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188-074
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) ~'Two-Sided RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: ~]IL~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is~ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN ~SHERYL MARIA LOWELL PAGES: 1~+ (at the time of scanning) SCANNED BY: BEVERLY BREN ~HERYL MARIA LOWELL ReScanned {done) RESCANNED BY: ~BREN. VINCENT SHERYL MARIA LOWELL Is~ General Notes or Comments. about this file: PAGES: ~:~/~ Quality Checked (done) RevlNOTScanned.wpd STATE OF ALASKA ALAS~IL AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEiVE® MAR 1 3 2008 Alaska Oii ~ Gas Cons. Commissi 1a. Well Status: ^ Oil ^ Gas ^ Plugged • ®Abandoned ^ Suspended zoAAC zs.,oe zoAAC ze.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions.... Zero 1b. Well Class: OCci~@ ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband.~ ~- -~~ 12. Permit to Drill Number 188-074 307-341 3. Address: c/o P.O. Box 196612, Anchorage, AK 99519-6612 6. Date Spudded . 3 a~~ "'~ 08/14/1988 13. API Number 50-029-21837-00-00 4a. Location of Well (Governmental Section): Surface: 745' FNL 1855' FWL SEC T 7. Date T.D. Reached 08/28/1988 14. Well Name and Number: 30-02 , , . 22, 13N, R09E, UM Top of Productive Horizon: 3274' FSL, 4156' FEL, SEC. 16, T13N, R09E, UM 8. KB (ft above MSL): 59' Ground (ft MSL): 15. Field /Pool(s): Kuparuk River Unit ! Kuparuk Total Depth: 3397' FSL, 43$6' FEL, SEC. 16, T13N, R09E, UM 9. Plug Back Depth (MD+TVD) 10308 6712 River Poo! 4b. Location of Weil (State Base Plane Coordinates, NAD 27); Surface: x- 525491 y- 6022072 'Zone- ASP4 10. Total Depth (MD+TVD) ~ 10420 6794 ~ 16. Property Designation: ADL 025513 _ TPI: x- 519459 y- 6026074 Zone- ASP4 Total Depth: x- 519228 y- 8026197 Zone- ASP4 11. SSSV Depth (MD+TVD) N!A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1700' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): D1L / FDC / CNL, SWC, CBL / GR, GYRO 22. CASING, LINER AND CEMENTING RECORD CASING 'SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP "BOTTOM - TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 115' Surface 1115' 24" 19 sx Arcticset II 9-518" 36# J-55 Surtace 5930' Surtace 4002' 12-1/4" 1400 sx AS Ill 400 sx Class 'G' To Job: 100 sx AS I 7" 26# J- 5 Surface 10392' Surface 6773' 8-1/2" 315 sx Class'G' 175 sx C I 23. Open to production or inject ion? ^ Yes ®No 24: Tuewc RECORD If Yes, list each interval open (MD+TVD of Top i;< Bottom; Perforation Size and Number): SIZE DEPTH .SET MD PACKER SET MD 3-1/2", 9.3#, J-55 9963' 9891' MD TVD MD TVD Z5. ACID, FR,4CTURE, CEMENT SQUEEZE, ETC. ~~~~6~ ~~~ ~ ~ 2U0~ ~ s ~ DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED 9t63~ ' ~ ) 10073' P&A w/ 16 Bbls Cement 9970' Pumped 2nd Plug of 11 Bbls Cement 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED Z4-HOUR RATE OIL-BBL: GAS-MCF: WATER-B6L: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No • Sidewal l Cores Ac wired? ®Yes - ^ No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. 3 None ~ D/'f~ z = %y. v ~3 ~~ti~l~jl"F~I} '1 ..GG,,CCyyAA-- ,. ~ Form 10-407 Revised 02/2007 ~ ~ ~ rq ~ ~~ r~NTINUED ON REVERSE SIDE ~~ 3~1~ ~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS A RKERS ENCOUNTERED): 29. FORMATION TESTS ' NAME TVD Well Test ^ Yes ®No Permafrost Top If yes, fist intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top Kuparuk C 10022' 6506' None Base Kuparuk C 10041' 6519' Top Kuparuk A 10043' 6520' Base Kuparuk A 10188' 6622' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work, Well Schematic Diagram 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. 3 Signed Terrie Hubble Title Drilling Technologist Date ~1 ~o~ ~ 30-02 188-074 307-341 Prepared By Name/Number. Tem`e Hubble, 564-4628 Well Number Drilling Engineer: Gary Eller, 529-1979 (Cell) Permit No. / A royal No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and fog on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion, Irem 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Irem 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 0212007 Submit Original Only • • Well 30-02 Events Summary Kuparuk River Unit Date Event 12/23/2007 PRE CTD, TIFL (PASSED), PT & DD- MV (PASSED), PT & DD- SV (PASSED), PT-WV (PASSED), DD- SSV (PASSED), POT & PPPOT-T PASSED. 2/5/2008 TAGGED AT 10120' SLM, EST. 10143' RKB. BRUSHED & FLUSHED SSSV. CLOSURE TESTED, GOOD. IN PROGRESS. 2/6/2008 PULLED GLVs FROM 3508', 6256', AND 7846' RKB. REPLACED WITH DVs. PULL DV FROM 9836' RKB. SET 2.75" C-A2 PLUG AT 9928' RKB. IN PROGRESS. 2/7/2008 LOADED WELL WITH 225 BBL INHIB SW AND DSL CAP. SSSV INITIALLY NOT TESTING. EXCERCISE AND FUNCTION TEST SSSV, APPEARS TO PASS CLOSURE TEST. IN PROGRESS. 2/8/2008 SET DV AT 9836' RKB. MIT'd TBG AND IA 2500 PSI, GOOD. PULLED 2.75" C-A2 PLUG FROM 9928' RKB. READY FOR CTU /CMT. 2112!2008 ,PUMPED 17 PPG CEMENT SQZ IN 7" LINER, TOTAL OF 16 BBLS CEMENT PUMPED. _~EST TOC 9963' CTMD WITH 10 -11 BBLS BEHIND PIPE, WELL LEFT SHUT IN WITH 700 PSIG WHP, DIESEL TO 4000' MD., READY FOR SLICKLINE TAG. 2/14/2008 TAG TOC C~ 10,004' SLM. MITT/CEMENT PLUG TO 2000 PSI, PASSED. JOB ~ 2/15/2008 Perform CMT Millout. Tagged CMT C~ 10031 CTMD, Corrected depth off TTL C~3 9953 CTMD, Undereamed to 10073 CTMD, 120 ft below TTL, Circ out clean S/W, Freeze protected well, Rtn in A.M. 2/16/2008 Pumped 11 bbls of 17 PPG cement in 7", Maintained 1 for 1 rtns throughout job, Jetted tubing out from TTL, Freeze protected Well, Left 500 psi WHP. 2117!2008 MIT TBG TO 2000 PSI (PASSED). DRIFT TBG W/ BL BRUSH TO 9890' SLM; UNABLE TO WORK ANY DEEPER. IN PROGRESS. f KRU 30-02 Producer Proposed A-sand CTD Completion Updated 3/11/2008 ~1 ~i~~~1~4~ ~ QC~C'~S$~ AL2-01 lateral (northern, upper) A2/3 Sand, TD @ 11,625' AL2 lateral (northern, lower) Al Sand, TD @ 11,630' 99:" surfacz casing shoe at 5930' 2'li' s{otted {finer top -9950' Cement ramp exit, top of cement 9970' MD A sand perts: 10,052' -10,148' ~ (plu99ed) ~_ - Aluminum billet @ 10,960' 7", 26 ppf, J-55 casing shoe at 10,392' • 3%i' TROP SSSV at 1787' • 3%", 9.3#, EUE Srd Mod tubing w! 3'/i' gas lift mandrels (six) • 3'/z" x 7" Baker RHS packer with PBR at 9891" • 2.75" D-nipple at 9928' • 3'/2" tubing tail at 9963' AL1 Lateral (western, upper) V~indownT'2E~tJ55casr~ A2f3 Sand, TD @ 13,200' @ 10,060' MD Aluminum billet t~ @ 10,225' ` ~ r, ~ ~ ~' „%i ~ ~~ ~ ~~ ~ ~~ ~ ~~ . i ..i .. '~ ~~ /~ „ii '' AL3 Lateral (western, upper) .,...::...~ ~ ;~ oo ii ~ o _;.. ~~ ~ ~ A2l3 Sand, TD @ 13,120' \, Aluminum billet @ 11,170' 'A' sidetrack (western, tower) A9 Sand, 7D ~ 13,180' • . Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E {DOA) Sent: Friday, February 22, 2008 3:47 PM To: Regg, James B (DOA) Subject: RE: KRU 30-02 (188-074) Perf Plugging Jim, I don't have anything new, however I looked at the sundry issued for the work. CPAI did intend to raise cement to the tubing tail at 9963'; however they then intended to drill through the cement establishing a "cement ramp" to exit the casing at about 10060'. The quad laterals they will be drilling are horizontally targeting the A sands presently accessed by the existing well. I do not believe there is a regulatory issue with the TOC given that the plan was to drill to 10060'. CPAI may have difficulties doing their well exit with only 27' of cement. Let me know if you need anything additional. From: Regg, James B (DOA) Sent: Friday, February 22, 2008 3:33 PM To: Maunder, Thomas E (DOA) Subject: KRU 30-02 Pert' Plugging John C. witnessed plug tag -his report is attached. They did not meet 20 AAC 25.112(c){1) requirements. Curious if you have any more info. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 ~~ DEB ~ ~ 2a~~ Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 2!24/2008 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~?{~lz ~-~zzi~v DATE: February 14, 2008 P. I. Supervisor ~~~ ~~~ ~~~~ ~ - b ~ l~ FROM: John Crisp, Petroleum Inspector SUBJECT: Cement Plug Tag Conoco/Phillips Kuparuk River Field 30-02 February 14, 2008: I traveled to Conoco/Phillips KRU to witness a perforation abandonment cement plug tag on 30-02. witnessed Haliburton Slick Line .RIH with no go muleshoe to X nipple @ 9928' to have data to correlate depths for cement plug tag. I witnessed Halliburton Slick Line RIH to a depth of 10,033' where hard cement `~ was confirmed. The top perforation for 30-02 is 10,052'. The cement abandonment plug top did not meet 20 AAC 25.112 (c) (1). Summary: I witness cement plug tag on KRU 30-02 that did not meet AOGCC regulations for perforation abandonment. Attachments: none Non-Confidential ~~;~ \ i Cj Cement plug tag for perforation abandonment 30-02 02-14-08 jc.doc STATE OF ALASKA ~ ~~/ ALASKA OIL AND GAS CONSERVATION COMM~ION ~d"~~ ~(~V ~ ~ ~a~~ ``3~ APPLICATION FOR SUNDRY APPROVAL ~~~ 20 AAC 25.280 AI8Sk8 011$ G85 00113. ~dfC11111S~;Yllflt>f 1. Type of Request: ®Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Pfug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number Conoco Phillips Alaska Inc. ®Development ^ Exploratory 188-074 3. Address: ^ Service ^ Stratigraphic 6. API Number: Go P.O. Box 196612, Anchorage, AK 99519-6612 50-029-21837-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 30-02 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft}: 11. Field /Pool(s): ADL 025513 ° 59' - Kuparuk River Unit /Kuparuk River Pool 12~ PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10420 ~ 6794 - 10308 6712 None 10185 Ca in Len th Si a MD TVD Burst Colla se Structural Conductor 115' 1 115' 115' Surface 5930' 9-5/8" 5930' 4002' 3520 2020 Intermediate Production 10392' 7" 10392' 773' 4 0 432 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Gralde: Tubing MD (ft): 10052' - 10148' 6529' - 6596' 3-1/2", 9.3# J-55 9963' Packers and SSSV Type: 3-1/2" x 7" Baker'RHS' packer Packers and SSSV MD (ft): 9891' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for Commencin O erations: January 2008 16. Well Sta s fter proposed work: p ^ Gas ^ Plugged f~Aband no ed 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby ify that the for going is true and correct to the best of my knowledge. Contact Gary Eller, 529-1979 (Cell) Printed Naiv1 Gary Eller Title CT Drilling Engineer ~- Prepared By Name/Number: Signature Phone 263-4172 Date ~~ ~ ~jj ( Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ..~ Conditions of approval: Notify Commission so that a representative may witness c~ 2~0~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~+b~~C.~' ~~5~ ~ L~ ~ -t~o~-~-G~ ~`'l y~C ~~++~,1~'C'- ~v Subsequent Form Required: ~O~ APPROVED BY ,L .,~L _ A roved B : MMISSIONER THE COMMISSION Date ~ "/^~(J~ Form 10-403 Revised 06/2006 V'w / ~-- Su it In Du licate ,. • • KRU 30-02 Quad Sidetrack/Laterals -Coiled Tubing Drilling Summary of Operations: A coiled tubing drilling rig will drill four sidetracks & laterals in well KRU 30-02 using the managed pressure drilling technique. These horizontal laterals will target Kuparuk A2/3 and Al sand reserves to access upswept and trapped oil. The perforations in the motherbore will be plugged with cement. 1. The A sidetrack will exit the motherbore at 10,060' MD and be a 3140' horizontal targeting the Al sand to the southwest. It will be completed with 23/8" slotted liner to a TD of 13,200' MD. 2. The ALl lateral will kick off from the A sidetrack at 10,300' MD targeting A2/3 Sands to the southwest. The AL1 lateral will be 2900' in length and will be completed with 23/s" slotted liner to a TD of 13,200' MD. 3. The AL2 lateral will kick off from the A sidetrack at 10,225' MD and will target Al Sand to the north. The AL2 lateral will be 1405' in length and will be completed with 23/s" slotted liner to a TD of 11,630' MD. 4. The final lateral, AL3, will kick off from the AL2 lateral at 10,960' MD and will target the A2/3 Sands to the north. The AL3 lateral will be 665' in length and will be completed with 23/8" slotted liner to a TD of 11,625' MD. Only the final drilled lateral will remain accessible throu h-tubing. ~s 9f but e/qlf k..'/~ Tiny it .~~ ~M ,1 n~o CTD Drill and Complete 30-02 program: January 2008 Gaf ~rAf y /'~/f~ ~~~c~ ~! Lsa4~' v~f~ oR ~ ~ispvrcrf iffl/~.~ Pre-Rig Work 1. Obtain updated static BHP on A sand. `~ ee/'frd q'~~va~ '~" cr~f~y ~~~ ~ 90 2. Test Packoffs - T & IC. YB ~ SpPIO ~, .~~tov~ /efvh' ~^ (~ 3. Positive pressure and drawdown tests on MV and SV. ~raaat~ ~~fr ,yN~/O,rc~ RtGVdy /~r'1 Y,. ~ 4. Drawdown test on SCSSV. 5. Slickline tag fill and drift 3'/z" tubing. (.t/'l~ Cv~-y/ jG7'~•c. /e e/' y, ~` d'~~~'`~ 6. Install dummy valves in GLMs ~~( 7. MIT-IA, MIT-OA. 8. Coil tubing plug existing A sand perfs with 17 ppg cement up to tubing tail at 9963' MD. 9. Slickline tag top of cement. ~.'~b1~~s o~ ~~r~~.~~ ~p ~~~~ Rig Work 1. 2. ~ ~~ ~'~-C-p^,~~ CS~ 4. 5. cyst ~S ~~ ~t1~3 MIRU Nordic Rig #2 using 2" coil tubing. NU 7-1/16" BOPE, test. Drill low-side pilot hole and cement ramp for exit at 10,060' MD. Mi112.74" window and 10' of open hole from 10,060' MD. 30-02A Sidetrack (Western Lower) a. Drill pilot and cement ramp for high-side exit at 10,060' MD. b. Mill 2.74" window with high-side orientation. The planned KOP is at 10,060' MD in the A sand. c. Dril13" bi-center horizontal `A' sidetrack southwest in the Al sand from the window to TD at 13,200' MD. d. Kill well. Run 23/8" slotted liner with aluminum billet from TD up to (10,300' MD. 30-02AL1 Lateral (Western Upper) a. Drill 3" bi-center horizontal AL1 lateral southwest in the A2/3 sand from 10,300' to TD at 13,200' MD. b. Kill well. Run 23/8" slotted liner with aluminum billet from TD up to f 10,225' MD. 30-02AL2 Lateral (Northern Lower) a. Drill 3" bi-center horizontal AL2 lateral north in the Al sand from 10,225' to TD at 11,630' MD. b. Kill well. Run 23/8" slotted liner with aluminum billet from TD up to f 10,960' MD. 30-02AL3 Lateral (Northern Upper) a. Drill 3" bi-center horizontal AL3 lateral north in the A2/3 sands from 10,960' to TD at 11,625' MD. b. Kill well. Run 2318" slotted liner with aluminum billet from TD up into the 3'/z" tubing tail at 9963' MD. 7. Freeze protect. ND BOPE. RDMO Nordic 2. Page 1 of 3 November 2, 2007, FINAL • KRU 30-02 Quad Sidetrack/Laterals -Coiled Tubing Drilling Post-12i~ Work 1. Run GLVs 2. Obtain static BHP 3. Produce well to sales. Mud Program: • Will use chloride-based Biozan brine (10.0 ppg) for milling operations, and chloride-based Flo-Pro mud 010.0 ppg) for drilling operations. Since there is an SCSSV installed in 30-02, we should not have to kill the well to deploy 23/8" slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1 R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 30-02A: 23/8", 4.6#, L-80, STL slotted liner from 10,300' MD to 13,200' MD • 30-02AL1: 23/8", 4.6#, L-80, STL slotted liner from 10,225' MD to 13,200' MD • 30-02AL2: 23/8", 4.6#, L-80, STL slotted liner from 10,960' MD to 11,630' MD • 30-02AL3: 23/8", 4.6#, L-80, STL slotted liner from 9960' MD to 11,625' MD Existing Casing/Liner Information Surface: 95/8", J-55, 36 ppf Burst 3520 psi; Collapse 2020 psi. Production: 7", J-55, 26 ppf Burst 4980 psi; Collapse 4320 psi Well Control: • Two well bore volumes 0180 bbl) of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4500 psi. Maximum otential surface pressure is 4335 psi assuming a gas gradient to surface and maximum potential formation pressure based on the highest pressure measured in offset injectors (i.e. 4995 psi in 3Q-15 in July 2006). • The annular preventer will be tested to 250 psi and 2500 psi. Directional• • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 30-02A: 10,600' to property line, 1400' to 3Q-16 at the toe • 30-02AL1: 10,600' to property line, 1400' to 3Q-16 at the toe • 30-02AL2: 9000' to property line, 1000' to 3R-19 at the toe • 30-02AL3: 9000' to property line, 1000' to 3R-19 at the toe Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Page 2 of 3 November 2, 2007, FINAL • KRU 30-02 Quad Sidetrack/Laterals -Coiled Tubing Drilling Hazards • Expect to encounter increased pressure in the western laterals, particularly beyond a fault that will be encountered at 11,500' MD. The static reservoir pressure in the 3Q-16 injection well which the western laterals are drilling towards is approximately 14.5 ppg EMW. • Lost circulation is a risk due to the likelihood of encountering increased formation pressure at major fault crossings, particularly in the western laterals. • We1130-02 has 145 ppm HzS as measured on 1/22/07. Wells 30-01 and 30-03 are adjacent to 30-02. 30-01 has 265 ppm HZS as measured on 1/22/07, and 30-03 has 140 ppm HZS as measured on 1/25/07. The maximum HZS level on the 30 pad is 265 ppm from we1130-01. All HZS monitoring equipment will be operational. Reservoir Pressure • The most recent static pressure measured in 30-02 is 3703 psi on 10/02/07 (i.e. 10.9 ppg EMW at 6567' TVD). Prior to that, the survey taken in January 2005 showed that reservoir pressure was 3006 psi (i.e. 8.8 ppg EMW). Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the 23/8" pipe/slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. There is a functional SCSSV in well 30-02, so the well should not have to be killed prior to running 23/8" slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Estimated reservoir pressure: 3703 psi at 10,101' MD (6562' TVD), or 10.9 ppg EMW. • Expected annular friction losses while circulating: 905 psi (assuming friction of 90 psi/1000 ft). • Planned mud density: 10.0 ppg equates to 3412 psi hydrostatic bottom hole pressure at 6562' TVD • While circulating 10.0 ppg fluid, bottom hole circulating pressure is estimated to be 4317 psi or 12.7 ppg EMW without holding any additional surface pressure. • When circulation is stopped, it is anticipated that 300 psi of additional surface pressure shall have to be applied to balance reservoir pressure. 