAXIMUM HOLE ANGLE 23 Ol(see20 (c) (2) 21 9. Unit or lease name Prudhoe Bay it 10. Well number 11. Field )ool Bay Oil Pool Amount $200,000.00 15. Distance illing or completed 3000 .,feet January 1 , 1981 3330 Psig@ ...... Surface Proposed Casing, Liner ,g Program SIZE CASING AND LINER SETTING DEPTH Casing Weight Grade Coupling Length TOP TVD MD BOTTOM TVD 20" K-55 80 ' 72~ L-80 2700' L-80 9000 ' Surface 9000 ' I ~ I 7" L-SO S O0' 8220' 22. Describe proposed program: QUANTITY OF CEMENT (i ncl ude stage data) 2700' 3250 cu 87( 130 cu.ft. Arcticset 9600' 28'0 cu.ft. Class G wi' 18% salt See attached proposed drilling 'ram outline. RECEIVED DEC 1 7 1980 Naska 0il & Gas Oons. Commission Anchorage 23. I hereby SIGNED The space below for Commissio{ Jse Samples required Mud log required []YES ~NO []YES ~NO Permit number Approval date . correct to the best of my knowledge TITLEDiSt~ct Dr~ CONDITIONS OF ~~ Dire~ ~-'~'~ / SEE COVER L'~T~,~ FOR OTHER REQUIREMENTS ,COMM I SSI ON ER DATE by order of the Commission D~qember 18, 1980 Form 10-401 Rev. 7-1-80 Submit in triplicate PROPOSED DRILLING & CC~PLETION PROGRAM MP TRACT WELL (32-30-11-13) Dry bucket 26" hole to 80' below ground level and cement 20" conductor to surface using 8 cu.yds, concrete. Install diverter system and drill 17 1/2" hole to 2700'. Run open hole logs. Cement 13 3/8" 729 L-80 Buttress casing to surface using 4650 cu. ft. Arcticset II cement. Blowout Prevention Equipment consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer from 13 3/8" casingpoint to T.D. M2uximumpossible bottomhole pressure is 4390 psi at 8800' TVD ss (based on original reservoir pressure). Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVD ss and an oil column to 8800' TVD. Directionally drill 12 1/4" hole to 8700' TVD. Run 9~5/8'' 47# L-80 Buttress casing to 8700' TVD and cement first stage with 1250 cu.ft. Class G cement. 9 5/8" casing will be hung at surface. Drill 8 1/2" hole to T.D. at 9600' TVD. Cement 7" liner to 500' inside the 9 5/8" casing shoe with 380 cu.ft. Class..G cement with 18% salt. If well is~productive, the well will be suspended, 9 5/8"x 13 3/8" annUlus wiil'be cemented With 130 cu'ft, PermafroSt cement preceded by Arctic paCk through FO cementer at 2600'. Tubing and production packer assembly will be run to 8200' TVD. A subsurface safety valve with dual control lines will be placed at 2080'. Displace tubing to diesel. Install and test Xmas tree. Suspend for perforating subsequent to rig release. Details of proposed perforations to be submitted on Sundry Notice to follow. If unproductive, well will be plugged and abandoned. DEC 1 ? 19 0 Alaska Oil & Gas Cons, Commission Anchorage I I II I II I I I I II II IIIIIII I IIIIIII II I 26 I I 24 19 25 I 3~ PROPOSED I _ ~'MP TRACT WELL I (3;?-30-11-13) I LAT. = 70° 16' 40.78 LONG. 148°55'55.84 I X = 631,984 31 I Y: 5,952,391 I 1 - I I I I I ' I I I I I I I T. lIN. T. ION. SCALE: I"= IMILE CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered to- practice land surveying in the State of Alaska and that this plat' re presents a location survey of the wellpad shown and the well thereon. This survey was made by me or under my supervision and all dimensions and other details are correct. Bottom hole locations are furnished by others, Dote SURVI~YOR REVISED PROPOSED SUR. LOC. REVISED PROPOSED BHL , RECEIVED DEC 1 ? 1980 Alaska Oil & Gas Cons. Commission Anchorage DHO PJR 5/80 12/~/8o PROPOSED MP TRACT WELL (3g-$0-11-15) Located in S E I/4 PROTRACTED SEC. 301T II Nt R 13 E, UM!AT MERIDIAN, AK. Surveyed for SOHIO ALASKA PETROLEUM CO. Surveyed by F M. LINDSEY I~ ASSOC. LAND t~ HYDROGRAPHIC SURVEYO'RS :>502 West Northern Lights Boulevard Box 4-081 Anchorage Alaska f-- FLOWLINE DRILLING RISER GROUND LEVEL 10-3/4" HYDRAULIC CONTROL BUTTERFLy. Io ;' 12" MAX. RECEIVED DEC 1 7 1980 Rlaska Oil & Bas ~ ~ommlssion 20" 2000 PSI WP ANNULAR PREVENTOR DRILLING 'SPOOL 20" CONDUCTOR PIPE 3O DIVERTER SYSTEM DETAIL DRILL. DEPT. MARCH 19 NOTE: DIVERTER LINE HAS TWO DIRECTION DIS~ CAPABILITY AFTER RIG SUB-BASES. i I ~ )/8" TRIPLE ' RAM - 5000 PSI WP . - , ;. DRILLING ANNULAR PREVENTER . 1 PIPE ,1 BLIND RAMS ' ] .I 2:'. KILL LINE · CH ECl( GATE- GATE -o DRILLING sPOOL -1 I PIPE RAMS . 1 .1_ CHOKE LINE. HAND GATE HYDR. AS'ST. GATE RECEIVED DEC 1 ? Alaska Oil & Gas Cons. Commissio~ Anchorage t CHECK LIST FOR NEW WELL PERMITS Item Approve Date (1) Fee /~/~ .~-t7.~ (2) ~Loc. ?~. (3) k~in. ~~-- ;~l?-Fu / Yes 1. Is the permit fee attached .......................................... 2. Is w~ll to be located in a defined pool ............................. 3. Is a registered survey plat attached ................................ 4. Is well located proper distance frcm property line .................. No 5. Is well located proper distance frcm other wells .................... ~ 6. Is sufficient undedicated acreage available in this pool ............ ~ ... 7. Is well to be deviated .............................................. ~ 8. Is operator the only affected party ....................... · .......... ¢&4~ 9. Can permit be approved before ten-day wait .......................... ¢~_ 10. Does operator have a bond in force .................................. ~~ / 11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... . ....~ 13. Is conductor string provided ........................................ ~ 14. Is enough cement used to circulate on conductor and surface ........ ~ . 15. Will c~uent tie in surface and intermediate or production strings ...~ 16. Will cement cover all known productive horizons ..................... ~ Lease & Well No../~j ~ (5) BOPE ~~ 17. Will surface casing protect fresh water zones ....................... 18. Will all casing give adequate safety in collapse, tension and burst. 19. Does BOPE have sufficient pressure rating - Test to ~-~O~ ~ psig . Approval Recaumended: Additional Requirement: co~/J /~,~ ~~-~ ~ 3~) -f{-~'~ ~,-/{~ ~ ~ .S~,'~_ ~-_~/~. ¢~',~. Geology: Engine~ring: rev: 03/05/80 CHECK LIST FOR NEW %~LL PERMITS Item Aplorove (1) Fee (2) Loc. Date Yes /_ ~ ~.,,,~,,f,, 1. Is the permit fee attached ~e ...... ~ ............................. 2 Is ~11 to l~ locat~], in a fined ol ...... 3. Is a registered survey plat attached ............................... 4. Is ~11 located proper distance f_r'cm property line .................. 5. Is ~11 located proper distance frcm other ~lls .................... sufficient undedicated acreage available in this pool ............ 6. Is 7. Is ~11 to be deviated .............................................. ~z · No (4) Casg .~~ (5)BOPE ~~.~. Additional Requirements:, 8. Is operator the only affected party ................................. 9. Can permit be approved before ten-day wait .......................... ~ .. 10. Does operator have a bond in force .................................. 11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... 13. Is conductor string provided ........................................ 14. Is enough cement used to circulate on conductor and surface ........ 