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196-006
TTT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: AOGCC WNS wells Geochem request 12/6/2022 DATE: 01/11/2023 Transmitted: North Slope, Colville River Unit, Alaska Via SFTP ___AOGCC WNS wells Geochem request email 12/6/2022 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: wells e-transmittal well folder Receipt: Date: Alaska/IT-Support Services |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 By Meredith Guhl at 10:28 am, Jan 19, 2023 194-026 T37450 191-147 T37451 196-006 T37452 195-020 & 204-245 T37453 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.19 10:37:44 -09'00' THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE 001 M PI_ A T E E W IA L U N D ER T C :LORI~fF]LM.DO C ' H I$ M ARK ER "/'5 9' F'ERF~ DATA 9 6 ,-- 0 0 ? '/ / D ;..q 't e: 0/~/' 2 8 ,/' !3 7 Q /3'% . . . DAZLY WELL OPS R W e 'i 1 i'1 C 0 Ni ki E N T S ? bo - ! "'" / t'- C:J / -p /.: ,. .":96 "- 006 96--006 96 --006 96--006 96 .... 006 96-006 96---006 96--006 96 .... OO6 9 [,-3--006 96 - 006 96 ...... 006 '?058 7059 ~[::, R / S D I/' L D T ,,," ,:..i N T G/' rS IR O 'q~RFT SWCC R PT SC, RELAB .-.b-"/'SEPZA E,,I PD E SONIC FORklATtON LG MECH SW ,S,S, RE RE,s~EF'Lr.A .... ~'< - ' RF'T ~SEPIA f) ,i!.i 'to e:: :: i 2 / 1 i/' ,(ii t::: IJ i",.] 13 A '1" E F.: E (3 V D ' '" /96 05 / 1 :-~ .,. .. -" .... q 6 fib/ l.s/ .,.. 05/' i3/"96 0'.5/ 'i 3 / 96 '1 05/ 1 .3/96 05 / 03 / 96 'j ri 5/ i '-* 96 .... ~ ,,/' ". 96 (') !5/' 1 J ,/ '1 05 / i 3 /96 05/' 'i 5,. ,.,' 96 [':l r. 9 ,,,/28/' 6 0 tS ./03//96 DZR SI.,!RV ~ ASCII '"'. .[',)ZR SURV ,.-"¢- DATA SET~ END OF WELL RPT Are dr"y d'¥tch samples r'eq u i' r"ed ? Was Lhe we 'l 'i c;c;,t-ed ..r no Aha 'l ysi s &. descr'i p'l:.-'i' on O,.. ,--~ ~.¢, ..,,,, h., "/..'~:'.~ '!'--, '~-:- Weil is i'l~ compliance ___¢~ _. Z n i 't-')' a l C O f,"l hi E N T S L~ ARCO Exploration Company E] ARCO Oil and Gas Company '~ ARCO Alaska, Inc. ,,, Record Of Shipment Of Confidential Information IDistrict: Alaska From: ARCO Alaska, Inc. AOGCC Attn.- Mr. Robert P Crandall P.O. Box 100360 99501 3001 Porcupine Dr Anchorage Alaska Anchorage, Alaska 99510-0360 Attn.- Kelli Thibodeau (907)265-6240 (X) Enclosed ( )Under separate cover ()Via /Alpine 3 "Bergschrund 2 /Bergschrund 2A Well Summary Report as Displayed Well Summary Report as Displayed Well Summary Report as Displayed by ARCO by ARCO 01S" - ~1 Lc by ARCO Cf G- 0 %-~ / Sidewall Core Description Run I as Displayed by ARCO / Sidewall Core Description Run 2 as Displayed by ARCO -/Nanuk I Well Summary Report as Displayed by ARCO / Sidewall Core Description - Rotary as Displayed by ARCO .. Neve 1 Core Report as Displayed by ARCO by ARCO by ARCO by ARCO by ARCO r Well Summary Report as Displayed ,,--' Core Chip Description as Displayed ... Core Chip Description as Displayed ,/~emptation I Well Summary Report as Displayed /'"Temptation lA Well Summary Report as Displayed by ARCO ~ f~ - O-I q; Note - PleAse verify and acknowled~le receipt, by signing and returnin~l a copy of this transmittal. Signed ~~-'~ 0_,~.t Date ~, 08/16/96 Receive(hrb~/ t;~ ' Date Remarks: Please Note that all included information is CONFIDENTIAL. RECEIVED AJG.~I 9 19~G ~s Alaska 0il & G%C0~ns. C0mrn's~ Anchor.ge ~~'" ARCO Alaska, Inc. AtlanticRichfieldCornpany TO: AOGCC Attn.: Mr. Robert P Crandail 3001 Porcupine Dr Anchorage Alaska 9950 FROM: ARCO Alaska, Inc. Attn.: Ms. Keili A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: June 2, 1996 Transmitted herwith is the following data: DIGITAL DATA Displayed by Schlumberger: Bergschrund 2A 6" Open Reel Tape -LDWG Format -"LOGGING WHILE DRILLING" CDR & CDN with paper file listing 3.5 Floppy-ascii Format-Depth-adjusted Directional Survey Temptation lA 6" Open Reel Tape -LDWG Format -"LOGGING WHILE DRILLING" CDR & CDN with paper file listing 3.5 Floppy-ASCii Format-Depth-adjusted Directional Survey END OF WELL REPORTS Displayed By EPOCH WELL LOGGING INC.: Bergschrund 2A Nanuk 1 .eve1 ~I ¢~ Temptation I ~' Temptation lA If you have any questions please call me at (907) 265-6240. Kelli RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by: DATE: _ ,~proved for transmittal by: ~ Manager, No~h Alas~plor i'q 0 ~ ~996 /- F.M. ~eycu~ Gas~¢orage~nS. Commission a~ ARCO Alaska, Inc. AtlanticRichfieldCompany TO: AOGCC Attn · Mr. Robert P Crandail 3001 Porcupine Dr Anchorage Alaska 99501 FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: June 2, 1996 Transmitted herwith is the followinq data: Enclosed is the following data: LOGS: I Sepia Copy Displayed by Schlumberger: Bergschrund 2A CDN FINAL PRINT CDN FINAL PRINT TRUE VERTICLE DEPTH CDR FINAL PRINT CDR FINAL PRINT TRUE VERTICLE DEPTH MECHANICAL SIDEWALL CORING RECORD 13 MARCH 1996 I Sepia Copy Displayed by Schlumberger: Temptation lA CDN FINAL CDN FINAL CDR FINAL CDR FINAL PRINT PRINT TRUE VERTiCLE DEPTH PRINT PRINT TRUE VERTICLE DEPTH I Blueline Copy Displayed by Schlumberger: Bergschrund 2A CDN FINAL PRINT CDN FINAL PRINT TRUE VERTlCLE DEPTH CDR FINAL PRINT CDR FINAL PRINT TRUE VERTICLE DEPTH MECHANICAL SIDEWALL CORING RECORD 13 MARCH 1996 1 Blueline Copy Temptation 1 CDN FINAL CDN FINAL CDR FINAL CDR FINAL Displayed by Schlumberger: A PRINT PRINT TRUE VERTICLE DEPTH PRINT PRINT TRUE VERTICLE DEPTH JUN .0 5 i,396 Alaska 0il ~ PLUGGIng. & LOCATION CLEA~.=,{CE REPORT State of Alaska 7'73'0, Note casing size, wt, depth, cm= vol, & procedure. Sfc Csg: Perf intervals Review the well file, and' comment on plugging, well head s t. atus, and lo~tion c~earanc.e- .Dro3z~de loc. clear, code. 7o6o--, --~..~-.,~,.,.~ ~..mms~//~s'' ' Code FROM: DATE: AR CO Alaska Inc. AtlanticRichfieldCompany CONFIDENTIAL DA TA Sandra D. Lemke, ATO1354 ARCO Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Ak. Oil & Gas Conservation Comm. ATTN: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99510 ac, ucc data request: ColvilIe directional survey data 05/28/96 Transmitted herewith is the followint: Colville Delta Exploratory well directional ASCII files · CONFIDENTIAL DA TA c[ ~ - (.3 t~ t~ -~- *Temptation 1 survey digital data 501032023300 0'-7660' md *TemptationlA 501032023301 0-8950' md *Bergschrund 2A 501032023201 1797.5'-7894' **Alpine 3 501032023400 an updated version of this survey is forthcoming to AAI from Geoquest - the original survey was in error. additional surveys for 1996 drilling season deviated boreholes will be forthcoming when data is available. (waiting on surveys for Neve 1 and lA) CC: M. McDermott, Kelli Thibodeau Approved for transmittal by: Receipt: '~.-~ ~J~ Return receipt to: ARCO Alaska, inc. ATTN: S. Lemke, ATO-1354 700 G. Street Anchorage, AK 99501 Prepared by;. .... ~S_.andm D, Lemke STATE OF ALASKA ALAS,.,~ OIL AND GAS CONSERVATION COMMIt.,. ON WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [---J GAS F'-] SUSPENDED E~ ABANDONED [] SERVICE E~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-006 3 Address 18 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20233 4 Location of well at surface 9 Unit or Lease Name 1891' FSL, 539' FWL, SEC. 16, T12N, R4E, UMi'~'i~i~i~.iii~'ii~'~i~-~ '~?~'~/~~-' -- t~: N/A ^,To 1888' FSL, 524' FWL, Sec. T12N, R4E, UM ~ ~',',EE~ ~~ 11 Fie,dandPoo, At Total Depth 1885' FSL, 518' FWL, Sec. 16, T12N, R4E, UM ........................ WILDCAT 5 Elevation in feet (indi~te KB, DF, etc.) I 6 Lease ~signation and Serial No. RKB 35' ABOVE SLJ ADL 380095 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or A~nd. ~ 15 Water Depth, if offshore 16 No. of Completions 24-Mar-96 01-Apr-96 4-4-96 Abandoned~ NA feet MSL NA 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Su~ey 12o Depth where SSSV set 21 Thickness of ~rma~ost 7750' MD, 7750'~D YES ~ NO ~I NA feet MD =800'ss 22 Ty~ Electric or Other Logs Run TO BE SENT UNDER SEPARATE COVER BY EXPLORATION GEOL~Y 23 CASING, LINER AND CEMENTING .RECORD SETTING DEPTH MD .CASING SIZE ~ GRADE TOP B~ HOLE SIZE CEME~ ~RD 16" 62.58¢ B SURF 110' 20" 300 sx AS I 9.625" 53.5¢ U80 SURF 1817' 12.25" 291 SX AS III & 607 SX AS I 24 Perforations o~n to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD inte~al, size and numar) SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED See a~ached operations summary 27 PRODUCTION TEST Date First Production ~Method of Operation (Flowing, gas li~, etc.) N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, ~rosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. TO BE SENT UNDER SEPARATE COVER BY EXPLORATION GEOLOGY Form 10-407 Submit in duplicate 30. GEOLOGIC MAF~ERS 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 AS-BUILT SURVEYS, P&A DIAGRAM, AND DIRECTIONAL SURVEYS AND DAILY DRILLING REPORTS 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 B I T B I T MAKE AND SERIAL JETS DEPTH DEPTH FEET HOURS R O P WOB BIT RPM PUMP PRES MUD MUD BIT. NO. SIZE TYPE NUMBER IN OLfl' On Btm ,A,v,~l Lo- Hi-A¥~I Lo - Hi- Av[I Lo - Hi- Avg WT VIS , , , , , , ~ , , , , , , ,1 12.25" STC MA1SL LE3939 2-15, 1-10 107' 1825' 1718 13.31 129.0 0.3- 21 - 6 74- 127- 124 577- 1768- 1181 10.1 110 , , , 2 8.50" HYCALOG SX70B2FT+ 17388 6-10 1825' 7750' 5925 68.72 86.2 0.4- 15- 5 204- 376- 352 913- 3049- 2473 10.2 42 ' ' * * GRADE RATING: BIT NO. 2 = 2-3-CT, BT-A-IN-NO-TD Epoch ~'eil Logging, Inc. DATE: MARCH 24, 1996 i:i:i:i:i:i:!:i:i:!:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:!:i:i:!:!:i:!:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:!:i:icasing to Date: 16" at 107' :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ................................... ......................................................................................................................... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: BIT INFOR~TION: No. S~e Type Sedal No. Jets Inte~al Footage Hours condition 1 12.25" MA1SL l~l~10(cant, rJ.~) 107'- In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth' 107' 9.5 110 20 40 26/48 14.8 3 0.0 0 Tr 22.5 9.1 600 40 DRILLING PARAMETERS: N/A High Low Average Rate of Penetration at at fi/hr Surface Torque at at Ft-lbs Weight on Bit at at Klbs Bit RPM at at RPM - Pump Pressure at at psi 3~UMMARY: High Low Average To[al Ditch Gas Out: I N/A I at at units Methane (C-1) at at ppm Ethane (0.-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at. at ppm Total Cuttings Gas: at at units Background Gas: I I units Wiper Gas: units @ Connection Gas: None units average units max. Tdp Gas: units @ HYDROCARBON SHOWS: N/A LITHOLOGY: N/A DAILY ACTIVITY SUMMARY: Rig up prior to Spud; test bag and diverter; pick up NB #1 (12.25"); test MWD tool, but unable to get a response; work on MWD tool. D£pTHi-"11~5' 'l(4i00'X~ii ............ ~e'~t'~l~;: ....... '1'0~: .............. ~4'H'~6~'P~0'g~e~'~: ......... ~!iiii~iiiiiiiiiiiiiiiiiiiiiiijiiiiiii!iiiiiiiiiiiiiiiiiiiii!iiiiiiiiijiiiiiiii~i~iiiijij~i~i ~ ~: 0.8 I~IFoR~~: ~..~/c~~., s~, c~o.. ..... I~~?1'~"~ ~: 2.~. CO~ ~S: I un. J~[~[~;~P GAS: ~ f~[~[~I~MUM GAS: 10 un~s J~[[~]~ EXPORT: 0.80 BIT INFORMATION: No. Size Type 1 12.25" MA1SL Serial No. Jets Interval Footage Hours Condition LE4718 15-15-10(center Jet) 107'- In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth · 1080' 9.8 118 7 57 48/64 16.9 3 7.4 0 0.75 30.0 8.5 2,300 60 DRILLING PARAMETERS: High Low Average Rate of Penetration 403.6 at 109' 9.5 at 437' 130.6 fi/hr - Surface Torque 152 at 760' 41 at 330' 99 Ft-lbs Weight on Bit 21 at 760' 0.1 at 201' 7 Kibs Bit RPM 127 at 512' 74 at 132' 123 RPM Pump Pressure 1768 at 909' 595 at 141' 1411 psi .3AS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 956' 0.4 at 378' 2.5 units Methane (C-1) 2040 at 956' 91 at 378' 501 ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: 10 at 960' 0 at 120' 3.4 units Connection Gas: 1 units average 3 units max. Trip Gas: units @ :HYDROCARBON SHOWS: None LITHOLOGY: Gravels / Conglomerate 46% Sand 45% Clay / Claystone 9% DAILY ACTIVITY SUMMARY: Unable to get response from LWD tool; P, IH with NB #1 and MWD tool; building BHA while running in hole; drill out conductor; Spud in hole; drill from bottom of conductor at 107' to report depth. · ~.::::~:,:::::~;~:::.::::,::::~:::.:::.:::~:::.:.:.:~:~:~:::::~:,::;,:~::;~:,x~:::::~:::~:~:::::::~ · · . ~ . ',:':':':':':':':':':'?:':':':' ::':':':': DATE. iVIARCH 26, 1996 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: Casing to Date. 16 at 107, 9 5/8 at 1815:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:. ~~;~;~:~;~;~;~:~:~;~;~:~;~:~;~:~;~;~;~;~;~;~;~;~;~;~:~;~:~~~~~;~;~;~~~:~~~:~:.:~;~;~:~:~:~~~~.~~~;~;~;~:~~~~~:~:~~~:~:~:~;~~~;~;~~~;~~~;~~~~;~;~~~:~;~;~:~~~~:~~~;~:~~~;~;~;~~~;~:~;~;~:~~~~~:~;~;~;~;~;~:~:~~~;~:~;~;~;~:~;~:~;~;~;~:~~~~~:~~~:~;~;~:~:~:~:~:~;~;~;G;G:~x:::;:;:;::::~::;:;:::}::;G};G:~}:~:{~}}:~;E:;: ::::::::::::::::::~:::::::::::::::::;:::::::::::::::::::::::::::::::::::::~::::,~::::::;::~::::::::::::::::::::::::::::::::::::~:::~:::::::::::;:::::::::::::::;:::::::::::::::::::::::::::::::::::::::::::::::;::::::::::::::::;:~::;:::;:::~:::::~:::::::;:::::::::::::::::::;::::::::::::::;::;:::::;::::::::::;::::::::::::::::::::;::::: ~::x~:~x~;q`;~;~;~q~:~;~;~;~:~;q~;~;~;q~;~;~;~x~;~``E~:~;`;~;~;q~;~x~x~:~;~;~;`;~q~;~:~:`:`;~;~;~;~;q~;~;~;~:~xq~;`:~:~:~:~:~;~;`;~:~;~``~:q~x~;~:~:~:~:~;~;~x~:~x~;~E~;~;~:~:~:~:~;~:~:~:~:~;~:~:~:~;~x~:~:~:~:~:~:~:~:~:~:`~:~:~x`;~:~;~;`;`:~;~;~`~:~:~:~ ::-~-;~;~::~::~:~;~:~;-:~::~::~:~;~:~;.~:~:~:~:~-~:;:;-:~:~:~:~:~::~:~::~-~:~::~:;:~:::~:6~;~:~:~:~:~:6;~;,:~;~:~:~:::~;~::~;~:~::;~;~:~:~:~;~:~:~:~:~;~;::~:::~:::~:~:~:.:,:~;::~;~;~;~:~;~;~;-~:~>::>>::X°:~X~>:44:x~>h>x<~X~x~>x->>: ~;~~~:~~~~~~~~.;~~~;~~~~~;~;~;~;~;~:~:.:~~~~~:~:~~~.~;~~~;~;~~~~~;~:~:~;`;~~~~~~~.~~~~~~~.~~~~~~~~~~~~~~~~~~`~.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.~~~~.~~~~.~~~~~~~~~~~~.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.~~~~~~~~~~~~~~~~~~~~~.~~~~~~~~~~~~~~~~~~~~~~~~~~~.~~~~~~~~~~~~~~~~~~:~~~~~~~~~~~~~~~~~~~~~ alT INFORi~t&TION: No. Size Type Serial No. Jets Interval Footage Hours Condition 1 12.25" MA1SL LE4718 15-15--10(center Jet) 107'-1825' 1718' 16.313 2-2-WT-A-C-1/8-NO-TD :!!:i:!:i:!:i:i:i:i:i:i:i:i:!:!:!:!:i:i:i:i:i:!:i:i:i:i:!:!:i:i:!:i:i:i:!:!:i:!:!:!:!:!:i:i:!:i:i:!:!:!:!:!:!:!:i:!:i:!:!:!:i:i:i:!:i:!:!:!:!:!:i:i:!:i:i:!:i:!:i:!:!:!:!:;:!:i:!:i:i:i:i:i:i:!:i:!:i:i:i:i:i:!:!:!:!:i:!:!:!:i:i:!:!:i:!:!:!:!:!:!:!:!:!:!:!:i:!:!:!:i:;:!:i:i:!:!:!:;:i:!:i:i:!:!:!:!:i:i:i:;:!:i:;:!:!:i MUD INFO: MW VIS PV YP GELS FL FO SOL OIL SD MBT pH Cl Ca+ Depth · 1825' 10.1 58 16 22 8134 14.2 2 8.9 0 0.5 25.0 8.7 2,750 20 :!;!;!!!ii:i!i!iii!;!iii;!:!!ii!i!;ii!;!;!ii!i;!:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:!~!:!:i:i:i:i:;~i:!:!~i:i:i:i:!:i:!:i:i:i:!:i:!