905 psi of additional surface pressure must be held to maintain the same bottom hole pressure as during drilling operations. Page 3 of 3 November 2, 2007, FINAL • • ConocoPhillips Alaska, Inc. KRU 30-02 KRU 30-02 Producer Proposed A-sand CTD Completion Footage Drilled = 8110' Updated 11/2/2007 9~•" Surface casing shoe at 5930' 2'/a" slotted liner top -9950' ~ Cement ramp exit, top of cement -9970' MD AL3 lateral (northern, upper) A2/3 Sand, TD @ 11,625' A sand perfs: 10,052' - 10,148' ~ (plugged) AL2 lateral (northern, lower) \ Aluminum billet Al Sand, TD @ 11,630' @ 10,960' 7", 26 ppf, J-55 casing shoe at 10,392' • 3'/~' TRDP SSSV at 1787' • 3'/z', 9.3#, EUE 8rd Mod tubing w/ 3'/~' gas lift mandrels (six) • 3'/i' x 7" Baker RHS packer with PBR at 9891" • 2.75" D-nipple at 9928' • 3'/z" tubing tail at 9963' ~ VVinda~v in T' 261E J55 casing ~ I j @ 10,060' MD ~~ ~ Aluminum billet \~~~~ _ / ~ @ 10,225' 'A' sidetrack (western, upper) A2/3 Sand, TD @ 13,200' Aluminum billet @ 10,300' .. _~~ AL1 lateral (western, lower) Al Sand, TD @ 13,200' • • MEMORANDUM TO: Julie Heusser, Commissioner THRU: State of Alaska Alaska Oil and Gas Conservation Commission Tom Maunder, P. I. Supervisor DATE: FROM: Chuck Scheve; SUBJECT: Petroleum Inspector January 26, 2001 Safety Valve Tests Kuparuk River Unit 30 Pad Friday, January 26, 2001' ! traveled to the Kuparuk River Field and witnessed the 90-day retest of the safety valve systems on 30 Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Low pressure pilot on WAG injector 30-05 tripped below the required set point. This pilot was retested and passed at the the time of this test. Eamie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary: I witnessed the 90-day SVS testing at 30 Pad in the Kuparuk River Field. KRU 30 Pad, t2 wells, 24 components, 1 failure 4.1% failure rate 12 wellhouse inspections Attachment: SVS KRU 30 Pad 1-26-01 CS X Unclassified . Confidential (Unclassified if doc. Removed) SVS KRU 30 Pad 1-26-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator Rep: Earnie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: .Kupamk / KRU / 30 Separator psi: LPS 67 Date: 1/26/01 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI,. ps! . Trip . Code Code ..,Code .Passed ,..GAS .o.r cYc.ta~ 30-01 1880730 67 70 80: P P OIL 30-02 .... ISSb~)40 ' 6~/' '70 60 P P ....... OiL 30-03 1880750 ' '~7' ' '~0 60 P P ............. OiL 30-04 ' 1880620,' ' 67 70 "' 65' P 'P ....... 6ILl · , , 30-06 1880600! . 30-08 1880640i '67 70 '~ P' P", . ,."" , , '',' 'i3IL 30-09 188061 O: 67 70 40 P P OIL 30-11 ' '1880420' 67 70 " 60t' P' "P ....... OIL 36-13 1880400 "67! 70 60 ' P ' P ....... OIL 30-14 1880390,., ..... 30-15" ' 1880310 67~ 70 ,. , ,7..01. P ..... P OIL 30-18 ..... 18802~0 ' '6:7i 70 55 P' "P ..... ~)i'L 30-20 1970450 67! 70 60 P P OIL ... 30-05 1880760 3750 2000 '1100 3 ' P 1/26/01 WAG Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.17% [390 t)av Remarks: pilot 9n W6G, ig,)ec,to, r 30-05 tripped, below,required set pressure. ,.Pilot was r.et.e,.sted and passe,d this date. RJF 1/16/01 Page 1 ofl SVS KRU 30 Pad 1-26-01 CS.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 745' FNL, 1855' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 2029' FNL, 1115' FWL, Sec. 16, T13N, R9E, UM At effective depth 1939' FNL, 936' FWL, Sec. 16, T13N, R9E, UM At total depth 1899' FNL, 871' FWL, Sec. 16, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical I 0420 feet 6792 feet 6. Datum elevation (DF or KB) RKB 59 7. Unit or Property name Kuparuk River Unit 8. Well number 30-02 9. Permit number/approval number 88-74 10. APl number 50-029-21837-00 11. Field/Pool feet Plugs (measured) Kuparuk River Field/Oil Pool None Effective depth: measured 10308 feet true vertical 6709 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 80' 16" 5895' 9-5/8" 10359' 7" 199 Sx AS II 1 15' 1400 Sx AS III & 5930' 400 Sx Class G w/100 Sx AS I Top Job 315 Sx Class G 10392' 115' 4000' 6771' measured 10052' - 10068', 10072' - 10098', 10102' - 10148' true vertical 6528' - 6539', 6542' - 6560', 6563' - 6595' Tubing (size, grade, and measured depth) ~"~'i~ ~' ..:'- . 3.5", 9.3#/ft., J-55, EUE 8 RD, ABMOD, Tail @ 9963' Packers and SSSV (type and measured depth) Packer: AVA RHS @ 9891'; SSSV: Camco TRDP @ 1787' 13. Stimulation or cement squeeze summary Fracture Stimulate 'A' Sands on 9/3/96 ORIGINAL Intervals treated (measured) 10052' 10068', 10072' - 10098', 10102' - 10148' Treatment description including volumes used and final pressure Pumped 122 Mlbs of 20/40,12/18, & 10/14 ceramic proppant into formation, fp was 5800 psi 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3 5 3 1 6 6 219 1271 191 Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 1005 4 5 4 765 1300 193 16. status of well classification as: Oil X Gas Suspended Service 17. I he~y certify that the foregoing is true and correct to the best of my knowledge. (/ · ' Signed ~~F--'t~/~~~A..rr~ Title Wells Superintendent SUBMIT IN DUPLICATE STATE OF AI_ASKA AI_AoKA OIL AND GAS CONSERVATION COMMI~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ... Stimulate X Plugging Pull tubing Alter casing . Repair well .. Perforate Other 2. Name of Operator ARCO Alaska. Inc, 3. Address Po O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development * Exploratory .- Stratigraphic _ Service 4. Location of well at surface 745' FNL, 1855' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 2029' FNL, 1115' FWL, Sec. 16, T13N, R9E, UM At effective depth 1939' FNL, 936' FWL, Sec. 16, T13N, R9E, UM At total depth 1899' FNL, 871' FWL, Sec. 16, T13N, R9E, UM 12. Present well condition summary Total Depth: measured 1 0420' feet true vertical 6792' feet Plugs (measured) 6. Datum elevation (DF or KB) 59' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 30-02 9. Permit number/approval number ~0-74 10. APl number 50-029-21837 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured I 03 0 8' feet true vertical 6709' feet Casing Length Size Conductor 8 0' 1 6" Surface 58 95' 9 5/8" Production 1 0 3 5 9' 7" Junk (measured) Cemented Measured depth 199 Sx AS II 1 15' 1400 Sx AS III & 5930' 400 Sx Class G Top job w/100 Sx AS I 315 Sx Class G 1 0392' True vertical depth 115' 4000' 6771' Perforation depth: measured 10052'-10068', 10072'-10098' & 10102'-10148' true vertical 6528'-6539', 6542'-6560'& 6563'-6595' Tubing (size, grade, and measured depth) 3.5" 9.3# J-55, EUE 8 RD, ABMOD, Tail @ 9963' Packers and SSSV (type and measured depth) SSSV: Camco TRDP @ 1787', Packer: AVA RHS @ 9891' 13. Stimulation or cement squeeze summary 14. RECEIVED P B Gas Cons. C0~tSS't0~ 'Anchorage Intervals treated (measured) Perforated interval. Treatment description including volumes used and final pressure Refractured A Sand w/41.5 M LBS proppant & 928 BBL gelled sea water. Final pressure 8120 psi. Reoresentative Daily Average Production or Injev--tiorl Dat~, OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 892 292 -0- 1250 150 1589~557 24 1140 131 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Title Petroleum Engineer SUBMIT IN DUPLICATE WELL ~ONTRACTOR .,..~.. .., '~ - HEMARKS In(,~. WELL SERVICE REPORT ARCO Alaska, ~'~ Subsidiary of Atlantic Richfield Company . I~'''°'s'~'°' -'~~~ I°~'s, t z.j-~-~ RECEIVED S E P 2 8 '~992 I'-'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Alaska Oil & Gas Cons. CommiSSiOn ;Anchorage Wind Vel. knots REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES · ,~, ~:~."' Diesel ~ ~~ ~ ~p ' ~o.- Methanol Supe~ision Pr~ob Safety Meeting · . AFE ,., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WI=LL COMPLKTION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number 88-74 ARCO Alaska, Inc. 3. Address 8. APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50- 029-21837 4. Location of well at surface 9. Unit or Lease Name 745' FNL, 1855' FWL, Sec.22, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 2029' FNL, 1115' FWL, Sec.16, T13N, R9E, UM 30-2 At Total Depth 11. Field and Pool 1899' FNL, 871' FWL, Sec.16, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool RKB 59'I ADL 25513 ALK 2554 12. Date Spudded08/14/88 13. Date T.D. Reached08/28/88 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°nsl 2/19/88' N/A feet MSL 1 ' 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10420'MD/6792'TVD 10308'MD/6709'TVD YES I~ NO [] 1787' feet MD 1700'(approx) 22. Type Electric or Other Logs Run DIL/FDC/CNL, SWC, CBL/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# U-40 Surf 115' 9-5/8" 36.0# J-55 Surf 5930' 12-1/4" Tn.n jnh w/100 7" 26.0# J-55 Surf 10392' 8-1/2" 315 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9963 ' 9891 ' Perforated w/8 spf, 45° phasing 10110 ' -10130 'MD/6567 ' -6581 ' TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addend,jm, dated 1-24-89 for fractur.) data. · 27. N/A PRODUCTION TEST , Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED,,k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c~'ri Press. 24-HOUR RATE "Ir 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · , . · None , · NOTE: Drilled RR 8/29/88. Perforated well and ran tubing 10/2/88. Fractured wel 1 12/19/88. ~ :.i, ,-~ Form 10-407 096/WC5 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 10022' 6506' N/A Base Kuparuk C 10041' 6519' Top Kuparuk A 10043' 6520' Base Kuparuk A 10188' 6622' 31. LIST OF ATTACHMENTS Addendum (dated 1-24-89) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~' ~C/~, Titl~rea Drillin9 En~lr. Date ¢O'~J]~/l~? INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 9/17/88 12/19/88 30-2 Rn GR/JB to 10,309' WLM. Rn CBL/GR f/10,309'-8200'. Rn Gyro f/10,300' to surf. Frac Kuparuk "A" sand perfs f/10,110'-10,130' in seven stages per procedure dated 12/14/88 as follows: Stage 1: Pmp 205 bbls gelled diesel pre-pad @ 25 BPM, 4828-5300 psi Stage 2: Pmp 400 bbls gelled diesel pad @ 25 BPM, 4838-4562 psi Stage 3: 45 bbls gelled diesel, 2 ppg Carbolite @ 25 BPM, 4395 psi Stage 4: 55 bbls gelled diesel, 4 ppg Carbolite @ 25 BPM, 4395 psi Stage 5: 77 bbls gelled diesel, 6 ppg Carbolite @ 25 BPM, 4395-4513 psi Stage 6: 75 bbls gelled diesel, 8 ppg Carbolite @ 20 BPM, 3900-4061 psi Stage 7: 45 bbls gelled diesel, 10 ppg Carbolite @ 20 BPM, 4100-6800 psi Job screened out w/45 bbls, 10 ppg stage gone. Fluid to Recover: Sand in Zone: Sand in Csg/Tbg: Average Pressure: 642 bbls 33,560# 22,900# 4600 psi I D: KRU-'C I/NU/DR ! LL I NG AIL WELLS LOCATED IN SEC. 22 T. I$ N., la,. 9E., UMIAT MERIDIAN. TEL NO: 90 VICIN~_TY MAp NOTES t. AIL COORDINATES &RE &,S.P., ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.~.L. 4. REFER. F~ELD aOOK I,.-~a-~, 5. O.a~ ELEVATIONS FROM 6. HORIZONTAl,. POSITION BASED ON ~0 CONTROL MONUMENTS Prr, r,.R LOUN~BURY & A~ior. o sT. OiST. ...... Well , Y ASPI, X, LATITUDE LONGITUDE ENL E~L I~lev. F_Je~. I 6,OZ 2,0~5::'7 525,478. Z7 70eZ~ 17,$38';~ 149e 47'$0.$97' '~4' 1842' t 'r. 5' 23.9' 2 6,022,073.~ 525 ~490.94 700~' 17.128" 149041'30.5~'' 745' 1855' 17.7' 3 6,022,052.13 525,~.67 ~' 16,913" 149° 47"~0. I~" 76~ 1867' t?.9' ~7 6,0zz,~8.~ 5z5,528.38 7~8' 1~5" 149 47 29 4~ 81 I, 189Z, la. 2~6, 6,0~1,~2~. IZ 5~,57~.27 i5.632" 149 47 27,974 89T 194t 18.4 23.2 I0 6~OZl ,84~ 525,623.6~ ~28' 14.~3" 149°47'26.6~'' 975' 1986' 18.7' 2~5' Il 6,0ZI ,822. ~ 525 ~6~5.71 ~' 14.651" 149° 4T'Z6.~5" t998' 18.8' 23.5' ~7' I' i~ 6~OZl ,6~.e7 525,648.~ 7~26', 14.4~7', 149047'~.9~'' 1019' 201 18.8' 13 6,021,779. 16 525,66i .~ ~e~, 14. 223" 149047'25.5~" 1041', 2024', 18.9', 23.0, 14 6,OZI ~7. ~ 5Z5 ~6~.~ ~e~, 14.010 '~ o ' 15 6,021 ~735. 76 5Z5 ~6.12 ~e~ 13.~5 149°47 24.8~" 1084 Z048, 19.0, 16 6,0~ 1,714. 15 5Z5,6~. 17 ~28' 13.~5" 149°47~24.4~" I I~ 20~, 19. I 17 6,OZl ~69~ 5Z5 ~710.85 ~' 13, S69" ~49°4T Z4.0~' 112~ 2073 19.0' 2~9' t8 6,0~ I ,670.97 5~5 ,TZ~.~ ~25 t3. t57" 149~47'~3,733 1149' ~085' 19.0' 23.3' Ual i i ..... SURVEY MADE BY tdE OR UNDER. MY ~UPERVI~ION, &ND THAT ALL DIMEN810~ &NO OTHF.~ ARE CORRECT did OP' ....... 1 i i · , i _ iii A, CO Alaska nc. D.S. 3-0 WELL coNDUCTOR AS-BUILT LOUNSBURY Associates ANCNO~AGE ......... ALASKA '.. -- ' · -- "--~ ~,&...,b ..·,d, ,al. Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 October 19, 1988 Re: Our Boss Gyroscopic Survey Job No. AK-BO-80097 Well: 3-o-2' Field: Kuparuk Survey Date: September 16, 1988 Operator: T. McGuire Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure NL Sperry-Sun/N Lindustries, I nc: RO. Box 231649, Anchorage, Alaska 99523-1649 Tel. (907) 522-1737 · -,F R --,it ::, ~RVEY , 1.1~ ANC:HORA,]E ALASKA ~ ' :' ':: :~ ~:: :~'::' ARCO ALAoKA, INC. DATE OF SURVEY SEPTEMBER !6' 1988 KUP~RUK SEPTEMBER 16, 1 - '"-' W:~o JOB NUMBER ~K-BO-80097 ~L~K~ KELLY BUSHING ELEV 5~. O0 FT . MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECT~NGLIL~R C:OORD IN~TES VERTICAL DEPTH DEPTH DEPTH DEG M I N DEGREES DEG/100 NORTH/SOLITH E~ST/WEST SECT I 0~' .j ................... 0 ............ o. Oo .... ........... ........... o .......... ..... O, .... p 'E ............ b':6o .... O. Oo O. oo o. oO 100 100.00 41.00 0 13 200 200.00 141.00 0 12 300 299.96 240.96 2 51 350 349.87 290.87 4 1 400 399.69 340.69 5 33 450 449.36 390.36 7 28 500 498.77 439.77 10 2 S 5.39 E 0 '-"'--' .....~ 0.20 S 0.02 E -0.13 S 5, 50 _.E.. ' "~- - o_ ,-. c' ........ · ?_._.~.x_~ .................... gb..D~-_,.. :: ....................... 9 06 F -0.37_ N 45.''''~ o:; W .:,'". 01 0.97 N 1 .71 W 1 . ¢~/-,.. N 47.10 W ~':". o=,'~'/- ._,.':' 03 N .:: . ~ .-. W 4 . ':~':'.. ~ N 48 '-" .~u W '-' 07 ~:??,~ N 7.00 W N 50.6:.:> W 3.84 9.47 N 11.:34 W 14.68 N 49.:39 W 5.15 14.37 N 17.16 W 22.24 550 547 83 600 596 ='~ .=,'~-'~ ~2 14 0 N 48 10 W ':' 69 ~1~,:, ._ ._'s/. . -- ._i I 650 644.74 5u._,. 74 16 .z~.. N 48.60 W 5.31 700 692 4:3 633 43 1R,~ I4 N~c}~' :7:~)_. W ':' ':"-' 750 739.73 680.73 19 800 786.58 727.58 21 850 832.87 773.87 23 900 878.57 819.57 24 950 923.69 864.69 26 1000 968.16 909.16 28 1050 1011.89 952.89 29 1100 1054.90 995.90 31 35 N 50.60 W 2.71 16 N 49. 0 W 3.54 4 N 47.8(~N ........ 3.73 46 N 45.39 W ~,'~.92 13 N 44.19 W 3.08 10 N 42,80 W 4,10 48 N 41.89 W 3.36 28 N 41.10 W 28.20 N 32.90 W 42.99 36.99 N 42.78 W 56.07 46.72_!~ .... ~4 ~_IA. 7o. 95 57.04 N 66.68 W 87.06 68.31 N 80.00 W 104.38 94.79 N 108.82 W 143.0 110.07 N 123.99 W 164. 126.65 N 1:39.71 N 186, 34 144.56 N 156.0:3 W 209.82 163.65 N 172.91 W 234.42 1150 1097.22 1200 1138.9~ 1300 1220.73 1400 1299.89 1500 13~6.69 1600 1451.47 1700 1523.78 1800 1593.76 1900 1662.51 2000 1730.23 ..1.0:~6.~'_2._2_ ..... ?_2 .... ._5! ......... N__ 41.80 1079.98 33 1161.73 36 1240.89 38 1317.69 40 1392.47 42 25 N 48.30 W ::::::::::::::::::::::~ 1464 78 44 _~4 ............ N_48.8~ W 2:~0 1534.76 46 15 N 50.69 W 1.91 1603.51 46 53 N 55.19 W 3.33 W 51 N 42.80 W 2.28 203.93 N 209.04 W 27 N 44.50 W 2.78' 245.57 N 248.80 W 51 N 46,30.~ .... 2,.6~ .......... ~.,_~.~ ........... ~.31 ~ .......... 46 N 47.80 W 2.14 332.05 N 339.18 W 376.42 N 388.56 W 422..12_N ....... ~40.81 W ........ 468.25 N 494.82 W 511.98 N 552.77 W 2.86 .. 183.60__N ..... l?O._~,.W ............ 2.60.1L ..... 286.75 342.86 465.91 531.56 599.~1 .... 670.81 743.26 .~,60 N 61~.._4_~_.~ .............. 8/_6.83 SPERRY-.'~_U~N__Id~ SLLRVEY ING CAM~_P__A.N.Y PAGF~__~- ANCHORAGE ALASKA ARCO ALASKA, INC. DATE OF SURVEY SEPTEMBER 16, 1°'='°~,:,~ KUPARU~( SEPTEMBER 16, 1.988 JOB NUMBER AK-BO-800.97 ALASKA KELLY BJoHING ELEV. 5~. 00 FT OF'ERATOR-MCGU I RE -~E"~i"~SA'E~'- ~SE~:: ~' I 0N ' ~k COLATED ~ ~L~NP- CLOSURE TRUE MEASURED VERTICAL DEPTH DEPTH VERT I CAL I NCL I NAT I ON D I RECT I ON SEVER I TY RECTANGULAR COORD I NATES DEPTH DEG MIN DEGREES DEG/100 NORTH/SOUTH EAST/WEST ............... 2i6o 2200 2250 2300 2400 1795. L~ 17:~&.02 .~,1 21 N 54.69 W 3.6'~- ................ 5'~i~.'~.z;'~-'~i .......... 676,04 W ~,..,'~ 84 17'.'-;5.84 == . Jo, .9 N~,-".80 W 4.10 644.36 N 740.~2 W VERTICAL SECTIC" .) 8~'? 95 ~72..96 1,.--,/8~, "'~ ................................................................ ,~ ~-; 18Z3.8,9 56 .:,5 N .'=,'-' 1.9 W 3.03 ._6( ,.., N ......._7.Z~,...!i._.~ ............... l.g.l_'~, 2..4 ...... /_-I .~4. --'"' 1.91 C). 04 1 '~'~ o._ 1.04 :J7 37 N .=,o~ ._,. 60 W F:._ 14 -" ~,_-, N 806..94 W 1056.1'~'._-~ 54 69 q:.~, 8° 1.962.60 1903.60 :j,~,=o_ 56 N. W 1.62 744.6.9 N ,~_._. ~ .. W 1141 . 11 · -, -) .- ,-, - _ ,~, - ~ .-, ~_ - (-) ?, ,- .-,,~ ¢; ~ ~_ .-,.-, ,~ ._~.g.. ! :~_-.,:,c.) 1W54. c,c.) 5 ~; ~Z_-, N ~,4.60 W . . .. 1 .... _7. :....4...'; ~._....,:', ~ ..... ..N_ ................ :;..4_~.,, .... .., W_. ................. _~_~=..~A ............. :-;/., 2600 2064.87 2005.87 2700 2116.51 2057.51 2800 2168.03 '~10~ 03 290A oo - .~ c,.-, ~1~ 82 157 3000 226.9.05 2210.'=o._, 3100 '~J 1~ ~'" '?~ ' ~ :.. ~ ~6£). ~._.'~'~' 3200 2370.15 ~311.15 5.9 3 3300 2423.6.9 2364.6~ 56 12 ............ ~40.Q .......... ~7~,~ .... 24~0,_.,~ ........ ~ ....24__ ...... . 54 49 3500 2537 08 2478.08 3600 25.94.83 2535.83 54 37 3700 2652.67 2593.67 . 5~. .42 . 3800 2710.10 2651.10 55 11 3900 2767.22 2708.22 55 8 ............ ~99 ......2824, ~ 27~ ~ ........ ~ ....2_.9 ... 4100 2880.78 2821.78 55 2.9 4200 2.937.50 2878.50 55 23 4300 2994.36 '-'9~'= .. ~.o~.36 55 18 4400 30,53.19 2994.19 52 37 4500 3115.66 3056.66 50 3 4600 3180.10 3121.10 4.9 43 4700 3245.11 3186.11 4~ 10 4800 3310 40 '~'-'= · o~._,1.40 49 19 844.61 N 1015.7:3 W 1312.86 8c;~. -- --~ ,~-, ;,. 1~ N 1084.88 W 1..,9c,.39 .... :.'4.6~ (..