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Home My WebLink About195-063ON oR'BEFORE 95 .... 063 HI..ID L. 107 .....i.2. x'50 'i 9!5 ..... 063 S'FF;,'AT HI RES DIP L. 5200--- 10617 3 95--08::} ~..-:.3TEAT i---fi iq,:ES ()IF' i... 'i060.q .... 'i233'i a. 95-.-06s STF,:AT HI R.ES r'.,iF .... ...... . L. 5ix"~5209 i 95 ..... 08!} FH'T PRESS & S,&I','iF' L. 11516 .... 12170 · i 0 ..... 4'.- q ~ R' r' C, H P i... E T i. 0 iq D A T k / ~ : ., ,. ., Ai""e dr"y <.l-¥tch samp'Jes Was Lhe v,~eii eot'ed? .. , r'~ Y I n 'i k i a 'i C O i,'1 hi [' N i S 95~--063 '~'F<AT m~ RE'.}?, DIP L 5200'~ 10617 95 .... 063 L.p~K2, TRAT HI RES DIP 95---063 .L~S~'.,TRA"F t--i5. RES DSF' . 95---063 ~ PRESS & SAh~P ~:~5 063 L. DT 9 s o 6 s ~y L/s F L/[.;, Z 'F~: / s 95--06 S ~IL/S Fi./D ITE/SP 9 5 -~-.n .... 6 ~', ~ 2 a T L 512--12294. !... 512-.-12322 T D .T. T E//!... i3, 'F --'- D/' (.': N T ' ,3 .~ [/) S ;'[ ~ S H I..':, T F: F T 9 5 ..... 06 3 9 5 --- 0 6 ~"~.ND OF WELL. L...OG i') SF'ERRY ,q. i'..)ISI<S DAI'A i08 .... 12350 F.].'iNAI... 0 'i /"16//'96 .... -N-GI0/DGF.':/-E. WR'a.- ........... I.. 'i"40'-"9600' H'D ...................................... i ,': $ ~. '? 10/;l '?/..95, ... I 0'-407 DAZI...Y WE!...L OF'S Ar'e dr"y d':i'Ech sarnpless r'equ'?r'ed? Ar'e we'l'l t:es-i:s r'-equir'ed ~.' 2. I r i i... i ,.~'~ i C O kl k'~ E N T S no Arid r'ece'i'ved? ~ no n ,?,. 'J y s '¥ s 8: d e s c r" i' p i: i' o n r' e c e i '.,' e d ~..... ~ .1 Geoio,~;jS'ca'] Mater"ials llnven't:or'y P E B'. M Z T D A T A T D A T A_.i,~' L I.J S 95'-063 MUD L 10'? .... 12350 95 ...... 063 STRAT t--IZ RES DIP L 5200"i061'1 95---063 S'TRAI' HI RES OtP L 10604~'123-31 95-..063 STRAT HI RES DIP L 51'2 52(39 95-~-063 FMT PRESS & SAMP L '11516-'12170 95 .... 06S 'rN/LDT 95~---063 DSSI L 512-w1229a. L 512-12294 L 512 .......J°3~:~ 2©¢, L 512,~12322 95--~063 95~--06~ 95---063 95--06~ DI[../'SF!.../DITE/SP b I L/:SF L/bITE/S P 69_-,,° ?, 6924 T DITE/LDT-"D/CNTIG~DSI~SHDT T RFT 95 .... 063 END OF \.?ELL LOG D SPERRY 8 DISKS DATA 108~'123,r':i0 i0-*'/+0'? R rOMi.:,LETION DATE / / /' /i / /' -' / / TO t /' DAII...Y WELL. OPS R / /' / / / /' Ar.e dr'.y W a s t h e Ar'e ~,vel 1 We'i 1 i s C C, Iq M E N T S di'_.iz, ch samples reqL, ired? PLUGG!~%~ & .LocATION CLEA~.a_NCE REPORT State of AlaSka Memcrandu_m To File: APr MOo Well Na_~e Ooerator .ALASKA OIL & GAS CONSERVATION Lease Note casinq size, wt, deot~, cmt vol & orocedure. Perf inta~als - tops: ~ ~) Review the well file, and-comment on plugging, well head Code Sigae ! ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ATO 1202 Phone 265-6890 Fax 265-6224 September 4, 1996 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 (907) 276-7542 (fax) Re: Well Completion Report, Form 10-407 Final Operations Report Summary Bufflehead No.1 Exploratory Well Permit No. 95-63 "TIGHT HOLE" Gentlemen: As per the APD approval for this well, please find attached the Well Completion Report (Form 10-407) and the final operations summary for the ARCO Bufflehead No. 1 for the final P&A and reserve pit close out operations. The well is now P&A'd, and the location is closed out, pending a Final Location Clearance ruling from your staff. Please contact our office to arrange for access to this location for a site inspection as required. You will notice that the well is considered a "TIGHT HOLE", and we would request that your office maintain the information on this well accordingly. If you have any questions or require any additional information on this project, please contact me at 265-6890. Sincerely, Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany CC: Mr. Joseph A. Dygas Chief, Branch of Lease Operations United States Department of Interior BLM- District Office 6881 Abbott Loop Road Anchorage, AK 99521 (907) 267-1 441 (907) 267-1304 (fax) RECEIVED SEP 0 5 1996 Alaska Oil & (]as Cons, Commission Anchorage "'--'-" STATE OF ALASKA ' A,_,,SKA OIL AND GAS CONSERVATION CCi; .... ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL E~ GAS E~] SUSPENDED E~] ABANDONED [] SERVICE E~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-63 · 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-133-20466 4 Location of well at surface ~-'? ~'~.-.,v,,~ f'L'.': ......... [ '..':ji'~ ~ ! ~ 9 Unit or Lease Name 1412' FEL, 2238' FSL, SEC. 3, T8N, RDW, SM ~,,. :~'~- ~ '~ 1 '~ !, Bufflehead At Top Producing Interval i ._~ _.~¢'"W~ [ i~)~,/'-~ [ 10 Well Number 1412'DepthFEL, 2238' FSL, SEC. 3, T8N, RDW, SM~, ~.~..~~~ _ BUFFLEHEAD #1 At Total ~..~..~,~:~.~.:~¢~_>~_~.~ : 11 Field and Pool 1412' FEL, 2238' FSL, SEC. 3, T8N, RDW, SM WILDCAT 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 302'I ADL A-028405 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 16-Sep-95 09-Dec-95 7/27/96 Abandoned NA feet MSL NA 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 DirectionalSurvey 120 Depth where SSSV set 121 Thickness of permafrost 12350' MD, 12350'TVD Surface YES ~ NO [~I NA feet MDI NA 22 Type Electric or Other Logs Run TO BE SENT UNDER SEPARATE COVER BY EXPLORATION GEOLOGY 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 20" 169# SURF 107' N/A Driven to refusal 13-3/8" 72# N-80 SURF 512' 17.5" 850 sx G 9-5/8" 53.5# L-80 SURF. 5204' 12.25" 1100 sx Lead G, 425 sx Tail G 7" 29# L-80 SURF. 10620' 8.5" 470 sx Lead G, 186 sx Tail 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) N/A NA 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED well P&A'ed. See diagram attached. Surface plucj: 10 bbls Class G Annular plug: 145 bbls Class G 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc,) I N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. TO BE SENT UNDER SEPARATE COVER BY EXPLORATION GEOLOGY ORIGINAL RECEIVED SEP 0 5 1996 Alaska 011 & Gas Cons. Commission Anchorage Form 10-407 Submil in duplicate 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. TO BE SENT BY EXPLORATION GEOLOGY 31. LIST OF A-I-I-ACHMENTS P&A diagram, Daily Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. T i t i o ~/~/~ ¢-~//~"'- ~ DATE INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28:1f no cores taken, indicate "none". R E C E IV E Form 10-407 SEP 0 5 1996 Alaska Oil & Gas Cons. Commission &nnhnrnnn BUFFLEHEAD #1 P&A MARKER POST INSTALLED Final P&A Plugs 13.6 PPG KILL WEIGHT MUD IN ANNULUS TYONEK @ 5817' TVD TYONEK 'D' MARKER @ 6175' TVD PRESSURED TYONEK GAS SANDS @ 8202' TVD Final P&A Schematic I ~// I ::'".': I =// I I..'.':.'..': I.=5, I=~/I L'.::.':.: ~ =// L'.'.:.'; ,,._/,/, ?....:: I'-// ,. :'.".::': I'.// ': :'.:::'.: ClBP @ 255' I-'/'/ :;'::::': I '- / ~ ' :.".'..:.~ MUD ! 2':.".':::'.] , ==,-: (.':: ::.l ~- - ':::'::"1 '~m.. ::'...;; ................ -- -- --t~r.: '.' .".. '.'.~ I ::::::::::::::::::::::::::::::::::::::::::::::: i I ".'.:: :.'.'". ::.:: ".'.:'. :.'..': :.'.:: :.'..'.' :.'.-': :-'.-': ::. I I I ! I I ! I I ~ 1 1.1 PP~ I MUD I I I I I I I ! ! ~:mm-'..-.~.~1! EST CEI ,,,~ ': :}'}: :?}: :}~ FROM C jr.':?:::.'.':? ?i'..';'i'..';'i::' :.'.~.': :.'.":: :.'.".': :.':': :.'..': ::~':::.~::::..~'i:.'..?. [.-..:....-::.....::: ~~... -._.'~ :::...::.....: ::! [::.'....':[...':¢~ 2;.:..'.:.~ '":' ":' ":' ~.'.';!.'.'i ~.........., L.': ":.:: ::.:: :.' ::::::::::::::::::::::::::::::::::::::::::::::: ::.:::.'.":::1 .::":.":::.::":. :::.:::".::::.::::.::::.:::.'.::::.":"".:::.'.:::: :.:.':: :.:.i: i.'l CEMENT TOP @ 10,216' TVD ;EMENT BOND LOG ,:-.",:..".:-.:: ..'.:.,'. :-.'.:..".:..".;,.'.:.; :.;'.:.;'.:.'.',:.;'.:.:'.:.;'-:-;'.:.:'.:.;'.: ;.'.'.:.. ::..': :&.'.'..': ::/:.':.::.'.'.:: :: .'..':..'...'.' 11.1 ppg MUD HEMLOCK @ 11507' I I I HEMLOCK SHOWS, 11925-12085*:".'.'".'-:".':#}"~:'.'.:":-v.'.'"-':..~-~ [ :.....: :. ...: ?....: :. . .. .. .,.. . .:: :. ...: :. ...: :. :.: :. . I I WEST FORELANDS @ 12102' I 11.1 ppg I I MUD I i ARCO Alaska, Inc. 20" STRUCTURAL CSA 107' DRIVEN TO REFUSAL J TD=12,350' 113-3/8" CONDUCTOR CEMENTED TO SURFACE 9-5/8" CSA 5,204' (TVD) CEMENTED TO SURFACE PLUG #3, 5080-5331' ABOVE CIBP @ 5362' EZSV RETAINER @ 10559' 10,620' (TVD) CSA 512' PLUG #2, 10509-10734' (pressure tested to 3000 psi, OK) PLUG #1, 11811-12150' (tagged on 12/12/95) TWM, 9~4~96 Date: 9/3/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:BUFFLEHEAD %1 RIG:NABORS WELL ID: AX9312 AFC: AX9312 -- STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST TYPE' FIELD: WILDCAT SPUD: START COMP: BLOCK: FINAL: TIGHT HOLE API NUMBER: 50-103-20466-00 07/08/96 (127) TD'12350'( 0) SUPV: 07/09/96 (128) TD'12350' ( 0) SUPV: 07/10/96 (129) TD' 12350' ( 0) SUPV: 07/11/96 (130) TD' 12350' ( 0) SUPV: 07/12/96 (131) TD'12350' ( 0) SUPV: 07/13/96 (132) TD:12350' ( 0) SUPV: 07/14/96 (133) TD:12350' ( 0) SUPV: 07/15/96 (134) TD:12350' ( 0) SUPV' LD MW' 0.0 PV/YP: 0/ 0 APIWL: 0.0 Mobilizing contractor equipment for Bufflehead %1 wellsite closure and P&A. MW: 0.0 PV/YP' 0/ 0 APIWL: 0.0 Veco circ 1000 bbls of fluid from pit across shaker and into Dowell tanks. Dowell rigged up pump unit. Held pre-pump safety meeting. Test lines to 3500 psi. Started pumping into 7" by 9-5/8" annulus. Shut in well. MW' 0.0 PV/YP' 0/ 0 APIWL. 0.0 VECO circ 2000 bbls of fluid from pit across shaker and into Dowell tanks. Open well to start injecting. MW' 0.0 PV/YP' 0/ 0 APIWL' 0.0 Veco continued to pump fluid from reserve pit across shaker and into Dowell tanks for injection. MW: 0.0 PV/YP' 0/ 0 APIWL. 0.0 Veco continued to pump fluid from reserve pit across shaker and into Dowell tanks for injection. MW' 0.0 PV/YP: 0/ 0 APIWL: 0.0 Veco continued to pump fluid from reserve pit across shaker MW' 0.0 PV/YP' 0/ 0 APIWL: 0.0 Dowell injected fluid. Veco continued to pump fluid from pit across shakers to Dowell tanks. MW: 0.0 PV/YP: O/ 0 APIWL: 0.0 VECO continued to work on ramp and roadway down center of pit - put trackhoe on roadway stirred up pit w/hoe - continue to haul fluid with vac trucks by backing down roadway. Dowell injected fluid. RECEIVED SEP 0 5 1996 Alasl~a 011 & Gas Cons. comrnig~ion Anchorage Date: 9/3/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 07/16/96 (135) TD:12350' ( 0) SUPV: LD 07/17/96 (136) TD:12350' ( 0) SUPV:LD 07/18/96 (137) TD:12350' ( 0) SUPV: LD 07/19/96 (138) TD:12350' ( 0) SUPV: LD 07/22/96 (139) TD:12350' ( 0) SUPV:LD 07/23/96 (140) TD:12350' ( 0) SUPV: LD 07/24/96 (141) TD:12350' ( 0) SUPV:LD 07/25/96 (142) TD:12350' ( 0) SUPV: LD 07/26/96 (143) TD:12350' ( 0) SUPV: LD 07/27/96 (144) TD:12350' ( 0) SUPV:LD MW: 0.0 PV/YP: O/ 0 APIWL: 0.0 VECO continued to haul fluid by backing vac truck down ramp and onto roadway, then across shaker and into Dowell tanks. Continue to inject fluid. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 VECO continued to haul fluid to Dowell tanks. Dowell continued to inject fluid. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 VECO continues to haul fluid into Dowell tanks. Dowell injecting fluid. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 Finish taking fluid from pit, it became too thick to pump. Dowell injecting fluid into annulus. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 Checked the hardness of the cuttings and cement in pit. Prepare to close liner. Cumulative cement used in reserve pit to stabilize cuttings was 3540 sx. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 Release shaker and tank. Clean up location. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 Work on liner. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 Pump 10 bbls Class G cement in top of 7" casing for P&A surface plug. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 Inject 40 bbls of fluid, followed by 145 bbls Class G cement into 9-5/8" x 7" annulus for P&A annular plug. Total cumulative volume of fluid injected into annulus is 11,148 bbls. Note: Joe Russell with BLM witnessed all P&A plugs set. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 Cut off well head 11' below pad level. Install P&A marker post. Back fill well cellar and septic tank hole. Date: 9/3/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 07/28/96 (145) TD:12350' ( 0) SUPV:LD MW: 0.0 PV/YP: O/ 0 APIWL: 0.0 Finish sealing the liner for containment of reserve pit. Note: Alaska Department of Environmental Conservation inspected and approved cuttings stabilization and pit liner sealing operation prior to backfilling of reserve pit. 07/29/96 (146) TD:12350' ( 0) SUPV: LD MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 Veco continued to work on filling in reserve pit. 07/30/96 (147) TD:12350'( 0) SUPV:LD MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 Veco continued to work on filling in reserve pit. 07/31/96 (148) TD:12350' ( 0) SUPV:LD MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 Finish pulling 6" casing and cementing water well. 08/01/96 (149) TD:12350' ( 0) SUPV:LD MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 Veco finished leveling location and demobilize all equipment. 08/02/96 (150) TD:12350' ( 0) SUPV: LD MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 Veco finish picking up equipment. Peak built and installed gate in road leading to Bufflehead #1. Picked up location. End of WellSummary for Well:AX9312 .. ARCO Alaska, Inc. Post Office Box 10036o Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Bufflehead (Permit No. 95-63) Well Completion Report Dear Mr. Commissioner: ARCO Alaska, Inc., as operator of the exploration well Bufflehead, submits the the enclosed "Well Completion Report" (form 407). The Commission is requested to keep confidential the enclosed information due to the exploratory nature of the well. If you have any questions regarding this matter, contact me at 265-6890 or Sharon Allsup-Drake at 263-4612. Sincerely, T. Mc Kay Drilling Engineer Kuparuk Development TWMc/skad RECEIVED MAY ~ 1 1996 STATE OF ALASKA ALA,~,,A OIL AND GAS CONSERVATION COMrv,~SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~ GAS ~ SUSPENDED r~] ABANDONED [] SERVICE E~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-63 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-133-20466 4 Location of well at surface 9 Unit or Lease Name 1412' FEL, 2238' FSL, SEC. 3, T8N, R9W, SM~'~;:;-7.';:~"ii'i :i';;':: "i t~~.':--?¢ Bufflehead At Top Producing Interval ~' ..... ' i1.. *~,'~L~,~'~'~; 10 Well Number 1412' FEL, 2238' FSL, SEC. 3, T8N, R9W, SM ~ BUFFLEHEAD #1 AtTotal Depth ' ~~-.:;J_. : !;;_~J¢.,~--ii 11 Field and Pool 1412' FEL, 2238' FSL, SEC. 3, T8N, R9W, SM ......... ~.--;~ WILDCAT 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Serial No. RKB 302'I ADL A-028405 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 16-Sep-95 09-Dec-95 12-16-95 Suspended NA feet MSLI NA 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey [20 Depth where SSSV set I 21 Thickness of permafrost 12350' MD, 12350'TVD 255'TVD YES J J NO JxJI NA feet MDI NA 22 Type Electric or Other Logs Run TO BE SENT UNDER SEPARATE COVER BY EXPLORATION GEOLOGY 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 20" 169# SURF 107' N/A Driven to refusal 13-3/8" 72# N-80 SURF 512' 17.5" 850 sx G 9-5/8" 53.5# L-80 SURF. 5204' 12.25" 1100 sx Lead G, 425 sx Tail G 7" 29# L-80 SURF. 10620' 8.5" 470 sx Lead G, 186 sx Tail 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) N/A NA 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ¢ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. TO BE SENT UNDER SEPARATE COVER BY EXPLORATION GEOLOGY 1 1996 ORIGINAL Form 10-407 Submit in duplicate 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. TO BE SENT BY EXPLORATION GEOLOGY 31. LIST OF A'FI'ACHMENTS AS-BUILT SURVEYS, P&A DIAGRAM, AN/D DAILY DRILLING REPORTS 32. I hereby certify that the~foregoing is lue and correct to the best of my knowlege. b 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- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:BUFFLEHEAD #1 RIG:NABORS WELL ID: AX9312 AFC: AX9312 TYPE: -- STATE:ALASKA AREA/CNTY: ~O~TH SLOPE FIELD: WILDCAT BLOCK: SPUD: START COMP: FINAL: WI: 0% SECURITY: 0 TIGHT HOLE API NUMBER: 50-103-20466-00 09/01/95 (1) TD: 0'( 0) SUPV: DRM 09/02/95 (2) TD: 80'( 80) SUPV:DRM 09/03/95 (3) TD: 80'( 0) SUPV:DRM 09/04/95 (4) TD: 0'( 0) SUPV: DRM 09/05/95 (5) TD: 19'( 19) SUPV:DRM 09/06/95 (6) TD: 0'( 0) SUPV:DCB 09/07/95 ( 7) TD: 0'( 0) SUPV:DCB MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 DRIVING 20" CASING Driving 20" casing to 34' below ground level and welded up joint #2. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 DRIVING 20" CASING Driving 20" casing to 80' below ground level. Crane and hammer down until 16:30. Hammer would not fire and required calling out mechanic and welding. Crane had to double the whip line to handle hammer. Final blow count at 80'=119 blows per foot. Conductor began driving crooked last 20' Tried to straighten by pulling pile with loader. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PROBLEMS WITH 20" CONDUCTOR Determined 20" conductor was driven too crooked to use. Abandoned the 20" 169# H-40 welded casing driven to 80' below GL. Cut off conductor 11' below GL and recovered stub. Left 69' of casing in hole. Dug out and removed cellar ring. Decision based on risk associated with drilling through crooked conductor can cause variety of major problems later on during drilling operations. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 BACKFILLED AROUND CELLAR RING Backfilled and compacted around old and new cellar rings. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 DRILLED 12" LINE PIPE Drilled and drove 12" line pipe rathole sheath to 19' for drilling rig kelly. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MIRU RIG 154 MIRU Nabors 154. Lay out pit liner and weld same for rig footprint. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MIRU RIG 154 MIRU Nabors 154. Set drawworks, off-drillers side doghouse, pits and solids control skids. Set in pump skids and set mud pumps. Set engine skids and boilers. Assemble derrick on ground, and start stringing auxiliary derrick lines. Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 09/08/95 (8) TD: 0'( 0) SUPV:DCB 09/09/95 (9) TD: 0'( 0) SUPV: DCB 09/10/95 (10) TD: 0'( 0) SUPV:DCB 09/11/95 (11) TD: 0'( 0) SUPV:DCB 09/12/95 (12) TD: 0'( 0) SUPV:DCB 09/13/95 (13) TD: 0'( 0) SUPV:DCB 09/14/95 (14) TD: 75'( 75) SUPV:DCB 09/15/95 (15) TD: 107'( 32) SUPV:DCB 09/16/95 (16) TD: 107'( 0) SUPV:DCB 09/17/95 (17) TD: 272' (165) SUPV:DCB MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RU RIG 154 MIRU Nabors 154. Set derrick in position on stand and pin to sub. Start rigup of compounds. MW: 0.0 RU RIG 154 R/U Nabors 154. PV/YP: 0/ 0 APIWL: 0.0 RU RIG 154 R/U Nabors 154. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RU RIG 154 R/U Nabors 154; break tower, Continue rig up of floor, pits, and electrical equipment. Unable to get drawworks power, trying to trace out problem. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RU RIG 154 RU Nabors 154. Electricians working on drawworks problems. MW: 0.0 RU RIG 154 Rig up Nabors 154. PV/YP: 0/ 0 APIWL: 0.0 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 DRIVE 20" CONDUCTOR Rig up Nabors 154. Accept rig at 1400 hfs on 9/13/95. Drive 20" conductor. MW: 0.0 COOL SOW STARTING HEAD Drive 20" conductor. PV/YP: O/ 0 APIWL: 0.0 MW: 8.6 PV/YP: 0/ 0 APIWL: 0.0 BUILD SPUD MUD Cool down bradenhead and pressure test weld. NU diverter system. Function test diverter system. Held pre-spud safety meeting. Build spud mud, circulate pits. MW: 8.6 PV/YP: 16/64 APIWL: 16.8 DRILL 17-1/2" HOLE Build spud mud. Strap and P/U BHA. Fill stack, circ. and check flow line for leaks. Clean out casing. No pump Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 09/18/95 (18) TD: 512' (240) SUPV:DCB 09/19/95 (19) TD: 512'( 0) SUPV:DCB 09/20/95 (20) TD: 512'( 0) SUPV:DCB 09/21/95 (21) TD: 512'( 0) SUPV:DRM 09/22/95 (22) TD: 512'( 0) SUPV:DRM pressure. Work on %1 mud pump. Clean out gravel/sand from 20" conductor. Spud well at 2030 hfs 9/16/95. Drilling from 107' to 272'. MW: 9.3 PV/YP: 21/28 APIWL: 12.4 N/D DIVERTER Drill from 272' to 512'. R/U and run 13 its. 13-3/8" casing to 512'. Cement casing. MW: 9.2 PV/YP: 20/11 APIWL: 12.4 WAIT ON WELLHEAD PARTS Raise stack, hang off, latch on casing string and set slips on 13-3/8" casing. N/D diverter system. Install packoff support bushing and N/U 21-1/4" casing head. Leak through inner seals on packoff bushing. Remove wellhead and bushing. Check seals, backup seals and find no obvious problem. Caliper all components. Reinstall backup (new) packoff support bushing and install casing head. Test failed, through ring gasket. Ring gasket damaged. Wait on additional ring gaskets from FMC-Anchorage. MW: 9.2 PV/YP: 19/16 APIWL: 12.4 WAIT ON SOW HEAD Nipple up 21-1/4" x 13-5/8" casing spool. Could not pull flanges together. Standoff more than 1/4" at ring groove. N/D wellhead and inspect. Grind down slip segments 1/4", tested seat with support bushing. Bushing no longer in contact with slips. Pipe is off center in casing bowl by 5/32". Nipple up spool again. Use hydraulic torque wrench to tighten studs. Flanges still not pulling together and will not test. Nipple down spool. Try to pull 13-3/8" casing slips. Installed third packoff support bushing. No success with seat in wellhead. Removed packoff bushing and prepared cellar for cutting 20" casing. MW: 9.1 PV/YP: 15/ 8 APIWL: 13.2 NIPPLE UP BOP STACK Waiting on SOW head and engineering recommendations from FMC. Modify packoff support bushing. Welders cut 1/8" metal from bottom outside diameter and 1/8" metal from bottom chemfer diameter. Grind out cuts. Install packoff support bushing and wellhead. Pressure test head packoff and seals to 2000 psi. Install test plug. Nipple up wellheads. Nipple up BOP stack. MW: 9.0 PV/YP: 12/ 5 APIWL: 12.4 NIPPLE DOWN BOPE Nipple up BOPE. Rig up and test BOPE. Had ring gasket failure between B and C wellhead sections during test #4. Set back kelly and lay down test joint. Nipple down BOPE at wellhead to inspect ring gasket and groove. Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 4 09/23/95 (23) TD: 512'( 0) SUPV:DRM 09/24/95 (24) TD: 512'( 0) SUPV:DRM 09/25/95 (25) TD: 1142' (630) SUPV:DRM 09/26/95 (26) TD: 2245' (1103) SUPV: DRM 09/27/95 (27) TD: 3190' (945) SUPV:DRM 09/28/95 (28) TD: 4061' (871) SUPV:DRM 09/29/95 (29) TD: 4241'(180) SUPV:DRM 09/30/95 (30) TD: 4740'(499) SUPV:DRM MW: 9.0 PV/YP: 13/ 6 APIWL: 12.4 NIPPLE UP BOPE. TORQUE FLANGE Finished nipple down BOPE. Inspection of top of the 20-1/4" x 13-5/8" head and the bottom of the 13-5/8" x 13-5/8" head determined both flanges were fluid cut. Broke out and layed out damaged wellheads. PU and installed 21-1/4" x 13-5/8" casing head. Tested packoff and seals. OK. Picked up and installed 13-5/8" casing head. Nipple up BOPE. MW: 9.0 PV/YP: 13/ 6 APIWL: 12.4 DRILL CEMENT & FLOAT COLLAR Pressure test BOPE. Pressure up on mud line, had leak in union. Pull test plug. Install new mud line union. Retest mud line. Leak in different union. Repair union and test line. Held OK. Run in hole with 12-1/4" bit and drill collars. Drilling on float collar at 426' MW: 9.0 PV/YP: 13/ 8 APIWL: 11.2 DRILLING Drill out float collar @ 426' and cement to 490'. Pressure test 13-3/8" casing to 3000 psi for 10 min, OK. Drill cement from 490' to 512', casing shoe at 512' and new hole from 512' to 522'. Perform formation integrity test to 12.0 ppg EMW, OK. Drill from 522' to 1142'. Survey on wireline. MW: 9.7 DRILLING Drilling from 1042' to 2245' PV/YP: 20/12 APIWL: 8.0 MW: 9.8 DRILLING Drilling from 2245' to 3190' PV/YP: 19/12 APIWL: 8.0 MW: 9.8 PV/YP: 19/15 APIWL: 7.2 TRIP TO REPAIR RIG Drilling with bit #3 from 3190' to 4061'. Survey on wireline. Lost power to drawworks. Lost #3 engine clutch and #2 pump block bearing. MW: 9.9 PV/YP: 20/16 APIWL: 7.4 DRILLING TOH to casing shoe to repair engine clutch and pump compound bearing. Rig Repair. Replace %2 motor clutch and compound bearing. RIH. Drilling with bit %3 from 4061' to 4241' MW: 9.7 PV/YP: 18/16 APIWL: 7.8 DRILLING Drilling with bit %3 from 4241' to 4740' Survey on wireline. Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 5 10/01/95 (31) TD: 4883'(143) SUPV:DRM 10/02/95 (32) TD: 5078'(195) SUPV:DRM 10/03/95 (33) TD: 5210' (132) SUPV: DRM 10/04/95 (34) TD: 5210' ( 0) SUPV: DcB 10/05/95 (35) TD: 5210' ( 0) SUPV:DcB 10/06/95 (36) TD: 5210' ( 0) SUPV:DcB 10/07/95 (37) TD: 5210' ( 0) SUPV:DcB 10/08/95 (38) TD: 5308'( 98) SUPV:DcB MW: 9.7 PV/YP: 18/22 APIWL: 8.0 RIH WITH BIT %4 Drilling with bit %3 from 4740' to 4883'. Survey on wireline. MW: 9.7 PV/YP: 16/10 DRILLING Drilling with bit %4 from 4883' to 5078'. APIWL: 8.0 MW: 9.7 PV/YP: 18/16 APIWL: 7.8 LOGGING WITH SCHLUMBERGER Drilling with bit %5 from 5078' to 5210'. Circulate Hi Vis sweep, and pump dry job. Short trip to casing shoe prior to logging. Hole has only minor drag. Washed 40' to bottom. No fill. Circulate and condition prior to POOH to log. Drop survey and pump dry job. POOH to log. Chained out. Hold prejob safety meeting and rig up wireline tools. Logging with Schlumberger. Run %1 Triple Combo (DITC, LDT, DNTG, GR, AMS). Loggers TD 5208' MW: 9.8 PV/YP: 16/12 APIWL: 7.8 CBU ON WIPER TRIP / Schlumberger logging with DIT/LDT/CNTG/GR/AMS (triple ~ combo). Log %2, DIT/DSI/Caliper/GR (~Y[c). Log %3, S~DT Dipmeter. MW: 9.8 PV/YP: 18/20 APIWL: 7.8 M/U CIRC. HEAD ON 9-5/8" Circulate and condition mud for casing. Run 128 jts. 9-5/8" casing to 5204' MW: 9.9 NU BOPE Cement casing. Test packoff. PV/YP: 16/12 APIWL: 8.0 MW: 9.8 PV/YP: 22/11 APIWL: 7.4 R/U DOWELL FOR CSG TEST Installed test plug. Unable to get test plug to seal. Pull plug, drain and flush stack, found gravel on packoff support bushing (from ram cavities). Install test plug. Test BOPE 500/5000 psi, annular 500/3500 psi. Drilling cement from 5050 - 5099' MW: 9.8 PV/YP: 17/ 9 APIWL: 7.5 DRILLING 8-1/2" HOLE Pressure test casing to 5000 psi for 30 minutes, held OK. Drill cement from 5099-5170'. Drilling cement from 5170' to shoe @ 5204'; 10' new hole to 5220'. Perform formation integrity test. Drilling from 5220' to 5308' Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 6 10/09/95 (39) TD: 5506' (198) SUPV:DcB 10/10/95 (40) TD: 5757' (251) SUPV:DcB 10/11/95 (41) TD: 6100' (343) SUPV: DcB 10/12/95 (42) TD: 6440' (340) SUPV:DcB 10/13/95 (43) TD: 6603' (163) SUPV:DcB 10/14/95 (44) TD: 6949 (346) SUPV:DcB 10/15/95 (45) TD: 7192 (243) SUPV:DcB 10/16/95 (46) TD: 7289 ( 97) SUPV:DcB 10/17/95 (47) TD: 7511 (222) SUPV:DcB 10/18/95 (48) TD: 7738 (227) SUPV:DrM 10/19/95 (49) TD: 7862 (124) SUPV:DrM MW: 9.7 PV/YP: 12/ 6 APIWL: 7.4 DRILLING 8-1/2" HOLE Drilling from 5308-5345'. RIH BHA 04. Drilling from 5345-5506' MW: 9.8 PV/YP: 14/12 APIWL: 7.4 DRILLING 8-1/2" HOLE Drilling from 5506-5757'. Surveys with Teledrift tool. MW: 10.0 PV/YP: 17/14 DRILLING 8-1/2" HOLE Drilling from 5757-6100'. Wireline survey. APIWL: 7.1 MW: 9.9 DRILLING 8-1/2" HOLE Drilling from 6100-6440' PV/YP: 16/13 APIWL: 6.5 MW: 10.0 PV/YP: 21/12 APIWL: 6.5 DRILLING 8-1/2" HOLE Drilling from 6440-6603'. Test BOPE 350/5000 psi and 350/3500 psi annular. MW: 10 1 PV/YP: 15/14 DRILLING 8-1/2" HOLE Drilling from 6603' - 6949' Wireline survey. MW: 10 1 PV/YP: 18/14 DRILLING 8-1/2" HOLE Drilling from 6949' to 7192'. Wireline survey. MW: 10 3 DRILLING 8-1/2" HOLE Drilling from 7192' to 7289' PV/YP: 18/15 APIWL: 6 0 APIWL: 5 2 APIWL: 4 8 MW: 10 1 PV/YP: 16/14 APIWL: 5 2 DRILLING 8-1/2" HOLE Drilling from 7289'-7511'. Survey with single shot. MW: 10 1 PV/YP: 19/18 APIWL: 4 8 DRILLING 8-1/2" HOLE Drilling and Teledrift surveys from 7511'-7738' MW: 10 1 PV/YP: 19/17 APIWL: 4 4 DRILLING 8-1/2" HOLE Drilling and Teledrift surveys form 7738'- 7862' Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 7 10/20/95 (50) TD: 8140' (278) SUPV: DrM 10/21/95 (51) TD: 8235'( 95) SUPV:DrM 10/22/95 (52) TD: 8300' ( 65) SUPV:DrM 10/23/95 (53) TD: 8359'( 59) SUPV:DrM 10/24/95 (54) TD: 8609' (250) SUPV: DrM 10/25/95 (55) TD: 8815' (206) SUPV:DrM 10/26/95 (56) TD: 8972'(157) SUPV:DrM 10/27/95 (57) TD: 8972' ( 0) SUPV:DrM MW: 10.2 PV/YP: 19/18 APIWL: 4.2 DRILLING 8-1/2" HOLE Drilling and Teledrift surveys from 7862 to 8140'. MW: 12.8 PV/YP: 25/18 APIWL: 4.4 DRILLING 8-1/2" HOLE Drilling and Teledrift surveys from 8140' to 8206' Circulate and raise mud weight from 10.1#/gal to 12#/gal. Well bleeding in slowly and swabbing while working pipe. Shut in well. Opened up well and circulated to increase mud weight to 12.7#/gal. No flow. Drilling from 8206' to 8235' MW: 13.2 PV/YP: 28/18 APIWL: 4.2 SHORT TRIP Drill and Teledrift survey from 8235' to 8300'. Short trip to check for swabbing. Tight 25K @ 8025'. Ledge on RIH at 5210. Watched hole with flashlight. No evidence of swabbing. Hole fill normal. Circulate bottoms up. Gas 5974 units. Increased mud weight to 13.3#/gal. MW: 13.3 PV/YP: 26/15 APIWL: 4.2 DRILLING Pressure test BOPE 250 psi iow prsr. and 5000 psi high prsr. Circulate bottoms up prior to drilling. Bottoms up gas 1596 units. Drilling with bit #11 from 8300' to 8359' MW: 13.3 PV/YP: 28/20 APIWL: 4.2 DRILLING Drilling and teledrift surveys from 8359' to 8609' MW: 13.3 PV/YP: 30/20 APIWL: 4.0 DRILLING Drilling and teledrift surveys with bit %11 from 8609' to 8815' MW: 13.3 PV/YP: 28/24 APIWL: 4.5 DRILLING Drilling and teledrift surveys with bit %11 from 8815' to 8972'. MW: 13.6 PV/YP: 25/16 APIWL: 4.1 CIRCULATE BOTTOMS UP AT 8972' Hole not taking proper amount of fluid. Hole slick. No fill. Circulate and condition mud. Dilute mud system to control yield point. Hole still not taking proper amount of fluid. Hole tight at 7920' to 20k. No fill on trip in hole. Increase mud weight to 13.6#/gal. Dispersed system to control flow properties. Hole took proper amount of fluid. No tight hole. No fill on bottom. RECEIVED MA'{ ~ 1 1996 Alaska Oil & Gas Cons. Commission Anchorage Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 8 10/28/95 (58) TD: 8972'( 0) SUPV:DrM 10/29/95 (59) TD: 8972' ( 0) SUPV:DrM 10/30/95 (60) TD: 9071'( 99) SUPV:DrM 10/31/95 (61) TD: 9238'(167) SUPV:DrM 11/01/95 (62) TD: 9378' (140) SUPV:DrM 11/02/95 (63) TD: 9528'(150) SUPV:DCB 11/03/95 (64) TD: 9796'(268) SUPV:DCB 11/04/95 (65) TD: 9882' ( 86) SUPV:DCB 11/05/95 (66) TD:10000' (118) SUPV:DCB 11/06/95 (67) TD:10146' (146) SUPV: DCB MW: 13.6 PV/YP: 25/15 APIWL: 4.2 RIGGING DOWN DOWELL Run Dialog 64 arm casing caliper from 5000' to surface. Log indicated wear on top joint of 9-5/8" casing. Circulate and condition mud to perform open hole leakoff/pressure test. Pressure test hole to 15.0#/gal EMW (380 psi). No breakover/leakoff pressure observed while pumping. MW: 13.7 PV/YP: 22/15 APIWL: 4.0 REPLACE BENT KELLY Set packer at 450'. Pressure test 9-5/8" casing above RTTS to 4000 psi for 30 min. Test successful. Set test plug and pressure test BOPE. MW: 13.6 PV/YP: 20/13 APIWL: 4.0 DRILLING Replace bent kelly. Pick up mud motor to minimize surface rpm and prevent further casing wear. Drilling with RR bit %12 from 8972' to 9071' MW: 13.6 PV/YP: 21/15 DRILLING Drilling with RR bit %2 from 9071' to 9238' MW: 13.6 POH FOR BIT Drilling from 9238' to 9378' PV/YP: 24/16 MW: 13.6 DRILLING Drilling from 9378' to 9528' PV/YP: 21/13 APIWL: 3.9 APIWL: 3.9 APIWL: 3.8 MW: 13.7 CBU F/TRIP Drilling from 9528-9796' PV/YP: 21/12 APIWL: 3.6 MW: 13.6 PV/YP: 20/12 DRILLING Trip for bit. Drill f/ 9796-9882' APIWL: 3.8 MW: 13.6 PV/YP: 21/10 APIWL: 3.8 CHANGE SWIVEL PACKING Drilling from 9882'-10000'. Test BOPE equipment 250/5000 psi;annular 250/3500 psi. MW: 13.6 PV/YP: 16/10 DRILLING Drill from 10,000' to 10,146'. ADT=ll hours. APIWL: 3.6 Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 9 11/07/95 (68) TD:10251' (105) SUPV:DCB 11/08/95 (69) TD:10310' ( 59) SUPV:DCB 11/09/95 (70) TD:10510' (200) SUPV:DCB 11/10/95 (71) TD:10564' ( 54) SUPV:DCB 11/11/95 (72) TD:10610' ( 46) SUPV:DCB 11/12/95 (73) TD:10755' (145) SUPV:DCB 11/13/95 (74) TD:10755' ( 0) SUPV:DCB/TWM 11/14/95 (75) TD:10755' ( 0) SUPV:DCB/TWM MW: 13.6 PV/YP: 22/14 POH F/ LOGS Drilling from 10146' to 10251' ADT=8.9 hours. APIWL: 3.6 MW: 13.6 PV/YP: 22/14 APIWL: 3.5 DRILLING ~ Log run, triple co . Logger's depth o.k. to Driller's. Drilling from 10251' to 10310' ADT=6.3 hours. MW: 13.6 PV/YP: 20/12 APIWL: 3.4 POH F/ BIT Drilling from 10310' to 10510' ADT=13.2 hours. MW: 13.7 PV/YP: 21/13 APIWL: 3.5 DRILLING POH for bit. Broken #3 cone; lost nose cone portion. Drilling from 10,510' to 10,564' ADT=8.1 hours. Got by nose cone and have not felt junk after first connection. Slow drilling in silt with medium mill tooth. Probably some tooth damage. Averaging 7-8' per hour. MW: 13.6 PV/YP: 20/13 APIWL: 3.5 DRILLING Drilling from 10,564' to 10,581' Losing mud at 15 bbl/hour. Found leak in mud tank, pill pit, losing mud underneath rig onto pit liner. Mud had channeled to back end underneath boilers and was not easily observed in pit liner near leak. 1/2 bbl mud seeped onto pad; spill report submitted. Repair pit pill leak. M/U new bit #18; %17 junk-damaged. Drilling from 10,581' to 10,610' Total ADT=5.5 hours. MW: 13.4 PV/YP: 18/12 APIWL: 3.5 MIX MUD Drilling from 10,610' to 10,755' ADT=9.1 hours. Lose all returns at 10,684' No returns at 5 BPM. Mix and spot 45 bbl 20#/bbl LCM pill. Returns gradually increase to 35-40%. Lost total of 300 bbl. Pull 5 jts DP, monitor hole and mix more mud. Pull 5 stds DP to 10,120' Attempt to gel with only 10% returns. Build mud volume in active system. MW: 13.4 PV/YP: 22/11 APIWL: 4.0 TOH Build mud volume. Hole static but won't circulate. TIH spot LCM pill. Break circulation to get full returns. Circulate and condition mud, check for flow, POOH. MW: 13.4 PV/YP: 21/11 APIWL: 4.5 BATCH MIX CEMENT PLUG Cumulative mud losses 600 bbl to hole. Finish POOH. PU 10 jts 3 1/2 TUB with mule shoe. RIH to Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 10 11/15/95 (76) TD:10755' ( 0) SUPV:DCB/TWM 11/16/95 (77) TD:10755' ( 0) SUPV:DCB/TWM 11/17/95 (78) TD:10755' ( 0) SUPV:DCB/TWM 11/18/95 (79) TD:10755' ( 0) SUPV:DCB/TWM 11/19/95 (80) TD:10755' ( 0) SUPV:DCB/TWM 11/20/95 (81) TD:10755' ( 0) SUPV:DCB/TWM 10,660',breaking circulation at 3500', 7500', 8563', 5671' and 10,135' with full returns. RU Dowell. Break circulation, lost returns. AOGCC authorized postponement of weekly BOP test until cement plug in place. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 TEST BOPE RIH to 10,755'; spot 50 bbl LCM pill. Mix and pump 150 sx 15.8 ppg Neat G with celloflake. Displace to balance. Pull slow to 8192'; fill not correct. RIH to 10,135' Circulate and monitor; well o.k. POOH slow, flow checks o.k. LD tubing. Test BOPs. MW: 13.5 PV/YP: 21/11 APIWL: 5.8 TOH FOR LOGGING Cumulative mud losses 650 bbl. Test BOP. RIH to 10,129' CBU. Wash and ream to 10,620'. CBU; spot 50 bbl LCM pill. POOH slow for logs. MW: 13.4 PV/YP: 21/11 APIWL: 5.2 PULL WEAR BUSHING Cumulative mud losses 656 bbl. ~/ v ~/' Finish POOH. Rig up Schlumberger; run DSI/DIT and Dip w/ GR. Lost 1/2 bbl/hour while logging. MW: 13.5 PV/YP: 24/12 APIWL: 5.0 TOH F/ CSG, LD 5" DRILL PIPE Cumulative mud losses 656 bbl. Run casing caliper log to 500' inside 9 5/8" - no additional wear. PU BHA and RIH to 8459' and CBU. RIH to 10,620'; circulate and condition mud. Spot LCM pill. POOH, LD 5" drill pipe. MW: 13.4 PV/YP: 20/10 APIWL: 5.0 RUN 7' CASING Cumulative mud losses 656 bbl. Finish POOH and LD drill pipe. Safety meeting. Run 7" casing. MW: 13.4 PV/YP: 19/10 APIWL: 5.0 WAIT ON CEMENT, CLEAN PITS Cumulative mud losses 656 bbl. Run 7" casing to 10,620' Circulate pipe w/ partial returns. Spot 50 bbl LCM pill, followed by 470 sx Lead G at 13.8 ppg, followed by 186 sx G Latex Tail at 15.8 ppg. Blow two mud-feed hoses; switch to rig pumps to finish displacement. Bump plug w/ 1450 psi - floats hold. CIP at 0135 11/20/95. 117 psi on annulus. WOC. Spill report submitted: 3.75 bbl mud from blown hoses. Spill clean-up while WOC. RECEIVED MAY ? 1 't996 Gas [;ohs. Commission Ar~ohor~ge Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 11 11/21/95 (82) TD:10755' ( 0) SUPV:DCB/TWM 11/22/95 (83) TD:10755' ( 0) SUPV:DRM 11/23/95 (84) TD:10755' ( 0) SUPV:DRM 11/24/95 (85) TD:10755' ( 0) SUPV:DRM 11/25/95 (86) TD:10755' ( 0) SUPV:DRM 11/26/95 (87) TD:10828' ( 73) SUPV:DRM 11/27/95 (88) TD:10837' ( 9) SUPV:DRM/W~TP MW: 12.8 PV/YP: 14/ 8 APIWL: 5.6 NIPPLE UP BOPE Cumulative mud losses 656 bbl. WOC. Change liners in mud pumps and clean mud pits. Bleed off 45 psi trapped on 7"x9 5/8" annulus. Est 5 gal returned. No flow. Safety meeting. Set 7" casing slips with 320,000 lbs. MW: 12.5 PV/YP: 17/13 APIWL: 5.0 RIG DOWN SCHLUMBERGER NU AND TEST 7" HEAD. NU AND TEST BOPE. RU AND RUN CBT. TOC 10,216' MW: 12.5 PV/YP: 13/12 APIWL: 5.2 PICK UP AND RIH WITH 3 1/2' DP RD WL. CHANGE KELLY. RIG FLOOR FOR 3 1/2" DP. PU AND RIH WITH 3 1/2" DP. REDUCE MW TO 12.5 PPG. MW: 12.4 PV/YP: 18/11 APIWL: 6.8 CIRCULATE AT 10,639' FINISH RIH. REDUCE MW TO 12.5 PPG. WASH TO F.C. @ 10, 531' TEST CSG. DRILL FC/FS AND WASH 9' WITH NO CMT. LOT 14.4 EMW @ 10,639' SI WELL PRESS TO 460#. CBU WITH 3,240 UNITS GAS. SI WELL PRESS TO 320%. CBU WITH 480 UNITS GAS. MW: 11.7 PV/YP: 16/ 6 APIWL: 6.8 CIRCULATE & REDUCE MUD WEIGHT CBV. DRILL CMT 10,630'-10,735'. CBU WITH 324 UNITS GAS. DRILL CMT TO 10,755' POH TO 10,600'. CIRC AND REDUCE MW TO 12 PPG. RIH TO 10,755' CBU WITH 2,685 UNITS GAS. SI WELL PRESS TO 276#. DISPLACE TO KCL MUD. CBU WITH 2,639 UNITS GAS. REDUCE MW TO 11.7 PPG. MW: 11.5 PV/YP: 18/10 APIWL: 5.8 SHORT TRIP AT 10,828 REDUCE MW TO 11.5 PPG. SI WELL PRESS TO 4250. CBU WTIH 1, 668 UNITS GAS. SI WELL PRESS TO 217%. CBU WTIH 1,050 UNITS GAS. DRILL TO 10,809' JUNK ON BOTTOM. CIRC DRILL BRK @ 10,808' DRILL TO 10,829' CBU. MW: 11.5 PV/YP: 16/12 APIWL: 5.7 DRILLING WITH BIT 021. POOH 10 STDS. RIH. CBU WITH 1,348 UNITS GAS. POOH 20 STDS. CBU WITH 1,891 UNITS GAS. POOH. CHANGE BITS. RIH WITH JB. CBU WITH 1,405 UNITS GAS. DRILL 10,828'-10,837'. Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 12 11/28/95 (89) TD:l1052' (215) SUPV:WJP 11/29/95 (90) TD:ll060' ( 8) SUPV:DCB 11/30/95 (91) TD:l1280' (220) SUPV:DCB 12/01/95 (92) TD:11336' ( 56) SUPV:DCB 12/02/95 (93) TD:11489'(153) SUPV:DCB 12/03/95 (94) TD:11675' (186) SUPV:DCB 12/04/95 (95) TD:l1770' ( 95) SUPV:DCB 12/05/95 (96) TD:l1917' (147) SUPV:DCB 12/06/95 (97) TD:12074' (157) SUPV:DCB 12/07/95 (98) TD:12102' ( 28) SUPV:DCB 12/08/95 (99) TD:12229' (127) SUPV:DCB MW: 11.1 PV/YP: 11/ 8 APIWL: 5.2 DRILLING 6" HOLE Drilled 6" hole from 10,837' to 11,052'. Gradually reduced mud weight. Hole in good condition. MW: 11.1 PV/YP: 15/13 APIWL: 5.0 TIH W/ BIT %22 Drilling from 11,052' to 11,060'. CBU; running in rat hole, hit ice and bent kelly. Flow check at 10 stds; flow weak. Change out kelly. BOP test - good. M/U bit and one junk basket, same BHA. RIH. MW: 11.1 PV/YP: 14/10 DRILLING 6" HOLE Work junk basket. Drilling from 11060'-11280' APIWL: 5.2 MW: 11 1 TIH.W/BIT %23 Drilling from 10280'- 11336' PV/YP: 15/13 APIWL: 5 2 MW: 11 1 DRILLING 6" HOLE Drilling from 11336-11489' PV/YP: 13/11 APIWL: 5 0 MW: 11 0 DRILLING 6" HOLE Drilling from 11489- 11675'. PV/YP: 13/11 APIWL: 5 2 MW: 11 1 DRILLING 6" HOLE Drilling from 11675-11770' PV/YP: 14/10 APIWL: 5 2 MW: 10 9 DRILLING 6" HOLE Drilling from 11770'-11917' PV/YP: 14/ 8 APIWL: 5 3 MW: 10 9 DRILLING 6" HOLE Drilling from 11917-12704' PV/YP: 14/12 APIWL: 5 0 MW: 10 9 PV/YP: 16/12 APIWL: 5 0 DRILLING 6" HOLE Drilling from 12074' to 12102' Test BOPE 250/7500. TIH with bit #25. MW: 10.9 DRILLING 6" HOLE Drilling from 12102-12229' PV/YP: 16/12 APIWL: 5.2 RECE V£D AlaSKa OH & Gas Ce, ns. Commission Anchorage Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 13 12/09/95 (100) TD:12350' (121) SUPV:DCB 12/10/95 (101) TD:12350' ( 0) SUPV:DCB 12/11/95 (102) TD: 12350 ' ( 0) SUPV: DCB 12/12/95 (103) TD:12350' ( 0) SUPV:DCB/JN 12/13/95 (104) TD:12350' ( 0) SUPV:JN 12/14/95 (105) TD:12350' ( 0) SUPV:JN 12/15/95 (106) TD:12350' ( 0) SUPV:JN 12/16/95 (107) TD:12350' ( 0) SUPV:JN 12/17/95 (108) TD:12350' ( 0) SUPV: JN 12/18/95 (109) TD:12350' ( 0) SUPV:JN MW: 11.0 TRIP IN HOLE Drilling from 12229'- 12350' PV/YP: 18/11 APIWL: 5.0 MW: 11.0 PV/YP' 18//12 APIWL' LOGGING RUN ~3,~ D~ ~/ / ~/ Logging~R/C~CNL/LDT/D~, ' ~/ Dzpmener and Dipole Sonic. 4.8 MW: 11.1 PV/YP: 18/11 APIWL: 4.6 LOG RUN #4, SEIS~M~" CHECK SHOT Logging run %3/DSI. Run #4 seismic checkshot survey MW: 11.1 PV/YP: 17/10 APIWL: 4.6 RIH W/OPEN ENDED DRILL PIPE ~-'"- Log run %4, checkshot survey, log run #5, RFT. Run %6 RFT w/sample barrel. M/U mule shoe, run in open ended for cement plug #1. MW: 11.1 PV/YP: 17/11 APIWL: 4.6 RIH W/7" CEMENT RETAINER Pump cement plug #1 12150' to 11800' to cover Hemlock shows. WOC. RIH w/7" EZSV retainer @ 7" casing shoe. MW: 11.1 PV/YP: 17/11 APIWL: 4.6 SET CIBP, SET PLUG %3 Set 7" EZSV @ 7" csg shoe. Pump cement plug #2. Pressure test 7" csg and cement plug #2 to 3000#, hold/10 min. MW: 11.1 PV/YP: 16/11 APIWL: 4.8 NIPPLE DOWN BOP Pump balanced cement plug #3, from 5331-5080' RIH and set CIBP @ 255'. Install test plug. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RDMO Nipple down BOPE. Install tree. Freeze protect 7" x 9-5/8" annulus & 7" casing. Release rig @ 2400 hrs. 12/15/95. Rig down, prepare to move rig. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RDMO Rig down, lay down derrick, rig down floor, move power plant, bring in crane. MW: 0.0 PV/YP: 0/ 0 RDMO Rig down, rig up crane, prepare rig to move. APIWL: 0.0 RECEIVI D MAY 2 1 1996 Alaska Oit & Gas Cons. 6Q;nmissio. A.chomge Date: 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 14 12/19/95 (110) TD:12350' ( 0) SUPV:JN 12/20/95 (111) TD:12350 ( 0) SUPV:JN 12/21/95 (112) TD:12350 ( 0) SUPV:TBC 12/22/95 (113) TD:12350 ( 0) SUPV: TBC 12/23/95 (114) TD:12350 ( 0) SUPV:TBC 12/24/95 (115) TD:12350 ( 0) SUPV:TBC 12/25/95 (116) TD:12350 ( 0) SUPV:TBC 12/26/95 (117) TD:12350 ( 0) SUPV:TBC 12/27/95 (118) TD:12350 ( 0) SUPV:TBC 12/28/95 (119) TD:12350 ( 0) SUPV:TBC 12/29/95 (120) TD:12350' ( 0) SUPV:TBC MW: 0 0 RDMO Rig down. MW: 0 0 RDMO Rig down, move out, PV/YP: 0/ 0 PV/YP: 0/ 0 PV/YP: 0/ 0 MW: 0 0 RDMO Continue to rig down, demobilizing rig. MW: 0 0 PV/YP: 0/ 0 RDMO Continue to rig down, demobilizing rig. MW: 0 0 PV/YP: 0/ 0 RDMO Continue to demobilized rig. MW: 0 0 PV/YP: 0/ 0 RDMO Ail Nabors equipment off location. RDMO No activity. RDMO No activity. MW: 0 0 MW: 0 0 MW: 0 0 RDMO General clean-up of location. PV/YP: O/ 0 PV/YP: 0/ 0 PV/YP: 0/ 0 PV/YP: 0/ 0 APIWL: 0 0 APIWL: 0 0 APIWL: 0 0 APIWL: 0 0 APIWL: 0 0 APIWL: 0 0 APIWL: 0 0 APIWL: 0 0 APIWL: 0 0 APIWL: 0 0 MW: 0 0 RDMO Drilled all fence post holes required for permanent fence around reserve pit and cellar. MW' 0.0 PV/YP' 0/ 0 APIWL' 0.0 RDMO General pad clean-up and securing. Date' 5/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 15 12/30/95 (121) TD:12350' ( 0) SUPV:TBC 12/31/95 (122) TD:12350' ( 0) SUPV:TBC 01/01/96 (123) TD:12350' ( 0) SUPV:TBC MW: 0 0 PV/YP: 0/ 0 RDMO General pad clean-up and securing. MW: 0 0 PV/YP: 0/ 0 RDMO General pad clean-up and securing. MW: 0 0 PV/YP: 0/ 0 RDMO Monitor location only. No activity. APIWL: 0 0 APIWL: 0 0 APIWL' 0 0 01/02/96 (124) TD'12350' ( 0) SUPV: TBC MW: 0 0 PV/YP: 0/ 0 RDMO Monitor location only. No activity. APIWL · 0 0 01/03/96 (125) TD:12350' ( 0) SUPV:TBC 01/04/96 (126) TD:12350' ( 0) SUPV:TBC MW: 0 0 PV/YP: 0/ 0 APIWL: 0 0 RDMO General pad, staging area clean-up and securing. MW: 0 0 PV/YP: 0/ 0 APIWL: 0 0 RDMO Ail equipment has been moved off pad and staging areas. Drill site is secure - reserve pit and cellar/wh. Final report until reserve pit closed out in spring. End of WellSummary for Well:AX9312 SEISMIC POINT 710 ( NOT LOCAIED ) BUFFLEHEAD PAD [ACH 24 INCH CULVERT PROPOSED &: AS-BUILT PAD AND ROAD BUFFLEHEAD WELL LOCATED WITHIN SEC. 3, T§N, R9W, SEWARD MERIDIAN 1412 F£L, 2238 FSL. LAT:60'4-8'44" LONG:150'49'48' GRAPHIC SCALE ~E~ ~ D s IR O. AMI REVISED ASSOC. ""-"~: ~°/~ .~: ~/~o c~[c~[o ~r: RCD ~R~ ~o.: ARCO-1 PROF[SSIOBAL LA~, ~O~S~U¢~IO~ A BINERAL 1~8T0 SNO~HOE LANE A~HORAGE, ALASKA (907 345--343~ 285 28O 27.5 27O 26.5 26O NW PAD A,,..., SAFE BRIEFING AREA NO,1 GO o p,%t ' ,% BUFFLEHEAD NO.1 X = 351830 Y = 2,489747 LAT: 60'48'44" LONG: 150'49'48" e>,~ ELEV AT GROUND: 277 FT. MONITOR ~_.LL ~1 WELL© COMMUNICATION TOWER A SECTION A-A EMERGENCY RESPONSE EQUIPMENT BUILDING MONITOR iSPiLL VANi WATER WELL WELL #4- I SAFE BRIEFING AREA NO.2 ~ SHOP J ~ FIRE ExmI1NOUISHER NE PAD % MUD STORAGE LEGEND ~ SECONDARY CON TAINMENT SYSTEM IJ BERM AND BANK CONTAINM£NT SYSTEM ,% SAFETY FENCE I PIT 285 28O 275 270 265 26O MO -- SAFTEY FENCE REC£1VED ~A'( ~ 1 199G CERTIFICATE OF SURVEYOR I HEREBY CERlIFY ll-IAT I AM PROPERLY REGISTERED AND LICENSED TO PRACllCF LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PRO, JECT WAS DONE UNDER MY DIRECT SVPERVISION. ,,~.- ,x('~']" ~' ' · ~ ' DATE SURVEYOR: REG. NO. 1657-5 Naska 0ii &Anchorag~Gss gens. g~mmissio~ ...... GRAPHIC SCALA~ I inch - 30 28O 275 27O 265 26O SECTION B-B // x 28O 275 27O 265 26O AS-BUILT SURVEY BUFFLEHEAD NO. 1 LOCATED WITHIN 1412 FEL, 2238 FSL SEC.~, TSN, Rgw. S.M. ARCO ALASKA. INC, 700 'C" STREET ANCHORAGE, ALASKA R.C. DAVIS & ASSOCIATES 14870 SNOWSHOE LANE ANCHORAGE. ALASKA 99516 DATE OF SURVEY I SEPT. 14 & 1S, 199,5J SWANSON RIVER BUFFLEHEAD #1 Plugback & Suspension Diagram - Actual WELL SHUT IN @ SURFACE 20" STRUCTURAL CSA 107' DRIVEN TO REFUSAL 11.1 ppg MUD 13-3/8" CONDUCTOR CSA 512' CEMENTED TO SURFACE 13.6 PPG KILL WEIGHT MUD IN ANNULUS TYONEK @ 5817' TVD TYONEK 'D' MARKER @ 6175' TVD PRESSURED TYONEK GAS SANDS @ 8202' TVD I I I I I I I I I I I HEMLOCK @ 11507' 11.1 ppg MUD ::::::::::::::::::::::::::::::::::::: 11.1 ppg MUD 9-5/8" CSA 5,204' (TVD) ! CEMENTED TO SURFACE I I PLUG #3, 5080-5331' I ABOVE CIBP @ 5362' I I I , I I I I I I I :::..'..::.::::J ::.'2::.::::! '~:'-":'~ EZSV RETAINER ~i.'.{:i::i :N:.,'..:::..'l ::'..:::..::'J ~ 7" CSA 10,620' (TVD) ANNULAR INJECTION ZONE, UPPER TYONEK, TYONEK 'D' SANDS EST CEMENT TOP @ 10,216' TVD FROM CEMENT BOND LOG @ 10559' PLUG #2, 10509-10734' (pressure tested to 3000 psi, OK) HEMLOCK SHOWS, 11925-12085~!i[i?iiiiili~iiiiiii:!i!ili~iiiiiii~ I I WEST FORELANDS@'12102' ~ 11.1 ppg ~ I MUD I L J TD = 12,350' ARCO Alaska, Inc. PLUG #1, 11811-12150' (tagged on 12/12/95) TWM, 5/15/96 ARCO Alaska, Inc. Post Office 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Charles W. Landmesser ATO Room 1300 Phone (907) 265-6384 January 19, 1996 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. Robert P. Crandall Re: BUFFLEHEAD 1 Well Information North Kenai Peninsula Gentlemen: ARCO Alaska, Inc. (ARCO) hereby submits information for the subject well, pursuant to 20 AAC 25.071, as described on the enclosed transmittal form. ARCO requests that the enclosed information be held strictly confidential. Please execute and return the transmittal/receipt after you verify that all described data and logs are enclosed. Charles W. Landmesser Geophysicist Core Areas Exploration Enclosures ARCO Alaska, Inc. Is a Subsidiary of AtlanflcRIchfleldCompany ARCO Alaska, Inc. Record of Shipment of Confidential Information Subject BUFFLEHEAD I WELL INFORMATION To Alaska Oil and Gas Conservation Commission Attention: Robed P. Crandall 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 From ARCO Alaska, Inc. Attention: Charles W. Landmesser P. O. Box 100360 Anchorage, AK 99510-0360 (907) 265-6384 Please acknowledge receipt by signing and returning a copyr/of this record to --~ Received by (please print) I(X,/)"~n/~losed //') I (//) /ti/haler se~'~ate~ cover via Signature Date A~ p ro/(/j~l t~\s hit~~ //// Date ~'--' ~ r~/~--~-------_~ 1/19/96 Quantity 1 1 Well log final print Well log sepia reproducible Description Compensated Epithermal and Thermal Neutron Lithology Density, Runs 1,2 and 4, 2" and 5", logged 10/3 - 12/9/95 Well log final print Dual Induction - SFL/DITE/SP/GR, Runs 1,3 and 4, 2", Well log sepia reproducible logged 10/3 - 12/9/95 Well log final print Dual Induction - SFL/DITE/SP/GR, Runs 1,3 and 4, 5", Well log sepia reproducible logged 10/3 - 12/9/95 Well log final print Well log sepia reproducible Well log final print Well log sepia reproducible Dipole Sonic Imager, Upper Dipole and P&S Modes, Runs 1,3 and 4, 2" and 5", logged 10/3 - 1 2/10/95 Repeat Formation Tester Pressures and Samples, Run 4, logged 12/11/95 Well log final print Well log mylar reproducible Well log final print Stratigraphic High Resolution Dipmeter Raw Log and Dips, Run 1, 5", logged 10/3/95 Stratigraphic High Resolution Dipmeter Raw Log and Dips, Well log mylar reproducible Run 3, 5", logged 11/17/95 Well log final print Well log mylar reproducible Stratigraphic High Resolution Dipmeter Raw Log and Dips, Run 4, 5", logged 12/10/95 Well log color print Dipole Sonic Imager, Upper Dipole, 450-2690 ft, 5" logged 10/3/95, processed 11/28/95 Well log color print Dipole Sonic Imager, P&S Mode, Compressional, Run 3, 5", logged 11/!6/95 processed 11/30/95 Well log color print Dipole Sonic Imager, Upper Dipole, Run 3, 5", logged 11/16/95. processed 11/30/95 Well log color print Dipole Sonic Imager, P&S Mode, Compressional, TD Run, 5", logged 12/10/95. processed 12/15/95 1 Well log color print Dipole Sonic Imager, Upper Dipole, TD Run, 5" logged 12/10/95 processed 12/15/95 1 Well log magnetic tape Open hole edit, merged Runs 1, 3 and 4, 512-12320 fl, and verification listing tape date 1/8/96 LIS LDWG format, 1600 BPI 1 Well log magnetic tape and verification listing Repeat formation tester field data, Run 4, 11610-12170 ft, tape date 1/4/96 LIS format, 1600 BPI Corrected Sperry-Sun mud log diskette Buff-1 Self Extract Archive, Disk 1 of 1, dated 1/17/96 (REPLACES Disk 1 of 1, Zipped ASCII Files, dated 12/18/95, transmitted 1/11/96 with Sperry- Sun End of Well Logs and Data R.,ep,.grt) ,.._.~, ~,-- ~ ~ ~ ~,.. ~ ,, cc: M. M. McDermott, AAI T. K. Hillegeist, AAI Anchorage AR(~,O Alaska, Inc. Record of Shipment of Confidential Information Subject BUFFLEHEAD I WELL INFORMATION To From Alaska Oil and Gas Conservation Commission Attention: Robert P. Crandall 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 ARCO Alaska, Inc. Attention: Charles W. Landmesser P. O. Box 100360 Anchorage, AK 99510-0360 (907) 265-6384 Please acknowledge receipt by signing and returning a copy of this record to Received by (please print) Signature Date Quantity 1 I ( X ),~F_n/elosed ( /)' Ujfider sepa,~te cover via Ap~3 rov?l t o//,~ ~ E~//~ Date. Bescription Sperry-Sun Final End of Well Logs and Data with 2" blueline and reproducible mud logs and 3 database diskettes cc: M. M. McDermott, AAI T. K. Hillegeist, AAI ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Charles W. Landmesser ATO Room 1300 Phone (907) 265-6384 January 11, 1996 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Mr. Robert P. Crandall Re: BUFFLEHEAD 1 Well Information North Kenai Peninsula Gentlemen' ARCO Alaska, Inc. (ARCO) hereby submits information for the subject well, pursuant to 20 AAC 25.071, as described on the enclosed transmittal form. ARCO requests that the enclosed information be held strictly confidential. Please execute and return the transmittal/receipt after you verify that all described data and logs are enclosed. Charles W. Landmesser Geophysicist Core Areas Exploration Enclosures Alaska Oii& Gas Cons. Con~.rnissio~.i ARCO Alaska, Inc, Is a Subsidiary of AtlanficRIchfieldCompany TO; ARCO Alaska, Post Office do× 100360 Anchorage, Alaska 99510-0380 Telephone 907 27,3 1215 TRANSMITTAL State of Alaska AOGCC 3001 Porcupine Drive Anchorage, Alaska 99501 ATTN: Robert Crandall DATE: January 08, 1996 AIRBILL: AIRLAND646157 CHARGE CODE:AX9312 AFT#: ABV-06-01-08-01 to 05 WELL NAME: Bufflehead/11 API #: 501330246600 SAMPLE TYPE: Dry cuttings S~_'~/LP_ LES SENT: 107'-12350' John, SENT BY: ANGELA T. LANGSTON UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: _RECEIVED BY: Arco Alaska, Inc. 619 E. Ship Creek Ave Suite 104 Anchorage, AK. 99510 Attn: Dan Przywojski 1996 q 2~2-2603 AR~,B-6003-93 SPERRY-SUN DRILLING SERVICES LOGGING SYSTEMS CONFIDENTIAL END OF WELL LOGS and DATA ARCO Alaska, Inc. Well: Bufflehead No. 1 Kenai Peninsula, Alaska December 1995 PREPARED FOR: ARCO ALASKA, INC PREPARED BY: John Patton Sperry-Sun Drilling Services Logging Systems Anchorage, AK 0 Ft I I--I--I ~1G SGI:t~JI C Ec: December 21, 1995 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Sirs: This folder contains the following information relative to ARCO Alaska, Inc. - Buffiehead No. 1: o . One prefolded, blueline reproduction of the mud log. One set of 3.5" Sperry-Sun database disks that require the use of Sperry-Sun Rig Database Software to access. One 3.5" database disk presented in ASCII format. The data on this disk has been compressed with PkZip. One rolled, clear film reproduction of the mud log has also been delivered with this data. Please contact the Mud Logging Supervisor, Steve Carroll, at the Sperry-Sun District Office in regards to any questions about the logs or data disks. Sincerely, ~)oM Pa~on Se~or ~T Engineer Alaska District 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company !0'22AM ARCO ALAS A iNC No. 5547 A! .... ~CA OILAND GAS CONSERVATION COMM[S ! APPLi,..- TION FOR SUNDRY APPI--,OVALS 1. Type ol Request: Abandon Alter casing _ Chang? approved program_._. 2. Name of Operator Suspend X. Operation Shutdown_ Re.enter suspended well _ Time extension_ Stimulate Variance Perforate _ Other Repair well _ Plugging Pull tubing _ 5. Type of Well: Development Exploratory Stratigraphic Service ARCO Alaska. Inc. . _ 3, Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1412' FEL, 2238' FSL, Sec. 3, T8N, Rgw, SM At top of productive interval _. ORIGINAL 14 6. Datum elevation (DF or KB) RKB,, 304 7. Unit or Proper~y name Bufflehead 8. Well number ._ B._ufflehead #_1 9. Permit number 95~63 10. APl number 50-133_-20466 Ar total depth 12' FE_L. 2238' F.SL. Sec. 3. TSN. R9W. SM Present well condition summary Total Depth: measured 12350' feel true vertical 12350' feet Effective depth' measured feet l~ue vertical feet Casing Structural Conductor Surface Intermediate Produmion Liner Perforation depth: Length Size 75' 20" 482' 13-3/8" 5176' 9-5/8" 10594' 7" N/A measured N/A true vertical N/A Tubing (size, grade, and measured depth N/A Packers and S$$V (type and measured depth) N/A 11. Field/Pool ,,Wildcat Plugs (measured) Well plugged back to 255' TVD. Directional survey to define BHL in progress, Junk (measured) Cemented Measured depth True vertical depth Driven to refusal 1 07' 1 07' 850 sx G 51 2' 5 1 2' 1525 sx G 5204' 5204' 656 sx G 10620' 1 0620' ARCO proposes to plugback and suspend subject well as per 20 AAC 25.110. Hydrocarbons shows were en- countered in the lower Hemlock interval, but logs indicated no commercial quantities present. ARCO projects work complete by end of 3rd quarter 1996, after reserve pit is closed out and surface plugs are set in well, 13. AttachmenTs Description summary of proposal ~ Detailed operation program _ Proposed suspended wellbore diagram & goner,al suspension procedure. 14, Estimated date for commencing operation J 15. Status of well classification as: Depembe, r 12, 1995 j Oil _ oas _ 16, It proposal was verba, lly aPpr°ved ~,~'~--'¢r ,,.{~'~/1 0/95 Name of approver Blair Wondzelr Date approved Service 17, I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed ~ ~' //~/'-,.~,.. Ti,lo Sen,or Ddlling,,Enginee, FOR COMMISSION USE ONLY BOP sketch_ Suspended X t2- l-K-- Conditions oi' approval: Notify Oommis ' o re ' , Mechanical Integrit~ Approved by, the order of the Comm~ ]~orm 10-403 Rev 06/~5/88 SUBMIT 1~ TRI'PLICATE .J95 i0'£2AM ARCO ALAS~[A !NC No. 5547 BUFFLEHEAD NO. 1 SUSPENSION PROCEDURE PROCEDU_RE' 1995 Operation 1) Run in hole with open ended drill pipe and mule shoe, and circulate and condition well for setting cement plugs. Circulate and condition 11.1 ppg kill weight mud throughout well. 2) Pull up to 12150'. Batch mix and pump Plug #1 which will cover the interval 11800-12150' which includes lower Hemlock shows observed on mud log from 11925-12085'. Balanced Plug #1 to consist of 85 sx of 15,8 ppg Class G Neat cement plus additives. 3) After balance point is reached, shut down pumps, pull out of plug slowly, and trip to 7" casing shoe. Break circulation to clear pipe. Lay down drill pipe as required. 4) Wait on cement until surface samples firm up. Expect cement to set in approximately 6-8 hours. 5) Trip in hole and tag p!ug. Note top of plug on IADC and ARCO morning,reports. Trip out of hole, laying down drill pipe as required ~n preparation for Plug #2. 6) Trip in hole with,, EZSV retainer on 3,-1/2" drill pipe, Circulate bottoms up at 7 casing shoe (10620 ). Set retainer at 10550'~, Circulate and condition 11.1 ppg kill weight m~d;. - 7) Sting into retainer and establish injection rate. Batch mix and pump Plug #2~hich will cover the interval 10500-10720' which will isolate the 7" intermediate casing shoe. Puli out of retainer and drop 50' of cement on top of the retainer, Plug #2 to consist of 115 sx of 15.8 ppg Class G Neat cement plus additives. 8) Pull up 5-10 stands slowly and circulate to clear pipe. Trip out of well laying down drill pipe as required in preparation for Plug #3. 9) After WOC on Plug #2, shut in well and pressure test 7" casing and Plug #2 to 3,000 psi for 10 minutes, plot and report results on IADO and ARCO morning reports. Trip in hole with Cast Iron Bridge Plug (CIBP) to 5350' and set CIBP. Circulate and condition well above CIBP for setting Plug #3. Circulate and condition 11.1 ppg kill weight mud. 395 i O'22AM ARCO ALAS~fA iNC ....... ~to. 5547 P. ~/? 11) Batch mix and pump Plug #3 which will cover the interval 5100- 5350' which will be placed inside the 7" casing across from the 9- 5/8" surface casing shoe at 5204', Balanced Plug #3 to consist of 50 sx of 15.8 ppg Class G Neat cement plus additives. 12) Pull 5-10 stands slowly and circulate to clear pipe, Trip out of well laying down drill pipe in preparation to release rig. 13) Run in and set second CIBP at 250' inside 7" casing. Freeze protect well at surface inside 7" casing, and inside 7" x 9- 5/8" annulus. Nipple down BOPE and install tree on top, flange,of tubinghead. Secure well for over-wintering, and re~ease ,g. Demob rig equipment for winter. _1_996 O~eration 15) Return to location in summer of 1996, and pump all reserve pit fluids incidental to drilling operation down 7"x 9-5/8" annulus. Displace fluids with 13.6 ppg kill weight mud. 16) Batch mix and pump Plug #4 down same annulus to isolate disposal annulus for well abandonment. 17) Rig up and run 1" pipe (or coiled tubing) inside 7" casing down to second CIBP. Batch mix and pump Plug #5 on top of CIBP. Circulate cement to surface for sudace plug. 18) Cut off wellhead components three (3) feet below original ground level, and weld on identification plate (AOGCC requested that no marker post be installed). Fill in cellar, and mound up to account for settling and water drainage. 19) Clear location and close out reserve pit per ADEC permit requirements. 20) Arrange for site inspection and Final Location Clearance from AOGCC. TWM, 12/12/95 ~s95 ~40' 23AM ARCO AL~S~[A iNC 5547 P. 5/7 WELL SHUT IN @ SURFACE BUFFLEHEAD #1 Plugback & Suspension Diagram 20" STRUCTURAL CSA 107' DRIVEN TO REFUSAl. 11.1 ppg MUD 13-3/8" CONDUCTOR CSA 512' CEMENTED TO SURFACE 13.6 PPG KILL WEIGHT MUD IN ANNULUS TYONEK @ 5817' TVD TYONEK 'D' MARKER @ 6175' 'FVD PR ESSURED TYONEK GAS SANDS @ 8202' TVD HEMLOCK @ 11507' I I I"-- I"- I I I I I I I I i I i 11.1 ppg MUD 11.1 ppg MUD 9-5/8" CSA $,204P (TVD) CEMENTED TO SURFACE I I i [ I I I I I I ! PLUG #3, 5'100-5350' ABOVE CIBP ANNULAR INJECTION ZONE, UPPER TYONEK, TYONEK 'D' SANDS I EST CEMENT TOP @ 10,216' TVD tFROM CEMENT BOND LOG EZSV RETAINER @ 10550' (+/-) ~!i:.[.:-i - "-:,';?,!:1 .;:~5:.;.,1 ~ ?" ¢$A 10,620' (TYD) PLUG $2, 105!D0-10720' ::~::.',:,'-'.:;.',-,'.'.-;-:::-'.;::.::,:ilt ,.,.,.,. ,.,.. ,,. ;, ,,-, ,,-,,,-,, HEMLOCK SHOWS, 11925- 2085~'...:.i:'.../:::.::[:~::~.':::;:::;:::;::}1 I I WEST FORELANDS @ 12102' , ! 11.1 ppg I MUD I L .J ARCO Alaska, Inc. PLUG #1, 11800-12150' TWM, 12/12/95 ~s95 !0'23AM ARCO~,,~,,~^T^¢¢'^ .TNC ~o. 554 ? ?. 6/7 CEMENT PLUG INFORMATION_ P__L.U.G ~1 Hemlock ,S. hows. Bottom Plus Cement Slurry: Depths: Density, ppg Yield, cu ft/sk Mix water, gal/sk Thickening time, hrs:min Volume from dipmeter caliper: Dividing by yield, (77/1.15): Adding 25% excess: Rounding off: BHST BHCT Compressive Strength, psi 5 hour 10 hour 85 sx (17.4 bbls) Premium Class G 0.05 gal/sk D047 Defoamer 0.05 % D065 Dispersant 0.25 % D800 Retarder 11800-12150' TVD 15.8 1,15 5,0 2 hrs 47 min 77 cuft 67 sx 84 sx 85 sx 165 Degrees F 150 Degrees F 500 psi 1928 psi PLUG ~ 7" Ca_sing S.b.oe Isolation Cement Slurry' Depths: Density, ppg Yield, cu ff/sk Mix water, gat/sk Thickening time, hrs:min Open hole volume from dipmeter caliper: Dividing by yield, (80/1.15): Adding 25% excess:. Cased hole volume (0.2085 cu ft/ff): Dividing by yield, (25/1.15): Plus 10 % excess: Rounding off total: BHST BHCT Compressive Strength, psi 4 hour 14 hour 115 sx (23.6 bbis) Premium Class G 0.05 gal/sk D047 Defoamer 0.05 % D065 Dispersant 0.10 % D800 Retarder 10500-10720' TVD 15.8 1.15 5.0 3 hfs 0 rain 80 cuft 70 sx 88 sx 25 cuft over 120' 22 sx 24 sx 115sx 150 Degrees F 130 Degrees F 500 psi 2280 psi 395 !0'23AMARCO ALASKA INC No. 55~,? P. PLUG #3 7" Casing plug Adjacent to Cement Slurry: Depths: Density, ppg Yield, cu ft/sk Mix water, gal/sk Thickening time, hfs:rain Volume of casing (0.2085 cu fi/fi): Dividing by yield, (52/1.15): Adding 10% excess: Rounding off: BHST BHCT Compressive Strength, psi 12 hour 24 hour 9-~5/8',___Cesing Sho_e 50 sx (10.2 bbls) Premium Class G 0.05 gal/sk D047 Defoamer 0.20 % D065 Dispersant 5100-5350' TVD 15.8 1.15 5.0 2 hrs 55 rain 52 cuft over 250' 45 sx 50 sx 50 sx 110 Degrees F 90 Degrees F Under test Under test TVVM, 12/12/95 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo~ DATE: Chairman ~ November 29, 1995 THRU' Blair Wondzell, ~~ FILE NO: P. I. Supervisor FROM: Lou Grimaidi,'¢'~..~ ~. SUBJECT: Petroleum Inspector #1 A9SJK3CD.DOC BOP test Nabors rig #154 Arco well Buffiehead PTD #95-63 Wednesday, November 29,1995: I witnessed the weekly BOP test on Nabors rig #154 which is presently drilling Arco's exploratory well Buffiehead #1 north of the Swanson River field. I was notified that the test was to happen at approximately 1600-,,'"-',,. ~,,"'"~"'~I"",,.,,,.~. ,~ day and as the roads were bad,I left a little early arriving location at 1430 hrs. Due to hole problems the rig was ten stands off bottom when I arrived and observing the well for flow. The test was not begun until 2300 Tuesday evening. The test went very well with all components functioning and holding their pressure test properly. A 350 psi Iow and 7500 psi hi test were applied to all components with the annular preventer having a 350 Iow and 3500 hi test. The rigs gas detection system was in place and operational and was calibrated and tested while I was on location. All other equipment I observed had the appearance of regular maintenance. One area I was concerned with was the "Poor Boy" degasser and the line going to it. These were exposed to the ambient temperature and could freeze if fluid remained in them to long. I was informed that they are routinely checked by blowing air through them. SUMMARY: I witnessed the weekly BOP test on Nabors rig #154 drilling Arco's exploratory well Buffiehead #1. Test time 5 hours. No failures. Attachments: A9SJK3CD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nabors Alaska Operator: ARCO Well Name: Bufflehead #1 Casing Size: 7" Set @ Test: Initial Weekly Rig No. 154 PTD # 95-63 Rep.: Rig Rep.: Location: Sec. X Other DATE: 11/29/95 Rig Ph.# 263-3172 Dave Bumgamer Marvin 3 T. 8N R. 9W Meridian Seward TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign P Drl. Rig P Hazard Sec. P Quan. Test Press. P/F 1 350/3500 P I 35O/75O0 P I 350/7500 P 1 350/7500 P 1 350/7500 P 2 35O/75O0 P 1 350/7500 P N/A 350/7500 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 350/7500 P 350/7500 P 350/7500 P 350/7500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 15 Test Pressure P/F 350/7500 P 38 350/7500 P I P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: Four Bottles 2350 average (w/1 spare) 2,900 P 1,300 P minutes 35 sec. minutes 30 sec. P Remote: P Psig. TEST RESULTS Number of Failures: 0 ,Test Time: 5.0 Hours. Number of valves tested 21 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: freeze up. Very Good test. Insure Poor boy degasser and associated lines are blowndown periodically to prevent Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES NO X Waived By: Witnessed By: Louis R. Grimaldi FI-021L (Rev. 12/94) A9SJK3CD.XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo.~h~~ Chairm~ THRU: Blair Wondzeli,~'~,,'~!~'L P. !. Supervisor'~.TM DATE: FILE NO: FROM: Bobby Foste~'t SUBJECT: Petroleum Inspector October 6, 1995 A8SIJFCD. doc BOPE Test- Nabors 154 ARCO - Buffiehead#1 - Explo. PTD # 95-0063 Wildcat Friday, October 6, 1995: I traveled this date to ARCO's exploration well Buffiehead #1 being drilled by Nabors rig #154 and witnessed the weekly BOPE test. As the attached AOGCC BOPE Test Report shows there was 1 failure. The sensor unit on the choke manifold would not function. This was repaired and was put back in operation. The excessive test time was due to the test plug not wanting to seat properly. Approximately 3+ hours was due to this. The rig was clean and ali equipment seemed to be in good working order. The location was clean and ali extra equipment was stored properly. ARCO has a reserve pit dug on this location. It is lined and seems to be holding all fluids OK. Summary: Witnessed BOPE test on ARCO's exploratory well Buffiehead #1 - Nabors rig #154 - Test time 7.5 hours - 1 failure. Attachment: A8SIJFCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPI~ Tes~ Repor~ OPERATION: Drlg: X Workover: Drlg Contractor: NABORS Operator: ARCO Well Name: BUFFLEHEAD #t Casing Size: 9.625" Set @ Test: Initial X Weekly Rig No. 154 PTD# Rep.: Rig Rep.: 5174' Location: Sec. Other 95-0063 DATE: 10/6/95 Rig Ph.# 263-3172 DA VE BUMGARNER MARVIN ROGERS 3 T. 8N R. 9W Meridian SEWARD Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping:.. OK (Gan) PTD On Location YES Standing Order Posted YES Well Sign OK Drl. Rig OK ,, Hazard Sec. YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. , ,, 1 ,, Pressure 500/5,000 500/5,000 500/5,000 500/5,000 P/F P P P 'p , BOP STACK: Quan. Annular Preventer f Pipe Rams 1 Lower Pipe Rams f Blind Rams 1 Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves Check Valve Test Press. 300/3, 000 500/5,000 500/5,000 500/5,000 50O/5,0OO 500/5,000 I 500/5,000 N/A P/F P P P p, P P P MUD SYSTEM: Visual Alarm Tdp Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES , CHOKE MANIFOLD: No. Valves f5 No. Flanges 46 Manual Chokes 1 Hydraulic Chokes 2 Test Pressure 500/5,000 500/5,000 Functioned Functioned P/F P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 4 Blind Switch Covers: Master: Nitgn. Btl's: 4 (~ 2550 3,000 i P 1,250 "P minutes 50 sec. minutes 12 sec. _ YES Remote: YES Psig. Number of Failures: f ,Test Time: 7.5 Hours. Number of valves tested 2f Repair or Replacement of Failed Equipment will be made wi{hin 0 'days'. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 ~,,~,~ si°p, ~,,~,, ,o. 6~-~(~ o, ~ If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I I I I I II I I II I I I II I I II I IIII I III I I I REMARKS: Failure: The sensor unit on the choke manifold was not operational - this was corrected before I departed the location. NOTE: The ac~urnu'la~ ~ontrol panel 'on the dg flo~r ne~ds to have the accumulator pressure g.a..gue, chan. ged out because it does not read the correct pressure. NOTE: Excessive test time caused because of test plug not seating; Waived By: W~tnessed By: BOBBY D. FOSTER Distribution: orig-Weil File c - Oper./Rig c - Database c - Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO r I ' Ft-021L (Rev. 12/94) ASSIJFCD.XL$ ! found the pad area however congested was well laid out and offered very good access to the rig, all storage areas were neatly stacked. Summary: I witnessed the Diverter Function Test on Nabors 154 with 2 failures, 3 hours test time. Attachments: E99LIOCD.XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David J~ DATE: Chairman ~ September 16, 1995 THRU: Blair Wondzeil, ,~'~ FILE NO: P. i. Supervisor FROM: John Spauiding/~ SU~J-ECT: Petroleum Insp.~ E99LIOCD.doc Diverter Function Test Nabors 154 ARCO Bufflehead #1 Exploration PTD 95-63 Friday September 15, 1995: I traveled by POV to ARCO's Bufflehead exploration project located approximately 3 miles North of the Swanson River Field to witness the Diverter Function Test on Nabors rig 154. The rig recently was taken out of stack for this project, and has not worked for about 1 year. i found the rig in fairly good shape with some minor housekeeping problems, mainly cleanliness and picking up, I was informed by Marvin Rogers Nabors Toolpusher that these would be taken care of in the near future. The diverter vent line (10") is bifurcated, with the straight section being 120' from the wellhead, the bifurcated section is 100' from the valves and is pointed into the reserve pit. The bifurcated section will be the primary vent line with the valve on the straight section being closed and tagged. Both hydraulically actuated full opening ball valves are 40' from the wellhead. Due to the very small footprint of the pad area the straight line section points toward the comer of the office complex. After conferring with Blair Wondzell on the straight line section the decision was made to accept the straight line section. The rig will be on the diverter for 500' MD and then surface casing and rig up the BOPE equipment. During testing it was noted that some of the accumulator bottles needed to be re-charged with nitrogen. Two nitrogen backup bottles were found empty and were being replaced. The rig gas detection system was not working during the test, the toolpusher informed me that these items would be repaired prior to spudding the well. i have received notification at this time that the repairs have been made. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Operation: Development Exploratory: X Ddg Contractor: NABORS' Rig No. 154 PTD # 95-63 Rig Ph. # _~ 263;3172. Operator: ARCO Oper. Rep.: Dave Baumsarner Well Name: ..... Buffiehead #1 Rig Rep.: ..... Maryin, R0gers Location: Sec. 3 T. 8N .... R." 9w Merdian Seward MISC. INSPECTIONS: Location Gen.: ok Well Sign: ok Housekeeping: ok (Gen.) Drig. Rig: ok Reserve Pit: ' ok Flare Pit: na , ~ DIVERTER SYSTEM INSPECTION: Diverter Size: Divert VaNe(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Tums Targeted / Long Radius: 20 in. yes yeS , 10 iN. 120'x100' ff. yes , . ye,s y ~es. , , na ACCUMULATOR SYSTEM: Systems Pressure: . 3000 ,, psig Pressure After Closure: 1350 psig 200 psi Attained After Closure: ~min. 23 sec. Systems Pressure Attained' 2 min. 34 sec, Nitrogen Bottles: 2500, 2650, 600, 0 MUD SYSTEM INSPECTION: Light Alarm Trip Tank: ok ok Mud Pits: ok ok Flow Monitor:. ok -ok GAS DETECTORS: Light Alarm Methane ok ok Hydrogen Sulfide: ok ok , psig Staging area Access road Motors Pumps Pits Reserve Pit Area North South Prevailing ~vind~ ~ lavdown ~. Bi-furcated section 100' raulic actuated F! 0 rack ~ ~ ball valve I ' I Plmexy vent line will St~al~[ht section will be closed durlnl[ normal I Office and change ro~m coml~le× i drilling[ operations [ Drawing not to scale ..... Distribution orig. - Well File c - Oper/Rep c - Database c - Trip Rpt File c- lns~2 AOGCC REP.: ,, OPERATOR REP.: E99LIOCD.XLS ~995 2'¢4PM ARCO ALASKA INC No. 3301 ?, FAX .COVER .SHEET DATE: 9/15/95 TO: Blair Wondzell AOGCC FAX NUMBER: FROM: PHONE NUMBERS: FAX NUMBERS: (907) 276-7542 Tom McKay S EP 1 ~ ;99,5 i907)265-6890 (work) 907) 349-9380 (home) ~~~Jl ~ ~as ~0,~. t::;_Q..~.'_..~. 907) 244-5067 (cellular/<-~Q~ '~f ~ 907) 265-6224 (fax) /i2. COMM ~ iCOMM ~'~) ,COMM , ~"'~ r RES ENG~ '"' SR EN~-i'-~" NRO !w'~ STAT TEC~I 'FILE ~~ NUMBER OF PAGES: g NCLUDING THIS COVER HEEl') MESSAGE: Blair, attached is th.e letter dated 7/25/95 asking for the Bop pressure test excepbon we talked about earlier on Bufflehead. If you have any problems with this plan, please let us know. The BLM has approved the waiver already, FYI. Thanks for your help. Best regards, Tom McKay ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Mike Zanghl Drill Site Development Supervisor I(uparuk Drill Site Development ATO 1276 Phone 265-6206 Fax 265-6224 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 (907) 276-7542 (fax) July 25, COMM COMM COMM RES ENG sRENG :NRO SRGEOL~ ~ GEOLAS%~' STAT STAT T~ 'F~ Re: Approved Application for Permit to Drill (APD), Permit No. 95-63 Request for BOP Test Pressure Waiver and Project Status Update Bufflehead No. 1 Exploratory Well Gentlemen' Please find attached a copy of a letter to the Bureau of Land Management (BLM) dated July 25, requesting waivers to APD requirements and updating their office as to the current status of the project. ARCO is requesting a waiver to the requirement for testing the 10,000 psi BOP stack on the well to the full working pressure of 10,000 psi. The attached letter explains the rationale for this request. Please let us know if you have any objections to this waiver. If you have any questions or require any additional information on this project, please contact Tom McKay at 265-6890 or the undersigned at 265-6206. Mike Za g KRU Drill Site Development Supervisor ARCO Alaska, Inc. TWM/mac ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany CC: Mr. Joseph A. Dygas Chief, Branch Lease Operations United States Department of Interior Bureau of Land Management Division of Minerals 222 West 7th Avenue, #13 Anchorage, AK 99513-7599 (907) 271-4403 / 4436 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Mlke Zanghl Drill Site Development Supervisor Kuparuk Drill Site Development ATO 1276 Phone 265-6206 Fax 265-6224 July 25, 1995 Mr. Joseph A. Dygas Chief, Branch Lease Operations United States Department of Interior Bureau of Land Management Division of Mineral Resources 222 West 7th Avenue, #13 Anchorage, AK 99513-7599 (907) 271-3343 / 4403 / 4436 (907) 272-2249 (fax) ,ILl!_ 2 6 i"3-85 /',b..¢,?.;,, Oil x', .-. ~,s Oorls. Commission Re: Application for Permit to Drill (APD) Bufflehead No.1 Exploratory Well Request for BOP Test Pressure Waiver and Project Status Update Dear Mr. Dygas, Thank you for your recent approval of the above referenced APD. Please note that road and pad construction for the project was started on Tuesday, July 18th, and the spud of the well is expected to occur on or about August 7, 1995, depending on weather conditions. Upon review, of the approved APD for the Bufflehead #1 well, and the Conditions of Approval for same, we have found a couple of items which ARCO would like to request waivers for. The items are listed as follows: Onsite Seotic System On page 4 of the Environmental Assessment, under the Mitigating Measures Section, it states that Sewage will be hauled away. Please note that ARCO is in the process of permitting an onsite septic system consisting of a leach field which will be built as an integral part of the drilling location adjacent to the small camp which will support the operation. The permits for this aspect of the operation are being secured through the Alaska Department of Environmental Conservation office in Soldotna, Alaska. ARCO AJas~, Inc. t~ · ~ of Atla~icRichlleldCompa~y Actual Surface Location and Elevation Due to surface topography and construction cost constraints, the actual surface location for the well will differ somewhat from the permitted location submitted in the APD. However, the target bottomhole location remains the same. Some minimal directional monitoring and surveying will be required during the drilling operation to assure target penetration is achieved. ARCO will prepare as as-built diagram, and survey in the actual surface location wellbore position upon completion of the pad construction operation. This information will then be forwarded to your office using the "Sundry Notices and Reports on Wells" (Form 3160-5). Currently, the well's surface location is staked at: 1405' FEL, 2242' FSL, Section 3, T8N, R9W, S.M. ~- BOP Stack Pressure Testing Item 10 in the BLM Conditions of Approval for the Bufflehead No. 1 project includes the following clause: 'Ram type preventers and associated equipment shall be tested to approved stack working pressure, if isolated by test plug, or to 70 % of internal yield pressure of casing if BOP stack is not isolated from casing. Pressure shall be maintained for at least 10 minutes. If a test plug is utilized, no bleed-off pressure is acceptable. For a test not utilizing a test plug, if a decline in pressure of more than 10 % in 30 minutes occurs, the test shall be considered to have failed. Valve on casing head below test plug shall be open during the test of the BOP stack.' ARCO's concern with this clause relates to the requirement in the first sentence for testing the ram type preventers and associated equipment to approved stack working pressure if isolated by test plug. In ARCO's A~D submittal for the project dated May 2, 1995, it was detailed that all BOP stack testing would be performed to the calculated Maximum Anticipated Surface Pressure (or 'MASP') for the particular interval being drilled below the casing and BOP stack installed for the interval. Due to the potential downhole pressures anticipated on the Bufflehead well, ARCO will be using a 10,000 psi working pressure rated BOP stack. However, none of the calculated, worst case MASP's are near 10,000 psi. In the Casing Program section of the APD, ARCO describes and calculates a number of MASP values for the different well intervals using various 'worst case scenarios' in the event of full well evacuation, and the assumption of full bottomhole pressure transferred to the BOP stack minus a gas gradient inside the casing. Other calculations are performed which assumes that the MASP is bas~l~ .~.. ~f~ Page 2 gradient at the casing shoe which results in even higher pressures than the full evacuation scenarios. The point of this discussion is that ARCO does not see it as necessary to pressure test the BOP stack to the full 10,000 psi working pressure. The MASP calculations in the APD are quite conservative, and assume worst case conditions, i.e. gas from surface to total depth, or frac gradient.pressures at the casing shoe transmitted to surface. For example, the MASP calculation for the 7' intermediate casing results in a MASP of 7,140 psi, the 5' liner has a MASP value of 7,525 psi, and 70% of minimum yield on the 5' liner is 7,098 psi. Thus, using a test plug, ARCO recommends a BOP stack pressure test to 7,500 psi for the 7' and 5' casing strings, as opposed to the full 10,000 psi working pressure tests. ARCO considers this more than adequate pressure testing for this project. As stated in the APD, ARCO feels a reasonable approach should be taken when establishing test pressures to avoid bursting the casing or exposing men and equipment to a very high test pressure which is unnecessary from an engineering standpoint. Most importantly however, is the fact that the BOP stack on the Nabors 154 rig has been tested in the DSR yard in Anchorage to 10,000 psi, and the certifications for this testing are attached for your reference. In closing on this subject, we request that the BLM waive the 10,000 psi pressure test specification, and reduce it to 7,500 psi using a test plug for the 5' and 7" casing strings as per the above discussion for this project. Oil Soill Contingency Plan (OSCP) / ~PCC plarl The SPCC Plan for Nabors 154 is completed and has been approved by a registered professional engineer. The SPCC Plan will be attached to the OSCP. The Oil Spill Contingency Plan is nearing completion, and has undergone a couple of drafts reviewed by the Alaska Department of Environmental Conservation. ADEC approval of the OSCP is required prior to spudding the well. At that time ARCO will immediately provide your office with the approved OSCP which will contain ~r3e sPCC plan as an attachment. Distance to Nearest Lease Line Error- ^PD Form 3160-3 In Box 15 of the APD Form 3160-3, the well distance to the nearest lease line is inserted. We have discovered that the 1523 feet from lease line originally stated in the APD is incorrect. The correct figure should be 2,943 feet to the north boundary of Section 3, T8N, R9W, S.M. This also corresponds to the northern boundary of the lease line. This distance is computed from the bottomhole target location at the top of the Hemlock interval. Page 3 , ivED JUL · . ~. uon ....Con'~rnis,sion ;'q~,sl-,'.a. Oil/t, Gas Anchor; If you have any questions or require any additional information, please contact Tom McKay at 265-6890 (244-5067, cellular) or the undersigned at 265-6206. Sin~, erely, Mike Z, aflgh~ KRU Drill Site Development Supervisor ARCO Alaska, Inc. TWM/mac CC: Bufflehead No. 1 Well File Jim Frates J.P. Foley S.B. Porter T.J. Scarbrough C.W. Landmesser T.W. McKay M.B Winfree D.R. McKelvey D.C. Bumgarner KNWR, Soldotna ATO-1370 ATO-1396 ATO-1366 ATO-1300 ATO-1202 ATO-1296 ATO-1200 ATO-1200 Alaska Oil and Gas Conservation Commission jul_ 2 · ; ),..-.I,,- ~.-,,z,~,~ ()ii ~ Gas Cons. Cornm]ss]on Page 4 DSR COMPANIES I - II I II I - I I I July 11, 1995 Mr. Tom McKay ARCO Alaska, 700 G Street Anchorage, AK 99501 RE: Bufflehead/Nabors 154 BOP Stack Dear Tom: DSR Companies has completed a succe~ful test on the Nabors' BOP stack earmarked/or the Buffiehead Project (see attached chart reports). Thc three (3) ram cavities were tested to 10,000 PSI for the high pressure test and 400 PSI for the low pressure test. The hydraulic cylinders were replaced or repaired on the double, and new ram shaft seals were installed on ail four doors. These BOP units are being shipped with the CSO and 5" pipe rams used in the test. In our opinion, these BOP's are very sound and capable of providing excellent service. Sincerely, Bruce SFittler PHONE 907-522-3234 225 W. 92nd AVENUE ANCHORAGE, ALASKA 99515 FAX 907-522-8568 J?--522--8568 ! I .,ri COMPANIES DSR COMPANIES I I - ! II I PO1 JUL 11'95 08:53 I I FACSIMILE TRANSMISSION ADVICE DATE: TO: FROM: Bruce Spi=tler DSR COMPANIES 225 W. 92nd Avenue Anchorage, AK 99515 TOTAL PAGES REFERENCE: PHONE: (907) 522-3234 FAX: (90'7) 522-8568 FAXED INCLUDING THIS PAGE: NOTES: PHONE 907-522-3234 pa W. 9,?.nd AVENUE ANCHORAGE, ALASKA 99515 FAX 907-522-8568 ~?--5~--8568 DSR COMPANIES 8~49 P~ -- 4O $0-~ JUL 11'95 88: 54 .. · 7-, :; ,. .. · ~?--5~--85~8 ~SR COMPANIES 5O JUL 11'95 ~8: 55 O~ ,'-:.~'"~"~ 0][ & Gag Oon~.Onmm'°~loSlOrl" 'Anchor: HOUR 30 40 BO.] $O00-8,,~HL J LJL 0 O~ Anctlor:. !~1 Ll L~'~\~_ iJ t~-~; 17~.~ /' ~L~S~ OIL ~ GAS / CONSERVATION CO~SSION / TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 1, 1995 Michael Zanghi Drill Site Development Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Bufflehead # 1 ARCO Alaska, Inc. Permit No: 95-63 Sur. Loc. 1319'FEL, 2337'FSL, Sec. 3, T8N, R9W, SM Btmhole Loc. Straight Hole Dear Mr. Zanghi: : Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from Obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. Thc report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. -- David W.~.ohnston ~ Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures CC; Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AL,,~SKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill X Redrill -- I lb. Type of Well Exploratory X~ Stratigraphic Test Development Re-Entry __ Deepen --I Service ~ Development Gas __ Single Zone. Multiple Zone _X__ 2.. Name of Operator 5,Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 275', Pad 250' GL feet Wildcat 3. Address 6. Property Designation P. O. Box 100360, Anchora~le, AK 99510-0360 A-028405 CIRI Fee Minerals 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1319' FEL, 2337' FSL, Sec. 3, TSN, RDW, SM Bufflehead Statewide At top of productive interval 8, Well number Number 1319' FEL, 2337' FSL, Sec. 3, TSN, RDW, SM Bufflehead #1 #U630610 At total depth 9. Approximate spud date Amount 1319' FEL, 2337' FSL, Sec. 3, TSN, RDW, SM 6/1/95 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line SOCAL 212-10 (32-10) 1523' from lease line 12,500' MD 303' from 1/4 sec feet 9100' south @ TD feet 2160 12,500' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth N/A feet Maximum hole angle N/Ao Maximum*urface 7525 ps~g Attotal depth (TVD) 12500' TVD psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) N/A 20" 169# Weld 80' 35' 35' 1 15' 1 15' Conductor to be driven 17.5 13-3/8" 72# N-80 BTC 465' 35' 35' 500' 500' 662 sxClassGw/ 1.0% CCI 12.25 9-5/8" 53.5# L-80 BTC 5165' 35' 35' 5200' 5200' 925 sx lead,500 sx tail+additives 8,5 7" 29# L-80 BTC 10465' 35' 35' 10500' 10500' 242 sx Class G w/additives 6.0 5" 1 8# L-80 FL4S 2300' 10200' 10200' 12500' 12500' 200 sx Class G w/ additives 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sC:~dacU:t°rR E C E IV E D Intermediate Production MAY - 5 1995 Liner Perforation depth: measured ~!~$~:t, 0It & Gas Cons. Commission true vedical Anch0ra. 20. Attachments Filing fee X Property plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program Drilling fluid program ~ Time vs depth plot X Refraction analysis _ Seabed report _20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Drill Site Development Supervisor Date ( ~,~ Commission Use Only / o-/zz- z o I '/-- other requirements Conditions of approval Samples required ,z~Y e s N o Mud Icg required ,~' Y e s__ N o Hydrogen sulfide measures __ Y e s ~ N o Directional survey required __ Yes ~<' N o Required working pressure forBOPE ~2M' __ 3M; )/,., 5M · Z~ 1 OM' __ 1 5 M Other: ddgmal Signed By Oavid W, Johnston by order of/ / Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Mike Zanghl Drill Site Development Supervisor Kuparuk Drill Site Development ATO 1276 Phone 265-6206 Fax 265-6224 May 10, 1995 Mr. David W. Johnston, Chairman Alaska"Oil And Gas Conservation Commission 3001/Porcupine Drive Anchorage, AK 99501 (907) 279-1433 (907) 276-7542 (fax) Re; Application for Permit to Drill (APD) Identification of Contacts Bufflehead No.1 Exploratory Well Gentlemen' Pursuant to your request, the following individuals have been identified as principal contacts for your office for the above referenced project. Listed for your reference are their titles, office numbers, and all phone numbers which you may require. Thomas McKay Senior Drilling Engineer ATO-1202 Work Phone: 265-6890 Home Phone: 349-9380 Fax Phone: 265-6224 Pager: 275-4704 Cellular: 244-5067 Mike Zanghi ATO-1276 Work Phone: Home Phone: Fax Phone: Pager: Cellular: Drill Site Development Supervisor 265-6206 345-2679 265-6224 275-7901 244-5072 RECEIVED MAY 1 ~ 1995 u~l & (]as Cons. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany Michael Winfree ATO-1296 Work Phone: Home Phone: Fax Phone: Senior Drilling 263-4603 274-4437 265-6224 Engineer If you have any questions or require any additional information, please contact Tom McKay at 265-6890 or the undersigned at 265-6206. Sincerely, Mike KRU Drill¢Site Development Supervisor ARCO Alaska, Inc. TWM/mac CC: Mr. Joseph A. Dygas Chief, Branch Lease Operations United States Department of Interior Bureau of Land Management Division of Minerals 222 West 7th Avenue, #13 Anchorage, AK 99513-7599 (907) 271-4403/4436 RECEIVED N~AY 1 2 1995 ~s~ u~ & Gas Cons. Commission Anohorafi¢- cc: Bufflehead No. 1 Well File J.P.Foley S.B. Porter T.J. Scarbrough C.W. Landmesser T. Hillegeist T.W. McKay M.B Winfree ATO-1370 ATO-1396 ATO-1366 ATO-1300 ATO-1302 ATO-1202 ATO-1296 ~AY 1 2_ 1995 ~s~ U~l & Gas Cons. Commission Anchora~r~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Mike Zanghl Drill Site Development Supervisor Kuparuk Drill Site Development ATO 1276 Phone 265-6206 Fax 265-6224 May 2, 1995 'Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 (907) 276-7542 (fax) Re: Application for Permit to Drill (APD) Form 10-401 Bufflehead No.1 Exploratory Well RECEIVED MAY - 5 1995 Alask~ tJll & Gas Cons. Commission /~ch0ra;je Gentlemen' ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory well, the Bufflehead No. 1, located approximately two miles north of the Swanson River Field in the Kenai National Wildlife Refuge. ARCO will be operator on the project with Cook Inlet Region, Inc. ("CIRI") as the only partner. The Bufflehead No. 1 surface location will be a newly constructed gravel pad which lies north of the Swanson River Field, and is approximately 20 miles north of Sterling, Alaska. ARCO intends to use Nabors Rig No. 154 to drill Bufflehead No. 1, with spud planned for June 1, 1995, pending all permit approvals. Attached please find the information required by 20 AAC 25.005 - 20 AAC 25.075 for your review. In addition to these requirements, a request for a spacing exception per 20 AAC 25.055 has been previously submitted per correspondence dated April 17, 1995. Other pertinent information attached to this application is confidential data including the following: 1) Pressure information as required by 20 AAC 25.035 (d) (2),. 2) Prediction of overpressured strata as required by 20 AAC 25.033 (e). Please note that ARCO has included data from four (4) offset wells to predict the formation pressures we expect at Bufflehead. This data consists of sonic log interval transit time versus depth plots which show relatively accurately the overpressured ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRichfieldCompany zones in the area. Aisc included is a mud weight prediction based on the seismic line shot across this prospect. Please note that this analysis does not reveal any shallow hazards at this location. As also required by 20 AAC 25.033 (e) (2) and (3), ARCO will utilize a complete and continuously manned drilling fluid monitoring unit to monitor all critical drilling parameters and trends. 3) Hydrogen sulfide planning as required by 20 AAC 25.065. ARCO does not anticipate the presence of hydrogen sulfide in the formations to be encountered in the Bufflehead well. Therefore, ARCO does not plan to meet the requirements for hydrogen sulfide drilling operations as detailed in 20 AAC 25.065. 4) Well site shallow hazard survey as required by 20 AAC 25.061. ARCO requests a waiver of this requirement for shallow hazard refraction or reflection profile analysis. The SOCAL 212-10 (32-10) well, which lies approximately 1.5 miles south of Bufflehead did not encounter any shallow gas or hazards as confirmed on the mud and electric logs for this well. Aisc, since the seismic evaluation for this well indicated that no hazards are present, a waiver of this requirement is requested. 5) Well deviation information as required by 20 AAC 25.050. The Bufflehead No. 1 well is planned to be a vertical well, and as such only 500 foot surveys are required per these regulations. 6) Annulus pumping request as required by 20 AAC 25.005 (c) (10). ARCO requests permission to utilize the intermediate casing (7" x 9-5/8") annulus for pumping of drilling muds and precipitation in the reserve pit which are fluids incidental to the drilling of the Bufflehead exploratory well. Further details relating to this operation are included in the attachments to this correspondence. if you have any questions or require any additional information, please contact Tom McKay at 265-6890 or the undersigned at 265-6206. Mike Z'~ n g~i' KRU Drill'Site Development Supervisor ARCO Alaska, Inc. TWM/mac Attachments RECEIVED MAY - 5 1995 Oil & Gas Cons. CommissiO. n Anchora ..~¢, CC: Bufflehead No. 1 Well File J.P. Foley S.B. Porter T.J. Scarbrough C.W. Landmesser T.W. McKay M.B Winfree ATO-1370 ATO-1396 ATO-1366 ATO-1300 ATO-1202 ATO-1296 RECEIVED MAY - ,fi 1995 A{~ska 0il & Gas Cons. Commission Anohora ;~, Per 20 AAC 25.005 (c) (4): PROPOSED CASING AND CEMENTING PROGRAM As required by 20 AAC 25.030 Gas Cons. Anchor~ .... BUFFLEHEAD #1 CEMENTING PROGRAM 20" STRUCTURAL CASING The 20" 169# welded joint conductor will be driven and will not be cemented. Setting depth will be to point of refusal estimated at 80 feet below pad level, or 110' RKB depth. 13-3/8" CONDUCTOR Casing weight, grade, connection: 72# N80 BTC Hole size: 17-1/2' Setting depth (MD/TVD): 500' BHST: 80 degrees BHCT: 70 degrees Top of cement: Surface Volume estimated, Lead: N/A Tail: 662 sx Excess calculated, Lead: N/A Tail: 100% Slurry design(s): Lead: N/A Slurry weight: N/A Slurry yield: N/A Thickening time: N/A Tail: Class G w/ 1% Calcium Chloride Slurry weight: 15.8 ppg Slurry yield: 1.15 cu ft / sk Thickening time: 3+ hours 9.-5/8" SURFACE CASING Casing weight, grade, connection: Hole size: Setting depth (MDFI'VD): BHST: BHCT: Top of cement: Volume estimated, Lead: Tail: Excess calculated, Lead: Tail: Slurry design(s): Lead: Class G w/ 2.0% Extender Retard/Accelerate as required Slurry weight: Slurry yield: Thickening time: 53.5# L80 BTC 12-1/4" 5200' 135 degrees 110 degrees Surface 925 sx 500 sx 50% N/A 12.5 ppg 2.64 cu ft / sk 4+ hours Class G w/ Retard as required Slurry weight: Slurry yield: Thickening time: 7" INTERMEDIATE CASING 15.8 ppg 1.15 cu ft per sack 3.5 to 4.5 hours Casing weight, grade, connection: Hole size: Setting depth (MD/TVD): BHST: BHCT: Top of cement: Volume estimated, Lead: Tail: Excess calculated, Lead: Tail: Slurry design(s): 29# L80 BTC 8-1/2" 10500' 165 degrees 145 degrees Approx 8500' N/A 242 sx N/A 10% Class G w/ 0.5% Fluid Loss Additive 0.4% Dispersant Retard as required Slurry weight: Slurry yield: Thickening time: 15.8 ppg 1.15 cuft per sack 4.5 to 5.5 hours 5" PRODUCTION LINER Casing weight, grade, connection: Hole size: Setting depth (MD/TVD): BHST: BHCT: Top of liner / cement: Volume estimated, Lead: Tail: Excess calculated, Lead: Tail: Slurry design(s): 18# L80 FL4S 6" 12500' 185 degrees 165 degrees Approx 10200' N/A 200 sx N/A 10% Class G w/ 0.5% Fluid Loss Additive 0.4% Dispersant Retard as required Slurry weight: Slurry yield: Thickening time: 15.8 ppg 1.15 cu ft per sack 3.5 to 4.5 hours Note: Cement volumes and slurry designs may change slightly depending on actual hole conditions, temperatures, caliper results, etc. that are obtained during the actual drilli,13~0~l~>~' well. ,,,, {". ~_\ TWM, 4/20/95 BUFFLEHEAD PROSPECT- ARCO Alaska, Inc. SURFACE LOCATION: 2337' FSL, 1319' FEL, SEC 3 T8N, R9W, SM TARG ET LOCATION: 2337' FSL, 1319' FEL, SEC 3 T8N, R9W, SM UPPER TYONEK TOP LOWER TYONEK TOF I I I I I I I I I I I I I I I I t'..':.'.;::.'. PROPOSED WELLBORE DIAGRAM ..-....',..: ..'.....'.. 2 STRUCTURAL CSA 120' ':::..':::. :.::::..':t ~i.?~i..'.'j 13-3/8" CONDUCTOR CSA 500' CEMENTED TO SURFACE ':::..':::..1 '::;..'::;..1 ~ 9-5/e" (TVD) CSA 5,200' CEMENTED TO SURFACE CEMENT TOP APPROX 8,500' R E C E'l V E D IvlAY - 5 !905 A!~sk~ Oil & Gas Cons. Commission Anchor~ ~ TOL APPROX 10,200' (TVD) HEMLOCK 7" CSA 10,500' (TVD) CEMENTED UP TO APPROX 8,500' WEST FORELANDS TWM, 2/14/95 5" CEMENTED UP TO TOP OF LINER (TOL) PBTD 5" LINER CSA 12,500' (TVD) Per 20 AAC 25'005 (c) (6): PROPOSED DRILLING FLUID PROGRAM, AND SCHEMATIC DIAGRAMS AND DESCRIPTION OF THE DRILLING FLUID SYSTEM TO BE USED As required by 20 AAC 25.033 ARCO Alaska, Inc. Bufflehead Prospect Sec 3-aN-9W Kenai Peninsula, Alaska BAROID MUD PROGRAM (Revision Date - 4/18/95) Well Plan: Location - Sec 3-8N-9W Kenai Peninsula Casing Program - 20" - 120' (TVD)- Preset 13 3/8" - 500' - 17 1/2" Hole 9 5/8" - 5200' - 12 1/4" Hole 7" - 10,500' - 8 1/2" Hole (Total Depth) 5" - 12,500' - 6 1/4" Hole Directional Program - Straight Hole Mud Program Discussion - Spud the well with a standard fresh water bentonite spud mud and drill to the 13 3/8" casing point at 500'. Drill ahead in the 12 1/4" hole to the 9 5/8" casing point with a "cleaned-up" spud mud from the preceding interval maintained as a fresh water Gel/PAC system. To drill ahead in the 8 1/2" hole below the 9 5/8" casing, displace the well with a new fresh water gel/PHPA/PAC system. This new fresh water system is well suited to this long Tyonek interval of the well and is cost effective and very flexible in terms of addressing a variety of drilling problems which may develop. For drilling ahead below the 7" casing into the Hemlock target, a 7% KCl/Polymer System is suggested to minimize potential formation damage. However, with the current casing program which top-sets the Hemlock, several options may be considered for this tail section of the well. INTERVAL: HOLE SIZE: CASING SIZE: MUD TYPE: Spud to 500' (Quaternary into Sterling Formation) 17 1/2" Hole 13 3/8" Casing Fresh Water Spud Mud MUD PARAMETERS Weight: Viscosity: PV: 15-25 YP: 35-45 pH: 8.5-9.5 Filtrate: 10-15 Max Solids: <6% 8.6-9.6 ppg 100-200 sec/qt. Spud the well with a fresh water spud mud consisting of bentonite and extender. The initial viscosity should be built to the 100-200 sec/qt, range then adjust as needed based upon actual hole cleaning requirements. Barazan (XCD) could be used to supplement the viscosity requirements if needed. Maximize pump rates to provide increase annular velocities to reduce mud viscosity requirements. *Coarse gravel and hole sloughing can be anticipated. Primary focus should be on adequate viscosity for effective hole cleaning. *Some lost circulation noted. Keep adequate supply of LCM on location. *Lightly treat the system with Desco CF and/or PAC's prior to TOH to run casing to avoid possible sticking problems or lost circulation. *Maximize solids contro~ efforts to keep sand content to <1% by volume. *Bump the plug on the 13 3/8" with watered back spud mud. INTERVAL: HOLE SIZE: CASING SIZE: MUD TYPE: 500' to 5200' (Sterling and Beluga Formations to Top Tyonek ) 12 1/4" 9 5/8" Fresh Water Gel/PAC System MUD PARAMETERS Weight: 9.0-11.0 ppg Viscosity: 40-50 Sec/Qt. PV: 15-20 YP: 10-20 pH: 8.5-9.5 Filtrate: 6-10 Solids: <6% Drilled Solids Clean up the surface system via dilution and mechanical separation, prior to drilling ahead in the 12 1/4" hole, building new volume as required with bentonite and PAC's. When drilling out, allow the watered back spud mud blend with the re-conditioned surface mud and drill ahead with a fresh water Gel/PAC system. Primary focus for this interval of the well should be: 1.) Maintain adequate viscosity for effective hole cleaning using bentonite and PAC polymer theology. Drill out of 13 3/8" shoe with a 40-50 sec/qt funnel viscosity then adjust based upon actual hole cleaning requirements. RECEIVED MAY - 5 1995 A!~.ska Oil & Gas Cons. Commission Anchor~,-, 2.) Control any excessive theology which may develop with additional Therm-Thin treatments or Desco-CF treatments on an as needed basis. 3.) Keep pH in the 9.5 range with Caustic Soda. 4.) Continue the use of PAC polymers for improved filtration control for better wellbore stabilization. The reduced API filtrate from the PAC treatment will also improve conditions for the logging activities and reduce the differential sticking potential while running the 9 5/8" casing through the surface sands. Baranex or Carbonox treatments should also be considered if improved filtrate control is desired. 