~!:i:!..i:i:i:!:i:i..!..i3!:i:i:i:!:i:i:;:!:i-.i:i:!:!:i¢i:i:!:i:i:i:i:i:!:i:i:i:!:i:i:i:i:i..i:;:i:i:i:i:!:!:i:!:i:i:i:!:i:i:i:i:i:i:¢:i:i:i:!:i:i:i:i:i:i:i:i:i:i:::::::::::::::::::::::::i..i:!:i: BRILLIN6 PJt~aiIETERS: High Low Average Rate of Penetration 176.4 at 1583' 5.3 at 1407' 120.1 ft/hr Surface Torque 127 at 1641' 61 at 330' 108 Ft-lbs Weight on Bit 17 at 1181' 0.4 at 1593' 6 Klbs Bit RPM 126 at 1771' 119 at 1802' 124 RPM Pump Pressure 1525 at 1816' 577 at 1181' 1432 psi GAS SUMMARY: High Low Average Total Ditch Gas Out: [ 3.0 ~ at 1704' 0.9 at 1185' 1.5 units Methane (C-1) 616 at 1704' 180 at 1185' 311 ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: 5 at 1800' 1 at 1470' 3.4 units Connection Gas: 0.5 units average 1 units max. Tdp Gas: units @ HYDROCARBON SHOWS: None LITHOLOGY: Siltstone 36% Claystone 34% Sand/Sandstone 26% .Conglomerate 2% Pyrite fragments 2% DAILY ACTMTY SUMMARY: Drill from 1145' to 1825'; circulate bottoms up; do wiper trip to 980'; run back to bottom; circulate bottoms up; drop survey; POOH; lay down BHA; dg up to run casing; run 9 5~8" casing; shoe set at 1815'; make up circulating head; circulate while reciprocating casing. A R C O A L A S K A I N C. :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: TEMPTATION :~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:+:~:~:~:~:~:~:~:~:~:.:~:~:~:.:~:~:~:~:.:~:~:+:~:~:~:~:~:~:. :~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:.:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:+:~:~:~:~:~:::::::::::::::::::::::::::: DATE: MARCH 27, 1996 !:i:!:!:i:i:i:!:i:!:i:!:i:i:i:i:!:i:i:i:!:!:i:!:!:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:!:i:i:i:i:!:i:i:i:i Casing to Date: 16" at 107', 9 5/8" at 181:5!:i:i:i:!:!:!:!:!:i:i:!:!:i:i:!:i:i:i:i:i:!: ~~:.:~:~:~:~~~:~:~:~~~:~:.:~~~:~~~:~~~~~:~:~:~:~:~;~~~:~:~:~~~~~~~:~:~:~:~:~:~:~:~:~~~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~~~~~:~:~:~:~:~:~:~:~:~:~~~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~~~:~:~:~;~:~~~:~:`:~:~:~:~~~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~ :~i:::':':'~:~:~:' :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~ili i~ iifx!il ~i~i~ii!~ i~ ii i~ !ii~ !illin! ~i~i i! ~!i !~iiii!iiii~iii~i~ ii i~ii!i ~ ~i".~0.~.' :ti::iiiii::ii ii::!::iiii~0,~m,'i" '~i ................................................................i~~t,~<o,,~).:.:.:.:.:.:.:.:.:.:.: ................... o~s i'~:0';,',a; .~.:~.~.:.:~:.:~:~:~:.:.:.:.:.:~:.:.:.:~:~.:.:~:~:~:~:.:.~.:.:.:~:~:.:.:~:.:~:~:.:.:~:~:.:~:.:.:.:.:~:~:.:.:~:~:~:~:~:~:.:.:.:~:.:~:.:~:.:~:~:.:.:.:.:.:~.:.:.:.:.:.:.~.:~:.:.:~:~:.:~:.:.:~:.:~:.~.:~:.:.:.~.:~:.:~:.:.:.:~:~:.:.:.:.:~:.:.:.:.:~:.:.:.:~:.:.:.:.:.:.:~:.:.:.:.:.:.:.:.:.:.:.:~:.:.:.:~:.:.:.:.:~:~:.:.:~:~:~ ~:~:~:~:~:::::::~::~:~:::~::::2:~:~:~::::~::::~:::~::2:~::::::::~:~:~:~:~:::~:~:~:~::::::::~:~:~:~:::::~:~:::~:~:~:~:~:::~:~:::::~::~;:::2::::~:::::::~:::~::~::~::~:::::~:::~::::::::::::~:~::~::::::::::::~:::::::~:::::::~5~2:222::~:~22::2:2r:~:2::::::2:::2~2~2:22~:::2:222::: '~;;'~'~;~'~;";':' ~ii'~;"::: .... :'iiiii !ilii iiiiiiiii:~i; i~i';':~X:' ':'' ':':':' ':':'::' ':':iiii iii li !i! !i'~;"i~i' i "~"~ ':':':':':" ':' "':':':' ':':'""ii!ii i i !!i iii !iii!ii i i BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hours Condition I 12.25" MA1SL LE4718 15-15-10(center jet) 107'-1825' 1718' 16.31 2-2-WT-A-C-I/8-NO-TD ~:::i:i:!:!:!:i:!:!:i:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:i:!:!:i:!:i:i:!:!:!:!:!:!:i:!:i:i:!:i:!:!:!:!:!:i:i:i:i:i:!:!:!:!:!:!:!:!:!:!:!:!:i:!:!:i:!:i:!:!:!:!:!:i:i:i:i:!:!:!:!:i:i:i:!:!:!:i:!:i:!:!:!:!:i:!:!:i:i:i:i:i:i:!:!:!:!:!:i:i:!:!:!:!:!:!:!:!:!:i:!:!:!:!:i:i:!:!:!:i:i:!:i:i:i:i:i:i:!:!:!:!:i:i:i:i:i:i:i:!:i:i:i:!:!:!:i:i:!:i:!:: 'MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth · 1825' 10.2 43 15 13 3/8 10.4 2 9.4 0 0.5 22.5 9.1 2,700 20 DRILLING PARAMETERS: High Low Average Rate of Penetration at at fi/hr Surface Torque at at Ft-lbs Weight on Bit at at Klbs Bit RPM at at RPM Pump Pressure at at psi GAS SUMMARY: High Low Average Total Ditch Gas Out: I 3.0 I at While circulating 1.0 at 1.5 units Methane (C-1) at and reciprocating at ppm Ethane (C-2) at the 9 5/8" Casing at ppm Propane (C-3) at at ppm Butane (C-4.) at at ppm Pentane (C--5) at at ppm Total Cuttings Gas: at at units Gas: ~ units Wiper Gas: units Background Connection Gas: units average units max. Trip Gas: 3 units @ 1815' HYDROCARBON SHOWS: None LITHOLOGY: N/A DAILY ACTIVITY SUMIVIARY: Circulate while reciprocating 9 518" Casing; pump 10bbls water; pressure test the line to 3000psi; pump 10bbl water spacer; drop bottom plug; pump 100bbls 12.1ppg lead cement; pump 100bbls 15.7ppg tail cement; displace cement with rig pumps; bump plug at determined stroke count; rig up and do a top job; nipple down diverter system; do rig maintenance; nipple up BOPE; test BOPE, ?~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~-:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~~~:~:~:~:`:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:::~:~:~:::::::~:~:~:~:::::~:::::::::::::::::::::~:: BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hours Condition 2 8.5" HYCALOG SXTOB2F+6J LE4718 6-10 1825'- In Hole MUD INFO: MW ViS PV YP GELS FL FC SOL OIL SD MBT pH CI Ca+ Depth · 2200" 10.1 46 14 11 2/22 7.8 2 9.8 0 0.5 22.5 9.0 3,100 180 DRILLING PARAMETERS: High Low Average Rate of Penetration 153.0 at 1827' 9.2 at 2284' 87.4 fi/hr Surface Torque 127 at 2295' 32 at 1826' 87 R-lbs Weight on Bit 15 at 2303' 1 at 2062' 5 Klbs Bit RPM 362 at 2305' 204 at 1834' 307 RPM Pump Pressure 2245 at 2295' 1157 at 1835' 1831 psi GAS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 2229' 1.5 at 1828' 12.5 units Methane (C-1) 4460 at 2229' 290 at 1828' 2486 ppm Ethane (C-2) 79 at 2297' 0 at 3 ppm Propane (C-3) 33 at 2297' 0 at 1 ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm !Background Gas: ~ 6 ~ units Wiper Gas: units Connection Gas: 5 units average 10 units max. Tdp Gas: units HYDROCARBON SHOWS: None LITHOLOGY: Shale 29% Siltstone 25% Claystone 24% Tuff/Bentonite 12% Tuffaceous Claystone 8% Sandstone 2% DAILY ACTIVITY SUMMARY: Test BOPE; pick up NB #2 and BHA; RIH; ddll float collar; drill cement; drill out shoe and 10' new hole; circulate out; run Leak Off Test (13.1ppg equiv.); circulate; run second check LOT; break circulation; drill from 1835' to report depth. :i!il MORNING REPORT DATE: MARCH 29, 1996 i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:!:i:i:!:i:!:!:i:!:!:i:i:i:!:i:!:i:i:!:!:!:!:i:i~asing to Date: 16" at 107', 9 5/8" at 181§!:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:!:i:i:i:i: !MUD WT: li!iiiiiiiiiiiiiii}l':oR_MAT f: c to.o, Sh,de, S sto. ne,.,Tuff(Bent...o te)- I!iiiiiiiiii!iii!i)iiiilBKGRNP OAS:Sunits cma GAs: 2 un~s llii!iiiiiii!i!iiiitTR"' GAS: 2,'/.nits j!ii!iiiii!i!iiiiii!lMAXMJM GAS: t44 units DC EXPONENT: 0.92 EstPOREPRESSURE: 9.10 Iiii!ii!iiiiiiiiiiiit,OP{~HALE): 10o, o ..... :::::::~:~:~:~:~:::::~::~:::~::::::::~:::::~::~:~:::::::~¥~¥:~.:~:~:~:~:.:~:.:.:~:~.~:.~:~:~:~:~:.:~:~:~:.:.:.~:~:~:~:~:~:~:~:.:~:~:.:.:.~:~:~:.:~ BIT INFORMATION: No. Size Type Serial No. Jets 2 8.5" HYCALOG SX70B2FT+6J 17338 6-10 Interval Footage Hours Condition 1825'- In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH CI Ca+ Depth · 3300'., 10.1 42 .. 14. 11 2/28 7.0 2 9.4 0 0.25 20.0 9.5 2,200 60 !ii!i iii i iii!ii !ii!ilili !! iii!i il i ii!!!iiii!:! :E i! i!ii iii! ii !i i!iEii!!iiii:!:! :i:!:i:i :!:i :i:i:i:i:i:i:i:i:i:i :i :i:i:!:i:!:i:!:i:!:i :i :! :!:i :!:i :!:!:!:! :! :i:i:! :i:!:i:!:i:! :!:i:i :i :!:i:!:i:i :!:i:i:!:!:!:i:i :i:! :!:i:i :i :!:i:!:!:i :i :i:i:i :i :!:! :!:i:i :! :i:i:i3 i:i:i:i:i:i :!:i:! :i :i :i:i:i :i:i :i :i3i :i :i:!:! :i 3i:i:i :i:i:i :i :i :i :i: DRILLING PARAMETERS: Rate of Penetration Surface Torque Weight on Bit Bit RPM ~ump Pressure High Low Average 164.9 at 2466' 9.5 at 3373' 106.2 fi/hr 150 at 3187' 20 at 1826' 98 R-lbs 13 at 2569' 1 at 2062' 5 Klbs 370 at 3335' 262 at 1834' 358 RPM 2549 at 3187' 913 at 2470' 2176 psi ., High Low ,.~AS SUMMARY: Average Total Ditch Gas Out: I 't44.0 ~ . at 2992' 3.6 at 2842' 36.9 units Methane (C-1) 26578 at 2992' 720 at 2825' 6597 ppm Ethane (C-2) 762 at 3022' 0 at 102 ppm Propane (C-.3) 655 at 2380' 0 at 40 ppm Butane (C-4) 309 at 2380' 0 at 9 ppm Pentane (C-5) 12 at 2993' 0 at 0 ppm Total Cuttings Gas: 118 at 2760' 4 at 3420' 17.4 units Background Gas: ~ .......... ~'l~ii~ ....................................................... ~p~r; ~i ........... 2~ .....U'r~ii~'"@ ..... 32~; ............. Connection Gas: 2 units average 74 units max, Trip Gas: units @ HYDROCARBON SHOWS: None LITHOLOGY: Claystone 41% Siitstone 27% Shale 21% Sandstone 6% Tuff/Bentonite 5% DAILY ACTIVITY SUMMARY: Drill form 2337' to 2495'; circulate out; do 7 stand wiper trip; drill from 2495' to 3277'; circulate out; do 10 stand wiper trip; drill from 3277' to report depth. ~:i:i:i::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::i:i:i:!:i:i:!:i:i:i:!3i:i:i:i:i:i:i:~::i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: EPOCH WELL LOGGING ::: ........................................... ::2::;::::2:::::2::::: MUD WT: ·:-:':-:-:':-:.:':':':':-:-:':':':':':':':':':. Est PORE PRE$~JRE: 9.10 li::!ii::i::i::!::i::iil}it.ROP <~IALE}: ~30.0 ....... f::i::i::i!ii!::i::i::i::l'~O~._. ~$ .AND_)_: !35_ft/hr . . . ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :.:~:~:.:.~~~.:.:~:~:.~~:~:.~~:.:.:.:~:.~.:~:.:~:.:.:.:.~.~.:.:~:.~~~.:.~.~.:.:~:.:~:~:.:.:.~.:~~~:.:.:.:.:.:.:.:.:~:~~.:~:.:.:~:.:.:.:.:.:.:~:~:.~~:.~.:.:.:.:.:.~.:.:.:~:.:.:.:.:.:.:.~.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:~:.:~:~:~:~:.~~:.:.:.:.:.:~:.:.~.:.:. BIT INFORMATION: No. Size Type Sedal No. Jets Interval Footage Hours Condition 2 8.5" HYCALOG SX70B2FT+6J 17338 6-10 1825'- In Hole iMUD INFO: MW VIS 13%/ YP GELS FL FC SOL OIL SD MBT pH Cl Depth' 3300' 10.3' 41 13 9 2/14 6.6 2 10,9 0 0.25 19.0 8.6 2,100 DRILLING PARAMETERS: High Low Average Rate of Penetration 180.5 at 4406' 12.5 at 3842' 130.6 PJhr Surface Torque 245 at 4455' 51 at 3843' 172 Ft-lbs Weight on Bit 10 at 3942' 0.2 at 4458' 4 Klbs Bit RPM 375 at 4467' 276 at 3849' 367 RPM Pump Pressure 2782 at 4456' 1547 at 3849' 2504' psi High Average GAS SUMMARY: Low Total Ditch Gas Out: ~ at 3907' 12.1 at 3840' 55.8 units Methane (C-1) 49404 at 3857' 1154' at 3839' 8934 ppm Ethane (C-2) 1567 at 4070' 9 at 3838' 360 ppm Propane (C-3) 1121 at 4448' 0 at 163 ppm Butane (C-4) 655 at 4070' 0 at 77 ppm Pentane (C-5) 234 at 3856' 0 at 13 ppm Total Cuttings Gas: 120 at 4080" 8 at 3540' 41.9 units Background Gas: ~ units Wiper Gas: 56 units @ 4811' Connection Gas: 2 units average 10 units max. Trip Gas: units @ HYDROCARBON SHOWS: Trace to poor show at several small sand intervals from 3850' to 3990'; very fine sandstone, gradational to siltstone; mostly very poor visible porosity; moderate petroleum odor; heavy gases through pentane; 10% oil sheen on blendor sample; no oil pops from mud; 5% dull brownish gold sample flourescence; very slow streaming medium yellow cut fluorescence; dull yellowish gold residual fluorescence. LITHOLOGY: Claystone Siltstone Shale Sandstone 66% 16% 13°,(, 5% DAILY ACTIVITY SUMMARY: Drill form 3432" to 3839'; circulate out; do wiper trip to shoe; cut and slip drill line; drill from 3839' to 4811'; circulate out; do 10stand wiper trip; drill fi.om 4811' to report depth. BIT INFORMATION: No. Size Type Serial No. Jets 2 8.5" HYCALOG SXTOB2FT+6J 17338 6-10 Interval Footage Hours Condition 1825'- In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH CI Ca+ Depth: 6150' ., 10.2 41 13 11 3/11 6,2 2 10.4 0 0.25 17.5 9.0 1,700 20 DRILLING PARAMETERS: High Low Average Rate of Penetration 172.8 at 5779' 40.2 at 4854' 109.4 ft/hr Surface Torque 284 at 6314' 114 at 5586' 206 Ft-lbs Weight on Bit 12 at 5308' 0.5 at 5559' 5 Klbs Bit RPM 376 at 4856' 314 at 6013' 351 RPM Pump Pressure 2823 at 6078' 2258 at 5560' 2586 psi GAS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 5830' 7.3 at 4852' 55.8 units Methane (C-1) 57932 at 5830' 1142 at 4852' 7809 ppm Ethane (C-2) 1810 at 5830' 28 at 4852' 283 ppm Propane (C-3) 3292 at 5830' 8 at 4852' 197 ppm Butane (C-4) 1813 at 5830' 0 at 95 ppm 'Pentane (C-5) 608 at 5830' 0 at 21 ppm Total Cuttings Gas: 90 at 5700' 8 at 5390' 22.4 units Background Gas: ~ units Wiper Gas: 44 units @ 6336' Connection Gas: 10 units average 20 units max. Trip Gas: units @ HYDROCARBON SHOWS: Trace to poor show at several small sand intervals from 5600' to 5900'; very fine sandstone, gradational to siltstone; poor to good visible porosity; moderate petroleum odor; heavy gases through pentane; light oil sheen on blendor sample; no oil pops from mud; 2-20% bright yellow sample flourescence; instant bright blooming and streaming yellow to yellowish white cut fluorescence; pale to bright yellow residual fluorescence; faint straw cut in plain light. 63% 14% 13% 10% LITHOLOGY: Claystone Shale Sandstone Siitstone DAILY ACTMTY SUMMARY: Drill from 4829' to 5558'; circulate out; do wiper trip; drill from 5558' to 6336'; circulate out; do wiper trip. ..................................................................................................................................................................... o.3 C' One ....... GAS: :.:.:.: .................................................................................................................................................................. .................................................................................. ........................................... :: .......................................... : .... :..::...: ....................... :~:~:~:.:.:~:~]~:~:~:.:.:~:~:.:~:~:~:~:~:~:~:~:~:~:~:.~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:.:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~ BIT INFORMATION: No, Size Type Serial No. Jets 2 8.5" HYCALOG SX70B2FT+6J 17338 6-10 Interval Footage Hours Condition 1825'- In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH CI Ca+ Depth' 7541' 10.3 43 14 16 5/12 5.0 2 11.4 0 Tr 22.5 9.1 1,300 40 DRILLING PARAMETERS: High Low Average Rate of Penetration 148.8 at 6463 7.2 at 7795' 89.0 t'dhr Surface Torque 2844 at 7372' 107 at 7056' 215 Ft-lbs Weight on Bit 16 at 7034' 1 at 6888' 7 Kibs Bit RPM 372 at 7156' 313 at 7025' 349 RPM Pump Pressure 2929 at 7245' 2237 at 6337' 2776 " GAS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 7175' 20.4 at 7394' 49.1 units Methane (C-1) 57954 at 7175' 3003 at 7394' 8533 ppm Ethane (C-2) 4319 at 7175' 186 at 6388' 523 ppm Propane (C-3) 5602 at 7175' 98 at 6493' 492 ppm Butane (C-4) 2679 at 7175' 0 at 6493' 243 ppm Pentane (C-5) 611 at 7175' 0 at 7155' 47 ppm Total Cuttings Gas: 270 at 7420' 10 at 6400' 54.5 units !iii!i:i!iiii!!!:!:i!!ii:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:!:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:!:!:i:!:i:i:!:i:!:!:i:i:i:!:i:i:i:i:i:!:i:i~:i:i:!:i:i:i:!:!:i:!:!:i:i:i:i:i:i:!:i:i:!:!:i:i:i:i:!:i:i:!:i:i:!:i:!:!:i:!:i:!:i:!:!:!:!:!:!:i:i:!:i:i:!:!:i:i:i:i:i:i:!:!:i:!:!:i:i:!:i:i?i:i:i:i:!:i:i:i:!:i:!:!:i:i:i:i:i:i:!:i:?i Connection Gas: 6 units average 10 units max. Trip Gas: units @ HYDROCARBON SHOWS: Good show at 7400' to 7500'; very fine quartz arenite sandstone; strong petroleum odor; pale straw cut in plain light; bright instant yellowish white cut fluorescence with fast blooming and streaming; bright gold residual ring fluorescence; It brown ring in plain light; common pops in washed sample, LITHOLOGY: Shale 62% Sandstone 26% Siltstone 11% Claystone 1% DAILY ACTIVITY SUMMARY: Drill from 6336' to 7156'; circulate out; do wiper trip; drill from 7156' to report depth. ii:.EP0.cb.Pe.r.s..°n. ne!.°,n..s.!t.e:....4 ........ iiiii::?:iiiiiiiii!i::i::i::iiiii::iiiiiilil'ARCO SUPERVISOR: Dave Bumgarner [i?iiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiii!iiii Report by: Craig Silva ...................................................................................................................................................................... lVlUD WI': 10.2 t!iiiiiiiiiiiiii}i[IFORMATION: Siltstone. m~,, Sandstone li!!iiiii!!i!iiiiiiiiiitBKeRND...................... GAS: 40units ;.;::....:.::......:.......................;,......... .......................................................................................................................................... · ..