-, _N .............. !.1.~:~,..8__l.. W ........... 1.~..,a~Z ......... . . ._,6W. ~5 ~.97 77 N 1222 6.9 N 1~ - .' '-- . 6._6.21 1050 ~3 N l:'P1 4~ N 1 5 11 "-' u: ~.._~ ....... ~~K..~ _~~~_ N 52.19 W 0.73 1155.52 N 1428.15 W 1828.:30 N 55.10 W ~.~.75 1205.59 N 1496.14 W 1912.62 N 54.30 W 1.08 N 54.10 W 0.26 N 53.69 W 0.34 N 53.19 W 0.63 N 53.10 W 0.10 N 52.69 W 0.48 N 52.30 W 0.33 N 52.1.9 W 0.12 N 52.30 W ~_ 0.,_13 N 54.80 W 3.36 N 54.50 W 0.63 N 54.5C) W O. 15 1299.96 N 1631.17 W 2077.3 1347.71N 16~7.38 W 2158.86 13.95.78 N 1763 30 ~ . ~'~o 35 1444.53 N 1829.06 W 2322.08 14.93.76 N 18.94.74 W 2404.01 1543.36 _.~ ....... 1'.~____6~ ~2_~ ....... ~__~ 1593.52 N ~.'~r)'~5~._. 70 W 2568.26 1643.94 N 20.90.82 W 2650.37 .......... 1694.30 2155.86 W 2732.40 1742.36 N 2220.87 W 2813.12 1786.76 N 2285.09 W 2891.18 ~ ;~] :~ ~ ........ 23___4_~._0J_ ~ ...... 2967. ~L 1874.09 N 2410.05 W 3043.56 1918.07 N 2471.72 W 3119.26 N 54.3C) N_W_ ....... Q-~.~ ........ !762:_.3~ .N ........2~:~:__ :::.~d__, _N_ ............. ':_:,~_1~,_26_ ....... ARCO ALASKA, INC. 3-0-2 KUPARUK ALASKA PAGE ANCHORAGE ALAoKA DAIE...,,_.,.....____... ,.._.~...,._i?; ~:OF SURVEY SEPT.,EMBER 16.: 1788. /.~I_M..,..F' L~ T.~.I.I !3N....~!E BQ~. SEPTEMBER 16, 1..----_-, dOB NUMBER AK-BO-800?7 KELLY BUSHING ELEV. = 5?.00 FT. : MEASURED DEPTH 5000 5100 5200 5300 5400 VERTICAL DEPTH VERT I CAL I NCL I NAT I ON D I RECT I ON DEPTH DEG M I N DEGREES SEVER I TY REC TANGLILAR L. UL RD I NATES VERT I C:AL DEG/100 NORTH/SOUTH EAST/WEST SECT I C 03 205A.43 N ,'-'-,60 07 W 334? 37 5500 3746.76 5600 3806.65 5700 3866.12 5800 3724.~4 5?00 3783.17 6000 4041.33 · :,6o7.7/-, ~,:-~ ~, N ~,6. o ~.-~ W O. 3747.65 53 17 N 56.~,0 W 0. 3807.12 53 41 N 56.3¥] W 0. . i38~_. ?4_. 5~ !5 N ~.,/~.,. )_.W :3924 17 ._4 31 N 55.80 W 0 · -"' '~"-, S . 3.9 0. · :,Po~.33 54 '21 N ._6 W 40 2267 89 N .~09'~ . z:-.~.17 W 3746.33 37 ~" ~ z312.3~ N 3057.17 W 3826.72 ~ ......... 2357.~ ! ~ ~ ~'?~t,..~Z....~ ....... 3~O.Z, 5~ ........... 32 2402.8? N 3173.67 W 3~88.88 ~')..~ 2448.26 N 3261.~1W 4070.22 /-,1AO 4(:)99. ?,1 4(')40.51 54 6200 4157.57 4098.57 54 6300 4215.43 4156.43 54 6400 4273.23 4214.23 54 6500 4331.17 4272.17 54 6600 4387.10 4330.10 54 6700 4446.~? 4387.?~ 54 6800 4505.00 4446.00 54 6?00 4563.42 4504.42 54 · _-,.) N .'=, . 0 · _6 ...)(.. W 30 N 56. 0 W O. 47 N 55.89 W O. 34 ....... _N__.~.~, .'6%._tE ............. !). 36 N 55.50 W O. 34 N 55.69 W 0. 40 N 55..60 W ........ O. 23 N 55, 30 W O. 6 N 55.10 W O. !7____ ..... 2473.33_b1_ .......... ~~9_~ .... 24 2538.68 N 3396.53 W 2? 2584.35 N 3464.11 W 2~ .......... 2630,j~.6__~ ........... 3~.1~___W ........ 25 2676.15 N 3578.~3 W 17 2722.20 N 3666.18 W 13 2768.21 N 3733.51 ~ 37 2814.40 N 3800.5? W 33 2860.72 N 3867.24 W 7000 4622.53 4563.5:]~ _ 7100 4682. :37 4623.37 7200 4742.71 4683.71 7300 4:--:03 r~'.~ 4744. ................. ? _- . . .......... 7400 4863.27 4804.27 7500 9--,::: . 4...'~. 64 4864 64 5.3. '_2.5 .. N5_7_._ ..... g_W.. .....!._6~_ ..... 2~05. Z6__N ....:~.~. 1:3W · _~ 3 N 58 60 W 1 3:3 2?48 45 N 4001..92 W 52 43 N 58.3:-.? W 0. :38 2.9?0.1'7 N 406.9.71 W 53 0 ~'~~R .~,(', ~-~ q(-,-':,~ ,:,'-, z~l"::7 ,:,.~ ........................ :..~_._,.__~._~_._,.__~ .... .r-.2~?_ .--,~,.=.i_~.~.::~ N .... _~_..-~ ~.~. N 53 0 N 58.37 W 0.08 3073.62 N 4205.71 W 52 43 N 57.8.9 W ~ ~:.~..~.~48 311~',.,. 6.9 N 4,.7,.'-' '~. 62 W 7600 4984.25 4?25.25 7700 5044.8.9 4.985.8.9 7800 5105.55 5046.55 7.900 5166.05 5107.05 52 41 N 58. 0 W 0.0.9 5'2 37 N 57.60 W (3. :32 ~--, ?].;, ._ ~... ~. ._,_..~., . N.. ~_7. _. 6_(.) W C). ~7 _~4151.55 ....... 4232.77 4314.53 4477.6 ?' 4~,~. .J~, 11 4640.64 _ 4722.07 4803.21 ~8~.~16 .... 4.963..95 5043.65 · . ,__~.u~~ ....... 5203.15 5282.84 3200.15 N 4408.40 W 5441.85 3242·51 N 4475.68 W 5521.34 3.~, 17 N. 454'.~,:P_0 l~ ............. D,_60~r~._~ ..... .................................................................................................. SP____E_~Y__-.~UN__W~=.L.I~_ SL!_RVEY_____I NO COMPANY ARCO ALASKA, INC. ._.~..-0,_.;2': KUPARUK ALASKA V~i~ T'i]~:'~L- ~E'C-~-i ON CAL C:uEA~E~:: ALO~'G '"'~iL]~i'~O~ ................................................................................................................ Tr..t-!E_ ........ SUB~SEA L_-.:p_~! .R_..,__=:E.. ..... .L-_:P.._L!~SE P_o_G_~._L_EG _TO~_A.L._ ANCHORAGE ALASKA DATE OF SURVEY SEPTEMBER I6, !~88~ C ~~ BT~ .C~__~!.~ ZE_ B_.O..'~.. n.._~!~: -~.O~_~Z~ R VEi ¥::: i:::i :ii. i: i ::ii: ................. SEPTEMBER 16, 1988 ..lOB NUMBER AK-BO-80097 KELLY BUSHING ELEV. = 59.00 FT. OPERATOR-MC:GUIRE PAGE MEASURED DEPTH 8000 8100 VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEG M I N ~ EL~R EE._-, DEG/10A NORTH/SOUTH EAST/WEST SEF:T I 0 · ~"~._ ~6.4::,= ~,~ 1 ........ 67.4~,=--- ~S::'~ ....... 48-~ ................... N ~i_';'~j Z ....... ~,o~: W i:-i'~" 1~ ...... :-z-X~'2~'~" '~4 N 4610 .16 W ~'~" .=;'""~'~ . ~' .') '"A · _i~6 77 53 3370. o., N 4677.43 W 5760.3.9 . ._,~_-.77 0 N 57 50 W O.~C 5:347, :34 ~8~:._~_4_ ............. ~'__2 ....... .26__ ............. N.. 5Z_..~9....w__ ......... 0:_~.~ ......... ~.41_~_..:3!.._~N ........ _4._7...4_4:..:_~,'_3__W_ .......... ._~5_8_~,.:..:~4_ ......... 8300 8400 8500 8600 8700 8800 8900 9000 9100 9200 .9300 6037.43 ....... ~.~oo ......... 9500 6165.39 .9600 6229.75 .9688 6286.62 5909.72 5850.72 50 23 N 68. 0 W 5973.60 5.914.60 50 12 N 68. 0 W 5.978.43 50 27 N 68.19 W 6~.,_~Z ....... ~ ...... ~ ......... ~.-_6E~_ ~ ...... 6106.39 50 20 N 68.39 W 6170.75 49 32 N 68.39 W 6227.62 49 55 N 68.39 W .9700 6294.36 .9800 6359.23 ~ 64~4.~ . 10000 64~1.11 10100 6559.71 10200 .... 10256 6671.35 10300 10400 10420 6235.36 49 46 N 68.10 W 6300.23 49 19 N 68.3.9 W 6~6~,5~ ........ ~9_ 4 N 68,10 W 6432.11 47 30 N 66.30 W 6500.71 45 52 N 64.89 W 6571.66 43 43 .~8__(~_ N 6612.35 43 :3 N 60.39 W 6703.57 6644.57 42 48 N 58.19 W ._6_7_7__6:94 .. ..67_~._7,~_.4_ ........... _4._2____. 48 ....... _N___~_.._I~_H 6791.61 6732.61 42 46: N 58.19 W 0.34 ._,':'aS.=,~._ ,.. 17 N 4811 .93 W 5919 .13 0 42 '--' '-- · ._-4 ~/_-.. 45 N 4879 .2':.~. W ~,~,~o._ .... ,~. 0.9 ' .--;~1~'~_*--, r~- .-, .'"ir ,-- i'~'_, ' -- (.). ~.._. .:.,..._'~7. ~'. N 4 .*'46. c, 1 W 6(.)76.9., 0.68 3577.46 N 5014.38 W 6155.47 3.84 3614.26 N .~, '--"-. . · _08:--~ 44 W 6233 38 '.2.:5_? ~.4_~, 97._.N .... :sJ ~4_~?__.w ........ 6~_0'.?,~? ...... 0 · 08 :2:675.55 N -=,'-'*"= '-'.=, _ _ _ ,- -,'-~,....:.._ W A:38.=, · 61 O. 23 :]~704.9:3 N 5296.45 W 6461.14 '-",. . _ 5'- ?, - ='-' 0.~5 3733 96 N ..L-:~:?_,._7.__.._N /_6t,,,,,,,,,,,,,,~;_:~,__6~ ._66_~ 0.18 3762.78 N 5439.09 W 6612.09 0.29 3791.49 N 5510.51 W 6687.52 __Q ._i~ ........ .'~_9.. ~2 .. _N ......... ~s~81 .._9..5 __.1~ ............... 6Z62 .~' 0.30 .~'-"~:=: 20 N 5653.37 W 6838 0. 0.80 3876.37 N ~ 7.-4. ~,._~ W 6912.94 O. 44, 8901. O~ N .... ~ ~,Z~N 6.978.68 2.27 3.904.49 N 5795.48 W 6.987.66 O. 50 3.932.6.9 N 5866.16 W 7062.20 .._~ ...... .~96_~..~ ..1~ ..... ~s~:36. ~Z.... W ........... ZI'~ 35 2.07 398.9.65 N 6005.28 W 720.9.71 1.92 4019.69 N 6071.53 W 7281.56 2, 2.9 ......4.05~.~_]~Z_~ ......... _~t~ 0_4__~ ............. _7._~51,36 4.33 4068.16 N 6169.02 W 7389.63 i~:~i~i~ii:i.:i!~:~46 4083.45 N 6194.7.9 W 7419.57 O' :,0.2_ ....... 4..! 1.?._'"~ N ....... 62~'.~. $~__ H ....... 7487.48 ...... 0.10 4126.42 N 6264.08 W 7501.07 ............. ..HCj_R! .Z!3NTA_L. D ! ~_P.L.._A]..-,~gM.E,.N_T..=. ..... 7~.5!.~! _..~).7_ .... _F_EET._A~_!~2.R_TI-i__.~6 P,E~,.. ~:Z.....~I~, ..... WIE~T._.~IT IM!f~... ~._...1.0~_ THE CALCLILATION PROCEDLIRES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD· ANCHORAGE ALASKA ARCO ALASKA, INC. ..... ~._-. 0_,..~_: ~! i~.. ~. KUPARUI< SEPTEMBER 16, 19:--:8 ALASKA TRUE MEASURED VERTICAL DEPTH DEPTH DATE OF SURVEY SEPTEMBER 16, 1988 ,JOB NUMBER AK-BU-oL .~7 KELLY BU:=,HINu ELEV. -- 59.00 FT. OPERATOR-MCGU I RE i ' INTERnaliZED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH_ ............. ..N_,~,_R..T_Hy;~o_u TH ........... _E_.A_~!._T.Z.~.g~!__T ........ D I .F__F...E_ R_' .E.N__Cg .......... CORRECT I ON 0 1000 3000 4000 ....... 5060 6000 7000 8000 ~000 10000 10420 0. O0 -59. O0 0. O0 0. O0 0. O0 .-.-,63,.! 6 . ......... ~0.?: !_6_ ................ ~ 26__: ~_.. N ......... !i~'?.... 7 ~ _..W _ "-' .... ~!,~.4. s1,84 17:30 '-"-~ 1671...'3 =='- --,-u .~----. .~._ ~_,._,:_-: .60 N 613.45 W 26:-?. 77 ..._,7 ..... :, 22/_-,9.05 '-'"' . . 4/_-, 1 18 · -'-' 1A. A5 1050. '-'"' ~._', N 1291 43 W 730 95 . -- .-- ._--~ I~_ ~-~ ,-- ,~ ---, 2:_~24.1'2 2765.12 ............ 15..4_~.:_..3~_N.. .............. l_?~.,~:J.: :~__..~ _1_._! 7.._-.,. ..j--,_,'~ ....................... .4_4.....4_._...~._-_~ ................................................. 34:39.57 <:'" -"' '-'='-" ,.,~80.57 2006.46 N .--._, :.-o. 21 W 1 o60.43 384.55 "'- :3~61.21 W 1958.67 3'B8.24 4O41, :i~:_~ 3982.33 2448.26 N "'--' 46~_Z_'. O.S .... 4563, .._s..~ .............. ~90~.~__7.6 ..N_ .............. ?__3_'.4 .....i_S .._W_ ............. :2.~.7.~._4.7. ........................ _4..; 8~8! ......................... 5226.45 5167.45 3:327.94 N 4610.16 W 277:--~.._s~'._, :396 . AS. ._,7o6. _.o0 :3704. _'~:3 N 52-.~/-,. 45 W 3154 10 .'~80 ~ 6491.11 6432.11 3989.65 N 6005.28 W 3508. :=:q',, .._ .... :354.79 6791 · 61 6732.61 4126.42 N 6264.08 W 3628.39 119.50 THE CA.L_C._LI_L_A_T_!_C_I_N__ _F:~OC_.'E...D_L!RES ARE BASED ON THE USE OF _T_HREE, D IME~,IONAL RADIU.~_OE_J~Lt~E_~'D. _- T SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA ARCO ALASKA, INC. KUPARUK SEPTEMBER 16, 1988 ALASKA TRUE MEASURED VERTICAL DEPTH DEPTH DATE OF SURVEY SEPTEMBER 16, 1988 INTERROL~TED VALLEo~ o FOR EVEN 100 FEET OF '>:..UB-oEA° DEPTH SUB-SEA TOTAL dOB NUMBER AK-BO-80097 KELLY BUSHING ELEV. = 59.00 FT. OPERATOR-MCGU I RE : VERT I CAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL ~ 0 0.00 59 59.00 159 159.00 259 259.00 359 359.00 459 459.00 561 559.00 664 659.00 770 759.00 878 859.00 -59. O0 O. O0 O. O0 0.00 0.04 S 0.00 E 100.00 0.43 o'-' 0.04 E · .' 30.00 0.1.:."' ~ '=' 0. ._,6 = W :300.00 3.47 N 4.36 W 400.00 10.30 N 1°.-.35 W 500.00 22.28 N 26.25 W 600. oo ~'.-?, 02 ~ 4.6..: o~.....w_ 700.00 61.47 N 72.02 W 800.00 88.48 N 102.40 W 0.00 0.00 0.01 0.16 0.73 2.43 ~,~ ................ 11.~? 19.46 989 959. 00 '- ' '. ~0o O0 12:3. ¢ ._, N 1:36. :38 1104 1059. O0 1000. O0 165.54 N 174.56 1224 1159.00 1100. O0 213.87 N -.-'?'18.33 1347 ...... ! ~59._ 00 ! 2.'_00 ,. Q.Q ............... ~O_6._Q!._ 1476 1 '::='-? .... .... ,. 00 1300 O0 321 80 N :327 88 1610 1459.00 1400.00 381.00 N 393.70 1749 1559.00 1500.00 445.2~. N .... 46~. 92 1894 1659.00 1600.00 509.81 N 549.71 2043 1759.00 1700.00 572.06 N 640.43 W 45.81 W 65.21 W ........... ~8.?_~ W 117.64 W 151.21 W 190.84 W 235.86 W 284.55 0.00 0.01 .......... f!_....i~ O. 58 1.70 3,..47 ......................... 5.59 7.98 11.15 ...................... 15.19 19.40 ................ 2 ~. Z~ ............................................. 28.68 33.57 39.64 __ 45.02 48.69 ARCO ALASKA, INC. I<LIPARUK ALA:=.KA I NTERROL~ATED VALLEo FOR EVEN ANCHORAGE ALASKA DATE OF SURVEY SEPTEMBER 16, 1988 ................. _~!ME'~ ~T_ ~.._ .~A TE · 'REPTEMBER 16, 1'- ~.=,o dOB NUMBER AK-BO-8OO.g7 KELLY BUc. H ING ELEV. = 5:9.00 FT. 100 FEET OF SUB-SEA DEPTH ............... TRUE MEASURED VERT l' CAL DEPTH DEPTH SUB-SEA TOTAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL . ~!E PT__H_ ............ NORT__H_/.'_S~L_ITH g~E!T.~.~gST , D ~ FFE'__RE_NL~:E_ ........ !::ORREC:T I ON 2207 1859.00 23~3 1~5~.00 2588 2059.00 2782 215~.00 2~7~ 225~.00 3178 235~.00 3363 245~.00 3538 255~.00 ooo. O0 647. ~7 N 745.38 W ._,48. ~.8 63.73 I__?Q(,,.C_~.~ Z.4_l. ,_~_4.. N ............... ~Z ~_.,__0~ W _.4~.4 ,..(>:~ ~_..Z:_s_ 2000 00 '='--"~ :::'-~ ~._,. 5o :_~o:~ N 1007 79 W 529. - · -- '--- m -- ._ ..~ '-' ' ' ..-c-~,..96 N 1141.62 W . .93.76 ~ 1 O0 O0 o~,~- .=,.-., - - · 6 .-._, :~ .-_,.-.~ - . · ..-~.OL, .... O0 10:-~9 60 N 1277 62 W 720 2300.00 1144.12 N 1413.46 W 819..-',.~'-'"':'- 2400.00. 1235.54 N 153'~. 17 W 904 .21 84. ,_~.~:Re, 3710 · _,~ ~, 4061 -'6._, Y. O0 2600.00 1401.07 N 1770.50 W 1051. '~6 ..7._,.9 00 2700 00 1486.67 N 1 ~"-= . · . ~:-~,. 30 W 1126 ; '-' · =,:q=.o 00 '-"-"' - - ~,_~(.)t) O0 1574.15 N 2000.6:3 W 120z. 56 , .," ,.~ ._, ;;- . = 4237 440.g 4567 295~. 3059. 3159. 00 2900. O0 1663.04 N 2115.44 W 1278.86 O0 3000. O0 1746.6.g N 2227.04 W 1350.51 O0 3100. O0 1815.87 N 232_7.67 W .......... 1408. ~7 O0 3200. O0 1883.42 N 2423.13 W 1462.24 00 '-"='('>'" · :,o.v. O0 1.951.12 N 2517..92 W 151=~,.76 O0 :3400. O0 201'~. 76 N 2615 49 W 1571 . 43 . · :-:: . :::..: : --...,.,.. ~ .... :: ::: ............ . ,, O0 3500. O0 20~0.05 N 2718'80 W 1631' 4:8 O0 3600. O0 21~0.50 N 2827.66 W 16.~5.24 4721 4874 5030 3259. 335.9. 345.9. 5190 5354 3559. 365~. 72.91 74.66 76.31 71.65 ........ 57.86 53.87 53.52 60.05 63.75 :=.FERRY-oJN WELL :=.JRVEYINU COMPANY ANCHORAGE ALA.. KA ARCO ALA...K.A, INC. BATE OF SURVEY SEPTEMBER 3-0-2 ~' COMPUTATION ~TE ' i:~' KUPARUK SEPTEMBER 16~ 1'- '~'-' ~o JOB NUMBER AK-BO-800~7 ALA._KA KELLY BUSHING ELEV. = 5~.00 FT. OPERATOR-MCGU I RE I NTERRO~TED VALUES FOR EVEN I00 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERT I CAL VERT I CAL RECTANGULAR C:OORD I NATES MD-TVD VERT I CAL DEPTH DEF'TH D~F"T_~ .......~ 0~.~/..~a;).~!~T.~_ ............. ~O~!T_~MES~ P_I. EE.~.R.~.~:~ .......... E:I;~.~_R~¢? ~ ~;I.N_ .................................................. 5520 5687 5858 6030 6202 6375 6548 L-:7o~ O0 3700.00 .-.., o .q . .-, 82 N'-"-'-'- .~. r/:_-I:_--.:, '---":'~ o.-. W · --, .., l~':' ,--. OC! .-- L--, '} ' · :"='.-' .'-' - :'-'~'='(- O..!-)(~. ............ 2306_. 97 N . 305! ,1 ...... 1 W '~" '-' =- '-' 00 :qg00. O0 "-"-'"'--' ~::_.~o .... :_::4 N :Blt:=. 65 W 0 .':*' ._l .':.~'. .... ~, ._!. 4APi':,, 00 4000.00 2461 ,--,o --,.~,--,- ........ o.- N .:,~.-o: i. 72 W 4159 00 41 O0 O0 --,=,,--:,,r~ '---'c"'::'--e-?,---' · '=)" ....... ~?--..-'_ ~:_-. _O_-Z. N . · : ................... :._:__ <..~, ..i._....: .... 4259. O0 4200. O0 261,Sc:. 91 N 3515.09 W 4.>Dy. O0 4300. O0 2698.33 N 3631 . -'-~:'"'~ W 6720 44o.9.00 ----. ~5~"-- '--~ ·· m 7061 4659.00 7392 4859, 00 7558 "9='-' 00 ~l'. 7723 · _,0o .~ · 00 7888 5159.00 8053 5259.00 8219 5359. O0 1761'.'~'-'o,:. 66. 14 1899. :36 70.3:_=: 1971.31 71, '-=.~._, 204:=:, 4A -~'-' ~ =' /"'m 2116.44 72.98 2189.05 72.61 4400:O0 ._2777, 76_' N.. 3747:...4_9 W .... ~6!, 7"_-=: .......... Z2, 7~ ............................................................. 4500 00 2857 '.-"q N '-"='/-'-, ..... ..... :,o,:, ... 2.:: W ~. ..... :,. 46 71.6'.'.? "- '- '- '-, - .~ '-, ' '-, 4600.00 ~.'-.~._-:'." .26 N 0.97,. . ..,'~:-'=',:-, W -.'40.-'. 11 /_' ..... /_',4 4 7 0 0.0 0 '-' ' ' '--"-' · :, (.) 01. o._-~ N ' '-' 4. ~!o,_~_~_.. 1_.4__ .. __W._ 2467.89 65. 8382 5459.00 8545 5559.00 4800.00 3070.65 N 4201.09 W 4900.00 3140.37 N 4312.98 W 5OOQ, QQ ~,~6_..~ ...... 5100.00 3280.18 N 4535.02 W 5200.00 3351.01N 4646.36 W 5300.00 3421.37 N _4757,53 W. 5400.00 3489.34 N 4867.60 W 5500.00 3555.68 N 4977.50 W 2533.91 66.02 2599.38 65.47 ....... 2664.~2_~ ..................... 64.~90 .......... 2729.30 65.02 ............................. F 2794.87 65.57 2860,14 65,26 ............... 2923.64 63.50 2986.37 62.73 ANCHORAGE ALASKA ARCO ALASKA, INC. 3-0-2 '_ .............................. ~.~_L~.iDJA_. ~/~TF KLIPARUK SEPTEMBER 16, 1 '~'.".~oo'-'''''-'"' ALASI<A ][,ATE oF SURVEY SE'PTEMB~R !6, 1988 INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRI_~,- SUB-SEA ........................... TOTAL MEASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL i'!~PTH ............ _DEP. TH ............. P~.E'TH_ ........ N(!_R_T_H_./S~L.-!~.TH ................ E__~'_.$_T/ME__~iT._ D I FFERENCE CORRECT l.g~ dOB NUMBER AK-BO-80097 KELLY BLISHING ELEV. = 59.00 FT. OPE R_A_~ OR_-J~CGL! [RI ::3!:::::!:?,i:!:i: ::! ::::::::::::::::::::::::: '::::: ::::::: ::::::::::::::::::::::::: ====================== ::: x,:.: :.:.:::::: ,: :.:.:.:. ::: 8706 56:-, :/. 00 5600. O0 8863 5759. O0 5700. O0 3616.33 N 3664.91 N 3161.51 3218.19 3274.'~';o.. ~0~7.80 W 5199.77 W 9020 · _,o._, ~. O0 5800. O0 3710. 92 N 5311.04 W 9177 5959.. 00 5900. O0 3756.21 N ._.~=.a._-,-_-,. 84 W 9333 6059. O0 6000.00 3801.20 N ~'- . .... ~4 78 W 9489 6159. O0 6100. O0 3845.36 N 5646.20 W 9645 6259. O0 6200. O0 3889. O1 N 5756.45 W ........................ 6~t?_~_~ .......... ~.~%,:). O0 3932.59 N 58~5.91 W ~._,~ 64~,~. 00 6400.00 :T~97~_. _.._~:~._ N 597:3.01 W 1 0098 =='~ - - 6~,._, ~. 00 6500.00 4(:) 19.3~: N 6070.87 W 10239 6659.00 6600 00 4062.47 N 10375 6759.00 6700.00 4110.50 N 6238.41 W 10400 6776.94 6717.94 4119.26 N 6252.53 W 3047.18 60.81 56.52 56.68 56.70 3330.~8 56.09 3386.11 55.13 3493.35 52.71 3539.98 46.64 ~~ 40.11 3616.55 36.46 3623.06 6.51 THE CALC:ULATION F'ROC:EDLIRES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS ~;pERRY,-SUN WELL_ SURVEYING COM~NY ~- . ~ ANE, HORAGE: ALASKA ARCO ALASKA, INC. ' 3-0-2/_ .................. C.. OMP_LITAT I ON .~_ ~ KUPARIIK SEF'TEMBER 16, 1 _ ~i~, ALASKA INTER~i~E£1 VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER PAGE DATE OF SURVEY E;EPTEMBER ti6~::: I~88' : :::::::::::::::::::::::::::::::::: ,_lOB NUMBER AK-BO-80097 KELLY BL :_~HINI3 ELEV. 59.00 FT. OPERATOR-MCAU I RE · ~ ~. "'"'" '"" '"" "[~'P:'i':':: [': ':~i':':'~"i'~'"' 10022 ~0041 10043 10188 10300 10308 10420 6505 98 6446 98 ':".~g~. · . ..~,. ~. 17 N 6020.1:3 W TOP KUPARUK C 6518.81 ~.4~,.~_i .400~_-.~(!.. N ......... 4,~_~3~.,_76 W BAng ~ ~.~8.R.U~;._ ~: 6~,~ 16 6461.16 4002. '-~' . ._~ N 6034.30 W TOP KLIPARUK A 6621. "'-' - ~ '~' ~8 . . ." ' .... ~o 6._6~.. 4046 51 N 6127 59 W BASE KLIFARUK A 670~. 