15. Will cement tie in surface and intermediate or production strings . .~~~ 'k~16 Will cement cover all known productive horizons ............. ...... · · nec BoPE have sufficient pressure rating - Test to ~-Oc~62) psig ..~ ' ~Approval Reccnm'~ended Lease & Well No. £J~:/~. Remarks Geology: Eng '~znger~i~g: rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding inl~ormation, information of this nature is accumulated at the end of the file under APPEN. DIXi .. No special'effort has been made to chronologically organize this category of information. ,o GGGG H ~ G H G HHHH G GG, H G G H GGG H H 1 i111 Illi 11 11 11 11 11 11 11 ~.1111~ ~111! 66666 66666 6 6 66 66 66 66 'b6666 66666 000000 7777777777 000000' 7777777777 00 : O0 :: O0 0 : : O0 :: O0 77 77 77 77 77 77 77 77 , ' :00 7 7 77 =~00 00 : 77 7'/ 44 :::,::555555 5555 000000 44 4 ~' 555'55555:55 0 O0000 ~,. 55 ~ : 00 00 ' ~ '~ 55 00 00 44 : 555555' 00 0000 ~+~ 555555 00 0000 4444444444 55 00 00 00 i : 55~: 00 00 00 44 :~': .55 , 0000 00 55 ~ 0000 00 44 55 ~55 00 00 55 55 00 00 000000 000000 ~BBBB PPPP RRRR O U DDDD -H H OO0 ~EEEE · P P R ' R ' U O O ' D''H H 0 O B ..... P P 1R R 'O U :D. D ~;H H 0 0 E BBBBB PPPP RRRR U U D D' ' HHHHH 0 0 EEEE BB BB P "R L{ U D D.-H HO 0 EE P R R U U D 'D "H' HO 0 BBBB P EEEEE *START* USER PCAL [10707,614'50] JOB SHIP sEO.' R634-DATE il-MAR-81 09:51:48 NUNIT[]R SWS KL10E40 NOV-@0. *START, . . ,START* USER PCAL [10707,61450] JOB SHIp SEQ. 2634 DATE 11-MAR-81 09:51:48 MONIT(]R SWS KL10E40 NOV-80. *START* YV,_ VV VV V¥ 'V¥ VV VV VV VV V V VV VV VV VV VV VV VV VV VV VV vVV VV V vv vv VV 00000 00000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 OO O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 O000oO EEEEEEEEEE RRRRRRRR IIIIII FFFFFFFFFF ¥¥ EEEEEEEEEE RRRRRRRR IIIIII ~ FFFFFFFFFF ¥¥ EE RR RR I 1 FF Y ¥ EE RR RR II · ~FF Y¥ EE RR .II EE RR I I ' FF EEEEEEEE RRRRRRRR II i FFFF'FFFF EEEEEEEE RRRRRRRR I I ~ FFFFFFFF · EE RR RR ~I FF' ' EE R RR I IFF EE RR RR I'I ~ FF · EEEEEEEEEE R 000000 00000 O0 O0 22 O0 O0 22 00 0000 22 O0 0000 22 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 0000 0000 000000 2222222222 · . . - 000000 222222-2222 ' - !- YY YY YY Y¥ YY Y¥ YY YY YY Y¥ YY YY YY YY YY ,START* USER PCAL [107OT'61450]T*JOB'R SHIP SEQ..2634 DATE 11-MAR-81 09151:48 MONITOR SWS KL10E40 NOV 80. *STA :~ ' ~ FILE= DS~H:VERIFY.002<057>[10707.61450] CREA~ED. 11 MAR~ 81 09.48.23 PRINTED: ii'MAR-81 09:5~110 = QUEUE SWITCHES: /FILE:FORT /COPIES{1 - - ~ /SPACING:I /LIMIT:90 /FOR'MS:NO~MAL ' ~ SCHLUMBERGE~ COMPUTING CENTER 10707,61450 REEL HEADER LENGTh: 132 BYTES REEL NAME: ~.C.A.L. SERVICE NAME. EDIT REEL CONTINUATION NUMBER: O! PREVIOUS.REEL NAME: COMMENTS: LiS FORMAT CUSTOMER TAPE DATE: 8I/ 2/I4 TAPE HEADER LENGTH: 32 BYTES TAPE NAME:! 61406 DATE: 81./ 7/14 SERVICE NAME: EDIT TAPE CONTINUATION'NUMBER'. 0! REVIOU$.TAPE NAME: OMMENTS: TAPE COMMENTS RUNS 1,2 & ]/06-FEB-81/CAS DRL 9.63" $ 10195~/CAS LOG II200'/BIT S1ZE ~,500"/PLUID TYPE LO SOLIDS DISP/DENS IO.O0/V-ISC 38.00/PH 9.500/FLUID I,OS~ 3.000ML/RM 1.55 ~ 81DF/RRF 1'42 ~ 81DF/RMC 1'92'~ 8lDO/MAX TEMP [72D~. E {] F ~" ILE H~.;A DER ],ENGTH: 62 BYTES FILE NAME: EDIT .001 . MAXIMUM PHYSICAL RECORD LENGTH. PREVIOUS FILE NAME: 1024 BYTES WELL SITE INFORMATION RECORD LENGTH: 207 BYTES COMPANY: WELL: FIELD: RANGE: TOWN: SECT1UN: COUNTY: STATE: SOHIO' ALASKA PETROLEUM CO. MP TRACT WELL (22-]1-1~-13) PRUDHOE BAY 13E 11N ORTH SLOPE ALASKA DATA FORMAT SPECI~ICATION LENGTH: 650 BYTES ENTRY BLOC~ ~. TYPE SIZE REP CODE ENTRY . 0 I 66 0 DATUM ENTRY SPECIFICATION BLOCKS: IC TOOL SVORD'# UNITS API AP1 API API FILE# $I'ZE EXP DEPT SP D1L ILD DIL ILM DILL SFLU Di GR DIL GR CNL CALl CNL DRHO CNL NPHI CNL RHOB CNL NRAT CNL NC NL CNL FCNL CNL GR BHC DT BHC FT 0 0 0 ' 0 ~ 0 4' 0 OH~M 7 12 44 ~0 0 4 9 OHMS, 7 22 I ,, 0 4 GAPt - ? 31- 32 O- 0 4 0 GAPI 42 31 32 0 · ~:0 4 0 GIN 42 28 1 0 : O 4 0 /C3 42 '44 0 ~' O 0 4 0 PU 42 68 2 0 0 - 4 . 0 PS 42 ]4 9 CPS: ~ 42 34' 93 ...-0 GAPI ~ 60 31 32 0 US/F 60 52 3.2. ~ O 0 4 0 PROC SA REP 0 1 68 0 1 68 0 1 68 0 1 68 0 I 68 0 I 68 0 1 68 0 ! 68 0 I 68 0 1 68 0 I 68 0 I 68 0 1 68 0 1 68 0 I 65 0 I 68 DEPT 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SH1F DEPTH }1.236.000 11200.000 11100.OO0 11000.000 10900.000 !0800.000 10700,000 ..10600.000 105O0.0OO 10400.000 1O30O.OOO MNEMONIC VALUE MNEMONIC VALUE MNEMONIC VALUE - 13 8 .ooo - 2.752 NPHI FCNL 84.313 GR 158.-500 CALJ, 9.070 22.852 RHOB 2~631 ~ NRAI 2.588 939.000 GR · '84.313 : DT 81.000 SP GR PHI CNL SP -53.281 ILD 3.824 -- I'LM 4.594 NPHI' 17'77] RHOB 2,'680 NRAT 2.229 z 5.ooo . SP 10.570 ILD 5.496 iLM 5 520 GR 96'250~ GR 96,000 CALl 10~297 FCN!L :19,775 · RHOB 2,53! NRAT 2,484 1003.0'00 GR ' 96,250 DT 79.000 SP '52.81~ ILD 1.O76 i iLM 2,207 GR 18,109 GR 24,O31 CALl 8,828 NPHI 19,531 RHOB 2,277= ~ NRAT 2.346 FCNL 1444.000 GR 18,109 DT 86,000 ,078 GR I 8,750 PHI 18,408 :RHOB - 2,40.6 -~ NRAT 2,264 C'NL 1583;O00 GR 2]'078 DT 78,563 SP -62.438 · ILD : 1.972 ~ ' ILM 2.100 GR 2.4,906 GR 30,203 :~ CAL~ 8,773 NPHI 20.117 RHOB ' 2,285 NRAT 2.383 FCNL 1485,000. GR 24,906 ~ DT 88,188 . . . $.45 5. R 46.906~ GR : 53.656 CALI 8'898 NPHI 22,607 RHOB 2.453 NRAT 2,561 FCNL 1249,000 GR 461906 DT . 91.000 SP -44,594 ' ILD 12,406~ : IbM 11,273 ~Li 8,703 NRAT 2.621 FCNL 1260,000 GR ,219 DT 96 188 ' · NPHI NRAT 2,094 FCNL DT~ 76,56] MNEMONIC SFLU DRHO NCNb SFLU DRHO NCNb ,5FLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNL SFLU DRH.O NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNL SFLU DRHO NCNb VALUE ].617 0.051 2154.000 3,596 0.164 2448.000 7.941 0.010 3806.000 16,250 0,092 4268.000 3.971 0.061 2822.000 5.102 0.000 ]558.000 6,805 0,029 3832,000 4.348 0,004 3598,000 4.598 0.017 2998,000 11.836 0,027 34b0.000 16.422 0.020 2944.000 DEPTH 1~0200,000 10100,000 10000.000 9900,000 9800.000 9700.000 q600.O00 9500.000 9400.000 9300,000 9200,000 MNEMONIC VALUE. MNEMONIC VALUE MNEMONIC VALUE ~ · GSP 13,555 ILD 1,.407 IbM 436 1, ~ ~.~?.~8G~ i~?.~:~s ~ c~L~ ~-9~ P"I 35-791 RHOB 2,4t4 _ s~ .l~-~' .~L~ ~.4~o z~ ~ooo.ooo . SP -39,438 ILD 9,203 ~ .I~N 2000,000 GR 57,625 GR 63~281 CAL~ 8,898 NPHI 47.754- RBOB- 2.184 NRAT 4.2~1 FCNL 3~9.5'00 GR 57'625 DX 73.56] SP ILM' ~. 484 ' 3.50'4 108.750 2.744 15.391 PHI 21. 729 ~ RROB 2.527 NRAT 2.770 c,L ~4'.~oo ~ ~l,~i'~ ~ ~.~.~ PHi 19.'0~3 R~OB ' 2,559 NRAT' 2.613 FCNL 977-000 -GR ~ 67.438 ~ DT 87.375 . _ ~ .% . SP -26.417 - ILD 1.387 .: ILM 1.452 GP 93.688 GR - 100'i 8-7-5 ~ CALl 15.570 3.918 113.375 sp '8.406 - ~-' ~,349 ~ z~ 1.439 GR 113.875 .GR.. 112:.563 CALl- 18.250 NPHI 36.230 RHOB '2~402 NRAT 3.807 F'CNL 494-000 GR 97.125 - DT 112.188 ~C -13.240ILD 1.378 IL~ ~.472 93.313 GR 91.688 CAni lt' 758 3,822 108,750 SP '20'.092 ILD 2' 84-4- ILN 2,936 FCNL 953,000 GR 64,438 DT 93,000 . P '19,250 iLD 2-340 : IbM 2,441 R- 94.063 GR 79.063 ~ ' CALk 16.]44 ,-Al~ 2. 