~....._.............. ....................................................................................................................................................... BIT INFORMATION: No. Size Type Serial No. Jets 2 8.5" HYCALOG SX70B2FT+6J 17338 6-10 Interval Footage Hours Condition 1825'-7750' 5925' 68.718 2.3-CT,BT-A-In-No.TD MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth' 7750' 10.2 42 13 14 4114 5.0 2 11.4 0 Tr 22.5 8,8 1,200 40 DRILLING PARAMETERS: High Low Average Rate of Penetration 131.0 at 7669' 28.8 at 7662' 87.6 fi/hr Surface Torque 285 at 7672' 224 at 7750' 257 Ft-lbs Weight on Bit 7 at 7667' 2 at 7682' 4 Klbs Bit RPM 359 at 7741' 343 at 7701' 350 RPM p.u.m.p...p.re.s.s..u.r.e' ............................ .3..04..9. .... .at .... 7..7.21.'' ............. 2690 at 7587' 2888 psi GAS SUMMARY: High . Low Average Total Ditch Gas Out: ~ at 7592' 28.1 at 7750' 51.4 units Methane (C-1) 7446 at 7727' 3220 at 7749' 5462 ppm Ethane (C-2) 471 at 7592' 199 at 7749' 325 ppm Propane (C-3) 583 at 7592' 231 at 7749' 356 ppm Butane (C-4) 432 at 7592' 130 at 7632' 219 ppm Pentane (C-5) 55 at 7592' 2 at 7750' 20 ppm Total Cuttings Gas: 22 at 7710' 18 at 7750' 19.3 units B~kg'round Gas: ~ units Wiper Gas: 120 units Connection Gas: units average units max. Tdp Gas: units 7750' SHOWS: Trace show in very fine sandstone from 7587' to 7640'; fair visible porosity; heavy gases through pentane; no mud pops; Tr-2% bright yellow sample fluorescence; fast blooming and streaming moderately bright yellow cut fluorescence; very faint straw cut in plain light; pale to bright gold residual fluorescence. LITHOLOGY: Siltstone Shale Sandstone 63% 31% 6% DAILY ACTIVITY SUMMARY: Drill from 7586' to 7750' (TD); circulate bottoms up; do wiper trip to shoe; run back to bottom; circulate bottoms up; POOH; rig up Schlumberger and run wireline logs. SUPERVISOR: Dave Bumgarner :.:-: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: M O R N i N G R E P O R T ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: DATE: APRIL3, 1996 !:!:!:!:i:!:!:!:!:i:!:!:i:!:!:!:!:!:i:!:!:i:!:i:!:!:!:!:!:!:!:!:!:!:i:!:i:!:i:!:!:i:i:i:i:!:!:!:i:i:i~asing to Date: 16" at 107', 9 5/8' at 181§!'!'!'!'!'!'!'!'!'!'!'!'!'!'}'!'!'!'i'! CO~ ~: ~A ~ GAS:. ~, ~: "O ~s I DC E~ON~T: ~A BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hours Condition MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth · 7750' 10.2 55 16 20 5~25 4.8 2 11.5 0 Tr 25.0 8.4 1,000 60 DRILLING PARAMETERS: High Low Average Rate of Penetration at at fi/hr Surface Torque at at Ft-lbs Weight on Bit at at Kibs Bit RPM at at RPM pump Pressure at at GAS SUMMARY: High Low Average Total Ditch Gas Out: 80L~.o at Tdp Gas 8,0 at 30,0 units Methane (C-1) at at ppm Ethane (0,-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: at at units Background Gas: ~' units Wiper Gas: units @ Connection Gas: units average units max. Trip Gas: 80 units @ 7750' HYDROCARBON SHOWS: N/A LITHOLOGY: N/A DAILY ACTIVITY SUMMARY: Run Schlumberger wireline logs; rig down Schlumberger; move I-IWDP to other side of derrick; RIH with muleshoe; pick up ddll pipe while running in; run to bottom; circulate bottoms up; circulate and clean hole prior to cementing. ARCO ALASKA ~,~:' APRIL 4, 1996 DEPTH: 1815' Yesterday: MUD WT: 10.2 't!i!i!i!!ii!i!i!i!iIFORMATION: I~A CON. GAS: N/A jiii::iii::iiiiiiiiiitTRIP GAS: N/A .............. ~ :.'.-:.:.:.:-:-:.:.:.:-:.:.'..:.:.:.:.:-:.:::: ' :.: 7750' 24 Hour Progress: __ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: BKGRND GAS: 3 units EXPONENT: N/A :.:.; BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hours Condition MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH CI Ca+ Depth · 7750' 10.2 55 16 20 5125 4.8 2 11.5 0 Tr 25.0 8.4 1,000 60 DRILLING PARAMETER, S: High Low Average Rate of Penetration at at E/hr Surface Torque at at Ft-lbs Weight on Bit at at Klbs .Bit RPM at at RPM 3ump Pressure at at psi GAS SUMMARY: High Low Average Total Ditch Gas Out: ~ at While circulating 2.0 at 7.0 units Methane (C-1) at after setting the at ppm Ethane (C-2) at lower plug. at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (0,-5) at at ppm Total Cuttings Gas: at at units Background Gas: ~ 3 ~ units Wiper Gas: units Connection Gas: units average units max. Trip Gas: units HYDROCARBON SHOWS: N/A LITHOLOGY: N/A DAILY ACTIVITY SUMMARY: Circulate and clean hole; continue with plug and abandon procedures; set three plugs total, with the top plug through an interval above and below the shoe; lay down dd{I pipe when pulling out of hole after each cement job; POOH; test BOPE. ARCO ALASKA INC. TEMPTATION NO. 1 DRILLING TIME SCHEDULE DEPTH VS TIME -2 -4 -6 -8 -10 DEPTH (THOUSANDS) ,.2DRILL OUT 16" SHOE 1/4" BIT 3-25-96 ............ --_ ....................................................... RUN 9 5/6'1 CASING AT 1815' "HOLE ~ RAN SCHLUMBERGER E-LOGS AT TOTAL DEPTH ..,. ~ TOTAL DEPTH: 7750' REACHED ON 4-02-96 0 1 2 3 4 5 6 7 8 9 10 11 DAYS 3-24-96 to 4-01-96 EPOCH WELL LOGGING INC. [CORE I CORE LABORATORIES BASIC ROCK PROPERTIES ARCO ALASKA, INC. TEMPTATION NO. 1 WELL GO¢~F~DENTIAL p~.r ~,0~CC r~.~. 20 AAC 25.537 FINAL REPORT Performed for: ARCO ALASKA, INC. 700 G Street, Rm: ATO1450 Anchorage, Alaska 99501 April 26, 1996 ORIGINAL Date Pe~ormed by: ~~~ Core ~boratories, Inc, Rock Pro~ies Laborato~ Dallas Advan~d Technology Center Ca~ollton, Texas 75006 File: DAL-95099 PETROLEUM SERVICES April 26, 1996 Ms. Rene Hannon ARCO Alaska, Inc. 700 G Street Rm: ATO1450 Anchorage, Alaska Subject: CMS-300TM Permeability and Porosity of Core Samples Temptation No. 1 Well File: DAL-96099 Dear Ms. Hannon, Please find enclosed the results of basic rock properties testing performed on twenty-one 15/16 inch diameter rotary core plug samples delivered to our laboratory for analysis. A description of laboratory procedures is included with the testing results. Preliminary data was provided by fax on April 17, 1996. The plug samples were returned to the client on April 24, 1996. We appreciate the opportunity to have been of service to ARCO Alaska, Inc. If you have any questions or if we may be of further assistance, please call us at (214) 466-2673. Sincerely, Daniel J. S~ ~ Rock Properties Laboratory Dallas Advanced Technology Center Core Laboratories, Inc. 1875 Monetary Lane, Carrollton, Texas 75006-7012, (214) 466-2673, Telex 163166, CORDAL UT, Fax (214) 323-3930 ARCO Alaska, Inc. File: DAL-96099 PROJECT PARTICIPANTS Basic Properties Jol~ A. Kieschnick Data Evaluation Report Preparation Final Review Melanie F. Dunn Core Laboratories ARCO Alaska, Inc. File: DAL-96099 BASIC ROCK PROPERTIES Analytical Procedures Sample Preparation and Analysis . Twenty-seven 15/16 inch diameter rotary plug samples were received for testing. Each sample was removed from its shipping bottle and dry trimmed to form a right cylinder plug. Two samples were not right cylinders and as a result only porosity and extraction data could be obtained. Six samples contained only enough material for a general description. Each sample was assigned a number and checked for fluorescence, then weighed to the nearest 0.01 grams. The samples were then loaded into a pre-boiled Dean-Stark apparatus for distillation to determine residual fluid saturations. Each set of Dean-Stark glassware was sealed with Teflon tape to prevent leakage and capped with desiccant to prevent the introduction of condensed atmospheric water. Water volume in each Dean-Stark receiving tube was monitored during the toluene refluxing until stabilization. A wire was used to swab off any water droplets from the neck of the condenser. A record of time and water volumes was kept for each sample. Extraction time for each sample was approximately 30 hours. After Dean-Stark distillation the samples were placed in a vacuum oven at a temperature of 140°F for twenty-four hours. . After the samples cooled, weights were determined. The length and diameter of each sample were measured with digital calipers. Grain volumes were measured in a matdx cup at ambient conditions by the AutoPorosimeterTM using Boyle's law, with helium as the gaseous medium. Grain density was calculated for each sample using the dry sample weight and grain volume data. During these procedures, exposure to the atmosphere was minimized to preclude absorption of moisture. . Permeability and porosity were measured on the right cylinder plugs with sufficient length using the CMS-300TM at 800 psi confining stress. A standard system leak test of the CMS-300TM was performed before testing to ensure correct equipment operation. A calibrated, known volume check cylinder and a known permeability check plug were run with each carousel suite of samples. The Klinkenberg (slip corrected) permeability for each plug sample was determined as a function of pressure decay (helium blow-down). A reference cell of known volume charged the sample with helium. A downstream valve vented the sample to atmosphere, and the change in pressure with time was monitored. The multiple flow regime data allowed the determination of Klinkenberg permeability of the sample, a 'calculated air permeability (Kair), along with parameters helium slip factor (b) and the Forcheimer inertial resistance factor beta (1~). Porosity for each plug sample was calculated using Boyle's law by the CMS-300TM with grain volume and pore volume by: Porosity, percent = Vp * 100 Vp+ Vg Where: Vp = Pore volume at net confining pressure (cc) Vg = Grain volume (cc) Core Laboratories ARCO Alaska, Inc. File: DAL-96099 Samples with insufficient length for the CMS-300TM were measured for permeability using the steady- state permeameter, AutopermeameterTM, at a hydrostatic overburden equivalent to the CMS-300TM at 800 psi net overburden (minimum confining stress). Ambient porosities for the odd shaped and short plugs were determined by: Porosity, percent = Vb- V!::I * 100 Vb Where: Vb '- Bulk Volume measured by Mercury Immersion (cc) Core Laboratories ARCO Alaska, Inc. File: DAL-96099 CMS-300 QUALITY CONTROL DATA Net Confining Stress: 800 psi QC Sample Porosity, fraction Number measured I actual RPD 25-5 3.204 3.204 0.0 QC Sample Permeability to Air, millidarcys Number measured I actual RPD 328B 7.27 7.25 0.3 RPD (relative percent difference) = absolute value ((actual value-measured value)/actual value * 100) Acceptance criteria for porosity'= +/- 0.5 porosity units Acceptance criteria for permeability in this range = +/- 5% 25-5 pore volume = 3.204 Core Laboratories iO00.O Permeability vs~ Porosity O.Ot iO .0 ~LOg(Y) ' 0.'64' # X - ':"4'' t8.4 ~i. 2 24 Law He)- ~ ARCO Alaska, lnc, Temptation No. I (7t75-7476 feet) - LEGEND - Colv~lle Delta ARCO Alaska, Inc. Temptation No. I Well Colville Delta Exploration CORE ANALYSIS RESULTS (CMS-300 Hydrostatic Confinement) File: DAL-96099 17-April-1996 Rotary Net Overburden Pressure: 800 psi Dean Stark Rotary Plug Permeability Grain Saturation Core Depth, Klinkenberg,I to Air, Porosity, Density, Oil I Water, Number feet millidarcysI millidarcys percent gm/cc percent PVI percent PV Description Rotary Core Analysis Data 1 7175.0 218. 22.1 2.79 18.1 47.6 2 7176.9 34.7 17.1 2.88 20.5 47.5 3 7179.0 119. 22.0 2.70 2.4 62.5 4 7181.0 151. 166. 23.6 2.71 19.3 56.7 5 7375.9 Insufficient Sample 6 7380.1 0.389 0.560 12.2 2.65 8.3 30.2 7 7390.0 0.099 0.166 11.7 2.65 10.0 70.0 8 7395.0 0.033 0.066 8.5 2.79 0.0 48.0 9 7400.0 2.84 14.0 2.66 25.1 62.2 10 7402.0 Insufficient Sample 11 7403.9 3.02 14.6 2.65 10.5 61.4 12 7406.0 0.971 1.27 12.8 · 2.65 15.6 66.0 13 7408.0 Insufficient Sample 14 7410.1 0.438 12.6 2.66 14.3 66.5 15 7411.8 1.57 2.08 14.3 2.64 15.0 57.2 16 7414.0 9.55 10.8 16.3 2.63 18.5 57.5 17 7416.1 2.80 14.4 2.65 21.5 54.4 18 7418.0 Insufficient Sample 19 7420.0 2.04 15.4 2.64 22.0 57.9 20 7422.0 1.85 2.29 14.1 2.64 21.7 55.3 21 7424.0 0.618 0.845 13.0 2.65 28.0 56.1 22 7426.1 Insufficient Sample 23 7434.0 * 8.1 2.68 18.0 87.5 24 7444.0 0.065 0.115 10.1 2.65 · 17.7 69.6 25 7455.0 0.089 10.4 2.64 9.5 83.5 26 7466.0 * 13.2 2.66 19.9 52.2 27 7476.0 Insufficient Sample 'Not suitable for permeability measurements. Sst tn-bm m gr even gld fluor Sst bm m gr even gld fluor Sst bm m gr even dull gld fluor Sst bm vf gr even dull gld fluor SSt bm vf gr spty gld fluor Sst tn f gr mott dull gld fluor Sst tn-bm f gr mott dull gld fluor Sst tn f-vf gr mott dull gld fluor Sst bm f gr mott brt gld fluor Sst bm m-f gr even dull gld fluor Sst tn m gr strky gld fluor Sst bm-tn f gr even gld fluor SSt It bm m gr mott dull gld fluor SSt tn f-m gr mort dull gld fluor SSt It bm f gr mott dull gld fluor SSt bm f gr mott gld fluor Sst It bm f gr even gld fluor Sst bm sli arg f gr even gld fluor Sst bm m gr even gld fluor Sst tn f gr strky gld fluor Sst bm f gr sli arg strky gld fluor SSt dk bm arg f gr no fluor SSt tn f gr mott v/dull gld fluor SSt It gry-bm f-vf gr mott dull gld fluor Sst gry-bm vf gr mott gld fluor Sst gryish bm f gr strky brt gld fluor SSt bm f gr spty gld fluor Core Laboratories Date: 4/22/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL: TEMPTATION %1 WELL ID: AX9365 AFC: AX9365 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: WILDCAT SPUD: START COMP' RIG:NO RIG BLOCK' FINAL: TIGHT HOLE API NUMBER: 50-103-20233-00 03/17/96 (1) TD: '( 0) SUPV:DBS 03/18/96 (2) TD- '( ) SUPV:DBS 03/19/96 (3) TD: ' ( ) SUPV: DBS 03/20/96 (4) TD: '( ) SUPV:DCB 03/21/96 (5) TD: 110'( 0) SUPV:DCB 03/22/96 (6) TD' 110'( 0) SUPV'DCB 03/23/96 (7) TD: 110'( 0) SUPV:DCB 03/24/96 (8) TD: 110'( 0) SUPV:DCB 03/25/96 (9) TD' 1280' ( 1173) SUPV:DCB 03/26/96 (10) TD' 1825' ( 545) SUPV:DCB 03/27/96 (11) TD' 1825'( 0) MW: PV/YP: APIWL: RIG DOWN MOVE TO TEMPTATION %1 Rigging down to move to another loaction. MW: PV/YP' RIG DOWN- MOVE TO TEMPTATION #1 Continue to rig down for move. MW: PV/YP: APIWL' RIG DOWN- MOVE TO TEMPTATION %1 Continue to rig down for move. Begin moving to Temptation. MW: PV/YP: APIWL: RIG UP AT TEMPTATION Mi Move components from Neve %1 to Temptation %1. Continue rig up of drawworks and first derrick components. MW" MIRU R/U derrick. PV/YP- APIWL: MW: PV/YP: MIRU Continue to R/U derrick. MW: PV/YP' APIWL- R/U FLOOR AND UTILITIES Continue to R/U floor and pits. MW: 9.5 PV/YP: 20/40 APIWL: 14.8 WORK ON PUMPS/SCR Function test diverter system and Koomey unit test. Held pre-spud meeting. MW' 9.8 PV/YP: 7/57 APIWL' 16.9 DRILLING 12-25" SURFACE Drilling surface hole from 107' to 1280' MW: 10.1 PV/YP: 16/22 APIWL: 14.2 CEMENT 9-5/8" CASING Drilling surface hole from 1280' to 1825'. Run 9-5/8" casing. Cement surface casing. MW: 10.2 PV/YP: 15/13 APIWL: 10.4 INSTALL WEAR BUSHING SUPV:DCB 03/28/96 (12) TD: 2375' ( 550) SUPV:DCB 03/29/96 (13) TD: 3560'( 1185) SUPV:DCB 03/30/96 (14) TD: 4966'( 1406) SUPV:DCB 03/31/96 (15) TD: 6462'( 1496) SUPV:DCB 04/1/96 (16) TD: 7750'( 1288) SUPV:DCB 04/2/96 (17) TD: 7750'( 0) SUPV:DCB 04/3/96 (18) TD: 7750'( 0) SUPV: DBS 04/4/96 (19) TD: 1650'( 0) SUPV:DBS Cement surface casing. CIP @ 0735 hrs. 3/26/96. N/U BOPE. Test BOPE 300/3000 psi. MW: 10.1 PV/YP: 14/11 APIWL: 7.8 DRILLING 8.5" HOLE Pressure test casing to 2500 psi, hold 30 min. Lost 25 psi, good test. Drill FC, good cement and FC, 10' new hole to 1835'. Perform leakoff test. Drilling new hole from 1825' to 2375' MW: 10.1 PV/YP: 14/11 APIWL: 7.0 DRILLING 8.5" HOLE Drilling from 2375 to 3560'. MW: 10.3 PV/YP: 13/9 APIWL: 6.6 DRILLING 8.5" HOLE Drilling from 3560' to 4966'. MW: 10.2 PV/YP: 13/11 APIWL: 6.2 DRILLING 8.5" HOLE Drilling from 4966' to 6462' MW: 10.3 PV/YP: 14/16 APIWL: 5.0 CIRCULATING @ TD Drilling from 6462' to 7750' MW: 10.2 PV/YP: 13/14 APIWL: 5.0 LOGGING W/SCHLUMBERGER Run %1, triple combo DSI/CNL/FDT/GR/CAL. Log TD 7750 ±, OK w/driller TD. MW: 10.2 PV/YP: 16/20 APIWL: 4.8 POH 7 STDS TO 7100' Log GR/RFT. RIH w/rotary sidewall and log. TIH with 5" DP and mule shoe to TD at 7750' Pump %1 cement plug. POH w/ 5" DP to 7100' and prepare to spot %2 plug. MW: 10.1 PV/YP: 15/14 APIWL: 7.6 PREP. TO PICK UP BHA #4 Wash from 7091'-7300'. Pump cement. CIP. Spot plug %3 from 2100'-1650'. Test BOPE to 250/3000 psi. PAG~ NO~ ~ ,m**~***** 9]RVEY PROGRAM *~**~***~* COMPANY ARCO ALASKA W~LL ~qME TEMP ~! LOCATION ! COLVILLE RIVER LOCATION 2 ~UDHOE BAY~ NSB~ AB: MAgNETiC DECLI~T!ON 26.61 ~ID [~G~E ~GLE 0,~ W~ HU~ 0 WELL H£A~ LOCATION: LAT(NT-S) 0,00 AZIMUTH ~:OM ROTARY TABLE TO TARGET IS TIE iH POINT(TIP) : MEAS'~ED DEFg'H 1!0.00 TRUE VERT DEPTH 110,00 INCLINATION 0,00 AZIMUTH 0.00 LATITUDE(N/-S) DEPARturE (Ei-W) 0,00 DEP(E/-W) 0.00 ******~ ANADRILL ~=~=~* SL~RVEY CALCULATIONS ............. CIRCUbqR ARC M~A~ iNTeRVAL VERTICAL DB~H D:EPTH ft ft ft 110.00 0.0 110.00 238.79 128.8 2~,79 324,97 86,2 324,97 418,10 ~,! 