44 6650.44 4086.32 N 6199.41 W PLUG BACK TD 6791 . ~ 1 6732.61 4126.42 N 62~4.08 W TOTAL DEPTH ARCO ~':-' ALA~.KA, INC" 3-0-2: .......... ~ T~_TI OR ¢.,l='J-lI..=¢:_' SU~Y==;__ DER ZVED USING D'~L DEPTHS AND SPERRY SUN SURVEY DATA M~RKER ....... COORD I NATES URED DEPTH TVD ....... THICKNESS ,=c,-. '~2 . : :::..: :: .::::: .~~ TOP KLIPARUK C 10022 A'='' _ ._,¢.~5, '.~,'E: 6446 · '.,'>8 3:~:;,"/_..,, · 17N 6020 · 1 BASE KUPARUK C 10041 /- .~" '-' '--'" '=',= ,~', TOP KUPARUK A 10043 6520 · ! 6 646 ! · ! 6 4002, 3'.~N 6034 · · " I .... .., ,.-, 6562, - _o BASE KLFARUK A 10188 6621 '~Y~-' · ~.-- 4046.51N 6127, 5'-~W PLUA BACK TD 10308 ....................... ~.7~__.._4...4 ......... ~,~.._50.,4~ .......... "- '-4'r, TOTAL DEPTH 10420 6791,/_-,1 6732.61 4126.42N 6264.08W 1) FROM LINEAR EXTRAPOLATION BELow DEEPEST STATION. ':: 2) COMPUTER PROGRAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE. DATA CALCULATION AND_INTERPOLAT_ION BY RADIUS OF CURVATURE , COMPUTATION DATE SEPTEMBER 16, 1~88 DATE OF SURVEy SEPTEMBER 16~ i'---'Py~_, · JOB KELLY 'BUSHING. E_LEV ..... _=_ ...... ~E..FT. 5CRLE :- t INCH ,TO 1000.00 / 1000.0 KUPRRUK RRCO RLRSKR, 8-0-2 SEPTEMOE~ 16, RK-80-80097 INC. 1988 TRUE NORTH -70~0.00 -4000. O0 ~.?-.' _ o -lO00. O0 -~~: -4oho. oo -~o~o. oo -~obo. oo t; -~obo. oo t_lO00. O0 HOFi I Z ON TFt.L PROJECTION SPERRY -SUN 0.00 i5oo. oo 5CRLE KUPRRUK 3 -8 -2 RK-80-80097 INCH TO 1500.00 / 1500.0 RRC8 RLRSKR, INC. SEPTEMBER 16. 1988 3000.00 4500.00 6000.00 7500.00 8?9{.. 61 1500. 00 3000. oo ~5oo. oo 60bO. O0 10420 I ~soo.. oo I 9000. VERTICFIL PROJECTION ARCO Alaska, Inc. Date: April 5, 1989 Transmittal Ct: 7457 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. PleaSe acknowledge receipt and return one signed copy of this transmittal. 30-01 30-06 30-09 30-02 2Z-13 27-13 27-01 2D-16 2D-14 30-02 30-09 30-06 Ku Ku Ku Ku Ku Ku Ku 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Fluid Level Report Camco BHP Report Camco BHP Report Sub-Surface Pressure Report Sub-Surface Pressure Report Sub-Surface Pressure Report 3 - 2 6 - 8 9 Sand 'A' Sand 'A' 2 - 1 5 - 8 9 Sand 'A' 2 - 1 9 - 8 9 Sand 'A' 3 - 2 4 - 8 9 Both Sands 3 - 2 4 - 8 9 Sand 'A' 3-21 -89 Tubing 3-09-89 BHP 3-09-89 BHP 2-19-89 #64613 2-19~89 #64613 2-20-89 ct29855 · Receipt Acknowledged' DISTRIBUTION' D&M State of Alaska SAPC Alaska 0J~ & G~s Cone. Commission Anchorage Mobil Chevron Unocal ARCO Alaska, Inc. Date: November 28, 1988 Transmittal #: 7362 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H-0 3 Kuparuk Fluid Level Report I 1 - 1 I - 8 8 3 H- 1 8 Kuparuk Fluid Level Report I 1 - 1 I - 8 8 3 A- 01 Kuparuk Fluid Level Report 1 1 - 2 3 - 8 8 3A-01 Kuparuk Fluid Level Report 1 I - 1 8 - 8 8 30-02 Kuparuk Fluid Level Report 1 I - 1 9 - 8 8 3 H- 2 2 Kuparuk Fluid Level Report 1 I - 1 7- 8 8 3 H- 1 2 .Kuparuk Fluid Level Report 1 1 - 1 7- 8 8 Casing Casing Casing Casing Casing Tubing Tubing Receipt Acknowledged: ~ISTRIBUTION: D&M SAPC Chevron Unocal Mobil State of Alaska ~-'-, STATE OF ALASKA '-' , ALA ~ OIL AND GAS CONSERVATION COMMIS,_ _~N . REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging ~ Perforate __ Pull tubing ~ Alter casing __ Repair well m Pull tubing ~ Other 'N..~_ COMPLETE 2. Name of Operator ARCO Alaska:' Inc. 3. Address P.O. Box 100360:' Anchorage:, AK 99510-0360 4. Location of well at surface 745' FNL, 1855' FWL, Sec.22, T13N, R9E, UM At top of productive interval 2029' FNL, 1115' FWL, Sec.16, T13N, R9E, UM At effective depth 1939' FNL, 936' FWL, Sec.16, T13N, R9E, UM At total depth 1899' FNL, 871' FWL, Sec.16, T13N, R9E, UN 5. Type of Well: x Development ~__ Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 59' 7. Unit or Property name Kuparuk River Unit 8. Well number 30-2 9. Permit number/approval number 88-74/8-777 10. APl number 50-- 029-21837 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10420'MD 6792 ' TVD feet feet Plugs (measured) Plug ~ 267' w/1060 sx AS I Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 5895' 10359' 10308 'MD 6709 ' TVD Size 16" 9-5/8" 7" measured 10110'-10130'MD true vertical 6567 ' -6581 ' TVD feet feet Tubing (size, grade, and measured depth) 3-1/2", J-55, tbg w/tail ~ 9963' Packers and SSSV (type and measured depth) AVA 'RHS' pkr @ 9891' & Camco 'TRDP' SSSV ~ 1787' Junk (measured)~,., None Cemented Measured depth True vertical depth 199 sx AS II 115'MD 1400 sx AS Ill & 5930 'MD 400 sx Class G - Top Job w/lO0 sx AS I 315 sx Class G 10392'MD 115 'TVD 4000 'TVD 6771 'TVD 13. Stimulation or cement squeeze summary /A I n~rvals treated (measured) Treatment description including volumes used and final pressure 14. N/A Representative Daily Average Production or I niection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run%__ Gy re Daily Report of Well Operations ~ 16. Status of well classification as: Oil ~ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 2~ ~ ~__,~_~-~,~.. Title Area Drill ing Engineer Form 10-404 Rev 06/15/88 /~ (Dani) SW03/056 *NOTE: Completion Well History Service Date/~//~ ~,~e~O-O~ SUBMIT IN DUPLICATE ARCO Oil and Gas Company ~, Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are sterled, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ~D, CO Alaska, Inc. Field KUPARUK RIVER UNIT Auth. or W.O.~2947 Lease or~ .. 25513 Title COMPLETE Jstat~lk~ 30-2 IWell no. API: 50-029-21837 Operator ~.CO I Date 10/1/88 IH°u~200 HRS [*"c~W;'oooo Prior status if a W.O, Spudded or VV~%~-b~ Date and depth as of 8:00 a.m. 10/02/88 ( 11 TD:10420 PB:10309 SUPV:JH Complete re(~{~l~t~ch~'~y reported RIH W/ COMPLETION STRING 7"@10392' MW:10.0 NACL MIRU, ACCEPTED RIG @ 2200 HRS, 10/1/88. ND TREE, NU BOPE & TSTD TO 3000 PSI, RU E-LINE, PERFORATE 10110'-10130' W/ 8 SPF, 45 DEGREE PHASING, RIH WITH COMPLETION STRING DAILY:S57,000 C0M:$1,339,368 ETD:S1,339,368 EFC:$1,455,000 The above.,~co rrect Signat~ ~ For'form prepar~'r~'nd distribut~ see Procedures ~l~,~flual. Section 10. I~rilllnn P,~o~n 8'6"-and 87. ] Date / ] Title ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may' be used for reporting the entire operation if space is available. District Field Auth, or W.O. no. IAccounting cost center code State ~ 30-2 [ Well no. Operator Spudded or W,O. begun Date and depth as of 8:00 a.m. - ~n/o3/ee ( TD:10420 PB:10309 SUPV:JH IA.R.Co. W.~.6' Date Complete reco?~'dC~"~h la~ rape.ed Iotalnumber of wells (active or inactive) on this est center prior to plugging and ] bandonment of this well I our ~00 ~K~ [Prior status If s W.O. ............. 7::~i039~~ ~w: ~.7 DIESEL CONT. RIH WITH COMPLETION STRING, SET PKR, LAND TBG, TEST TBG TO 2500 PSI, TEST CSG TO 2500 PSI, TEST SSSV, PUMP OUT SHEAR OUT BALL, ND BOPE, NU TREE, TEST TREE TO 5000 PSI, DISPLACE WELL WITH 350 BBL OF DIESEL, RELEASE RIG ~ 2400 HRS, 10/2/88 DAILY=S187,897 CUM=$1,527,265 ETD=S1,527,265 EFC=$1,455,000 NOTE= CAMCO 'TRDP' SSSV ~ 1787', AVA 'RHS' PKR ~ 9891', & TT @ 9963'. Old TD I New TD J PB Depth Roi drig .... JDate IKtnd of rig Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) I Producing method I Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production , Oil on test Gas per day Pump size, SPM X length -- Choke size - T.P~ C.P. Water % GOR Gravity Allowable Effective date corrected Signa see Procedures ~_.~ual, Section 10, Drilling, Pages 8'~ and 87. D at e['~'~ / 'r'~itle STATE OF ALASKA Ab-,,.,KA OIL AND GAS CONSERVATION COMMIb,.,~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown ._~ Re-enter suspended well __ Plugging ~ Time extension __ Stimulate __ Pull tubing ~ Variance ~ Perforate ~ Other 5. Type of Well: Development Exploratory Stratigraphic 99510 0360 Service FWL, Sec.16, T13N, R9E, UM (approx) FWL, Sec.16, T13N, RgE, UM (approx) FWL, Sec.16, T13N, RgE, UM (approx) 2. Name of Operator ARCO Ala~kaj Inc. 3. Address P. O. Box 100360~ Anchorage~ AK 4. Location of well at surface 745' FNL~ 1855' FWL, Sec.22, T13N, R9E, UM At top of productive interval 2027' FNL, 1141 ' At effective depth 1897' FNL, 1003' At total depth 1862' FNL, 931 ' 6. Datum elevation (DF or KB) RKB 59 ' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2,0-2 9. Permit number 88-74 10. APl number 50-- 029-21 837 11. Field/Pool Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical 10420 ' M D feet Plugs (measured) 6833 ' TVD feet Plug ~ 267' w/1060 sx AS I Effective depth: measured true vertical 1 0308 ' MD feet Junk(measured) 6756'TVD feet None Casing Length Structural Conductor 80 ' Surface 5 895 ' Intermediate Production 1 035 9 ' Liner Perforation depth: measured Size Cemented Measured depth 16" 199 sx AS II 115'MD 9-5/8" 1400 sx AS I I I 5930 'MD & 400 sx Class G - Top job w/lO0 sx AS 7" 315 sx Class G 10392'MD None True vertical depth 115'TVD 4032'TVD 6814'TVD true vertical None Tubing (size. grade, and measured depth) Packers and SSSV (type and measured depth) None None 13. Attachments Description summary of proposal Wel 1 Hi story Detailed operations program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: September~ 1988 16. If proposal:was ver. bally approved ..... Oil X Gas M Suspended Name of apProvei;. ,:/E~';..-z-:/~- ;.: . ~_ lO o2~,,,.,~',~ate approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~ t/~~ ~ Title A sso~ia I;:~ E nq i ne¢r p -- ' FOR COMMISSION USE ONLY Conditions of provah Notify Commission so representative may witness ( D a n i ) 5 A 3 / 0 0 4 9 Plug integrity __ BOP Test ~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- APlC'oved Copy Returned ORIGINAL SIGNED BY Approved by order of the Co~nf~i~nOe'r SMITH Commissioner Date J Approval No. <:~' _ 77 ~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK RIVER UNIT Auth. or W.O. no. AK2947 Operator lCounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25513 TiUe DRILL ISta~K 30-2 IWell no. API: 50-029-21837 ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 08/14/88 ( TD: 731'( SUPV:SLC 08/15/88 ( TD: 2912'( SUPV:SLC 08/16/88 ( ~ TD: 5833'( 2~ SUPV:SLC 08/17/88 ( TD: 300'( SUPV:SLC 08/18/88 ( TD: 115'( SUPV:DL 08/19/88 ( TD: 490'( SUPV:DL I IARCO W.I. 56.0000 IDate IHour Prior status if a W.O. 08/14/88 0100 HRS Complete record for each day reposed DOYON 14 ) i31) DRILLING MW: 9.0 VIS: 67 MOVE RIG FROM 30-5 TO 30-2. RU AND MODIFY DIVERTER SYSTEM PER AOGCC REP BOBBY FOSTER. RU MWD AND MUD LOGGERS. PU BHA. SPUD 0100 HRS, 8/14/88. DRILL TO 400' AND KICKOFF AND DRILL TO 731' DAILY:S20,055 CUM:$20,055 ETD:S20,055 EFC:$1,455,000 :) 81) DRILLING CONTINUE KICKOFF 731'-2297'. 2297'-2912'. DAILY:S44,329 CUM:$64,384 MW: 9.3 VIS: 63 TOH AND PU NL MWD, TIH. DRILL ETD:S64,384 EFC:$1,455,000 ) 21) CIRC PRIOR TO RUN 9-5/8 MW: 9.2 VIS: 41 CONTINUE DRILL AND SURVEY 2912'-5833'. CIRC BOTTOMS UP AND MAKE SHORT TRIP. CIRC AND CONDITION WELL FOR CASING. DAILY:S63,607 CUM:$127,991 ETD:S127,991 EFC:$1,455,000 0) RIH TO DRESS KICKOFF PLUG MW: 9.6 VIS: 68 CONTINUE CIRC AND CONDITION WELL. TOH TO 966'. HOLE GOT TIGHT. PULLING TO 170,000%, UNABLE TO MOVE. RU CIRC HEAD AND PUMP OUT OF HOLE, PULLING TO 235,000#. PIPE CAME FREE @ 660'. FINISH TOH. DOWN LOAD MWD DATA AND LD TOOL. MU BHA AND TIH. TAG SOLID @ 590'. WASH AND ATTEMPT TO GET INTO OLD HOLE TO 729'. BELIEVE HOLE HAS SIDETRACKED ON LOW SIDE DUE TO SURVEY DIFFERENCES. TOH LDDP RIH W/ DRILL PIPE. RU DOWELL AND SPOT 530 SX AS I, WEIGHT 15.8 VOLUME 87 BEL PLUG LENGTH 700'-300'. PULL OUT OF PLUG AND CIRC OUT, SLIGHT CONTAMINATION. LDDP AND CASING EQUIPMENT. WOC AND MU BHA TO DRESS OFF PLUG. DAILY:S69,070 CUM:$197,061 ETD:S197,061 EFC:$1,455,000 0) WAIT ON CEMENT PLUG #2 MW: 9.1 VIS: 42 RIH TO 389', CIRC BOTTOMS UP, CEMENT NOT SET. WOC. RIH TO 414', CEMENT NOT SET. WOC. RIH TO 500', CIRC OUT CEMENT AND CONDITION MUD. TOH, RIB W/ DRILL PIPE TO 480'. RU DOWELL, PUMP 30 BBLS LIME WATER (10 SX) AND 530 SX AS I. CIP 2245 HRS, 8/17/88. TOH, FLUSH LINES AND DIVERTER. WOC. DAILY:S66,465 CUM:$263,526 ETD:S263,526 EFC:$1,455,000 '5) NAVIDRILLING @ 490' MW: 8.8 VIS: 46 CONTINUE WOC. MU BHA, RIH TO 143', CEMENT STILL SOFT. WOC. RIH AND TAG CMT @ 242'. DRESS PLUG TO 267'. CEMENT HOLDING 20,000~ WEIGHT W/ 1000 PSI. TOH. MU NAVIDRILL AND ARIENT. TIH. NAVIDRILL 267'-490' MAKING NEW KICKOFF. DAILY:S52,400 CUM:$315,926 ETD:S315,926 EFC:$1,455,000 The above is correct For form preparation/~'d"d~s'tri-bution, see Procedures Mar/Val, Section 10, JDat. lO'5'BZ5 J'~itle ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforaling, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit '*Interim" sheets when filled out but not less frequently Ihan every 30 days, or (2) on Wednesday of lhe week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish [StateAK . NORTH SLOPE Lease or Unit 30--2 Field ARCO Alaska, Inc. KUPARUK RIVER UNIT IWell no. Date and deptl~ as of 8:00 a.m. 08/20/88 ( TD: 3448'( SUPV:DL 08/21/88 ( TD: 5950'( SUPV:DL 08/22/88 ( TD: 5950'( SUPV:DL 08/23/88 ( TD: 7658'( SUPV:DL 08/24/88 ( TD: 8865'( SUPV:DL 08/25/88 ( TD: 9917'( SUPV:EEV 08/26/88 ( 1 TD: 9937' ( SUPV: EEV The above is correct Complete record for each day while drilling or workover in progress DOYON 14 7) 2958) 8) 502) DRILLING MW: 9.8 VIS:110 NAVIDRILL NEW KICKOFF 490'-2397'. DROP SINGLE SHOT AND TOH, CHANGE BHA, RIH. DRILL AND SURVEY 2397'-3448'. DAILY:S56,775 CUM:$372,701 ETD:S372,701 EFC:$1,455,000 o) RIH TO WORK TIGHT HOLE MW: 9.6 VIS: 96 DRILL AND SURVEY 3448'-5950'. CIRC AND CONDITION WELL, DROP SURVEY, TOH. HOLE TIGHT @ 750'. WORK THROUGH TIGHT HOLE 750'-500'. CHANGE OUT BHA AND RIH. DAILY:S45,524 CUM:$418,225 ETD:S418,225 EFC:$1,455,000 o) 1708) ND DIVERTER 9-5/8"@ 5930' MW: 9.8 VIS: 46 RIH SLOW, HIT TIGHT SPOT @ 2070'. REAM AND WASH 2070'-2573'. FINISH TIH. CIRC AND CONDITION WELL AND TOH. RU AND RUN 153 JTS 9-5/8", 36#, J-55 BUTT CASING. SHOE @ 5930', COLLAR @ 5850'. RU DOWELL AND CIRC AND CONDITION WELL. CEMENT W/ 80 BBL FRESH WATER, 1400 SX AS III AND 400 SX CLASS G. DISPLACE W/452 BBL FRESH WATER, LOST RETURNS AFTER 224 BBL. BUMPED PLUG W/ 2500 PSI OK. FLOATS HELD OK. CIP 0345 HRS, 8/22/88. RD DOWELL AND ND DIVERTER. DAILY:S237,133 CUM:$655,358 ETD:S655,358 EFC:$1,455,000 07) DRILLING 9-5/8"@ 5930' MW: 9.1 VIS: 30 PERFORM TOP JOB W/ 100 SX AS I. NU SPEED HEAD AND BOPE. TEST BOPE TO 3000 PSI. PU BHA, LOAD MWD SOURCE, ORIENT MWD, TIH, TAG FLOAT COLLAR @ 5851'. TEST CASING TO 2000 PSI, OK. DRILL OUT TO 5960' AND PERFORM LEAK OFF TEST TO 12.5 EMW. NO LEAK OFF. DRILL AND SURVEY 5960'-7658' DAILY:S49,763 CUM:$705,121 ETD:S705,121 EFC:$1,455,000 2) )52) DRILLING 9-5/8"@ 5930' MW: 9.1 VIS: 35 DRILL AND SURVEY 7658'-8165'. TOH, CHANGE BIT, DOWNLOAD MWD, CHANGE OUT TURBINE TIH AND DRILL 8165'-8324'. REPAIR BROKEN COUPLER. DRILL 8324'-8675'. REPAIR MUD LINE FLANGE UNDER RIG. DRILL 8675'-8865'. DAILY:S62,298 CUM:$767,419 ETD:S767,419 EFC:$1,455,000 Signature . ~ For form preparation e~distrJbution ~~ ,De~ i ~nr~.c ~da~ r:: 81~ a:nUd~8~ e c,, o n 10. TOH FOR BIT 9-5/8"@ 5930' MW:10.0 VIS: 51 DRILL AND SURVEY 8865'-9917'. PENETRATION RATE SLOWED. CIRC BOTTOMS UP AND TOH DOWN LOAD LOGGING DATA AND STAND BACK BHA. DAILY:S54,048 CUM: $821,467 ETD:S821, 467 EFC:$1,455,000 3) DRILLING 9-5/8"@ 5930' MW:10.0 VIS: 48 20) FINISH LOADING LOGGING TOOL AND TIH. CUT DRILL LINE AT SHOE AND FINISH IN HOLE. WASH TO 9900', HOLE PACKED OFF, PULL AND PUMP OUT OF HOLE TO 9518', CIRC BOTTOMS UP. ATTEMPT TO WASH TO BOTTOM, HOtE PACKING OFF. TOH, LD TURBINE, MU NEW BHA. IDate ]Title /O-'5-E~ AssOQIATE ENGIN_FER ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Le~aseCOUnty or Parish [~tateAK ._ NORTH SLOPE 30-2 ARCO Alaska, Inc. KUPARUK RIVER UNIT IWell no. Date and depth as of 8:00 a.m. 08/27/88 ( TD:10380' ( SUPV:EEV 08/28/88 ( TD:10420'( SUPV:EEV 08/29/88 ( TD:10420 PB: SUPV:EEV Complete record for each day while drilling or workover in progress DOYON 14 ) 43) 5) 40) TIH, WASH AND REAM 9494'-9917'. DRILL 9917'-9937'. DAILY: $47,581 CUM: $869,048 ETD :$869,048 EFC:$1, 455, 000 POH TO LOG 9-5/8"@ 5930' MW:10.0 VIS: 43 WORK THROUGH TIGHT SPOT @ 9920' DRILL AND SURVEY 9937'-10032'. MAKE 10 STAND SHORT TRIP, CIRC AND CONDITION WELL, DROP SURVEY, SPOT PILL AND TOH TO LOG. DAILY:S42,432 CUM:$911,480 ETD:S911,480 EFC:$1,455,000 CIRCULATE FOR CASING 9-5/8"@ 5930' MW:10.0 VIS: 43 FINISH TOH, RETRIEVE MWD DATA. RU SCHLUMBERGER AND LOG W/ TRIPLE COMBO 10363'-5932'. PU SWC GUN. HAD 2 GR FAILURES. LAST RUN UNABLE TO GET BELOW 7000'. SHOT 20 SWC, RECOVERED 20 SWC. MU BHA AND RIH. REAM 40' TO BOTTOM AND DRILL RAT HOLE 10380'-10420'. CIRC BOTTOMS UP AT REPORT TIME. DAILY:S105,246 CUM:$1,016,726 ETD:S1,016,726 EFC:$1,455,000 CEMENTING 7" CASING 7"@10392' MW:10.0 WBM FINISH CIRC AND CONDITION WELL. SPOT PILL AND TOH LDDP. RU AND RUN 40 JTS CASING. MUD IN PITS CUT TO 9.2 DUE TO OVERRUNNING INJECTION PIT WITH WATER. LOWERED VOLUME AND WEIGHT UP TO 10.0 PPG. CONTINUE IN HOLE WITH 260 JTS 7", 26#, J-55, BUTT CASING. SHOE DEPTH 10392'. RU DOWELL AND CIRC AND CONDITION WELL. RECIPROCATE PIPE. TEST LINES TO 4000 PSI AND BEGIN PUMPING SPACERS. DAILY:S165,141 CUM:$1,181,867 ETD:Si,IS1,867 EFC:$1,455,000 The above is correct Sign atu re //,q L/, I Date For form preparation and/lilistribution see Procedures Manual ~3i/ction 10, Drilling, Pages 86 and 8~ __~Title ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District lng cost center code l Countyor Parish [~tate~ ARCO Alask_~a Inc. ~ NORTH SLOPE T Lease ~rr Uni--'~'~ Well no. KUPARUK RIVER UNIT ADL: 25513 30-2 ~ DRILL Field Auth. or W.O. no. AK2947 Operator ~ W.I. ARCO 56.0000 Spudded or W.O. begun ]Date SPUD I 08/14/88 Date and depth as of 8:00 a.m. Old TD Released rig 08/30/88 ( 1 TD:10420 PB:10309 SUPV:EEV Classifications (oil, gas, etc.) C"~'~-plete record for each day reported DOYON 14 API: 50-029-21837 nOtal number of wells (active or inactive) on thist ost center prior to plugging and donmen_...