732 ' 92,000 . MNEMONIC SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNL SFLU DRHU NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFDU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb r~ VALUE 1.781 0.087 2108.000 0.236 -0.543 1499.000 0.378 -0.507 1426.000 1.665 0.019 1903.000 2.533 0.099 2582.000 3.063 0.121 2682.000 1.706 0.011 1785.000 1.581 0.055 1882.000 1.701 0.010 1760.000 2.588 0.034 2970.000 2.271 0.027 2798.000 DEPTH .9100.000 9000,000 ~900.000 8800,000 8700.000 8600.000 8500.000 8400.O00 8300.000 8200.000 8100.000 MNEMONIC VALUE NNEM .IN lC VALUE MNEMONIC SP -20 073 GR 96 -" 688 GR NPH! 33.008 RHOB FCNL 5!2.000 GR VALUE SP -19.760 ILD GR 106.688 GR NPHI 34.131 RHOB FCNL 465.750 GR MNEMONIC P -16.573 ILD R 100.000 GR PH! 3].984 ~OB CNb 508.750 (~ VALUE A 146 IbM 1.226 SFLU 1.178 9 ~688 CALl 15.703 DRHO 0.048 2.48:4 NRAT 3.527 NCNb 1986.000 84,625 DT 109.750 0.965 ILM 10~.688 CNAL! .352 RAT 91.]13 DT ?..50 CALl 625 D SP -18.573 ILD 1.40{ GR 94.063 GR 91.813 NPHI 35.645 RHOB 2.338 FCNL 481-750 GR 89.625 IbM CALl NRAT DT SP - 406 PH I 37.109 CNL 457.250 1.038 16.578 3.623 118.000 ILD GR RHOB GR SP '30.604 ILD R 86.813 GR PHI 30'713' RHOB FCNb 597.000 GR 1.209 15.766 11~ '592 .375 SP NPHI FCNL 1.471 15.289 3.689 114.375 1.173 15.008 3.777 113.563 1 10 : ILM 457 : N~AT ,o : 88 SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNL SFLU DRHO NCNL 2.455 IbM 2.475 SFLU 85.063 CALl 13.969 DRHO 2- .475 NRAT 3.334 NCNb 81.063 DT 100.563 1.850 16.500 3.852 111.750 1.665 15.867 3.555 116.563 4.012 12 .563 1.807 = 89~563 : CAL'I 408 : NRAT -31.4t7 ILD 98.813 GR 37 646- R OB FCNb 457.500 GR 90.813 DT . 9 IbD 1 5 CALl PHi '40 039 RHOB 2.365 - NRAT 'CNL 406:750 GE 180.000 DT 2.236 14.813 4.148 12.2.375 SP -32.125 ILD 2.139 ILM GR 2~:3. 750 GR 21~ 250 CALI NPHI 2,871 RHOB '::318 ~:' 'NRAT FCNL 413.750 GR 213.125 DT SFLU DRHO NCNb SFLU DRHO NCNb SFbU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SP '39.8'13 ILD 2. 928 IbM 2. 893 GR 139.750 GR 1391375 CALI 15.141 NPHi 32.129 EH 400 'NRAT 3. 453 FCNL 552,000 GR 750 DT 113.375 1.042 0.027 1767.000 1.254 0.033 1844.000 1.448 0.037 1911.000 1.293 0.061 1757.000 2.941 0.106 2122.000 1.81] 0.037 1911.000 1.746 0.046 1830.000 1765.000 2.820 0.022 1752.000 3.410 0.030 1981.000 DEPTH 8000.000 7900.000 7800.000 7700.000 7600.000 7500.000 7400.000 7~00,000 7200.000 71o0.ooo 700O.OOO ~NEMONIC VALUE MNEMONIC VALUE MNEMONIC VALUE SP -27.625 ILD GR 126.750 GR HPHI 3.4,473 RHOB FCNL 540,000 GR 2.813 1bM 2.893 120.375 CALl 14.492 422 - NRAT 3.592 !I "375 DT 107.750 . SP -25.771 ILD I .548 IbM 1.641 GR 196,875 GR 18~ 250_ CALl 14.64i NPHi 39. 404 RHOB z~ 307 NRAT 3. 918 P'CNL 523.000. GR 184.375 DT 118.563 SP -23,646 ILD 1,344 GR 178.500 GR I60-750 : CALl NPHI 35-449 RHOB 2 357 NRAT FCNL 522.000 GR 148'.250 DT SP GR NPHI FCNL -22.81.3 ILD 1.778 ILM 176,125 GR 167.750 CALl 33.447 RHOB 2.316 : NRAT 510,750 GE 156,000 DT $IP -27 438 ILD GR 1011063 GR NPHI 29 150 RHOB FCNL 671 ~500 GR 375 ~ CALl 414 NRAT OT SP -29.292 ILO GR 92,063 GR NPHI 27.686 RHOB FCNL 761.500 GR 1.415 14.781 3.662 115.750 NPHI FCNL 1.762 14.883 3.535 116.188 2.248 15.3t6 3.266 98.000 2.506 ILM 2.537 8~!188 CALl 15,172 383 NRAT 3.I66 79 063 DT 97.000 -30.583 IhD 7~ 250 ~ .lng 84.563 GR :250 CALI 22 949 .RHOB 2 324 NRAT 979;000 GR 78'~688 DT 4.281 14.148 .820 8 750 . SP -26.833 ILD GR 90.750 GR NPHI 30.322 ~ RHOB FCNL 673.500 GR MNEMONIC SFLU DRHO NCNb SP -27 438 I. LD GR 85~563 GR NPH! 29 .102 R~O~ FCNL 679~500 GR SFLU DRHO NCNb SP -26,I67 ILD GR 96,813 GR NPHI 29.053 RHOB FCNL 673.500 GR SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNL SFLU DRHO NCNb SFhU DRHO NCNL 9 :188 NCAL1 15.242 DRHO 361 RAT 3.340 NCNb 862 . 141 .250 CALl 385 NRAT 752:438 DT 2.156 ~5.414 3.264 101.000 SFLU DRHO NCNb 2.385 IbM 2.400 SFLU 87.938 CALl 15.523 DRHU 2,432 NRAT 3.266 NCNL 82,563 DT 101.000 2.7O9 15.813 93.338 9 . 750 SP -27 792 iLD 2 750 GR 89."688 GR 88:938 NPHI 30 029 RHOB ~.4.26 87:5oo SFLU DRHO NCNb VALUE 2.951 0.025 2062.000 2.0bl 0.015 1987.000 1.861 -0.005 1959.000 1.800 -0.000 1901.000 2.174 0.017 2358.000 2.395 0.011 2510.000 4.082 0.010 2936.000 2.426 0.025 2298.000 2.082 0.015 2300.000 2.326 0.046 2278.000 2.615 0.044 2422.000 DEPTH 6900.000 6800.000 6700.000 6600.000 6500.000 6400.000 6300.000 6200.00O 6100.000 6000.000 5900.000 MNEMONIC R PHI CNL SP VALUE MNEMONIC VALUE MNEMONIC VALUE -31.500. · 1Lb 4.563 = IbM 4.309 88,875 GR ~ 79.500 CALl 15.031 31.348 RHO'B 2.389- - 'NRAT 3.400 709.~66 GR 83.813 - DT 94.563 -29.667 ' ILD" 3'28I !~ ILM 3.232 OR 108.188 GR ~' 105.938 ~ CALl 16.7)4 NPHI 28~467 ~HOB - 2.449 ~ NRA'T 3.258 FCNL 677.000 GR 86'.i88~ DT 97.188 . P -36.958 ILD 3.:738 -'= ibm 3.699 R 90.066 GR - 92'688 CALl 16.250 NPRI 24.805 RHOB :2..465 ,~ NRAT 3.000 FCNL 842.906 GR 91'~000 DT 98.563 SP PHI FCNL SP -3~.292 ILD 4.5.16 ~ ibm ~4.363 GR 9z,OO0~ ~R 91't25 CALl 1,-391 ' 3 NPHI 27.637 RHOB 2.459 .: NRAI .221 FCNL 703.500 GR '801375 ' DT 100.563 SP GR NPHI FCNL P -39 3.852 R 88 16.797 SP -40,958- ILD 3.707 i ILM 3.582 16.672 GR 3.176 NPHI FCNL 82~.-500 100.000 - 8 SP 4..333 . ILD 5.910 ~ IbM 5.520 GR 90i7~6' GR : 81,750 ;:CALI 16.156 NP.HI .31.738 BHOB. 2.428 NRAT 3.457 FCNL 579.060 GR 65'5OODT 97.563 SP 7.082 R 70.438 . GR 74.063 ~. CAL~ 15.859 'PHI ' 27;1~8 RHOB 2.406 ~ NRA2 3.146 fCNL 730.000 GR 72.438 DT 96.375 · R 59.004 GR 63.406· CALl 1)'602 NRAT 3.061 DT 93.188 . ~ MNEMONIC SFbU DRHO NCNb SFLU DRHO NCNL SFLU ORHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFbU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb VALUE 3.271 0.030 2580.000 3.432 0.077 2310.000 3.516 0.077 2578.000 4.11~ 0.041 2272.000 3.793 0.048 2420.000 3.209 0.031 2510.000 3.617 0.015 2934.000 3.213 0.019 2570.000 4.b33 0.050 2060.000 6.352 0.021 2386.000 10.203 0.054 2452.000 D-EFTH .5800,000 5700,000 5600.000 5500,000 5400,000 5300,000 5200,000 5100,000 5OOO,00O 4000,000 4800.000 MNEMONIC VALUE MNEMONIC SP -45,667 GR 87.063 NPHI 28,223 FCNL 709~500 SP -91,500 44 93~ SP -98.667 GR 41.094 NPH! 31,689 FCNL 719.500 SP GR NPHI FCNL VALUE MNEMONIC VALUE MNEMONIC GRILD 7~'250 IbM 4.~23 SFbU ,750 CALI 20. ]8 DRHO RHOB . 2,]791 NRAT 3,]54 NCNb 8 625 ~ DT 107 563 GR 7 . . ILD 2,473 IbM 3,i27 SFLU GR 40,156 ~- CALl 13,547 DRHO RHOB 2,193 NTRA 3.113 NCNB GR 48,719 DT 104,000 ~LD ,93~-~ ~ 2,387 SFGU R 4~ LM ALI 56 DRHO ,81 13, ] 2 2.05 NRAT 3.387 NCNb 4j':781 DT 103.563 -92,667 ILl) 2.615 42 813 GR 4~: 438 26;709 RHOB .~ :260 804,500 GR . 45-656 -104.08~ 46.96 ~FHI .]0,518 FCNL 785.500 LD R HOB R SP '55'I25 ILD GR 64,875 NPHI 27'246 RHOB FCNL 695,000 GR SP GR P~I ~CNL -67.000 ILD 50,656 GR 27,686 RHOB 692,000 GR SP -61.292 ILD GR 61.281 GR NPHI 30,176 RHOB FCNL 678,000 GR SP -84,000 ILD GR 47.31] . GR NPHI 31.348 RHOB FCNL 7i].500 GR SP -60.958 ILD GR 59,844 GR NPHI 32.471 RHOB FCNL 742,000 GR SP GR PHI CML .33.105 RHOB 652.0OO GR IbM 3.059 SFLU ~ ~AL~ 1~,734 DRHO RA .063 NCNb DT 96.000 ~,68! IbM 2,076 SFLU 4 ,969 -~ CALl 13,367 DRHO . ' :365 RA 3.150 NCNB 64,313 ~ DT 104,000 4,172 IbM 4,695 SFLU 47,906 ~ CALl 14.836 DRHO -2.391 NRAT 3,154 NCNb ,375 : DT 101,188 3.479 IbM 3,742 SFLU 60,219 .