418,0~ 507,48 89,4 507,47 TARG~ STATION. AZIMb'tH LATITUDE S)~C?ION I~LN, N/-S ft ~ deg ft 0,00 0.00 0.00 0,00 -0.62 0.57 194.42 -0o62 -1.27 0.3~ 217.15 -1,27 -1,49 0,29. 277,08 -1.49 -1,54 0,43 258,11 -1,54 D£PAR?U~ I)I~LACBIk'NT at E/-W ft ft 0,00 0,00 -0,16 0,64 -0.44 1.35 -0,87 1,73 -1,42 2,09 AZIittttH deg 0,00 194,42 199,24 210.09 222,72 DLS deg/ lOOft 0.44 0.30 0.37 0,21 598,63 687,61 777.33 867,50 965,42 91.1 598,62 89,0 687,60 89,7 777,32 90,2 867.49 97,9 965,41 -1,70 0,23 239,52 -1,70 -1,76 0,20 282,46 -1,76 -1,79 0,15 232,01 -1,79 -1,89 0,12 250,88 -1,89 -1,03 0,18 309,73 -1,83 -1,91 2,56 228,37 0.25 -2,22 2,83 231,65 0,18 -2,46 3,05 233,% 0,17 -2,64 3.25 234,37 0,05 -2,86 3,39 237,38 0,16 1051,18 1t42,06 1235,77 1328,90 1422,91 85,8 1051,16 90,9 1142,05 93,7 1235,76 93.1 1328,89 94,0 1422.90 -1.5I 0,35 331,75 -1,51 -1.19 0,15 51,44 -1,19 -0,91 0,29 28,96 -0.91 -0,58 0,15 352,42 -0,58 -0,45 0.04 289,23 -0,45 -3.08 3,43 243,94 0.23 -3.13 3,34 249,18 0,39 -2.92 3.06 252,74 0.18 -2,82 2,88 258,40 0,21 -2.87 2,?0 261,17 0,14 1516,26 1611,23 1707,99 1798,24 1888,66 93,3 1516,25 95,0 I611,21 96,8 1707,98 ~,2 1798,22 ?0,4 1888,65 -0,34 0.14 32,47 -0,34 -0,02 0,34 40,94 -0,02 0.33 0,18 31,70 0,33 0,58 0,18 25,74 0,58 0,57 0,40 243,32 0,57 -2,84 2,86 263,23 0,17 -2,59 2,59 269,52 0.22 -2.31 2,34 278,10 0,17 -2,18 2,25 284,97 0,03 -2,39 2,46 283,43 0,61 1983,72 2O77,52 2158.22 ~49,78 2346,96 95,I 1983,71 93,8 ~77,50 80.7 2158,2O 91,6 2249,76 97,2 2;q6,93 0,69 0,36 25,32, 0,69 0,87 0,40 254,52 0,87 0,66 0,34. 124,55 0,66. 0,29 0,40 133.64 0,29 -0.25 0,43 148,33 -0,25 -2,56 2,65 285,18 0,75 -2.74 2,88 287.68 0.73 -2,81 2,89 283,26 0,83 -2,36 2.38 276,98 0,08 -1,92 1.94 262,53 0,11 2440,22 2537,69 2~.Jl,54 2726.09 281%69 93,3 2.440,19 97,5 2537,66 93,9 2631,5! 94,5 2726,06 93,6 2819,66 -0,90 0,45 197,10 -0,90 -1,47 0,43 125,38 -I.47 -I,68 0.35 90,86. -1.68 -1,~ 0,34 291,36 -1,58 -1,26 0,34 41,34 -1,26 -1,85 2,05 244,14 0,39 -1,66 2,22 228,54 0,53 -I,09 2,00 212,98 0,26 -1,06 1.90 213,91 0.73 -1,14 1.70 221.95 0.60 2913,39 3007,51 3100,08 ' 3195,66 3284.25 93,7 ~I3,36 94,! 3007,48 92.6 3100,04 95,6 3195,62 88.6 3284.21 -1,19 0,~ 241,26 -i.19 -1,02 0,38 8,45 -1.02 -0.60 0,35 65,10 -0,60 -0,42 0,38 280,97 -0,42 -0,70 0.44 171,13 -0.70 -1.2O 1.69 225,24 0,73 -1.41 1,74 233,96 0.69 -1.11 1,26 241,35 0.37 -1,15 1,23 249.83 0.72 -1,38 1,55_ 243,15 0.75 3377,03 3472,15 3565,12 3660,16 3747,08 ?2,8 33.77,0.0 95.! ~72,11 93.0 3565,08 95.0 3660,12 66,9 3747,0~ -0,79 0,37 329.79 -0,79 -0.76 0,4! 224,70 -0.76 -0,86 0,38-- 62,6i -0.86 -1.05 0.41 182,39 -1,05 -I.06 0,~ 345,~8 -1,08 -1,48 1,68 -1,68 2.02 -1,84 2.03 -1.58 1.90 -1,66 1,98 241.97 247,87 244,97 236,23 237,02 0,86 0.65 0,83 0.71 0,91 Pt~E NO, ~ T~P #~ MEA~ I~L V~i"ICAL ~B~I'H O£PTH ft ft ft 7596,40 97,4 7596o10 **~.~***.' ANAl)RILL ~:~~= SUE~,'EY CALCULATIONS ************* CIRCULAR ARC METHOI)******** TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLACEMENT at AZIMUTH DLS SECTION INCLN, N/-S E/-W decj/ ft deg deg ft ft ft deg lOOft -5.70 0.41 i02.2~ -5.70 -20.66 21.43 254.58 1.38 ,,.~£ NO. 3 ********~ AWADRILL ~:::x~xx~****. Sbl~£Y CAIJ~U~ATIONS ************* CiRCUIJ~R ARC TARGET STATION AZIMUTH ~ATItlFDE si~r~iON INCH, ~'-S ft deg deg ft -0.52 0,40 52,~ -0o52 -0,52 0.37 230.96 -0.52 -0,93 0,38 130.13 -0,93 -1,05 0.38 75.93 -1,05 -1,22 0.37 144.31 -1.22 D~ARTI.,~ DISPI~4CEMENT at ~/-W ft ft -1,46 1,55 -1,44 1.53 -1,44 1,72 -0,94 !,41 -0.46 1.31 AZIMUII~ 250,37 250,31 237,15 200,65 DLS deg/ 0.42 0.62 0.58 0.39 0,44 4322,08 4420.50 450.5.67 4598,93 4694.21 ?4,7 4322,03 98.4 4420.45 86,2 4506.62 92,3 4598,88 95.3 4694,15 -1,64 0.3? 238,73 -1.64 -2.12 0.37 162.16 -2.12 -2,45 0.44 259.00 -2.45 -2,42 0.38 71,71 -2.42 -2,47 0.42 115,i4 -2,47 -0.~ 1.73 198.72 0,59 -0,74 2,24 199,33 0,48 -0.98 2.63 ~1.81 0,70 -1,03 2,63 203,12 0,88 -0.41 2,50 189,52 0.31 4786.13 4878,51 4974.71 5067.72 5162.24 91,9 478~,07 92,4 4878.45 96,2 4974,65 93,0 ~067,65 94,5 5162,17 -2.98 0.52 153.21 -2.98 -2.96 0.52 342.57 -2.96 -3.09 0.~ 180.53 -3o09 -4,00 0.66 2;5,67 -4,00 -4.67 0.55 228.65 -4.67 0.08 2.99 178,42 0.35 0.15 2.96 177,17 1,13 0.01 3,09 179,83 1,21 -0.38 4.01 I85.40 0.54 -1,10 4.80 193,28 0,12 5254,18 535!, 62 .5443,~ 5537,42 5631,45 91.9 5254,11 97.4 5351.54 92,3 5,443.82 93.5 5537.34 94.0 5631.35 -5,32 0.57 218,75 -5,32 -5,2? O,b"5 330,20 -5,~ -5,0~ 0,47 240,79 -5,10 0.68 288,74 -5.10 -4,8~ 0.66 276,16 -4,86 -1,72 5,5? 197,89 0,11 -2,25 5,75 203,03 0,94 -2,80 5,81 208.77 0,78 -3.66 6,28 215,64 0,54 -4,72 6.78 224.16 0,16 5725,94 5817.39 5912,22 6002,91 94,5 5725.84 91.4 5817.29 94.8 5912.12 90.7 6(X)2.80 89,8 6092.54 -4,33 0.78 317.69 -4,33 -3,68 0.51 62.50 -3.68 -3,72 0.38 135,95 -3.72 -3,55 0.91 302.~ -3.55 -2,77 0,7! 316,30 -2.77 -5,69 7,15 232,75 0,55 -5,76 6,83 237,37 1,13 -5.17 6,36 234.25 0,57 -5,56 6.60 237,45 1.41 -6o54 7,11 247,04 0,31 6167.90 6284.14 -6375,31 6470,4? 6564.31 95,2 6187,77 96,2 6284,01 91,2 6375,18 95.2 6470,35 93.8 6564,17 -1,71 0.86 333.86 -1,71 -0.83 0,40 313.88 -0,83 -0,44 0.5? 292.50 -0.44 -0,01 0,55 301.25 -0,01 0,71 0,61 2.69 0.71 -7,26 7~46 -7,82 7,86 -8.48 8,49 -9,32 9,32 -9,68 9.70 256,75 263,91 267.06 269,92 274,22 0.2? 0,52 0.29 0,10 0.63 ~6657,46 67'51.70 6847,13 -6941,19 7033,76 93.1 6657.31 94.2 6751,55 ~.4 6846,97 94,1 6941,02 92,6 7033,56 1.74 0.66 8.53 1,74 2,07 0.51 240.85 2.07 1.38 0,61 160.84 1,38 -0,15 1.37 !99%83 -0.15 -1,71 1,75 248.35 -1,71 -9.58 9,73 260,28 0,08 -9.86 i0,07 281.65 1,11 -10,06 10,15 277,83 0,76 -10.27 10.27 259,19 1.03 -11,96 12,08 261,89 1,44 7127,78 -7219,86 7313,15 7409,41 .,7499.04 94,0 7127,54 92.1 7219.60 93,3 7312,88 96.3 740~,13 69,6 7498,74 -2,60 1.61 253.96 -2,60 -3,01 0,38 259.73 -3,01 -3,80 1.18 :~0,36 -3.~ -4.81 1,16 254,80 -4.81 -5,32 0.99 249.16 -5,32 -14.57 14.80 259,68 0.23 -16,12 16,39 259,41 1.35 -17,04 17.46 257.42 0.99 -18.62 19,23 255,51 0,72 -20.21 20.~3 25'5.24 0.22 ,.,uNF1DENTIAL per AOGCC re§. 20 AAC 25.537 WELL SUMMARY Well Name: ARCO Temptation #1 ~ - ~ ~ APl #: 50-103-20233-00 Location: WKE 93-17, sp. 1872 ASP: x=358,259 y=5,994,332 zone:4 Lat.: 70.392079 N Long: 151.153170 W SFF/R:1891' FSL, 539' FWL, sec.16, T12N, R4E Lease Number: ADL 380095 Rig: Pool 6 Elevation: G.L. = 2' K.B. = 34' Spud Date: March 25, 1996 Total Depth: 7750' MD' (-7715' SS) driller TD Date: April 1, 1996 Completion Date: April 4, 1996 (begin lA sidetrack) Completion Status: Formation @ TD: Plugged & Abandoned Jurassic Kingak RECEIVED Casing Record: Production Tests: 16" @ 110' MD 9 5/8" @ 1817' MD none (see RFT below) AUG 1 9 1996 Ala'Aa 0~1 & Gas Cons. C~rnr~i~ A~or~e Depths from logs shifted to sonic wireline Geological Tops: Base Permafrost Top West Sak Top Shale Wall Top Albian Top Albian B Top Albian C HRZ K-1 LCUFFop Jurassic Total Depth (driller) MD not logged not logged 2184' 4126' 5211' 5818' 6912' 7096' 7183' 7750' SS -2150' -4092' -5177' -5784' -6878' -7062' -7149' -7716' Temptation #1 page 2 Conventional Cores: none Logging Runs: Run #1 (1818'-7743'): LDT/CNTG/GR Run #2 (1818'-7686'): DSI/GR Run #3 (5838'-7418'): RFT/GR Run #4 (7175'-7476'): MSCT/GR (rotary sidewall cores) MWD gamma ray/resistivity: surface to TD Mudlog: surface to TD Sidewall Cores: Rotary (7175'-7476'): shot 27, recovered 27 RI=T: 2 RFT samples taken. The first sample was taken at 7412' MD (Nechelik Sand). Formation pressure was 3365 psi with a calculated mobility of 1.2 md/cp. The 2 3/4 gallon chamber was left open for 1 hr. 30 minutes, then sealed with a pressure of 350 psi. Recovery was 1.48 ft3 gas and 4500 cc of dark brown oil and water mix. The tool came off the formation with no sticking. The 1 gallon sample was opened at 7180.5' MD with formation pressure of 3264 psi and a mobility of 32.5 md/cp. The chamber was closed after 6 1/4minutes at a pressure of 3249 psi. Recovery was 1.55 ft3 gas and 3500 cc of dark brown oil/water mix. TEMPTATION #1 FINAL PLUGBACK AND ABANDON DIAGRAIV NOTE: WELL WAS SIDETRACKED AT 1865' TO TEMPTATION #1A 3000 PSI WELLHEAD EQUIPMENT 16" CONDUCTOR AT 110' RKB 12-1/4" HOLE TOP OF SIDETRACK PLUG #3 @ 1865' BASE OF PLUG #3 @ 2100' 8-1/2" HOLE TOP OF PLUG #2 @ 7000' BASE OF PLUG #2 @ 7300' TOP OF PLUG #1 @ 7300' BASE OF PLUG #1 @ TD 10.2 LB/GAL MUD 1 10.2 LB/GAL MUD. 10.2 LB/GAL MUDi ::::::::::::::::::::::::::::::::::::::::::::::::::::::: ': ::2 :.'.-': ".'..': ::.:: :.'.:: :.'..': :.'..': :.'.:: :.'..': :.'..': :.'..".: ::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~M'..:.':MMM::2.M::.::::,':::,':M: ?,': ::,': ::2::.::::.:::.'..'::: 2.:.::::.'2.'.:..': ::..': : %::,':'..:.':::,'::::':::.::::.::::,,.::..':'.....':::..':::..,.: :::::::::::::::::::::::::::::::::::::::::::::::::::::: 72 :'.-'.' :'..': :'2:2 :'..': :',"'32 :.'..R,i'l'2 .': ::..': ::.:: :.:.': ::2 ::.-': :.::: :.',': ".:-': :.'..': ::2 :.'.:: i ':.'.'.?:;'.'.'.:P.?:{.?:;'.'.":;'.%?:i'.'.'.:P.?:;'.?:i'81 i :::::::::::::::::::::::::::::::::::::::::::::::::::: 9-5/8" SURFACE CSG AT 1817' RKB NOTE: 10.2 PPG KILL WEIGHT MUD PLACED BETWEEN ALL PLUGS NO TAG REQUIRED ON PLUG #2 PER AOGCC 7170-7185' HYDROCARBON BEARING ZONE - KUPARUK HYDROCARBON 7200-7350' BEARING ZONE- NECHELIK TD AT 7750' MD/TVD ARCTIC-SET CEMENTS CLASS G CEMENT WITH ADDITIVES TWM, 5/2/96 ACCESS30' %~'-' ICE PAD LIMITS (TYP.) . , I ~ 20' CUINGS ~ ~, STORAGE 250' ~ ~7' } , , ~ j= 5~7' =j LOCA~D ~IN PRO~AC~D SEC. 16, ~. 12 N., RGB 4 E. NOT ~ ~ UMIAT MERIDIAN ~T. = 70' 23' 31.~3' NO~ LONG. = 151" 09' 11.412' ~. e~¢s ~ H~/zo~r~ ~oc~oN A~¢ ~~ 1,891' F.S.L, 539' F.W.L /s u.s¢~ ~u~T e~. Y = 5,994,332.53 ~ c~¢/N4~ ~o~ ~ ~~ sr4~ P~¢ X = 358,259.52 z~¢ ~, N.~¢. 2z GROUND E~V.=2' 3' ¢A~ ~ ~R~' 3/~/¢~' TOP ICE PAD E~V. = 3.9' ~. ~A ~ONS ~0~ ARE ~.P.M.~ ~ ~ ~7~n m ~ ~ ~ DONE BY ~ ~ UNDER ~ DIRECT SUPERVISION AND ~~t ~T ALL D/~NS/ON, AND O~ER DETAIL, ARE CORRECT '~'~,~~ A$ OF ~CH /3. 1996. I ARCO Alaska, inc. CONDUCT~ Subaidiary of Atlantic Ri~fleld Company ~-~UJLT ~601208I 3[14(96 J C _Ml _601D208 OOl ¢ 1I 1 TO: AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 ARCO Alaska' Inc. AtlanticRiclff~.~eldCompany DATE: May 10, 1996 FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Transmitted herwith is the followinq data: REPORTS: Alpine 3 "BASIC ROCK PROPERTIES"- Final Report as Displayed by Core Laboratories Bergschrund 2A "BASIC ROCK PROPERTIES" - Final Report as Displayed by Core Laboratories Nanuk 1 "BASIC ROCK PROPERTIES"- Final Report as Displayed by Core Laboratories /./Temptation 1 "BASIC ROCK PROPERTIES"- Final Report as Displayed by Core Laboratories If you have any questions please call me at (907) 265-6240. Kelli RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by: DATE: ~A&Y'I 5 1996 ,~J~k~ Oil & Gas Cons. C0mmissi0~ Approved for transmittal by: / - "'' - F.M. Honr~y-,~] u{t Manager, North Alaska E)/pl~ration / TO: DATE: AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 May 10, 1996 ARCO Alaska, Inc. AtlanticRichfieldCompany FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Transmitted herwith is the following data: Enclosed is the following data: LOGS: Sepia Copy Displayed by Schlumberqer: Temptation 1 /CDR FINAL PRINT .COMPENSATED THERMAL & EPITHERMAL NEUTRON LITHO-DENSITY / GR ~.DIPOLE SONIC IMAGER UPPER DIPOLE AND P & S APRIL 2, 1996 -MECHANICAL SIDEWALL CORING RECORD 2-APRIL-1996 ~"REPEAT FORMATION TESTER - RFT / GR I Blueline Copy Displayed by Schlumbercjer: Temptation 1 .CDR FINAL PRINT ~ ~'COMPENSATED THERMAL & EPITHERMAL NEUTRON LITHO-DENSITY / GR A /DIPOLE SONIC IMAGER UPPER DIPOLE AND P & S APRIL 2, 1996 /~ MECHANICAL SIDEWALL CORING RECORD 2-APRIL-1996 REPEAT FORMATION TESTER - RFT ! GR DIGITAL DATA Displayed by Schlumber~ler: Temptation I -~ ~ 0 T ~ ,,/6" Open Reel Tape-LDWG Format-"Open Hole Edit" CDR/DSI/LDT/CNTG/GR with paper file listing -~ ~) 0 ~- ~ ~/~0" Open Reel Tape-LIS Format-"Open Hole" RFT FIELD TAPE - RUN ONE /~ with paper file listing .~.5 Floppy-ASCII Format-Directional Data ( Meas Depth, Devi, Hazi) /r TO: AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 ARCO Alaska, Inc. AtlanticRichfieldCompany DATE: May 2, 1996 FROM: ARCO Alaska, Inc. Attn.: Ms. Keili A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Transmitted herwith is the followinq data: DIGITAL DATA Displayed by Schlumberger: Nanuk 1 6"'Open Reel Tape-LDWG Format-"Open Hole Edit" MWD CDPJCDN & Wireline DSI/LDT/CNTG with paper file listing 10" Open Reel Tape-LDWG Format-"Open Hole" RFT FIELD AQUIRED DATA with paper file listing 3.5 Floppy-Ascii Format-Directional Data ( Meas Depth, Devi, Hazi) REPORTS: Nanuk I Wireline Tops as Displayed by ARCO If you have any questions please call me at (907) 265-6240. Kelli RETURN SIGNED COPY TO: ARCO Alaska, inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: Ap.~o~oved for transmittal by: ~ Manager, No~h Alaska ~loration~ ARCO Alaska, Inc. AtlanticRichfieldCompany TO: AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: May 2, 1996 Transmitted herwith is the followinq data: Enclosed is the following data: LOGS: I Sepia Copy Displayed by EPOCH: C..-Temptation 1 Formation Log 2" = 100' (107' to ~117750') Temptation lA Formation Log 2" = 100' (1816' to 8950') I Blueline Copy Displayed by EPOCH: ~mptation 1 Formation Log 2" = 100' (107' to r/750,) Temptation lA Formation Log 2" = 100' (1816' to 8950') I Sepia Copy Displayed by Schlumbercjer: Nanuk 1 CDN FINAL PRINT CDR FINAL PRINT COMPENSATED THERMAL & EPITHERMAL NEUTRON LITHOLOGY DENSITY DIPOLE SONIC IMAGER UPPER DIPOLE AND P & S 19-MARCH-1996 I Blueline Copy Displayed by Schlumber~jer: Nanuk 1 CDN FINAL PRINT CDR FINAL PRINT COMPENSATED THERMAL & EPITHERMAL NEUTRON LITHOLOGY DENSITY DIPOLE SONIC IMAGER UPPER DIPOLE AND P & S 19-MARCH-1996 .- STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1, Type of Request: Abandon X Suspend Operation Shutdown Re-enter suspended well Alter casing _ Repair well Plugging _ Time e.xtension Stimulate Change approved program _ Pull tubing _ Variance _ Perforate _ Other 2, Name ol Opera[or ARCO Alaska. In(;. 3. Address Box 100360, Anchorage, AK 99510 4. Location of well at 5. Type of Well: Development _ Exploratory X Stratigraphic _ Service 6, Datum elevation (DF or KB) RKB 35' Ab_ove__,~!,.__ 7. Unit or Property name N/A Well number 1891' FSL, 539' PC/L, Sec. 16, T12N, R4E. UM At top of productive interval 0 R IGINAL At total depth Same : Temolatigp ¢¢1 9, Permit number 9.6-006 10, APl number $0-103-20233 11, Field/Pool Wildcat 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Caring Le n g t h Structural Conductor 8 0' Surface 1 8 1 7' Intermediate Production Liner Perforation depth: measured: None 7750' teet 7750' feet 16" 9 -5/8" tc'ue vertical: None Tubing (size, grade, and measured depth: None Packers and S$SV (type and measured depth): None Cemented 300 Sx AS I 291 Sx AS III & 607 Sx AS I Measured depth True vertical depth 110' 110' 1817' 1817' c[J tvED APR 0 b l!)96 Aiaska Oil & Gas Cons. Commi,~sioc, .