~t of th..__~is well r~--r- status ~ ~ w,o. 0100 HRS Producing method Potential test data Well no, [Date P--'~"~-p size, SPM X length The above is correct RIG RELEASED 7"@10392' MW:10.0 NACL CEMENT WELL W/315 SX CLASS G W/ 3.0% KCL, 0.9% D-127, 0.3% D-13, 0.2% D-46. DISPLACED WITH 496 BBL 10.0 PPG BRINE. BUMPED PLUG W/ 3500 PSI, FLOATS HELD OK. CIP 0740 HRS, 8/29/88. RD DOWELL, ND BOPE, BLOW 120' BRINE FROM CASING, SET SLIPS AND CUT OFF CASING. SET PACKOFF AND NU TUBING HEAD. TEST TO 3000 PSI OK. FREEZE PROTECTED ANNULUS AND RELEASE RIG 1230 HRS, 8/29/88. DAILY:S100,501 CUM:$1,282,368 ETD:S1,282,368 EFC:$1,455,000 D~ae~eTM Reservoir Producing Interval size PB Depth Signature ~ I~r fnrm nr~n~rmtin~. Kind of rig Water % completion (single, dual, etc.) i~ ~ name(s) t i me c t ett't't't't't't't't'~y d Production Oil on test Allowable Gas per day '~ective date Iitle ASSOCIATE ENGINEER ARCO Alaska, Inc. Date: September 21, 1988 Transmittal #: 7289 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATOol 119 P.O. Box 100360 Anchorage, AK. 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-03 OH LIS Tape and Listing 9- 1 3-88 #72926 OH LIS Tape and Listing 9 - 1 0 - 8 8 # 7 2 9 0 2 dm,:;a 011 & Gas Cons. Comrniss]o~ Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: September 21, 1988 Transmittal #: 7287 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. "30-2 '30-2 ' 30-2 '30-2 __ ,,~ 30-2 "~- *~'3-0"- 3 - e30-3 '30-3 e30-3 ,30-3 2" Dual Induction 8 - 2 7 - 8 8 5 93 2 - 1 0363 5" Dual Induction 8 - 2 7 - 8 8 5 93 2 - 1 0363 2" & 5" Raw FDC 8-27-88 9395-1 0334 2" & 5" Porosity FDC 8 - 2 7 - 8 8 93 95 - 1 033 4 Cyberlook 8 - 2 7 - 8 8 2" Dual Induction I 0 - 6 - 8 8 51 4 9 - 91 3 6 5" Dual .Induction I 0 - 6 - 88 5149 - 9136 2" & 5" Raw FDC 1 0-6-88 8300-9113 2" & 5" Porosity FDC I 0 - 6 - 88 8300 - 9113 Cyberlook I 0 - 6 - 88 Receipt Acknowledged: Oil & Gas Cons. Commi",:~: ........................... Date: ............ DISTRIBUTION; NSK Drilling Franzen D&M State of Alaska(+sepia) -M-EMORANDuM State of. Alaska Lonnte C. Smith.' ":'"" DATE: Au~r~s~ 18~ 1988 ' ~ Commissioner ~,,~ ~o: D. BDF. 015 THRU: Michael Sr. PetroleUm Engineer FROM: Petroleum Inspector TELEPHONE NO: SUBJECT.' Diverter Test AAI KRU 30-2 Pemit No. 88-74 Kuparuk Rv Field Saturday, A.u~st 13, 1988: The Diverter Inspection and Function Test began' a~'"lO:30' p.m. and was concluded at 11:30 p.m. This Diverter system is acceptable after changes requested by Harold Hawkins during a pervious inspection were made.' All turns are now 90" using target- ed T's and vent lines, venting in two directions 100 feet from any pont of ignition. This systeTM meets AOGCC Regulations with the exception of the Extra 10" line which was approved by the Commission. ~, Attachment 02-001A (Rev. 8~85) . _I~ector Weil C, .. .3_, _ Dr i ! 1 i n~_.C o n t t, gc~ t ion, Come:al ~ ' l Well Gemerhl Hbusekeeping_ ~I J I Rig .. Reserve Pit ~Jud_q_d_~$tems Visual Trip Tank Pit Cause FiSw Monitor Gas Detectors STATE OF ALASKA ALASKA OIL & CAS CONSERVATION CO.~4]SSION . B.O.P.E. Inspection Report ... ,.. __ z---- Full Charge Pressure ~000 PSiS Pressure After Closure~. ~.~ psis Audio Pump ~ncr cios pres. 200 psis min~- sec. Full Charge Pressure -- Controls: Master V~'~ ~~ ~ "Reaote ~.f'~' Blinds switch cover Kelly and FlOor Safe:% Valves Pressure. ~O~ , essure Pressure '? r,,r~ ^, Pressure Test Pressure Inspector/ BOPE Stack ~ T_es.__~t P~'__~e.~su__[e Opper .Annular Preventer__k__~__ .~OfO© Lower Kelly___~____Te s t P~pe Rams ~ ~C300 Ball. Type ~ Test Blind Ram~~__ ~00~ Inside BOP ~ Test 'ChOke Line Valves~_ ~O~ . Choke Manifold M,CR .. I1__ QO_O ..... Check Valve ~ Adjustable Chokes ,drauically operated choke Test Results: ~ailures ~--~ Test T~e !~/~ hrs. Repair or Replacement of failed equipm~nt to-be mode w~thln days and Cmmissiom office notified. Distribution cc - Operator cc - Supervisor July 18, 1988 Telecopy: (907)276-7542 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 30- 2 ARCO Alaska, Inc. Permit No. 88-74 Sur. Loc. 745'FNL, 1855'FWL, Sec. 22, T13N, R9E, UM. Btmhole Loc. 1899'F~, 949'FWL, Sec. 16, T13N, R9E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to comencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to con~mencing installation of the blowout prevention equipment so that a representative'of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very ~.trul4~, yours t "~"~ ' -- ,'"'~ ' ~ i' , :' / /.':/.' .// .5>` ChaPman of Alaska Oil and gas gonservatlon Comisston BY ORDER OF THE COF~fISSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ---- STATE OF ALASKA ALASKA L.,_ AND GAS CONSERVATION CO,.,~VllSSION PERMIT TO DRILL 2O AAC 25.005 I la. Type of work Drill [] Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenF11 Service [] Developement Gas [] Single Zone L~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 59' , PAD 24'GL feet Kuparuk River Field 3. Address 6. Property Decsignation Kuparuk River Oi 1 Po P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25513 ALK 2554 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 745'FNL,1855'FWL,Sec.22,T13N,R9E,UM Kuparuk River Unit Statewide At top of productive interval(~ target) 8. Well nu.mber Number 2027'FNL,1141 ' FWL,Sec. 16,T13N,R9E,UM 30-2 #8088-26-27 At total depth 9. Approximate spud date Amount 1899 ' FNL,949 ' FWL,Sec. I 6,T1 3N ,R9E,UM 08/09/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line DS 30-1 10383 'MD 949 ' ~ TD feet 25 ' @ surface feet 2560 671 6 ' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 400 feet Maximum hole angle 540 Maximum surface 2391 psig At total depth (TVD) 31 70 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80 35 35' 115 115' +200 # cf 12-1/4" 9-5/8" 36.0# J-55 BTC 5757 35 35' 5792 4039' 1400 sx AS Ill & k-bNIA 400 sx Class G 8-1/2" 7" 26.0# J-55 BTC 10349 34 34' 10383 6716' 100 sx 50/50 Poz Lea F-ER~ 200 sx Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations.~up ,-u'T"°'l~a°-'f'kG 500' above Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing ,. · -,... Length Size Cemented Measured depth True Vertical depth Structural RECEIVED Conductor Surface IntermediateJLIN 2 7 J988 Production Alaska Oil & Gas Cons. Commission Liner Anchorage Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [~ BOP Sketch [] Diverter Sketch I~ Drilling program [~ Drilling fluid program [] Timevs depth plot [] Refraction analysis [] Seabed report [] 20AAC25.050 requirements 21. I hereby certify that the f~regoing is true and correct to the best of my knowledge Signed ~.~ ~.,)~~'"'¢~,,~64,42kTitle\ I~egional I')r'iilln0 Fnnin~r Date ~-'¢/~,~/~ [} ' Commission Use Only~_¢~,,m (TEM) PD3/006 (~JSx/ ' Permit Number I AP[ number I Approval daze I See cover letter Ra-"z'~ I50-O¢--5~'- 2-'18-0'7'''~ I 07/18/88I for other requirements Conditions of approval Samples required [] Yes ,~ No Mud Icg required ~ Yes ~ No Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes [] No R equiredwork~,~~~E~ 10M; F1 15M Other: · by order of Approved by (~ ~'~ /. L ~,~'~~1~ Comm,ssioner the commission Date Form 10-401Rev.~2?r-85 t Su triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing .point according to directional plan. 4) Run and Cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to loggihg point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and 'cement 7" casing, Pressure te~,t, to 3500 psig. 11) DownsqueeZe Arctic pack'and cement in x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. MUD CLEANER RECEIVED Jt~lN 2 7 1988 Alaska Oil & Gas (ions. Commission Anchorage SHALE STI STIR STIR SHAKERS MUD CLEANER CENTRIFUGE TYPICAL MUD SYSTEM 'SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weigh~. ,Up 9.6-9.8 8.7-9.2 Weigh, t Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 " 5-12 Filtrate AP1 20 10-20 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators RECEIVED J[IN 2 7 ]988 Alaska Oil & Gas Cons. Commission Anchorage Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur · before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. ucr,5 / ih RIVER UNIT 20' DIVERTER SCHEHATIC L 1. 2. FI"C SLIP-4~ ~ $'r'~qTIl~ ~ 3. Fl'lC: OlVE.qTER AS~BLY MT'I4 ~ :2-1116' 200Q I)SI 8ALL VALVES 5. 10' HCa 8ALL VALV~V/IO' ~ UI4S. A SINGLE VAI, V~ ~ &UTCI"IA~¥ ~ I~l"lO~Y Ct3~IiIIJ, JD TO ~ DIVFJ~ICIL 6. 20'20001~1 Nell,,Alllgl~lfrl~ ... 4 ARCO ALA~, INC.. I:IEGI.IEST~ APt:lg0V,t. OF THIS DIVER~ SY~I'EI'I AS A VARIANCE Fl~0r'l 20AAC2"J.03~) I"IAI NTENANCE & OPERATION RECEIVED I UPON INITIAL ~NSTALLATI(~, C:LOSF,, PI:~rVENTER vERIFY TI~T VALVE 2. CLOSE ANNULAR ~[NTER ANO ~1,0~ AIR T'HR(XIG DIVERTEI~ LINES EVERY 12 I'101.I~. 3. CLOSE ANNULAR PI~VENI'LrR IN THE EVENT THAT iNFLUX OF WELLB01~ FLUIDS ~ GAS IS DETECTED. OPEN APPI~0PRIATE VALVE TO ACHIEVE DIVERSION. JUN 2 7 Ifi,~8 'Alaska. 0il & Gas Oons. Commissi, DO NOT SHUT I N WELL_ '. Anchorage UNDER ANY CIRCU~STAN££-q · 7 6 5 4 DIAGRAM #1 13.5/8' 5000 PSI RSRRA BOP STACK I. 16' - 21300 PcJI T1¥4(C0 S'I'NtTII~ I1' - 3000 PSI C~II~ I-E~ 4. 1~5/8' - KILL & 1~/8' - ~ ~I ~E ~~I~ ~~ T~, ACO. MJLATCR CAPACITY TEST I. Q-ECK ~ FILL ~TCR RESERVOIR TO PR(I~R LEVEL WITH HYDRALLIC FLUID. 2. ~ THAT AC~TCR PRESStI1E IS 3IXIO PSI WITH 1500 PS! ~TREAM ~ THE RE(t.I. ATOR. 3. CBSER~ TIb~_. THEN CL~[ NJ.. IJNITS SII~I. TAI~CUSLY AN3 REO3RD ]]-E TI~ AN3 Pfa~SSIJRE RE34~ININS AFTER ALL LIMITS ARE CL~ WITH CHARGING ~ CFF. 4. RECIJIID CN ~ REPORT, THE ACt:SJ~NN.E LO/~t LIMIT IS 45 SE~ CLCSING TII~ ~ 1200 PSI REI~INING L d 2 13--5/8" BOP STACK TEST I, F!LL BI~ STAQ( ~ CI-1[3(E I~N~FCLD WITH ARCT!C DIESEL. 2. CI..ECX THAT ALL LOCI( ~ S13~ IN N~LLi..EAD ARE FLLLY RETRACTED, SEAT TEST PLUG IN ~.LL~ WITH RLI~iINS JT ~ ~ IN L(X3(EX3W~ 3, CLOSE ~ PI~:'VENTER AhO ~ KILL AhD LIHE VALVES ADJACENT TO BC~ STACK, ALL O'TI..ER vALVES ~ Q. IO<ES SHa. I.D BE 4. P~ESSI. I~ UP TO 250 PSI ~ HOLD FCIt I0 MIN. IN.- CREA,~ F~ESSI,RE TO 31300 PSI AI~ H~LD FOR I0 MIN. BLEED P~~ TO 0 PSI. 5. CPEN AN~LLN~ PRE~NTE~ AhD ~ KILL AN3 O. K3<E LIHE VALVES CLCI~ TCP PIPE ~ ~ HCR VALV~ CN KILL. AI~ CHCKE LIltS, 6. TEST TO 250 PSI /~D 3030 PSI AS IN STEP 4. 7. CCNTINJE TESTINS ALL VALVES, LIHES,, ~ Q-ICKES WITH A ~ F~I LOW AI~ 31XIO P~31 HIt3.1. TEST AS IN STEP 4. DO M3T PRF~aI~E TF~q'r ANY ~ THAT IS h[JT A FULL CLOSING PI~ITIVE SEAL O-lCKE. CN.Y FI..I~II[J~I 11151- Q.4J(E$ Il-IAI DO MJI FULLY CLOSE. 8. ~ TCP PIPE RN~ N~ CLOSE 80T'r(~ PIPE RAIDS. TEST BOTTCM PIPE RNvB TO 250 PSI ~ 30IX) PSI. 9. OREN BOTTOM PIPE R.Nffi, BACK OUT RI,N~NG JT AI~ I0. CLOSE BLII~ ~ ,N~ TEST TO 250 PSI MM) 30(10 PSI. IdN~IFQ..D N~ LIliES N~ FI.I.L Q:' hi(IN-FREEZING FLUID. SET ALL VALVES IN 12RILLING I::~SITICI~. 12. TEST S'I'AM~IPE VALVE',',',~ KELLY, KELLY' COQ(S, ERILL PIPE S~ETY VALVE, /k~ II~IDE BOP TO 250 PSI tREC(3~ TEST IWCRI~TION CN BLON:I.rT PREVENTER TEST FOR~ S]~ ~) see ~o mZLLZNG SUPERVZ~. JUN 2 7 1988v~EKI''Y TI-I-'IIEAFTER FLI~TICIqAU. Y OPERATE ~ I~ILY. AlaSka Oil' & Gas Cons. Commission Anci~oracja 51 OO84O0 ARCO ALASKA, Inc. ' Pad ~0. I,/ell Not 2 Propoeed Kuperulc Field. North Slope. Alaeke 1000 2000 'T RKB. ELEYATtON, 59' KOP' TVD'400 TIID'400 DEP'O 3 9 t5 2?' BUILD 3 DE;G: PER 1 oo FT B/ PERHAFROST TVD-1719 THD-1856 DEP'529 SI EOC TVD-Ig52 THO-2211 DEP-?96 3000 4000 iT/ UGNU SNDS TVD-2679 TffD-3459 DEP-1810 T/ W SAK SNDS TVD-3459 THD-4797 DEP-2897 K-12 TVD-3839 THD-5449 DEP-3427 9 5/8' CSG PT TVD-4039 THD-5792 DEP-3705 5000 AVERAGE ANGLE 54 DEG 20 MI N 6000 7O00 1000 K-5 TVD-$809 TMD-8828 DEP-6172 T/ ZONE D TVD-6459 TMD-gg43 DEP-7078 T/ ZONE C TVD-6486 TMD-gg8g DEP-7116 T/ ZONE A TVD-6501 TMD-10015 DEP-7137 TARGET CNTR TVD-6550 THD-lO099 DEP-?205 B/ KUP SNDS TVD=6599 TMD-I0183 DEP-?273 TD (LOG PT) TVD-6716 TMD-10383 DEP-?436 I I I I I I v~.,~c^, s~c,~o. R E C E IV JUN 2 7 1988 Alaska Oil & Gas Cons. Commission ^nchorage I 8000 I Z 0 N T ^L SCALE 1 IN. PROJECT I O-,N I 1000 FEET ARCO ALASKAo ! no. Pad 30, In/ell No, 2 Kuperuk Field. North Propoeed Slope, Ale.ke 5000 4000 3000 2OOO 1000 1000 7'000 6000 $000 I I TARGET CENTER TVD-6550 TI'ID- 10099 DEP-?205 NORTH 3998 WEST 5994, TARGET LOCATION, 2027'' FNL. 1141 ' FWL b'EC. 18. T13N. RgE NEST-EAST 40OO 3000 I I TD LOCATION, 1899' FNL, 949' FWI.. SEC. 16. TI3N, RgE N 56 DEG 18 MI N W 7205' (TO TARGET) 2000 1 000 0 I I I SURFACE LOCAT [ ON ' 7'45' FNL, 1855' ~ SEC;. 22, T13N, RgE RECEIVED JLIN 2 7 I988 AI~sk~ Oit & Gas Cons. Commission Ancl~orage 1 850 I I I 65Q .... 750 1 800 1 900 1 900 2000 __ ~ ~ ~oo I \ I I ! \ I 1500 I / ~1 900 I \ I & / +soo I 1[1 O0 2O5O I ~~ ~'~ZO0 I ~ / I 700._ . I / I -' '"'a,oo \\ ___ ~/t/300" I ~ '~?Ou I --.oo / oo , '"'q r~"09.. 1,4 O0 ! ZOo! I ·~oo ~oo ' /"~oo '~ LSO0 I 800 I ~ ' !. 9oo ~' %-t 500 i 41 O0 / ~'2500 300 I I ~,I soo ~."'~oo .~o I -~.oo I [~oo I 900 * ~ - - I 950 I JUN I ,Ai~s~A 0[[ & Gas Gons. Commission I 1000 ' m m m m m -- m m m m m m m m 1750 1 800 1 850 1 900 1 950 2000 2050 60( _ 65( 701 75 I _ 80 CHECK LIST FOR NEW WELL PERMITS Company ,~/~fiO Lease & Well No. ITEM APPROVE DATE YES NO (1) Fee. u~~' ~"7~9f~, 1. Is the permit fee attached .......................................... ~3-- -- REMARKS (2 thru 8) (8) (]) 9 thru 13) 10. (10 and 13) 12. 13. (4) C as g /~.~, ./~, z./_O.,~.,.~j:.ff (14 thru 22) (23 thru 28) 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. ~ 4. Is well located proper distance from other wells .................... ~_ 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ z~ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~__ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... /~ Is the drilling fluid program schematic and list of equipment adequate/~ Are necessary diagrams and descriptions of diverter and BOPE attached.,~ Does BOPE have sufficient pressure rating - Test to ~oo psig .. ,~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (29 thru 31) (6) Add: For exploratory and Stratigraphic wells: ../ ~J~ 29. Are data presented on potential overpressure zones? ............... 30. Are seismic analysis data presented on shallow gas zones ....... ~... 31. If an offshore loc., are survey results of seabed conditions p~sented / 32. Additional requirements ............................................. 0 ~Z Geolo~ EngSngering: :/% rev: 02/17/88 6.01'1 INITIAL GEO. UNIT ON / OFF POOL CLASS STATUS AREA NO. SHORE ~9 ¢~ coo Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ .. No Special'effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * * SCHLUMBERGER * , , COMPANY NAME : ARCO ALASKA INC. WELL NAME : 3 0-2 FIELD NAME : KUPARUK BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-21837-00 REFERENCE NO : 94291 LIS Tape Verification Listing Schtumoerger Alaska Computing Center 30-AUG-1994 08'30 **** REEL HEADER **** SERVICE NAME ' ED~ DATE · 88 9/12 ORIGIN : FLIC REEL NAME : 72902 CONTINUATION # : PREVIOUS REEL : COMMENT : LIS TAPE, ARCO KUPARUK 3 0-2, API #50-029-21837 **** TAPE HEADER SERVICE NAME ' ED%T DATE · 88/09/12 ORIGIN : FLIC TAPE NAME : 72902 CONTINUATION # : PREVIOUS TAPE : COMMENT : LIS TAPE, ARCO KUPARUK 3 0-2, API #50-029-21837 PAGE' **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · 00}A0~ DATE · 88 09 12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE ARCO ALASKA INC. 3 O-2 KUPARUK ALASKA NORTH SLOPE U.S.A. 50-029-21 837-00 2 13N 9E 745' FNL & 1855'FWL ONE MSL 59. RKB 59. 58. 24. 10381. 10366. 10313. 8 1 2' 103 1. · Company Name · Well Name · Field Name · State · Bo7ough · Nation ·API Number · Section Township Range Location Run Number · Permanent Datum Above Permanent Datum Log Measured From · KB Elevation DF Elevation GL Elevation · TD Driller · TD Logger . Bottom Loq Interval · Bit Size 1 Bit Size Depth 1 LIS Taupe Verification Listing Schlumb~erger Alaska Computing Center 30-AUG-1994 08'30 9 5/8" 5930,. 5932. LSND POLY 10. 8.5 4.4 43. 4.63 70. 4.91 64. 