5.) The mud weight requirements for this interval should run from the native mud weight of 9.0 ppg, for the watered back spud mud when coming out of the 13 3/8" shoe, to a 9.6-9.8 ppg native mud weight by the 12 1/4" TD at 5200'. However, there have been cases where the shallow gas sands of the lower Sterling (Beaver Creek Sands e3200'-3500') have dictated mud weights in the 10.0-Ii.0 ppg range for sufficient control. However, off-set data (SRU 242-16) does indicate these sands can be drilled with native mud weights. In any case, extra caution should be exercised when drilling this interval of the well the well. INTERVAL: 5200' TO 10,500' (Tyonek Formation) (Top "E" Zone Water Flow eg000') HOLE SIZE: CASING SIZE: MUD TYPE: 8 1/2" 7" PHPA/PAC Mud (Fresh Water) MUD PARAMETERS Weight: Viscosity: PV: YP: pH: Filtrate: Solids: 10.0-12.5 ppg 40-50 sec/qt. 15-25 15-20 9.0-9.5 8-10 cc/30 min. Initial 4-6 cc/30 min. Final <6% Drilled Solids Drill the 9 5/8" casing shoe and rat hole with a portion of the mud from the preceding interval, routing returns for disposal. Displace hole and surface mud system with a new fresh water PAC/PHPA system. This moderate pH fresh water system is well suited for drilling in the Cook Inlet Basin as it provides effective filtration control with good filter cake quality and can be modified as required to address a variety of drilling problems which can develop. Mud-up the system as follows: Per Barrel Formulation Treat make-up water for excess hardness (Soda Ash) 0.10 ppb Caustic Soda lO.O0 ppb Aquagel (w/extender) 0.75 ppb PAC-L 0.50 ppb EZ Mud-DP 0.25 ppb Therma-Thin 0.20 ppb Aldacide-G Barite to weight (probably lO.O ppg range) Drill ahead keeping the pR 9.0-9.5 with caustic soda and controlling the API filtrate with additions of PAC. Keep the commercial bentonite content in the 4-6 ppb range for good filtration control and wall cake characteristics. The EZ Mud-DP (PRPA) treatments are focused at improved well bore stabilization due to the long interval designated for this section of the well. The initial .5 ppb concentration should be increased to .75-1.0 ppb based upon hole conditions as drilling proceeds. Additional PAC and Carbonox/Baranex treatments will be required for the reduced fluid loss specification for the lower 8 1/2" interval. Therma-Thin, a polymer deflocculant, treatments should be initiated early in the 8 1/2" hole to avoid theological control problems. Desco-CF, a tannin thinner, may also be required for theological stabilization. Specialty additives for this interval may include sulfonated asphalts (Barotrol) for coal stabilization and drilling soap (Con Det) for balling problems. Coals may be expected to present some drilling problems in this interval. However, except for addition of sulfonated asphalts (Soltex/Barotrol) to the mud system as referenced above, coal problems and their solutions will be mostly mechanical in nature. The key to successfully drilling these coals is early detection by the drilling and then controlled drilling operations. Also, effective hole cleaning mechanism/support is essential. A brackish water flow may be encountered in the mid to lower Tyonek "E" zone at ~9000'. Mud weights up to 12.5 ppg may be required to control this water flow. With these high mud weights, lost circulation and/or differential sticking may be a problem. This fresh water system with effective filtration control will minimize these potential problems as additional mud weight may be required for either coals or this water flow in this interval of the well. Note also the following comments on the change-over and maintenance of this proposed polymer mud system: · While nippling up on the 9 5/8" casing, clean the surface p~t system thoroughly. This should include pits, lines and sol,ds control equipment. R 'CEIVED MAY -- 5 995 i~.i~s.~ Oij & Gas Cons, Commission A, nchnr;.. ~ , Salvage a certain portion of the spud mud to clean out the 9 5/8" casing and to drill approximately 10' of new hole below the shoe. , Mud up and displace with the new fresh water system as outlined below: a . Fill pits with an appropriate amount of fresh water to provide a comfortable circulating volume based upon hole volume plus surface volume. B . Treat the make-up water with soda ash as required to reduce the excess calcium to less than 100 ppm (use approximately .0015 pounds of soda ash per barrel for each ppm calcium). If the excess hardness is less than 100 ppm calcium, no treatment will be required. C . Adjust the pH of the make-up water to 9.0 with caustic soda (~.1 ppb). D . Add 10.0 ppb Aquagel (bentonite) and the appropriate amount of X-Tend II (one 2# can per 5 sxs. gel) and allow full hydration. E . F . 'Add .75 ppb PAC-L and .5 ppb EZ Mud-DP. At this point the initial Yield Point should be adjusted upward with additional small treatments of PAC-R or reduced with small additions of Therma-Thin. The Yield Point should be run in the 8-12 range for the initial 8 1/2" hole. The density of the initial mud-up formulation as outlined to this point will be in the 8.6-8.8 ppg range. If this is considered to be insufficient, weight- up as needed with Baroid (barite). A 10.0 ppg density will probably be required as a drill-out mud weight. 4. Maintenance: *Maintain commercial bentonite concentration at 4-6 ppb. *Keep pH 9.0-9.5 with caustic soda. *Utilize PAC and Baranex/Carbonox treatments to achieve an API filtrate in the 6-8 cc range by the early-8 1/2" hole then to below 6 cc's by the 8 1/2" TD. The HPHT should be in the 12-15 cc range at 200 degrees by the 8 1/2" TD. *Control excessive theological treatments on an as needed basis with light treatments of Th er ma-Thin. As the Therm- Thin looses its effectiveness, initiate treatments of Desco-CF on an as needed basis to control excessive _~¥~scosity or gelation problems. _ ~~B~Additional Yield Point may be achieved as dictated by hole cleaning efforts by additions of bentonite or PAC-R. Also, Barazan (XCD) (or Xanvis) can be use for Yield Point optimization. *Adjust PHPA concentration based upon hole conditions. *Add Aldacide-G at 5-10 gal/tour rate to control bacterial activity. · Barotrol (sulfonated asphalt) treatments should be initiated on an as needed basis as a general well bore conditioner or response to a troublesome coal bed. The Barotrol has a proven application in regards to Cook Inlet Basin drilling operations particularly in response to coal problems that may develop. Foaming may be a problem with this treatment in this proposed polymer system. Add defoamers as required. · As this is designated a near vertical well, hole cleaning efforts should first be approached from a mud theology perspective. Laminar flow should be maintained in the annulus by manipulation of mud theology and pump rates. This should also prove beneficial in terms of minimizing hole wash-out through erosional mechanisms. High viscosity sweeps should be used on an as needed basis to supplement hole cleaning efforts. · Regular short trips are suggested to "wipe" the hole· This is particularly true in conjunction with long bit runs to eliminate the build up of excessive wall cake deposits above the BHA. Also, the formations associated with Cook Inlet Basin drilling seem to respond well to these wiper trips as needed in the reduction of problems associated with daily drilling and tripping operations. · Maximize solids control efforts and maintain sufficient dilution to keep the low gravity solids content less than 6%. Frequent retort analysis should be conducted to insure the accumulation of "fines" does not occur. , Weight-up the mud systems as dictated by hole conditions. Weight-up with barite, do not allow weight-up with drilled solids. 10. Cook Inlet Basin coals have a bad reputation as a true drilling hazard in this area. Drilling breaks should be monitored closely and circulated out to insure a stuck pipe situation does not develop. Drillers should be warned of these coals and instructed as to their response. Mud weight increases and sulfonated asphalt treatments have been effective past treatments. Also, high concentration asphalt pills (~15 ppb) have been successfully spotted across troublesome coal beds as a mud response to achieve stability. 11. Disperse the system as required based upon the accumulation of drilled solids, mud weight requirements and temperature· This theological control should first be accomplished through light deflocculation treatments with Therma-Thin, then moderate dispersion with Desco-CF, and finally full dispersion if required with Enviro-Thin. RE(E[VED I 4AY - 5 199 A.l~,ska 0il & Gas Cons. Commission · 12. Effective filtration control is essential for successful Cook Inlet Basin drilling. PAC/Carbonox/Baranex treatments should be optimized to achieve effective filtrate control to minimize the potential for differential sticking. 13. Use lignite/caustic treatments as required for cement contamination. INTERVAL: HOLE SIZE: 10,500' TO 12,500' (Hemlock/West Forelands) 6 1/4" CASING SIZE: 5" MUD TYPE: 7% KC1/PAC Polymer Mud MUD PARAMETERS Weight: Viscosity: PV: YP: pH: Filtrate: Solids: Chlorides 9.5-10.5 ppg 40-50 sec/qt. 15-25 15-20 9.0-9.5 4-8 cc's/30 min. <6% Drilled Solids ~35,000 ppm (7% KCl system) Once the well is cased off w/7" casing to the top of the Hemlock, several drilling mud options will be available based upon the priorities of the well plan. As formation damage issues have been of highest concern to this point, an inhibitive KCl/polymer system is suggested for use in this interval of the well. As at the previous casing point, drill-out with the old fresh water system from the 8 1/2" hole the displace with the new KC1 mud to avoid cement contamination of the new system. Build a sufficient volume of new mud to displace the well as follows (Note: The following is a 9.5 ppg formulation. Reduce the mud weight as allowed for this interval, based upon formation pore pressure estimates.): Per Barrel Formulation (Listed in order of addition) .914 bbl Water 0.10 ppb Caustic Soda 7.00 ppb Aquagel (w/extender) 1.00 ppb PAC-L 1.00 ppb PAC-R 0.50 ppb Therma-Thin 24.30 ppb 47.80 ppb Baroid 0.20 ppb Aldacide-G (adjust YP as required w/Xanvis) RECEIVED MAY -'5 1995 .Oil .& Gas Con~, Co~yl~rlisstor~ ;Anchor , Drill ahead keeping the pH 9.0-9.5 with caustic soda and controlling the API filtrate with additions of PAC. Keep the commercial bentonite content in the 2-6 ppb range for good filtration control and wall cake characteristics. The salinity should be kept in the 35,000 ppm range with KC1 brine additions. (Note: There should be no fresh water additions to this system. An addition KC1 brine storage tank may be required to support this drilling operation.) Continue with Therma-Thin treatments for theological stabilization and Aldacide-G treatments to control bacterial growth. To summarize mud maintenance objectives, please note the following: ,Maintain commercial bentonite concentration at 4-6 ppb. *Keep pH 9.0-9.5 with caustic soda. ,Utilize PAC and Carbonox/Baranex treatments for effective filtration control. *Control excessive rheological treatments on an as needed basis with light treatments of Therma-Thin. As the Therm- Thin looses its effectiveness, initiate treatments of Desco-CF on an as needed basis to control excessive viscosity or gelation problems. *Additional Yield Point may be achieved as dictated by hole cleaning efforts by additions of bentonite or PAC-R. Also, ×anvis can be use for both YP and/or LSR-YP optimization. *Add Aldacide-G at 5-10 gal/tour rate to control bacterial activity. ,Barotrol additions for coal stabilization. *Weight-up the mud system as dictated by actual drilling conditions. RECEIVED DRILLING BUFFLEHEAD #1, NABORS RIG 154 FLUID & SOLIDS CONTROL SYSTEM, UNWEIGHTED MUDS A) DESANDER PUMP B) DESILTER PUMP C) MUD CLEANER PUMP D) MIXING PUMP E) CENTRIFUGE CATCH TANK #1 F) CENTRIFUGE CATCH TANK #2 G) MIXING HOPPER =-' ~_. ARCO Alasl~a. Inc TWM, 4/15/95 TOTAL GARDENEP~ DENVER PZ-10 1300 HP MUD PUMP PILL PIT 72 BBLS VOLUME TANK 443 BBLS DESILTER SUCTION TANK 107 BBLS SURFACE SYSTEM GARDENER- DENVER PZ-10 1300 HP MUD PUMP CENTRIFUGE ~2 SUCTION TANK 212 BBLS DESILTER 16 CONES DESANDER 2 CONES MUD 16 CONES OVERSCREEN DEGAS DESANDER SUCTION TANK 159 BBLS SAND TRAP EST 25 BBLS VOLUME = 1018 BBLS SHALE SHAKERS SAND TRAP DUMP NOTE: CENTRIFUGE #1 IS OPTIONAL DERRICK F LO-LINE CLEANER8 ARCO ALASKA, INC. FLOW DIAGRAM-WEIGHTED MU O CLEANER EPPIILEIIT i DlaCHARGE TO ~'~==' ~ - I I II MUD CLE~N'~'~ ~CREEN I I i.li CENTRIFUGE C~IiI'CH TANK RETURN TO ACTIVE SYSTEM BAROIO JAY OLIVE RESERYE PIT- CENTRIFUGE CATCH TANK MARKII CENTRIFUGE ~ ALFA-LJIMkL 418 CENTRIFUGE P Ell I BARITE RECOVERY J DISCHARGE TO ACTIVE SYSTEM RESERVE PIT Per 20 AAC 25.065: HYDROGEN SULFIDE CONSIDERATIONS RECEIVED [vIAY - 5 I995 .,&l~,s~ .0ii .& Gas Cons. Commission Anchor~-" BUFFLEHEAD #1 H2S CONSIDERATIONS Hydrogen sulfide is not expected to occur in the Bufflehead well, particularly since no H2S has been observed in any of the surrounding offset wells. The presence of H2S is not typical to the geologic environments which occur on the Kenai Peninsula. Thus, ARCO does not plan to implement an H2S program for Bufflehead. However, mudlogging services will be in operation on the well from below 20" structural casing to total depth, and combustible gas detection and monitoring equipment will also be in operation from spud to rig release. Mudlogging and drilling fluid engineering services will include 24 hour per day monitoring of gas entrainment in the drilling fluid, hourly drilling fluid density checks, drilling fluid salinity checks, shale chip density, rate of penetration, and combustible gases. Communications between the mudlogging and drilling fluid engineering units, and the rig floor will be available and operational on a 24 hour per day basis. Rig floor personnel will be notified immediately upon indications of any excursions away from normal drilling trends and conditions are observed. Daily mud reports will be completed, and the drill string will not be tripped out of the well until the mud system is balanced, and the return mud properties are in line with the mud being pumped down the drill string. 'I'VVM, 4/26/95 R CrclV D .0il & Gas Cons. Commission ~ ~chor~ ' ARCO Alaska, Inc. Date: May 4, 1995 Subject: Bufflehead Prospect- H2S From: To.- T. K. Hillegeist - ATO-1302 T. W. Mc Kay - ATO-1202 Hydrogen sulfide will not pose a problem at the Bufflehead #1 Well. Historically, hydrogen sulfide has not been encountered in any of the wells in the Swanson River area. Several wells have penetrated the same section that will be drilled by the Bufflehead well. The Birch Hill 22-25 well to the north of Bufflehead location and the Swanson River #1 (SRU 34-10) approximately a mile to the south of the prospect both penetrated the complete Tertiary section and a few hundred feet of the Mesozoic; neither of these wells encountered H2S. In addition, other deeper penetrations into the Mesozoic at the Swanson River/ Soldotna Creek units have not encountered hydrogen sulfide. In general, the Cook Inlet is a low sulfur system. This is reflected in the low sulfur coals and the lack of H2S in the producing fields. In summary H2S is not a, problem ~ the area of the Buffiehead well. T. K. Hillegeist fi/ cc: C. W. Landmesser M. F. Honeycutt RECEIVED lviA¥ '- ,5 1995 A!as~. Oil & Gas Cons. Commission gnchor~ -- Per 20 AAC 25.055: REQUEST FOR LOCATION SPACING EXCEPTION (Previously submitted by ARCO letter dated April 17, 1995) ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 J. Patdck Foley Distdct Landman Telephone (907) 265-6283 Fax (907) 263-4933 April 17, 1995 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 30001 Porcupine Dr. Anchorage, AK 99501 Request for Exception to the Provisions of 20 AAC 25.055 (drilling units and well space) ARCO - CI~ Buffiehead No. 1 Well Cook Inlet. Alaska A-028405 Dear Chairman Johnston: ARCO Alaska, Inc. ("ARCO") hereby applies for an exception to the provisions of 20 AAC 25.055 for the drilling and completion of the ARCO - CIRI Buffiehead No. 1 Well (the "Well"). The Well will be drilled as a straight hole with a surface and intended bottomhole location of as follows: T8N, R9W. Seward Meridian Section 3: 1319' FEL 2337' FSL Lat: 60° 48' 45.0"N Long: 60.812508 N 150.829336 W 150° 49' 45.6"W Section 3 is under lease A-028405 and that portion of said lease containing the Well and lying outside of the Swanson River Unit is owned by ARCO (80%) and CIRI Production Company (20%) as co-leasees. A plat showing the location of the well, all other completed and drilling wells on the property, and all other adjoining properties and wells is attached as Exhibit 1. The names and addresses of all owners and operators of the governmental quarter sections directly and diagonally offsetting the proposed drilling unit for the well are set forth in Exhibit 2. Included in Exhibit 3 is the verification required by the referenced provisions, a copy of the notice sent to the owners and operators listed in Exhibit 2, and the date such notice was mailed. If you have any questions or require any additional information, please contact the undersigned at (907) 265-6283. Sincerely, J. Patrick Foley District Landman Attachments RECEIVED [~/iA¥ - 5 1995 Gas Cons. Commission gr.,ch0r[ EXH~Brr 1 ARCO / CIRI BUFFLEHEAD NO. I T 8 N - R 9 W - SEWARD MERIDIAN - ALASKA PROPOSED LOCATION 3 2 _~' 1.321 mo '~' ~' 1,319' f ~- , R'ECEIVEL~ ARco 80% - C~R~ 20% UNOCAL 100% LEASE NO. A-028405 Exhibit 2 Request for Spacing Exception Working Interest Owners CIRI Production Company 2525 "C" Street Anchorage, AK 99509 Attn: Kevin Brown Union Oil Company of California PO Box 196247 Anchorage, AK 99519-6247 Attn: Kevin Tabler ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Attn: Mr. David A. Sutter Royalty Owners United States Department of the Interior Bureau of Land Management Alaska State Office 222 W. 7th Avenue # 13 Anchorage, AK 99513-7599 Attn: Joe Dygas Cook Inlet Region, Inc. 2525 "C" Street Anchorage, AK 99509 Anchorage, AK 99509 Attn: Jerry Booth Overriding Royalty Owners None - Not Applicable EXHIBIT 3 TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) Request of ARCO Alaska, inc. for ) an Exception to the Provisions ) of 20 AAC 25.055 for ARCO - CIRI ) Bufflehead No. 1 Well ) ) VERIFICATION OF FACTS AND AFFIDAVIT OF J. PATRICK FOLEY STATE OF ALASKA ) l~'l/k'~ -- $ 1995 ) SS. THIRD JUDICIAL DISTRICT ) ~.~s~ 0'~ 8, Gas Cons. Comm'~ss'~¢ J. Patrick Foley, being first duly sworn, upon oath, deposes and states as follows: 1. My name is J. Patrick Foley. I am over 19 years, old and have personal knowledge of the matters set forth herein. 2. I am a District Landman for the well operator, ARCO Alaska, Inc. 3. I am acquainted with the facts associated with the drilling of the ARCO - CIRI Bufflehead No. 1 Well. exploratory oil well. 4. I have reviewed the application submitted for the exception to 20 ACC 25.055. To the best of my knowledge and belief all facts therein are true and accurate. 5. I have reviewed the plat attached as Exhibit 1 and it correctly portrays pertinent and required data. 6. Pursuant to 20 AAC 25.055 (b), ARCO Alaska, Inc. ("ARCO"), the well operator, prepared a Notice of Request for Exception to the Provision of 20 AAC 25.055. A copy of this notice is attached hereto. 7. On April 17, 1995, pursuant to 20 AAC 25.055 (b), ARCO sent a copy of said notice by certified mail to the last known address of all owners and operators of governmental quarter sections directly and diagonally offsetting the governmental quarter section of the proposed locations of the ARCO - CIRI Bufflehead No. 1 Well. exploratory oil well. These names and addresses are set forth on Exhibit 2 attached to ARCO's Request for Exception to Provisions of 20 AAC 25.055 dated April 17, 1995 Subscribed and sworn to this 17th day of April, 1995. STATE Of ALASKA THIRD JUDICIAL DISTRICT ,/J. Patdck ~ ~" SS. The foregoing instrument was acknowledged before me this 17th day of April, 1995, by J. Patdck Foley. OFFICIAL SF. AL STATE OF ALASKA Marilyn H. Roth NOTARY PUBUC Notary Pub~, State of Alas~k,a My Commission Expires: ¢/~ ~///'q ? ARCO Alaska. In=. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 J. Patdck Foley District Landman Telet3hone (907) 265-6283 Fax (907) 263-4933 April 17, 1995 CERTIFIED MAIL CIRI Production Company 2525 "C" Street Anchorage, AK 99509 Attn: Kevin Brown Union Oil Company of California PO Box 196247 Anchorage, AK 99519-6247 Attn: Kevin Tabler United States Department of the Interior Bureau of Land Management Alaska State Office 222 W. 7th Avenue # 13 Anchorage, AK 99513-7599 Arm: Joe Dygas Cook Inlet Region, Inc. 2525 "C" Street Anchorage, AK 99509 Anchorage, AK 99509 Attn: Jerry Booth Gentlemen: Notice of Request for Exception to the Provisions of 20 AAC 25.055 ARCO - C[RI Buffiehead No. 1 Well A-O28405 Pursuant to the provisions of 20 AAC 25.055 (b), ARCO Alaska, Inc. hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission (AOGCC) for an exception to the well spacing requirements of 20 AAC 25.055. ARCO's request, if approved, will permit the drilling of the ARCO - CIRI Bufflehead No. I well as an undirected straight hole at the following surface and bottomhole location' T8N, R9W, Seward Meridian Section 3: 1319' FEL 2337' FSL Lac 60° 48' 45.0"N Long: 150° 49' 45.6"W 60.812508 N 150.829336 W The surface and bottomhole of the well is on CIRI/BLM lease A-028405. The portZon of said lease which lies outside of the Swanson River Unit is owned by ARCO (80%) and by CI]~I Production Company (20%). Lease royalties are split between the BLM (15.625%) and CIRI (84.375%). No ovemding royalty exists on this lease. A complete copy of our application to the AOGCC is attached for your files. Should you have any questions, please call the undersigned at (907) 265-6283. Sincerely, J. Patrick Foley District Landman RECEIVED cc: David W. Johnson, AOGCC Oil & Gas C0n~. [;omrnission Anchor[ ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 THE APPLICATION OF ARCO ) ALASKA, INC. for an order granting ) an exception to spacing requirements of ) Title 20 AAC 25.055 to provide for the ) drilling of the ARCO Buffiehead No. 1 ) exploratory oil well. ) Conservation Order No. 357 ARCO Alaska Inc. Buftlehead No. 1. May 11, 1995 IT APPEARING THAT: ARCO Alaska, Inc. submitted an application dated April 17, 1995, requesting exception to 20 AAC 25.055(a)(1) to allow drilling the ARCO Bufllehead No. 1 exploratory oil well closer than 500 feet to a drilling unit boundary. . Notice of hearing was published in the Anchorage Daily News on April 22, 1995 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: The ARCO Bufllehead No. 1 well as proposed will be a straight hole drilled to a bottom-hole location 2337' from the south line and 1319' from the east line of Section 3, T8N, R9W, Seward Meridian. . Offset owners CIRI Production Company and Union Oil Company of California have been duly notified. 3. An exception to 20 AAC 25.055(a)(1) is necessary to allow drilling of this well. CONCLUSION: Granting a spacing exception to allow drilling of the ARCO Bufflehead No. 1 well as proposed will not result in waste nor jeopardize correlative rights. Conservation Order No. 357 May 11, 1995 NOW, THEREFORE, IT IS ORDERED: ARCO Alaska, Inc.'s application for exception to 20 AAC 25.055 for the purpose of drilling the Buffiehead No. 1 well is approved as proposed. DONE at Anchorage, Alaska and dated May 1 1, 1995. · ~:~ion Com~ssion Russell A. Douglass, Commissi~aer Alaska Oil and Gas Conservatio~n Commission ~uckerman Babcock, ~ommissioner Alaska Oil and (]as Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day ifa holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court hms from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). inspinfo.frm INSPECTION INFORMATION - EXPLORATORY WELLS -Thi~ form is intended to supply'some basic well information that will be' useful to the inspectors when inspecting diverter and BOPE systems. PTI) No.: ~--~ ~ Operator: ~ Conductor size: Diverter line: size: Surface hole size:~ Surface Casing size: , configuration: and weight & grade: Surface casing BOP: size: . 1~{~ , Pressures - WP/TP: /6>~ / ~~ Intermediate hole size: ~,b Prod casing size: and weight & grade: Prod casing BOP: size: I~% , Pressures - WP/TP: Liner hole size: &,OtI Liner/casing size: ~ ~ and weig.ht & grade: ~yctrogen Sulfide Measures: Name: ,Date: ARCO Alaska, InC. ~ Kuparuk Unit Disbursement Account. P.O. Box 102776 Anchorage; AK 99510-2776 PAY TO THE ORDER OF: ALASKA DEPT OF REVENUE ~c~ ..~.~. 2300554.58 APRIL 10, 1996 VOID AFTER 90 DAYS 839 0997587 EXACTLY *********** I00 DOLLARS AND O0 CENTS $***********I00.00 TRACE NUMBER: 230055458 cio [, ARCO Alaska, Inc. ~ Kuparuk Unit Disbursement Accotmt P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: ALASKA DEPT OF REVENUE .OM... 230055458' APRIL 10, 1996 VOID AFTER 90 DAYS 839 0997587 EXACTLY *********** I00 DOLLARS AND O0 CENTS $*********** I00.00 The First National Bank of Chicago-0710 Chicago, I Illnols Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 230055458 ,:08 ~ qo oqq ? 5~ ?~' Per 20 AAC 25.005 (c) (10): PROPOSED DRILLING PROGRAM As required by 20 AAC 25.033 (e) BUFFLEHEAD # I PROJECT SUMMARY The following procedure outlines the planned work to drill, complete and test the proposed Bufflehead #1 exploration well. The zone of interest is the Hemlock and West Forelands sands expected to be encountered at 10750' and 11450' TVD, respectively. These zones are expected to contain producible oil and gas reserves. The secondary objective is the Cretaceous sands expected to be encountered at 11850' TVD. The surface location will be a newly constructed all season gravel pad positioned at 1319' FEL, 2337' FSL, Section 3, T8N, R9W, S.M. This location ties in with seismic line BH-90-1. The total depth of the well is planned to be 12500' TVD. Following road and pad construction and reserve pit excavation, a drilling rig will be mobilized to location. A 20" 2000 psi diverter system will be rigged up on the pre-set 20" conductor, and a vertical 17-1/2" diameter hole will be drilled to approximately 500' TVD. Then, 13-3/8" conductor casing will be run and cemented to surface. A BOP stack will be installed on the 13-3/8" casing and subsequently tested to the "MASP" (Maximum Anticipated Surface Pressure). The 13-3/8" conductor casing will then be drilled out using a 12-1/4" bit, and a leak-off test will then be performed below the 13-3/8" shoe to determine the pressure integrity of the casing shoe for well control purposes. A 12-1/4" vertical hole will then be drilled to 5200' TVD. The Bufflehead #1 is planned as a straight hole, and deviation will be minimized while drilling. Following the surface hole interval wireline logging program, 9-5/8" intermediate casing will be run from 5200' TVD to surface. This casing will be cemented from TD to surface, depending on log results. Following installation of the next casing spool, the BOP stack will be tested to the MASP. The 9-5/8" surface casing will then be drilled out using a 8-1/2" bit, and a leak- off test will then be performed below the 9-5/8" shoe to determine the pressure integrity of the casing shoe for well control purposes. A 8-1/2" vertical hole will then be drilled to 10500' TVD. Potential for high pressure water flows in the lower Tyonek interval is expected as observed in several offset wells. Following the intermediate hole interval wireline logging program, a 7" intermediate casing string will be run from surface to 10500' TVD. This casing string will be cemented up to approximately 8500' TVD, depending on log results. Following installation of the next casing spool, the BOP stack will be again tested to the MASP. The 7" intermediate casing will then be drilled out using a 6" bit, and a leak-off test will then be performed below the 7" shoe to determine the pressure integrity of the casing shoe for well control purposes. BUFFLEHEAD # I PROJECT SUMMARY (continued) Drilling fluids and precipitation captured in the reserve pit which are incidental to the drilling operation will be pumped into the 7" X 9-5/8" annulus as required following the casing drill out operation. The zones receiving these fluids, namely the upper Tyonek, are in no way connected to any fresh water aquifers. One of the rig pumps can be used for the injection operation. Injection pressures and pump rates should be limited to 1,500 psi and 2 bpm. A 6" vertical hole will then be drilled to 12500' TVD, the planned total depth of the well. An intermediate log run may be performed across the Hemlock interval prior to drilling below the Hemlock depending on mud log observations and hole conditions. Following production hole logging operations, and if the well is to be tested, a 5" liner will be run at TD, with the top of the liner estimated at approximately 10200' TVD, hung in the 7" intermediate casing (see attached wellbore diagram). This liner will be cemented from TD up to the top of the liner, depending on log results. After clean out to PBTD, cased hole surveys and logs will be run. The rig will then install a test packer and 2-7/8" / 3-1/2" tubing to surface. The well will be perforated and tested with any produced hydrocarbons being processed through test separators and other surface well testing equipment. Currently, all testing is planned to be completed without the rig on the well. Depending on test results, development plans will continue or the well will be plugged and abandoned as per all state and federal regulations. Following abandonment, the location will be closed out per all state and federal regulations. 'rWM, 5/5/95 BUfflehead #1 Drilling Time Estimate -1000 -2000 -3000 -4000 -5000 -6000 Depth -7000 -8000 -9000 -10000 -11000 -12OOO -13000 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 ARCO Alaska, Inc. Days From Spud RECEIVED TWM, 4/3/95 MAY - 5 I995 .Oil .& Gas Cons. CoriimissJon Anchor~ · BUFFLEHEAD #1 PROPOSED DRILLING PROGRAM Site Preparation 1) Construct gravel access road and pad at proposed Bufflehead #1 location north/northeast of Swanson River Field. 2) Excavate reserve and flare pits as designed and line reserve pit with impermeable liner. 3) Excavate well cellar as staked and drive 20" structural casing to +/- 80' below pad level. Use 20" plain end casing and weld joints together. Weld on 20" slip-on head with 21-1/4" 5,000 psi flange to accomodate 20" diverter system riser. MobilizatiOn 4) Mobilize drilling rig to location and rig up riser and diverter system on 20" structural casing. Function test diverter system. Rig up mud loggers and sample catchers. Be certain to center rig over well accurately to avoid future problems. Conductor Hole 5) Spud well and drill 17-1/2" vertical hole with pendulum BHA to 500' TVD. Maintain well as vertical as possible. Condition for casing. 6) Rig up and run 13-3/8" conductor casing to 500' and cement same to surface. Perform top job as required. Wait on cement. ,,.Surface Hole 7) 8) Nipple down diverter and riser and install 21-1/4" 5,000 psi (bottom flange) by 13-5/8" 10,000 psi (top flange) casinghead. Nipple up 10,000 psi working pressure BOP system, install test plug to isolate casing, and test same to the "MASP" (Maximum Anticipated Surface Pressure) for surface hole interval. Remove test plug. Pressure test casing to 3,000 psi as required by agency regulations but do not exceed 3,700 psi (70% of internal yield pressure), drill out and perform pressure integrity test to 12.0 ppg equivalent or leakoff. Report results to office. 9) Drill 12-1/4" vertical hole to 5200' TVD. RECEIVED A!~.ska 0il & Gas Cons. Commission BUFFLEHEAD #1 PROPOSED DRILLING PROGRAM (continued) 10) Rig up and run logs as follows: a) Triple Combo, CNL / LDT / DITE b) Sonic c) Dipmeter 11) Trip in with drilling assembly and condition for casing. Trip out for casing. 12) Rig up and run 9-5/8" surface casing and cement same to surface. Wait on cement. Intermediate Hole 13) Nipple down BOP stack and install slips and packoff. Test packoff and install 13-5/8" 10,000 psi (bottom flange) by 13-5/8" 10,000 psi (top flange) casinghead. Nipple up 10,000 psi working pressure BOP system, install test plug to isolate casing, and test same to the MASP for intermediate hole interval. Remove test plug. 14) Pressure test casing to 5,000 psi as required by agency regulations but do not exceed 5,500 psi (70% of internal yield pressure), drill out and perform pressure integrity test to 13.5 ppg equivalent or leakoff. Report results to office. 15) Drill 8-1/2" vertical hole to 10500' TVD. 16) Rig up and run logs as follows: a) b) c) d) e) 0 Triple Combo, CNL / LDT / DITE Sonic Sidewall Cores (optional) RFT (optional) Dipmeter Checkshot Survey (optional) 17) Trip in with drilling assembly and condition for casing. Trip out for casing. 18) Rig up and run 7" intermediate casing and cement same up to approximately 8500' 'I"VD. Wait on cement. Pump drilling muds and precipitation captured in the reserve pit, which are considered incidental to the drilling operation, down the 7" X 9-5/8" annulus. Receiving zone will be the upper Tyonek formations which are geologically and physically unconnected to any fresh water bearing aquifers (see attached memorandum). E C E IV E D [viAY - ,5 1995 /~.i~sk;.t dtl & Gas Cons. C0rnm. lss[0.rl Anchor~,...q BUFFLEHEAD #1 PROPOSED DRILLING PROGRAM (continued) Production Hole 19) Nipple down BOP stack and install slips and packoff. Test packoff and install 13-5/8" 10,000 psi (bottom flange) by 13-5/8" 10,000 psi (top flange) casinghead. Nipple up 10,000 psi working pressure BOP system, install test plug to isolate casing, and test same to the MASP for production hole interval. Remove test plug. 20) Pressure test casing to 5,000 psi as required by agency regulations but do not exceed 5,700 psi (70% of internal yield pressure), drill out and perform pressure integrity test to 14.0 ppg equivalent or leakoff. Report results to office. 21) Drill 6" hole to 12500' TVD total depth. An intermediate logging run may be performed depending on mud Icg results over the Hemlock zone prior to drilling into the Cretaceous. 22) Rig up and run logs as follows: a) b) c) d) e) f) Triple Combo, CNL / LDT / DITE Sonic Sidewall Cores (optional) RFT (optional) Dipmeter Checkshot Survey (optional) 23) Trip in with drilling assembly and condition for casing or P&A depending on Icg results. 24) Rig up and run 5" liner and trip in hole to setting depth. Cement liner up to top of liner and set hanger. Reverse out excess cement and trip out. Wait on cement. 