&nchomge 13, Attachments Description summary of proposal_ Detailed operation program ~ BOP skmch _ P&A Wellbore 14, E.~tlmated date tor commencing operation 15. Status o[ well classilication as: April 2. 1996 Oil _ Gas _ 16. I[ proposal was verbally approved Jack Hartz -J~i..z/ April 2, 1996 Name of approver Date appro_v?_d Service ' 7. i-I~reby certify thj~ the foregoing is [rue and correct [o the best of my knowledge. --- FOR COMMISSION USE ONLY Suspended _ Conditions of approval: Notify Commbsion so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require Signed By Approved by the order of ~he Co_mm, lesion Oavid W. Johnston Form 10-403 Rev 06/15/88 Commissioner IApproval No. SUBMIT IN TRIPLICATE TEMPTATION #1 PROPOSED PLUGBACK AND ABANDON DIAGRAM 3000 PSI WELLHEAD EQUIPMENT 6" CONDUCTOR AT 110' RKB 12-1/4' HOLE TOP OF PLUG ~ @ 1650' BASE OF PLUG ~ @ 2100' 8-1/2" HOLE TOP OF PLUG #2 @ 7000' BASF. OF PLUG ~r2 @ 7300' TOP OF PLUG #1 @ 7300' BASE OF PLUG #1 @ TD 10.2 LB/GAL MUD ::::::::::::::::::::::::::::::::::::::::::::::::::::::: 10,2 LB/GAL MUD! iliii 9.5/8" SURFACE CSG AT 1817' FtKB NOTE: lO.2 PPG KILL WEIGHT MUD PLACED BETWEEN ALL PLUGS 10.2 LB/GAL MUD ~:~:ii~:~!~[~t 7200-7350' BEARING ZONE- NECHELIK t::~:~:~~t TD AT 7750' MD~VD BEARING ZONE - KUPARUK ARCTIC-SET CEMENTS CLASS G CEMENT WITH ADDITIVES TWM, 412/96 TEMPTATION #1 PLUGBACK AND ABANDONMENT PROCEDURE Notify AOGCC 24 hrs. prior to beginning any P&A activity (907) 279-1433 , . . RIH with open-ended drill pipe and 3-1/2" stinger to TD (7750'). Lay a 45 bbl (220 sx) balanced cement plug from 7300'-7750'. (estimated top of cement plug with excess is 7191'), Pull up 7 stands slowly to 7191', and circulate out DP. WOC 6 hours. TIH and wash to 7300'. With the drill pipe at 7300' lay a 31 bbl (150 sx) balanced cement plug from 7300'- 7000'. (estimated top of cement plug with excess is '6902') Note: The AOGCC has waived the requirement per 20 AAC 25.105 (I) to test this plugs location and integrity. 4, Puli up 15 stands slowly', and circulate out DP. 5. POOH to +_2350'. , , 1 12. 13. 14. 15. 16. 17. 18. Spot a 20 bbl hi-vis pill from 2350'-2100', sx) balanced cement plug from 1650'-2100'. is 1505'). Pull up to 2100' and lay a 53.4 bbl (300 (estimated top of cement plug with excess Pull up 10 stands slowly, and circulate out DP. TOH and continue with sidetrack program for Temptation #lA. NOTE: If sidetrack is cancelled and Temptation #1 well is P&A'd, continue with the following program, RIH and tag cement plug #3 above casing shoe with 15,000 lb. Document plug location and integrity for AOGCC. Notify AOGCC in advance for opportunity to witness, Pull 5 stands. Pressure test cement plug to 500 psi for 10 minutes, Record pressure on a chad and submit to AOGCC and office. POH, laying down all but 250' of drill pipe. RIH with 9-5/8" bridge plug and set at 250'. Weight test by slacking off all drill pipe weight on it. Place 15.6 bbl (95 sx) of Arctic Set I cement on top of the bridge plug. With drill pipe at 33', reverse out excess cement Note: top of the surface cement plug is required to be at surface (casing cutoff point) POOH. N/D BOP stack, Rig down and begin final rig demob. Cut all casing strings off at or below 3' below ground level. Fill all annuli to sudace with cement. Remove cellar. Back fill cellar with gravel as needed. Send casing head with stub to Materials for repair/redressing. cid cover plat? 3r all casing strings with the following the top: ...... -?marion bead welded into ARCO ALASKA, INC TEMPTATION #1 ADL 380095 APl# 50-103.-20233 1891' FSL, 539' FWL, S16-T12N-R4E,UM Note: ARCO has reque~tecl tl~e AOGCC waive the requirement for an above ground P&A marker per 20 AAC 25.120. 20. Back fill remaining hole to ground level with gravel. Clean up location. Y' Dr~gineer,,.) Approved by ~,,.~R-U DS Dev~opment ~t~pervisor Algska, Inc. =t Office Box ,100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 3, 3[ 996 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 (907) 276-7542 (fax) APR 0 1996 g~vaka 0~1 & Gas Cons. Commi~o~ ~chorage Sundry Nodce m Plug and Ab~don ARCO Temptation ~l Pe~it No. 96-006 Dem- Commissioner Johnston, The ARCO Temptation #1 well has been drilled to 7750' MD/TVD and plans are being made to plug and abandon. ARCO Alaska, Inc, hereby applies for sundry approval with a variance to plug and abandon the ARCO Temptation #1, permit number 96-006, A detailed plug and abandonment procedure is enclosed_ Please note that the well may be sidetracked below the surface casing shoe at 1 $17', but that the P&A of the open hole section of the Temptation #1 well will occur according to this plan regardless. A separate APD package will be submitted if needed for the Temptation #lA sidetrack. ARCO requests a variance to the requirements of 20 AAC 25.105 (1) for the cement plugs #1 and #2 (7000'-7750') placed as shown at total depth on the attached diagram. ARCO proposes to place plug #1 and plug #2 in the well per 20 AAC 25.105 (fi) using caliper hole volumes plus 25 % excess cement volume without recording the actual location or integrity. Plug #1 at total depth will be placed on the bottom of the hole which will prevent any chance of the cement falling downhole. Plug #2 will be placed directly above Plug #I. Thus, there is no chance of any downward migration of Plug ~2 either. High viscosity mud will be placed below plug #3 to prevent the cement from falling downhole. ARCO also requests a variance to the requirements of 20 AAC 25.120 Well Abandonment Marker_ Rather than place an above ground marker over the wellbore, ARCO proposes to weld a cover plate to the casing stub 3' below ground level with the information required in 20 AAC 25,120 (b) bead welded to the top. The location will then be backfilled with gravel. If you have questions or require additional information, please contact Tom McKay at 265-6890 in our Anchorage office. Sincerely, Tom McKay (/ Senior Drilling Engineer KRU Ddllsite Development APR 0 3 1~96 ~ ,- Fi, O ,qFi fll 1,5,,9!0 IL, Oii& Ga~ Coas. ' .Anchorage o Alaska, inc. ost Office Box 100360 Anchorage, Alaska 99510-0380 Telephone 907-276-1215 April 3, 1996 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 (907) 276-7542 (fax) Re: Sundry. Notice to Plug and Abandon ARCO Temptation #1 Permit No. 96-006 Dear Commissioner Johnston, The ARCO Temptation #1 welt has been drilled to 7750' MD/TVD and plans are being made to plug and abandon. ARCO Alaska, Inc, hereby applies for sundry approval with a variance to plug and abandon the ARCO Temptation #1, permit number 96-006, A detailed plug and abandonment procedure is enclosed. Please note that the well may be sidetracked below the surface casing shoe at 1817', but that the P&A of the open hole section of the Temptation #1 well will occur according to this plan regardless. A separate APD package will be submitted if needed for the Temptation #lA sidetrack. ARCO requests a ~to the requirements of 20 AAC 25.105 (1) for the cement gllugs #1 and #2 (7000'-7750') placed as shown at total depth on the ~ttached diagram. ARCO proposes to place plug #1 and plug #2 in the well per 20 AAC 25.105 (fi) using ~ hole volumes plus 25 % excess cement volume without recording the actual location or integrity~ Plug #I at t6tal depth will be placed on the bottom of the hole which will prevent any chance of the cement falling downhole. Plug #2 will be placed directly above Plug #1. Thus, there is no chance of any downward migration of Plug ~e2 either. High viscosity mud will be placed below plug #3 to prevent the cement from falling downhole. ARCO also requests a variance to the requirements of _20 AAC 25.120 Well~ o.k (~ Abandonment MarXer. Rather than place an"above ground marker over the~ore, ' ' ARCO proI/oses to weld a cover plate to the casing stub 3' below ground level with the ~'. ~. 6~ information required in 20 AAC 25.120 (b) bead welded to the top. The location will then be backfilled with gravel. If you have questions or require additional information, please contact Tom McKay at 265-6890 in our Anchorage off'me. Sincerely, Senior Drilling Engineer KRU Drillsite Development Anchor~. ,~ska 99510-0360 Telephone ~07 276 1215 March 25, 1996 Dzvid W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3C01 Porcupine Drive Anchorage, Alaska 99501-3192 Weekly Operations Report .-ARCO Temptation #1 Permit No. 96-006 ARCO Bergschrund #2A Permit No. 96-033 ARCO Nanuk #1 Permit No. 96-057 Dem' Commissioner Johnston, Attached is ~e wee~kZy operations summary for the ARCO Temptation ~-1, Bergschrund #2A Sidetrack and Nanuk #1 wells being drilled in the Colvi~e delta ama. The Nanuk #1 was drilled ro 7630' TI), logged and P&A. The Doyon ng was then moved back to t~e Bergschrund ice pad. The Bergscha--und #2A is drilling out cement in the surface casing. The Temptation well is drilling surface hole at 1200'. ff you have questions or require additional information, please contact Fred Johnson att 265- t a92. Sincerely, ,/ Fred Johnson Drilling En~neer AF~3~-600O 9;i RECEIVED Alaska 0il & ~ 22P~ A.~?~.C.O. ALASI'~A iNC No, 84.66 P, 3/5 Date: 3/25/96 ARCO ALASFA INCORPORATED WELL S~Y REPORT Page: 1 WELL: TF. MPTATION #1 I{IG:NO RIG WELL ID: AX9365 AFC: AX9365 STATE:ALASkA ARF~/CNTY' NORTH SLOPE WEST FIELD- WILDCAT BLOCK: SPUD: START COMP' FINAL: TIGHT HOLE API NUMBER: 50-103-20233-00 03/17/96 (1) rD- '( 0) SUPV: DBS 03/18/96 (2) TO: '( ) SUPV:DBS MW: PV/YP: APIWL: RIG DOWN MOVE TO TEMPTATION #1 Rigging down to move to another loaction. MW: PV/YP' APIWL: RIG DOWN- MOVE TO TEMPTATION $1 Continue to rig down for move. 03/19/96 (3) TD: '( ) SUPV:DB$ MW: PV/YP: A~IWL: RIG DOWN- MOVE TO TEMPTATIO~ #1 Continue to rig down for move. Begin moving to Temptation. 03/20/96 (4) TD: '( ) SUPV:DCB W~: PV/YP: APIWL: RIG UP AT TEFWTATION #1 Move components from Neve %1 to Temptation #1, Continue rig up of drawworks and first derrick components. 03/21/96 TD: 110 SUPV:DCB (5) '( O) MIRU R/U derrick. MW' PV/YP: APIWL: 03/22/96 TD: 110 SUPV:DCB (6) '( 0) MW: PV/YP: MIRU Continue to R/U derrick, 03/23/96 TD: 1%0 SUPV:DCB (7) '( 0) MW: PV/YP- APIWL: R/U FLOOR AND UTILITIES Continue to R/U floor and pits. 03/24/96 TD: 110 SUPV:DCB (8) '( 0) MW: 9.5 PV/YP: 20/40 APIWL: 14.8 WORK ON PUMPS/SCR Function test diverter system and Koomey unit test, Held pre-spud meeting, 03/25/96 (9) WA: 9.8 PV/YP: 7/57 APIWL: 16.9 TD: 1280'( 1173) DRILLING 12-25" SURFACE SUPV:DCB Drilling surface hole from 107' to 1280' End of WellSummary for Weli:AX93&3 RECEIVED MAR 2 6 199G Alaska Oil & 6as Cons. Commission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo n, DATE: Chairman March 23, 1996 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor ~f~,i't~ e9zlcwdd.doc FROM: John Spaulding,,~o,~£,, SUBJECT: Petroleum lnsp. 006 Diverter Function Test ARCO / Pool 6 Temptation # 1 Exploration PTD 96- Saturday March 23, 1996: ! traveled this date to ARCO's exploration well Temptation # 1 to witness the Diverter Function Test on Pool rig 6. The AOGCC test report is attached for reference. All portions of the diverter system worked well as noted on the test form. The rig is well laid out taking good advantage of the wind direction. Access to the pad area is away from the vent line area. The end of the diverter vent line extends 80' outside of the rig structure and is well in excess of 100' from an ignition source. Summary' I witnessed the Diverter function test on Pool rig 6 with no failures. Attachments: e9zlcwdd.xls Drlg Contractor: Operator: Well Name: Location: Sec. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Pool ARCO Temptation #1 16 T. 12N R. Operation: Development Rig No. 6 PTD # Oper. Rep.: Rig Rep.: 4E Merdian Umiat Date: Exploratory: 96-006 Rig Ph. # Dave Baumgarner 3/23/96 X 263-3142 Rick Brumley TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok Reserve Pit: N/A (Gen.) DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(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: Turns Targeted / Long Radius: Well Sign: Drlg. Rig: Flare Pit: yes ok NIA 20 in. yes yes 16 '-"'in. 135 ft. N/A yes yes N/A ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 2,800 1,250 min. 40 2 min. 57 6 bottles psig psig sec. sec, MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: 3 @ 1950 & 3 @ 2000 psig Light Alarm ok ok GAS DETECTORS: Methane Hydrogen Sulfide: ok ok ok ok Light Alarm ok ok ok ok DIVERTER SCHEMATIC Full opening knife valve Shop Camp' Pipe Shed Mud Pits Motors Diverter vent line 80' outside rig walls, 2 anchors in place North ,, - Wind Direction Non Compliance Items 0 Repair Items Within 0 Remarks: Diverter vent line extends 80' outside the rig Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - Oper/Rep c - Database c - Trip Rpt File c - Inspector AOGCC REP.' OPERATOR REP.' E9ZLCWDD.XLT John H. Spaulding Dave Baumgarner DVTRINSP.XLT (REV. 1/94) AI,ASKA 0IL A~¥D GAS CONSERVATION COM3~$SION / I / / TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mar~ 13, 1996 Thomas W. McKay, I~.E. Senior Drilling E~eer Kupamk Drill Ske Development ATO 1202 ARCO Alaska, he. P.O. Box 100360 Anchorage, AK 99510-0360 Requested annular disposal of cement washdown water from Colville Delta exploratory wells Dear M.r. McKay: The Commission has received your request for'authorization for disposal of cement washdown water from certain Colville Delta exploratory wells in the annuii of wells currently being drilled in the Kupmk River Unit. The washdown water would be generated by drilling operations at the following exploratory wells during the 1996 season:. Bergsdmmd #2, Bergsc_Anmd #2A, Alpine #3, Nanuk #1, Neve #1, Neve 3lA, and Temptation #1. Disposal would take place into the nnnuli of wells being dh/led by Parker Rig #245, for which ~nnular disposal MS already been authorized. We understand that cement washdown water is produced as a result of blending and mixing cement used in drilling wells. It therefore appears that the cement washdown water you propose for annular disposal is a nonhazardous waste assodated with the act of drilling an oil or gas well for exploratory purposes, within the meaning of AS 31.05.030(e)(2). Ordinarily nnnular disposal is permitted in well annul/located on the same drill pad as the well generating the waste in question You have explained that the Colville Delta exploratory wells will not have annuli available for disposal operatiom. The Commission authorizes ARCO AlaSka, Inc., to dispose of cement washdown water from the above-t/sted Colville Delta exploratory wells in the annuli of wells curre~y being drilled within the Kupamk River unit by Parker Rig #245, subject to the existing terms and conditions governing annular cflsposal in the iatter wells. This authorization is for the 1996 drilling season only. Sinc~rely, f. David Norton, P.E. Commissioner ¢: /ruck~rman Babcock Commis~oner ALASKA 0~~ CxA~ CONSERVATION COMM/SSION / / I ; / ! : TONY KNOWt_E$, GOVERNOR 3001 PORCUPINE 12RP,/E ANCHOFI~GE, ALASKA 99501-3192 PHONE: (907} 279,1433 FAX: (907) 276-,75,42 February 29, 1996 Will/am S. [sam:son Drilling Engineer Kupanflc Dr/il Site Development ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: request for waiver to 20 'A~C 25.080(d)(4), Annular Disposal ofDfiiling Wasm Dear Mr. Isaacson The Commission tmz received your re~ue~ for w~ver ~~ ~os~ of ~iling ~ ~om ~ ooe~o~ for w~ver is ~d~ for we~ 1Q-21 ~d ~- 17. ~CO s~ ~o~on to ~je~ ~]ling ~ ~m ~e 4 3/4" hole s~ ofwe~ IQ-21 ~d ~-I7 ~ ~e ~~ of a ~ ~ eider 3H or ~ I~ .... 