3.19 64. PRUDHOE BAY 1 040 27AUG 145. MALLAEY LOWEN/SWENSON / MCGIMSEY 1 .5" STANDOFFS ON DIL SONDE MDEN=2.65, MATRIX=SAND, BHC=OPEN, HC=CALIPER DIS 1114 DIC 1 422 SET 33 CNC 1 238 SGC 2626 27-AUG-88 9-SEP-88 72902 J. KOHRING Casing Size 1 · Casing Driller CasiQg Logger_ · Drilling Fluid Type Drilling Fluid Density · Drilling Fluid PH Drilling Fluid Loss Dr%lling Fluid Viscosity Mud Resistivity Mud Sample. Temp Mud Filtrate Resistivity · Mud Filtrate Sgmple Temp · Mud Cake ResisEivity · Mud Cake Sample Temp Logging District Time Loqger On Bottom · Bottom ~ole Temp · Logging Engineer · Witness Field Remarks Tool Numbers Log Date Dale Job Started Job Reference Number LDP/Analyst ******************************************************************************* ***** THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS ***** * SCHLUMBERGER LOGS INCLUDED WITH THIS FILE (EDIT.001)' * * <SEE FILE EDIT.002 FOR 1.2" SAMPLED FDC/CNL DATA> * * DUAL INDUCTION SPHERICALLY FOCUSED LOG (.Dim) * * FIRST TO LAST READING· 10363' TO 5932' * * FORMATION DENSITY COMPENSATED LOG (.FDC) * * FIRST TO LAST READING' 10334' TO 5932' * * COMPENSATED NEUTRON LOG (.CNL) * * FIRST TO LAST READING' 10320' TO 5932' * * GAMMA RAY IN CASING (.CHL) * * FIRST TO LAST READING' 5932' TO 940' * PAGE' LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-AUG-1994 08:30 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS ( HEX ) DEPT FT 530801 00 000 00 0 1 1 1 4 68 TENS DIL LB 530801 00 000 00 0 1 1 1 4 68 SFLU DIL OHMM 530801 00 000 00 0 1 1 1 4 68 ILM DIL OHMM 530801 00 000 00 0 1 1 1 4 68 ILD DIL OHMM 530801 00 000 00 0 1 1 1 4 68 SP DIL MV 530801 00 000 00 0 1 1 1 4 68 GR DIL GAPI 530801 00 000 00 0 1 1 1 4 68 TENS FDC LB 530801 00 000 00 0 1 1 1 4 68 DPHI FDC PU 530801 00 000 00 0 1 1 1 4 68 DRHO FDC G[C3 530801 00 000 00 0 1 1 1 4 68 RHOB FDC G/C3 530801 00 000 00 0 1 1 1 4 68 CALI FDC IN 530801 00 000 00 0 1 1 1 4 68 GR FDC GAPI 530801 00 000 00 0 1 1 1 4 68 TENS CNL LB 530801 00 000 00 0 1 1 1 4 68 NPHI CNL PU 530801 00 000 00 0 1 1 1 4 68 TNRA CNL 530801 00 000 00 0 1 1 1 4 68 RTNR CNL 530801 00 000 00 0 1 1 1 4 68 RCFT CNL CPS 530801 00 000 00 0 1 1 1 4 68 RCNT CNL CPS 530801 00 000 00 0 1 1 1 4 68 CFTC CNL CPS 530801 00 000 00 0 1 1 1 4 68 CNTC CNL CPS 530801 00 000 00 0 1 1 1 4 68 GR CNL GAPI 530801 00 000 00 0 1 1 1 4 68 TENS CHL LB 530801 00 000 00 0 1 1 1 4 68 GR CHL GAPI 530801 00 000 00 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS TaDe Verification Listing Schlumberger Alaska Computing Center 30-AUG-1994 08:30 PAGE: DATA DEPT. 10403.000 TENS.DIL ILD.DIL 3.834 SP.DIL DPHI.FDC 3.537 DRHO.FDC GR.FDC 95.750 TENS.CNL RTNR.CNL 3.698 RCFT.CNL CNTC.CNL 2025.051 GR.CNL 2680.000 SFLU.DIL -19.000 GR.DIL 0.136 RHOB.FDC 2680.000 NPHI.CNL 527.381 RCNT.CNL 95.750 TENS.CHL DEPT. 939.500 TENS.DIL -999.250 SFLU.DIL ILD.DIL -999.250 SP.DIL -999.250 GR.DIL DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FDC GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 4.444 95.750 2.592 42.561 1977.707 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1310.000 ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL 4.076 2680.000 8.094 3.431 600.235 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 43.375 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 ,. SERVICE : FLIC VERSION · 001A~ DATE '88~ 12 MAX REC SIZE ' 10 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .002 SERVICE : FLIC VERSION ' 001A0~ DATE ' 88/09 12 MAX REC SIZE · 1024 FILE TYPE : LO LAST FILE : ******************************************************************************* ***** THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS ***** ******************************************************************************* LIS Tape Verification List%ng Schlumberger Alaska Computing Center 30-AUG-1994 08:30 PAGE: * SCHLUMBERGER LOGS INCLUDED WITH THIS FILE (E~IT.002)' * <SEE FILE EDIT.001 FOR 6" SAMPLED DIL/FDC/CNL/GR DATA> * FORMATION DENSITY COMPENSATED LOG (.FDH) * FIRST TO LAST READING' 10334' TO 9397' * COMPENSATED NEUTRON LOG (.CNH) * FIRST TO LAST READING: 10320' TO 9397' ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.099 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS ( HEX ) DEPT FT 530801 00 000 00 0 2 1 1 4 68 TENS FDH LB 530801 00 000 00 0 2 1 1 4 68 DPHI FDH PU 530801 00 000 00 0 2 1 1 4 68 DRHO FDH G~C3 530801 00 000 00 0 2 1 1 4 68 RHOB FDH G/C3 530801 00 000 00 0 2 1 1 4 68 CALI FDH IN 530801 00 000 00 0 2 1 1 4 68 GR FDH GAPI 530801 00 000 00 0 2 1 1 4 68 TENS CNH LB 530801 00 000 00 0 2 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS TaDe Verification Listing Schlumberger Alaska Computing Center 30-AUG-1994 08:30 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS ( HEX ) NPHI CNH PU 530801 00 000 00 0 2 ] ] 4 68 TNRA CNH 530801 00 000 00 0 2 1 1 4 68 RTNR~CNH 53080] 00 000 00 0 2 1 1 4 68 RCFT CNH CPS 530801 00 000 00 0 2 1 1 4 68 RCNT CNH CPS 53080] 00 000 00 0 2 1 1 4 68 CFTC CNH CPS 530801 00 000 00 0 2 1 1 4 68 CNTC CNH CPS 530801 00 000 00 0 2 1 1 4 68 GR CNH GAPI 530801 00 000 00 0 2 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DATA ** DEPT. 10407.000 TENS.FDH 4688.000 DPHI.FDH 16.238 RHOB.FDH 2.382 CALI.FDH 8.000 GR.FDH 97.750 NPHI.CNH 38.586 TNRA.CNH 3.099 RTNR.CNH 3.339 RCNT.CNH 2003.490 CFTC.CNH 673.669 CNTC.CNH 2051.452 DEPT. 9397.199 TENS.FDH 6172.000 DPHI.FDH 18.651 RNOB.FDH 2.342 CALI.FDH 11.031 GR.FDH 130.250 NPHI.CNH 40.282 TNRA.CNH 3.529 RTNR.CNH 3.963 RCNT.CNH 1924.277 CFTC.CNH 557.947 CNTC.CNH 1930.938 ** END OF DATA DRHO.FDH TENS.CNH RCFT.CNH GR.CNH DRHO.FDH TENS.CNH RCFT. CNH GR.CNH -. 0.231 4688.000 591 .903 97.750 -0.013 6172.000 511 .551 130.250 **** FILE TRAILER FILE NAME : EDIT .002 SERVICE : FLIC VERSION ' 001A0~ DATE ' 88~9 12 MAX REC SIZE ' 10 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME · EDIT DATE ' 88/09/12 ORIGIN : FLIC TAPE NAME : 72902 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : LIS TAPE, ARCO KUPARUK 3 0-2, API #50-029-21 837 ~IS TaDe Verification Listing ~chlumberger Alaska Computing Center 30-AUG-1994 08'30 **** REEL TRAILER **** SERVICE NAME · EDIT DATE · 88/09/1 2 ORIGIN : FLIC REEL NAME : 72902 CONTINUATION # : PREVIOUS REEL : COMMENT : LIS TAPE, ARCO KUPARUK 3 0-2, API #50-029-21837 PAGE' ALASKA COMPUTING CENTER COMPANY NAME : ARCO ALASKA lINC. WELL NAME : 3 0-2 FIELD NAME : KUPARUK STATE : ALASKA :BOROUGH : NORTH SLOPE API NUMBER : 50-029-2:1837-00 REFERENCE NO : i'2902 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA SOMPUTING CENTER 10-SE~-1985 12:17 · ~ REEL HEADER SERVICE NAME : EDIT DaTE : 88/09/10 ORIGIN : ~LIC REEL NAME : 72902 CONTINUATION ~ = PREVIOUS REEL COMMENT : LIS TAPEr ARCO KUPARUK 30-Z~ AP1 ~50-029-21837 ~ TAPE HEADER SERVICE NAME : EDIT DATE : ~8/09/10 ORIGIN : FLIC TAPE NAME = 72902 CONTINUATION # : 1 PREVIOUS TAPE COMMENT : LIS TAPEr ARCO KUPARUK 3 0-2~ API ~50-029-21837 **** FILE HEADER **** FILE NAME . : EDIT .001 SERVICE : FLIC VERSION : O01AO2 DATE : 88/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ARCO ALASKA INC. 3 0-2 KUPARUK ALASKA NORTH SLOPE U.S.A. 50'029-'21 837-00 2 745' FNL & ONE MSL 59. RKB 24. 10381. 10366° 10363. 8 1/2' 10381. COMPANY NAME WELL NAME FIELD NAME S'TATE BOROUGH NATION API NUM~E~ SECTION TOWNSHIP RANGE LOCATION RUN~'NUM~E~ PERMANENT DATUM A~OVE PERMANENT DATUM LOG MEASURED FROM ELEVATION OF ELEVATION GL ELEVATION TO ORILLE~ TO LOGGER BOTTOM LOG INTERVAL BIT SIZE 1 BIT SIZE DEPTH ! IS 'TAPE VERIFICATION LISTING CHLUMBERGER ALASK~ COMPUTING CENTER lO-SEP-19B8 12:17 9 5/8" 5930. LSND POLY 10. 8-5 4.4 43. 4.63 70. 4.91 64. 3o19 64. PRUOHOE BAY 1040 27AUG 145. MALLARY LOWEN/SWENSON/MCGIMSEY 1.5" STANDOFFS ON OIL SONDE MDEN=2.65, MATRIX=SAND, BHC=OPEN, HC=CALIPER DIS 1114 OlC 1422 SET 33 CNC 1238 SGC 2626 27-AUG-B8 9-SEP-B8 72902 Jo KOHRING ! CASING SIZE 1 ! CASING DRILLER ! CASING LOGGER ! DRILLING FLUID TYPE ! DRILLING FLUID DENSITY ! DRILLING FLUID PH ! DRILLING FLUID LOSS ! DRILLING FLUID VISCOSITY ! MUD RESISTIVITY ! MUD SAMPLE TEMP ! MUD FILTRATE RESISTIVITY ! MUD FILTRATE SAMPLE TEMP ! MUD CAKE RESISTIVITY ! MUD CAKE SAMPLE TEMP ! LOGGING DISTRICT ! TIME LOGGER ON BOTTOM ! BOTTOM HOLE TEMP ! LOGGING ENGINEER ! WITNESS ! FIELD REMARKS TOOL NUMBERS LOG DATE DATE JOB STARTED JOB REFERENCE NUMBER LOP/ANALYST THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER 'LOGS INCLUDED WITH THIS FILE (EDIT'O01): (SEE FILE EDIT.O02 FOR 1.Z" SAM'PLED FDC/CNL DATA) :, :, DUAL INDUCTION SPHERICALLY FOCUSED LOG (.OIL) FIRST TO LAST READING: 10363m TO 5932' FORM,~TION DENSITY COMPENSATED LOG (.FDC) FIRST TO LAST READING: 103'34' TO 9396' COMPENSATED NEUTRON LOG (.CNL) FIRST TO LAST READING: 10320' TO 9396' GAMMA RAY IN CASING (.CHL) FIRST TO LAST READING: 5932' TO 940' PAGE: IS TAPE VERIFICATION LISTING 10-SEP-1988 12:17 CHLUMBERGER ALASKA COMPUTING CENTER PAGE: TABLE TYPE : CONS TUNI V~LU DEFI CN ARCO ALASKA INC. COMPANY NAME FN KUPARUK FIELD NAME WN 3 O-Z WELL NAME NATI U.S.A. NATION STAT ALASKA STATE OR PROVINCE CDUN NORTH SLOPE COUNTY SECT 2 SECTION TOWN I3N TOWNSHIP RANG gE RANGE FL 745' FNL E 1855'FWL FIELO LOCATION OPER MALLARY OPERATOR'S CODE SON 530801 SERVICE ORDER NUMBER APIN 50-029-21837-00 API SERIAL NUMBER TABLE TYPE : CURV DEFI DEPT DEPTH CHANNEL NAME TENS TENSION SFlU SFL UNAVERAGED ILM IL-MEDIUM RESISTIVITY ILO IL-DEEP RESISTIVITY SP SPONTANEOUS POTENTIAL' GR GAMMA RAY TENS TENSION DPHI DENSITY POROSITY DRHO DELTA RHO RHOB BULK DENSITY CALI CALIPER GR GAMMA RAY TENS TENSION NPHI NEUTRON POROSITY TNRA CALIBRATED THERMAL NEUTRON RATIO RTNR RAW THERMAL NEUTRON RATIO RCFT RCFT RCNT RCNT CFTC CFTC CNTC CNTC GR GAMMA R AY TENS TENSION GR GAMMA RAY IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 10-SEP-1988 12: 17' PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ~*~.- TYPE REPR CODE VALUE ! 66 O 2 66 0 3 73 96 4 66 8 68 0.5 9 65 FT 11 66 10 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 SET TYPE - CHAN ~ NAME SERV UNIT SERVICE API API API APl FILE NUMB NUMB SIZE REPR ID ORDER e LOG TYPE CLASS :MOD NUMB SAMP ELEM CODE DEPT FT 530801 TENS OIL LB 530B01 SFLU OIL OHMM 530801 ILM OIL DHMM 53;0801 ILO OIL OHMM 5'30801 SP OIL MV 530801 GR OIL GAPI 530801 TENS FOC LB 530801 DPHI FDC PU 530801 ORHO FDC G/C3 530801 RHOB FDC G/C3 530801 CALI FOC IN 5308'01 GR FDC GAPI 530801 TENS CNL LB 530801 NPHI CNL PU :530801 TNRA CNL 530801 RTNR CNL 530801 RCFT CNL CPS 530801 RCNT CNL CPS 530801 CFTC CNL CPS 530801 CNTC CNL CPS 530801 GR CNL GAP~ 530801 TENS CHL LB 530801 GR CHL GAPI 530801 68 68 68 68 68 68 68 68 6 B 68 68 68 68 68 68 68 68 68 68 68, 68 68 68 68 PROCESS CHEX) 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 000~0000000 O000OO0~O00 OOOOOOOOO0 OOOO00OO00 000000:0000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS TAPE VERIFIC:ATIDN LISTING CHLUMBERGER ALASK& COMPUTING CENTER 10-SEP-1988 12:17 PAGE: DEPT. 10403.000 TENS.OIL ILO. OIL 3.834 SP.DIL DPHI.FDC 3.537 DRHO.FDC GR.FDC 95.750 TENS.CNL RTNR. CNL 3. 698 RCFT.CNL CNTC.CNL 2025.0 51 GR. CNL DEPT. 10400.000 TENS.OIL ILO.OIL 3.834 SP.DIL DPHI.FDC 3.537 DRHO.FDC GR.FOC 95.750 TENS.CNL RTNR.CNL 3.698 RCFT.CNL CNTC.CNL 2025.051 GR.CNL DEPT. 10300.000 TENS.OIL ILO.OIL 3-047 SPoDIL DPHI.FDC 10.706 DRHO.FDC GR.FDC 91.1BB TENS.CNL RTNR.CNL 3.230 RCFT-CNL CNTC.CNL 2104-503 GR.CNL DEPT. 10200.000 TENS.OIL ILO.OIL 3.253 SP.OIL DPHI.FDC 12.495 DRMD.FDC GR.FDC 97.188 TENS.CNL RTNR.CNL 3.429 RCFT.CNL CNTC.CNL 1947.424 GR.CNL DEPT. 10100.000 TENS.OIL ILO.OIL 8.136 SP.OIL DPHI.FDC 11.855 DRHO.FDC GR.FDC 91.688 TENS..CNL RTNR.CNL 3.000 RCFT.CNL CNTC.CNL 2263.394 GR.CN'L DEPT. 10000.000 TENS.OIL ILO.OIL 3.818 SP.DIL DPHI.FDC -5.396 ORHO.FDC GR.FDC 100.313 TENS.CNL RTNR.CNL 3.575 RCFT.CNL CNTC.CNL 2371.87'9 GR.CNL 2680.000 SFLU.DIL -19.000 GR.OIL 0.136 RHOB.FDC 2680.000 NPHI.CNL 527.381 RCNT.CNL 95.750 TENS.CML 3680.000 SFLU.DIL -19.000 GR.DIL 0.136 RHOB.FDC 3680.000 NPHI.CNL 527.381 RCNT.CNL 95.750 TENS.CML 7320.000 SFLU.DIL -15.758 GR.DIL 0.064 RHOB.FDC 7320.000 NPHI.CNL 629.363 RCNT.CNL 91.188 TENS.CHL 7072.000 SFLU.OIL -9.992 GR.OIL 0.051 RHOB.FOC 7072.000 NPHI.CNL 544.484 RCNT.CNL 97.188 TENS.CML 6708.000 SFLU.DIL -17.016 GR.OIL 0.014 RHOB.FDC 6708.000 NPHI.CNL 673'874 RCNT'CNL 91.688 TENS'CHL 6744.000 SFLU.OIL -27.750 GR.DIL 0°068 RHOB.FDC 6?44.000 NPHI.CNL 676.5'55 RCNT.CNL 100.313 TENS.CHL DEPT. 9900.000 TENS.OIL 6952.000 SFLU.DIL ILO.OIL 2.238 SP.DIL -25.500 GR.OIL DPHI.FOC 17.220 DRHO.FDC 0.035 RHO~.FDC GR.FDC 112.063 TENS.CNL 6952.000 NPHI.CNL RTNR.CNL 4.000 RCFT.CNL 401.440 RCNT.CNL CNTC.CNL 1694.721 GR.CNL 112.063 TENS.CML DEPT. 9800'000 TENS.OIL ILO.OIL 2.291 SP.DIL DPHI.FDC 17.957 ORHO.FDC GR.FDC 105.125 TENS.CNL RTNR.CNL 4.040 RCFT.CNL 68Z8.000 SFLU. OIL -23.719 GR.OIL 0.037 RHOB.FOC 68Z8.000 NPHI.CNL 430.252 RCNT'CNL 4.444 95.750 2.592 42.561 1977.707 -999.250 4.444 95.750 2.592 42.561 1977.707 -999.250 3.430 91.188 2.473 35.742 Z073.835 -999.250 3.906 97.188 2.444 37.880 '1911.980 -999.250 7.676 91.688 2.454 33.291 2245.063 -999.250 3.406 100'313 2.739 34.052 2413.372 -999.250 2. 148 112.063 2.366 42'023 1626.843 -999.250 2.236 105-125 2.354 43 .I22 1696.897 ILM.DIL TENS.FDC C&LI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC C&LI.FDC TNRA.CNL CFTC.CNL GR .CHL ILM.DIL TENS.FOC CALI.FDC TNRR.CNL CFTC.CNL GR.CML ILM. DIL TENS.FOC CALI.FDC TNRR.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FOC C ALI. FDC TNRA.CNL CFTC'CNL GR.CHL ILM.OIL 'TENS. FDC C ALI. FOC TNRR.CNL CFTC.CNL GR .CML ILM.DIL TENS.FDC C AL I. FO C TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNR,~.CNL CFTC.CNL 4.076 2680.000 8.094 3.431 600.2.35 -999.250 4.076 3680.000 8.094 3.431 600.235 -999.250 3.154 73Z0.000 8.961 3.130 689.202 -999.250 3.413 70'72. O00 8.734 3.228 621.013 -999. 250 8.005 6708,000 8.664. 2.972 779.616 '-999 3.991 6744.000 10.180 3.137 759. 553 -999.250 2.376 695'2.000 12.758 3.669 445-902 -999.250 2.304 68Z8.000 I0.664 3.672 482.079 IS TAPE VERIFIC~T'ION LISTING CHLUMBERGER ALASKA COMPUTING CENTER CNTC.CNL 1771.528 GR.CNL 9700.000 TENS.OIL 2.577 SP.OIL 16.647 DRHO.FDC 114.563 TENS.CNL 4.000 RCFT.CNL 1756.595 GR.CNL 9600.000 TENS.OIL 3.480 SP.OIL 14.228 ORHO.FOC 126.125 TENS.CNL 4.130 RCFT.CNL 1735.526 GR.CNL DEPT. ILO.OIL DPHI.FDC GR.FDC RTNR.CNL CNTC.CNL DEPT. ILO.OIL DPHI.FDC GR.FOC RTNR.CNL CNTC.CNL DEPT. ILD.OIL DPHI.FOC GR.FOC RTNR.CNL CNTC.CNL 9500.000 TENS.OIL 2.581 SP.OIL 7.615 DRHO.FOC 419.250 TENS.CNL 3.833 RCFT.CNL 2451.844 GR.CNL DEPT. ILO.OIL DPHI.FDC GR'FDC RTNR.CNL CNTC.CNL 9400.000 TENS.OIL 1.739 SP.DIL 15.958 DRHO.FDC 159.000 TENS.CNL 3.813 RCFT.CNL 1952.688 GR.CNL DEPT. ILO.OIL DPHI.FDC GR.FDC RTNR.CNL CNTC.CNL 9300.000 TENS.OIL 3.214 SP.DIL -999.250 DRHO.FDC -999.250 TENS.CNL -999.25'0 RCFT.CNL -999.250 GR.CNL DEPT. ILO.OIL DPHI.FDC GR.FDC RTNR.CNL CNTC.CNL 9200.000 TENS.OIL 4.424 SP.OIL -999.250 DRHO.FDC -999.250 TENS.CNL -999.250 RCFT.CNL -999.250 GR.CNL lO-SEP-1988 12:17 105.125 TENS.CHL 6658.000 SFLU.OIL -24.000 GR.OIL 0.012 RHDB.FDC 6668.000 NPHI.CNL 430.252 RCNT.CNL 114.563 TENS.CHL 6752.000 SFLU.OIL -43.000 GR.DIL 0.065 RHDB.FDC 6752.000 NPHI.CNL 383.038 RCNT.CNL 126.125 TENS.CHL 6604.000 SFLU.OIL -22.234 GR.DIL -0.009 RHOB.FDC 6604.000 NPHI.CNL 642.318 RCNT.CNL 419.25'0 TENS.CHL 6328.000 SFLU.OIL -41.500 GR.DIL 0.026 RHOB.FOC 6328.000 NPHI.CNL 504.479 RCNT.CNL 159.000 TENS.CHL 6348.000 SFLU.OIL -36.500 GR.OIL -999.250 RHOB.FOC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL 6428.000 SFLU.OIL -40.750 OR.OIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999-250 TENS.CHL DEPT. 9'100.000 TENS.OIL 6292.000 SFLU.OIL ILO.OIL 1.299 SP.OIL -30.750 GR.OIL DPHI.FDC -999.250 DRHO.FDC -999.250 RHiOS.F'DC GR.FDC -999.250 TENSoCNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 gR.CNL -999.250 TENS.CHL DEPT. ILO.OIL DPHI.FDC GR'FDC 9000.000 TENS.DIL 2.419 SP.OIL -999.250 DRHO.FDC -999.250 TENS. CNL 6484.000 SFLU.OIL -34'000 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 2.635 114.553 2.375 43.3T8 1786.743 -999.250 3.701 126.125 2.415 44.714 1731.961 -999.250 4.444 419.250 2.524 37.121 2299.707 -999.250 2.158 159.000 2.387 38.777 1804.156 -999.250 3.110 117-438 -999.250 -999.250 -999.250 -999-250 4.703 103.625 -.999.250 -999.250 -999.250 -999.250 1.515 146.875 -999.250 -999.250 -999.250 -999.250 3.105 137.000 -999.250 -999.250 GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC .CNL GR.CHL ILM.OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR .CHL ILM.DIL TENS.FDC CALI. FDC TNRA.CNL CFTC.CNL GR.CHL ILM.,OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR .CHL ILM.DIL TENS.FOC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.OIL TENS. FDC CALI .FOC T N R:A. CNL C FT C. CN L GR.CHL ILM.DIL TENS.FDC CALI. FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL PAGE: -999.250 2.666 6668.000 11.344 3.T06 478.679 -999.250 3.595 6752.000 14.383 3.859 450.639 -999.250 2.913 6604.000 I0.227 3.309 768.838 -999.250 1.851 6328.000 10.906 3.443 557.305 -999.250 3.236 -999.250 -999.250 -999.250 -999.250 -999.290 4.574 -999.250 - 999.250 -999.250 -999.250 -999. 250 1.421 -999.250 -999.250 -999.250 -999.250 -999.250 2.517 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA ;OMPUTING CENTER 10-SEP-1988 12:17 PAGE: RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. BgO0.O00 TENS.OIL ILO.OIL 3.020 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.2 50 GR.CNL DEPT. 8800.000 TENS.OIL ILO.OIL 2.458 SP.DIL DPHI.FDC -999.Z50 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 8700.000 TENS.OIL ILO.OIL 3.739 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 8600.000 TENS.OIL ILD.DIL 3.546 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.Z50 GR.CNL DEPT. BSO0.O00 TENS.OIL ILO.OIL 3.360 SP.OIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.25'0 RCFT.CNL CNTC.CNL -999.250 GR.CNL -999.2.50 -999.250 6320.000 -33.750 -999.Z50 -999.250 -999.250 -999.250 6144.000 -21.969 -999.250 -999.250 -999.250 -999.250 5908.000 -41.500 -999.250 -999.250 -999.250 -999.250 5892.000 -30.500 -999.250 -999.250 -999.250 -999.250 5848.000 -36.719 -999.250 -999.250 -999.250 -999.250 RCNT.CNL TENS.CHL SFLU.DIL GR.DIL RHOB.FDC NPHI.CNL RCNT.CNL TENS.CHL SFLU.DIL GR.DIL RHOB.FDC NPHI.CNL RCNT.CNL TENS.CHL OIL RHOB.FDC NPHI.CNL RCNT.CNL TENS.CHL SFLU.DIL GR.DIL RHOB'FDC NPHI.CNL RCNT.CNL TENS.CHL SFLU.OIL GR.DIL RHOB.FDC NPHI-CNL RCNT.CN:L TENS.CHL DEPT. 8400,000 TENS.OIL 5824.000 SFLU.DIL ILO.OIL 3.435 SP.OIL -40.000 GR.DIL DPHI.FDC -999.250 DRHD.FDC -999.250 RHOB.FDC GR.FDC .999.250 TENS.CNL -999.250 NPHI.CNL RTNR.CNL -999.250 RCF'T.CNL -999.250 RCNT'CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS..CHL DEPT. 8300.000 TENS.DIL 57Z4'000 SFLU.DIL ILO.OIL 3.245 SP.OIL -41-000 GE.OIL DPHI.FDC -999.Z50 DRHO.FDC -999.250 RHOS.FDC GR.FDC -99'9.250 TENS.CNL -9'99.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL -999.250 -999.250 10.005 85.625 -999.250 -999.250 -999.250 -999.250 2.231 83.125 -999.250 -999.250 -999.250 -999.250 3.725 123.188 -999.250 -999.250 -999.25:0 -999.250 3.543 102.000 -999.250 -999.250 -999.250 -999.250 3.376 102.875 -999.250 -999.250 -999.250 -999.250 3.424 105.875 -999.250 -999.250 -999.250 -999.250 2.973 97.688 -999.250 -999.250 -999.250 -999.250 CFTC.CNL GR.CHL ILM.OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL I'LM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI .FOC TNRA.CNL CFTC.CNL GR.CHL ILM .OIL TENS. FOC CALI.FDC TNRA.CNL CFTC .CNL GR. CHL ILM.DIL TENS. FOC CALI .FDC TNRA .CNL CFTC.CNL GR.CHL -999.250 -999.250 3.622 -999.250 -999.250 -999.250 -999.250 -999.250 2.506 -999.250 -999.250 -999.250 -999.250 -999.250 3.907 -999.250 -999.250 -999.250 -999.250 -999'250 3.646 -999.250 -999.250 -999.250 -999.250 -999.250 3.458 -999.250 -99'9.250 -999.250 -999.25'0 -999 . 