~ CALl 15,188 DRHO ,232 NRAT 3,328 NCNB 57,750 DT 110,375 3,O02 ILM 3.449 SFbU 46 .906 CALl 14,211 DRHO , ~05 NRAT 3.379 NCNB 5 ,53I DT 118.000 3,508 IbM 3.781 SFLU 50,969 CALl 15,188 DRHO -178 NRAT 3,479 NCNL 51,438 DT 118,000 72-3 1LM -- ,875 ~ DT 4,813 SFLU 15.95 3 DRHO 10 750 VAbUE 3.760 0,035 2496,000 8,961 -0,004 26]0,000 4,996 -0.010 2426.000 6.648 0,031 2528,000 7,738 0,015 2684,000 4,520 0.032 2324.000 5,711 -0.002 2220,000 4,813 0,014 2304.000 5,461 0.000 2460,000 3,686 -0.008 2600.000 3.836 0.012 2402,000 DEPTH 4700.000 4600,000 4500,000 4400,000 4300.000 4200.000 4100,000 4000.000 3900.000 3800,000 3700.000 MNEMONIC VALUE MNEMONIC SP -61.958 ILD GR 60.406 GR NPHI 30.957 RHOB FCNL 750.000 GR SP -58.667 ILD GR 62'625 GR NPHI 28'906 RHOB FCNL 739.000 GR SP -70.958 ILD GR 62'969 GR PMI 31 543 . RHOB 'CNn 658 ~000 ' GR SP -53.833 VAL JE MNEMONIC 3.695 48.188 CA 526.1446 NRAT . 69 DT 5.09O 6~.875_ CAL .289 NRAI 66.688! DT 5~-373 .038 = CALI .71g 5.094 SP -71.333 ILD GR 55.56.3 GR NPHI 35.596 RHOB FCNL 521.500 GR P -74.833 ILD R 51.375 GR NPHI 29.2:97 RHOB FCNL 587.500 GR SP -58.OO0 iLD R 80.125 GR PHI 38,916 ~ RHOB FCNL 436.750 GR 9~.789~ ILM '625 CALX 8~,258 ~ NRAT i06'3 DT 3.037 IbM 5t,656 CALl 2;'131 NRAT 50.938 DT 3.686: ibm 48,531 :~ C'ALI 4~,1.52 ~. NRAT .OO0 ~ DT 7.867 IbM 77,438 CAb ~ 2.244 NRA~' D' 69.438 ~ P -53.458 ILD 6.523 : R 91,87'5 GR 77,938<~ CALl PHI 38.086. RHOB - : 2.266 ~ . NRAT CNL 370.750- - GR 7'71625 :' DT SP -60.292 ILD GR. 73.000 GR NPHI 33.83'8 RHOB FCNL 504.500 GR 7.824 6~:260 ' UR'AT 66.375 DT -79.167 33'313 NPHI 791 883 078 CAb VALUE 3.859 15.164 3.379 126.000 5,141 16,891 3.293 115,000 3.537 14,508 3,400 118,563 4.973 16,125 3.805 116,563 .164 I .227 4.051 119.750 3.191 14.711 3.670 136.750 4.~17 17. 31 3.318 122,188 6.887 17.82-8 3.969 117.375 5.820 21.844 4.020 129.375 8.313 16,109 3,592 116,563 8,961 14.711 3.682 152.500 MNEMONIC SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb VALUE 3.252 -0.000 2704.000 5.105 0.026 2554.000 5.520 0.008 2394.000 5.988 0.035 1780.000 5.b21 0.013 1631.000 3.799 0.001 2102.000 6.004 0.057 1913.000 7.016 0.042 1672.000 5.629 0.052 1846.000 7.820 0.026 1951.000 9.094 0.006 2052.000 DEPTH ,3600.000 3500.000 3400.000 3300.000 3200.000 3100o000 3000.000 2900.000 2800.000 2700.000 2600.000 MNEb!ON IC R NPHI FCNL VALUE VALUE -82,333 ILD 9,523 · ~LM 9.633 ~9.~I9 GR ' 45~906 CALl 14.016 33 057 BHOB 2-129 NRAT 3.486 5891500 GR ' 4].156-~ DT 137'125 SP -63.500 ILD ~ 8"750 :-. ILM 0.313 PHI 341619 RHOB 2-273 ' NRAT' ~[631 FCNL 497.750 GR 65,188 < DT 126.]75 ~P -79.792 ILD 9.992: ~ IbM 9.945 GR 57.563 GR 51-'531 = CALX 14.305 PHI 30.176 RHOB 2.135 ~= NRAT 3.305 c.~ ~6.ooo ~ ~,155 ~T ~9o.ooo PHI 35.5~9 RHOB 9,~34 NRAT 3.734 FCNL 497.250 GR - 76.000 DT 135.750 · SP -64.458 ILD 1Oo414 _ Ih.M 9.930 GR 66.813 ~R ' ~8.]13' CALX 14.547 NPHI 36.865 RHOB 2.295 NRAT ~ 748 FCNL 488,000 GR 64,188 DT 375 SP -62.333 ILD 6.367~i ILM 5.566 38.135 828 FCNL 473.5-00 GR 6],313 ' DT 126.375 P -65.000 1LD 10.289 ~ :IbM 10.305 R 69.375 GR 68~750 -'~ CALl I4.625 ~P.z 36.o33 .~.o~ 2.2~8 ~A~ 3.697 rC~L ~75.060 ~ 63'.]t3 ~ PT 126.000 Sp .55.16'? ILD '-6.918 ;~ I5~' 6.121 OR 72.500 GR 72.875~. ·CALl 1~.656 ~c.~ ~44.~o ~ .~.o~ o~ ~.~oo · . -59.~5 ~D 6.590 ~ ~M · 156 ~ 69.75'~ GR ?0,~50 C~ 1,'438 N~I 42.48O a~OS · 2.215 ~ N~ 4.2~5 FCNL 317-$50 G~ 60.594 DT ~43.500 sP -72.583 ~SD 4.695-I ~L~ 4.707 R 64.375 GR 59.000 CALl 15,289 PHI 45~6~8 RHOB 2'049 ~ NRAT 4.301 FCNL 327.750 GR 55.719 DT 148.375 l 5.592 SP -62 500 .I [999.250 GR 60 281 FCNL'999 144.125 /_~ ? - MNEMONIC SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFbU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCN~ VALUE 9.852 0.009 2043.000 8.320 0.020 1746.000 11.070 -0.008 1896.000 8.023 0.015 1920.000 9.063 0.033 1952.000 0.305 0.01{ 1946.000 9.828 0.021 1857.000 5.395 0.040 1455.000 6.891 0.020 1349.000 5.367 0.017 1527.000 5.483 -999.250 -999.250 DEPTH .2500,000 2400.000 2300.000 2200.000 2100.000 2000.000 1.900.000 1800.000 1700.000 1600.000 1500.000 MNEMONIC VALUE MNEMONIC VALUE MNEMONIC VALUE · GP ~x.~8~ GR -99~'.250 CALl -999.250 ~PHI -999 ,250 FCNL -999~ ,875 SP -{14.500 iLD : ].590 ibM . 3,656 GR 33,125 . GR 999,25'0 ~ CALl : 999,250 NPH! -999.~50 '~HOB -999'250 - NRAT -999.250 FCNL -999.250 GR 33.125 DT 150.719 . SP GR Np. -999.250 a. OB -999.2 0 - -999.250 SP -119.000 ~ILD 12'504: IbM 11,875 NPHI FCNL -113.0OO ILD . ~0.O39 ~ IbM . 9.844 45j938 GR 999i250 CALI 999.250 -999.250 RHOB -999.250 : NRAT -999.250 -999.250 GR 45~938 DT 136.875 SP -283.250 ILD .114.375 - IbM . 69.094 GR 35.256 GR 909'250 CALl 999.250 PHI 999.250 RHOB -999.250 NR~? -999.250 FCNL -999.250 OR 35~2'50 '-' DT 96.359 SP -259,750 ILD '128,484 ~! IbM . 80,703 GR 37,0~0 OR .999-250 CALl .999,250 NPHI-9992250 ~HOB 9992250 NRAT 999.250 SP -165.625 1LD 1876.750 !LM_ .168.8.44 GE ~1'.978 GR -999.250 ' CALl 999.250 NPHI -999.250 RHOB -999-.250 .NRAT -999.250 FCNL -999~250 GR 21.578 DT 69.031 SP -148.875 ILD 72'344. IbM 49.594 OR . 53,063 · GR ]999.250 CALl -999.250 NPHI 9~250 RHOB ,99912~0 ~ NRAT -999.250 FCNL -999.~56 GR 53.063 DT 114.875 SP M . 1~6.766 G~ 1 -999.250 NPHI -999 NRA~ 999.250 FCNL -999 DT 87.219 ·. MNEMONIC SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFbU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb VADUE 3.862 -999.250 -999.250 4.017 -999.250 -999.250 12.584 -999.250 -999.25O 10.805 -999.250 -999.250 11.b99 -999.250 -999.250 152.313 -999.250 -999.25O 211.438 -999.250 -999.250 129.875 -999.250 -999.250 697.500 -999.250 -999.250 56.523 -999.250 -999.250 630.875 -999.250 -999.250 SU~IMARY OF DATA RECORDS 'NUMBEI{ OF ~{ECORD$: 1486 LENGTH Of' RECORDS: 966 BYTES LENGTH OF' LAST RECORD: 390 BYTES [~ ILE T}~AILER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAX]MUM PHYSICAL RECORD LENGTH: NEXT ~']LE NAME: 1024 BYTES TAPE TRAILER LENGTH: 132 BYTES TAPE NAME: 61406 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O1 NEXT TAPE NAME: Cf]MM~NTS: DATE: 81/ 2/14 111 000000 7777777777:1 ~' ' '000000 ....7777777777. 11 006600:~:'' 777:7-77'7777- ::-000000 777777 7777 1111 O0 O0 77 O0 O0 77 1111 O0 O0 O0 · O0 77 11 O0 0000 77 O0 0000 77 11 O0 0000 . 77 O0 ' 0000 ~ 77 1! 00 00 00 177 00 00 00 77 I1 O0 00.00 ' = '77 !i'~O O0 O0 77 1 0000 O0 77 0000 O0 77 1 0000 O0 ~ ' 77: 000000 77 11 O0 O0 77 O0 O0 ? 7 il O0 O0 77 O0 O0 77 111111 1111.11 - 666666 11 44 44 666666 333333 666666 il : 44 ~ :44 -::!66.6666 ' 333333 66 1111 44: 44 66 33 33 66 ~i1i !,.'' 44- . 44 66 33 :33 66 33 66 33 66666666 33 66666-666 33 66 66 11 44 66 66 33 66 66 1! 66 · 33 66 66 11 44 66 66 33 33 66 616 - 44 ~ ~66 66 33 33 666666 111111 44 666666 333333 666666 : ij111I 44- -'6:66666 333333 GGGG H H BBBB PPPP RRRR U O DDDD H H 000 EEEEE G H H B B :P: : P R : R U U D D fl:. H 0 . 0 E GG H ,H B B P P R R U U D D H H 0 0 E HHHHH BBBB '-'~- PPPP' - RRRR- U . U -_D- D HHBHH -O O EEEE G GGG H H B~ B P R R U O D D H H 0 0 E G G H ~ ~ B P' R R- : U U : D ~ H:: H O O E GGG H H BBBB P R R OUUUU DDDD H H OOO EEEEE *START* USER PCAL [I0707,61463] JOB: : SHIP SEQ. '4348 DATE 29'MAR-8! 