17 we~ ~ be ~ by e~er Nor~c ~1 or a a~able for Nj~on p~os~ on ~e IQ ~d ~ p~, nei~er No~c ~ffiU m ~d ~d Nje~ m~s for ~~ ~os~ p~os~. av~Io on P~er 245, wNch N ~ m ~e 3H ~d ~CO ~ ~~ ~ a C~s ~ ~pos~ ~ ~ ~o be a~able for ~e ~ ~e ~ove me~o~ ~iling ope~om. Pl~e be ~~ mmfion~ N yo~ ~~ ~er ~ g~er~ ~ ~iling a~= ~ ~ ~p~ for The Commission hereby grants a waiver to ARCO gln_~ka, Inc. for wells lQ-21 and 2X-t7 from the requirements of 20 AAC 25.080(d)(4). Sincerely, David Norton, PE. Commissioner Tuckennan Babcock Commissioner 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 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 (907) 276-7542 (fax) Annular Disposal of Cement Washdown Water Coiviile Delta Exploratory Wells Re' Gentlemen' ARCO hereby requests a waiver to the AOGCC Regulations (20 AAC 25.080.) covering Annular Disposal of Drilling Waste recently adopted by the Commission on January 31, 1996. This waiver is requested to cover ARCO's Colville Delta exploratory wells currently being drilled during the 1996 winter drilling season. Cement washdown water is an integral part of any cement job). Cement is used as a means of pressure control in the wells being drilled. Each casing string, sidetrack plug, P&A plug, and other cement plugs mixed for use in d,'illing wells oroduce a relatively small amount of cement washdown water as a result of the cement blending and mixing operation. We are requesting the Commission determine under 20 AAC 25.080. that this washdown water is a waste associated with the act of drilling a well and permitted for annular disposal. Secondly, ARCO requests permission to transport cement washdown water from the Colville exploratory operations to approved disposal annuli in the Kuparuk River Unit. This waiver is required since cement washdown water is not exempt, and thus cannot be disposed of in Class 2 injection wells in the Kuparuk River Unit. It is also required because the Colville Delta exploratory wells do not have annuli available for annular disposal operations. Normally, the amount of cement washdown water generated for any individual cement job is less than 250 bbls, although it an vary widely depending upon the operation. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany The wells generating cement washdown water needing a waiver this winter include' Bergschrund #2 Bergschrund #2A Alpine #3 Nanuk #1 Neve #1 Neve #1A Temptation #1 The destination of the waste would be the permitted annu!i of the wells currently being drilled within the KRU by Parker Rig #245. The cement washdown water would be pumped into the permitted annulus that Parker Rig 245 was connected to at that time. Again, the permitted well would be within the Kuparuk River Unit. We appreciate your consideration of this request. If you have any questions or require any additional information on this matter, please contact me at 265-6890. Sincerely, Thomas W. McKay, P.~.. Senior Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. TONY KNOWLE$, GOVERIVOI~ ALASKA OIL kND GAS CONSERVATION COM HSSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 8, 1996 Mike Zanghi, Ddg Engr Supv ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Temptation No. 1 Company Permit # Surf Loc Btmhole Loc ARCO Alaska, Inc. 96-006 540'FWL, 1890'FSL, Sec 16, T12N, R4E, UM 540'FWL, 1890'FSL, Sec 16, T12N, R4E, UM 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. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Your request for variances from 20 AAC 25.035(b)(1) to allow an unbifurcated diverter, 20 AAC 25.065 regarding H2S and 20 ACC 25.033(e,2,D) regarding shale density have been approved. 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 belowthe surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be David W Johnston Chairman ~., . ,, BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASr,;,A OIL AND GAS CONSERVATION COMMISbJON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill __ lb. Type of Well Exploratory X___ Stratigraphic Test Development Oil _ Re-Entry__ Deepen _ Service _ Development Gas __ Single Zone _ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. KB ht above sea level:40 feet Wildcat 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL-380095 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 540' FWL, 1890' FSL, Sec. 16, T12N, R4E, UM N/A Statewide At top of productive interval 8. Well number Number Same Temptation #1 #U63061 0 At total depth 9. Approximate spud date Amount Same 2-30-96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) property line 3200 feet 5.25 Miles 1501 Lease Acres 7940' RKB MD & TVD feet 16. To be completed for deviated wells N/A 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth feet Maximum hole angle Maximum surface 1075 psig At total depth (TVD) 3716 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) 2 0" 16" 62.58# B PEB 8 0' 4 0' 4 0' 120' 120' Permafrost Cement 12.25" 9.625" 53.5# L-80 BTC 1760' 40' 40' 1800' 1800' _+290 sx ASIII, 600 sx ASI 8.5" 7" 26.0# L-80 BTCMoC 7900' 40' 40' 7940' 7940' _+200 sx G 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 Conductor Surface Intermediate Production LinerJAN 1996 Perforation depth: measured Alaska Oil & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee ~ Property plat ~ BOP Sketch X Diverter Sketch ~ Drilling program X Drilling fluid program X Time vs depth plot X Refraction analysis _ Seabed report 20 AAC 25.050 requirements __ 21. I hereby certify t~at the foreg..oing is true and correct to the best of my knowledge SignedJ ~" '° _~ TiUle KRU Drillsite Development Supervisor Date LC/ ~-- Commission Use Only Per,~ Number ~ I ~ number I Approval date /,., I See cover letter for - I 5 0-,)/~, - ~ 0 2.. ,~3 I O ~/(~ :~' / f'¢ (~2 I other requirements Conditions of approval Samples required ~¢~.Y e s N o Mud Icg required ' ,~'Y e s N o Hydrogen sulfide measures __ Y es ~ N o Directional survey required __Yes ~ N o Required working pressure forBOPE __2M; __ 3M' ~ 5 M · __ 1 0M' __ 1 5 M Other: Original Signed By David W. Johnston by order of Approved by Commissioner the commission Date (~ 2.-/~) F/Y (-~ Form 10-401 Rev. 7-24-89 Submit in triplicate ~ r_ :~(~RiH lion ~ssir ~ ~ ', 5w N S B U ~ Y PLANNERS SURVEYORS ~ - TEMPTATION #1 - ARCO Alaska, Inc. ~, EXPLORATORYWELL Subsidiory of Atlantic Richfield Compony PERMIT EXHIBIT CADD FILE NO. IDRAWlNG NO: SHEET: [REV: LK601185 12/07/95 NSK 6.01 d185 ~ OF 2 0 92-~0 .. . "'qb.,.._---~ ~ LOCATED WITHIN PROTRACTED ._~'.~__-~---' : .'/ "-, :~ ,¥ SEC. !6, TWP. 12 N., ~ ~~ ~,: ,,,~,~T ~D~,A~ : ] ~ ~ / UIVII~/ IVlLIN U!~ ~ ,~ ~ : ~ ( AT -- ?~' aZ' ~~ ; .~ ,.~ ~ ~'. - .=. =~, ~,,, "t ~ ,' - · '~ n ~ ~ p~ LONG. = 151 09 ~7 ~ '5/ b '~' " ~' v '~' ~ ~ ~ ~9~ p, ~ :: = 5,994 332 TEMPTATION ~1 ~,x ~., ~ ~ ~s.L, ~ ,.~.~.: · ., / ~ , -~ ~ ~ ~ ~ x ~X~ /' : ~ ~k~ ~x '., X k~ '~" i'~ % ' 4 ,/ .,', 93~15' : "~ i F ~ /i / ~( 4~93-21 ~I~ ~u ~ 'x' / // / / x "'"x '( : N~NUK .. .' .~-~- ~ ]- ~ , ~ ~ : ~-, ~x ,- ..... ~ / -- . b I ~ ~ ' ~ ,h ; I ', , ~ ": ', ' _, ~ ~ , -~~.~, :~.,. ., ,.,,.~ : .~ . ,. , ~ -'~ · , LOUNSBURY~ ~.,~ ,, j~ '.. u It ,,-a :~ ',, ':[~3-4~ ~l :IUh/ & ASSOCIATES, INC. ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company CADD FILE NO. I DRAWING NO: LK601185 . 12/07/95 I TEMPTATION #1 EXPLORATORY WELL PERMIT EXHIBIT NSK 6.01 d185 ISHEET: REV: 2 OF2 0 RW RI~ (+ I o,;~o) .HUNT TEMPTATION #1 AAI 2.5~: 7.5x (co ALK4715 ADL 25538 APC 20.0: 1 -,.31~'75 -ADL 25558 AAI 72.5: ~ UTP ,- '-'APC 20.0~. 1-51-75 -.-:- (COND). ,, AL K471""7 ADL 255,.59 UTP APC 20~ 3-51 ALK455~ ,372107 -~ AAl~O5x UTP ARC 20.1~, 1,~31 -75 ; (COND) ADL 25557 AAI' UTP 16.1x APC 20.Ox ALK4551 ' 't, DL 372095 AAI 63.9x UTP 16.1x APC 20x ADL 372096 DIAGRAM AND DESCRIPTION OF DIVERTER SYSTEM TO BE USED (Per 20 AAC 25.005(c)(5)) Per 20 AAC 25.005(c)(3)' DIAGRAM AND DESCRIPTION OF BOP EQUIPMENT TO BE USED (As required in 20 AAC 25.035(a)(1)) AND INFORMATION ON MAXIMUM PRESSURES (As required in 20 AAC 25.035(d)(2)) DIVERTER SCHEMATIC POOL RIG #6 HYDRIL MSP 21-1/4" 2000 psi Annular Preventer 21-1/4" I I 2000 psi 16" Outlet ~ Spool (2) 16]1~ 62#, PEB Conductor Flowline 16", 200 psi Hydraulic Knife Valve 16" OD Diverter Line BOP SCHEMATIC POOL RIG #6 13-5/8", 10,000 PSI I I I 5 I I I I I I See listing of individual components on following page Revised 1/31/95 BOP COMPONENTS TEMPTATION #1 POOL RIG #6 13-5/8, 10,000 PSI Diverter System: . , , 21-1/4", 2000 psi WP, Hydril Type MSP annular preventer with companion flange to diverter spool. 21-1/4", 2000 psi WP diverter spool with one 16" outlet. 16", 200 psi WP FNW knife valve with hydraulic actuator on diverter outlet. BOP Stack: 4. 13-5/8", 5000 psi WP, Hydril Type GK annular preventer with companion flange to bell nipple. 5. Single 13-5/8", 10,000 psi WP, Hydril type MPL ram blowout preventer fitted with pipe rams. 6. Single 13-5/8", 10,000 psi WP, Hydril type MPL ram blowout preventer fitted with blind rams. 7. Single 13-5/8", 10,000 psi WP, Hydril type MPL ram blowout preventer fitted with pipe rams. 8. 13-5/8", 10,000 psi WP drilling spool with one 3"and one 4" 10,000 psi WP outlets Choke Valves: 9. 4", 10,000 psi WP McEvoy Type E gate valve with hydraulic actuator 1 0. 4", 10,000 psi WP McEvoy Type E manual operated gate valve Kill Valve: 1 1. 3", 10,000 psi WP McEvoy Type E manually operated gate valve 12. 3", 10,000 psi WP McEvoy Type E gate valve with hydraulic actuator Revised 1/31/95 PRESSURE INFORMATION ARCO TEMPTATION #1 The following presents data used for calculation of anticipated surface pressures (ASP) during drilling for the Temptaion #1 well' Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure Drilling (in.) (ft. RKB) (lbs/gal) (lbs/gal) (psi) (psi) 1 6 1 20 10.9 8.6 5 3 5 5 9-5/8 1800 13.6 9.0 842 1075 7 7940 16.3 9.0 371 6 N/A Procedure for Calculating Anticipated Surface Pressure (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.11]D where' ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft RKB 2) ASP = FPP - (0.11 x D) where: FPP = Formation Pore Pressure at the next casing point ASP Calculations 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.11]D [(10.9 x 0.052) - 0.11] x 120 55 psi ASP = .... FPP - (0.11 x D) 842 - (0.11 x 1800) 644 psi 2. Drilling below surface casing (9-5/8") ASP = [(FG x 0.052) - 0.11]D : [(13.6 x 0.052) - 0.11] x 1800 = 1075 psi ASP= FPP - (0.11 x D) = 3716 - (0.11 x 7940) = 2842 psi Casing Performance Properties Size Weight Grade (in) (Ib/ft) 1 6 62.58 B Cnxn PEB 9-5/8" 53.5 L-80 BTC 7 26 L-80 Internal Collapse Tensil Strength Yield Resistance Joint Body (psi) (psi) (1000 lbs) Conductor Casing 7930 6620 1329 1244 BTC-Mod 7240 541 0 667 604 Casing Setting Depth Rationale 1 6" 120' RKB 9 - 5 / 8" 1800' RKB 7" 7940' RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to next casing setting point. Production casing to cover all open hole and all previously set casing to allow comprehensive testing of the well. This casing will not be set if logs indicate the well is a dry hole. SUPPORT DOCUMENTS FOR REQUEST FOR EXCEPTION TO 20 AAC25.035(b)(1) (Bifurcation of Diverter Line) ARCO Alaska, Inc. hereby applies for an exception to the provisions of 20 AAC 25.035(b)(1), concerning bifurcation of the diverter line. Following are the major concerns associated with this request. 1) After extensive study of the 1992 Cirque blowout and the performance of the equipment on Cirque, ARCO Alaska, Inc. has determined that a combination of one 16" line with no 90© turns is the optimum design. 2) Effective operation of remote valves positioned 100 feet from the rig are limited. 3) Prevailing winds on the North Slope during the winter drilling season are generally in the direction of NE to SW. With perpendicular placement of the diverter line, there is minimum exposure of gas blowing back onto an ignition source. It is our opinion that with proper placement of the diverter line with respect to prevailing winds in conjunction with the short duration of time while drilling under the diverter, a bifurcated line is not necessary. PROPOSED CASING AND CEMENTING PROGRAM ARCO TEMPTATION #1 (Per 20 AAC 25.005(c)(4)) Casing Size: Hole Size: Depth: Top of Cement: WELLBORE SCHEMATIC Excess Calculated: 16" Conductor @ 12I' RK ~ 12-1/4 Hol~ 9-5/8" Surface Casing @ 1,800' RKB 53.5 Ib/ft L-80 BTC 8-1/2" Hole Top of Cement at approx. 6,500' RKB TEMPTATION #1 Volume Calc: (120')(0.7855 cuft/ft)(2) = (189 cuft)/(0.93 cufVsk) = 203 sks 16'l 20" 120' RKB Surface 100% 203 sacks ARCTICSET I Slurry Volume 189 cuft Slurry Weight 15.7 ppg Slurry Yield 0.93 cu. ft./sk Mix water 3.59 gps Thickening time 2+ hours Casing Size: 9 5/8" Hole Size: 12 1/4" Depth: 1,800' RKB Top of Cement: Surface Excess Calculated: 100% BHT (Static): 60°F BHT (Circ): 60°F Volume Calc: Lead (900')(0.3132 cuft/ft)(2) = (564 cuft)/(1.94 cuft/sk)= 291 sks Volume Calc: Tail (900')(0.3132 cuft/ft)(2) = (564 cuft)/(0.93 cuft/sk)= 607 sks Lead: 291 sacks ARCTICSET III + 1/4 #/sk D29 (celloflake) Slurry Volume 564 cuft Slurry Weight 12.1 ppg Slurry Yield 1.94 cu. ft./sk Mix Water 11.11 gps Thickening time 6.0+ hours Tail: 607 sacks ARCTICSET I + 1/4 #/sk D29 (celloflake) Slurry Volume 564 cuft Slurry Weight 15.7 ppg Slurry Yield 0.93 cu. ft./sk Mix water 3.59 gps Thickening time 3+ hours Casing Size: 7" Hole Size: 8 1/2" Depth: 7,940' RKB Top of Cement: 6,500' RKB Excess Calculated: 20% (depending on caliper) BHT (Static): 170°F BHT (Circ): 140°F Volume Calc: (7940' - 6500')(0.1268 cuft/ft)(1.2) = (219 cuft)/(1.19 cuft/sk) = 184 sks 184 sacks Class G cement + 2 gps D600(latex) + 0.1 gps D135(stabilizer) + 0.1 gps D47 (defoam) + 3% D53(Gyp) + 0.7% D65(dispersant) + 0.05% D800(retarder) 7" Production Csg @ 7,940' RKB, 26 lb/h, L-80, BTC Mod Cemented to 500' above Jurassic Sands Slurry Volume 219 cuft Slurry Weight 15.8 ppg Slurry Yield 1.19 cu. ft./sk Mix water 5.18 gps Thickening time 3.5 - 4.5 hours PROPOSED DRILLING FLUID PROGRAM and DRILLING FLUID SYSTEM DESCRIPTION ARCO TEMPTATION #1 (Per 20 AAC 25.005(c)(6)) ARCO Alaska, Inc. Proposed Mud Program Temptation #1 (Colville Exploration) November 20, 1995 General Well Plan: A standard Kuparuk type fresh water spud mud (10.0 ppg) will be used to the 9 5/8" casing point. From there to TD, a fresh water LSND system similar to that used on last winter's Alpine and Fiord tests will be used to drill the 8 1/2" hole. The plan is to treat the fresh water spud mud for cement contamination when drilling out of the 9 5/8" surface shoe and drill ahead in the 8 1/2" hole to TD treating the system as a standard fresh water LSND system. However, as dictated by the actual drilling requirements of this well, an inhibited mud (KCl) may be required to address special coring or formation damage issues. Estimated Casing Program: Hole Size Casing Size 20" Conductor 12 1/4" 9 5/8" 8 1/2" 7" I. Surface Hole (12 1/4" Hole to 9 5/8" Casing): 1.) The current plan is to have 800 bbls of 10.0 ppg spud mud at the Baroid Prudhoe Bay Mud Plant to spud this well. The mud will be delivered to the rig with the following target properties: Density - 10.0 ppg Viscosity - 120 sec/qt YP - 35-40 lbs/100ft(2) pH - 9.0-9.5 To drill ahead, maintain the viscosity at initial levels to the base of the permafrost (800'-'1000') then reduce the viscosity as allowed based upon actual hole cleaning requirements. A funnel viscosity of 50 - 80 sec/qt may be suitable by the 12 1/4" TD. It should be noted that the actual mud viscosity requirements will vary in this area based upon the actual amount of surface gravel present at each specific location. However, generally only minimum gravel has been noted in this area allowing successful drilling with reduced viscosities. 