250 3.534' -999.250 -999.250 -999.250 -999.250 -999. 250 3.255 -999.250 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 8200.000 TENS.OIL ILO.OIL 3.010 SP.DIL DPHI.FDC -999.250 DRMO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 8100.000 TENS.OIL ILO.OIL 2.892 SP.OIL DOMI.FDC -999.250 DRMO.FOC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 8000.000 TENS.OIL ILO.OIL 2.919 SP.OIL DPMI.FOC -999.250 DRHO.FOC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 7900.000 TENS.OIL ILD.DIL 3.670 SP.DII DPHI.FOC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CML RTNR.CNL -999.2510 RCFT.CNL CNTC.CNL -999..250 GR.CNL DEPT. 7800.000 TENS.OIL ILO.OIL 3.157 SP.DIL DPHI.FDC -999.250 DRHO.FOC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 7700.000 TENS.OIL ILO.OIL 2.968 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL 10-SEP-1988 12:17 5608.000 SFLU.OIL -¢3.500 Gl.OIL -999.250 RMOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL 5508.000 SFLU.OIL -39.750 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CML 5544.000 SFLU.OIL -¢2.000 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL 5348.000 SFLU.OIL -44.750 GR.OIL -999.250 RMOS.FOC -999.250 NPMI.CNL -999.250 RCNT.CNL -999.250 TENS.CML 524B.000 SFLU.DIL -46.000 GR.OIL -999.250 RHOB.FDC -999.250 NPMI.CNL -999.250 RCNT.CNL -999.250 TENS.CML 52~0.000 SFLU.OIL -~5.250 ,GR.DIL -999.250 RMOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CML DEPT. 7600.000 TENS.OIL 5220.000 SFLU.OIL ILO.OIL 3.447 SP.DIL -~7-250 GR.DIL DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FOC GR.FDC -999.250 TENS.CML -999.250 NPHI.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL DEPT. 7500.000 TENS.OIL ILO.OIL 2.785 SP.DIL DpHI.FDC -999.250 DRHO.FDC GR.FOC -999.250 TENSoCNL RTNR.CNL -999'250 RCFT.CNL CNTC.CNL -999.250 GR.CNL 5220.000 SFLU.DIL -44.250 GR.DIL -999. 250 RHOB.FDC -999.250 NPflI.CNL -999. 250 RCNT.CNL -999.250 TENS.CHL 2.933 107.563 -999.250 -999.250 -999.250 -999.250 2.730 97.500 -999.250 -999.250 -999.250 -999.250 2.899 101.625 -999.250 -999.250 -999.250 -999.250 2.687 103.625 -999.250 -999.250 -999.250 -999.250 2. 949 98.125 -999. 250 -999.250 -999.250 -999.250 2.766 99.938 -999.250 -999.250 -999.250 -999.250 3.107 89.250 - 999.2:50 -999.250 -999.2:50 -999.250 3.207 87.250 -999.250 -999.250 -999.250 -999.250 ILM .OIL TENS.FDC CALI.FDC TNRR.CNL CFTC .CNL GR.CHL ILM.DIL TENS. FDC CAlI .FDC TNRA.CNL CFTC .CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNR~.CNL CFTC.CNL GR.CML ILM.DIL TENS.FDC CALI.FDC TNRA. CNL CFTC.CNL GR.CHL ILM.DIL TENS.FOC CALI.FDC TNRA.CNL CFTC.CNL GR.CML ILM.DIL TENS.FDC CALI.FOC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS. FDC CALI .FDC TNRR.CNL CFTC.CNL GR.CHL PAGE: 3.0a9 -999.250 -999.250 -999.250 -999.250 -999.250 2.798 -999.250 -999.250 -999.250 -999.250 -999.250 2.956 -999.250 -999.250 -999.250 -999.250 -999.250 3.349 -999.250 -999.250 -999. 250 -999.250 -999.250 3.161 -999.250 -999.250 -999.250 -999.250 -999.250 2.990 -999.250 -999.250 -999.250 -999.250 -999.250 3.4~3 -999.250 -999.250 -999.250 -999.250 -999.250 2.884 -999' 25:0 -999. 250 -999.250 -999.250 -999. 250 IS TAPE VERIFICATION LISTING CHLUMSERGER ALASKA COMPUTING CENTER 10-SEP-1958 12:17 PAGEr DEPT. 7400.000 TENS.OIL ILO.OIL 3.2¢3 SP.DIL DPMI.FDC -999.250 DRHO.FDC GRoFDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 7300-000 TENS.OIL ILO.OIL 3.178 SP.OIL DPMI.FDC -999.250 DRHO.FOC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC. CNL -999.250 GR.CNL DEPT. 7200.000 TENS.OIL ILD-DIL 3.069 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL ETNA.CML -999.250 RCFT..CNL CNTC.CNL -999.250 GR.CNL DEPT. 7100.000 TENS.OIL ILO. OIL 3.182 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR.FOC -999.250 TENS.CML RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 7000.000 TENS.OIL ILO.OIL 3.0~4 SP.DIL DPMI.FDC -999.250 ORHO.FDC GR.FDC -999.250 TENS.CNL R~TNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL 5052.000 SFLU.DIL -49.000 GE.DIL -999.250 RHOB.FOC -999.250 NPM[.CNL -999.250 RCNT.CNL -999.250 TENS.CHL 49¢0.000 SFLU.DIL -49.000 GE.OIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CML 4932.000 SFLU.DIL -46.750 GR.OIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL ¢868.000 SFLU.DIL -42.781 GE.OIL -9:99.250 RHOB.FOC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL 4688.000 SFLU.DIL -31.000 GE.OIL -999.250 RHOB'FOC -999.250 NPHI'CNL -999.250 RCNT.CNL -999.250 TENS'CHL DEPT. 6900.000 TENS.OIL 4732.000 SFLU.DIL ILD.DIL 3.148 SP.DIL -75.250 GR.DIL DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FOC GR.FDC -999.250 TENS.CML -939.250 NPHI.CNL ETNA.CML -999.250 RCFT.CNL -999.250 RCNT'CNL CNTC.CNL -999.250 ~GR.CNL ,-999.2'50 TENS.CML DEPT. 6800.000 TENS.OIL ILO.DIL 3.018 SP.DIL DPMI.~DC -999'.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -'999.250 GR.CNL DEPT. 6700.000 TENS.OIL ILO. OIL 3.157 SP.OIL DPHI.FOC -999.250 DRMO.FDC GE" FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL ~688.000 SFLU.OIL -70. 000 GR.DIL -999.250 RHDS.FDC -999.2,50 NPHI.CNL -999.250 RCNToCNL -999.250 TENS.CHL ~¢3¢¢.000 SFLU.DIL -59.219 GR.OIL '-999.250 RHOB.FOC -999.250 NPHI.CNL -999.25!0 RCNT.CNL 3.099 86.063 -999.250 -999.250 -999.250 -999.250 2.794 86.688 -999.250 -999.250 -999.250 -999.250 2.778 94.375 -999.250 -999.250 -999.250 -999.250 3.154 78.625 -999.250 -999.250 -999.250 -999.250 2.696 89.125 -999.250 -999.250 -999.250 -9'99.250 2.804 87.000 -999.250 -999.250 -999.250 -999.250 2.733 99.313 -999.250 -999.250 -999.250 -999.250 2.698 91.688 -999.250 -999.250 -999.250 ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CML GR.CHL ILM.DIL TENS.FOC CALI.FDC TNRA.CNL CFTC.CNL GE.CML ILM.DIL TENS.FDC CALI.FDC TNRA.CNL C~TC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.OIL TENS.FDC CAL'I.FDC TNRA.CNL CFTC.CNL GE.CML ILM.DIL TENS..FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.OIL TENS. FDC CALI.FDC TNR~.CNL C FTC. CML 3.229 -999.250 -999.250 -999.250 -999.250 -999.250 3.064 -999.250 -999.250 -999.250 -999.250 -999.250 3.035 -999.250 -999.250 -999.250 -999.250 -999.250 2.914~ -999.250 -999.250 -999.250 -999.250 -999.250 3.0151 -999.250 -999.250 -999'250 -999.250 -999.250 3.088 -999.250 -999.250 -999.250 -999.250 -999.250 2.955 -999.250 -99'9'250 -999.250 -999.250 -999.250 3.067 -999.250 -999. 250 -999. 250 -999. 250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER CNTC.CNL -999.250 GR.CNL DEPT. 6600.000 TENS.OIL ILD.DIL 3.201 SP.DIL DPHI.FDC -999.250 DRHg. FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 6500.000 TENS.OIL ILO.OIL 3.573 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 6400.000 TENS.OIL ILO.OIL 3.096 SP.DII DPHI.FOC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 6300.000 TENS.OIL ILO.OIL 3.068 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR.FOC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 6200.000 TENS.OIL ILO.OIL 2.535 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR. FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCF'T.CNL CNTCoCNL -999.250 GR.CNL DEPT. 6100.000 TENS.DIL ILO.OIL 3.991 SP.OIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL R'TNR.CNL -:999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEP'T. 6000.000 TENS.OIL ILO.OIL 3.475 SP.DIL DPHI.FDC -999.25'0 DRHO.FOC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 5900.000 TENS.OIL ILO. OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL 10-SEP-1988 12:17 -999.250 TENS.CHL 4272.000 SFLU.DIL -53.500 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CML 4220.000 SFLU.OIL -57.000 GR.DIL -999.250 RMOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CML 4140.000 SFLU.DIL -52.250 GR.DIL -999.250 RMOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL 4044.000 SFLU.OIL -52.281 GR.DIL -999.250 RHOB.FOC '-999.250 NPHI.CNL -999.250 RCNToCNL -999.250 TENS.CML 3900.000 SFLU.DIL -62.000 GR.OIL -999.250 RHO3.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL 3954.000 SFLU.DIL -60.250 GR.OIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL 3874.000' SFLU.DIL -62.250 GR.OIL -999.250 RHOB.FOC -999.250 NPHI.CNL -999. 250 RCNT.CNL -999.250 TENS.CHL -999.250 2.756 97.125 -999.250 -999.250 -999.250 -999.250 3.109 90.813 -999.250 -999.250 -999.250 -999.250 2.718 82.500 -999.250 -999.250 -999.250 -999.250 2.917 80.875 -999.250 -999.250 -999.250 -999.250 2.453 101.438 -999.2'50 -999.250 -999.250 -99:9.250 3.272 82.813 -999.250 -999.250 -999. 250 -999.250 2.958 87.688 -999.250 -999.250 -999.250 -999.250 -999.250 SFLU.DIL -999.250 -999.250 GR.OIL -999.250 -999.250 RHOB.FDC -999,250 -999.250 NPHI.CNL -999.250 GR.CHL ILM.OIL TENS .FOC C~II.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI .FDC TNRA.CNL CFTC.CNL GR.CHL ILM.OIL TENS.FDC C~LI.FDC TNR~.CNL CFTC.CNL GR.CHL ILM.DIL TENS. FDC CALI.FDC TNR~.CNL CFTC.CNL GR.CML ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTCoCNL GR.CHL ILM.OIL TENS. FDC C A L I. F D C TNRR.CNL CFTC .CNL GR.CHL ILM.OIL TENS.FDC CfLI.FDC TNRR.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL PAGE: 10 -999.250 3.099 -999.250 -999.250 -999.250 -999.250 -999.250 3.423 -999.250 -999.250 -999.250 -999.250 -999.250 2.991 -999.250 -999.25'0 -999.250 -999.250 -999.250 2.995 -999.250 -999.250 -999.250 -999.250 -999.250 2.460 -999.250 -999.250 -999.250 -999.250 -999.250 3.653 -999.250 -999'250 -999.250 -999.250 -999.250 3.335 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 10-SEP-1988 12:17 PAGE: 11 RTNR.CNL -999.250 RCF'T.CNL -999.250 RCNT.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CML DEPT. 5800.000 TENS.OIL -999.250 ILO.OIL -999.250 SP.DIL -999.250 DPHI.FOC -999.250 DRHO. FDC -999.250 GR.FDC -999.250 TENS.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 DEPT. 5700.000 TENS.OIL ILO.OIL -999.Z50 SP.OIL DPHI.FDC -999. 250 DRHO.FOC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999. 250 GR.CNL DEPT. 5600.000 TENS.OIL ILD.DIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999'250 GR.CNL DEPT. 5500.000 TENS.OIL ILO.OIL -999.250 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -9'99.250 GR.CNL DEPT. 5400-000 TENS.OIL ILO.OIL -999.250 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR.FOC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 5300.000 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.25:0 -999.250 -999.250 -999. 250 -999.250 -999.250 -99'9. 250 SFLU.OIL GR.DIL RHOB.FDC NPHI.CNL RCNT.CNL TENS.CHL SFLU. DIL GR.DIL RHOB.FDC NPHI.CNL RCNT.CNL TENS.CHL SFLU.DIL GR.OIL RHOB.FDC NPH[.CNL RCNT.CNL TENS.CHL SFLU.OIL GR.DIL RHOB.FDC NPHI.CNL RCNT.CNL TENS.CML SFLU.OIL GR.OIL RHOB.FDC NPHIoCNL RCNT.CNL TENS.CHL SFLU. OIL GR.OIL RHOB.FOC NPHI'CNL RCNT-CNL TENS.CHL -999.250 3884.000 -999.250 -999.250 -999.250 -999.250 -999.250 3844.000 -999.25'0 -999.250 -999.250 -999.250 -999.250 3830.000 -999.250 -999.250 -999.250 -999.250 -999.250 3744.000 -999.250 -999.250 -999.250 -99'9.250 -999.250 3624.000 -999.250 -999.250 -999..250 -999.250 -999.250 3610.000 -999.250 -999.250 -999.250 -999.250 -999~250 3540.000 CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM. OIL TENS.FDC CALI.FDC TNRA.CNL CFTC. CNL GR.CHL ILM.OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CNL ILM.OIL TENS.FDC CALI.FDC TNRA.CNL CFTC .CNL GR.CHL ILM.DIL TENS. FDC CALI.FDC TNRA.CNL CFTC.CNL GR. CHL ILM.OIL TENS.FDC CALI. FDC TNRA .CNL C FTC. CNL G R. CML -999.250 55.813 -999.250 -999.250 -999.250 -999.250 -999.250 57.688 -999.250 -999.250 -999.250 -999.250 -999.250 66.938 -999.250 -999.250 -999.25'0 -999.250 -999.250 56.719 -'999'250 -999.250 -999.250 -99.9.250 -999.250 49.719 -999.250 -999.250 -999.250 -999'250 -999.250 55.250 -999.250 -999-250 -999.250 -999.250 -999.250 55.3~4 DEPT. 5200.000 TENS.OIL -999.250 SFLU.OIL -999.250 ILM.OIL -999.250 ILO.OIL -999.250 SP.DIL -999.250 GR.OIL -999.250 TENS.FDC -999.250 DPHI.FDC -999.250 DRHO.FDC -999.250 RHOB.FOC -999-250 CA:LI.FDC -999.250 GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 3494.000 GR.C'HL 5,8.906 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 5100.000 TENS.OIL ILO.OIL -999. 250 SP.DIL DPHIoFDC -999.250 DRHO.~DC GR.FOC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999. 250 GR.CNL DEPT. 5000.000 TENS.OIL ILD.OIL -999.250 SP.DIL DPHI.FOC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999-250 GR.CNL DEPT. 4900.000 TENS.OIL ILO.OIL -999.250 SP.OIL DPHI.FDC -999.250 ORHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 4800.000 TENS.OIL ILO.OIL -999.250 SP.OIL DPHI.FDC -999.250 DRHO..FDC GR.FOC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL 10-SEP-1958 12:17 -999.250 SFLU.DIL -999.250 GR.OIL -999.250 RHOS.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 -999.250 -999.250 -999.250 -999.250 3490.000 ILM.DIL TENS.FDC C~L[.FDC TNRA.CNL CFTC.CNL GR.CML PAGE: 12 -999.250 -999.250 -999.250 -999.250 -999.250 60.563 -999.250 SFLU.OIL -999.250 ILM.DIL -999.250 -999.250 GR.DIL -999.250 TENS.FDC -999.250 -999.250 RHOB.FDC -999.250 CALI.FOC -999.250 -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 -999.250 TENS.CML 3444.000 GR.CHL 61.469 -999.250 SFLU.DIL -999.250 -999.250 GR.OIL -999.250 -999.250 RHOB.FDC -999.250 -999.250 NPMI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CHL 3364.000 ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL -999.250 -999.250 -999.250 -999.250 -999.250 3304.000 -999.250 SFLU.OIL -999.250 GR.OIL -999.250 RHOB.FDC -999.250 NPMI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL DEPT. 4700.000 TENS.OIL -999.250 SFLU.OIL -999.250 ILM. DIL ILO.OIL -999.250 SP.OIL -999.250 GR.OIL -999.250 TENS.mDC DPHI.FDC -999.250 ORHO.FDC -999.250 RHOB.FDC -999.250 CALI.FDC GR.FOC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 3234.000 GR.CHL DEPT. 4600.000 TENS.OIL -999.250 SFLU.OIL -999.250 ILM.DIL ILD.DIL -999.250 SP.DIL -999.250 GR.OIL -999.250 TENS.FDC DPHI.:FDC -999.250 DRHO.FDC -999.250 RHOB.FDC -999.25:0 CALI.FDC GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 3220.000 GR.CHL DEPT. 4500.000 TENS.OIL -999.250 SFLU.OIL -999.250 ILM.DIL I:LD.OIL -999.250 SP.DIL -999.290 GR.OIL -999.250 TENS.FDC OPHI.FOC -999.250 DRHO.FDC -999.250 RHOB.FDC -999'250 CALIoFDC GR.FOC -999.250 TENS.CNL -999.250 NPMI.CNL -999.250 TNRA.CNL RTNR.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 ~CFTC.CNL CNTC.CNL -999.250 GR.CNL -999.250 TENS.CML 3150.000 GR.CHL DEPT. 4400.000 TENS.OIL -999.250 SFLU.DIL -999.250 ILM.DIL ILO.OIL -999.250 SP.DIL -999.250 GR.DIL -999.250 TENS.FOC DPHI.FDC -999.250 DRHO. FDC -999.250 RHOB.FDC -999.250 CALI.FDC GR.FDC -999.250 TENS.CNL -999.250 NPHI.CNL -999.250 TNRA.CNL RTNR.CNL -999.250 RCFT.CNL' -999.250 RCNT.CNL -999.250 CFTC.CNL CNTC.CNL -99~9.250 GR.CNL -999.250 TENS.CHL 3070.000 GR.CHL -999.250 -999.250 -999.250 -999.250 -999.250 ¢3.719 -999.250 -999.250 -999.250 -999.250 -999.250 48.188 -999.250 -999.250 -999.250 -999.250 -999.250 41.563 -999'250 -999.250 -999.250 -999.250 -999.250 45.406 -99'9.250 -999.250 -999.250 -999.250 -999.250 29-297 -999.250 -999.250 -999.250 -999.290 -999.250 34.844 IS TAPE VERIFICATION LISTING CMLUMBERGER ALASKa COMPUTING CENTER DEPT. 4300.000 TENS.OIL ILO.OIL -999.250 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 4200.000 TENS.OIL ILO.OIL -999.250 SP.OIL DPHI.FOC -999.250 DRHO.FDC GR. FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 4100.000 TENS.OIL ILD.OIL -999.250 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 4000. 000 'TENS.OIL ILO.OIL -999. 250 SP.DIL DPHI. FDC -999.250 DRHO. FDC GR.FOC -999.250 TENS.CML RTNR.CNL -999. 250 RCFT.CNL CNTC.CNL -999. 250 GR.CNL DEPT. ILO.OIL DPHI.FDC GR.FDC RTNR.CNL CNTC.CNL DEPT. ILO.OIL DPHI.FDC GR.FOC RTNR.CNL CNTC. CNL O E P T. ILO.OIL DPHI .FOC GRoFDC RTNR.CNL CNTC.CNL DEPT. ILO.OIL DPHI.FDC GR.FOC RTNR.CNL lO-SEP-19BB 12:17 -999.250 SFLU.OIL -999.250 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CML -999.250 -999.250 -999.250 -999.250 -999.250 2960.000 -999.250 SFLU.OIL -999.250 -999.250 GR.DIL -999.250 -999.250 RHOB.FDC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCN?.CNL -999.250 -999.250 TENS.CHL 2820.000 -999.250 SFLU.OIL -999.250 -999.250 GR.OIL -999.250 -999.250 RHOB.FOC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CML 2840.000 -999.250 SFLU.OIL -999.250 -999.250 GR.OIL -999.250 -999.250 RHOB.FDC -999.25'0 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CHL 275:0.000 ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CML ILM.DIL TENS.FDC CALI.FDC TNRA.'CNL CFTC.CNL GR.CML ILM. DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL 3900.000 TENS.OIL -999'250 SFLU.OIL -999.250 ILM.DIL -999.250 SP.OIL -999.250 GR.DIL -999.250 TENS.FDC -999.250 DRMO.FDC -999.250 RHOB.FDC -999.250 C~LI.FDC -999.250 TENS.CML .-999.250 NPMI'CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 GR.CNL -999.250 TENS.CHL 2730.000 GR.CHL -999.250 SFLU.OIL -999.250 GR.DIL -999-250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT'CNL -999.25!0 TENS'CML 3800.000 TENS.OIL -999.250 SP.DIL -999.250' ORHO.FDC -999.250 TENS.CNL -999.250 RCFT.CNL -999.250 GR.CNL -999.250 -999.250 -999.250 -999. 