10:08:43 MUNiTi]R SWS KLIOE40 NOV-80. *START* ,614631 JOB SHIP SE(}. 43-48 DATE 29 . R 81 10:08:43 *STARt- USER PCAh { 107.07 : ' { ,ii ' :" ' ' 'MA $~ ' · DEPTH 300.000 200.000 100.000 96.000 ~P -411o250 ILD .152.000 ~ ihM . 54.922 GR 50;031 GR 999.250' CALl 999.250 ~c~ -g~'~o ~n' ~o-o~ u~ ~o~.~g GR 25.516 OR ~-999.250 ~ CA5i -999.250 NPHI -999'250- RHOB '999,250 NRAT '999.250 FCNL '999.250 OR 25.516 · DT. 69.969 · ~P -~v~.ooo iUD. ~-000.000 I~ R 1@.32~ OR ' '99922§0 ~ · C~I,l -999.250 ~PH! ~992.250 RHOB. .' - 999,250 ~ NRAT'999.250 BP '999"250 ILD 1250'188 ~ IbM -249.420 GR -9 99.250:. GR · 999.250 ~: CALl -999.250 . NPHI -999.250 RHOB -999,'250 -~ NRAT '999.250 ~"C NL -999.250 ~ OR -999.250 DT -735.289 -. . .J ~ · . · . i ' . i : '. ' . _ , ~ - - '' i ' . - .~ ' ' - ~ ' TJ ! _ MNEMONIC SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFGU DRHO NCNb VALUE 320.250 -999.25O -999.250 600.375 -999.250 -999.250 0.760 -999.250 -999.250 -249.171 -999.250 -999.250 DEPTH .~400.000 1300.000 1200.000 ~100.000 1000.000 900.000 800.000 700.000 600,000 500.000 400,000 MNEMONIC VALUE SP -172.62 GR SP -224.625 GR 22.281 NPHI -999.250 FCNL -999.250 MNEMONIC VALUE - MNEMONIC VALUE . I LD 210.719 iLM 52.141 R -9991250 ~ CALI -999.250 PHI -999.250 RHOB -999.250 NRAT -999.250 CML '9991250 GR 26.938" DT 84.]28 SP -277.000 ILD GR 24.063 GR -999.250 CALl· -999. NPHI '999.250 R'HOB' -999'250 ' NRAT '999.25050 2 ~CNL -999.250 GR 24.063 ~ DT 79.563 - 3 - ~ 26.125 GR =999.250 : CALl :999.250 N PHI 999.250 · -RHOB . 999.250-.' · NRAT 999.250 FCNL '999. 250 G~ 26:'X25 DT 87. * 19 sP - 9o.5oo 7 s.ooo' l i.s 4 GR . 19.609 GR '999.250-: CALl '999.29 5O NPHI '999.250 RHOB '999.250 - NRAT -9991250 FCNL '999.250 GR 19.609 DT 7].859 25.094 GR ''999;250 : CALi 99~-250 NPH. I 2999 250 RHOB -999.250 NRAT -999.250 FCNL '999]250 GR 25'094 : DT' 76.297 ILD 140'.453 : IBM 93.891 GR -999.250 CALl -999.250 RHOB '999"250 NRA'T '999.250 GR 22.281_ < DT 89.656 · SP -317.000 ILD SP -309.750 iLD 2000.000 - ~LM 211.031 GR 21.938 ~ GR -999;250 CALI -999.250 N - PHI 999.250 RHOB 999.250 RAT 999.250 FCNL-999.'250 G~ 21.938 DT 70.125 sp -]44.o.oo 66 ' oo 4a.4o6 ~H 38.594 GR -999.250 ~ CAL~ -999.250 I '999.25'0 RHOB '999~250 NRAT '999.250 FCNB -999.250 GR 38.594 DT 98.125 SP -385.000 IL . .157.250 GR 24.922 GR I 999.250 NPH ~ NRAT '999.250 FCN ~ DT 72.156 · ~ MNEMONIC SFBU DRHO NCNB SFLU DRHO NCNB Sf, LU DRHO NCNB SFBU DRHO NCNB SFBU DRHO NCNB SFLU DRHO NCNB SFLU DRHO NCNB SFBU DRHO NCNB SFBU DRHO NCNB SFLU DRHO NCNB SFLU DRHO NCNb VALUE 934.375 -999.250 -999.250 405.125 -999.250 -999.250 579.688 -999.250 -999.250 847.500 -999.250 -999.250 475.4~8 -999.250 -999.250 367.000 -999.250 -999.250 115.906 -999.250 -999.250 102.891 -999.250 -999.250 ~06~.000 99 .250 -999.250 262.438 -999.250 -999.250 1341.500 -999.250 -999.250 _ SU~4MAR~ OF DATA RECORDS 'NI1HBEI~ OF RECORDS! 167B LENGTH QF ~ECORDS: <)66 BYTES LENGTH ('}F [JAST RECORD: 726 BYTES FILE TRAILER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM P~YSICAL RECORD LENGTH: NEXT FILE NAME: 1024BYTES EOF TAPE TRAILER I~ENGTH: 132 Y~ES TAPE NAME: 61345 SERVI~; NAME: EDIT TAPE ONTINUgTION NUMBER: Ol NEXT TAPE NAME: C/)MMENTS: DA.E. 81/ 3/.4 DE?TE 300.000 200.000 !00.000 IO0.O00 MNEMONIC VALUE MNEMONIC VALUE MNEMONIC VALUE aP 14 343 ILD 15 M 100.000 GR 29:96! GR 79.887 CALI :999.250 DRHO -999°250 NPHI -999.250 NRAT ,,~999i250- :NCNL '999.250 : .~'CNL -999.250 POTA -999.250 1.IRA -999.250 THO -999.250 ' _ _ 6P 39 424 ILD 33.729 ILM 112.720 GR 30:716 . G~ 130~O55 .~ DT . 72.042 CALI :999.250 DRHO :999.250 NPHi :999.250 NRAT ,,,,,,,9:99~250 NCNL .........999i250 FCNL ,999.250 POTA -999.250 URA -999.250 TH~ -999.250 SP 230.049 1LD 162754.780 . ILM 0.643 GR 19-981 GR :2I~56-5DT 200.'912 CALl :99 250 POTA -999.250 230. CAn~ :999.250 NRAT ,,, 999. 250 POTA -999.250 URA -999.250 THO -999.250 ~, :. . ~- 0.643 200.9~2 D~HE] :999.250 NPH1 :999.250 NCNL ,~,,,99~250 : FCNL ,999.250 LIRA .250 MNEMON IC SFLU GR RH(3B GR SFLU GR RHOB GR SFLO GR RHOB GR SFL0 GR RH[)B GR VALUE 390.841 -999.250 -999.~50 -999.250 ~43.558 -999.250 -999.250 -999.250 0.643 -999.250 -999.250 -999.250 0.643 -999.250 -999.250 -999.250 DEPTH 1.200.0oo 1100.000 1000.000 900.000 800.000 700,000 600.000 500.000 400,000 MNEMONIC VALUE MNEMONIC VALUE MNEMONIC VALUE SP -42.192 ILD 31.333 iLM 93.756 GR 27~361 OR 8712'34- ~ DT 91.086 ALI DRHO -999.250 NPHI -999.250 ~AT,999;250- NCNL:'999;'250 ~: FCNL -999.250 POTA -999.250 URA -999.250 THO -999.250 F' -3.687 iLD 31.333 ILM 58.614 ~R 28.70] GR 92-507 :~ DT 69.773 ~ALI 1999.250 DRHO 2999.250 . NPHI -999.250 RAT' , 999.250 -NCNL ,,,999i250 ~' ~CNL -999.250 POTA -999.250 URA -999.250 THO -999.~50 ' - ~ SP 56.544 ILD 27.797 ILM ]1.915 GR 26'858 GR ' 81-96I ! DT' 135.194 SP 6.2.756 ILD 20.324 1LM 29.648 GR 49;503 .. ' GR 68.939 ' DT 97.056 CNALI DRHO -990.250 NPHi -999.250 2999.~50 RAT ,,,,~999'250 NCNL '99-9i250- ~;~ ~CNb -9991250 POTA P 55.571 ILD 25.823 ILM 89.5~6 R 48~497 GR ' :-86.275 : DT 98. 980 CALl -999.250 DRH[) ' .999.~50 NPHi - .999.250 NRAT -9991250 -, NCNL '99912-50 FCNL -999.250 POTA -999.250 URA '-999.250 THO '999.250 GR CALI NRAT POTA P R 26.694 ILD 27.0~0 ILM 82.414 43.120 GR - 87-234 ~ DT 9.2.567 [999 250 DRHO [999.250 NPHi -999.250 ,,,',,99922~50~ ~NCN. b 2.99-9.~50'-~ rcN~ 2999.250 '999.250 URA 999.250 THO 099.250 -33.917' ILD ~1.333 ILM 199.526 34'155 GR ' -80'O44' ::DT · 70.907 SP 79.604 iLD 30.479 ILN 127.057 GR ]4.490 ' GR 94.025 : DT 79.940 CALI 1999.250 DRHO 1999.250 NPH! 2999.250 NRAT ~'999.250 NCNL ~",,'999-250 ~ ~:CNL "999.250 PQTA -999.250 ORA -999.250 THO -999.250 SP 136.018 ~LD 23.768 ILM 28.576 GR 27.948 GR I01,455 DT 73.720 CALINRAT 299,,,99~: 250 DR~O :999.250 NPHI -999.250 -999.250 POTA -999.250 ORa -999.250 /HO -999 250 MNEMONIC SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR VALU~ 253.513 -999.250 -999.250 -999.250 201.372 -999.250 -999.250 -999.250 96.383 -999.250 -999.250 -999.250 33.419 -999.250 -999.250 -999.250 92.045 -999.250 -999.250 -999.250 115.878 -999.250 -999.250 -999.250 432.514 -999.250 -999.250 -999.250 242.103 -999.250 -999.250 -999.25O 59.70~ -999.250 -999.250 -999.250 DEPT~ 2100.000 2000.000 lqO0.O00 1~00.000 1700.O00 1600.O00 ~.500.000 1400.000 ~300.000 MNEMONIC VALUE MNEMONIC VABt]E MNEMONIC VABUE SP -29.134 ILD 9.036 ILM 12.023 GR . 63-929 GH i .-64~;066 i:. DT 1~5.901 CALI 999.250 DRHO .999.250 NPHI -§99.250 NRAT '999,1250 NCNL "999~25'O ~- FCNL -999.250 PDTA -999.250 UBA -999.250 THO -999.250 P -23.859 ILD 26.~03 iLM 70.469 R 34'~9 GR 85~1716 DT 96.119 AL! i999.250 DRHO ~999.250 NPHI -999.250 ~RAT · ',,999~50 NCNL FCNL '99~.250 POTA -999.250 URA -999.250 THO -999.250 SP -20.803 ILD 21.281 ILM 48.753 GR 38'097 ~ i ~0~6..~ ~ D~: 95.033 CALI 1999.250 ORHO 1999.250 NPHI ~999.250 NRAT ,,,,999'250 NCNL ....... ~99i~50 ~ F~NL ,9'99'250 POTA -999.250 URn -999.250 THO -999.250 ~ _ - ~ ~ . H 42~542 'GR.I ?6'769 '~ D? 102.2 CA~I 2999.2~g ~HO . 2999.250 NPH! -999.250 NRAT ...,.999,25'. ON5 ~999~250 ' ~ FCNL ~999.250 POTA -999.250 URA 999.250 THO 99~.250 SP -26.691 ILD 27.290 ILM 118.032 GR 28.871-GR.