2.) Due to concerns for gas below the permafrost and to reduce barite mixing activities during spud operations, spud the well with a 10.0 ppg mud weight and basically hold that mud weight to TD of the 12 1/4" surface hole at 1800'. While there is some mud weight latitude from spud to the base of the permafrost at 800'-1000', the mud weight should be a solid 10.0 ppg by the base of the permafrost then held at that weight to the 12 1/4" TD (or as dictated by actual hole conditions). 3.) PAC treatments can be initiated toward the 12 1/4" TD for improved well bore stabilization by reducing the API filtrate to 8-10 cc's. JAN Paae - i Alaska Oil & C.~,s Cons, 4.) Circulate and short trip the hole prior to running the 9 5/8" casing. A light. Desco-CF treatment will be useful to reduce the gel strengths of the mud prior to running the casing and cementing. Note: There should be adequate chemical treatment of the mud to insure rheological stabilization of the system prior to TOH to run the surface casing. As the cement contamination while drilling out of the surface casing on Alpine #1 created significant problems, extra focus should be made to insure this problem does not recur. Condition the mud prior to TOH to run the surface casing and then again after the surface casing has been landed and the rig is circulating the hole prior to the actual cement job itself. Target a pretreatment of 2 ppb Bicarb and I ppb PH6 with .5 ppb Therma-Thin (pilot test for specific treatments) to minimize the effects of the cement contamination when drilling out. When drilling out, continue with bicarb treatments to remove the excess calcium, add PH6 (citric acid) as required to neutralize the pH and treat with thinners as needed for rheological stabilization. 5.) Maximum utilization of solids control equipment is recommended throughout surface hole drilling operations to keep the sand content less than 1% by volume and improve overall drilling conditions. II. 8 1/2" Hole (From 9 5/8" Shoe to Top Zone of Interest): Again, assuming normal spud operations and a salvageable spud mud, the plan is to clean-up the spud mud as required while NU on surface casing and drill ahead with the conditioned spud mud into the 8 1/2" hole. The system will be maintained as a standard fresh water gel/PAC LSND system (as done on the Alpine #lA and #lB sidetracks) for this interval of the well. Mud treatments should be based on an as needed basis for the 8 1/2" hole. 1.) The important initial properties for the initial 8 1/2" hole would include a neutral pH in the 8.5 to 9.0 range, YP in the 10-15 lbs/100 SF range and an API filtrate in the 6-8 cc range. The initial funnel viscosity should be in the 40 to 50 sec/qt range or as dictated by actual well bore conditions. For drill-out, the initial mud weight requirement is for a 9.8-10.0 ppg mud weight. As drilling continues in the 8 1/2" hole, the mud weight should be increased on an as needed basis with barite. The maximum mud weight for the 8 1/2" hole should be in the 10.2 - 11.0 ppg range. To reduce or control the mud weight while drilling ahead, maximize the solids control equipment efficiency and dilute with fresh water as required. Some rig site solids analysis will be required to identify the best mechanism for overall solids control. 2.) The viscosity of the mud in the 8 1/2" hole can be sustained with additions of Aquagel and extender and/or PAC treatments. Xanvis or Biozan can also be used to provide good LSRV support on an as needed basis. These viscosity treatments should be based upon actual hole cleaning requirements. Page - 2 3.) Maximize all solids control efforts. Run as fine as screens possible on the shale shakers. The use of the rig's desander, desilters/mud cleaners and centrifuge should be based upon daily mud solids analysis versus the current mud objectives. With a weighted mud from spud to TD (10.0 ppg+), the application of the various pieces of solids control equipment will change based upon the changing condition of the mud itself. 4.) Treatments with PAC polymers should be used throughout this section of the hole to control the API filtrate in the 6 to 8 cc range or as required based upon actual well bore conditions. Low viscosity or regular viscosity PAC products are available for use. 5.) Control excessive rheological conditions with additional Therma-Thin treatments on an as needed basis. Therma-Thin is an effective polymer deflocculant designed to provide effective rheological stabilization. By maintaining a .25-.5 ppb concentration of Therma-Thin in all make-up additions, better rheological stability will be observed. 6.) The commercial bentonite (Aquagel) concentration should be kept at 2-4 ppb minimum through this intermediate section of hole. 7.) Dilute as necessary and maintain volume with fresh water as required. 8.) Maintain the pH in the 8.5 - 9.0 range with caustic soda additions. 9.) Torq-Trim II or ConDet treatments may be required to reduce balling problems through the "sticky" clays found in this interval of the well. 10.) Continue with tourly treatments of Aldicide-G while drilling this interval of the well. A 5-10 gal/tour treatment rate has proven effective in recent North Slope work. III. 8 1/2" Hole (~From of Top Zone of Interest to TD): 1.) Prior to drilling into the zone of interest, the mud should be conditioned as follows'to insure mud stability and to reduce the API filtrate for pay-zone protection. One should expect a minimum dilution of 10-15% with fresh water to re-adjust total solids and to make the system receptive to the following treatments: A. Run the pH in the range of 8.5-9.5 with caustic soda. B. The API filtrate should be reduced to the 4-5 cc range with Baranex and PAC's at a 3 : 1 ratio. This will probably require approximately 3 ppb Baranex and .5-1.0 ppb PAC's. Target a HTHP filtrate of 15 cc's at 200 degrees. C. Be aggressive with biocide (Aldacide-G) treatments to reduce/minimize bacterial degradation. A field kit is available to monitor the residual biocide concentration. D. Continue with fresh water dilution as required to adjust the total solids content of the mud. Page - 3 E. Adjust the mud weight as required with Baroid (barite). The anticipated mud weights for this interval of the well is between 10.0 and 11.0 ppg. 2.) To control excessive rheology, treat as required with Therma-Thin (a polymer deflocculant) and/or Desco CF (tannin powder). 3.) At TD, conditioned for logs and possibly a 7" casing job. Primary focus should be on rheological stabilization with caustic treatments for pH control and Desco-CF, Therma-Thin and/or Enviro-Thin thinners to control excessive rheological trends. IV. Suggested Mud Properties: Upper Lower Surf. 8 1/2" 8 1/2" Density 9.8-10.0 9.8-10.2 10.0-11.0 PV 15-25 10-25 20 YP 20-40 10-20 15 Viscosity (Initial) 80-120 40-50 45 (Final) 50-80 Ini. Gel 5-15 5-10 5 10 min. Gel 15-35 10-15 15 API Fil. (Initial) 10-20 6-8 <5 (HTHP @15) (Final) 8-10 pH 9-9.5 8.5-9.0 8.5-9.5 %Solids 4-10 <6% LGS <6% LGS Page - 4 POOL ARCTIC ALASKA RIG #6 DRILLING FLUID SYSTEM 'l .Ud NOLLSflS 7111] Ot, l Lid T/Id 788 J.Id t~FIIOA 188 li] ~ JJd 30/I.~I~N']..q ~ ~ mm M mo = ~NVl 39V'dOJ3 Z ]SflOHlO01 ~0013 ~JtLN3O lO~LbNO0 ~010N ~W NO08 8O$ i oo 3SflOHgOO PRESSURE ANALYSIS ARCO TEMPTAION #1 (Per 20 AAC 25.005(c)(7), as required in 20 AAC 25.033(e)) ARCO TEMPTATION #1 ANTICIPATED PORE PRESSURE, MUD AND FRACTURE GRADIENT WEIGHT, -1000 SURFACE CASING 1800' -2000 -3000 -4000 -5000 -6000 -7000 -8000 8 9 10 11 12 13 14 15 16 17 18 EQUIVALENT MUD WEIGHT (LB/GAL) ARCO BERGSCHRUND -1000 -2000 -3000 MUD WEIGHT CURVE MARCH 1994 -4000 -5000 -6000 -7000 -8000 8 9 10 11 12 13 14 15 16 17 18 MUD WEIGHT LB/GAL -1000 -2000 -3000 -4000 -5000 -6000 -7OO0 -8000 ARCO ALPINE #1 MUD WEIGHT CURVE JANUARY 1995 , , , ~-- ', ~q'~M LOT 14.6 LB/GAL 13-3/8" SURFACE I i ~ .............. ~'"':'""~ ......................................... - -- bA'SIRG' @'1¢65~ ~-- ~-- ~ ~ ~ ~ -!~ ..... ................ ~"-"-~ '-'~ .... ~ ........... ~ ............ ~ ................. ~ ~ .............. ~...~ .............. __~~, ~_ ~ ....... ~- ~~ ~ .............. ...... ....... ~ ............ ...., ~ ....... .................................. 8 9 10 11 12 13 14 15 16 17 18 MUD WEIGHT (LB/GAL) Date: Subject: January 3, 1996 Pore Pressure Prediction for the Temptation #1 Well (TXCO86-04) correlated to the Alpine #1 Well. From: lA Wydrinski AEPT D. Gingrich AAI Telephone: 265-6465 This letter is to summarize the pore pressure work done in the Colville area using the above data. The slope and intercept for the normal pore pressure trend was determined from the Alpine #1 well; and the seismic velocity from TXCO86-04 was used for the Temptation #1 location. There are no large pressure anomalies at this well location. Seismic line WKE95-17 was also processed but there was a velocity anomaly at 2000'. The signature of this velocity anomaly looked much different than the other velocities in the area. After consulting with Herb Swan and Keith Ritchie at AEPT, it appears this seismic anomaly is due to changing permafrost depths along the line. This seismic line transitions from land to water to land and back to water in this immediate area. The orientation of TXCO86-04 keeps this line on land. Seismic Processing: The accuracy of Geopressure prediction is highly dependent upon the accuracy of the seismic stacking velocity field that is used as input. This velocity field is generated by picking velocities at every CDP location with an automated high resolution velocity analysis program (UHCI process developed by AEPT). This process produces a very accurate and densely sampled velocity field to cover every CDP location. The RMS velocities that are output have been smoothed over 300 ms vertically and 150 CDPs horizontally to normalize any instabilities in the velocity field that might result from noise, lack of signal, or variations in CDP fold. Pressure Prediction Procedure: ARCO's PPFG software was used to calculate the pore pressures. the steps taken for the other seismic lines to calculate the pressures: These were 1) The Gamma Ray log from the Alpine #1 well was used to distinguish the sand intervals from the shales. 2) A Normal Compaction Trend Line (NCTL) was determined in the shales from the wireline sonic data for this well. This line indicates the predicted sonic value if these shales were normally compacted (no 3) 4) pressure). If the sonic delta T increases past the compaction line, (this change is AAT), then there is an indication of an increase in pressure. Using the mud weight data from the Alpine #1 and Bergschrund #1 wells, a Translational Trend model was developed to convert the AAT to equivalent mud weight (PP). This equation is · PP = C: * AAT 2 + C~ * AAT + Co where C2 = -1.34 e-05; C1 = .0062; Co = .465 This NCTL and Translational Trend was used for the seismic line. Alpine #1 Figure #1 is the pore pressure plot from the wireline sonic data. The curves from left to right are: 1) The black curve is the sonic log. The green dots are the shale 2) 3) 4) 5) 6) intervals. The red line is the Normal Compaction Trend Line. The blue curve is the pore pressure. The green curve is the actual drilling mud weights. The red curve is the fracture gradient. The points labeled "pressure" are RFT measured pressures in equivalent mud weight. "LOT" is the leak off test in equivalent mud weight. There are no major pressure intervals in this well. There are some minor ones at 2000' and 3800' where the mud weights may need to be increased to 10 ppg. At 6800', there is an increase in the sonic AT which is attributed to the kerogen in the shales. This can be seen on the Gamma Ray increase on the logs. Since there was only one leak off test, it was difficult to create a fracture gradient curve. A Gulf of Mexico trend curve was used in this model and appears to be pessimistic. TXCO86-04 (Temptation #1) Figure #2 on the right side of the plot is the velocity (Red line) from CDP 1600. The green line is the NCTL. The left side of the plot is the change in travel time verses depth. Figure #3 is the pore pressure plot at CDP 1600 (Temptation #1 location). There is no pressure until 7400'. The pressure deeper than 7400' may be due to the kerogen in the shales or lithology changes. Figure #4 is the pore pressure plots over the seismic interval verses depth and Figure #5 is verses time. Ray Wydrinski Dean Gingrich ~000 2000 9000 : : ~000 2000 8000 4000 5001 5000 600~ i ~ooo 7000 7000 8000 8000 8~2 20 ~ARCO ~×ploration amd Pmductio~ Technology ~'~ Pore Pressure a~d Fracture Gradieat System 2/ 2/95 Ra~dr ils ( S~le: Verdcal 1 in = ~6790, I toriTonlal I in = 185 ~ TF. ST CDP ~ 22223 6 02570 0 05 50 MSL 0.0- 334444 570257 050505 TT~tEM PTATION I TEST4 [ I 1 l I t I [ i I I I I I I I I [ 2 2 2 22 22 5 5 5 6 6 6 6 7 7 7 7 8 8 8 9 9 9 9 0 0 0 0 I I 1 2 57025702570 4 702570257025 o 05 o5o 50 ~ 9~ 9 9 70505o50505o usec/ft Prqiect Name: COLVILLE_AAI Cross Section: TXCO04 ITl' DataSet: VELF_DT CDP 1600 Well: q%MPTATION_I Trend Liie Feet (Dalum sel to MSL) MSL40 60 80 100 120 t60 D E P T H fit) [250,0 25(X)J 50(X}.1 625{).0 1250 190,0 180.0 170.0 160.0 ] 50,0 -- 140.0 1300 375(/ 90.0 80,0 70.0 60.0 50.0 40.0 6250 7500,0 7500 8750,0 ~ARCO Exploration and Production Technology Pore Pressure and Fracture Gradient System Pro.iuc[ Nmne: COLVILLE AAI Cross Secdon: T×CO04 PP DataSet: PLEIS18045_PPG Method: Trend Curve NCTL: SSTXO4_180_45 Me×la: PLIESTOCENE D E P T H (f0 12/12/9.5 Ray Wyddnski TEST TSFEMPTATION I TF~$T4 CDP I 222233334444 5 55666677778 8 89 6 02570257025 7 2 57 025702570 4 70 0 050505050505 0 05050505050 0 50 MSL 0.0- t250,0' 25~3.0 3750,0 50{~X0- 6250,0- ~, ~500.0- 112222222 990000111 570257025 050505050 PPg .00 .50 9.00 9.50 i 0.50 1.50 2.00 12.51) 13.50 14.50 16.50 PPG curve a/CI)P 1600 Feet (Datum set to MSL) MSL 8 I0 12 14 16 18 20 22.2, Z2,Z;; ........................ J I 3750 5f×}0 6250 7500 [2/12/95 Ra~drinski TEST CDP ~, 6 8 0 0 0 0 0 0 0 0 0 0 0 0 0 MS[. 0.0 I250.0 2500.0 D 3750.0 E P T H (It) 50(x).o 6250.0 Prl~iect Name: COLVILLE_AA~ Cross Section: TXCO04 PP DataSet: PLEiSIS045_.PPG Seismic DataseE TXCO-4_Z Scale: Vertical [ ia = 1679 fl Hc~izonlal I in = 123 cdp 233333444445 802468024680 000 T3 TEMPTATtONI 55556666 24680246 00000000 Melhod: Trend Curve NCTL: SSTX04_180_45 Modeh PL[ESTOCENE TEST4 7 7 7 7 7 8 8 8 8 8 9 9 9 9 9 0 0 0 0 0 1 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 PPg 8.50 9.(x) 9.50 10.00 12.50 14.50 15.00 15,50 16.50 17.00 t8.50 t9.00 750(J.0, ARCO Exp~omtioa and Production Technology Pro.icc, N~,,,,~: COLVILLE_AA[ Cross Section: TXCO04 Pore Pressure and Fracture Gradient System P~'~a.