25) Trip in and clean out to top of liner. Pressure test liner lap. Trip out. 26) Pick up 3-1/2" drill pipe and slim hole assembly and trip in. Clean out to PBTD and test liner again. Circulate well over to kill weight brine as required for completion and testing. Trip out. 27) Rig up electric line and run gauge ring and junk basket to PBTD. 28) Run cased hole logs as required from PBTD to surface. RECEIVED [v~A¥ - 5 1995 Gas Cons. Commission Anchors, *~ PROPOSED Completion & Testing 29) 30) 31) 32) 33) 34) BUFFLEHEAD #1 DRILLING PROGRAM (continued) Rig up and run completion tubing and packer as required to test well. Land tubing and secure well. Release rig. Rig up surface testing equipment (separator, flare, etc.) and prepare for flow test. Flow test well without rig below packer using wireline tools and coiled tubing as required. Suspend or abandon well per all state and federal regulations. Rig down and release testing equipment, clear location. Dewater and closeout reserve pit per permit stipulations. Close out location as per all state and federal regulations. TWM, 5/5/95 RECEIVED ~'vlA¥ - 5 1995 &~s~ .0il & Gas Cons. Commission Anchors. -' ARCO Alaska, Inc. Date: Subject: F~om: To: Internal Correspond~ May 3, 1995 Annular Injection Zones in the Buffiehead # 1 Well and Isolation from Quaternary Fresh Water Aquifers. Tony Hillegeist ATO- 1302 Tom McKay ATO- 1202 As per your request, this information addresses annular injection in to the Beluga and Tyonek Formations. The log analysis of the nearest offset well (SRU 212-10) was conducted by Wayne Campaign on April 21, 1995. The results are addressed in the note "Annular Water Injection Concerns for the Buffiehead Well" from Wayne Campaign/4-21-95 (attached). Based on this evaluation, the injection zone contains a salinity of 3,000 - 9000 ppm NaC1. The potential zone of injection in the Buffiehead well (4500' SS to 8500' SS) is isolated from the shallow Quaternary fresh water aquifer by several well developed clay/siltstone beds and interbedded sandstones. The base of the Quaternary sands is located at 512' md(-202' SS) in the SRU 212-10. The injection zone is below the productive Sterling/Beluga Gas sands of the wells at the north end of Swanson River Field, and is isolated from the Birch Hill 22-25 - Tyonek "D" Gas sand by several faults. In summary, there should be no concern about injecting into the interval between 4500' and 8500' SS in the Buffiehead well as this interval contains saltwater, is not in communication with the flesh water aquifers, and is not expected to contain hydrocarboqs. cc: C. Landmesser ATO-1300 M. Honeycutt ATO- 1476 W. Campaign ATO- 1454 ARCO Alaska, Inc. Is a Subsidiary of AtlanticRichfieldCompany , -. ,, b'~ ~ Gas Cons, Anchot~ Page2 Date: April 21, 1995 Subject: Annular Water Injection Concerns for the Buffiehead Well From/Location: W. Campaign ATO 1454 To/Location: T. W. McKay ATO 1202 In preparation for this well, the SRU 212-10 well has been brought to me for water salinity determination. This SRU well is seismically nearly fiat to the proposed Buffiehead well and the sands in question extend from 4500' SS to 8500' SS. Available data included SP, Deep Induction and Sonic logs. The specified intervals in this offset well contain neither flesh water nor hydrocarbons. The sands are within the Beluga and Tyonek formations, and analysis of the logs indicate salinities increase from about 3 Kppm NaC1 in the Beluga sands around 4500', to about 9 Kppm in the Tyonek sands below 5900'. SP analysis indicates salinity of 3 Kppm to continue uphole to at least 1400'. Above this level, valid mud properties are not available, but similar sand resistivities continue uP to 503' measured depth. This should give ample standoff between fresh water and the intended injection zones. If you have any further questions, comments or concerns, feel free to call me. Wayne Campaign CC T. Hillegeist C. Landmesser ATO 1302 ATO 1300 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED {v1A¥ -5 'i99~ ~!as~.Oil & Gas Cons. Commission .AnchorE ' WELL LOCATION MAPS, LEASE, AND PAD LAYOUT DIAGRAMS '~Y'~. \ ."~'~'/ ' f ~'"'~"~-_~ .,~'/ I ' ~, ~ F~ .~ ~A ~" .. ~- ~. ~ ? ~ ~ ~'~ .... - ~ ~ ~ Alas~ Vicini~ Map ?./ ~ _~, Cook Inlet Vicini~ x,,,..~ - .,., - / ,,..... ~ ,.,., ~; : euff. lehead#1/; ~ ' ~ ~ Project~~, . ! Locatlon~'~, ~ " ~, ' G~; ,~' ~-.- i ,' ~{ .... ~ ,, , ~ ~ fi~~'" r-. ~ i Proposed Bufflehea~ ~1 ~ ~ ~ ~ Well Location 1/ ~ ~ K~i Peninsula Borough AK94 092603 A00 Exhibit A, Figure 1 T. 8 iN .2., -~-::>.., ,~.,_2;.., :' ;/....'.;:~ )PROPOSED BUFFLEHEAD WELL. ,, ,, ,~,,.. , ,. ..- .~ ..... LOCATION : · ,,"<-',--- -':,,- .... . ...... '~, : '-. ', v' .../i ~ : '-. '.. "--' '' l ' ' ""~ ' '; '" ' "' ' ......... ' ',,,: :,:,.:,~ /:, "....'..: .... ...... '......... '....~ ;:':.'.i i.'L/~1 " ,-r~ '"; / : ',', '" ..' :~' "~ / f _~_K' I ~ ' L/,-' .,'. .: ', '~ ' -'" ,~ '~... "~p..I:I'OI~/~$ED .... BUFFLEHEAD . , ., ; ~ .--~ ,~,'.~.,~f....' - ..... ..-.., .. .- / ',,,~/I -.. - . !-, ~ ,~'..:;.- ~, '."'., .-':ti.-_. .......... .'^ ': .- ..i,r-., ;' '_, ..... · -' ..t~ '. ?/~...' -= -- .- .'.,%. I~ .- ,~ v .,i' .-'1 12 ~,--::_: ~-.::'...-" .- I,- '.:.'... : ~'~x,s~-,.~-'.o^~ ..... /~ .~,.--- ) i ' · -' " " '1 ,il · . .- . ~ -"--"-1 ' .'? .' -' / ~ ".:o ..-~:" ; f · .... ~l, 4 I ,---'~.,,, ! / ~:' "..%j ~P'"- ', "' ) ,~' ,~' "-,,-) ~/~' ;-:,::~ -~/~'":~~:, '--,'1 .... ~ -!.-..,~. '. --- ' ~ - '~ I i'-:---- " '-.' '~-'"'::~.. "- a~. " ""-. :1.5:?: ~- ' '~ ,.'-,, ~ ', I ...... /~'~,// ..... ;;~.-,.:, ':. '~-', 'i--' . / ',% " I "~m ~ 'll.-'"!?.l '. .... j,,, ...r~l~o ~ ' "' '! '..:- .... '"::1'.'--' '-'< ...... " <",~,~,' <.~-... ~.: :'. ,~,~o,-,,.~o~,~'~-~"°~ i : ',: " ~k'~' / ~: I ' . -.,o · ,[ ,',' ,_ · ~ ___/... .......... .. .- i ~ .-'.-/ ~ i.., - I/ - ' '' ; ,_,;.,.,, '-' ~'--' i~ ..., ° ! LEGEND: ~ '' N O F:IITI''-I I ~ 0 3000 FEET PROPOSED BUFFLEHEAD BRANCH ROAD TO BE CONSTRUCTED EXISTING RIGHT-OF-WAY (TUS PERMIT M-275-KE) · ''''''''" EXISTING ROAD MONTGOMERY WATSON Anchorage. Alaska FIGURE 2 ARCO ALASKA, INC. Amendment to Birch Hill Environmental Assessment BUFFLEHEAD ENVIRONMENTAL ASSESSMENT PROPOSED PROJECT 0 3000 FEET LEGEND: LEASE BOUNDARY 22 (g) LA~DS BOUNDARY REF1JGE BOUNDARY SWAJ~SON RNER AND B~RCH HILL UN~ BOUNDARIES ~ONEK NAT~E COR~ON ~DS (a) US~ (b) (a) REMAINS SUBJECT TO THE LAWS AND REGULATIONS GOVERNING USE AND DEVELOPMENT OF THE KNWR (b) NATIVE SELECTIONS PENDING FIGURE ARCO ALASKA, INC. Amendment to Birch Hill En,mironmentmt Assessment @UFFLEHEAD ENVIRONMENTAL ASSESSMENT PROJECT ARF~ LAND STATUS - SURFACE N 0 ~TH , 0 3000 FEET LEGEND: LEASE BOUNDARY ~ {g) LANDS ~-~ ] B~NDARY flEdGE BOUNDARY ~$ON R~R ~O BIRCH HiLL UNE BOUNDARIES OTHER CIRI SUBSURFACE IN KNOWN GEOLOGIC STRUCTURE (a) ClRI SUBSURFACE {a) ClfiI-SELECTED FEDERAL SUBSURFACE 1N KNOV~ GEOLOGIC STRUCTURE (a) EXISTING FEDERAL WERE TRANSFERRED PROViSiON THAT ALL TERMS AND COND~TI~ CONTINUE IN FULL FO~ EFFECT, WITH PROVISION SURFACE VALUES BE TO MAXIMUM EXTENq~ PRACTICABLE AND MOST ADVANCED AV~ COMMEROAL TECH~ USED TO DEVELOP OIL, GAS, AND COAL BASE MAP: U.S.GS ~E~ ~,~ :~ ~ON'I"GOA~ERY WATSON Anchorage, Alaska FIGURE 12 ARCO ALASKA, INC. Amendment to Bimh Hill Environmental A~sessment BUFFLEHEAD ENVIRONMENTAL ASSESSMENT PROJECT AREA LAND STATUS - SUBSURFACE '34 T.a N ~' LEGEND: ~mBwm LEASE BOUNDARY .............. UNIT BOUNDARY EXISTING UNITS LEASE A-O 28404 L~SE Ax)2~O5 Anchorage, Alaska FIGURE 13 ARCO ALASKA, INC. Amendment to Birch Hill EnvironmentalAssessment BUFFLEHEAD ENVIRONMENTAL ASSESSMENT ARF~ OIL AND GAS LEASES AND UNITS FLARE PIT 50' X 50' 174' 300' DERRICK LAYDOWN AREA LINED RESERVE PIT 94' CATWALK & PIPE RACKS WELL CENTER CENTRAL RIG PACKAGE, DERRICK, PUMPS & ENGINES 135' WATER TANKS, BOILERS ETC. I I I~CCES~! I.O~D I I I I I I I 300' Overburden Storage Area (ROWAN RIG #29 USED FOR CONCEPTUAL LAYOUT) PROPOSED BUFFLEHEAD #1 WELL LOCATION LAYOUT KENAI PENINSULA BOROUGH STATE OF ALASKA APPROX SCALE: 1" = 50' OCTOBER 24, 1994 ARCO Alaska, Inc. BERM WELL BERM LINED RESERVE PIT CELLAR .... ~,~ I~.~1~1~1~1~1~"~ "~1~1~1~1 · · · · · APPROX SCALE: 1"= 50' PROPOSED BUFFLEHEAD #1 WELL LOCATION LAYOUT GRAVEL PAD CROSS SECTION KENAI PENINSULA BOROUGH APRIL 28, 1995 ARCO Alaska, Inc. Per 20 AAC 25.005 (c) (7): TABULATION SETTING OUT THE DEPTHS OF PREDICTED OVERPRESSURED STRATA As required by 20 AAC 25.033 (e) and Per 20 AAC 25.005 (c) (8): SEISMIC REFRACTION AND REFLECTION ANALYSIS As required by 20 AAC 25.061 (a) BUFFLEHEAD #1 GEOPRESSURE ANALYSIS AND PREDICTION DISCUSSION An analysis and prediction of overpressured strata was performed for the Bufflehead #1 well as required by AOGCC and BLM regulations. This prediction is based on an evaluation of the seismic data and well test data as well as numerous offset wells indicated in the attached plat and listed as follows: SOCAL 32-10 (aka 212-10) 10-8N-9W Richfield 34-10 1 0-8N-9W SOCAL 31-15 10-8N-9W SOCAL BHU 22-25 25-9N-9W SOCAL 41 A- 15 15-8N-9W SOCAL 21-15 15-SN-9W SOCAL 211 - 15 15-8N-9W The closest wells to Bufflehead geologically and geographically are the primary offset wells shown above in BOLD print. Mud weight versus depth plots are provided for these primary offset wells and are attached. It is felt that much of the mud weight data shown for these wells must be reviewed with the knowledge that these wells were drilled many years ago, and that the practice of running dispersed mud systems with poor solids control equipment relative to today's technology was common. It is therefore confidently assumed that the mud weights shown were possibly far in excess of the weights actually required to balance the formation pressures in this area. Also evaluated for Bufflehead, was a prediction of the mud weights required from the seismic data shot on the BH-90-1 seismic line which intersects the proposed location. This plot is attached which also shows higher pressures in 12.5 to 14.0 ppg range in the lower Tyonek and Cretaceous intervals. However, these calculations were linked to the actual mud weights used in the SOCAL Birch Hill Unit (BHU) 22-25 well drilled to the north of the Bufflehead location in 1965. Again, it appears that mud weights in these older wells may have been excessive, and that "calibrating" seismic pore pressure prediction calculations using excessive mud weights will result in the prediction also being excessively overbalanced. Nonetheless, higher mud weights up to 13.5 ppg will be used to "design" the Bufflehead well, but in reality when the well is actually drilled, weights this high may not be required. In addition, sonic Icg interval transit time analysis was performed for SOCAL SRU 32-10 (212-10) and SOCAL BHU 22-25 to identify overpressured strata encountered in those specific wells. This data is presented in graph form and is attached. Plots were made of sonic Icg interval transit time (ITT) versus depth along with actual mud weights used and formation tops encountered in these two wells. It is felt that this data represents the most accurate engineering prediction of overpressured strata available for the Bufflehead well since the data used is actual subsurface sonic Icg (geophysical) data from wells in relatively close proximity to the proposed wellbore. These sonic Icg plots also show a divergence from the normal pressure trend line starting in the lower Tyonek formation, and continuing to TD. Thus, the well design and operational plan for Bufflehead is designed with the expectation of pressured zones starting at approximately 8,500-9,000 feet. The attached Bufflehead pore pressure/mud weight/frac gradient plot shows the expected pressures, mud weights, frac gradient, formation tops and casing setting depths for the well. As indicated on the primary offset well sonic Icg ITT plots, trend reversals indicating overpressuring are observed in the lower Tyonek and Cretaceous zones. This data is supported by the mud weights required on most offset wells in the area. The frac gradients at Bufflehead are expected to range from 0.7 to 1.0 psi/ft as is the typical trend for formations in this area. Based on offset wells, the following maximum mud weights are predicted to be required in Galena. These mud weights were used to design the casing strings and BOP equipment to be utilized in this well. Actual mud weights used will likely be less than these values, as the weights listed below are conservative and used for design purposes only. Interv¢l Mud Weiaht -- 17-1/2" Conductor Hole, Surface to 500': 12-1/4" Surface Hole, 500-5200': 8-1/2" Intermediate Hole, 5200-10500': 6" Production Hole, 10500-12500': 9.5 ppg 10.5 ppg 13.0 ppg 13.5 ppg The higher mud weights (13.0-13.5 ppg) shown for the depths 5200' to 12500' are driven by the expectation of high pressure water flows in the lower Tyonek section starting at approximately 9000' TVD. The deeper pressure zones are expected below the West Forelands interval which could potentially have abnormal pressure based on drilling history and seismic data interpretation in this area. RECEIVED 1995 ~SbSka. 0il & Gas Cons. Commission Anchor; Experience in this general area shows that the higher mud weights used in the Cretaceous and Jurassic intervals in wells in the vicinity of Bufflehead were required to maintain hole stability as opposed to well control requirements caused by pore pressures. SHALLOW HAZARD EVALUATION No shallow hazards (such as shallow gas) are expected at Bufflehead since none of the primary offset wells listed above encountered any shallow hazards during the drilling operation. In particular, a review of drilling records, mud logs and electric line logs from the SOCAL SRU 32-10, 34-10, BHU 22-25, and other offsets revealed no hazards down to a depth of 5200' which is the surface casing setting depth for Bufflehead. The seismic data interpretation at the location does not reveal any shallow hazards either. Thus, a waiver of the requirements of 20 AAC 25.061 has been requested from the AOGCC. TWM, 4/26/95 Gas Cons. Commissio~ Anchorz," BUFFLEHEAD #1 PORE PRESSURE/MUD WEIGHT/FRAC GRADIENT VS. DEPTH 1000 20O0 3000 4OOO 5OOO 6000 7000 DEPTH TVD 8000 9OOO 10000 11000 12000 13000 14000 15000 EQUIVALENT MUD WEIGHT, PPG 10 11 12 13 14 15 16 ~ FRAC GRADIENT PORE PRESSURE ' WATER FLOW POTENTIAL tt .... 17 18 19 20 3/8" -5/8" ARCO Alaska, Inc. TWM, 4/15/95 BUFFLEHEAD 21 28 33 OFF~£T WELL VICINITY PLAT 22 27 34 23 26 35 24 25 BIRCH HILL 22-25 36 30 31 Rgw R8W T9N 17 R10W 16 21 3 PROPOSED BUFFLEHEAI: 20 Rgw 10 212-10 (aka 32-10), 34-10, 31-15 15 SOCAL 41A-15, 21-15, 211-15 22 11 14 23 12 13 24 Ar~cho TSN ms, Cornrniss~o~ SCALE: 1 SQUARE = 1 SECTION TWM, 4/12/95 SOCAL SRU 32-10 MUD WEIGHT PROFILE Sec 10, T8N, R9W Depth 12~X~ Sterling @ 51 ~CSA 1474 . Beluga @ 381 . _ ~.. ' ...... lyonek @ R"~~ E-Zone @ 946 .......... WATER- FEOWIEOS T-el _ PRO_BL~MS @ 97~'$' , > ,. "' ~,,-f .Hemlock 1 5' 6247' ~690' 9.0 10.0 11.0 1~'.0 13.0 14.0 · ~. -.',,: bi[ ~ Gas Cons, Commis~ior~ Mud Weight, ppg ,, '~hor~,'~ ARCO Alaska, Inc. TWM 3,22 95 SOCAL. 34-10 MUD WEIGHT Sec 10, T8N, R9W .,-. PROI-'ILE Depth lOO0 2OOO 3OOO 4000 5OOO 60O0 700O 8000 9000 10000 11000 12000 13000 .~ I Beluga @ 385 Tyonek @ 582 ' ............ D-Marker @ 6()90' F ~' 9-5/8" CSA · 9228' i ~-- I West Foreland 12000' t I Cretaceous I 9 10 11 12 13 4 Mud Weight, ppg h.~¢~.~i[ .& 6as Cons, commission 'ir~ohor~, 117oo' 12085' ARCO Alaska, Inc. TWM, 4/10/95 SO~,AL 31-15 MUD WEIGHT Pr~OFILE Sec 10, T8N, R9W Depth 1000 2OOO 3000 4ooo 5000 6OOO 7000 8000 9000 10000 11000 12000 9.0 · Sterling @ 65t _..._._I.Q~/~ L~3SA ..~ .............. ,399 f I Beluga @ 38~ I 1 .......... T¥onok @ ~-- ~ D-Marker ~ 61 . 10.0 11.0 12.0 Mud Weight, ppg '8' 01' 295' ARCO Alaska, Inc. TWM, 4/13/95 SOCAL ,SRU 22-25 MUD WEIGHT , ROFILE Sec 25, T9N, R9W Depth ........................... Sterling @ 9~ ~ ., cs,.. , ..... _ ........... Tyonek @ 74 ~~_~~ D-Marker @ ........... ,'EASOt] 0 t-FOR-WEI~ HT--U P .............. UNCLEI~R IN. REC(:~RDS ......... o 1 ~ Hemlock @ 1 ~ ......... Jurassic @ 1 j TD = 15500' 965' 9' 7490' 7920' 4710' 5210' 100( 200( 300( 400( 500 6O0 70O 800 900 1000 1100~: 12 13 14 10.0 11.0 12.0 13.0 Mud Weight, ppg RECEIVEB ARCO Alaska, Inc. TWM, 3/23/95 Bufflehead Seismic Mud Weight Prediction (Prediction Data Calibrated from BHU 22-25 Actual Mud Weights) ' Sterling 1000 ............................ ' ..... ................ :'-"'" ........... ~ .................................................................................................... ' t 2000 .......................................................... ............... ~ .......... ~ ............................ 3000 ............................................................................................................................ Beluga ............................. · ............................................... ................ ~ ............... , ................. ..r- ............ : ............................... 4000 \ _ ..................................... Tyonek ~ooo 6000 -- ~ ................... .- ............... ' ......... ~ ................................ - ................................................ · 7000 ~-'-'- ............. : ................. ~'~ 9000 ~oooo .............................................................................................................. i ................ '.._.._._.._..~._....~~ ..................................... Hemlock 11000 ........ / jWest ForelaMesozo,c 12000 - - ................... -----~--'-- ---------- ............................................ " , 'r ~,~ .................................... Yo = 12,500' 13000 ........ i- ................................ _]~[ .......... ! .............! ............. 14000 - ............. ; ................ ; i ................ ----~ ! ........................... =' ............... i ................................ · 15000 ~ , 16000 ........................................ ' ................... T 17000 ' ' ' ' ' ' , / ..... 9.0 9.5 10.0 10.5 11.0 11.5 12.0 12.5 13.0 13.5 14.0 14.5 15.0 13-3/8" planned 0 500' 9-5/8" planned 0 5200' 7' planned ~ 10500' Predicted Mud Weight, ppg RECEIVED Bufflehead Seismic Pore Pressure Prediction (based on Birch Hill 22-25 mud weight data) TWM, 4/12/95 BH-90-1 BH-90-1 BH-90-1 BH-90-1 BH-90-1 Top Bottom Top Seismic Top Bottom Top Bottom Subsea Subsea RKB Predicted Predicted Two Way Time Two Way Time Two Way Time Two Way Time Depth Depth Depth Mud Weight Formation (secollds) i~secondsl ~millisecondsl ~millisecondsl ~feetl ~feet) , ~ (PPg) Tops ~feet. RKBI 0.00 1.40 0 1400 0 . 5214 0 9.4 Sterling @ 3230' 1.40 1.45 1400 1450 5214 5446 5464 9.8 Beluga @ 3800' 1.45 1.50 1450 1500 5446 5680 5696 10.3 Tyonek @ 5530' 1.50 1.60 1500 1600 5680 6157 5930 10.7 Tyonek 'D' @ 5990' 1.60 1.70 1600 1700 6157 6646 6407 10.3 1.70 1.75 1700 1750 6646 6889 6896 10.7 1.75 1.80 1750 1800 6889 7119 7139 11.2 1.80 1.90 1800 1900 7119 7583 7369 11.6 1.90 2.10 1900 2100 7583 8558 7833 11.2 2.10 2.15 21 O0 2150 8558 8808 8808 11.6 2.15 2.20 2150 2200 8808 9060 9058 12.1 2.20 2.25 2200 2250 9060 9314 9310 12.5 2.25 2.30 2250 2300 9314 9570 9564 13.0 2.30 2.35 2300 2350 9570 9828 9820 13.5 2.35 2.70 2350 2700 9828 11690 10078 13.9 Hemlock @ 10750' 2.70 2.75 2700 2750 11690 11979 11940 13.0 West Foreland @ 11450' 2.75 2.80 2750 2800 11979 12291 12229 13.5 Mesozoic @ 11850' 2.80 2.85 2800 2850 12291 12606 12541 13.9 2.85 2.90 2850 2900 12606 12928 12856 13.0 2.90 2.95 2900 2950 12928 13303 13178 12.1 2.95 3.10 2950 3100 13303 14488 13553 11.6 3.10 3.25 31 O0 3250 14488 15729 14738 12.1 3.25 ~,:, 3.50 3250 3500 15729 17917 15979 12.5 --.--:__..~" .tr"rl Assumes -< ¢~ 250' KB ~ ~ ~ r1'1 Elevation o ~ ~-~ above MSL TWM "~ 4/17/95 SOCAL 32-10 / 212-10 Sonic ITT vs. Depth MD, feet 1000 2OOO 3000 4000 5O0O 6000 7000 8000 9000 10000 11000 12000 10 i i lOO Sonic ITT, usecift Tyonek Tyonek'E' Hemlock 1000 RECEIVED [~IAY - 5 1995 A~S~ .OLI & Gas Cons. ': Ancho~ ' SOCAL 22-25 Sonic ITT vs. Depth TVD, ft 1000 2000 3000 4000 5ooo 6000 7000 80OO 9000 10000 11000 12000 13000 14000 15000 16000 10 i 100 Sonic ITT, usec/ft Tyonek Hemlock Jurassic 1000 Per 20 AAC 25.005 (c) (3): PRESSURE INFORMATION As required by 20 AAC 25.035 (d) (2) BUFFLEHEAD #1 pRESSURE INFORMATION AND CASING DESIGN Casing Setting DePth and BOPE Rationale: 20" 110' TVD/RKB Structural casing, driven to point of refusal in competent formation to provide sufficient anchorage for high capacity flow diverter system. Based on offset well history, diverter system is sufficient for drilling quaternary gravels above Sterling formation. 20" 2000 psi diverter system to be rigged up on 20" structural for drilling of 17- 1/2" conductor hole below structural. 13-3/8" 500' TVD/RKB Conductor casing, cemented to surface to provide sufficient anchorage for 5000 psi BOP system. Setting depth just above Sterling formation to case off all potential fresh water zones, and to provide adequate well control capability for potential Sterling and Beluga formation potential gas zones. 9-5/8" 5200' TVD/RKB Surface casing, cemented to surface to provide anchorage and control for 10000 psi BOP system, and to provide adequate well control capability for overpressured zones and water flows expected in the lower Tyonek intervals. Setting depth just above Tyonek formation. 7" 10500' TVD/RKB Intermediate/Production casing, cemented up to approximately 8500' to provide anchorage and control for 10000 psi BOP system, and to provide adequate well control capability for potential overpressured zones below West Foreland formation. Intermediate casing also allows Hemlock objective zone to be isolated from lower Tyonek pressured zones. This allows Hemlock interval to be drilled and logged with lower mud weights. 5" 12500' TVD/RKB Production liner to be set only if well is to be tested or if hole conditions require a drilling liner be set to reach TD. Casing Performance Properties*: Size Weight Grade Connection Internal Yield (Burst) Collapse Resistance Joint Strength Body Yield 13-3/8" 72# N80 BTC 5380 2670 1693 1661 9-5/8" 7" 5" j~ 53.5# 29# 18# I,,.L=! LBO L80 L80 ~ BTC BTC FL4S 7930 8160 10140 ~ 6620 7020 10490 L.I.J 1286 718 326 1244 676 422 * All casing will be in new condition. Note: For drilling below 13-3/8" casing, 5000 psi BOP equipment is adequate. For drilling below 9-5/8" and 7" casing, 10000 psi equipment will be utilized. Pressure Information and Casing Design Page 1 Procedures for Calculating Anticipated Surface Pressures: a. For drilling below Structural, Conductor, Surface, and Intermediate Casing (with BOP stack installed) ASP is determined on the basis of breakdown of the formation at the casing seat with a gas gradient to the surface as follows: ASP = {[(FG x 0.052)- 0.1] x TVD} Where: ASP FG TVD 0.052 0.1 = Anticipated surface pressure in psi. = Fracture Gradient at the casing seat in lb/gal, EMW. = True vertical depth of the casing seat. = Constant for converting lb/gal to psi/ft. = Gas gradient is psi/ft. b. For drilling below Intermediate Casing (with BOP stack installed) ASP is determined on the basis of breakdown of the formation at the casing seat, followed by lost returns resulting in a complete loss of the mud in the drill pipe by intermediate casing annulus along with the depletion of the available surface mud system. Well control is provided by a column of fresh water to the surface. The calculations are performed using the following equation: ASP = [(FG - 8.4) x 0.052 x TVD] Where: Values are as above and 8.4 ppg is the density of fresh water in lb/gal. c. For production design for the Intermediate Casing and Production Liner ASP is determined on the basis of developing a tubing leak during testing and/or production operations. The leak is located immediately below the BOP or wellhead. Bottom hole pressure is offset only by the gas gradient in the tubing string from the reservoir to the surface. The gas gradient is calculated using the Weymouth exponential formula, ASP = {BHP x [1/e(0.0000347 x gg x TVD)]} Where: ASP BHP TVD g. 0.0000347' = Anticipated surface pressure in psi. = Bottom Hole Pressure at top perforation, psi. = True vertical depth of the top perforation. = Gas specific gradient (0.6 used for calculations). = Empirical constant. Pressure Information and Casing Design Expected Maximum Design Mud Weights: 17-1/2" Conductor Hole, Surface to 500': 12-1/4" Surface Hole, 500-5200': 8-1/2" Intermediate Hole, 5200-10500': 6" Production Hole, 10500-12500': 9.5 ppg 10.5 ppg 13.O ppg 13.5 ppg Please note that ASP calculations using frac gradients presents a worst-case scenario for surface pressure estimates. A more realistic approach to what could reasonably be expected would be to calculate ASP based on anticipated pore pressures in each hole interval. Using the expected mud weights listed above, another set of ASP calculations are presented using the following equation: ASP = ((PP x 0.052)- 0.11)D where: ASP = Anticipated Surface Pressure in psi PP = Pore Pressure in ppg (use above mud weights) 0.052 = Conversion Factor from ppg to psi/ft D = True Vertical Depth of Casing Shoe 0.11 = Gas Gradient in psi/ft Calculations' 1) Drilling below 13-3/8" Conductor Casing: ASP = ( (PP x 0.052)- 0.11) D = ( (10.5 x 0.052) - 0.11) 500 =218psi 2) Drilling below 9-5/8" Surface Casing: ASP = ( (PP x 0.052)- 0.11) D = ( (13.0 x 0.052) - 0.11) 5200 = 2943 psi 3) Drilling below 7" Intermediate Casing: ASP =((PPx0.052)-0.11)D = ( (13.5 x 0.052) - 0.11) 10500 =6216 psi Observe that these estimated pressures are less than the pressures shown above using the frac gradients as the basis for calculating ASP. The calculations using pore pressure are more realistic, and since they are less, indicate that the proposed casing program and design will adequately control the expected pressures to be encountered in the Bufflehead well. In any case, it should be noted that gas is not expected in the zones below the Tyonek formation, namely the Hemlock, West Forelands, and Cretaceous zones. Pressure Information and Casing Design RECEIVED {vlAY '- 5 1995 A!~ ~ii .& Gas Cons. Commission Page 3 Safety Factor and Casing Design Calculations: 13-3/8" Conductor Casinq 13-3/8" 72# N80 BTC Setting depth: Air string weight: Buoyant weight in 9.5 ppg mud: Buoyancy factor for 9.5 ppg mud: Joint strength: Body yield: Collapse pressure: Burst pressure (tube): Max mud weight by next casing point: Frac gradient at 13-3/8" shoe: Backup gradient mud weight: Freshwater backup gradient: Assumed gas gradient: 500' TVD 36,000 lbs 30,780 lbs 0.855 1,693,000 lbs 1,661,000 lbs (dictates tensile limits) 2670 psi (dictates collapse limits) 5380 psi (dictates burst limits) 10.5 ppg (or 0.546 psi/fi) 12.0 ppg (or 0.624 psi/fi) 9.5 ppg (or 0.494 psi/fi) 8.4 ppg (or 0.437 psi/fi) 0.1 psi/ft Tensile Calculations; Maximum setting depth (L) Joint strength safety factor Body yield safety factor = Body Yield / weight per foot = 1,661,000 / 72 = 23,069' (in air) = 1,693,000/(72)(500') - 47 (in air) = 1,661,000/(72)(500') = 46 (in air) Collapse Calculations: (Assume fluid level drops to 500' TVD due to lost returns, for design purposes) (Assume 9.5 ppg, 0.494 psi/ft mud weight backup gradient for collapse design purposes) Collapse safety factor = Collapse pressure / (external hydrostatic - internal hydrostatic) = 2670/[(500)(0.494)- (0)] = 2670/[247- 0] = 10.8 Check collapse during cementing: Collapse safety factor = Collapse pressure / (external hydrostatic- internal hydrostatic) = 2670/[(500)(15.8)(0.052))- (0)] = 2670/[411- O] =6.5 Pressure Information and Casing Design Page 4 Burst Calculations: (Assume freshwater backup gradient, 0.437 psi/ft for burst design purposes) (Assume worst case by using frac gradient at casing shoe for ASP calculations) Anticipated surface pressure (ASP) Top burst safety factor Bottom burst safety factor = (frac gradient - gas gradient) x shoe depth = (0.624- 0.1)(500') = 262 psi = Tube burst rating / ASP = 5380/262 =21 = [Tube burst rating + backup hydrostatic]/[ASP] = [5380 + (500)(0.437)]/[262] = [5380 + 219]/[262] = 21,4 SUMMARY OF 13-3/8' SAFETY FACTORS; SF Tensile/BY: SF Tensile/JS: SF Collapse: SF Collapse: SF Top Burst: SF Bottom Burst: 46 (in air) 47 (in air) 10.8 6.5 while cementing with 15.8 ppg cement 21 21.4 9-5/8" Surface Casing Setting depth: Air string weight: Buoyant weight in 10.5 ppg mud: Buoyancy factor for 10.5 ppg mud: Joint strength: Body yield: Collapse pressure: Burst pressure (tube): Max mud weight by next casing point (10,500'): Frac gradient at 13-3/8" shoe: Backup gradient mud weight: Freshwater backup gradient: Assumed gas gradient: Tensile Calculations: Maximum setting depth (L) Joint strength safety factor Body yield safety factor Pressure Information and Casing Design 9-5/8" 53.5# L-80 BTC 5200' TVD 278,200 lbs 233,562 lbs 0.840 1,286,000 lbs 1,244,000 lbs (dictates tensile limits) 6620 psi (dictates collapse limits) 7930 psi (dictates burst limits) 13.0 ppg (or 0.676 psi/fi) 14.5 ppg (or 0.754 psi/fi) 10.5 ppg (or 0.546 psi/fi) 8.4 ppg (or 0.437 psi/fi) 0.1 psi/ft = Joint Strength / weight per foot '= 1,286,000 / 53.5 = 24,037' = 1,286,000/(53.5)(5200') = 4.6 (in air) = 1,244,000/(53.5)(5200') = 4.5 (in air) RECEIVED v]AY - 5 1995 ~!~,$[z.~ Oil & Gas Cons. CommissJoI1 Anchor~- ~ Page 5 Collapse Calculations: (Assume fluid level drops to 3000' TVD due to lost returns, for design purposes) (Assume 10.5 ppg, 0.546 psi/ft mud weight backup gradient for collapse design purposes) (Assume 13.0 ppg, 0.676 psi/ft mud from 3000' to 5200' for collapse design purposes) Collapse safety factor = Collapse pressure /(extemal hydrostatic - intemal hydrostatic) = 6620/[(5200)(0.546)- (2200)(0.676)] = 6620/[2839- 1487] =4.9 Check co/lapse during cementing: (Assume a 13. 0 cement column ECD to surface during cement placement operation) (Assume 9.5 ppg mud used during cement displacement with fluid level inside casing dropping to 3000') Collapse safety factor = Collapse pressure / (external hydrostatic - internal hydrostatic) = 6620 / ([(5200)(13.0)(0.052)]- [(2200)(9.5)(0.052)+(3000)(0. 1)]} = 6620/[3515- 1087- 300] = 662O / 2128 =3. 1 Burst Calculations: (Assume freshwater backup gradient, 0.437 psi/ft, for burst design purposes) (Assume worst case by using frac gradient at casing shoe for ASP calculations) Anticipated surface pressure (ASP) Top burst safety factor Bottom burst safety factor = (frac gradient - gas gradient) x shoe depth = (0.754- 0.1)(5200') = 3401 psi = Tube burst rating / ASP = 793O / 3401 = 2.3 = [Tube burst rating + backup hydrostatic]/[ASP] = [7930 + (5200)(0.437)]/[3401] = [7930 + 2272]/[3401] = 3.0 SUMMARY OF 9-$/8' SAFETy FACTORS: SF Tensile/BY: 4.5 (in air) SF Tensile/JS: 4.6 (in air) SF Collapse: 4.9 SF Collapse: 3.1 while cementing with 13.0 equ~a~l~i1~l cement column SF Top Burst: 2.3 SF BoSom Burst: 3.0 Pressure Information and Casing Design Page 6 7" Intermediate / Production Casing 7" 29# L-80 BTC EXPECTED CASE Setting depth: Air string weight: Buoyant weight in 13.0 ppg mud: Buoyancy factor for 13.0 ppg mud: Joint strength: Body yield: Collapse pressure: Burst pressure (tube): Max mud weight by next casing point:. Frac gradient at 7" shoe: Backup gradient mud weight: Freshwater backup gradient: Assumed gas gradient: 10,500' TVD 304,500 lbs 244,009 lbs 0.801 718,000 lbs 676,000 lbs (dictates tensile limits) 7020 psi (dictates collapse limits) 8160 psi (dictates burst limits) 13.5 ppg (or 0.702 psi/fi) if drill to 12,500' TVD 15.0 ppg (or 0.780 psi/fi) 13.0 ppg (or 0.676 psi/fi) 8.4 ppg (or 0.437 psi/fi) 0.1 psi/ft Tensile Calculations: 'Maximum setting depth ('L) Joint strength safety factor Body yield safety factor = Body Yield / weight per foot = 676,000 / 29 = 23,310' = 718,000 / (29)(10500') - 2.4 (in air) = 676,000 / (29)(10500') = 2.2 (in air) Collapse Calculations: (Assume fluid level drops to 5000' 'I'VD due to lost returns, for design purposes) (Assume 13.0 ppg, 0.676 psi/ft mud weight backup gradient for collapse design purposes) (Assume 13.5 ppg, 0.702 psi/ft mud from 5000' to 10500' for collapse design purposes) Collapse safety factor = Collapse pressure /(extemal hydrostatic- internal hydrostatic) = 7020/[(10500)(0.676)-(5500)(0.702)] = 7020/[7098- 3861] = 2.2 Burst Calq:ulations; (Assume freshwater backup gradient, 0.437 psi/fi, for burst design purposes) (Assume gas from shoe to surface, worst case scenario for burst design purposes) (Assume worst case by using frac gradient at casing shoe for ASP calculations) Anticipated surface pressure (ASP) = (fmc gradient - gas gradient) x shoe depth : (0.780- 0.1)(10500') = 7140 psi (gas from shoe to surface, worst case) Top burst safety factor = Tube burst rating / ASP = 8160 / 7140 = 1.14 R[C[IV D Pressure Information and Casing Design "5 ' 995 Page 7 Gas Cons. Commission Anch0r~ Bottom burst safety factor = [Tube burst rating + backup hydrostatic]/[AS P] = [8160 + (10500)(0.676)] /[7140] = [8160 + 7098]/[7140] = 2.14 SUMMARY OF 7" SAFETY FACTORS: SF Tensile/BY: SF Tensile/JS: SF Collapse: SF Top Burst: SF Bottom Burst: 2.2 (in air) 2.4 (in air) 2.2 1.14 (assumes gas from shoe to surface and fmc gradient for ASP calculations, worst case) 2.14 Other 7" design notes: Another approach for design purposes is to apply the Weymouth equation previously discussed which calculates surface pressures in a production mode. The Weymouth equation is defined as follows: Production ASP = BHP x {1/e,",[(0.0000347)(GG)(TVD)]} where: ASP = Anticipated surface pressure BHP = Bottomhole pressure @ projected Hemlock top perf depth ('['VD) GG = Gas gravity, 0.6 assumed TVD = TVD at projected Hemlock top perf depth, assumed to be 11,000' at Bufflehead for this calculation Assume pore pressure at this depth to be 10.5 ppg (0.546 psi/fi) Note however that gas is not expected in the Hemlock formation in this area. Thus, Production ASP = {(11,000)(0.546)} x {1/e~[(0.0000347)(0.6)(11,000)]} Production ASP = {6006} x {1/e,',[0.229)} = {6006} x {1/1.257} = {6006} x {0.795} = 4775 psi Thus, rechecking top burst in a production mode, Top burst safety factor = Tube burst rating / Production ASP = 8160 / 4775 = 1.71 Deratinq 7" Collapse Due To Axial Load: It is also recommended to derate the collapse rating of the 7" 29# L80 BTC casing due to the effect of biaxial loading which occurs when the pipe is held in tension. Referring to the Lone Star Steel Casing & Tubing Technical Data Manual, the following procedure is followed: Step 1' Book value of collapse rating = 7020 psi Pipe body yield = 676,000 lbs Axial tensile load = 243,905 lbs full buoyant string weight @ 10,500' in 13.0 ppg mud, buoynacy factor for 13.0 ppg mud= 0.801 R'ECE IV £ D Pressure Information and Casing Design k-,lAY - 5 995 Gas Cons. C0mrrlissi01?ge 8 Step 2' Axial load factor, x = tension load / pipe body yield strength = 243,905 / 676,000 = 0.361 Step 3: From Lone Star Manual chart: Collapse strength rating factor, y = 0.840 Step 4: Derated collapse strength when full casing buoyant weight imposed at top of string, = (0.840)(7020 psi) = 5897 psi Step 5: Apply a 1.10 design factor from TDAS (ARCO Tubular Design Program), = (5897) / 1.10 = 5361 psi vs. book value of 7020 psi (at top of string) Since collapse is not a factor at the top of the string, evaluate this same condition at 5,000' TVD, Step 1' Book value of collapse rating = 7020 psi Pipe body yield = 676,000 lbs Axial tensile load = 127,760 lbs full string weight @ 5,000' in 13.0 ppg mud (5500' of 7" 29# casing suspended below this point) Step 2: Axial load factor, x = tension load / pipe body yield strength = 127,760 / 676,000 = 0.189 Step 3: From Lone Star chart attached, Collapse strength rating factor, y = 0.930 Step 4: Derated collapse strength when casing buoyant weight imposed at 5,000', = (0.930)(7020 psi) = 6529 psi Step 5' Apply a 1.1 0 design factor from TDAS, = (6529) / 1.10 -= 5935 psi vs. book value of 7020 psi (at 5,000') Rechecking collapse at 5,000' applying this derated value, "Derated" Coll¢pse Calculations; (Assume fluid level drops to 5000' 'I'VD due to lost returns, for design purposes) (Assume 13.0 ppg, 0.676 psi/ft mud weight backup gradient for collapse design purposes) (Assume 0.1 psi/ft gas gradient inside casing from surface to 5,000') Derated collapse safety factor = Derated collapse pressure /(extemal hydrostatic - internal hydrostatic) = 5935/[(5000)(0.676) - (5000)(0.1)] = 5935/[3380 - 500] =2.1 RECEIVED ~IAY - 5 1995 &~ ~il .