~ ~5~t6 ~-i DT. ~2.979 CALI -099.250 DRHO ~999.250 NPHI -999.250 NRAT -999,:250 ~-- NCNL~ '-.'999~250 ~:~-FCNL- -999.250 POTA -999.250 URA -999.250 THO -999.250 SP -35.098 ILD 20.512 ILM 42.855 GR 55,I2]. -GR '' 77~727 ':! DT 111.216 gALI 2999.250 D~HO 2999.250 NPHX -999.250 RA~ '"'999'250 ' ~.NCNB ~."'999,250 ~ PONh ' -~99.250 POTA -999.250 URA -999.250 THO -999.250 ' '~ -~-::--: '-' ~ " P -64.813 .. ILD 28.576 iL~ 67.298 R 32.~8-97· ~ GR ~ 88~:9~- - ~ D~~ · 83.390 ~ALI -9~.250 DR"O :999.250 NPHI 2999.250 RaT '9~a250. NCNL :'999~2'50 ~'CNL' .999.250 POTA P -88.039 ILD 27.040 ILM 63.680 R 3~974' - i GR ~ ~ 88~193'~ ~DT 82.502 ~A5I 2999 250 DRHO :999.250 · NPHI -~99.250 RAT ",,999:250- '~ NCNL-~ ......... 999~2§0-' '~:FCNL -~9.250 Pf)TA -999.250 ORA -999.250 THO -999.250 SP -86.378 ILD ~M 5.~.456 GR 30:38.1 : GR ~ 79.985 CALI -999 DRHO 250 NPHI ~999.250 NRAT -999 .... 999.250 POTA -999.250 ORA 9' ;0 THO -999.250 · · MNEMONIC SFbU GR RHOB GR SFLU RHUB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFbU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR VAbUL 10.471 -999.250 -999.250 -999.250 .111.686 -999.250 -999.25O -999.250 115.878 -999.250 -999.250 -999.250 85.507 -999.250 -999.250 -999.250 242.103 -999.250 -999.250 -999.250 40.926 -999.250 -999.250 -999.250 398.107 -999.250 -999.250 -999.250 ]88.799 -999.250 -999.250 -999.250 212.81,¢ -999.250 -999.250 -999.250 DEPTH 3000.000 2000.000 2800.000 2700.000 2600.000 2500.000 2400.000 2300.000 2200.000 MNEMONIC VALUE MNEMONIC VALtIE MNEMONIC VALUE SP '106.000 ILD 9.219 ILM 129'0473 GR 60~594 : GR-' 60-594 : DT .563 ALI 12.570 DRHO 0.000 NPHI 40.869 HAT '3'"957 -NCNL 1767~OO0. ~: FCNL 4'24.250 POTA '999.250 U A 999.250 IHO 999 250 P -109.250 ILL 7.0.82 ILM 6.891 R 67-625 GR 67-625 ' / DT 129.125 ALi 12.719 DRHO 0.021 NPHI 40.332 RAT 3~670 NCNL' !622'-OOO ' FCNL .458.500 POTA -999.250 URA 999.250 THO 999.250 POTA SP GR CALI NRAT -999.250 ORA -999.250 THO -999.250 ~ . ~ , ~. 2.038 1LD 4 1 ILM 5.546 ' 6~6-97 GR 143-582 2999.250 DRHO -999.250 NPHI -999.250 ..... 999 ' '"" ' ~ .250 · NCNL 999.250- FCNL -999.250 SP -49.877 ILL 3.192 ILM 3 G~ .753 46.400 ~. 87,634 -~ DT · .14~'597 CALl ~999.250 DRHO .999.250 NPHI 999.250 NRAT .........999,250 NCNL ,,..999.250 FCN~ -999,250 POTA SP -58.330 . !LD 3.436 ILM 3.908 'G~ 37.845 GR :-1t31837:' ~DT 14~.559 CALl -999.250 DRHO :999.250 NPHi :999.250 NRAT ~999.250~-.NCNL. '...999.250' ~FCNL .g991250 P(.ITA -999.250 URA -999.250 THO -999.250 SP GR CALl NRAT POTA ~P GR CALl NR-~T POTA -34.147 II, D 9.550 IbM 13.062 49.252 GR 8-3.399 ~ DT 141.559 1999.250 DRHO 1999.250 NPHI ~999.250 '9'99-250 NCNL ..... ~,99q~250 J FCNL ,,999.250 -999.250 URA -999.250 THO -999.250 MNEMONIC SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHO0 GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR VALUE 10.797 63.281 2.188 -999.250 9.445 60.438 2.260 -999.250 7.633 68.125 2.248 -999.250 5.277 00.719 .99~ '°82 .250 5.297 -999.250 -999.250 -999.250 3.945 -999.250 -999.250 -999.250 4.613 -999.250 -999.250 -999.250 1].552 -999.250 -999.250 -999.250 10.093 -999.250 -999.250 -999.250 DLPTH 3900.000 3800.000 '~700.000 3600.000 3500.000 3400.000 3300.000 3200.000 3100,000 MNEMONIC VALUE MNEMONIC VALUE MNEMONIC VALUE SP GR CALl NRAT POTA P R -100.250 {LD 5.504 ILM 5.422 59~500 · GR .591500 :~ DT I19.375 13,141 D~HO 0,031 NPHi 35,1.56 3'602' .NCNL 1930;000 > FCNL 504,250 -999.250 URA -999.250 THO -999 250 / · --. . -. ' -85,000 iLD 6,g22 ILM 6.379 6g~250. -GR -:6gi250 '< DT 121,563 -112 55 ,D ,g 8.836 116 '<188 POTA SP GR ALI RAT P 0 T A CALl NRAT POTA -999.250 URA -999.250 THO -999.250 :. :-: . 13.117 DRHO 0.016 NPHI 33. 594 3'602 -NCNb I917'000 : FCNL 511.750 -999.250 U~A -999.250 THO -999.250 -999.250 URA -999.250 THO -990,250 J : i ~ : - SP -131. 750 iLO I0. 328 ILM 9.844 GR 39,406 GR' t9.406 DT 124,375 CAL~, 12.38] DRHO 0.O4l NPHI 39.844 NRA~ ~ 3i887 : NCNL 1665;O00 FCNL 4331750 POTA -999.250 URA -999.250 THO - -999.250 · ~ SP -100.500 iLD 8. 038 ILM 8. 281 GR 69.563 GR ,69~563 DT 112.000 CALl 12.703 DRHO 0,025 NPHI 31.934 NRAT 3~.379 NCNL 1900'000 ~: .FCNL ' 518,000 POTA -999,250 URA -999,250 THO -999 250 ,5P -105.750 ILD 9.047 I~a 8.711 dR 65 i'O00 GR' 65'000 :. D~ 122.188 cghI 12. 352 DRHO 0.013 NPHi 38. 770 NRAT 3.'816 NCNL 1783.O00 i FCNL - 406.000 P()TA -999.250 ORA -999.250 THO -999.250 P -108.188. ILD 8.078 ILM 8. 477 R 62'844 GR 62.844 DT ~24.563 MNEMONIC SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFbU GR RHUB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR ~HOB GR SFLU GR RHOO GR VAbUE ~.844 69.750 2.258 -999.250 7.871 75.875 2.340 -999.250 7.957 53.781 2.348 -999.250 9.484 32.906 2.117 -999.250 9.141 68.938 2.275 -999.250 10.406 39.813 2.174 -999.250 9.6.~3 67.b88 2.324 -999.250 9.219 67.938 2.199 -999.250 9.898 64.500 2.203 -999.250 DEPTH ~.4800.000 ~700.000 4600.000 4500.000 4400.000 4~O0.nO0 47O0. 000 4100.000 4000.000 MNEMONIC SP -7 ' 4.500 IBD 4.409 IbM 4.094 GR 68'438 GR 68*438 ~ DT 104.563 CALf 15.258 DRHO 0.047 ~PHI 32.129 NRAT 3'461.' NCNL-'t798~000 ii ~CNL 462.000 POTA '999.250 ORA -999.250 TH[) -999.250 SP ALI 13.188 DR.HO 0,079 NPHI 32.666 RAT 3;438 - NCNB 2106-:O00 FCNL 584.000 POTA -999,250 URA -999.250 THO -999,250 SP -122,250 ILD 2,785 ILM 2 977 GR 40~'406 405406-~-DT - 113~000 CALl 14,633 DRHO .0.022 NPHI 41.113 NRAT 4;O51 NCNL' 1473iOOO < FCNL -323.500 POTA -999,250 ORA ~-999.250 THO 999.250 P -80,750 ILD 3.549 ILM ].574 R 61~750 GR 61i750 ~ DT 114.]75 CALl 1 ' ' ~P GR CALI I].453 DRHO 0.016 NPHI 59.229 NRAT. ~ 5ii80- ' NCNB 1262~'060. < FCNB 254.125 POTA -999.250 ORA -999.250 THO -999.250 CALI NRAT POTA P R CALl NRAT POTA SP CAbI NRAT POTA -88,750 ILD 4.094 ILM 4,055 67-000 - - GR ~ 67.000 : DT 116.375 12.523 DRHO 0.024 NPHI 35.303 3~596- : NCNL 1803,-000 :~ FCNL 487.000 -999,250 ORA -999,250 THO -999.250 -81,000 ILD 5.055 ILM 4.824 72'0.00 GR 72.0OO - - DT_ 116.188 12.742 DRHO 0.051 NPH1 ]6.768 3'695 NCNL 1690~OOO ~ FCNL 450.000 -999.250 URA -999'250 THO -999.250 -88.750 ILD 5.617 ILM 5.5]5 88'563: _ GR . 88~563 ~ DT 115.563 12.438 DRHO 0,072 NPHi 36.914 -]-697 NCNB 1772~000" FCNL 467.000 ~P GR CALl NRAT POTA -114.750 iLD 4.06] ILM 4.086 40;156 ' -GP' 402:156 ~DT 118.750 .965 .500 -999. 0 tiaa -999 0 THO -999.250 MNEMONIC SFLU GR RHOB GR SFI, U GR RHOB GR SFLU GR RHO8 GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR VALUE 4.984 74.56] 2,418 -999.250 4.660 41.906 2.197 -999.250 4.313 51.500 2.199 -999,250 3.479 b7.250 2.238 -999.250 6.539 51.375 1.b96 -999.250 5.95] 67.875 2.289 -999.250 4.996 79.500 2.391 -999.250 6.078 88.56] 2.387 -999.250 5.602 47.813 2.252 -999.250 DEPTH 5700.000 5600.000 5500.000 5400,000 5300.000 5200.000 5100.000 5000.000 4900.000 MNEMONIC i/gLUE S~ -59.969 ILD · 2.945 ILM 2.936 GR 7-7~56~ - GR 7~,563 DT 98.375 CAL~ 14.633 DRHO 0.036 NPH1 29.932 NRA~ 3'299 :NCNL 2406~OO0 FCNL 680.000 PQTA -999.250 URA -999.250 THO -999.250 SP -114.250 ILD 4.234 ILM 4.848 GR 58,3-I3 GR 518'31-3 - DT 9b.188 CALl 12.672 DRHO 0.014 NPHI 29.248 NRAT 3,150-- . NCNL: 2410-000 ~ .: FCNL 740.500 POTA -999.250 .250 SP GR ALI RAT P({TA SP GR CAI,! NPAT POTA -102.750 ILD 5.102 ILM 5.7]0 76.500- GR 76~5OO := DT 95.375 13.047 DRHO 0.057 NPHi 27.246 3.