250 -999.250 2634.000 '-999.250 SFLU.OIL -999.250 -999.250 GR.OIL -999.250 -999.250 RHOB.FOC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CML 25'64.000 3700.000~ TENS.OIL -999.250 SP.DIL -999.250 DRMO.FDC -999.250 TENS.CNL -999'250 RCFT.CNL -999.250 GR.CNL 3600.000 TENS.OIL -999.250 SP.OIL -999.250 DRHO. FDC -999.250 TENS.CNL -999.250 RCFT.CNL -999.250 SFLU. DIL -999.250 GR.OIL -999.250 RMOB.FDC -999.250 NPHI.CNL -999.250 RCN'T.CNL -999.250 -9919.250 -999.290 -999.250 -999.250 ILM.DIL TENS.FDC CALI. FDC TNRA. CNL CFTC.CNL GR.CML ILM.DIL TENS.FDC CALI. FDC · TNRA.CNL CFTC.CML GR.CHL ILM. OIL TENS. FDC CALI.FDC TNRA.CNL CFTC .CML PAGE: 13 -999.250 -999.250 -999.250 -999.250 -999.250 37.719 -999.250 -999.250 -999.250 -999.250 -999.250 41.65:6 -999.250 -999.250 -999.250 -999.250 -999.250 62.375 -999.250 -999.250 -999.2'50 -999.250 -999.250 37.688 -999.2510 -999.250 -999'250 --999.250 -999.250 37.813 -999.250 -999. 250 -999.25'0 -999. 250 -999.250 52.25O -999.250 -999.250 -999.250 -999.250 -999.250 38.750 -999.250 -.999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER CNTC.CNL -999. 250 GR. CNL DEPT. 3500.000 TENS.OIL ILO.OIL -999.250 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999'250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 3400.000 TENS.DIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 3300.000 TENS. OIL ILD.DIL -999.250 SP.OIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 3200. 000 TENS.OIL IlO.OIL -9 99. 250 SP.DIL DPHI.FDC -999.250 DRHD.FDC GR.FOC -999.250 TENS.CNL RTNR.CNL -99'9.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 3100.000 TENS.OIL ILO.OIL -999. 250 SP.OI1 DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999. 250 GR.CNL DEPT. 3000.000 TENS.OIL ILO. OIL -999. 2510 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 2900.000 TE~NS.OIL ILO.OIL -999.250 SP.DIL OPHI.FDC -999.250 DRHO.FDC GR.FOC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 2800.000 TENS.OIL ILO.OIL -999.250 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR..FDC -999.250 TENS.CNL 10-SEP-1988 12:17 -999.250 TENS.CHL 2620.000 -999.250 SFLU.DIL -999.250 -999.250 GR.DIL -999.250 -999.250 RHOB.FOC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CHL 2464.000 -999.250 SFLU.OIL -999.250 -999.250 GR.DIL -999.250 -999.250 RHOB.FOC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CHL 2384.000 -999.250 SFLU.DIL -999.250 -999.250 GR.OIL -999.250 -999.250 RHOB.FDC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CML 2360.000 -999.250 SFLU.OIL -999.250 GR.OIL -999.250 RHOB.FOC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 SFLU.OIL -999.250 GR.OIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CML -999-250 SFLU.OIL -999.250 GR.OIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250' RCNT.CNL -999.25:,0 TENS.CHL -999.250 SFLU.OIL -999.250 GR.OIL -999.250 RHO!.FDC -999.25:0 NPHI.CNL -999.2150 RCNT.CNL -999.250 TENS.CHL -999.250 SFLU.OIL -999'.250 GR.OIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 -999.250 -999.250 -999.250 -999.250 2244.000 -999.250 -999.250 -999.250 -999.250 -999.250 2140.000 -999.250 -999.250' -999.25:0 -999.250 -999.250 Zl14.000 -999.250 -999.250 -999.Z50 -999.250 -999.250 2025-000 -999.250 -999.250 -999.250 -999.250 GR.CHL ILM. DIL TENS.FBC CaLI.FOC TNRA .CNL CFTC.CNL GR .CHL ILM.OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CRLI.FDC TNRa. CNL CFTC.CNL GR.CML ILM.OIL TENS. FDC CALI.FOC TNRA.CNL CFTC.CNL GRoCHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC'CNL GR.CML ILM.OIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.OIL TENS.FDC CALI. FDC TNR A. CNL PAGE: 14 36.781 -999.250 -999.250 -999.250 -999.250 -999.250 38.250 -999.250 -999.250 -999.250 -999.250 -999.250 32.219 -999.250 -999.250 -999.250 -999.250 -999.25'0 36.750 -999.250 -999.250 -999.250 -999.250 -999.250 37-969 -999'250 -999. 250 -999.Z50 -999.250 -999.250 37.000 -999.250 -999.250 -999.250 -999.250 -999.250 35.125 -999.250 -999.250 -999.250 -999.2'50 -999.250 44-063 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 10-SEP-1988 12:17 PAGE: 15 RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 2700.000 TENS.OIL ILO.OIL -999.250 SP.OIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 2600.000 TENS.OIL ILO.OIL -999.250 SP.DIL OPHI.FOC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 2500.000 TENS.OIL ILO.OIL -999.250 SP.OIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 2400.000 TENS.OIL ILO. OIl -999.250 SP.OIL DPHI.FOC -999.250 ORMO.FOC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.2:50 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 2300.000 TENS.OIL ILO.OIL -999.250 SP.DIL GR.FOC S~99.~50 TENS.CNL RTNR.CNL 99. 50 RCFT.CNL CN'TC.CNL -999.250 GR.CNL DEPT. 2200.000 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR'CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. ZIO0.O00 TENS.OIL ILO.OIL -999.250 SO.OIL DPHI.FDC -999.250 DRHD.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 CmTC.CNL Z050.000 GR.CHL -999.250 54.156 -999.250 SFLU.OIL -999.250 ILM.DIL -999.250 -999.250 GR.OIL -999.250 TENS.FOC -999.250 -999.250 RHO~.FDC -999.250 CALI.FOC -999.250 -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 -999.250 TENS.CHL 1940.000 GR.CHL 49'344 -999.250 ILM.DIL -999.250 -999.250 TENS.FDC -999.250 -999.250 CALI.FDC -999.250 -999.250 TNRA.CNL -999.250 -999.250 CFTC.CNL -999.250 1910.000 GR.CHL 57.688 -999.250 SFLU.DIL -999.250 GR.DIL -999.250 RHDB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CML -999.250 SFLU-DIL -999.250 ILM.DIL -999.250 GR.DIL -999.250 TENS.FDC -999.250 RHO~.FOC -999.250 CALI.FDC -999.250 NPHI.CNL -999.250 TNR~.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 TENS.CML 1800.000 GR.CHL -999.250 -999.250 -999.250 -999.250 -999.250 43.938 -999.250 SFLU.DIL -999.250 GR.OIL -999.250 RHOB'FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CML -999.250 ILM.OIL -999.250 -999.250 TENS. FDC -999.250 -999.250 CALI'FDC -999.250 -999.250 TNRA.CNL -999.250 -999.250 CFTC.CNL -999-250 1820.000 GR.CHL 27'469 -999-250 SFLU.OIL -999.250 ILM.OIL -999.250 GR'DIL -999.250 TENS.FD'C -999.250 RHOB.FDC -999.250 CALI.FDC -999-250 NPHI.CNL -999-250 TNRA.CNL -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 TENS.~CHL 1760o000 GR.CML -999.250 SFLU.DIL -999.250 GR.DIL -999.250 RMOS.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999-250 TENS.CHL .-999.250 ILM.DIL -999.250 TEiNS.FDC -999.250 CALI.FDC -999.250 TNR~.CNL -999.250 CFTC.CNL 1730.000 GR.CML '-999.250 -999.250 -999.250 -999.Z50 -999.250 45.469 -999.250 -999.25:0 -999.2'50 -999.250 -999.250 34.406 -999.250 SFLU.OIL -999.250 ILM.DIL -999.250 -999.250 GR.OIL -999.250 TE!NS.FDC -999.250 -999.250 RMOB.FDC -.999.250 CALI.FOC -999.250 -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 -999.250 RCN'T..CNL -999.250 CFTC.CNL -999.250 -999.250 TENS.CHL 1745.000 GR.CML 43.125 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEPT. ZO00.O00 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 1900.000 TENS.OIL ILD.DIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TEN$.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 1800.000 TENS.OIL ILO. OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 1700.000 TENS.OIL ILD.DIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPT. 1600.000 TENS.OIL .ILO. OIL -999'250 SP.OIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR-CNL DEPT. 1500.000 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHO.FOC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 G~.CNL DEPT. 1400.000 TENS.OIL ILO. OIL '-999.250 SP.OIL OPHI.FDC -999.250 DRHO. FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL DEPOT. 1300.000 TENS.OIL ILO.OIL -999.250 SP.DIL DPHI.FDC -999.250 DRHD. FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999.250 GR.CNL 10-SEP-19BB 12:17 -999.250 SFLU.DIL -999.250 -999.250 GR.OIL -999.250 -999.250 RHOI.FOC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CML 1750.000 -999.250 SFLU.OIL -999.250 -999.250 GR.DIL -999.250 -999.250 RHOB.FDC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CHL 1735.000 -999.250 SFLU.OIL -999.250 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 SFLU.DIL -999.250 GR.DIL -999.250 RHOB.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999.250 -999.250 -999.250 -999.250 -999.250 1770.000 -999.250 -999.250 -999.250 -999.25:0 -999.250 1675.000 -999.250 SFLU.OIL -999.250 -999.250 GR.DIL -999.25'0 -999.250 RHOB.FDC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.2~0 TENS.CHL 1605.000 -999-250 SFLU.OIL -999.250 -999.250 GR.OIL -999.250 -999.250 RHOB.FDC -999.250 -999.250 N~HI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CHL 1560'000 -999.250 SFLU.DIL -999.250 GR.OIL -999.250 RHOB.FDC -999.250 NPHI.CNL 999.250 RCNT.CNL -999'250 TENS.CNL -999.250 SFLU.DIL -999.250 GR.OIL -999.250 RHOB.FOC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 TENS.CHL -999. 250 -999.25:0 -999.250 -999.250 -999.250 1525.000 -999.250 -999.250 -999.250 -999.250 -999.250 1485.000 ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM. DIL TENS .FDC CALI.FDC TNRA.CNL CFTC.CNL GR .CHL ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL ILM.DIL TENS.FDC CALI.FOC TNRA.CNL CFTC.CNL GR .CHL ILM.OIL TEN S. FO C C AL I. FD C TNR.~oCNL CFTC .CNL GR.CHL ILM.DIL T E NS. FDC C~LI.FDC TNRA.CNL C FTC. CNL GR .CHL ILM. OIL TEN S. FDC CALI.FDC TNRA.CNL CFTCoCNL GR. CHL ILM.OIL TENS. FDC C AL I. FD:C TNRA.CNL CFTC.CNL GR .CHL PAGE: 16 -999.250 -999.250 -999.250 -999.250 -999.250 32.219 -999.250 -999.250 -999.250 -999.250 -999.250 23.000 -999.250 -999.250 -999.250 -999.250 -999.250 ~5'8¢4 -999.250 -999.250 -999.250 -999.250 -999'250 .44.375 -999-250 -999.250 -999.250 -999.250 -999.250 26.438 -999.250 -999,250 -999.250 -999.250 -9'99'250 36.688 -999.2 50 -999.250 - 999.250 -999.250 -999.250 44.438 -999.250 -999.250 -999.250 -999.250 -999.250 21.625 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA ~OMPUTING CENTER 10-SEP-1988 12:17 PAGE: 17 DEPT. 1200.000 TENS.OIL ILO. OIL -999. 250 SP. OIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC. CNL -999.2 50 GR. CNL DEPT. 1100.000 TENS.OIL ILO.OIL -999. 250 SP.DIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.Z50 RCFT.CNL CNTC.CNL -999. 250 GR.CNL DEPT. 1000.000 TENS.OIL ILD. OIL -999. 250 SP. OIL DPHI.FDC -999.250 DRHO.FDC GR.FDC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -9 99.250 GR. CNL DEPT. 939.500 TENS.OIL ILO.OIL -999. 250 SP.DIL DPHI.FDC -999.250 DRHOoFDC GR.FOC -999.250 TENS.CNL RTNR.CNL -999.250 RCFT.CNL CNTC.CNL -999. 250 GR.CNL ENO OF DATA -999.250 SFLU.DIL -999.250 -999.250 GR.OIL -999.25'0 -999.250 RHDB. FDC -999.250 -999.250 NPHI.CNL -999.Z50 -999.290 RCNT.CNL -999.250 -999.250 TENS.CHL 1450.000 ILM.DIL TENSoFDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL -999.250 -999.250 -999.250 -999.250 -999.250 42.719 -999.250 SFLU.OIL -999.250 ILM.DIL -999.250 -999.250 GR.DIL -999.250 TENS.FDC -999.250 -999.250 RHOB.FDC -999.Z50 CALI.FDC -999.250 -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 -999.250 TENS.CHL 1420.000 GR.CHL 55.438 -999.250 SFLU.DIL -999.250 ILM.DIL -999.250 -999.250 GR.DIL -999.250 TENS.FOC -999.250 -999.250 RHOB.FDC -999.250 CALI.FDC -999.250 -999.250 NPHI.CNL -999.250 TNRA.CNL -999.250 -999.250 RCNT.CNL -999.250 CFTC.CNL -999.250 -999.250 TENS.CHL 1370.000 GR.CHL 47.031 ILM.DIL TENS.FDC CALI.FDC TNRA.CNL CFTC.CNL GR.CHL -999.250 SFLU. OIL -999.250 -999.250 GR-DIL -999.250 -999.250 RHOB.FDC -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999.250 TENS.CHL 1310.000 -999.250 -999.250 -999.250 -999.250 -999.250 43.375 **** FI:LE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001A02 DATE : ~8/09/10 MAX EEC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01AO2 DATE : 8'8/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 10-SEP-1988 12:17 PAGE: 18 THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS ~-f~ SCHLUMBERGER LOGS INCLUDED WITH THIS FILE (EOIT.O02): <SEE FILE EDIT.O01 FOR 6" SAMPLED DIL/FDC/CNL/GR DATA> FORMATION DENSITY COMPENSATED LOG (.FDH) FIRST TO LAST READING: 10334" TO 9397' COMPENSATEO NEUTRON LOG (.CNH) FIRST TO LAST READING: 10320' TO 9397' TABLE TYPE :' CONS TUNI VALU CN ARCO ALASKA INC. FN KUPARUK WN NATI U.S.A. STAT ALASKA COUN NORTH SLOPE SEC T TOWN RANG gE FL 745m FNL E 1855mFWL OPER MALLARY SON 530801 APIN 50-029-21837-00 DEFI COMPANY NAME FIELD NAME WELL NAME NATION STATE OR ~ROVINCE COUNTY SECTION TOWNSHIP RANGE FIELD LOCATION OPERATORmS CODE SERVICE ORDER' NUMBER API SERIAL NUMBER TABLE TYPE : CURV OEFI DEPT DEPTH CHANNEL NAME TENS TENSION DPHI DENSITY POROSITY DRHO DELTA RHO RHOB BULK DENSITY CALI CALIPER IS TAPE VERIFICATION LISTING CMLUMBERGER ALASK~ COMPUTING CENTER 10-$EP-1988 12:17 PAGE: 19 OEFI GR GAMMA RAY TENS TENSION NPHI NEUTRON POROSITY TNRA CALIBRATED THERMAL NEUTRON RATIO RTNR RaW THERMAL NEUTRON R6TIO RCFT RCFT RCNT RCNT CFTC CFTC CNTC CNTC GR GAMMA RaY DATA FORMAT SPECIFICATION RECORD *~ SET TYPE - 64EB ~ TYPE REPR C09E VALUE I 66 0 2 66 0 3 73 6¢ 4 56 1 8 68 0.099 9 65 FT 11 66 16 13 66 0 14 65 FT 15 66 68 15 66 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER ~ LOG TYPE CLASS MOO NUMB SAMP ELEM CODE OEPT FT 530801 TENS FDH LB 530801 DPHI FDH PU 530801 DRHO FDH G/C3 530801 RHO~ FDH G/C3 530801 CALI FDH IN 530801 GR FDH G~PI 530801 TENS CNH LB 530801 NPHI CNH PU 530801 TNRA CNH 530801 RTNR CNH 530801 RCFT CNH CPS 530801 RCNT CNH CPS 530801 68 6 8 68 68 68 68 68 68 6.8 68 68 68 68 PROCESS CHEX) 0000000000 0000000000 0000000000 0~0000000.00 0000000000 0000000000 0000000000 0000000000 00~00000000 0000000000 0000000000 0000000000 0000000000 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASK~ COMPUTING CENTER · 10-SEP-1988 1Z:17 PAGE: ZO NAME SERV UNIT SERVICE API &PI API ID ORDER ~ LOG TYPE CLASS .AP! mILE NUMB NUMB MO0 NUMB SAMP ELEM CFTC CNH CPS 530801 CNTC CNH CPS 530801 GR CNH GAPI 530801 SIZE 2 1 1 4 2 I 1 2 I I REPR PROCESS CODE (HEX) 68 0000000000 68 0000000000 68 0000000000 DATA DEPT. 10407.000 TENS.FOH RHOB.FDH 2.382 CALI.FDH NPHI.CNH 38.586 TNRA.CNH RCNT.CNH 2003.490 CFTC.CNH DEPT. 10400.000 TENS.FDH RHOB.FDH 2.382 CALI.FDH NPHIoCNH 38.586 TNRA.CNH RCNT.CNH 2003.490 CFTC.CNH DEPT. 10300.000 TENS.~DH RHOB.FDH 2.490 CALI.FDH NPHI.CNH 36.223 TNR~oCNH RCNT.CNH 2068.101 CFTC.CNH DEPT. 10200.000 TENS.FDH RHOB.FOH 2.471 CALI.FOH NPHI.CNH 43.788 TNRA.CNH RCNT.CNH 1946.953 CFTC.CNH DEPT. 10100.000 TENS.FDH RHOB.FDH 2.440 CALI.FDH NPHI.CNH 36.275 TNRA.CNH RCN'T.CNH 2150.514 CFTC.CNH DEPT. 10000.000 TENSoFDH RHOB.FOH 2.595 CALI.FDH NPHI.CNH 37-199 TNRA.CNH RCNT.CNM 2200.260 CFT:C.CNH DEPT. 9900.000 TENS.FDH RHOB.FDH 2.401 CALI.FDH NPHI.CNH 47.648 TNRA.CNM RCNT.CNH t748.590 CFTC.CNH DEP'T. 9800.000 TENS.FDH RHOB.FDH 2.357 CALIoFDM NPHI.CNH 42.703 TNRA.CNH RCNT.CNH 1773.088 CFTC.CNH 46~8.000 8.000 3.099 673.669 4812.000 6.281 3.099 673.669 7184.000 8.500 3.118 736.286 6920'000 8.828 3.55'9 593.490 6564.000 8.727 3.1¢0 778.120 6724.000 10.156 3.307 7'78.487 6824.090 13.414 3.994 4135.715 6820.000 10.531 3.638 485.5'77 DPHI.FDH GR.FDH RTNR .CNH CflTC .CNH DPHI.FDH GR.FDH RTNR .CNH CNTC .CNH DPHI.FDH GR.FDH RTNR.CNM CNTC.CNH DPHI .FDH GR.FDH RTNR. CNH CNTC.CNH OPHI.FDH GR.FOH RTNR.CNH CNTC..CNH DPHI.FDH GR .FOH RTNR.CNH CNTC .CNH DPHI.FDH GR.FDH RTNR.CNH CNTC.CNH DPHI.FDH GR.FDH R'TNRoCNH CNTC.CNH 16.238 DRHO.FOH 97.750 TENS.CNH 3.339 RCFT.CNH 2051.452 GR.CNH 16.238 DRHO.FOH 97.750 TENS.CNH 3.339 RCFT.CNH 2051.452 GR.CNH 9.723 DRHD.FDH 98.313 TENS.CNH 3.139 RCFT.CNH 2179.646 GR.CNH 10.855 DRHO.FDH 99.875 TENS.CNH 3.545 RCFT.CNH 1992.310 GR.CNH 12.740 DRHO.FDH 89.500 TENS.CNH 3.667 RCFT.CNH 2295.402 GR.CNH 3.313 DRHO.~DH 107.438 TENS.CNH 3.622 RCFT.CNH 2362.215 GR.CNH 15.088 DRHg. FDH 116.063 TENS.CNH 4.305 RCFT.CNH 1727.880 GR.CNH 17.785 DRHg. FDH 110.063 TENS.CNH 3.833 RCFT.CNH 1754.151 GR.CNH 0.231 4688.000 591.903 97.750 0.231 4812.000 591.903 97.750 0.073 7184'000 637.439 98.313 0.086 6920.000 4~4.326 99.875 O.OZO 6564.000 683.155 89.500 -0.032 6724.000 729.2.47 107.438 0.075 6824-000 438,113 116.063 0.019 6820.000 470.517 110.063 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 9700.000 TENS.FDH RHOB.FDH 2.299 CALI.FDH NPHI.CNH 43.185 TNRA.CNH RCNT.CNH 1613.779 CFTC.CNH DEPT. 9600.000 TENS.FDH RHOB.FDH 2.340 CALI.FDH NPHI.CNH 44.004 TNRA.CNH RCNT.CNH 1713.127 C~TC.CNH DEPT. 9500.000 TENS.~DH RHOB.FDH 2.488 CALI.FDH NPHI.CNH 35.483 TNRA.CNH RCNT.CNH 2519.708 CFTC.CNH DEPT. 9400.000 TENS.FDM RHOB.FDH 2.398 CALI.FDH NPHI.CNH 37.697 TNRA.CNH RCNT.CNH 1964.164 CFTC.CNH DEPT. 9397.199 TENS.FDH RHOB.FDH 2.342 CALI.FDH NPHI.CNH 40.282 TNRA.CNH RCNT.CNH 1924.277 CFTC.CNM 10-SEP-1988 12:17 6460.000 DPHI.FDH 12.742 GR.FDH 3.732 RTNR.CNH 466.540 CNTC.CNH 6492.000 DPHI.FOH 14.422 GR.FDH 3.821 RTNR.CNH 467.901 CNTC.CNH 6384.000 DPHI.FDH 10.156 GR°FDH 3.214 RTNR.CNH 804.114 CNTC.CNH .6192.000 DPHIoFDH 10.664 GR-FOH 3-376 RTNR.CNH 591.968 CNTCoCNH 6172.000 OPHI.FDH 11.031 GR.FDH 3.529 RTNR.CNH 557.947 CNTC.CNH PAGE: 21 21.283 DRHO.FDH -0.008 101.313 TENS.CNH 6460.000 3.960 RCFT.CNH 414.099 1717.126 GR.CNH 101.313 18.795 DRHD.~DH -0.005 129.000 TENS.CNH 6492.000 4.381 RCFT.CNH 408.577 1743.232 GR.CNM 129.000 9.833 ORHO.FOH 0.023 381.500 TENS.CNH 3.105 RCFT.CNH 609.093 2428.759 GR.CNH 381.500 15.258 DRHO.FDH 0.021 141.250 TENS.CNH 6192.000 3.577 RCFT.CNH 529.929 1971.423 GR.CNH 141.250' 18.651 DRHO.FDH -0.013 130.250 TENS.CNH 6172.000 3.963 RCFT.CNH 511.551 1930.938 GR.CNH 130.250 ENO OF DATA · ~¢~ FILE TRAILER ~¢ FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001A02 DATE : 88/09/10 MAX AEC SIZE : 1024 FILE 'TYPE : LO LAST FILE : · ~ TAPE TRAILER ~ SERVICE NAME : EDIT DATE : 88/09/10 ORIGIN : FLIC TAPE NAME : 72902 CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : LIS TAPE, ARCO KUPARUK 3 0-2, API #50-029.-21837 IS TAPE VERIFICATION LISTINr~ CHLUMBERGER ALASKA COMPUTING CENTER lO-SEP-198B 12:17 PASE: 22 ~ REEL TRAILER ~ SERVICE NAME : EDIT DATE : 88/09/10 ORIGIN : FLIC REEL NAME : 72902 CONTINUATION ~ : PREVIOUS REEL : COMMENT : LIS TAPE, ARCO KUPARUK 3 0-2, API ~50-029-21837