& Gas C0ns. 60mmissi0r, "~,,.. ;~ch0rs -' Pressure Information and Casing Design Page 9 Checking Safety Factors For Surface Tubing Leak During Testing / Production Mode: (Assume 0.1 psi/ft gas gradient to surface inside tubing) (Assume 10.5 ppg or 0.546psi/ft packer fluid behind tubing) (Assume 10.0 ppg or 0.520 psi/ft pore pressure in Hemlock at 11,000' TVD) (Assume tubing leaks to annulus right below wellhead, thus applying BHP minus gas column hydrostatic to annulus at surface) (Assume top of 7" cement column at 8500', pipe is supported below this point) (Assume 8.4 ppg or 0.437 psi/ft backup gradient above 7" cement top at 8500') (Assume 7" casing burst rating of 8160 psi) Calculate burst pressure exerted inside the 7" casing at the 8500' cement top given these conditions: Shut-in Tubing Pressure Below Wellhead: (11,000')(0.520- 0.1) 4620 psi Hydrostatic Pressure of Packer Fluid: = (8500')(0.546) = 4641 psi External Backup Pressure Behind 7": = (8500')(0.437) = 3715 psi Burst Pressure Exerted Equals: = 4620 + 4641 - 3715 = 5546 psi Burst Safety Factor Equals: = 8160 / 5546 psi = 1.5 Checking Safety Factors For Severe Lost Circulation Using Fresh Water for Well Control: Calculate ASP using criteria presented earlier in this section by the following equation: ASP = [(FG- 8.4) x 0.052 x TVD] Thus, Where: ASP = ASP = FG = TVD = 0.052 = 0.1 = 8.4 = Anticipated surface pressure in psi. Fracture Gradient at the casing seat in lb/gal, EMW, or 15.0 ppg True vertical depth of the casing seat, or 10,500' TVD Constant for converting lb/gal to psi/ft. Gas gradient is psi/ft. Fresh water gradient, ppg [(15.0 - 8.4) x 0.052 x 10,500] (6.6) x (0.052) x (10,500) 3604 psi Note that this value for ASP of 3604 psi is far less than the previous value of 7140 psi which was calculated assuming gas from TD to surface. Therefore, the condition whereby the entire mud system is exhausted in an effort to control the well, and only fresh water is used for well control purposes easily meets the design criteria for the 7" intermediate casing string. RECEIVED Iv]AY - ,5 1995 .Oil .& Gas Cons, Commission "'~'~ ~ch0rs - Pressure Information and Casing Design Page 10 5" Production Liner 5" 18# L80 FL4S (Note: Calculations show Iongstring case in addition to liner case) Setting depth: Approx liner top: Approx liner length: Air string weight (liner): Buoyant weight in 13.5 ppg mud: Buoyancy factor for 13.5 ppg mud: Joint strength: Body yield: Collapse pressure: Burst pressure (tube): Max mud weight at setting depth: Frac gradient at 7" shoe: Backup gradient mud weight: Freshwater backup gradient: Assumed gas gradient: 12,500' TVD 10,200' TYD 2,300' 41,400 lbs 32,859 lbs 0.794 326,000 lbs(dictates tensile limits) 422,000 lbs 10490 psi (dictates collapse limits) 10140 psi (dictates burst limits) 13.5ppg (or 0.702psi/ft) 15.0 ppg (or 0.780 psi/ft) 13.5 ppg (or 0.702 psi/ft) 8.4 ppg (or 0.437 psi/ft) 0.1 psi/ft Tensile Calculations: Maximum setting depth (L) = Body Yield / weight per foot = 422,O0O / 18 = 23,444' Joint strength safety factors Body yield safety factor Collapse Calculations: = 326,000 / (18)(2300') = 7.9 for liner (in air) = 326,000 / (18)(12500') = 1.45 for Iongstring (in air) = 422,000 / (18)(2300') = 10.2 for liner (in air) = 422,000 / (18)(12500') = 1.88 for Iongstring (in air) (Assume 13.5 ppg, 0.702 psi/ft mud weight backup gradient for collapse design purposes) (Assume gas inside pipe for collapse design purposes) Collapse safety factors = Collapse pressure /(extemal hydrostatic- internal hydrostatic) = 10490/[(12500)(0.702)-(2300)(0.1)] = 10490/[8775- 230] = 1.23 for liner Burst Calculations: = 10490/[(12500)(0.702). (12500)(0.1)] = 10490/[8775- 1250] = 1.4 for Iongstring (Assume freshwater backup gradient, 0.437 psi/ft for burst design purposes) (Assume gas from shoe to surface, worst case scenario for burst design purposes) (Assume 13.5 ppg, or 0.702 psi/fi: pore pressure~atjoJ~31,.t;J~l~tl~),.. R J::LI:I Pressure Information and Casing Design N1AY - 5 1995 0il & Gas Cons. Commission Page 11 Anticipated surface pressure (ASP) Top burst safety factor Bottom burst safety factor = (pore pressure gradient - gas gradient) x TD = (0.702- 0.1)(12500') - 7525 psi (gas from shoe to surface, worst case) = Tube burst rating / ASP = 10140 / 7525 = 1.35 for Iongstring = [Tube burst rating + backup hydrostatic]/[ASP] = [10140 + (12500)(0.437)]/[7525] = [10140 + 5463]/[7525] = 2.1 for liner or Iongstring SUMMARY OF 5' LINER SAFETY FACTORS; SF Tensile/BY: SF Tensile/JS: SF Collapse: SF Top Burst: SF Bottom Burst: 10.2 for liner, 1.88 for Iongstring 7.9 for liner, 1.45 for Iongstring 1.23 for liner, 1.4 for Iongstring 1.35 for Iongstring 2.1 for both liner & Iongstring In any case, it should be noted that gas is not expected in the zones below the Tyonek formation, namely the Hemlock, West Forelands, and Cretaceous zones. RECEIVED /~nchor~ ~ Pressure Information and Casing Design Page 12 Casing Tests: All casing strings will be tested as shown in the following table prior to drilling out the casing shoe. Tests will be held at least 30 minutes and the results documented on the appropriate IADC drilling report. After prolonged drilling operations in any single casing string the casing integrity will be evaluated either by re-testing or via casing inspection logs run on electric wireline. For the Bufflehead well, the definition of prolonged drilling is interpreted as meaning rotating time in excess of 30 days of cumulative drilling/rotating hours as recorded in the IADC reports. Casing Pressure Tests Planned Casing Depth Set 70% of Min Casing Casing Size Weight TVD/RKB Internal Yield Test Pressure String (in.) (Ibs/ft) Grade {feet) (psi) (psi) Conductor 13-3/8" 72# N80 500' 3,766 3,000 Surface 9-5/8" 53.5# L80 5,200' 5,551 5,000 Intermed / 7" 29# L80 10,500' 5,712 5,000* Production Liner 5" 18# L80 12,500 7,098 5,000* * Depending on the final mud weights which are in use when the casing is actually run, and taking into account the actual mud weights in use prior to drilling out the casing, these test pressures may be revised downward (pending agency approval) to account for the actual pressure differential imposed on the casing. An assumption of backup fluid gradient must also be made. A reasonable approach should be taken when establishing test pressures to avoid bursting the casing or exposing men and equipment to a very high test pressure which is unnecessary from an engineering standpoint. After drilling out each appropriate casing string, leakoff tests (LO'Ps) or pressure integrity tests (PI'Ps) will be performed on the formation drillied below the casing shoe. These tests will be performed on the 13-3/8" conductor and on all subsequent strings to be drilled out below the conductor. The results of the test will be recorded on the IADC drilling report. The tests will be performed with at least 10' of new hole, but no more than 20' of hole exposed below the particular casing shoe. The predicted frac gradient and planned casing seat test pressures listed on the following table are derived from a plot of regional leakoff data on offset wells. Casing Shoe / Pressure Integrity Tests Casing Seat Maximum Planned Anticipated Planned Mud Weight Before Fracture Casing Next String Set Gradient Seat Test 13-3/8" Conductor 10.5 12.0 12.0 9-5/8" Surface 13.0 14.5 13.5 7" Intermediate/ Production TWM, 4/26/95 Pressure Information and Casing Design 13.5 15.0 14.0 RECEIVED MAY - 5 1995 Dii & Gas Cons. Commission Page 13 Per 20 AAC 25.005 (c) (3): DIAGRAMS AND DESCRIPTION OF THE BOP EQUIPMENT TO BE USED As required by 20 AAC 25.035 (a) (1) and Per 20 AAC 25.005 (c) (5): DIAGRAM AND DESCRIPTION OF THE DIVERTER SYSTEM TO BE USED As required by 20 AAC 25.035 (b) RECEIVED tvlA ¥ - 5 1995 Oil & Gas Cor~s. Cor~rnission 4nchor~, ~ TRIP TANK FILL-UP LINE 20" 2000# 5 BUFFLEHEAD NO. 1 ANNULAR PREVENTER NABORS RIG 154 SYSTEM I MAINTENANCE AND OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVES OPEN PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. 4. VENT TANKS CAN BE UTILIZED INSTEAD OF PITS FOR DIVERTING FLUIDS OR GAS. 5. ALL TURNS ARE TARGETED TEES. 6. VALVE #6 OPENS AUTOMATICALLY WHEN #4 ANNULAR PREVENTER CLOSES. DURING OPERATIONS, VALVE #7 REMAINS OPEN AND VALVE #8 REMAINS CLOSED. IF NECESSARY, VALVE 7 CAN BE CLOSED AND VALVE 8 OPENED REMOTELY FROM THE ACCUMULATOR CONTROLS TO REDIRECT DIVERTED FLOW TO ALTERNATE PIT. SINCE CONTROL FOR 7 & 8 ARE SAME HANDLE ON PANEL, EITHER 7 OR 8 WILL ALWAYS BE OPEN. 3 2A ,../ 10" LINE / 10" LINE PIT TO RESERVE PIT 1) 20" CONDUCTOR (DRIVEN) 2) 20" SLIP-ON WELD STARTER HEAD W/21-1/4" 5000 PSI FLANGE UP 2A) 20" SPACER SPOOL W/20" 2000 PSI FLANGES UP & DOWN 3) 20" 2000 PSI DRILLING SPOOL W/21-1/4" 2000 PSI FLANGES AND ONE SIDE OUTLET 4) 20" 2000 PSI ANNULAR PREVENTER 5) 20" DRILLING BELL NIPPLE W/FLOWLINE AND TRIP TANK OUTLETS 6) 10-3/4" HOR FULL-OPENING "KNIFE" VALVE W/TARGETED T 7) 10" HYDRAULIC REMOTE FULL OPENING BALL VALVE 8) 10" HYDRAULIC REMOTE FULL OPENING BALL VALVE R'EC£IVi D .MAY - ,5 1995 ARCO Alaska, Inc. 0il & Gas Cons. Commission Anchors ~, TWM, 5/5~95 I I i 6BLIND RAM I I I <31 BUFFLEHEAD NO. I 13 5/8" 10000 PSI BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 30(X) PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3, OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND MASP AS IN STEP 4. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND MASP HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY 8. CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BO'FI'OM PIPE RAMS. TEST BO'I-rOM 9. RAMS TO 250 PSI AND MASP. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE 10. CLOSE BLIND RAMS AND TEST TO MASP FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD 11. AND 12. LINES ARE FULLOF ARCTIC DIESEL AND ALL VALVES ARE SET ~N 13. DRILLING POSITION. TEST STANDPIPE VALVES TO MASP, 14. TEST KELLY COCKS AND INSIDE BOP TO MASP WITH KOOMEY RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY, NOTE: MASP = MAXIMUM ANTICIPATED SURFACE PRESSURE INSTALL TEST PLUG PRIOR TO TESTING TO MASP 1. 20' - 5000 PSI STARTING HEAD 2. 13-5/8' - .5000 PSI x 13-.6/8' 10000 PSI CASING HEAD 3. 13-5/8' - IO000PSI X 13-5/8' - IO000PSI CASINGHEAD 4. 13-5,"8' - 10000 PSI PIPE RAMS 5. 13-5/8' - 10000 PSI DRLG SPOOL W/CHOKE AND KILL LINES 6. 13-5/8' - 10000 PSI BLIND RAMS 7. 13-5/8' - 10000 PSI PIPE RAMS 8. 13-5/8' - 5000 PSI ANNULAR RECEIVED MAY - 5 1995 T'VVM 5 3,'c~5 NAt~C,;~S ' 54 A!~s~3/Oil .& Gas Cons. Commission MAT TRIP TANK~ FILL UP LINE J ! ' ' I I < 13-5/8-1 OK 13-5/8-1 OK 20" SLIP-ON I' I PIPE RAM ~=, I BLIND RAM I J CROSS I I I I PIPE RAM F 9.40' 22.90' BUFFLEHEAD NO. 1 WELLHEAD AND BOP SPACEOUT NABORS RIG 154 STACK 25.15' MAT I ~ A) 20" CONDUCTOR DRIVEN TO +/- 80' BELOW PAD LEVEL B) 20" SLIP-ON WELD STARTER HEAD W/21-1/4" 5000# FLANGE UP, 21.5" HIGH (NET AFTER WELD-ON) C) 13-3/8" CASINGHEAD W/21-1/4" 5000# FLANGE DOWN & 13-5/8" 10000~ FLANGE UP, 33" HIGH D) 9-5/8" CASINGHEAD W/13-5/8" 10000# FLANGE DOWN & 13-5/8" 10000# FLANGE UP, 29" HIGH E) 7" CASINGHEAD W/13-5/8" 10000# FLANGES UP & DOWN. 29" HIGH F) TOTAL NET HEIGHT, SECTIONS B, C, D & E IS 112.5". OR 9 FEET, 4-1/2 INCHES NOTE: "X2" MEANS TWO VALVES RECEIVED MAY - 5 199,5 Oil & Ga~_ t;~$. Commission ARCO Alaska, Inc. TWM, 4/19/95 BUFFLEHEAD No. 1 Nabors Rig 154 MAJOR BOPE COMPONENTS, 13-5/8" 10,000 psi SYSTEM _.Diverter System 1. 21-1/4", 2000 psi, WP Hydril MSP Annular Preventer with companion flange to Diverter Spool. 2. 21-1/4", 2000 psi ,WP Diverter Spool with one 10-3/4" outlet. 3. Two (2) 10", Groove Hydraulic Remote Ball Valves controlled by single lever on panel which allows one valve to always remain open. 4. 10", Flanged Diverter Line, 150 feet long, or as required. BOPE Stack 5. 13-5/8", 5000 psi WP, Hydril Type GK Annular Preventer with companion flange to bell nipple. 6. 13-5/8", 10,000 psi WP, Shaffer Double Gate ram BOP fitted with pipe rams on top, and blind rams on bottom (immediately above drilling spool). 7. 13-5/8", 10,000 psi WP, Drilling Spool with two (2) 4-1/16" 10,000 psi WP outlets. 8. 13-5/8", 10,000 psi WP, Shaffer Single Gate ram BOP fitted with pipe rams; these rams are in the bottom position on BOP Stack. Choke Valves 9. 4-1/16", 10,000 psi WP, Cameron Type FC Hydraulic Valve with hydraulic actuator. 10. 4-1/16", 10,000 psi WP, Cameron Type FC Valve. 11. 4-1/16", 10,000 psi WP, OCT Kill Valves 12. 1-each 4-1/16", 10,000 psi WP, Cameron Type FC Valves and 1-each 4- 1/16", 10,000 psi WP, Cameron Type FC Hydraulic Valve with hydraulic actuator. Check Valve8 None RECEIVED Iv1AY - 5 1995 0il & Gas CODS. CommlssloD Anchors ~ RECEIVED JVlAY - 5 lcJB5 A C l 2 3 4 & ? $ 12 13 14 15 1116.10M 1116-10M IIIg. I§M 1116.101~! lll6-10al Ill6.10M III6.10M III6-11IM l/Itl .101~l 1116-10M II 16.101~1 I 116-10M ll16-10h,! Trillo tlyd. Choke · riflo Ilyd. Choke CamerQu Type H Adj. Choke OCT Model 30 Manual Gale Valve Cameron FC hhmual Gate Valve OCT I~lodel ~0 IVlanuaJ Gate Valve OCT l~lndel 30 Manual Gate Valve Cameron IcC Manual Oate Valve Cameron FC IVlanual Gate Valve OCT blodel 30 ~lanual Gate Valve OCT Model 30 IVJanual Gate Valve OCT Model 30 lVtanual Gate Valve Cameron FC Manual Gale Valve Camel-on FC Manual Gatt Valve Cameron FC Manlml Gale Valve 1/16.10M OCT Model 30 Manual Gate Valve 118-$M OCT Mndel 20 Manual Gale Valve 1116-10M OCT Model 3~ Mnn,,a~ Gate Valve ., · BUFFLEHEAD NO. 1 NABORS RIG 154 10,000 PSI CHOKE MANIFOLD HAND FROM BOP STACK/HCR VALVE 4-10 4-10 KEY: 4-10: 3-10: 4-5: 3-5: 4" X 10,000 PSI 3" X 10,000 PSI 4" X 5,OO0 PSI 3" X 5,O0O PSI TWM, 4/19/95 3-10 t TO GASSUSTER 3-10 10 3/4-10 4-10 I ' -1 0~___~ 1 -10 Spool m be 3/4- 1 0 - 1 0 TO RESERVE PIT/FLARE PIT 4-10 PANIC LINE TO PIT BUFFLEHEAD No. I SAFETY AND REPORTING PROCEDURES, Equipment Type Frequency Outline of Test Pit Volume Totalizer FIo Sho Weight Indicator Drill String Drag Beginning of each tour Each trip Each trip End of tour 1 - Move each pit level float and check chart for recording movement and calibration, if inoperative, notify ARCO Supervisor. 2 - Initial chart after verifying that PVT is operating in good order. Note mud volume in pits on tour sheet before and after each trip. 1 - Derrickman or Pitwatcher record on pit watchers form pit volume at end of trip. Record amount filled and number of stands when filled during trip. Record returns tripping in. Have toolpusher check recordings and initial. 2 - Record information on APl tour report. Observe chart for proper operation. I - Check weight of empty blocks against indicator. 2 - Check weight of DP, HWDP, and collars al surface casing. Report on tour sheet. 3- Check sensor element spacing between flanges. 4- Record drill line slip and cuts on APl report ~n designated form. I - Note and record on APl tour report; pick up weight, slack off weight and rotating weight 2 - Record any tight spot depths for safety reference. RECEIVED {vlAY - $ 1995 A!~.sga .0il & Gas Cons. Commission Anchors -, Circulation Rate Geolograph SPECIAL INSTRUCTION Beginning of each tour Every 24 hrs . 3- 4- 5- 1 - At beginning of each tour run each pump individually at slow rate of 30-35 strokes/min. Record on IADC repod.and geolograph chad exact pump strokes, pressure and leg of drill string. 1 - Drillers fill out new heading. Check date, well identification and depth of chart taken off. Record all connection depths on chad. Record depth and stad of trip Record change of bit or tools on BHA. Record depth of breaking circulation and reaming. 6- Record any and all down time. 7- Recording pens not in use or inoperative are to be repoded immediately to company rep. 8- Record explanation for unusual occurrences on chads. 9- Send chad in daily. Minimum of one Pit Drill per week will be held for each crew and recorded with times to stations on APl tour sheet. Crew timing to stations will designate frequency of pit drills by rig pushers. Give padicular attention to driller and toolpusher understanding the impodance of knowing and recording where every barrel of mud went while tripping in/out of hole. Pay extremely close attention to volumes and fill pit system to be sure of accurate performance during each trip. Toolpushers will check all geolograph, pit level chads, and IADC tour repods and initial for accuracy each morning before forwarding to Company representative. Each crew to hold week _ly safety meeting with discussion notes forwarded to Company representative. Record meeting on APl report. Mud engineer to fill out mud data completely on APl repod. No smoking is allowed within 150' of well center. TWM, 4/19/95 RECEIVED ~viAY ~ 5 1995 A!~ska ~ii & Gas Cons. Commission ^nch0r~. ~ WELL PERMIT CHECKLIST FIELD & POOL INIT CLASS ~// GEOL AREA ~ UNIT# PROGRAM: exp~ dev [] redrll [] aery [] ON/OF~ s~o~ ~1 ~DMINISTRATION ENGINEERING GEOLOGY 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number ............... 4. Well located in a defined pool .............. 5. Well located proper distance from drlg unit boundary...Y 6. Well located proper distance from other wells ...... ' 7. Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included . . F~/~ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order 12. Permit can be issued without administrative approval.. ~ N 13. Can permit be approved before 15-day wait ....... 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. Y ~ 30. Permit can be issued w/o hydrogen sulfide measures... ~.Y~ N ~/~.~,~ -~. Data presented on potential overpressure zones .. .... Y~ ~ - j .... ~f~~' Seismic analysis 9f shallow gas zones .......... Y ~ Comments/Instructions: J ' m mm m 31. 32. 33. Seabed condition survey (if off-shore) . . -~4 .... Y 34. Contact name/phone for weekly progress reports ..... Y [exploratory o~ly] COMMISSION: GEOLOGY: ENGINEERING: Z 0 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. , tmlberger Page * SCHLUMBERGER * ***************************** SCHLUMBERGER WELL SERVICES ALASKA DIVISION COMPUTER CENTER 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 907/562-2654 TAPE VERIFICATION LISTING LIS FORMAT LIS TAPE VERIFICATION FOR RFT FIELD TAPE Job Number 95335 Company Name ARCO ALASKA INC. Well Name BUFFLEHEAD #1 Field Name WILDCAT County KENAI State ALASKA Service Order Number 630331 ~eN~red 9-DEC-95 FOUR Date Processed 8-JAN-96 Files Included - . ., dmberger Page 3 LIST Command Listing KEY I LIST SUMMARY MNEMONICS summaries written, for Logical LIS structures: FILE /Abbrev: F) LIS logical file info TAPE ~Abbrev: T) LIS logical tape info REEL (Abbrev: R) LIS logical reel info and for tile entire LIS/A input logical unit: LU (Abbrev: L) LIS/A logical unit info The field labels appear on some or all of these summaries, as indicated by tile abbrev, on right. Summary Field Labels: TAPES R FI LES LRT / #PR LRTF/ #LR LRTF) #DR #ENC #FM PI PI UNITS MAXPI MINPI Number of logical reels on Number of logical tapes on Number of logical files on Number of physical records Number of logical records Number of data records Number of encrypted records Number of data frames Primary index channel name Primary index units mnemonic Maximum pr!mary index value Minimum primary index value .,umberger LIST $15DUA2:[9533~ ~_RFT]RFTFLD.LI Reel header DEFAULT Tape header DEFAULT File header RFTB .045 Frame data record(s) encountered File trailer RFTB .045 8-JAN-96 10:52:29 Pag. FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 34 68 0 7 277 DEPT .lIN 1242600 1226040 DEPT F 10355. 10217. DEPT M 3156.204 3114.1416 File header RFTB .046 Frame data record(s) encountered File trailer RFTB .046 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 36 70 0 9 396 DEPT .lIN 1398300 1374600 DEPT F 11652.5 11455. DEPT M 3551.682 3491.484 File header RFTB .078 Frame data record(s) encountered File trailer RFTB .078 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 33 67 0 6 249 DEPT .lIN 1392060 1377180 DEPT F 11600.5 11476.5 DEPT M 3535.8324 3498.0372 File header RFTB .079 Frame data record(s) encountered File trailer RFTB .079 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI ..... ~ ..... ~ ..... ~ ..... ~ ...... ~ .... ~---~ii~ .... i~ .... i~i~-- DEPT F 12050.5 11901.5 DEPT M 3672.9924 3627.5772 File header RFTB .080 Frame data record(s) encountered File trailer RFTB .080 .,umberger LIST $15DUA2:[95335..~_RFT]RFTFLD.LI 8-JAN-96 10:52:29 Page 5 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MA×PI MINPI _ 34 68 0 7 308 DEPT .lIN 1443720 1425300 DEPT F 12031. 11877.5 DEPT M 3667.0488 3620.262 File header RFTB .047 Frame data record(s) encountered File trailer RFTB .047 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MA×PI MINPI _ File header RFTB .048 Frame data record(s) encountered File trailer RFTB .048 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MA×PI MINPI -- File header RFTB .049 Frame data record(s) encountered File trailer RFTB .049 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MA×PI MINPI _ ..... ~ ..... i~¢ .... ~ ..... ~¢ ..... ~---~---~ .... i~~---~¢~- File header RFTB .050 Frame data record(s) encountered File trailer RFTB .050 FILE SUMMARY #LR #PR #EN¢ #DR #FM PI PI UNITS MA×PI MINPI ..... ~i ..... ~ ..... ~ ..... ~ ..... ~i---~--'~ .... File header RFTB .051 Frame data record(s) encountered File trailer RFTB .051 ..,umberger LIST $15DUA2:[9533. u_RFT]RFTFLD.LI 8-JAN-96 10:52:29 Pa§_ 6 FILE SUMMARY #LR #PR #EN¢ #DR #FM PI PI UNITS MAXPI MINPI -- 66 100 0 40 2633 TIME .5MS 21263366 22842566 File header RFTB .052 Frame data record(s) encountered File trailer RFTB .052 FILE SUMMARY #LR #PR #EN¢ #DR #FM PI PI UNITS MA×PI MINPI ..... ~ ..... ~ ..... ~ ..... ~ ..... i~-'-~i~-"~ .... ~~---~~' File header RFTB .053 Frame data record(s) encountered File trailer RFTB .053 FILE SUMMARY #LR #PR #EN¢ #DR #FM PI PI UNITS MA×PI MINPI -- 46 80 0 20 1279 TIME .5MS 24509762 25276562 File header RFTB .054 Frame data record(s) encountered File trailer RFTB .054 FILE SUMMARY #LR #PR #EN¢ #DR #FM PI PI UNITS MAXPI MINPI 42 76 0 16 1010 TIME .SMS 25707396 26312796 File header RFTB .055 Frame data record(s) encountered File trailer RFTB .055 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MA×PI MINPI -- ..... ~¢ ..... i~ .... ~ ..... ~ ..... ~---~i~---~ .... File header RFTB .056 Frame data record(s) encountered File trailer RFTB .056 ~,,~umberger LIST $15DUA2:[95335..~_RFT]RFTFLD.LI 8-JAN-96 10:52:29 Page FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MA×PI MINPI -- 53 87 0 27 1764 TIME .5MS 30322398 31380198 File header RFTB .057 Frame data record(s) encountered File trailer RFTB .057 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI ._ 50 84 0 24 1594 TIME .5MS 33749808 34705608 File header RFTB .058 Frame data record(s) encountered File trailer RFTB .058 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 38 72 0 12 801 TIME .5MS 37061984 37541984 File header RFTB .059 Frame data record(s) encountered File trailer RFTB .059 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI ..... ~ ..... ~ ..... ~ ..... ¢ ...... ~ .... ~i~---~ .... ~~---~¢~- File header RFTB .060 Frame data record(s) encountered File trailer RFTB .060 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 36 70 0 10 627 TIME .5MS 38340692 38716292 File header RFTB .061 Frame data record(s) encountered File trailer RFTB .061 .~,llulnberger LIST $15DUA2:[95335..=_RFT]RFTFLD.LI 8-JAN-96 10:52:29 Pag~ 8 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 37 71 0 11 673 TIME .5MS 40087696 40490896 File header RFTB .062 Frame data record(s) encountered File trailer RFTB .062 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI __ 36 70 0 10 637 TIME .5MS 40933240 41314840 File header RFTB .063 Frame data record(s) encountered File trailer RFTB .063 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI ._ 36 70 0 10 651 TIME .5MS 41908280 42298280 File header RFTB .064 Frame data record(s) encountered File trailer RFTB .064 FILE SUMMARY #LR #PR #EN¢ #DR #FM PI PI UNITS MAXPI MINPI -- File header RFTB .065 Frame data record(s) encountered File trailer RFTB .065 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI __ ..... ~ ..... ~i ..... ~ ..... ii ..... ~i .... ~i~---~ .... ~¢~---~i~- File header RFTB .066 Frame data record(s) encountered File trailer RFTB .066 .~nlumberger LIST $15DUA2:[95335.,u_RFT]RFTFLD.LI 8-JAN-96 10:52:29 Pag~ FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 47 81 0 21 1342 TIME .SMS 45239904 46044504 File header RFTB .067 Frame data record(s) encountered File trailer RFTB .067 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 50 84 0 24 1576 TIME .SMS 46358280 47303280 File header RFTB .068 Frame data record(s) encountered File trailer RFTB .068 FILE SUMMARY #LR #PR #EN¢ #DR #FM PI PI UNITS MAXPI MINPI ..... ~ ..... ~¢ ..... ~ ..... i¢ ..... i~---~i~'--~ .... ~~---~~- File header RFTB .069 Frame data record(s) encountered File trailer RFTB .069 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI - File header RFTB .070 Frame data record(s) encountered File trailer RFTB .070 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MA×PI MINPI ~_ ..... ~ ..... ~ ..... ~ ..... ~ ..... ii~---~i~---~ .... ~¢~---~¢~- File header RFTB .071 Frame data record(s) encountered File trailer RFTB .071 ~nlumberger LIST $15DUA2:[95335..u_RFT]RFTFLD.LI 8-JAN-96 10:52:29 Pag~ 10 FILE SUHMARY #LR #PR #ENC #DR #FM PI PI UNITS MA×PI MINPI _.- File header RFTB .072 Frame data record(s) encountered File trailer RFTB .072 FILE SUMMARY __ 33 67 0 7 465 TIME .5MS 51810484 52088884 File header RFTB .073 Frame data record(s) encountered File trailer RFTB .073 FILE SUMHARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI __ ..... ~ ..... ~ ..... ~ ..... ~ ..... i~i~'--~i~---~ .... ~i~-'-~i~- File header RFTB .081 Frame data record(s) encountered File trailer RFTB .081 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MA×PI MINPI .__ ..... ~ ..... ~ ..... ~ ..... ~ ..... i~---~---~ .... ~¢~ .... ~¢~i¢~-- File header RFTB .082 Frame data record(s) encountered File trailer RFTB .082 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MA×PI MINPI _ ..... ~ ..... ~i ..... ~ ..... ii ..... ~ .... ~i~-'-~ .... ~i¢i~ .... ~i~'- File header RFTB .083 Frame data record(s) encountered File trailer RFTB .083 .... nlumberger LIST $15DUA2:[95335..~_RFT]RFTFLD.LI 8-JAN-96 10:52:29 Pag~ 11 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI 82 116 0 56 3692 TIME .5MS 7917392 10131992 File header RFTB .084 Frame data record(s) encountered File trailer RFTB .084 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 38 72 0 12 803 TIME .5MS 10886784 11367984 File header RFTB .085 Frame data record(s) encountered File trailer RFTB .085 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- ..... ~ ..... ~ ..... ~ ..... ~ ..... ~---~i~---~ .... Tape trailer DEFAULT TAPE SUMMARY FILES #LR #PR 37 1778 3036 Reel trailer DEFAULT REEL SUMMARY FILES TAPES #LR #PR 37 1 1780 3038 (EOD) LU SUMMARY FILES TAPES REELS #LR #PR 37 1 1 1780 3038 Jct~tumberger LIST $15DUA2:[9533b..~_RFT]RFTFLD.LI 8-JAN-96 10:52:29 End of listing $15DUA2:[95335.TD_RFT]RFTFLD.LIS~2 Pag~ 12 ~.. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... ~ ............................ COMPANY NAME : ARCO ALASKA, INC. WELL NAME : BUFFLEHEAD #1 FIELD NAME : WILDCAT BOROUGH : KENAI STATE : ALASKA API NUMBER : 501332046600 REFERENCE NO : 95335 CONF)DENTIAL per A06CC reg. 20 ~ 25,53~' ~ A CROF Lt D _.~ Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/01/ 8 ORIGIN : FLIC REEL NAME : 95335 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., WILDCAT, BUFFLEHEAD #1, API# 50-133-20466-00 PAGE: **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/01/ 8 ORIGIN : FLIC TAPE NAME : 95335 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., WILDCAT, BUFFLEHEAD #1, API# 50-133-20466-00 TAPE HEADER WILDCAT OPEN HOLE WIRELINE LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD BUFFLEHEAD #1 501332046600 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 4-JAN-96 1ST STRING 2ND STRING RUN I RUN 3 RUN 4 95335 95335 95335 SIMMONS SIMMONS SIMMONS CAMPAIGN GRETHER CAMPAIGN 3 8N 9W 2337 1319 302.85 301.85 277.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ....... ..... 8. 500 9. 625 5204.0 _,~ Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 3RD STRING 6.000 7.000 10620.0 PRODUCTION STRING REMARKS: LDWG LIBRARY TAPE CONTAINING THE MERGED DATA FROM 3 RUNS OF DIT-E, LDT-D, CNT-G, DSI, AND SHDT LOGGING TOOLS. THE ABOVE DATA HAS BEEN DEPTH CORRECTED TO THE DIT-E RESISTIVITY TOOL AND ALL DATA HAS BEEN CLIPPED FOR INVALID DATA. $ **** FILE HEADER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH DTE 12320.0 528.0 DAS 12295.5 514.0 SDN 12295.0 512.0 CNTG 12273.0 512.0 $ BASELINE CURVE FOR SHIFTS: ILD CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH 88888.0 12266.5 12261.5 12260.5 12254.5 12251.5 12251.0 12194.0 12171.0 12151.0 12150.0 12149.5 12096.0 12095.5 DAS SDN CNTG 12258.5 12254.0 12250.5 12194.0 12170.0 12149.5 12095.5 12266.5 12260.0 12250.5 12194.0 12194.0 12171.0 12170.5 12150.5 12095.5 12148.5 12096.0 Tape Verification Listing Sd~lumberger Alaska Computing Center 8-JAN-1996 09:04 PAGE: 12084.5 12084.5 12082.0 12081.5 12081.5 12081.5 12078.0 12078.0 12065.0 12065.0 12062.5 12062.0 12061.5 12061.5 12059.5 12058.0 12057.5 12055.5 12054.5 12054.0 12054.0 12048.5 12048.0 12044.5 12044.0 12034.5 12034.5 12034.0 12034.0 12033.0 12034.0 12004.5 12004.0 12001.5 12001.5 12001.5 11961.5 11961.0 11961.0 11961.0 11935.5 11935.0 11934.5 11934.5 11916.5 11917.0 11916.0 11917.0 11906.5 11907.0 11906.0 11907.0 11880.0 11880.5 11872.5 11873.0 11872.0 11873.0 11842.0 11842.5 11842.5 11836.5 11834.0 11822.0 11822.5 11823.0 11821.5 11822.5 11812.0 11811.5 11811.0 11811.5 11812.0 11798.5 11798.0 11798.0 11798.0 11798.0 11768.5 11767.5 11768.0 11767.0 11763.5 11763.0 11763.0 11762.5 11754.0 11753.5 11753.0 11753.0 11707.0 11707.0 11697.5 11697.5 11675.0 11675.0 11672.0 11672.0 11648.5 11649.0 11648.0 11649.0 11649.0 11636.5 11637.0 11612.0 11612.0 11611.5 11611.5 11609.0 11608.5 11608.5 11608.5 11606.5 11606.0 11595.5 11595.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 PAGE: 11591.5 11591.0 11587.0 11586.5 11587.0 11584.5 11564.0 11563.5 11563.5 11503.5 11503.0 11494.0 11494.5 11485.0 11485.0 11476.5 11476.0 11476.5 11474.0 11473.5 11468.5 11451.5 11450.0 11450.5 11417.0 11416.5 11416.5 11416.0 11395.5 11395.0 11395.0 11369.0 11368.5 11368.0 11368.0 11327.0 11326.0 11326.0 11308.0 11307.5 11307.5 11296.0 11295.0 11295.5 11271.5 11270.0 11271.0 11270.5 11260.5 11260.0 11260.0 11253.5 11252.5 11252.0 11247.5 11238.0 11215.5 11215.0 11215.0 11200.5 11200.0 11199.5 11199.5 11193.5 11179.5 11180.0 11179.0 11161.5 11160.5 11161.0 11127.5 11126.5 11127.5 11123.5 11122.0 11123.0 11098.5 11098.0 11098.5 11591.0 11476.0 11450.5 11417.0 11368.0 11326.0 11295.5 11270.0 11199.5 11591.5 11587.0 11584.5 11563.5 11503.0 11476.0 11468.5 11416.5 11395.5 11368.5 11326.5 11307.5 11270.0 11259.5 11252.5 11247.0 11237.5 11215.5 11199.5 11193.5 11180.5 11161.0 11127.5 11123.0 11098.