~170 NCNL 2460~OO0 ' FCNL 761,500 -999.250 URA -999.250 THO -999.250 -127.000 1LD 3.]34 ILM 3.77! 54'0-31 -GR 54~O31 ~ DT 99'563 12.977 DRHO 0.040 NPH! 31.006 3 ,3-24 NCNL. - 2522~O00 : ~ FCNL 738,500 BP -g6.500 ILD 3.762 ILM 3.861 GR ' 63il.25 · GR : 6311:25 : <~ D'T 98.375 CALl 14.500 DRHO 0.046 NPHI 27.100 NRAT 3~t74- NCNL 2278'000 FCNL 709.500 POTA -999.250 URA -999.250 THO -999.250 SP -110,000 ILD 2,271 ILM 2. ~75 G~ 67-188 ~GR 67'188' DT 98.000 1683i000 : FCN5' 541,500 POTA -999,250 URA -999,250 THO -999,250 .~ 'i - · R ~.918~ GR 79'938 ::DT 106.I88 POTA P R CALl NRAT POTA SP GR CALI NRAT POTA -999.250 URA -999.250 THO -999.250 -163.000 ILD 1 . ]57 ibm 1. 600 49'344 . GR. 49.]44 : DT 107.188 1~,773 :' .156 -999.250 URA -999.250 THO -999.250 -99. 000 ~liLD 2. 439 ILM 2. 670 58.469 GR 582'469 DT 104.750 I ]. 875 DRHO 0.050 NPHI 28.662 .":~ · I97 NCNL 1_985'000 FCNL 625. 000 .250 MNEMONIC SFLU GR RHOB SFLU GR RHOB GR SFLU GR RHOB GR SFLU RHOB GR SFLU GR RHOB G~ SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR VALUE 3.505 87.025 2.379 -999.250 8.000 66.125 2.]48 -999.250 6.113 73.000 2.469 -999.250 8.016 55.250 2.352 -999.250 4.422 09.125 2.447 -999.250 3.188 72.4]8 2.477 -999.250 3.578 80.250 2.412 -999.250 5.617 43.313 2.217 -999.250 3.906 60.406 2.406 -999.250 DEPTH -6600o000 6500.000 6400.000 6300.000 6200,000 6100.000 6000.000 5000.000 5800.000 MN~SOUZC VALUE ~P -47.375 GR 74,06~ CALl 1~.2.34 NRAT ,277 POTA -999.250 1.935 98 ' 375 URA ,999'250 TH[:] -999. 250 P -47.750 ILD 2.039 . IBM 2.133 R 85.1.25 GR 85,t25 ~ DT 96.375 CALl 1~ 039 DRHO 0.067 NPHI 29.150 NRAT ~230 - NCNB: 24281000'~ FCNL 739.000 POTA -999.250 P -49.719 ILD 1.957 IBM 2.102 }~. 82'500 GR 821'500 - . ~ DT . 96.563 CNALI 14.008 DRHO 0.043 NPHI 29. 297 RAT 3,242 NCNB: 2610.000 : FCNL 773.500 POTA -999.250' URA -999.250 TH[] -999.250 NRA' ~0:7~ PflTA -999.250 ORA -999.250 THO -999.250 - - - CALl 13 . 297 DRHO 0 . 025 NPH1 26 . 514 NRAT 3 ..035 NCNB 2790'000 FCNL 8'89.500 POTA -999.250 URA -999.250 THO -999.250 6P -58 000 ILD 2.543 IBM 2.605 GR 97!56] GR 97'563 DT 99.375 CNALI ~ 5. 156 DRHO 0. 009 NPHI 26. 807 RAT 2;926 NCNB. 23]0.000 ; FCNL 7'79.000 POTA -999.250 URA -999.250 THO -999.250 ~P -61 219 ILD 4.164 IBM 4.094 ,~,,~ 9I~125 GR' 911125 ~ DT 98.56] CALl NRAT POTA SP GI~ CALl NRAT P[ITA SP GR CALl NRAT POTA -66 000 ILD 4.641 IBM 4.555 81:938. GR 81.938 ~¢ DT 92.750 1~ 914 -999.250 URA -999.250 THO -999.250 . . : -58 969 ILD 2.637 IBM 2.689 69~]1] GR 69,31] ~ DT 10'0.563 14.859 DRHO . 0.014 NPHI 29.297 !3.424 NC'NB 24'04.000 -FCNL -682.500 -999.250 URA -999.250 THO 999.250 - -! ': - ' - /': u ' MNEMONIC SFLU GR RHOB GR SFbU GR RHOB GR SFLU GR RHO0 GR SFLU GR RHOB GR SFLU GR RHOB SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR VALUE 2.123 85.563 2.471 -999.250 2.521 89.56] 2.516 -999.250 2.932 90.000 2.459 -999.250 2.955 96.813 2.416 -999.250 6.492 77.063 2.]54 -999.250 3.238 109.188 2.430 -999.250 4.262 94.813 2.438 -999.250 5.645 83.8'75 2.559 -999.250 2.000 72.250 2..396 -999.250 DEPTH 7500.000 7~00.000 7]00.000 7200.000 7100.000 7000.000 6900.000 6800,000 6700.000 MNEMONIC SP GR CNALI POTA SP GR ~gLI RAT -50.250 IBP 1.998 IbM 2.063 156~625 . GR : ,:1:56~625.- DT 120. 188 14,672 DRHO 0,014 NPHI 40.771 4-00'8 NCNB 1732~:000 . FCNL 419.250 -999,250 URA -999,250 THO -999.250 POTA -999,250 URA -999.250 THO -999.250 P -56,~750 ILD 2.471 ILM 2.520 R I'37~500 GR- I]7~5OO. '~ DT 117.563 CALl 14.742 . DRHO .0,042 NPHi 36.963 NRAT ],-762 NCNB 1-758~O00 ~-FC'NL 443.500 POTA .250 1 ,~ ~ p~Hp -_O,906 N_PHI 49 70 CALl 13,492 DRHO 0.020 NPHI 32.324 NRAT 3-6'33 NCNB 2104'~O60 : : FCNh 577.500 POTA -999.250 IJRA -999,250 THO -999.250 SP -60.219 ILD 3.332 IBM 3.529 ~R 131.OO0 : :~ DT . ' 104.188 ALI 14,398 DRHO .0,042 NPHI 31.445 RAT 3.393- NCN~!--~'2'I-54.000 ~ FCNB 608.000 POTA -q 9 - - ..9 .250 URA . 999.250 _ THO 999.250 - · SP -44.750 iLD 1,738 ILM 1.796 GR "; 199,500 ' GR ~ 1-99-~_500 < DT 112.000 POTA -999.250 URA -999.250 THO -999.250 P -47,250 ILD 2.010 IBM 2.086 ~ 167'375 GR 167~75 ~ DT '109.750 CALl NRAT POTA SP GR RAT POTA GR CA-LI NRAT P(~TA 14.164 DRHO 0.027 NPHi 35.010 ]-547 'NC:NL t870iO00 FCNL 500.000 -999,250 URA -999.250 THO -999,250 -47 9 iLD I M 1.83~ D 99.188 14,289 DRHO 0,026 ~PHI 31.494 . 3&'393 ' NCNB i ~2246;000 -~ FCNL 598.000 .250 -47.969 ILD 2.305 IBM 2.361 80.813 . GR 80.813' ~ DT.' 93.375 1, DR} .611 .500 Ti -999.250 MNEMONIC SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RH[}B GR VALUE 2.369 178.750 2.338 -999.250 2.994 365.000 ' . 0 3.189 165.375 2.418 -999.250 3.293 103.125 2.455 -999.250 4.5]5 141.875 2.490 -999.250 2.438 197.750 2.455 -999.250 2.842 178.250 2.467 -999.250 1.967 94.438 2.451 -999.250 2.652 90.938 2.500 -999.250 DEPTH -8400.000 8300.000 8200.000 8100.000 8000.000 7900.000 7800.000 7700.000 7600.000 MNEMONIC SP CALl NF~AT POTA SP GR CALI NRAT POTA GR ALI RAT PDTA VALUE MNEMONIC -39,000 66-563 1~.953 '838 -999.250 · .ILD · - , GR NDI~HO CNL URA ILD GR DRHO NCNL URA -40 375 69 81 13 953 2~537 -999.250 -41.688 ILD 94,938 ' GR 1].391 DRHO .615 i .'NCNL -999..250 URA -999.250 MNEMONIC VALUE .5 98 IbM 2.793 6 .563 DT 92,188 : .~0 062 NPHI 24,072 2660::000 ~CNL 9'13. 000 -999.250 THO -999,250 8 .ooo 0.046 NPHI 18.799 9 .ooo rc. 1 8.ooo -999.250 THO -999.250 0 002 NP .691 546.500 THO ~999.250 ~ -42 000 ILD I 107 ILM ~.170 81:10-00 GR 8' ~00-0 :~ UT 11 .375 CALI 1~ 859 DRHO 0 021 , NPHI ]6.475 NRAT :' ~736 -'- NCNL 186-8~OOO : FCNL 496.000 POTA -999,250 URA -999,250 THO -999 250 P R CALl NRAT P[JTA P -40.000 ILD ~.217 i~M 1.284 R 88,125 : GR 8 .1'25 < D 109.750 CALl 1~ 383 DRHO 0 012 NPHI 34.912 NRAT-~641~ -~:NCNL 192]~O00~ FCNL .5:23.000 POTA -999,250 ORA -999 250 THO 99q.250 P -34.000 ILD 1.578 1LM 1.666 24 000 POTA -999,250 URA -999.250 THO -999.250 . . . . , -- _~ . -37,969 ILD 1.]5! ILM 1.40~ 100-750 GR 1-00~750 ~ DT 111.750 1~ 758 DRHO 0.049 NPHI 39.209 ·3: ~88]- ' NCNL 1813. O00 ~ FCNL 451.250 -999.250 URA -999.250 THO SP -47 000 ILD 2,654 ILM 2.725 GR 89~06] GR 89-0:63 i :' DT 91.000 CALI 14,492 DRHO 0,058 NPHI 22.852 NRAT 2'.865 NCNLi ' Y298'O00 ' = FCNL 803.000 PGTA -999.250 URA -999.250 TH{] -999 250 ~ : . ' -47.469 ILD 1 8 82'625' GR 82 SP CALl NRAT POTA -999,250 UPA -999.250 2.~31 107. O0 0.028 NPHI 35.~10 1843.OOO ~ !: FCNL 498. O0 -999.250 MNEMONIC SFLU GR ~HOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR VALUE 3.016 74.125 2.547 -999.250 3.184 75.375 2.518 -999.250 1.456 94,875 2.391 -999.250 1.321 97.625 . 406 -99 .250 1.518 93,000 2.393 -999.250 2.004 94.313 .4~5 -99 .250 1.559 106.625 2.443 -999.250 2.889 92,375 2.500 -999.250 2.344 96.250 2.424 -999.250 DEPTH 9300.000 9200.000 9100o000 O000.O00 MNEMONIC VALUE MNEMONIC VALUE MNEMONIC VALUE SP 41.531 ILD 8.852 . ILM 6.750 GR ~ 82.750 16-000 GR 4:16~000 ' DT CALI ~8,148 DRHO 0,009 NPHI 21.143 NRAT ~1398 ~NCNL 283-0~OO0 FCNL 943.500 POTA 0.0613 URA 37,781 THO 23.922 SP -55.0.3! ILD 10,000 ILM 9. 492 GR 60"438 ' GR - 60143.8 ' DT 82.188 ALI 8.680 DRHO 0..032 NPHI 14.648 RAT 2'006 NCNL:' ' 37:58iO00 : FCNL I744.000 POTA 0.006 [JI~A 4.148 TMO 4..398 R . .813 GR : 98i-813- DT' I18.750 SP -0.594 II,D 1.757 ILM 1.833 G~ 106'1.88 : GR t06.I88 DT · 112.000 CALI~ 10~.750 DRHO 0.120 NPHI ]7.891 NRA~ ~,,717 NCNL I756~000 FCNL 420.000 POTA ~NE~ONIC SFLU GR RHOB GR SFLU RHOB GR SFLU GR RHOO GR SFhU GR GR VALUE 9.844 336.250 2.482 73.875 12.852 60.438 2.350 27.266 1.959 106.438 2.279 74.000 2.6'12 117.438 2.285 75.563 8QO0.O00 ~800.000 8700.000 8600.000 8500.000 ~P -21,969 ILD ~.456 ILM 1,557 CALf 12.813 DRHO 0.038 NPHI 39,307 RAT 3'953 NCNL 1792:000 : ~CNL 420'000 Pf)TA -999.250 RA 999,250 THO 99 .250 . -- .. .~RT 3'031. ~CNB 2534'000 FCNB 780.500 - : : SP -29.719 ILD 2.~04 . Ih~ 2.213 GR 85;125 GR · :85-'~25 :.' DT 91.750 CALl I 3.758 DRHO 0.084 NPHI 23.730 NRAT' 3-076 NCNL 1894,:OO0 FCNL 599.000 POTA -999.250 URA -999,250 THO -999.250 . _ - . ' .. ~ SP GR CALI NRAT POTA CALI P[.~TA -q99.2 -29.234 IL0 1.150 ILM ~.258 1'05.250 GR : 105~!250' : DT ' 109.750 13.898 DRHO 0.048 NPHI .35.205 -568 : · NCNL 1777-000 ~ FCNL 510,250 THO -999.250 32. 1. 58 '9s, 75 50 ORA 9 lO -999.250 SFLU GR RHOB GR SFDU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR SFLU GR RHOB GR 2.590 120.188 2.480 -999.250 2.742 9].]75 2.492 -999.250 2.068 94.438 2.537 -999.250 1.631 106.938 . 436 -99 .250 1.733 102.813 2.428 -999.250 DLPTH ~0,136,000 10100.000 110000,000 9q00.000 9800.000 9700.000 9600.000 9500.000 9400,000 P CALI NRAT P [) T A SP CALl NRAT POTA P ALI RAT POTA SP GR CALI NRAT POTA SP GR T 81.750 5.656 DRHO 0.038 NPHi 31.982 2,963 .' NCNL . '24-40.000 ~: FCNL 761.500 0.042 URA 6.309 THO 6.926 2.621 81.750 5.656 DRHO 0.038 NPHI 31.982 21963 NCNL 2440~'000 '!- FCNL 76.1.500 0.042 6.309 THO 6.926 -12.1ql .. ~LD 4.961 . I. LM 4.875 99;~8-13 '' GR 99;813 ~ DT 77.563 .844 DRHO 0.199 NPHI 16.846 ~250 -:: NCNB 24821000.. ~! FCNL 1062;000 0.025 URA -0.788 THO 17 422 ~: . ~ ' _ :< : · 29;J578 GR : 29.578 DT 83'750 .500 DRHO -0,004 NPH1 19.238 ;301 NCNB -39'70~OOO :: FCNL 1634.000 0.007 URA 1.411 THO ] 039 ALI I 20.264 0.336 DRHO 0.0q4 NPHI RAT. 2 ~5-20 NCN.L 3116~OOO ~ FCNL 1159.000 PflTA 0.027 URA 6.199 TH[.) 9.719 SP -91.938 ILD 2.354 GE 31.-656 GR i~ . ~1';656 ~ DT: ' ' 85'656.563 2 ALi 8.422 DRHO '0.017 NPH1 19.4,4 RAT ~305 .- NCNL 3630'000 ~ FCNb !416.000 Pt)TA 0.005 ORA 0.173 THO 4.234 P -98.000 1LD 1.989 IBM 2.37] R 17,469 G~- : :1'7~469 c DT 77.188 CALI 7.867.' DRHO 0.103 . NPH1 18.604 NRAT 2,203 NCNL -- 4220'OOO FCNL. 17-24.000 P{..)TA 0.004 . BRA, 1.313 ~P -95.313 ILD !LM 1.965 GR 25'172 - '::'GR. : . 91.375 CALl NRAT POTA SP GR CALI NRA T POTA -93. ]75 ILD 9. ]67 IBM 10.70 ] 32-906 ' . GE 32,906' - ':-DT. 87.375 8.117 DRHO 0.124 NPHI 22.217 469 NCNL 2976;000-':::-FCNL 1074.000 0.0.01 [iRA 2,084 THO ~. 820 ~ . ~_ '. ] - - _ ~ __ .~ ' . . . MNEMONIC SFLU GR RHOB GR SFLU GR RHOB SFLU GR RHOB GR SFLU 'GR RHO0 GR SFLU GR RHOB G~ SFLU GR RHOB GR 8FLU GR RHOB GR SF'LU GR RHOB GR SFLU GR RHOB GR VALUE 2.957 143.875 1.87] 9].438 2.959 143.875 1.873 9].438 5.793 105.625 2.521 105.688 9.984 31.000 2.318 21.906 4.148 119.750 2.503 76.688 7.762 24.672 2.271 25.797 7.949 27.406 2.332 18.172 5.969 27.016 2.275 19.250 33.531 36.063 2.293 17.938 DATUM SPECIFICATION NAM'E TOOL UNIT AP1 API AP1 Ali FILE, SIZE SA REP PROCESS INDICATORS _ ! GAPI 60 31 32 0 0 4 l 68 U$/F 60 52 32 -0 0 -4 ~ I' 68 cG/C3 42 ]5 I 0 0 4 1 68 /C · 42 42 1 0 0 4 I 6-8 ' CPS 42 .34 92 0 0 4 1 . 68. CPS 42 ~4 9] ' 0- O ' 4 1' 6'8 GAPI ]! 31 32 0 0 4 . ~ 68 PCT 31 0 O ,' O' 0 4 t 68 PP~ PPM USER DEFINED OUTPOT ARRAY OUTPUT SP AT OUTPUT ILO AT OUTPUT ILM AT UTP!!T SFLIJ AT UTPI.IT GR AT OUTPUT GR A~ OUTPUT DT A. UTP[IT GR AT U'TPUT CALl AT (]UTPU~ DRHO AT OUTPUT NPHI AT OUTPUT ~HOB AT RA~ AT t4 OUTPUT OUTPUT NCNL OUTPUT FCNL ~TT . OUIPUT ,~ AT 17 OUTPUT POTA AT 18 OUTPUT URA AT 19 OUTPUT THO AT 20 2 4 5 9 10 11 · DATA FOPMAT SPECIFICATION LF~i~tGTFI: 8 ~10 BYTES Ei, NTR~ BLOCKS: TYPE SIZE REP CODE ENTRY - · . 0 1 66 BlT SIZE = 8.500 FLUID IN THE HOLE = XC POLYMER ~)E~s ~ lo.1 VISC = 40.00 PH 59 50 RM ~ M~;AS TEMP ~ 4 O1 $ 90 F ~M~ ~ " " ' = 3:90 9 64 F RMC " "' = 2.82 ~ 64 F , , , * , * , , , * * , , * * * * ~"ILE H[ADEIq LEN =.I H: 62 BYTES FILE NA~aE: EDIT .00t MAXIMUM PHYSICAL RECORD LENGTH: 1024 BYTES PREVIOUS FILE NAME: 1F'ILE COMMENTS WORDS 21'18,19'20 ARE F:~OM ?HE NGT TOOL. THIS IS h THREE RUN MERGE. COMPANY : SOHIO ALAS!qA PETRO, WELL : MP TRACT WELL FIEI.,D : PRUDHOE BAY COUNTY : N. SLDPE STATE : ALASKA DENSITY : 800' Ills VERSION I5,HOI ?9/03126 SCHLUMBERGER COMPUTING~CENTER 10707,61463 REEL t. tEADER I~ENGTM: 132 BYTES BER. O1 REEL CONTINUATION NUN PREVIOUS REEL NAME: COMMENTS: LIS FORMAT CUSTOME~ TAPE DATE: 81/ 3/ 4 TAPE HEADER LENGTH: TAPE NA SERVICE rAPE CO REVIOU C(-IMMENT TAPE OIL RU 112 BYTES ME: 61345 NAME: EDIT NTINUATION~NU~BER: 01 S TAPE NAME: S: COMMENTS N ~ 1, LOGGED 28-DEC-80 CASING DRILLER = 20.000 IN. ~ BIT SIZE = 17.500 IN. FLUID IN THE HOLE ~ FMG DENS = g,io VISC R~ @ MEAS TE~P : 200.0 ~ . - 6'71 @-52 F R~F " " : 5.67 @ 52 F RMC " "8.25 ~ 5~F RM @ ~HT : 4.20 @ 86 F DIL ~[.IN # 2, LOGGED 6-JAN-81 = ~3.370 IN. 8 9000 BIT SIZE : 12.250 IN. FLUID tN THE H[JLE : I,,OW SOLIDS DENS : 9.90 v sc PH = 9. ' FLUID LOSS : 6.60 ML RM @ MEAS TEI~P : 4.0.t 965 F RMF " " : 4 86 @ 65 F RMC " " : ]~30:'10' 65'F DIL RUN ~ ], LOGGED '9-JAN-81 CASING DRILLER C AS I N G,..D R ILLER DATE: 811 ]/ 4 !10 FT. FT. = 9.625 IN. ~ 10IO3 FT. YV ¥'¥ EEEEEEKEEE ~RR~R V~ V~ EEEEEEEEEE R~RRRRRR VV VV EE RR RR VV VV EE RR RR VV VV EEEEEEEE RRRRRRRR V¥ VV EEEEEEEE ~RRRRRRR V¥ VV EE RR RR VV VV EE ~ RR VV VV EE RR RR VV EEEEEEEEEE RR RR V~ EEEEEEEEEE ~ RR IIIII] I'I I II~ I II II II FFI~'FFFI~'FFF FFFFFFFFFF FF FFFt~'FFFF FFFFFFFF FF FF FF FF Y¥ YY YY YY YY YY YY YY YY YY YY ~Y YY Y~ YY YY YY YY YY 000000 000000 11 OOOO00 000000 ll O0 O0 00 O0 Illl O0 O0 O0 O0 I11~ O0 0o00 O0 0000 ll O0 0000 O0 0000 ll. O0 O0 O0 00 00 O0 !I O0 O0 O0 O0 O0 O0 II 0000 O0 0000 O0 0000 O0 0000 O0 O0 O0 O0 O0 11 O0 O0 O0 O0 11 000000 000000 1111 000000 000000 1111 11 1,1 *START* USE~LPCAL [10.707,61463] ,jOB SHIP SEO.. 4]48 DATE MONITOI~ SWS ~ !0E40INOV.,80. *STA'RT:' BILE: DSgH:¥ERIF~..001<057>[10777.6.146]] CREATED: 20-MAR-8! PRINTED: 29....MAR-81 ~-~01-09:]2 QUEUE SWITCHES: ./FILEIF~RI /COPIES:I /SPACING:I /LlMI~:149 /FOR~S:NORMAL 2g-MAR-81 10:05:40 10:08:4] SHIP PCCC VENT~}~A, SHIPPING INSTRUCTI(]NS iSSUED 4-MAR-8! 23:29 BY PAM PCCC CALIFORNIA lllltI PPPPPPP IIIIII PPPPPPPP II PP PP 1I PP PP II PP PP II PP PP II PPPPPPPP II PPPPPPPP Il PP II PP II PP II PP IIIIII PP IIIIII PP ,START* USER PCAL [10707,6146)] JOB SHIP FILE: DS[H:SHIP.TO<$~?>[I0707.614~:~I CPEATED: PRINTED: 2: MAR. 81 101.09115 QUEUE SWITCHES: /FILE:FORT /COPIE,.1 /SPACING:I /LIMIT:149 /FORMS:NORMAL SEO. 434~ DATE 2q-MAR-R1 2q-MAR-81 09:40:31 10:08:4]