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 PAGE: 11088.0 11087.5 11087.5 11087.5 11079.0 11078.5 11077.0 11078.0 11074.5 11074.5 11074.0 11074.0 11036.5 11036.5 11036.0 11036.0 11036.0 11017.5 11017.5 11017.5 11005.0 11004.0 10991.0 10990.5 10984.0 10983,0 10983.5 10983.0 10981.0 10980.5 10978.0 10977.5 10971.0 10970.0 10968.5 10968.0 10954.5 10953.5 10953.5 10953.5 10943.5 10943.0 10942.5 10942.5 10942.5 10900.0 10899.5 10897.5 10896.5 10896.5 10896.0 10895.0 10894.0 10894.0 10894.0 10891.5 10890.0 10891.0 10890.5 10881.5 10881.5 10854.0 10853.5 10853.5 10853.5 10853.0 10853.5 10850.0 10849.5 10847.5 10847.0 10845.5 10846.5 10841.5 10841.0 10840.0 10841.0 10832.0 10831.5 10823.5 10823.0 10822.5 10822.5 10823.0 10816.5 10816.5 10789.5 10788.5 10759.5 10756.5 10748.5 10748.5 10748.0 10746.0 10746.0 10718.0 10717.5 10717.0 10717.0 10707.0 10707.0 10706.0 10706.5 10687.0 10688.0 10674.0 10674.5 10673.0 10674.0 10671.5 10673.5 10670.5 10670.5 10663.5 10664.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 PAGE: 10660.0 10660.5 10650.0 10649.5 10648.5 10649.5 10643.5 10646.5 10636.5 10634.5 10637.5 10630.5 10631.5 10628.0 10629.5 10623.5 10623.0 10623.5 10605.5 10606.5 10603.0 10604.5 10601.0 10603.0 10586.5 10586.0 10586.5 10543.0 10544.0 10531.0 10525.0 10526.0 10524.5 10514.5 10515.5 10507.0 10508.0 10493.0 10494.0 10484.5 10486.0 10476.5 10474.0 10475.5 10457.5 10453.5 10455.0 10451.5 10447.5 10445.0 10447.0 10410.5 10405.5 10407.5 10401.5 10402.5 10388.5 10390.0 10343.0 10343.5 10299.0 10299.5 10286.5 10286.5 10272.0 10271.0 10269.0 10268.5 10259.0 10260.5 10240.5 10240.5 10230.5 10231.5 10185.5 10185,0 10183.5 10185.0 10165.5 10165.0 10163.5 10164.5 10124.5 10122.5 10124.0 10102.0 10101.0 10101.0 10093.5 10093.0 10650.0 10636.5 10185.5 10164.5 10092.5 10649.5 10623.5 10586.5 10531.0 10524.5 10475.0 10457.5 10451.5 10447.5 10410.5 10405.5 10185.5 10165.0 10124.5 10101.0 10093.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 PAGE: 10660.0 10660.5 10650.0 10649.5 10648.5 10649.5 10643.5 10646.5 10636.5 10634.5 10637.5 10630.5 10631.5 10628.0 10629.5 10623.5 10623.0 10623.5 10605.5 10606.5 10603.0 10604.5 10601.0 10603.0 10586.5 10586.0 10586.5 10543.0 10544.0 10531.0 10525.0 10526.0 10524.5 10514.5 10515.5 10507.0 10508.0 10493.0 10494.0 10484.5 10486.0 10476.5 10474.0 10475.5 10457.5 10453.5 10455.0 10451.5 10447.5 10445.0 10447.0 10410.5 10405.5 10407.5 10401.5 10402.5 10388.5 10390.0 10343.0 10343.5 10299.0 10299.5 10286.5 10286.5 10272.0 10271.0 10269.0 10268.5 10259.0 10260.5 10240.5 10240.5 10230.5 10231.5 10185.5 10185.0 10183.5 10185.0 10165.5 10165.0 10163.5 10164.5 10124.5 10122.5 10124.0 10102.0 10101.0 10101.0 10093.5 10093.0 10650.0 10636.5 10185.5 10164.5 10092.5 10649.5 10623.5 10586.5 10531.0 10524.5 10475.0 10457.5 10451.5 10447.5 10410.5 10405.5 10185.5 10165.0 10124.5 10101.0 10093.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 10087.5 10087.5 10078.5 10079.0 10078.0 10079.0 10056.0 10055.5 10055.5 10055.5 10053.5 10055.5 10030.0 10030.5 10026.5 10026.0 10023.5 10025.0 10021.5 10021.5 10012.5 10013.5 10011.5 10011.5 10010.5 10010.5 10001.5 10003.5 9979.5 9979.5 9978.0 9979.0 9979.5 9953.0 9952.5 9952.0 9952.5 9951.5 9952.5 9942.5 9942.5 9932.5 9932.5 9928.0 9929.5 9924.0 9924.0 9922.5 9923.5 9921.0 9921.5 9908.5 9909.0 9908.0 9908.5 9886.0 9886.5 9879.0 9879.5 9871.5 9872.0 9864.0 9863.5 9862.5 9863.0 9847.0 9847.5 9845.5 9847.5 9836.0 9835.5 9833.5 9832.5 9832.5 9832.5 9827.0 9827.5 9823.5 9823.5 9822.0 9822.0 9805.5 9805.0 9804.0 9805.5 9793.5 9793.5 9793.0 9793.5 9792.5 9793.0 9782.5 9783.0 9776.0 9776.5 9768.0 9768.0 9761.5 9761.5 9761.0 9761.5 9760.5 9761.5 9750.5 9750.5 9750.0 9750.5 9748.5 9750.5 9728.0 9728.0 09:04 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9727.0 9728.0 9710.0 9709.0 9710.0 9694.5 9694.0 9695.0 9675.0 9674.5 9675.5 9662.0 9661.5 9660.0 9661.0 9655.5 9654.0 9655.0 9615.0 9613.0 9601.0 9600.0 9600.5 9590.5 9590.0 9590.0 9558.0 9557.5 9557.0 9558.5 9533.0 9524.0 9523.0 9523.5 9506.5 9505.0 9506.5 9502.5 9498.5 9497.0 9498.0 9449.5 9447.0 9449.0 9414.5 9414.0 9415.5 9403.5 9402.5 9394.5 9391.0 9392.0 9390.0 9373.5 9371.0 9372.0 9351.5 9352.5 9349.5 9347.5 9348.5 9334.0 9331.5 9333.0 9320.5 9300.0 9271.0 9268.0 9271.0 9264.5 9262.0 9264.0 9249.0 9246.0 9248.5 9230.5 9229.0 9710.5 9675.5 9661.5 9613.0 9558.0 9502.5 9450.0 9415.0 9401.5 9229.0 8-JAN-1996 09:04 9710.0 9694.5 9662.0 9655.0 9614.5 9601.0 9590.0 9558.0 9533.0 9524.0 9506.5 9498.5 9415.0 9402.0 9394.0 9389.5 9373.0 9348.5 9333.0 9320.5 9300.0 9271.0 9264.0 9249.0 9230.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 PAGE: 9 9228.0 9231.0 9216.5 9218.5 9214.5 9215.0 9199.0 9198.5 9196.0 9198.0 9184.0 9184.0 9181.0 9183.0 9152.5 9152.5 9152.0 9152.0 9150.0 9152.5 9134.5 9134.0 9133.0 9134.0 9093.5 9094.0 9093.0 9094,0 9091.5 9094.0 9070.0 9070.5 9069.5 9070.5 9067.5 9070.0 9043.5 9044.0 9042.0 9044.0 9038.0 9038.0 9029.5 9032.0 9002.5 9001.5 9001.5 9001.0 8979.5 8979.0 8979.0 8978.5 8977.5 8978.5 8965.5 8965.0 8964,0 8964.5 8950.0 8949.5 8942.5 8943.5 8934.5 8933.5 8922.0 8922.0 8920.5 8922.0 8916.0 8915.5 8899.5 8900.5 8899.0 8899.0 8895.5 8895.5 8895.0 8896.0 TABLE TYPE : CONS TUNI VALU DEFI CN ....... ~-~[~[-i~]- Company Name FN WILDCAT Field Name WN BUFFLEHEAD #1 Well Name APIN 501332046600 API Serial Number FL 1319 FEL & 2337 FSL Field Location SECT 3 Section TOWN 8N Township RANG 9W Range COUN KENAI County STAT ALASKA State or Province LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 PAGE: 10 TUNI VALU DEFI USA Nation NATI WITN CAMPAIGN SON 630331 PDAT MSL EPD FT O. LMF RKB APD FT 302.85 EKB FT 302.85 EDF FT 301.85 EGL FT 277. TDD FT 12350. TDL FT 12332. BLI FT 12320. TLI FT 512. DFT KCL/POLYMER DFD G/C3 11. DFPH 9.1 DFV S 43. DFL F3 5. RMS OHMM 0.25 MST DEGF 70. RMFS OHHM 0.34 HFST DEGF 70. RMCS OHMM 0.5 MCST DEGF 70. TCS 08:30 9-DEC-95 TLAB 17:38 9-DEC-95 BHT DEGF 176. Witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth Logger Bottom Log Interval Top Log Interval Drilling Fluid Type Drilling Fluid Density Drilling Fluid Ph Drilling Fluid Viscosity Drilling Fluid Loss Resistivity of Mud Sample Mud Sample Temperature Resistivity of Mud Filtrate S Mud Filtrate Sample Temperatu Resistivity of Mud Cake Samp] Hud Cake Sample Temperature Time Circulation Stopped Time Logger at Bottom Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth SFL SFL Resistivity Unaveraged ILD ILH IDPH IMPH SP GR MRES HTEM TENS TEND DT DTSH SCRA GR CALl RHOB Deep Induction Standard Processed Resistivity Medium Induction Standard Processed Resistivity INDUCTION DEEP PHASOR RESISTIVITY INDUCTION MEDIUM PHASOR RESISTIVITY Spontaneous Potential Gamma Ray MUD Resistivity Mud Temperature Tension Head Tension DELTA-T COMPRESSIONAL HF MONOPOLE COMPENSATED (P&S) DELTA-T SHEAR UPPER DIPOLE MODE COMPENSATED RATIO SHEAR TO COMPRESSIONAL DELTA T Gamma Ray Caliper Bulk Density LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 DEFI DRHO Delta RHO PEF PhotoElectric Factor CALl Caliper GR Gamma Ray MRES MUD Resistivity MFEM Mud Temperature TENS Tension TEND Head Tension NPHI Neutron Porosity ENPH Epithermal Neutron Porosity CRAT Thermal Neutron Ratio Calibrated NRAT Raw Thermal Neutron Ratio ENRA Epithermal Neutron Ratio Calibrated CFTC Corrected Far Thermal Counts CNTC Corrected Near Thermal Counts CFEC Corrected Far Epithermal Counts CNEC Corrected Near Epithermal Counts GR Gamma Ray C13 Caliper 1 - 3 C24 Caliper 2 - 4 DEV Hole Deviation AZ Hole Azimuth RB1 Pad 1 Azimuth GR Galllma Ray PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 168 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 PAGE: 12 ** SET TYPE - CHAN ** ,uM DEPT FT 630331 O0 000 O0 0 1 1 1 4 68 ---O000000000- --,.T~77~] SFL DTE OHMM 630331 O0 000 O0 0 i I 1 4 68 0000000000 ILD DTE OHMM 630331 O0 000 O0 0 I 1 1 4 68 0000000000 ILM DTE OHMM 630331 O0 000 O0 0 i i 1 4 68 0000000000 IDPH DTE OHMM 630331 O0 000 O0 0 1 I 1 4 68 0000000000 IMPH DTE OHMM 630331 O0 000 O0 0 I I I 4 68 0000000000 SP DTE MV 630331 O0 000 O0 0 1 i 1 4 68 0000000000 GR DTE GAPI 630331 O0 000 O0 0 1 I 1 4 68 0000000000 HRES DTE OHMM 630331 O0 000 O0 0 I i 1 4 68 0000000000 MTEM DTE DEGF 630331 O0 000 O0 0 i I I 4 68 0000000000 TENS DTE LB 630331 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DTE LB 630331 O0 000 O0 0 1 1 1 4 68 0000000000 DT DAS US/F 630331 O0 000 O0 0 1 1 1 4 68 0000000000 DTSH DAS US/F 630331 O0 000 O0 0 I 1 1 4 68 0000000000 SeRA DAS 630331 O0 000 O0 0 I 1 1 4 68 0000000000 GR DAS GAPI 630331 O0 000 O0 0 I 1 1 4 68 0000000000 CALl DAS IN 630331 O0 000 O0 0 i i 1 4 68 0000000000 RHOB SDN G/C3 630331 O0 000 O0 0 I I 1 4 68 0000000000 DRHO SDN G/C3 630331 O0 000 O0 0 1 I 1 4 68 0000000000 PEF SDN BN/E 630331 O0 000 O0 0 I 1 1 4 68 0000000000 CALl SDN IN 630331 O0 000 O0 0 1 I 1 4 68 0000000000 GR SDN GAPI 630331 O0 000 O0 0 1 1 1 4 68 0000000000 MRES SDN OHMM 630331 O0 000 O0 0 1 1 1 4 68 0000000000 MTEM SDN DEGF 630331 O0 000 O0 0 I 1 1 4 68 0000000000 TENS SDN LB 630331 O0 000 O0 0 1 1 1 4 68 0000000000 TEND SDN LB 630331 O0 000 O0 0 i 1 1 4 68 0000000000 NPHI CNTG PU-S 630331 O0 000 O0 0 1 I I 4 68 0000000000 ENPH CNTG PU-S 630331 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 630331 O0 000 O0 0 i 1 1 4 68 0000000000 NRAT CNTG 630331 O0 000 O0 0 I 1 1 4 68 0000000000 ENRA CNTG 630331 O0 000 O0 0 I 1 1 4 68 0000000000 CFTC CNTG CPS 630331 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 630331 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 630331 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 630331 O0 000 O0 0 1 1 1 4 68 0000000000 GR CNTG GAPI 630331 O0 000 O0 0 1 1 1 4 68 0000000000 C13 DIP IN 630331 O0 000 O0 0 1 1 1 4 68 0000000000 C24 DIP IN 630331 O0 000 O0 0 I I 1 4 68 0000000000 DEV DIP DEG 630331 O0 000 O0 0 1 1 1 4 68 0000000000 AZ DIP DEG 630331 O0 000 O0 0 I 1 1 4 68 0000000000 RB1 DIP DEG 630331 O0 000 O0 0 i 1 1 4 68 0000000000 GR DIP GAPI 630331 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 PAGE: 13 DEPT. 12320.000 IDPH.DTE 7.461 HRES.DTE 0.096 DT.DAS -999.250 CAL1.DAS -999.250 CAL1.SDN -999.250 TENS.SDN -999.250 CRAT.CNTG -999.250 CNTC.CNTG -999.250 C13.DIP 5.728 RB1.DIP 113.709 SFL.DTE IMPH.DTE MTEM.DTE DTSH.DAS RHOB.SDN GR.SDN TEND.SDN NRAT.CNTG CFEC.CNTG C24.DIP GR.DIP DEPT. 12000.000 SFL.DTE IDPH.DTE 20.790 IMPH.DTE MRES.DTE 0.095 MTEM.DTE DT.DAS 55.678 DTSH.DAS CAL1.DAS -999.250 RHOB.SDN CAL1.SDN 6.142 GR.SDN TENS.SDN 4293.625 TEND.SDN CRAT.CNTG 1.134 NRAT.¢NTG CNTC.CNTG 7627.446 CFEC.CNTG C13.DIP 6.204 C24.DIP RB1.DIP 179.272 GR.DIP DEPT. 11500.000 SFL.DTE IDPH.DTE 9.492 IMPH.DTE HRES.DTE 0.095 MTEM.DTE DT.DAS 77.121 DTSH.DAS CAL1.DAS -999.250 RHOB.SDN CAL1.SDN 6.343 GR.SDN TENS.SDN 4235.000 TEND.SDN CRAT.CNTG 2.282 NRAT.CNTG CNTC.¢NTG 3426.174 CFEC.CNTG C13.DIP 6.760 C24.DIP RB1.DIP 103.087 GR.DIP DEPT. 11000.000 SFL.DTE IDPH.DTE 5.418 IMPH.DTE HRES.DTE 0.102 MTEM.DTE DT.DAS 82.690 DTSH.DAS £AL1.DAS -999.250 RHOB.SDN CAL1.SDN 9.955 GR.SDN TENS.SDN 4035.000 TEND.SDN CRAT.CNTG 2.665 NRAT.CNTG CNTC.CNTG 2450.165 CFEC.CNTG C13.DIP 9.912 C24.DIP RB1.DIP 45.134 GR.DIP DEPT. 10500.000 IDPH.DTE 2.449 MRES.DTE 0.724 DT.DAS 93.633 CAL1.DAS 9.660 CAL1.SDN -999.250 TENS.SDN -999.250 SFL.DTE IMPH.DTE MTEM.DTE DTSH.DAS RHOB.SDN GR.SDN TEND.SDN 11.412 4.686 175.768 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 15.617 -999.250 201.744 26.304 174.532 106.523 2.698 51.240 989.813 1.140 3751.150 6.178 54.154 10.834 8.178 170.873 141.793 2.508 85.820 984.977 2.258 934.842 6.677 90.276 5.423 5.373 165.104 153.391 2.392 44.482 997.305 2.783 506.632 8.049 41.250 2.600 2.483 151.751 183.971 -999.250 40.826 -999.250 ILD.DTE SP.DTE TENS.DTE SCRA.DAS DRHO.SDN HRES.SDN NPHI.CNTG ENRA.CNTG CNEC.CNTG DEV.DIP ILD.DTE SP.DTE TENS.DTE SCRA.DAS DRltO.SDN HRES.SDN NPHI.CNTG ENRA.CNTG CNEC.CNTG DEV.DIP ILD.DTE SP.DTE TENS.DTE SCRA.DAS DRHO.SDN MRES.SDN NPHI.¢NTG ENRA.CNTG CNEC.CNTG DEV.DIP ILD.DTE SP.DTE TENS.DTE SCRA.DAS DRHO.SDN MRES.SDN NPHI.CNTG ENRA.CNTG CNEC.CNTG DEV.DIP ILD.DTE SP.DTE TENS.DTE SCRA.DAS DRHO.SDN MRES.SDN NPHI.CNTG 7.314 0.875 4385.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.547 18.264 -7.500 4295.000 1.892 -0.007 0.095 8.284 1.544 5792.016 3.775 9.052 -25.125 4235.000 1.773 0.009 0.095 25.253 3.385 3164.067 2.178 5.318 -37.313 4035.000 1.910 0.000 0.102 27.095 4.825 2444.319 2.015 2.404 18.625 3790.000 1.965 -999.250 -999.250 47.125 ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM. SDN ENPH.CNTG CFTC. CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFTC.CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.¢NTG CFT¢.CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFTC.CNTG GR.CNI'G AZ.DIP ILH.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG 3.908 -999.250 1078.355 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 133.006 26.882 51.240 989.524 52.563 4.294 174.532 5.889 6637.367 51.240 134.570 7.646 85.820 984.977 88.422 4.850 170.873 19.652 1477.981 85.820 111.118 5.317 44.482 1000.590 43.592 4.760 165.019 30.272 936.259 44.482 88.175 2.497 56.082 1100.798 56.082 -999.250 -999.250 43.469 LIS Tape Verification Listing Schlumberger Alaska Computing Center CRAT.CNTG 3.572 NRAT.CNTG CNTC.CNTG 1566.906 CFEC.CNTG Cl3.DIP 9.262 C24.DIP RB1.DIP 252.877 GR.DIP DEPT. 10000.000 SFL.DTE IDPH.DTE 2.545 IMPH.DTE MRES.DTE 0.768 MTEH.DTE DT.DAS 89.480 DTSH.DAS CAL1.DAS 8.803 RHOB.SDN CAL1.SDN 8.890 GR.SDN TENS.SDN 3515.000 TEND.SDN CRAT.CNTG 2.747 NRAT.CNTG CNTC.CNTG 3132.702 CFEC.CNTG C13.DIP 9.157 C24.DIP RB1.DIP 61.626 GR.DIP DEPT. 9500.000 IDPH.DTE 4.161 MRES.DTE 0.787 DT.DAS 92.078 CAL1.DAS 9.437 CAL1.SDN 9.693 TENS.SDN 3474.766 CRAT.CNTG 3.008 CNTC.CNTG 2679.199 C13.DIP 9.335 RB1.DIP 259.973 SFL.DTE IMPH.DTE MTEM.DTE DTSH.DAS RHOB.SDN GR.SDN TEND.SDN NRAT.CNTG CFEC.CNTG C24.DIP GR.DIP DEPT. 9000.000 SFL IDPH.DTE 4.117 IMPH MRES.DTE 0.797 MTEM DT.DAS 84.141 DTSH CAL1.DAS 9.147 RHOB CAL1.SDN 8.889 GR TENS.SDN 3370.000 TEND CRAT.CNTG 2.889 NRAT CNTC.CNTG 3371.000 CFEC C13.DIP 8.899 C24 RB1.DIP 232.215 GR .DTE .DTE .DTE .DAS .SDN .SDN .SDN .CNTG .¢NTG .DIP .DIP DEPT. 8500.000 IDPH.DTE 7.508 MRES.DTE 0.811 DT.DAS 81.164 CAL1.DAS 10.295 CAL1.SDN 9.530 TENS.SDN 3142.563 CRAT.CNTG 2.317 CNTC.CNTG 3879.452 C13.DIP 8.528 RB1.DIP 28.291 SFL.DTE IMPH.DTE MTEM.DTE DTSH.DAS RHOB.SDN GR.SDN TEND.SDN NRAT.CNTG CFEC.CNTG C24.DIP GR.DIP 8-JAN-1996 09:04 3.703 ENRA.CNTG 5.797 425.957 CNEC.CNTG 2469.063 8.891 DEV.DIP 1.752 55.512 2.354 ILD.DTE 2.476 2.462 SP.DTE -28.250 145.982 TENS.DTE 3780.000 179.164 SCRA.DAS 2.002 2.481 DRHO.SDN 0.007 57.633 MRES.SDN 0.670 1033.884 NPHI.CNTG 29.787 3.000 ENRA.CNTG 4.252 812.564 CNEC.CNTG 3455.253 8.942 DEV.DIP 1.882 47.993 4.071 ILD.DTE 4.090 4.315 SP.DTE -150.500 140.351 TENS.DTE 3610.000 221.063 SCRA.DAS 2.400 2.416 DRHO.SDN 0.047 49.146 MRES.SDN 0.694 1057.063 NPHI.CNTG 32.582 3.084 ENRA.CNTG 4.749 647.546 CNEC.CNTG 3075.276 8.723 DEV.DIP 1.529 42.125 4.299 ILD.DTE 4.003 4.083 SP.DTE -142.125 137.988 TENS.DTE 3620.000 148.000 SCRA.DAS 1.759 2.472 DRHO.SDN -0.010 62.561 MRES.SDN 0.713 1082.891 NPltI.CNTG 31.793 3.353 ENRA.CNTG 4.145 889.000 CNEC.¢NTG 3679.500 8.810 DEV.DIP 2.159 60.813 7.698 ILD.DTE 7.291 7.481 SP.DTE -144.000 135.233 TENS.DTE 3420.000 157.984 SCRA.DAS 1.946 2.486 DRHO.SDN 0.001 44.419 HRES.SDN 0.735 1109.313 NPHI.CNTG 22.490 2.383 ENRA.CNTG 3.772 948.312 CNEC.CNTG 3576.861 9.998 DEV.DIP 2.125 38.301 CFTC. CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFTC.CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFTC.CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPIt. CNTG CFTC.CNTG GR.CNTG AZ.DIP ILH.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFTC.CNTG GR.CNTG AZ.DIP PAGE: 14 463.883 40.826 94.764 2.537 50.477 1113.002 50.477 3.779 156.202 25.376 1151.516 57.633 99.572 4.193 39.718 1100.599 39.718 4.842 151.471 29.637 894.759 49.146 106.196 4.059 61.021 1078.620 61.021 4.530 147.394 24.365 1213.500 62.561 117.468 7.705 39.660 1118.590 39.660 4.426 143.988 20.891 1765.856 44.419 110.072 LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 8000.000 SFL.DTE IDPH.DTE 4.919 IMPH.DTE MRES.DTE 0.827 MTEM.DTE DT.DAS 93.563 DTSH.DAS CAL1.DAS 11.095 RHOB.SDN CAL1.SDN 11.123 GR.SDN TENS.SDN 3020.000 TEND.SDN CRAT.CNTG 2.643 NRAT.CNTG CNT¢.CNTG 3049.497 CFEC.CNTG C13.DIP 9.412 C24.DIP RB1.DIP 10.076 GR.DIP DEPT. 7500.000 SFL.DTE IDPH.DTE 3.191 IMPH.DTE MRES.DTE 0.853 MTEM.DTE DT.DAS 90.086 DTSH.DAS CAL1.DAS 13.211 RHOB.SDN CAL1.SDN 13.184 GR.SDN TENS.SDN 2952.500 TEND.SDN CRAT.CNTG 2.926 NRAT.CNTG CNT¢.CNTG 2716.663 CFEC.CNTG C13.DIP 10.301 C24.DIP RB1.DIP 6.091 GR.DIP DEPT. 7000.000 SFL.DTE IDPH.DTE 7.055 IMPH.DTE MRES.DTE 0.870 MTEM.DTE DT, DAS 100.271 DTSH.DAS CAL1.DAS 11.449 RHOB.SDN CAL1.SDN 12.068 GR.SDN TENS.SDN 2795.000 TEND.SDN CRAT.CNTG 2.619 NRAT.¢NTG CNTC.CNTG 3058.313 CFEC.¢NTG C13.DIP 10.139 C24.DIP RB1.DIP 169.293 GR.DIP DEPT. 6500.000 SFL.DTE IDPH.DTE 5.876 IMPH.DTE MRES.DTE 0.892 MTEM.DTE DT.DAS 95.633 DTSH.DAS CAL1.DAS 9.738 RHOB.SDN CAL1.SDN 9.928 GR.SDN TENS.SDN 2635.000 TEND.SDN CRAT.¢NTG 3.443 NRAT.¢NTG CNT¢.CNTG 2409.672 CFEC.CNTG C13.DIP 8.722 C24.DIP RB1.DIP 193.239 GR.DIP DEPT. 6000.000 SFL.DTE IDPH.DTE 6.795 IMPH.DTE HRES.DTE 0.934 MTEM.DTE DT.DAS 93.938 DTSH.DAS CAL1.DAS 11.774 RHOB.SDN CAL1.SDN 11.508 GR.SDN TENS.SDN 2525.000 TEND.SDN 8-JAN-1996 09:04 4.546 ILD.DTE 4.873 4.891 SP.DTE -148.375 131.601 TENS.DTE 3380.000 189.504 SCRA.DAS 2.025 2.368 DRHO.SDN 0.010 37.274 MRES.SDN 0.756 1109.250 NPHI.CNTG 25.684 2.770 ENRA.CNTG 4.255 718.968 CNEC.CNTG 3059.117 11.238 DEV.DIP 2.589 30.518 2.597 ILD.DTE 3.218 3.189 SP.DTE -146.625 128.308 TENS.DTE 3300.000 201.848 SCRA.DAS 2.241 2.433 DRHO.SDN 0.036 35.390 MRES.SDN 0.776 1136.938 NPHI.CNTG 29.400 2.982 ENRA.CNTG 5.026 557.933 CNEC.CNTG 2804.405 12.765 DEV.DIP 3.080 32.568 6.397 ILD.DTE 6.986 7.010 SP.DTE -153.063 125.085 TENS.DTE 3040.000 172.980 SCRA.DAS 1.725 2.405 DRHO.SDN 0.020 33.830 MRES.SDN 0.801 994.949 NPHI.CNTG 25.298 2.764 ENRA.CNTG 4.582 696.953 CNEC.CNTG 3193.063 11.528 DEV.DIP 2.426 28.684 5.124 ILD.DTE 5.825 5.744 SP.DTE -152.188 121.989 TENS.DTE 2920.000 190.820 SCRA.DAS 1.995 2.425 DRHO.SDN 0.047 53.941 MRES.SDN 0.827 1016.734 NPHI.CNTG 39.705 3.843 ENRA.CNTG 5.223 551.906 CNEC.CNTG 2882.438 9.770 DEV.DIP 1.803 46.328 5.701 ILD.DTE 6.690 6.318 SP.DTE -153.563 117.915 TENS.DTE 2785.000 178.078 SCRA.DAS 1.895 2.455 DRHO.SDN 0.044 49.026 MRES.SDN 0.852 1040.917 NPHI.CNTG 32.677 ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFT¢.CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFTC.CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFTC.CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFTC.CNTG GR.CNTG AZ.DIP ! LM. DTE GR. DTE TEND.DTE GR.DAS PEF.SDN MTEM. SDN ENPH.CNTG PAGE: 15 4.838 32.972 1116.999 32.972 3.351 140.628 24.621 1190.884 37.274 105.353 3.165 33.675 1119.979 33.675 3.394 137.326 31.572 955.036 35.390 105.218 6.894 29.602 1090.067 29.602 3.363 133.821 27.591 1142.125 33.830 120.475 5.688 47.844 1097.128 47.844 7.223 130.300 34.209 738.219 53.941 113.411 6.351 49.117 1088.567 49.117 4.265 126.673 31.558 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN- 1996 09: 04 PAGE: 16 CRAT.CNTG 3.119 NRAT.CNTG CNTC.CNTG 2488.906 CFE¢.CNTG C13.DIP 11.855 C24.DIP RB1.DIP 103.401 GR.DIP DEPT. 5500.000 SFL.DTE IDPH.DTE 9.064 IMPH.DTE MRES.DTE 0.959 MTEM.DTE DT.DAS 120.471 DTSH.DAS CAL1.DAS 10.619 RHOB.SDN CAL1.SDN 11.138 GR.SDN TENS.SDN 2365.000 TEND.SDN CRAT.¢NTG 4.353 NRAT.CNTG CNTC.CNTG 1832.186 CFEC.CNTG ¢13.DIP 10.412 C24.DIP RB1.DIP 65.829 GR.DIP DEPT. 5000.000 SFL.DTE IDPH.DTE 15.077 IMPH.DTE MRES.DTE 3.563 MTEM.DTE DT.DAS 92.471 DTSH.DAS CAL1.DAS 12.841 RHOB.SDN CAL1.SDN 13.189 GR.SDN TENS.SDN 2545.000 TEND.SDN CRAT.¢NTG 2.810 NRAT.¢NTG CNTC.CNTG 2219.875 CFEC.CNTG ¢13.DIP 12.377 C24.DIP RB1.DIP 346.066 GR.DIP DEPT. 4500.000 SFL.DTE IDPH.DTE 7.512 IMPH.DTE MRES.DTE 3.540 MTEH.DTE DT.DAS 124.609 DTSH.DAS CAL1.DAS 13.296 RHOB.SDN CAL1.SDN 14.157 GR.SDN TENS.SDN 2488.984 TEND.SDN CRAT.CNTG 2.987 NRAT.CNTG CNT¢.CNTG 2314.188 CFEC.CNTG ¢13.DIP 14.181 C24.DIP RB1.DIP 305.028 GR.DIP UEPT. 4000.000 SFL.DTE IDPH.DTE 6.719 IMPH.DTE HRES.DTE 3.556 MTEH.DTE DT.DAS 124.419 DTSH.DAS CAL1.DAS 12.423 RHOB.SDN CAL1.SDN 12.566 GR.SDN TENS.SDN 2260.000 TEND.SDN CRAT.CNTG 3.351 NRAT.CNTG CNTC.CNTG 2218.962 CFEC.CNTG Cl3.DIP 12.219 C24.DIP RB1.DIP 4.794 GR.DIP 3.198 ENRA.CNTG 5.001 603.016 CNEC.CNTG 3015.688 8.212 DEV.DIP 0.746 45.561 10.507 ILD.DTE 8.773 9.653 SP.DTE -178.063 114.415 TENS.DTE 2645.000 266.298 SCRA.DAS 2.210 1.907 DRHO.SDN -0.013 49.876 MRES.SDN 0.877 1005.010 NPHI.CNTG 55.255 4.796 ENRA.CNTG 6.649 369.639 CNEC.CNTG 2457.792 9.316 DEV.DIP 0.482 46.548 24.597 ILD.DTE 14.004 19.773 SP.DTE -41.063 106.096 TENS.DTE 2750.000 179.234 SCRA.DAS 1.938 2.466 DRHO.SDN 0.091 44.252 MRES.SDN 3.077 1191.331 NPHI.CNTG 27.432 2.823 ENRA.CNTG 5.076 441.688 CNE¢.CNTG 2238.313 12.615 DEV.DIP 0.494 41.034 8.223 ILD.DTE 7.416 7.269 SP.DTE -71.500 104.872 TENS.DTE 2460.000 252.880 SCRA.DAS 2.029 2.288 DRHO.SDN 0.006 43.923 MRES.SDN 3.041 1271.219 NPHI.¢NTG 29.643 3.184 ENRA.CNTG 5.130 459.773 CNEC.CNTG 2358.563 14.112 DEV.DIP 0.365 42.473 8.110 ILD.DTE 6.627 7.432 SP.DTE -59.563 103.578 TENS.DTE 2360.000 236.779 SCRA.DAS 1.903 2.197 DRHO.SDN 0.000 52.117 HRES.SDN 3.060 1221.508 NPHI.CNTG 36.286 3.451 ENRA.CNTG 5.268 461.195 CNEC.CNTG 2429.721 12.090 DEV.DIP 0.619 50.941 CFTC.CNTG GR.¢NTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.¢NTG CFTC.CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFTC.CNTG GR.¢NTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFTC.¢NTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN HTEH.SDN ENPH.CNTG CFTC.CNTG GR.CNTG AZ.DIP 839.625 49.026 111.509 8.852 48.130 1079.892 48.130 4.303 123.363 50.335 456.325 49.876 154.090 16.305 39.458 1392.167 39.458 2.881 106.719 31.958 808.250 44.252 43.635 7.259 45.531 1387.581 45.531 2.559 106.135 32.249 757.406 43.923 202.919 7.264 50.867 1400.618 50.867 2.937 105.044 34.001 676.905 52.117 281.265 LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 3500.000 SFL.DTE 10. IDPH.DTE 9.026 IMPH.DTE 9. HRES.DTE 3.671 MTEM.DTE 100. DT.DAS 118.582 DTSH.DAS 269. CAL1.DAS 12.245 RHOB.SDN 2. CALi.SDN 12.355 GR.SDN 44. TENS.SDN 2087.078 TEND.SDN 1201. CRAT.CNTG 3.745 NRAT.CNTG 3. CNTC.CNTG 2055.094 CFEC.CNTG 398. C13.DIP 12.048 C24.DIP 11. RB1.DIP 5.991 GR.DiP 40. DEPT. 3000.000 IDPH.DTE 15.451 HRES.DTE 3.761 DT.DAS 125.389 CAL1.DAS 12.134 CAL1.SDN 12.300 TENS.SDN 1929.156 CRAT.CNTG 3.286 CNT¢.¢NTG 2283.109 C13.DIP 12.046 RB1.DIP 73.995 SFL.DTE IMPH.DTE MTEM.DTE DTSH.DAS RHOB.SDN GR.SDN TEND.SDN NRAT.¢NTG CFEC.¢NTG C24.DIP GR.DIP 18. 16. 97. 296. 2. 47. 1189. 3. 423. 12. 44. DEPT. 2500.000 SFL.DTE 14. IDPH.DTE 14.902 IHPH.DTE 15. MRES.DTE 3.883 MTEM.DTE 94. DT.DAS 129.681 DTSH.DAS 312. CAL1.DAS 12.275 RHOB.SDN 2. CAL1.SDN 12.316 GR.SDN 38. TENS.SDN 1940.000 TEND.SDN 1225. CRAT.CNTG 3.584 NRAT.¢NTG 3. CNT¢.CNTG 2052.346 CFEC.CNTG 387. C13.DIP 11.877 C24.DIP 11. RB1.DIP 150.241 GR.DIP 40. SFL.DTE IMPH.DTE MTEM.DTE DTSH.DAS RHOB.SDN GR.SDN TEND.SDN NRAT.CNTG CFEC.CNTG ¢24.DIP GR.DIP DEPT. 2000.000 IDPH.DTE 21.072 HRES.DTE 4.059 DT.DAS 134.896 CAL1.DAS 12.168 CAL1.SDN 12.325 TENS.SDN 1675.000 CRAT.£NTG 3.777 CNTC.CNTG 2096.020 C13.DIP 12.031 RB1.DIP 117.907 SFL.DTE IMPH.DTE MTEM.DTE DTSH.DAS RHOB.SDN GR.SDN TEND.SDN 8-JAN-1996 09:04 DEPT. 1500.000 IDPH.DTE 20.361 HRES.DTE 4.290 DT,DAS 139.806 CAL1.DAS 12.632 CAL1.SDN 12.456 TENS.SDN 1590.000 20. 21. 90. 356. 2. 42. 1190. 4. 402. 11. 39. 20. 20. 86. 370. 2. 63. 1182. 469 ILD.DTE 8.711 668 SP.DTE -86.250 631 TENS.DTE 2280.000 078 SCRA.DAS 2.269 134 DRHO.SDN 0.004 411 MRES.SDN 3.119 797 NPHI.CNTG 43.601 994 ENRA.CNTG 5.771 246 CNEC.CNTG 2298.211 977 DEV.DIP 0.682 597 291 ILD.DTE 14.860 745 SP.DTE -100.250 729 TENS.DTE 2120.000 246 SCRA.DAS 2.363 173 DRHO.SDN -0.001 022 MRES.SDN 3.201 609 NPHI.CNTG 35.224 438 ENRA.CNTG 5.688 477 CNEC.¢NTG 2408.641 007 DEV.DIP 0.809 82O 883 ILD.DTE 14.185 676 SP.DTE -96.000 623 TENS.DTE 1980.000 025 SCRA.DAS 2.406 099 DRHO.SDN 0.002 284 MRES.SDN 3.311 711 NPHI.¢NTG 40.664 731 ENRA.CNTG 5.795 743 CNEC.CNTG 2246.937 883 DEV.DIP 0.598 O06 263 ILD.DTE 20.068 529 SP.DTE -97.875 870 TENS.DTE 1900.000 951 SCRA.DAS 2.646 088 DRHO.SDN -0.004 377 MRES.SDN 3.385 894 NPHI.CNTG 44.202 003 ENRA.CNTG 5.789 213 CNEC.CNTG 2328.234 960 DEr. DIP 0.338 685 162 ILD.DTE 19.494 115 SP.DTE -94.313 383 TENS.DTE 1720.000 324 SCRA.DAS 2.649 214 DRHO.SDN 0.007 001 MRES.SDN 3.533 671 NPHI.CNTG 45.431 I LM. DTE GR.DTE TEND. DTE GR.DAS PEF.SDN MTEM. SDN ENPH.CNTG C FTC. CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFTC.CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFTC.CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEH.SDN ENPH.CNTG CFT¢.CNTG GR.CNTG AZ.DIP ILM DTE GR DTE TEND DTE GR DAS PEF SDN MTEM SDN ENPH CNTG PAGE: 17 9.528 45.977 1414.658 45.977 2.842 102.807 39.442 583.535 44.411 287.248 16.010 45.006 1415.577 45.006 3.034 100.962 38.536 695.359 47.022 320.861 14.885 41.725 1407.050 41.725 3.336 98.868 39.718 582.80O 38.284 351.417 20.499 40.048 1435.882 40.048 3.120 95.836 39.652 573.156 42.377 243.921 19.373 59.998 1414.181 59.998 3.265 92.714 42.172 LIS Tape Verification Listing Schlumberger Alaska Computing Center CRAT.CNTG 3.847 NRAT.CNTG CNlC.CNTG 1921.169 CFE¢.¢NTG C13.DIP 12.165 C24.DIP RB1.DIP 102.413 GR.DIP DEPT. 1000.000 SFL.DTE IDPH.DTE 26.095 IMPH.DTE MRES.DIE 4.486 MTEH.DTE DT.DAS 145.824 DTSH.DAS CAL1.DAS ].2.333 RHOB.SDN CAL1.SDN 12.523 GR.SDN TENS.SDN 1440.000 TEND.SDN CRAT.CNTG 3.841 NRAT.CNTG CNTC.CNTG 2012.813 CFEC.CNTG C13.DIP 12.213 C24.DIP RB1.DIP 298.417 GR.DIP DEPT. 512.000 SFL.DTE IDPH.DTE -999.250 IMPH.DTE MRES.DTE 4.658 MTEM.DTE DT.DAS -999.250 DTSH.DAS CAL1.DAS -999.250 RHOB.SDN CAL1.SDN -999.250 GR.SDN TENS.SDN -999.250 TEND.SDN CRAT.CNTG 4.740 NRAT.CNTG CNTC.CNTG 1216.698 CFEC.CNTG ¢13.DIP -999.250 C24.DIP RB1.DIP -999.250 GR.DIP 8-JAN-1996 09:04 4.255 ENRA.CNTG 6.013 391.540 CNEC.CNTG 2354.238 12.203 DEV.DIP 0.353 53.595 23.507 ILD.DTE 24.887 24.899 SP.DTE -114.688 83.8]9 TENS.DTE 1640.000 444.515 SCRA.DAS 3.048 2.172 DRHO.SDN -0.003 42.618 MRES.SDN 3.661 1191.080 NPHI.CNTG 45.288 4.081 ENRA.CNTG 5.969 390.984 CNEC.CNTG 2333.410 12.126 DEV.DIP 0.583 44.589 -999.250 ILD.DTE -999.250 -999.250 SP.DTE -999.250 82.303 TENS.DTE 1520.000 -999.250 SCRA.DAS -999.250 -999.250 DRHO.SDN -999.250 33.705 MRES.SDN -999.250 -999.250 NPHI.CNTG 61.509 4.581 ENRA.CNTG 7.823 271.591 CNEC.CNTG 2124.772 -999.250 DEV.DIP -999.250 37.261 CFTC.CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEM.SDN ENPH.CNTG CFTC.CNTG GR.CNTG AZ.DIP ILM.DTE GR.DTE TEND.DTE GR.DAS PEF.SDN MTEH.SDN ENPH.CNTG CFTC.CNTG GR.¢NTG AZ.DIP PAGE: 18 515.595 63.001 213.891 24.186 41.861 1410.448 41.861 2.994 90.700 41.648 524.972 42.618 214.865 -999.250 36.378 1433.201 36.378 -999.250 -999.250 66.573 268.508 33.705 -999.250 ** END OF DATA ** **** FILE TRAILER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 PAGE: FILE HEADER FILE NUMBER 2 RAW OPEN HOLE MAIN PASS File containing merged data from 3 logging runs. Data is clipped and depth corrected. RUN NUMBER: 4 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE UTE LDT CNTG DSI $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: ID DRILLER (Fl): TD LOGGER(FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): START DEPTH STOP DEPTH 12320.0 528.0 12295.0 512.0 12273.0 512.0 12295.5 514.0 TOOL STRING (TOP TO BOTTOM) coo DSI SONIC LDT DENSITY CNTG NEUT POROSITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MiJD AT MEASURED TEMPERATURE (MT) : MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): 09-DEC-95 7C0-427 83O 1738 12350.0 12332.0 512.0 12320.0 1800.0 9-DEC-95 9-DEC-95 TOOL NUMBER 6.000 10620.0 KCL/POLYMER 11.00 43.0 9.1 176.0 0.250 70.0 0.340 70.0 19 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 MUD CAKE AT (MT): 0.500 MUD CAKE AT(BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): BOTH MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED MERGED DATA FROM 3 LOGGING RUNS. ALL CHANNELS USE SCHLUMBER NEUMONICS. $ LIS FORMAT DATA 70.0 PAGE: 20 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA, INC. Company Name FN WILDCAT Field Name WN BUFFLEHEAD #1 Well Name APIN 501332046600 API Serial Number FL 1319 FEL & 2337 FSL Field Location SECT 3 Section TOWN 8N Township RANG 9W Range COUN KENAI County STAT ALASKA State or Province NATI USA Nation WITN CAMPAIGN Witness Name SON 630331 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 302.85 Above Permanent Datum EKB FT 302.85 Elevation of Kelly Bushing EDF FT 301.85 Elevation of Derrick Floor ECL FT 277. Elevation of Ground Level TDD FT 12350. Total Depth - Driller TDL FT 12332. Total Depth - Logger BLI FT 12320. Bottom Log Interval TLI FT 512. Top Log Interval DFT KCL/POLYMER Drilling Fluid Type DFD G/C3 11. Drilling Fluid Density DFPH 9.1 Drilling Fluid Ph DFV S 43. Drilling Fluid Viscosity DFL F3 5. Drilling Fluid Loss RMS OHMM 0.25 Resistivity of Mud Sample MST DEGF 70. Mud Sample Temperature RMFS OHHM 0.34 Resistivity of Mud Filtrate S LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 PAGE: 21 TUNI VALU DEFI MFST DEGF 70. -- Mud Filtrate Sample Temperatu RMCS OHMM 0.5 Resistivity of Mud Cake Sampl MCST DEGF 70. Mud Cake Sample Temperature T£S 08:30 9-DEC-95 Time Circulation Stopped TLAB 17:38 9-DEC-95 Time Logger at Bottom BHT DEGF 176. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT CIDP IDPH CIMP IMPH CILD ILD CILM ILH IDQF IHQF IIRD IIXD IIRM IIXM SFLU SP GR TENS HTEN MRES MTEM DPttI RHOB DRHO PEF QLS QSS LS LU LL LITH SS1 SS2 LSHV SSHV SIRH LSRH LURH GR Depth INDUCTION DEEP PHASOR CONDUCTIVITY INDUCTION DEEP PHASOR RESISTIVITY INDUCTION MEDIUM PHASOR CONDUCTIVITY INDUCTION MEDIUM PHASOR RESISTIVITY Conductivity IL DeeP Standard Processed Deep Induction Standard Processed Resistivity Conductivity IL Medium Standard Processed Medium Induction Standard Processed Resistivity Induction Deep Quality Factor Induction Medium Quality Factor Deep Induction Real Intermediate Conductivity Deep Induction Quad Intermediate Conductivity Medium Induction Real Intermediate Conductivity Medium Induction Quad Intermediate Conductivity SFL Resistivity Unaveraged Spontaneous Potential Gamma Ray Tension Head Tension HUD Resistivity Mud Temperature Density Porosity Bulk Density Delta RHO PhotoElectric Factor Quality control of long spacing 'for LDT Quality control on short spacing for LDT Long Spacing Computed Count Rate (LL+LU/2) Long Upper 1-2 Window Count Rate(LUi+LU2) Long Lower Window Count Rate Litholog Window Count Rate Short Spacing i Window Count Rate Short Spacing 2 Window Count Rate Long Spacing High Voltage Short SAacing H~gh Voltage Short Spacing i Density Long Spacing Bulk Density Long Upper Bulk Density Gamma Ray LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 DEFI CALI Caliper TENS Tension HTEN Head Tension fiRES MUD Resistivity /-ITEM Mud Temperature ENPH Epithermal Neutron Porosity ENRA Epithermal Neutron Ratio Calibrated CFEC Corrected Far Epithermal Counts CNEC Corrected Near Epithermal Counts RCEF Raw Corrected Epithermal Far Counts RCEN Raw Corrected Epithermal Near Counts NPHI Neutron Porosity TNPH Thermal Neutron Porosity TNRA Thermal Neutron Ratio Calibrated RTNR Raw Thermal Neutron Ratio NPOR Neutron Porosity from an Application Program RCNT RAW NEAR CNT COUNTS RCFT RAW FAR CNT COUNTS CNTC Corrected Near Thermal Counts CFTC Corrected Far Thermal Counts GR Gamma Ray TENS Tension HTEN Head Tension HRES MUD Resistivity MTEM Mud Temperature DT4P DELTA-T COMPRESSIONAL HF MONOPOLE COMPENSATED (P&S) DT2 DELTA-T SHEAR UPPER DIPOLE MODE COMPENSATED PR Poisson's Ratio RSHC RATIO SHEAR TO COMPRESSIONAL DELTA T HCAL Caliper GR Gamma Ray C1 Caliper 1 - 3 C2 Caliper 2 - 4 GR Gamma Ray ItAZI Hole Azimuth DEVI Hole Deviation P1AZ Pad 1 Azimuth PAGE: 22 DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 308 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN- 1996 09:04 PAGE: 23 6 73 7 65 8 68 0.5 9 65 FT 11 66 3 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 i ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE ~-- PROC~--- ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630331 O0 000 O0 0 2 1 1 4 68 --~~-- CIDP OTE MMHO 630331 O0 000 O0 0 2 1 1 4 68 0000000000 IDPH UTE OHMM 630331 O0 000 O0 0 2 1 1 4 68 0000000000 CIMP OTE MMHO 630331 O0 000 O0 0 2 I 1 4 68 0000000000 IMPH UTE OHMM 630331 O0 000 O0 0 2 1 1 4 68 0000000000 CILO OTE MMHO 630331 O0 000 O0 0 2 1 ! 4 68 0000000000 ILD UTE OHMM 630331 O0 000 O0 0 2 i i 4 68 0000000000 CILM UTE MMHO 630331 O0 000 O0 0 2 i 1 4 68 0000000000 ILM UTE OHMM 630331 O0 000 O0 0 2 1 1 4 68 0000000000 IDQF UTE 630331 O0 000 O0 0 2 1 1 4 68 0000000000 IMQF UTE 630331 O0 000 O0 0 2 1 1 4 68 0000000000 IIRD UTE MMHO 630331 O0 000 O0 0 2 1 1 4 68 0000000000 IIXD UTE MMHO 630331 O0 000 O0 0 2 1 1 4 68 0000000000 IIRM UTE MMHO 630331 O0 000 O0 0 2 1 1 4 68 0000000000 IIXM UTE MMHO 630331 O0 000 O0 0 2 1 1 4 68 0000000000 SFLU UTE OHMM 630331 O0 000 O0 0 2 1 1 4 68 0000000000 SP OTE MV 630331 O0 000 O0 0 2 1 1 4 68 0000000000 GR UTE GAPI 630331 O0 000 O0 0 2 1 1 4 68 0000000000 TENS UTE LB 630331 O0 000 O0 0 2 1 1 4 68 0000000000 HTEN UTE LB 630331 O0 000 O0 0 £ 1 1 4 68 0000000000 MRES UTE OHMM 630331 O0 000 O0 0 2 1 1 4 68 0000000000 MTEM UTE DEGF 630331 O0 000 O0 0 2 1 1 4 68 0000000000 DPHI LDT PO 630331 O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LDT G/C3 630331 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO LDT G/C3 630331 O0 000 O0 0 2 1 1 4 68 0000000000 PEF LDT 630331 O0 000 O0 0 2 1 1 4 68 0000000000 QLS LDT 630331 O0 000 O0 0 £ 1 1 4 68 0000000000 QSS LDT 630331 O0 000 O0 0 2 1 1 4 68 0000000000 LS LOT CPS 630331 O0 000 O0 0 2 1 1 4 68 0000000000 LU LDT CPS 630331 O0 000 O0 0 2 1 1 4 68 0000000000 LL LDT CPS 630331 O0 000 O0 0 2 ! 1 4 68 0000000000 LITH LDT CPS 630331 O0 000 O0 0 2 1 1 4 68 0000000000 SS1 LDT CPS 630331 O0 000 O0 0 2 1 1 4 68 0000000000 SS2 LDT CPS 630331 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 PAGE: 24 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS--- --T~Z~ ID ORDER # LOG TYPE ('_ASS MOD NUMB SAMP ELEM CODE (HEX) LSHV LDT V 630331 O0 000 O0 0 2 I 1 ~ ..... ~ .... GGSGGGGGGG-- SSHV LDT V 630331 O0 000 O0 0 2 1 1 4 68 0000000000 S1RH LDT G/C3 630331 O0 000 O0 0 2 LSRH LDT G/C3 630331 O0 000 O0 0 2 LURH LDT G/C3 630331 O0 000 O0 0 2 GR LDT GAPI 630331 O0 000 O0 0 2 CALI LDT IN 630331 O0 000 O0 0 2 TENS LDT LB 630331 O0 000 O0 0 2 HTEN LDT LB 630331 O0 000 O0 0 2 MRES LDT OHMM 630331 O0 000 O0 0 2 MTEH LDT DEGF 630331 O0 000 O0 0 2 ENPH CNT PU 630331 O0 000 O0 ENRA CNT 630331 O0 000 O0 CFEC CNT CPS 630331 O0 000 O0 CNEC CNT CPS 630331 O0 000 O0 RCEF CNT CPS 630331 O0 000 O0 RCEN CNT CPS 630331 O0 000 O0 NPHI CNT PU 630331 O0 000 O0 TNPH CNT PU 630331 O0 000 O0 TNRA CNT 630331 O0 000 O0 0 2 1 0 2 1 0 2 1 0 2 1 0 2 1 0 2 1 0 2 1 0 2 1 0 2 1 RTNR CNT 630331 O0 000 O0 0 2 NPOR CNT PU 630331 O0 000 O0 0 2 RCNT CNT CPS 630331 O0 000 O0 0 2 RCFT CNT CPS 630331 O0 000 O0 0 2 CNTC CNT CPS 630331 O0 000 O0 0 2 CFTC CNT CPS 630331 O0 000 O0 0 2 GR 'CNT GAPI 630331 O0 000 O0 0 2 TENS CNT LB 630331 O0 000 O0 0 2 HTEN CNT LB 630331 O0 000 O0 0 2 MRES CNT OHMM 630331 O0 000 O0 0 2 MTEM CNT DEGF 630331 O0 000 O0 0 2 DT4P DSI US/F 630331 O0 000 O0 0 2 DT2 DSI US/F 630331 O0 000 O0 0 2 PR DSI 630331 O0 000 O0 0 2 RSHC DSI 630331 O0 000 O0 MCAL DSI IN 630331 O0 000 O0 GR DSI GAPI 630331 O0 000 O0 C1 SHD IN 630331 O0 000 O0 C2 SHD IN 630331 O0 000 O0 GR SHD GAPI 630331 O0 000 O0 HAZI SHD DEG 630331 O0 000 O0 DEVI SHD DEG 630331 O0 000 O0 P1AZ SHD DEG 630331 O0 000 O0 1 1 1 1 1 1 1 1 1 1 1 1 1 1 0 2 1 0 2 1 0 2 1 0 2 1 0 2 1 0 2 1 0 2 1 0 2 1 0 2 i 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 i 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 i 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 i 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 i 4 68 0000000000 i 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 i 4 68 0000000000 i 4 68 0000000000 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumber§er Alaska Computing Center DEPT. 12320.000 CIDP.DTE IHPH.DTE 4.686 CILD.DTE ILM.DTE 3.908 IDQF.DTE IIXD.DTE 31.725 IIRM.DTE SP.DTE 0.875 GR.DTE MRES.DTE 0.096 MTEM.DTE DRHO.LDT -999.250 PEF.LDT LS.LDT -999.250 LU.LDT SS1.LDT -999.250 SS2.LDT S1RH.LDT -999.250 LSRH.LDT CALI.LDT -999.250 TENS.LDT MTEH.LDT -999.250 ENPH.CNT CNEC.CNT -999.250 RCEF.CNT TNPH.CNT -999.250 TNRA.CNT RCNT.CNT -999.250 RCFT.CNT GR.CNT -999.250 TENS.CNT HTEH.CNT -999.250 DT4P.DSI RSHC.DSI -999.250 MCAL.DSI C2.SHD 15.617 GR.SHD P1AZ.SHD 113.709 DEPT. IHPH.DTE ILM.DTE IIXD.DTE SP.DTE MRES.DTE DRHO.LDT LS.LDT SS1.LDT S1RH.LDT CALI.LDT MTEM. LDT CNEC.CNT TNPH CNT RCNT CNT GR CNT MTEM CNT RSHC DSI C2 SHD PiAZ SHD 12000.000 CIDP.DTE 26.304 CILD.DTE 26.882 IDQF.DTE 4.855 IIRM.DTE -7.500 GR.DTE 0.095 MTEM.DTE -0.007 PEF. LDT 208.750 LU.LDT 208.508 SS2.LDT 2.745 LSRH.LDT 6.142 TENS.LDT 174.532 ENPH.CNT 5792.016 RCEF.CNT 8.766 TNRA.CNT 7879.114 RCFT.CNT 51.240 TENS.CNT 174.532 DT4P.DSI 1.892 MCAL.DSI 6.178 GR.SHD 179.272 DEPT. IMPH.DTE ILM.DTE IIXD.DTE SP.DTE HRES.DTE DRHO.LDT LS.LDT SS1.LDT S1RH.LDT CALI.LDT MTEH.LDT CNEC.¢NT 11500.000 CIDP.DTE 8.178 CILD.DTE 7.646 IDQF.DTE 14.386 IIRM.DTE -25.125 GR.DTE 0.095 MTEM.DTE 0.009 PEF.LDT 289.000 LU.LDT 233.253 SS2.LDT 2.470 LSRH.LDT 6.343 TENS.LDT 170.873 ENPH.CNT 3164.067 RCEF.¢NT 8-JAN-1996 09:04 134.037 IDPH.DTE 136.720 ILD.DTE 0.000 IMQF.DTE 239.760 II×M.DTE -999.250 TENS.DTE 175.768 DPHI.LDT -999.250 QLS.LDT -999.250 LL.LDT -999.250 LSHV.LDT -999.250 LURH.LDT -999.250 HTEN.LDT -999.250 ENRA.CNT -999.250 RCEN.CNT -999.250 RTNR.CNT -999.250 CNTC.CNT -999.250 HTEN.CNT -999.250 DT2.DSI -999.250 GR.DSI -999.250 HAZI.SHD 48.100 IDPH.DTE 54.754 ILD.DTE 0.000 IMQF.DTE 35.372 IIXM.DTE 51.240 TENS.DTE 174.532 DPHI.LDT 4.294 QLS.LDT 212.469 LL. LDT 269.617 LSHV.LDT 2.715 LURH.LDT 4293.625 HTEN.LDT 5.889 ENRA.CNT 3544.333 RCEN.CNT 1.134 RTNR.CNT 6072.018 CNTC.CNT 4293.625 HTEN.CNT 55.678 DT2.DSI -999.250 GR.DSI 54.154 HAZI.SHD 105.347 IDPH.DTE 110.470 ILD.DTE 0.000 IMQF.DTE 123.571 IIXM.DTE 85.820 TENS.DTE 170.873 DPHI.LDT 4.850 QLS.LDT 287.126 LL.LDT 294.325 LSHV.LDT 2.507 LURH.LDT 4235.000 HTEN.LDT 19.652 ENRA.CNT 847.811 RCEN.CNT 7.461 7.314 0.000 10.209 4385.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 133.006 20.790 18.264 0.000 11.449 4295.000 -2.936 -0.002 102.500 1592.224 2.722 989.813 1.544 5489.513 1.140 7627.446 989.813 106.523 52.563 134.570 9.492 9.052 0.000 11.345 4235.000 8.592 -0.019 145.437 1591.413 2.517 984.977 3.385 2887.927 CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR.LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI Cl. SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR. LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI Cl. SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR.LDT MRES.LDT CFEC.CNT NPHI.CNT PAGE: 25 213.395 255.917 125.452 11.412 1078.355 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5.728 3.547 38.017 37.200 55.358 201.744 989.524 2.698 -0.019 40.668 1647.826 51.240 0.095 3751.150 8.284 7.171 6637.367 0.095 0.306 6.204 3.775 122.282 130.792 103.468 10.834 984.977 2.508 0.032 53.524 1647.470 85.820 0.095 934.842 25.253 LIS Tape Verification Listing Schlumberger Alaska Computing Center TNPH.¢NT 25.939 RCNT.CNT 3397.052 GR.CNT 85.820 MTEH.CNT 170.873 RSHC.DSI 1.773 C2.SHD 6.677 P1AZ.SHD 103.087 DEPT. 11000.000 IMPH.DTE 5.373 ILH.DTE 5.317 IIXD.DTE 19.277 SP.DTE -37.313 MRES.DTE 0.102 DRHO.LDT 0.000 LS.LDT 347.293 SS1.LDT 235.023 S1RH.LDT 2.399 CALI.LDT 9.955 MTEM.LDT 165.019 CNEC.CNT 2444.319 TNPH.CNT 27.843 RCNT.¢NT 2385.814 GR.CNT 44.482 MTEN.CNT 165.019 RSHC.DSI 1.910 C2.SHD 8.049 P1AZ.SHD 45.134 TNRA.CNT RCFT.CNT TENS.¢NT DT4P.DSI MCAL.DSI GR.SHD CIDP.DTE CILD.DTE IDQF.DTE IIRM.DTE GR.DTE MTEM.DTE PEF.LDT LU.LDT SS2.LDT LSRH.LDT TENS.LDT ENPH.CNT RCEF.¢NT TNRA.CNT RCFT.CNT TENS.CNT DT4P.DSI MCAL.DSI GR.SHD DEPT. 10500.000 IMPH.DTE 2.483 ILM.DTE 2.497 IIXD.DTE 52.606 SP.DTE 18.625 HRES.DTE 0.724 DRHO.LDT -999.250 LS.LDT -999.250 SS1.LDT -999.250 SIRH.LDT -999.250 CALI.LDT -999.250 MTEM.LDT -999.250 CNE¢.CNT 2469.063 TNPH.CNT 42.376 RCNT.CNT 1462.500 GR.¢NT 40.826 HTEM.CNT -999.250 RSHC.DSI 1.965 C2.SHD 8.891 P1AZ.SHD 252.877 CIDP.DTE CILD.DTE IDQF.DTE IIRM.DTE GR.DTE MTEM.DTE PEF.LDT LU.LDT SS2.LDT LSRH.LDT TENS.LDT ENPH.CNT RCEF.CNT TNRA.CNT RCFT.CNT TENS.CNT DT4P.DSI MCAL.DSI GR.SHD DEPT. 10000.000 IMPH.DTE 2.462 ILM.DTE 2.537 IIXD.DTE 40.928 SP.DTE -28.250 CIDP.DTE ¢ILD.DTE IDQF.DTE IIRM.DTE GR.DTE 8-JAN-1996 09:04 2.282 RTNR.CNT 1253.895 CNTC.CNT 4235.000 HTEN.CNT 77.121 DT2.DSI -999.250 GR.DSI 90.276 HAZI.SHD 184.570 IDPH.DTE 188.034 ILD.DTE 0.000 IMQF.DTE 177.021 IIXM.DTE 44.482 TENS.DTE 165.104 DPHI.LDT 4.760 QLS.LDT 340.219 LL. LDT 307.178 LSHV.LDT 2.399 LURH.LDT 4035.000 HTEN.LDT 30.272 ENRA.CNT 457.019 RCEN.CNT 2.665 RTNR.CNT 804.132 CNTC.CNT 4035.000 HTEN.CNT 82.690 DT2,DSI -999.250 GR.DSI 41.250 HAZI.SHD 408.252 IDPH.DTE 416.013 ILD.DTE 0.000 IMQF.DTE 371.611 II×M.DTE 56.082 TENS.DTE 151.751 DPHI.LDT -999.250 QLS.LDT -999.250 LL. LDT -999.250 LSHV.LDT -999.250 LURH.LDT -999.250 HTEN.LDT 43.469 ENRA.CNT 389.344 RCEN.CNT 3.572 RTNR.CNT 405.875 CNTC.CNT -999.250 HTEN.CNT 93.633 DT2.DSI 9.660 GR.DSI 55.512 HAZI.SHD 392.883 IDPH.DTE 403.805 ILD.DTE 0.000 IMQF.DTE 365.901 II×M.DTE 50.477 TENS.DTE 2.258 3426.174 984.977 141.793 88.422 111.118 5.418 5.318 0.000 15.014 4035.000 15.639 -0.022 177.186 1589.449 2.411 997.305 4.825 2203.677 2.783 2450.165 997.305 153.391 43.592 88.175 2.449 2.404 0.000 30.293 3790.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5.797 2211.000 3.703 1566.906 -999.250 183.971 56.082 94.764 2.545 2.476 0.000 28.438 3780.000 NPOR.CNT CFTC.CNT MRES.CNT PR.DSI Cl. SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR.LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI Cl. SHD DEVI.SHD CIMP.DTE ¢ILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR. LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI Cl. SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE PAGE: 26 24.581 1477.981 0.095 0.266 6.760 2.178 186.121 188.092 162.512 5.423 1000.590 2.392 0.022 65.781 1643.797 44.482 0.102 506.632 27.095 27.058 936.259 0.102 0.311 9.912 2.015 402.671 400.460 337.572 2.600 1100.798 -999.250 -999.250 -999.250 -999.250 40.826 -999.250 425.957 47.125 43.439 463.883 -999.250 0.325 9.262 1.752 406.109 394.143 323.781 2.354 1113.002 LIS Tape Verification Listing Schlumberger Alaska Computing Center HRES.DTE 0.768 MTEM. DRltO. LDT 0.007 PEF. LS.LDT 308.977 LU. SS1.LDT 234.209 SS2. S1Rlt. LDT 2.446 LSRH. CALI.LDT 8.890 TENS. HTEM. LDT 156.202 ENPH. CNEC.CNT 3455.253 RCEF. TNPH.CNT 30.289 TNRA. RCNT. CNT 3146.581 RCFT. GR.CNT 57.633 TENS. MTEM.CNT 156.202 DT4P. RSHC.DSI 2.002 MCAL. C2.SHD 8,942 GR. P1AZ.SHD 61.626 DTE LDT LDT LDT LDT LDT CNT CNT CNT CNT CNT DSI DSI SHD DEPT. 9500.000 IMPH.DTE 4.315 ILM.DTE 4.193 IIXD.DTE 24.291 SP.DTE -150.500 MRES.DTE 0.787 DRHO.LDT 0.047 LS.LDT 367.250 SS1.LDT 256.480 SiRH.LDT 2.253 CALI.LDT 9.693 MTEM.LDT 151.471 CNEC.CNT 3075.276 TNPH.CNT 33.882 RCNT.CNT 2905.288 GR.CNT 49.146 MTEM.CNT 151.471 RSHC.DSI 2.400 ¢2.SHD 8.723 P1AZ.SHD 259.973 CIDP.DTE CILD.DTE IDQF.DTE IIRM.DTE GR.DTE MTEH.DTE PEF.LDT LU. LDT SS2. LDT LSRH. LDT TENS.LDT ENPH.CNT RCEF.CNT TNRA.CNT RCFT.CNT TENS.¢NT DT4P.DSI MCAL.DSI GR.SHD DEPT. 9000.000 CIDP. IMPH.DTE 4.083 CILD. ILM.DTE 4.059 IDQF. IIXD.DTE 23.191 IIRM. SP.DI'E -142.125 GR. MRES.DTE 0.797 MTEM. DRHO.LDT -0.010 PEF. LS.LDT 303.402 LU. SS1.LDT 223.383 SS2. SIRH.LDT 2.519 LSRH. CALI.LDT 8.889 TENS. HTEM.LDT 147.394 ENPH. CNEC.CNT 3679.500 RCEF. TNPH.¢NT 31.094 TNRA. RCNT.CNT 3014.000 RCFT. GR.CNT 62.561 TENS. HTEM.CNT 147.394 DT4P. RSHC.DSI 1.759 MCAL. DTE DTE DTE DTE DTE DTE LDT LDT LDT LDT LDT CNT CNT CNT CNT CNT DSI DSI 8-JAN-1996 09:04 145.982 DPHI.LDT 3.779 QLS.LDT 305.703 LL.LDT 299.582 LSHV.LDT 2.473 LURH.LDT 3515.000 HTEN.LDT 25.376 ENRA.¢NT 717.101 RCEN.CNT 2.747 RTNR.CNT 1095.139 CNTC.CNT 3515.000 HTEN.CNT 89.480 DT2.DSI 8.803 GR.DSI 47.993 HAZI.SHD 240.348 IDPH.DTE 244.502 ILD.DTE 0.000 IMQF.DTE 223.685 IIXM.DTE 39.718 TENS.DTE 140.351 DPHI.LDT 4.842 QLS.LDT 365.000 LL.LDT 326.000 LSHV.LDT 2.368 LURH.LDT 3474.766 HTEN.LDT 29.637 ENRA.CNT 648.938 RCEN.CNT 3.008 RTNR.CNT 873.662 CNTC.CNT 3474.766 HTEN.¢NT 92.078 DT2.DSI 9.437 GR.DSI 42.125 HAZI.SHD 242.915 IDPH.DTE 249.808 ILD.DTE 0.000 IMQF.DTE 230.984 II×H.DTE 61.021 TENS.DTE 137.988 DPHI.LDT 4.530 QLS.LDT 300.039 LL.LDT 291.589 LSHV.LDT 2.481 LURH.LDT 3370.000 HTEN.LDT 24.365 ENRA.CNT 785.000 RCEN.¢NT 2.889 RTNR.CNT 1011.688 CNTC.CNT 3370.000 HTEN.CNT 84.141 DT2.DSI 9.147 GR.DSI 10.234 -0.021 156.125 1580.045 2.478 1033.884 4.252 3080.189 3.000 3132.702 1033.884 179.164 50.477 99.572 4.161 4.090 0.000 16.076 3610.000 14.185 -0.045 184.750 1582.560 2.373 1057.063 4.749 2761.290 3.084 2679.199 1057.063 221.063 39.718 106.196 4.117 4.003 0.000 15.850 3620.000 10.786 -0.018 153.375 1582.393 2.490 1082.891 4.145 2870.375 3.353 3371.000 1082.891 148.000 61.021 RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR.LDT MRES.LDT CFE¢.CNT NPHI.¢NT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI ¢I.SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR. LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.CNT CFTC.CNT MRES.¢NT PR.DSI Cl. SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR.LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI Cl. SHD PAGE: 27 2.481 0.026 66.671 1634.604 57.633 0.670 812.564 29.787 30.004 1151.516 0.670 0.334 9.157 1.882 231.767 238.480 205.695 4.071 1100.599 2.416 0.043 66.500 1634.253 49.146 0.694 647.546 32.582 30.553 894.759 0.694 0.395 9.335 1.529 244.941 246.392 214.267 4.299 1078.620 2.472 0.010 59.609 1632.416 62.561 0.713 889.000 31.793 35.480 1213.500 0.713 0.261 8.899 LIS Tal~e Verification Listing Schlumberger Alaska Computing Center C2.SHD 8.810 GR.SHD PIAZ.SHD 232.215 DEPT. 8500.000 CIDP.DTE IMPH.DTE 7.481 ¢ILD.DTE ILH.DTE 7.705 IDQF.DI'E II×D.DTE 10.228 IIRM.DTE SP.DTE -144.000 GR.DTE MRES.DTE 0.811 MTEM.DTE DRHO.LDT 0.001 PEF.LDT LS.LDT 301.406 LU.LDT SS1.LDT 229.488 SS2.LDT S1RH.LDT 2.482 LSRH.LDT CALI.LDT 9.530 TENS.LDT MTEM.LDT 143.988 ENPH.CNT CNE¢.CNT 3576.861 RCEF.CNT TNPH.CNT 21.864 TNRA.CNT RCNT.CNT 3602.930 RCFT.CNT GR.¢NT 44.419 TENS.CNT MTEM.CNT 143.988 DT4P.DSI RSH¢.DSI 1.946 MCAL.DSI C2.SHD 9.998 GR.SHD PiAZ.SHD 28.291 DEPT. 8000.000 CIDP.DTE IMPH.DTE 4.891 CILD.DTE ILH.DTE 4.838 IDQF.DTE II×D.DTE 17.288 IIRH.DTE SP.DTE -148.375 GR.DTE MRES.DTE 0.827 MTEM.DTE DRHO.LDT 0.010 PEF.LDT LS.LDT 380.414 LU.LDT SS1.LDT 244.426 SS2.LDT S1RH.LDT 2.318 LSRH.LDT CALI.LDT 11.123 TENS.LDT MTEM.LDT 140.628 ENPH.CNT CNEC.CNT 3059.117 RCEF.CNT TNPH.CNT 26.248 TNRA.CNT RCNT.CNT 3006.657 RCFT.CNT GR.CNT 37.274 TENS.CNT MTEM.CNT 140.628 DT4P.DSI RSH¢.DSI 2.025 MCAL.DSI ¢2.SHD 11.238 GR.SHD P1AZ.SHD 10.076 DEPT. 7500.000 CIDP.DTE IMPH.DTE 3.189 CILD.DTE ILH.DTE 3.165 IDQF.DTE II×D.DTE 37.964 IIRM.DTE SP.DTE -146.625 GR.DTE MRES.DTE 0.853 MTEM.DTE DRHO.LDT 0.036 PEF.LDT LS.LDT 351.672 LU.LDT SS1.LDT 251.086 SS2.LDT S1RH.LDT 2.301 LSRH.LDT 8-JAN-1996 09:04 60.813 HAZI.SHD 133.200 IDPH.DTE 137.157 ILD.DTE 0.000 IMQF.DTE 122.625 IIXM.DTE 39.660 TENS.DTE 135.233 DPHI.LDT 4.426 QLS.LDT 297.906 LL.LDT 299.938 LSHV.LDT 2.484 LURH.LDT 3142.563 HTEN.LDT 20.891 ENRA.CNT 880.063 RCEN.CNT 2.317 RTNR.CNT 1558.481 CNTC.CNT 3142.563 HTEN.CNT 81.164 DT2.DSI 10.295 GR.DSI 38.301 HAZI.SHD 203.293 IDPH.DTE 205.205 ILD.DTE 0.000 IMQF.DTE 194.298 IIXM.DTE 32.972 TENS.DTE 131.601 DPHI.LDT 3.351 QLS.LDT 366.383 LL.LDT 323.992 LSHV.LDT 2.357 LURH.LDT 3020.000 HTEN.LDT 24.621 ENRA.CNT 664.427 RCEN.CNT 2.643 RTNR.CNT 1061.174 CNTC.CNT 3020.000 HTEN.CNT 93.563 DT2.DSI 11.095 GR.DSI 30.518 HAZI.SHD 313.399 IDPH.DTE 310.734 ILD.DTE 0.000 IMQF.DTE 294.835 IIXM.DTE 33.675 TENS.DTE 128.308 DPHI.LDT 3.394 QLS.LDT 340.547 LL.LDT 324.508 LSHV.LDT 2.397 LURH.LDT 117.468 7.508 7.291 0.000 8.507 3420.000 9.930 -0.016 152.469 1578.219 2.495 1109.313 3.772 3028.387 2.383 3879.452 1109.313 157.984 39.660 110.072 4.919 4.873 0.000 9.310 3380.000 17.077 -0.007 197.227 1576.970 2.368 1109.250 4.255 2583.373 2.770 3049.497 1109.250 189.504 32.972 105.353 3.191 3.218 0.000 18.211 3300.000 13.132 -0.005 181.383 1572.732 2.412 DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DI'E HTEN.D'I'E RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR.LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI Cl. SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR.LDT MRES.LDT CFEC.CNT NPHI.¢NT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI Cl. SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR.LDT PAGE: 28 2.159 133.663 129.782 124.060 7.698 1118.590 2.486 0.007 58.805 1630.775 44.419 0.735 948.312 22.490 24.132 1765.856 0.735 0.320 8.528 2.125 204.452 206.709 174.140 4.546 1116.999 2.368 0.015 95.836 1627.768 37.274 0.756 718.968 25.684 26.633 1190.884 0.756 0.339 9.412 2.589 313.607 315.960 261.426 2.597 1119.979 2.433 0.026 74.969 1626.218 35.390 LIS Tape Verification Listing Schlumberger Alaska Computing Center CALI.LDT 13.184 TENS.LDT HTEH.LDT 137.326 ENPH.CNT CNEC.CNT 2804.405 RCEF.CNT TNPH.CNT 29.750 TNRA.CNT RCNT.CNT 2608.852 RCFT.CNT GR.CNT 35.390 TENS.CNT HTEM.CNT 137.326 DT4P.DSI RSHC.DSI 2.241 MCAL.DSI C2.SHD 12.765 GR.SHD P1AZ.SHD 6.091 DEPT. 7000.000 CIDP.DTE IMPH.DTE 7.010 CILD.DTE ILM.DTE 6.894 IDQF.DTE IIXD.DTE 8.021 IIRM.DTE SP.DTE -153.063 GR.DTE HRES.DTE 0.870 MTEM.DTE DRHO.LDT 0.020 PEF. LDT LS.LDT 362.709 LU.LDT SS1.LDT 247.318 SS2.LDT S1RH.LDT 2.316 LSRH.LDT CALI.LDT 12.068 TENS.LDT MTEM. LDT 133.821 ENPH.CNT CNEC.CNT 3193.063 RCEF.CNT TNPH.CNT 27.977 TNRA.CNT RCNT.CNT 3021.250 RCFT.CNT GR. CNT 33.830 TENS.CNT MTEM.CNT 133.821 DT4P.DSI RSHC.DSI 1.725 MCAL.DSI C2.SHD 11.528 GR.SHD P1AZ.SHD 169.293 DEPT. 6500.000 CIDP.DTE IMPH.DTE 5.744 CILD.DTE ILM.DTE 5.688 IDQF.DTE IIXD.DTE 11.192 IIRM.DTE SP.DTE -152.188 GR.DTE HRES.DTE 0.892 MTEM.DTE DRHO.LDT 0.047 PEF.LDT LS. LDT 351.337 LU.LDT SS1.LDT 255.802 SS2.LDT S1RH.LDT 2.263 LSRH.LDT CALI.LDT 9.928 TENS.LDT MTEM.LDT 130.300 ENPH.CNT CNEC.CNT 2882.438 RCEF.CNT TNPH.CNT 37.842 TNRA.CNT RCNT.CNT 2338.797 RCFT.CNT GR.CNT 53.941 TENS.¢NT MTEM.CNT 130.300 DT4P.DSI RSH¢.DSI 1.995 MCAL.DSI ¢2.SHD 9.770 GR.SHD P1AZ.SHD 193.239 8-JAN-1996 09:04 2952.500 HTEN.LDT 31.572 ENRA.CNT 491.293 RCEN.CNT 2.926 RTNR.CNT 848.517 CNTC.CNT 2952.500 HTEN.CNT 90.086 DT2.DSI 13.211 GR.DSI 32.568 HAZI.SHD 141.741 IDPH.DTE 143.137 ILD.DTE 0.000 IMQF.DTE 136.912 IIXM.DTE 29.602 TENS.DTE 125.085 DPHI.LDT 3.363 QLS.LDT 347.955 LL.LDT 319.801 LSHV.LDT 2.385 LURH.LDT 2795.000 HlEN.LDT 27.591 ENRA.CNT 663.125 RCEN.CNT 2.619 RTNR.¢NT 1051.656 CNTC.¢NT 2795.000 HTEN.CNT 100.271 DT2.DSI 11.449 GR.DSI 28.684 HAZI.SHD 170.181 IDPH.DTE 171.667 ILD.DTE 0.000 IMQF.DTE 165.608 IIXM.DTE 47.844 TENS.DTE 121.989 DPHI.LDT 7.223 QLS.LDT 349.793 LL.LDT 310.424 LSHV.LDT 2.378 LURH.LDT 2635.000 HTEN.LDT 34.209 ENRA.CNT 511.445 RCEN.CNT 3.443 RTNR.CNT 681.625 CNTC.CNT 2635.000 HTEN.CNT 95.633 DT2.DSI 9.738 GR.DSI 46.328 HAZI.SHD 1136.938 5.026 2437.232 2.982 2716.663 1136.938 201.848 33.675 105.218 7.055 6.986 0.000 7.700 3040.0O0 14.825 0.004 188.730 1570.568 2.399 994.949 4.582 2724.984 2.764 3058.313 994.949 172.980 29.602 120.475 5.876 5.825 0.000 11.044 2920.000 13.626 -0.044 176.438 1571.191 2.395 1016.734 5.223 2448.125 3.843 2409.672 1016.734 190.820 47.844 113.411 MRES.LDT CFEC.¢NT NPHI.CNT NPOR.CNT CFTC.CNT MRES.¢NT PR.DSI Cl. SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR.LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.¢NT CFTC.CNT MRES.CNT PR.DSI Cl. SHD DEVI.SHD ¢IMP DTE ¢ILM DTE IIRD DTE SFLU DTE HTEN DTE RHOB LDT QSS LDT LITH.LDT SSHV.LDT GR.LDT MRES.LDT CFEC.¢NT NPHI.CNT NPOR.CNT CFTC.¢NT MRES.CNT PR.DSI Cl. SHD DEVI.SHD PAGE: 29 0.776 557.933 29.400 31.177 955.036 0.776 0.376 10.301 3.080 142.663 145.053 126.229 6.397 1090.067 2.405 0.030 90.929 1624.228 33.830 0.801 696.953 25.298 28.354 1142.125 0.801 0.247 10.139 2.426 174.087 175.820 149.726 5.124 1097.128 2.425 0.080 44.162 1624.028 53.941 0.827 551.906 39.705 39.047 738.219 0.827 0.332 8.722 1.803 LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 6000.000 CIDP.DTE IMPH.DTE 6.318 CILD.DTE ILH.DTE 6.351 IDQF.DTE II×D.DTE 9.343 IIRM.DTE SP.DTE -153.563 GR.DTE HRES.DTE 0.934 MTEM.DTE DRHO.LDT 0.044 PEF.LDT LS.LDT 344.885 LU.LDT SS1.LDT 252.531 SS2.LDT SIRH.LDT 2.300 LSRH.LDT CALI.LDT 11.508 TENS.LDT MTEM. LDT 126.673 ENPH.CNT CNEC.CNT 3015.688 RCEF.CNT TNPH.CNT 32.224 TNRA.CNT RCNT.CNT 2499.000 RCFT.CNT GR.CNT 49.026 TENS.CNT MTEM.CNT 126.673 DT4P.DSI RSHC.DSI 1.895 MCAL.DSI C2.SHD 8.212 GR.SHD P1AZ.SHD 103.401 DEPT. 5500.000 CIDP.DTE IMPH.DTE 9.653 CILD.DTE ILM.DTE 8.852 IDQF.DTE IIXD.DTE 6.399 IIRH.DTE SP.DTE -178.063 GR.DTE MRES.DTE 0.959 MTEM.DTE DRHO.LDT -0.013 PEF.LDT LS.LDT 828.202 LU.LDT SS1.LDT 257.600 SS2.LDT S1RH.LDT 1.961 LSRH.LDT CALI.LDT 11.138 TENS.LDT HTEH.LDT 123.363 ENPH.CNT CNEC.CNT 2457.792 RCEF.CNT TNPH.CNT 49.434 TNRA.CNT RCNT.CNT 1597.559 RCFT.CNT GR.CNT 49.876 TENS.CNT HTEH.CNT 123.363 DT4P.DSI RSHC.DSI 2.210 MCAL.DSI C2.SHD 9.316 GR.SHD P1AZ.SHD 65.829 DEPT. 5000.000 CIDP. IMPH.DTE 19.773 CILD. ILM.DTE 16.305 IDQF. II×D.DTE 9.337 IIRM. SP.DTE -41.063 GR. MRES.DTE 3.563 MTEM. DRHO.LDT 0.091 PEF. LS.LDT 376.701 LU. SS1.LDT 266.308 SS2. S1RH.LDT 2.171 LSRH. CALI.LDT 13.189 TENS. MTEM.LDT 106.719 ENPH. CNEC.CNT 2238.313 RCEF. DTE DTE DTE DTE DTE DTE LDT LDT LDT LDT LDT CNT CNT 8-jAN-1996 09:04 147.168 IDPH.DTE 149.485 ILD.DTE 0.000 IMQF.DTE 148.497 IIXM.DTE 49.117 TENS.DTE 117.915 DPHI.LDT 4.265 QLS.LDT 337.170 LL. LDT 318.678 LSHV.LDT 2.410 LURH.LDT 2525.000 HTEN.LDT 31.558 ENRA.CNT 572.688 RCEN.CNT 3.119 RTNR.CNT 703.125 CNT¢.CNT 2525.000 HTEN.CNT 93.938 DT2.DSI 11.774 GR.DSI 45.561 HAZI.SHD 110.331 IDPH.DTE 113.990 ILD.DTE 0.000 IMQF.DTE 106.859 IIXM.DTE 48.130 TENS.DTE 114.415 DPHI.LDT 4.303 QLS.LDT 823.627 LL.LDT 343.855 LSHV.LDT 1.920 LURH.LDT 2365.000 HTEN.LDT 50.335 ENRA.CNT 320.672 RCEN.CNT 4.353 RINR.CNT 401.252 CNTC.CNT 2365.000 HTEN.CNT 120.471 DT2.DSI 10.619 GR.DSI 46.548 HAZI.SHD 66.328 IDPH.DTE 71.407 ILD.DTE 0.000 IMQF.DTE 58.219 IIXM.DTE 39.458 TENS.DTE 106.096 DPHI.LDT 2.881 QLS.LDT 367.681 LL.LDT 336.472 LSHV.LDT 2.363 LURH.LDT 2545.000 HTEN.LDT 31.958 ENRA.CNT 424.508 RCEN.CNT 6.795 6.690 0.000 8.956 2785.000 11.841 -0.016 176.300 1569.505 2.418 1040.917 5.001 2541.125 3.198 2488.906 1040.917 178.078 49.117 111.509 9.064 8.773 0.000 -6.219 2645.000 45.022 -0.101 416.389 1567.538 1.919 1005.010 6.649 1960.496 4.796 1832.186 1005.010 266.298 48.130 154.090 15.077 14.004 0.000 4.014 2750.000 11.140 -0.025 192.860 1556.498 2.360 1191.331 5.076 2008.875 CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB LDT QSS LDT LITH LDT SSHV LDT GR LDT MRES LDT CFEC.CNT NPHI.CNT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI Cl. SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN DTE RHOB LDT QSS LDT LITH LDT SSHV LDT GR LDT MRES LDT CFEC CNT NPHI CNT NPOR CNT CFTC CNT MRES CNT PR DSI Cl SHD DEVI SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR. LDT MRES.LDT CFEC.CNT NPHI.CNT PAGE: 30 158.271 157.459 131.304 5.701 1088.567 2.455 0.043 77.359 1620.783 49.026 0.852 603.016 32.677 31.958 839.625 0.852 0.306 11.855 0.746 103.594 112.967 98.735 10.507 1079.892 1.907 0.078 182.365 1619.503 49.876 0.877 369.639 55.255 57.039 456.325 0.877 0.371 10.412 0.482 50.573 61.330 68.353 24.597 1392.167 2.466 0.049 106.885 1600.551 44.252 3.077 441.688 27.432 LIS Tape Verification Listing Schlumberger Alaska Computing Center TNPH.CNT 27.985 TNRA.CNT RCNT.CNT 2293.875 RCFT.CNT GR.CNT 44.252 TENS.CNT HTEH.CNT 106.719 DT4P.DSI RSHC.DSI 1.938 MCAL.DSI C2.SHD 12.615 GR.SItD P1AZ.SHD 346.066 DEPT. 4500.000 CIDP.DTE IMPH.DTE 7.269 CILD.DTE ILM.DTE 7.259 IDQF.DTE II×D.DTE 9.149 IIRM.DTE SP.DTE -71.500 GR.DTE HRES.DTE 3.540 MTEM.DTE DRHO.LDT 0.006 PEF.LDT LS.LDT 445.469 LU.LDT SS1.LDT 243.383 SS2.LDT S1RH.LDT 2.248 LSRH.LDT CALI.LDT 14.157 TENS.LDT MTEM. LDT 106.135 ENPH.CNT CNEC.CNT 2358.563 RCEF.CNT TNPH.¢NT 32.075 TNRA.CNT RCNT.CNT 2365.344 RCFT.CNT GR.¢NT 43.923 TENS.CNT MTEM.CNT 106.135 DT4P.DSI RSHC.DSI 2.029 MCAL.DSI C2.SHD 14.112 GR.SHD P1AZ.SHD 305.028 DEPT IHPH DTE ILH DTE II×D DTE SP DTE MRES DTE DRHO LDT LS LDT SS1.LDT S1RH.LDT CALI.LDT MTEM.LDT CNEC.¢NT TNPIt. CNT R£NT.¢NT GR.CNT MTEH.CNT RSHC.DSI C2.SItD P1AZ,SHD 4000.000 ¢IDP.DTE 7.432 CILD.DTE 7.264 IDQF.DTE 24.631 IIRM.DTE -59.563 GR.DTE 3.556 MTEM.DTE 0.000 PEF.LDT 515.000 LU.LDT 244.803 SS2.LDT 2.189 LSRH.LDT 12.566 TENS.LDT 105.044 ENPH.CNT 2429.721 RCEF.CNT 36.512 TNRA.CNT 2274.017 RCFT.CNT 52.117 TENS.CNT 105.044 DT4P.DSI 1.903 MCAL.DS! 12.090 GR.SHD 4.794 8-JAN-1996 09:04 2.810 RTNR.CNT 728.750 CNT¢.CNT 2545.000 HTEN.CNT 92.471 DT2.DSI 12.841 GR.DSI 41.034 HAZI.SHD 133.121 IDPH.DTE 134.848 ILD.DTE 0.000 IMQF.DTE 130.090 IIXM.DTE 45.531 TENS.DTE 104.872 DPHI.LDT 2.559 QLS.LDT 424.008 LL.LDT 326.518 LSHV.LDT 2.271 LURH.LDT 2488.984 HTEN.LDT 32.249 ENRA.CNT 453.156 RCEN.CNT 2.987 RTNR.¢NT 715.219 CNTC.CNT 2488.984 HTEN.CNT 124.609 DT2.DSI 13.296 GR.DSI 42.473 HAZI.SHD 148.828 150.896 0.000 129.998 50.867 103.578 2.937 492.006 333.252 2.188 2260.000 34.001 435.497 3.351 614.317 2260.000 124.419 12.423 50.941 DEPT. 3500.000 CIDP.DTE 110.797 IMPlt. DTE 9.668 CILD.DTE 114.792 ILM.DTE 9.528 IDQF.DTE 0.000 IIXD.DTE lO.511 IIRM.DTE 99.334 SP.DTE -86.250 GR.DTE 45.977 IDPH.DTE ILD.DTE IMQF.DTE IIXM.DTE TENS.DTE DPHI.LDT QLS.LDT LL LDT LSHV LDT LURH LDT HTEN LDT ENRA CNT RCEN CNT RTNR CNT CNTC.CNT HTEN.CNT DI'2.DSI GR.DSI HAZI.SHD I DPH. DTE I LD. DTE IMQF.DTE I I XM. DTE TENS.DTE 2.823 2219.875 1191.331 179.234 39.458 43.635 7.512 7.416 0.000 8.452 2460.000 21.964 -0.011 233.465 1553.333 2.276 1271.219 5.130 2043.188 3.184 2314.188 1271.219 252.880 45.531 202.919 6.719 6.627 0.000 15.063 2360.000 27.442 -0.029 268.996 1550.372 2.192 1221.508 5.268 2104.109 3.451 2218.962 1221.508 236.779 50.867 281.265 9.026 8.711 0.000 14.191 2280.000 NPOR.CNT CFTC.CNT MRES.CNT PR.DSI Cl. SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR. LDT MRES.LDI' CFEC.CNT NPHI.¢NT NPOR.¢NT CFTC.CNT MRES.CNT PR.DSI Cl. SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR.LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.CNT CFT¢.CNT MRES.CNT PR.DSI ¢i. SHD DEVI.SHD CIMP.DTE ¢ILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE PAGE: 31 26.817 808.250 3.077 0.318 12.377 0.494 137.569 137.757 115.631 8.223 1387.581 2.288 0.025 137.500 1601.716 43.923 3.041 459.773 29.643 31.208 757.406 3.041 0.340 14.181 0.365 134.553 137.659 140.559 8.110 1400.618 2.197 0.027 142.967 1601.897 52.117 3.060 461.195 36.286 35.457 676.905 3.060 0.309 12.219 0.619 103.439 104.955 103.265 10.469 1414.658 LIS Tape Verification Listing Schlumberger Alaska Computing Center MRES.DTE 3.671 MTEM.DTE DRHO.LDT 0.004 PEF.LDT LS.LDT 583.699 LU.LDT SS1.LDT 251.507 SS2,LDT S1RH.LDT 2.107 LSRH.LDT CALI.LDT 12.355 TENS.LDT MTEH.LDT 102.807 ENPH.CNT CNEC.CNT 2298.211 RCEF.CNT TNPH.CNT 40.572 TNRA.CNT RCNT.CNT 2001.250 RCFT.CNT GR.CNT 44.411 TENS.CNT MTEM.CNT 102.807 DT4P.DSI RSHC.DSI 2.269 HCAL.DSI C2.SHD 11.977 GR.SHD P1AZ.SHD 5.991 DEPT. 3000.000 CIDP.DTE IHPH.DTE 16.745 CILD.DTE ILM.DTE 16.010 IDQF.DTE IIXD.DTE 4.697 IIRM.DTE SP.DTE -100.250 GR.DTE MRES.DTE 3.761 MTEM.DTE DRHO.LDT -0.001 PEF.LDT LS.LDT 538.139 LU.LDT SS1.LDT 245.477 SS2.LDT S1RH.LDT 2.170 LSRH.LDT C^LI.LDT 12.300 TENS.LDT MTEH.LDT 100.962 ENPH.CNT CNEC.CNT 2408.641 RCEF.¢NT TNPH.CNT 36.750 TNRA.CNT RCNT.CNT 2342.938 RCFT.CNT GR.CNT 47,022 TENS,CNT MTEM.CNT 100.962 DT4P,DSI RSHC.DSI 2.363 MCAL,DSI C2.SHD 12,007 GR.SHD PiAZ.SHD 73,995 DEPT. IMPH,DTE ILH.DTE IIXD.DTE SP,DTE HRES,DTE DRHO.LDT LS.LDT SS1 LDT S1RH LDT CALI LDT MTEM LDT CNEC CNT TNPH CNT RCNT.CNT GR.CNT MTEM.CNT RSHC.DSI 2500.000 CIDP.DTE 15,676 CILD.DTE 14.885 IDQF.DTE 0.132 IIRM.DTE -96.000 GR.DTE 3.883 MTEM.DTE 0.002 PEF.LDT 617.431 LU.LDT 252.341 SS2.LDT 2.081 LSRH.LDT 12.316 TENS.LDT 98.868 ENPH.CNT 2246.937 RCEF.CNT 40,584 TNRA,CNT 2052.545 RCFT.CNT 38.284 TENS.CNT 98.868 DT4P.DSI 2.406 MCAL.DSI 8-JAN-1996 09:04 100.631 DPHI.LDT 2.842 QLS.LDT 562.952 LL.LDT 341.512 LSHV.LDT 2.121 LURH.LDT 2087.078 HTEN.LDT 39.442 ENRA.CNT 382.984 RCEN.CNT 3.745 R1NR.CNT 551.578 CNTC.CNT 2087.078 HTEN,CNT 118.582 DT2.DSI 12.245 GR.DSI 40.597 HAZI.SHD 64.719 [DPH.DTE 67.293 ILD.DTE 0.000 IMQF.DTE 59.287 IIXM.DTE 45.006 TENS.DTE 97.729 DPHI.LDT 3.034 QLS.LDT 513.891 LL. LDT 338.130 LSHV.LDT 2.164 LURH.LDT 1929.156 HTEN.LDT 38.536 ENRA.CNT 405.750 RCEN.CNT 3.286 RTNR.CNT 654.969 CNTC.CNT 1929,156 HTEN,CNT 125.389 DT2.DSI 12,134 GR.DSI 44.820 HAZI.SHD 67.107 IDPH.DTE 70.498 ILD.DTE 0.000 IHQF.DTE 63.749 IIXM.DTE 41.725 TENS.DTE 94.623 DPHI.LDT 3.336 QLS.LDT 582.203 LL. LDT 345.561 LSHV.LDT 2.088 LURH.LDT 1940.000 HTEN.LDT 39.718 ENRA.CNT 353.949 RCEN.CNT 3.584 RTNR.CNT 573,315 CNTC.CNT 1940.000 HTEN,CNT 129.681 DT2.DSI 12.275 GR.DSI 31.265 -0.050 302.222 1550.485 2.117 1201.797 5.771 1972.969 3.994 2055.094 1201.797 269.078 45.977 287.248 15.451 14.860 0.000 14.090 2120.000 28.931 -0.032 281.191 1549.480 2.167 1189.609 5.688 2120.250 3.438 2283.109 1189.609 296,246 45.006 320.861 14.902 14,185 0,000 47.353 1980.000 33.414 -0.026 326.329 1547.677 2.099 1225.711 5.795 1907.872 3.731 2052.346 1225.711 312.025 41.725 RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR.LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI C1.SHD DEVI.SHD CIMP.DTE C I LM. DTE I I RD. DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR. LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI Cl. SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR. LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI C1.SHD PAGE: 32 2.134 0.039 168.960 1602.461 44.411 3.119 398.246 43.601 41.813 583.535 3.119 0.379 12.048 0.682 59.721 62.459 60.782 18.291 1415.577 2.173 0.021 152.415 1601.888 47.022 3.201 423.477 35.224 35.646 695.359 3.201 0.391 12.046 0.809 63.790 67.183 63.064 14.883 1407.050 2.099 0.037 162.441 1600.497 38.284 3.311 387.743 40.664 40.570 582.800 3.311 0.396 11.877 LIS Tape Verification Listing Schlumberger Alaska Computing Center C2.SHD 11.883 GR.SHD P1AZ.SHD 150.241 DEPT. 2000.000 CIDP.DTE IMPH.DTE 21.529 CILD.DTE ILM.DTE 20.499 IDQF.DTE II×D.DTE -14.276 IIRH.DTE SP.DTE -97.875 GR.DTE MRES.DTE 4.059 MTEM.DTE DRHO.LDT -0.004 PEF.LDT LS.LDT 624.992 LU.LDT SS1.LDT 249.018 SS2.LDT S1RH.LDT 2.097 LSRH.LDT CALI.LDT 12.325 TENS.LDT HTEH.LDT 95.836 ENPH.¢NT CNEC.CNT 2328.234 RCEF.CNT TNPH.¢NT 42.810 TNRA.CNT RCNT.CNT 2068.891 RCFT.CNT GR.CNT 42.377 TENS.CNT MTEM.¢NT 95.836 DT4P.DSI RSHC.DSI 2.646 MCAL.DSI C2.SHD 11.960 GR.SHD PIAZ.SHD 117.907 DEPT. 1500.000 CIDP.DTE IMPH.DTE 20.115 CILD.DTE ILM.DTE 19.373 IDQF.DTE IIXD.DTE 1.266 IIRM.DTE SP.DTE -94.313 GR.DTE HRES.DTE 4.290 MTEM.DTE DRHO. LDT 0.007 PEF. LDT LS. LDT 506.142 LU.LDT SS1.LDT 249.022 SS2.LDT S1RH.LDT 2.170 LSRH.LDT CALI.LDT 12.456 TENS.LDT MTEM.LDT 92.714 ENPH.CNT CNEC.¢NT 2354.238 RCEF.CNT TNPH.CNT 43.888 TNRA.CNT RCNT.CNT 1893.067 RCFT.CNT GR.CNT 63.001 TENS.CNT HTEH.¢NT 92.714 DT4P.DSI RSHC.DSI 2.649 MCAL.DSI C2.SHD 12.203 GR.SHD P1AZ.SHD 102.413 DEPT. 1000.000 CIDP.DTE IMPH.DTE 24.899 CILD.DTE ILH.DTE 24.186 IDQF.DTE IIXD.DTE -0.134 IIRM.DTE SP.DTE -114.688 GR.DTE MRES.DTE 4.486 MTEM.DTE DRHO.LDT -0.003 PEF.LDT LS.LDT 537.074 LU.LDT SS1.LDT 244.641 SS2.LDT S1RH.LDT 2.175 LSRH.LDT 8-JAN-1996 09:04 40.006 HAZI.SHD 47.456 IDPH.DTE 49.830 ILD.DTE 0.000 IMQF.DTE 46.348 II×M.DTE 40.048 TENS.DTE 90.870 DPHI.LDT 3.120 QLS.LDT 589.895 LL.LDT 342.719 LSHV.LDT 2.082 LURH.LDT 1675.000 HTEN.LDT 39.652 ENRA.CNT 398.000 RCEN.CNT 3.777 RTNR.CNT 535.781 CNTC.CNT 1675.000 HTEN.CNT 134.896 DT2.DSI 12.168 GR.DSI 39.685 HAZI.SHD 49.114 IDPH.DTE 51.298 ILD.DTE 0.000 IMQF.DTE 49.033 IIXM.DTE 59.998 TENS.DTE 86.383 DPHI.LDT 3.265 QLS.LDT 481.602 LL.LDT 340.126 LSHV.LDT 2.198 LURH.LDT 1590.000 HTEN.LDT 42.172 ENRA.CNT 362.395 RCEN.¢NT 3.847 RTNR.CNT 509.323 CNTC.CNT 1590.000 HTEN.CNT 139.806 DT2.DSI 12.632 GR.DSI 53.595 HAZI.SHD 38.321 IDPH.DTE 40.181 ILD.DTE 0.000 IMQF.DTE 39.303 II×M.DTE 41.861 TENS.DTE 83.819 DPHI.LDT 2.994 QLS.LDT 509.432 LL.LDT 332.307 LSHV.LDT 2.165 LURH.LDT 351.417 21.072 20.068 0.000 24.568 1900.000 34.070 -0.028 330.047 1547.896 2.092 1190.894 5.789 2034.422 4.003 2096.020 1190.894 356.951 40.048 243.921 20.361 19.494 0.000 1.087 1720.000 26.398 -0.022 265.340 1548.948 2.204 1182.671 6.013 1989.405 4.255 1921.169 1182.671 370.324 59.998 213.891 26.095 24.887 0.000 1.292 1640.000 28.984 -0.023 282.358 1547.595 2.172 DEVI.SHD CIMP.DTE CILH.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR.LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI C1.SHD DEVI.SHD ¢IMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR.LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.CNT CFI'C.CNT MRES.CNT PR.DSI C1.SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR. LDT PAGE: 33 0.598 46.450 48.783 45.225 20.263 1435.882 2.088 0.034 169.475 1600.059 42.377 3.385 402.213 44.202 43.434 573.156 3.385 0.417 12.031 0.338 49.714 51.619 47.417 20.162 1414.181 2.214 0.022 142.252 1598.954 63.001 3.533 391.540 45.431 44.606 515.595 3.533 0.417 12.165 0.353 40.163 41.346 36.401 23.507 1410.448 2.172 0.032 148.848 1597.250 42.618 LIS Tape Verification Listing Schlumberger Alaska Computing Center CALI.LDT 12.523 TENS.LDT MTEM.LDT 90.700 ENPH.¢NT CNEC.CNT 2333.410 RCEF.¢NT TNPH.CNT 45.646 TNRA.¢NT RCNT.CNT 2036.352 RCFT.CNT GR.CNT 42.618 TENS.CNT HTEM.CNT 90.700 DT4P.DSI RSHC.DSI 3.048 MCAL.DSI ¢2.SHD 12.126 GR.SHD PIAZ.SHD 298.417 DEPT. 512.000 CIDP.DTE IHPH.DTE -999.250 CILD.DTE ILM.DTE -999.250 IDQF.DTE II×D.DTE -999.250 IIRM.DTE SP.DTE -999.250 GR.DTE HRES.DTE 4.658 MTEM.DTE DRHO.LDT -999.250 PEF. LDT LS.LDT -999.250 LU,LDT SS1.LDT -999.250 SS2.LDT S1RH.LDT -999.250 LSRH.LDT CALI.LDT -999.250 TENS.LDT HTEH.LDT -999.250 ENPH.CNT CNEC.CNT 2124.772 RCEF.¢NT TNPH.¢NT 62.223 TNRA.CNT RCNT.CNT 1272.030 RCFT.CNT GR.¢NT 33.705 TENS.CNT HTEM.¢NT -999.250 DT4P.DSI RSHC.DSI -999.250 MCAL.DS! ¢2.SHD -999.250 GR.SHD PIAZ.SHD -999.250 8 JAN-1996 09:04 1440.000 HTEN.LDT 41.648 ENRA.CNT 377.938 RCEN.CNT 3.841 RTNR.CNT 476.788 CNTC.CNT 1440.000 HTEN.CNT 145.824 DT2.DSI 12.333 GR.DSI 44.589 HAZI.SHD -999.250 IDPH.DTE -999.250 ILD.DTE -999.250 IMQF.DTE -999.250 IIXM.DTE 36.378 TENS,DTE 82.303 DPHI.LDT -999.250 QLS.LDT -999,250 LL.LDT -999.250 LSHV.LDT -999.250 LURH.LDT -999.250 HTEN.LDT 66.573 ENRA.CNT 258.920 RCEN.CNT 4.740 RI'NR.CNT 257.617 CNTC.CNT -999.250 HTEN.CNT -999.250 DT2.DSI -999.250 GR.DSI 37.261 HAZI.SHD 1191.080 5.969 2084.203 4.081 2012.813 1191.080 444.515 41.861 214.865 -999.250 -999.250 -999,250 -999.250 1520.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 7.823 1854.995 4.581 1216.698 -999.250 -999.250 36.378 -999.250 MRES.LDT CFE¢.CNT NPHI.CNT NPOR.CNT CFTC.CNT MRES.CNT PR.DSI C1.SHD DEVI.SHD CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE HTEN.DTE RHOB.LDT QSS.LDT LITH.LDT SSHV.LDT GR. LDT MRES.LDT CFEC.CNT NPHI.CNT NPOR.¢NT CFTC.CNT MRES.CNT PR.DSI Cl. SHD DEVI.SHD PAGE: 34 3.661 390.984 45,288 45.054 524.972 3.661 0.440 12,213 0.583 -999.250 -999.250 -999.250 -999.250 1433.201 -999.250 -999.250 -999.250 -999.250 33.705 -999.250 271.591 61.509 59.405 268.508 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1996 09:04 PAGE: 35 **** TAPE TRAILER SERVICE NAME : EDIT DATE : 96/01/ 8 ORIGIN : FLIC TAPE NAME : 95335 CONTINUATION # : 1 PREVIOUS TAPE COMMENT : ARCO ALASKA INC., WILDCAT, BUFFLEHEAD #1, API# 50-133-20466-00 **** REEL TRAILER SERVICE NAME : EDIT DATE : 96/01/ 8 ORIGIN : FLI¢ REEL NAME : 95335 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., WILDCAT, BUFFLEHEAD #1, API# 50-133-20466-00