~S~: PLE~S18045_PPG_T Seismic Dataset: TXCO-4 ~/ 2/~5 Ray Wydr Ilsk Scak: Vertical I in = 330 msec, Hofimn~aJ I in = 123 cdp TEST CDP ~ ~ 2 2 2 250.0 500.0 750.0 1000.0 1250.0 T I M E (ms) Method: Trend Curve NCTL: SST×04_lfl0_ 45 Model: PL, IESTOC ENE 2 3 3 3 3 3 4 4 4 4 4 5 5 5 5 5 6 6 6 6 6 7 7 7 7 7 8 8 8 8 8 9 9 9 9 9 0 0 0 0 0 I I l 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 5 o o o 9 o o o 9 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 o o 0 0 0 0 0 0 0 0 o 0 o o PPg 8,00 8,50 10.50 12.00 12.50 14,50 19.00 PROPOSED DRILLING PROGRAM ARCO TEMPTATION #1 (Per 20 AAC 25.005(c)(10)) Surface Hole Drilling Hazard Section Temptaion #1 No specific drilling hazards are expected. Analysis of shallow seismic data does not show any abnormal velocities and offset wells have not encountered any shallow gas. Normal drilling precautions for Exploration drilling should be taken. Minor drill gas and hole sloughing should be expected at the base of the permafrost. Base of permafrost is expected at +_850' RKB. Production Hole Mud weight should be 9.8-10.0 lb/gal prior to drilling the C-30/K5 interval at 2250'. This interval in offset wells contains gas that is thought to be slightly pressured at 9.6 lb/gal. Normal drilling precautions for Exploration drilling should be taken throughout the hole. JAN 0 9 19-3-5 Anchorage Temptation #1 : General Drilling Procedure Application for Permit to Drill January, 1996 (All depths are measured from RKB unless otherwise noted) Move in rig and rig up over pre-installed 16" conductor and cellar. Nipple up and function test diverter. Rig up mudloggers. Make up 12-1/4" bit and bottom-hole assembly and drill surface hole to 1,800' RKB. Run and cement 9-5/8" surface casing. Nipple down diverter, make up casing head, nipple up and test BOPs to 3000 psi. Pressure test 9-5/8" casing to 2500 psi. Drill out cement and float equipment with $-1/2" bit. Drill 10' of new hole and perform leak-off test. POOH. Make up 8-1/2" bit and bottom-hole assembly with MWD/LWD (GR-Res). Drill 8- 1/2" hole to TD. If warranted, run open-hole logs from TD to the 9-5/8" casing shoe. If log results are favorable, run and cement 7" casing. Nipple down BOP stack, nipple up tubing head, nipple up and test BOP stack. Run cased hole logs if required. Pressure test 7" casing to 3,500 psi. Freeze protect 9-5/8" X 7" casing annulus. Run in hole with conventional DST string or completion-type test string. Install and pressure test 5,000 psi tree, tool string and manifold. Perforate well underbalanced using tubing-conveyed guns. Flow up the tubing and through surface testing facilities. Test liquids will be stored in tanks on the drilling location and pumped back into the reservoir or hauled to Kuparuk and processed through Kuparuk facilities.. Gas will be flared. Testing will involve alternating flow periods and shut-in periods. Individual intervals may be tested separately or concurrently. For long-term flow testing, the rig will be moved off location prior to perforating and will be moved to a different, but nearby, drilling location. After completion of testing, abandon well per AOGCC regs. Rig down and release drilling rig. Thoroughly clean and abandon the ice pad and ice road on the way out. -1000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 TEMPTATION #1 STRAIGHT HOLE 1996 COLVILLE EXPLORATION ........................ LL ~. i DRi 1~2.1/4,, HOLETO 1800,- ! ~-- i i, .......... ...... ........ ......... ....... j. SET 9-5/8" CASING, N/U WELLHEAD AND BOP ........................ _[ ...... ~. ]. .............................................................. . ................ .. . I ! 1 t ...... , ' I ........... [¥ DRILL 8-1/2" HOLE TO TD .......... t ~' ' ....... ~ ~ = ~ ...... : ....... . .~;.'~;~.~-'t ............................... TD: 7940' RKB ZE'~] P ~';i i I I .................... 0 5 10 15 20 25 30 DAYS ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 8, 1996 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Temptation #1 Dear Commissioner Johnston, ARCO Alaska, Inc. hereby applies for a Permit to Drill an onsho~:e exploratory well, the ARCO Temptation #1, on State lands near the mouth of the Colville River. ARCO will act as operator for itself, Union Texas Petroleum and Anadarko Petroleum Corporation in evaluating acreage previously leased by ARCO, et al in Lease Sale 75 in December, 1992 from the State of Alaska and the Arctic Slope Regional Corporation. The proposed well location is approximately 5-1/4 miles northwest of the ARCO Alpine #1 drilled last winter. The wellsite will be accessed via ice road originating at KRU 2M Pad. ARCO plans to use Pool Rig No. 6 to drill this well from an ice pad during the winter of 1995-96. Attached find the information required by 20 AAC 25.005(c) and 20 AAC 25.061. All waste drilling mud and cuttings generated during the drilling of Temptation #1 will be hauled to either the Kuparuk River Field or Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be at the base of the Nechelik Formation which underlies the Kuparuk Formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Fommtion. Therefore, ARCO has not included an H2S contingency plan with this Application and requests an exempnon ~e H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. ARCO also requests an exception to the shale density requirement in ~. Tile shale density technique does not work.welt in Alaska due to the va~ble composition of the shales and the chemical used in the shale density column is listed as an exceptional health hazard. The Commission is requested to keep confidential the following attachments to this permit application which are drawn from research and data proprietary to ARCO Alaska, Inc.: Pressure Information Proposed Drilling Fluid Program Pressure Analysis Proposed Drilling Program JAN 1996 Alaska Oil & Gas Cons. Commission Anchorage AR3B-6003-93 242-2003 Finally, the following are ARCO's designated Contadts for reporting responsibihfles to the Comlnission: 1) Weekly Status Report Fred Johnson, Drilling Engineer 265-1492 2) Completion Report (20 AAC 25.070) Fred Johnson, Drilling Engineer 265-1492 3) Geologic Data and Logs (20 AA C 25.071 ) Mark McDermott, Explorationist 265-6394 If you have questions or require additional information, please contact Fred Johnson at 265-1492 or myself at 265-6206 in our Anchorage office. Sincerely, i Supervisor Kuparuk Drillsite Development JAN 0 ~ ]996 .Alaska Oil & Sas "~',.,. · Anchorage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-31 92 Re: THE APPLICATION OF/~,RCO ) ALASKA, INC. for an order granting an ) exception to spacing requirements of ) Title 20 AAC 25.055 to provide for the ) drilling of seven delineation oil wells in ) the Colville Delta vicinity. ) Conservation Order No. 367 ARCO Alaska, Inc. Nanuk No. 1, Neve No. 1, Neve No. lA, Neve No. lB, Temptation No. 1, Alpine No. 3, Bergschrund No. 4, IT APPEARING THAT: January 3, 1996. ; ARCO Alaska, Inc. submitted applications dated December 7, 1995 requesting exceptions to the well spacing provisions of Title 20 AAC 25.055 (3) to allow drilling the ARCO Neve No. 1, Neve No. lA, Neve No. lB, Nanuk No. 1, Temptation No. 1, Alpine No. 3 and Bergschrund No, 4 delineation oil wells to locations within 500 feet of a quarter-section line in the Colville Delta vicinity of the North Slope. 2. Notice of opportunity for public hearing was published in the Anchorage Daily News on December 15, 1995 pursuant to 20 AAC 25.540. 3. No protests to the applications were received. FINDINGS: , The Neve No. 1 delineation oil well as proposed will be drilled as a straight hole at a location 465' from the north line and 2440' from the west line of Section 14, T11N, R4E, Umiat Meridian (UM). , The Neve No. lA delineation oil well as proposed will be drilled as a deviated hole with a surface location 465' from the north line and 2440' from the west line of Section 14, T11N, R4E, UM and bottomhole location 2960' from the north line and 530' from the west line of Section 14, T11N, R4E, UM. , The Neve No. lB delineation oil well as proposed will be drilled as a deviated hole with a surface location 465' from the north line and 2440' from the west line of Section 14, T11N, R4E, UM and bottomhole location 640' from the south line and 3290' from the west line of Section 11, T11N, R4E, UM. . The Nanuk No. 1 delineation oil well as proposed will be drilled as a straight hole at a location 2290' from the north line and 1140' from the west line of Section 30, T11N, R5E, UM. . The Temptation No. 1 delineation oil well as proposed will be drilled as a straight hole at a location 1890' from the south line and 540' from the west line of Section 16, T12N, R4E, UM. The Alpine No. 3 delineation oil well as proposed will be drilled as a straight hole at a location 2145' from the north line and 2115' from the west line of Section 25, T12N, R4E, UM. .. Conservation Order No.~, January 3, 1996 Page 2 . . The Bergschrund No. 4 delineation oil well as proposed will be drilled as a deviated hole with a surface location 960' from the north line and 1620' from the west line of Section 9, T11N, R5E, UM and bottomhole location 535' from the south line and 20' from the west line of Section 4, T11N, R5E, UM. All owners and operators of governmental quarter sections directly and diagonally offsetting the quarter section proposed for each of the subject wells has been duly notified. 9. An exception to the well spacing provisions of Title 20 AAC 25.055 (3) is necessary to allow the drilling of each of the above listed wells. CONCLUSION: Granting a spacing exception to allow drilling of the ARCO Neve No. 1, Neve No. lA, Neve No. lB, Nanuk No. 1, Temptation No. 1, Alpine No. 3 and Bergschrund No. 4 wells will not result in waste nor jeopardize correlative rights.. NOW, THEREFORE, IT IS ORDERED: ARCO Alaska, Inc.'s applications for exception to the well spacing provisions of Title 20 AAC 25.055 (3) for the purpose of drilling the seven wells described above are approved. DONE at Anchorage, Alaska and dated January 3, 1996. J Dawd No,on, P E, Comm~ssmner Alaska Oil and Gas 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 an application for rehearing. A request for rehearing must be received by 4:30 PM on tho 23'd day following the date of the order, or next working day if a holiday or weekend, to bo timely filed. The Commission shall grant or refuse tho application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within tho lO-day period. An affected person has 30 days from tho date tho Commission refuses tho application or mails (or otherwise distributes) an order upon rehearing, both being tho final order of tho Commission, to appeal the decision to Superior Court. Where a request for rehearing is. denied by nonaction of the Commission, tho 30-day. period for appeal to Superior Court runs from tho date on which tho request is deemed denied (i.e., 10th day after the application for rehearing was filed). NELL PERMIT CHECKLIST COMPANY F~-//- ~___ _,~ INIT CLASS ~_.;d. . WELL NAME PROGRAM: exp~ dev ri, redrll [] serv [] wellbore s~ UNIT# ~ ~4 ON/OFF SHORE DMINISTRATION ENGINEERING 1. Permit fee attached .................. N 2. Lease number~appropriate ............... ~N~ 3. Unique well name and number .............. ~Y_ ~u 4. Well located in a defined pool .............. Y~-~ 5. Well located proper distance from drlg unit boundary. · .Y__% N~_~/ 6. Well located proper distance from other wells ..... ~ N 7. Sufficient acreage available in drilling unit ..... ~ N 8. If deviated, is wellbore plat included . . ~/'/~- . .~-~' Y N 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... -.Y~ N~ 11. Permit can be issued without conservation order ..... Y ~ 12. Permit can be issued without administrative approval..~ N 13. Can permit be approved before 15-day wait ....... ~ N REMARKS 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. . N 17. CMT vol adequate to tie-in long string to surf csg . . .~ ~ 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. Adequate wellbore separation proposed .......... 22. If diverter required, is it adequate .......... ~ N 23. N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ............. ~ ..... ~- N 26. BOPE press rating adequate; test to ~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y ,, GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. · .~.Y~ N 31. Data presented on potential overpressure zones .... ~ N 32. Seismic analysis of shallow gas zones ......... N 33. Seabed condition survey (if off-shore) . . A~/,~ .... N 34. Contact name/phone for weekly progress reports .... ~ N [exploratory only] GEOLOGY.: ENGINEERING: COMMISSION: DWJ~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : TEMPTATION #1 FIELD NAME : WILDCAT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-103-20233-00 REFERENCE NO : 96114 1996 LIS Tape Verification List,ing Schlumberger Alaska Computing Center 28-APR-1996 12:59 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/04/28 ORIGIN : FLIC REEL NAME : 96114 CONTINUATION # PREVIOUS REEL : COM~ENT : ARCO ALASKA INC., WILDCAT, TEMPTATION #1, API #50-20233-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 96/04/28 ORIGIN · FLIC TAPE NAME : 96114 CONTINUATION # : 1 PREVIOUS TAPE : CON, CENT : ARCO ALASKA INC., WILDCAT, TEMPTATION #1, API #50-20233-00 TAPE HEADER WILDCAT MWD/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: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN 1 96114 WARNER CAMPAIGN WELL CASING RECORD 1ST STRING 2ND STRING TEMPTATION #1 501032023300 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 28-APR-96 BIT RUN 2 BIT RUN 3 16 12N 4E 1891 539 33.60 32.10 2.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 1817.0 LIS Tape Verification Listin. g Schlumberger Alaska Computing Center 28-APR-1996 12:59 3RD STRING PRODUCTION STRING REMARKS: THIS LIBRARY TAPE CONTAINS THE MODIFIED LDWG FORMATTED DATA ON ARCO ALASKA INC'S TEMPTATION #1. DATA ACQUIRED: LOGGING WHILE DRILLING CDR, WIRELINE DIPOLE SONIC, LDT LITHODENSITY, CNTG COMPENSATED NEUTRON. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 96/04/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AUJMBER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMPiARY LDWG TOOL CODE START DEPTH DAS 7684.0 SDN 7742.0 CNTG 7723,0 CDR 1824.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 7662.5 7652.5 7651.0 7650.5 7635.0 7634.0 7632.0 7608.5 7599.0 7598.5 7597.5 7589.0 7576.5 STOP DEPTH 100.0 1817.0 1817.0 7708.0 t.... .......... EQUIVALENT UNSHIFTEDDEPTH .......... CDR SDN CNTG 88888,5 88888.0 88887.0 7651. S 7636.0 7633.0 7599.0 7590,0 7577,0 7662.5 7651.5 7651.5 7632.5 7608.0 7598.5 7598.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-APR-1996 12:59 PAGE: 7575 7575 7573 7561 7557 5 7545 0 7538 0 7530 0 7523.5 7521.5 7513.5 7509.5 7497.5 7493.5 7486.0 7476.0 7445.5 7434.5 7424.5 7408.5 7408.0 7396.0 7382.5 7370.0 7365.5 7364.0 7359.5 7355.5 7345.0 7343.0 7337.0 7336.0 7332.0 7322.0 7308.0 7305.5 7294.5 7285.0 7278.5 7278.0 7277.5 7277.0 7275.0 7258.5 7248 0 7239 5 7223 5 7203 0 7184 0 7182, 0 7181.0 7175.0 7171.0 7160.5 7160.0 7574.5 7546.0 7539.5 7530.5 7514.0 7510.5 7498.5 7494.0 7487.5 7477.5 7446.5 7435.5 7425.5 7397.0 7384.0 7371.0 7365.0 7356.5 7345.5 7342.5 7333.5 7323.0 7308.5 7296.0 7285.0 7279.0 7278.0 7259.5 7240.0 7224.0 7184.5 7171.5 7160.0 7575.0 7558.5 7523.0 7514.0 7407.5 7345.5 7336.0 7278.0 7181.0 7575.0 7562.0 7520.5 7514.0 7407.5 7395.0 7365.0 7359.0 7336.5 7305.0 7278.0 7273.5 7247.0 7202.0 7181.5 7175.0 7160.0 LIS Tape Verification Listing 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6779 0 6774 5 6772 0 6759 5 6749 5 6747 5 6739.5 6734.5 6728.0 6724.5 6724.0 6722.0 6721.5 6720.0 6709.5 6703.5 6701.5 6696.5 6695.0 6680.5 6676.0 6675.0 6667.5 6656.0 6650.5 6648.5 6647.5 6640.0 6633.0 6632.5 6630.5 6624.0 6622.0 6621.0 6614.5 6592.0 6570.5 6570.0 6566.0 6553 5 6553 0 6539 0 6528 5 6527 0 6513 0 6506.5 6813.0 6788.5 6780.5 6761.5 6751.5 6736.0 6730.0 6724.0 6712.0 6703.5 6697.0 6682.5 6652.0 6642.0 6632.5 6625.5 6623.0 6616.0 6594.0 6568.0 6554.5 6540. 0 6528.0 6513.0 6813.0 6806.0 6788.5 6740.5 6723.0 6703.0 6695.5 6675.0 6647.0 6632.5 6622.5 6569.5 6809.5 6799.0 6788.5 6779.5 6772.0 6770.0 6746.0 6723.5 6721.5 6719.0 6703.0 6695.5 6674.5 6667.5 6656.0 6647.5 6632.0 6620.5 6569.5 6564.5 6553.5 6528.0 6505.5 LIS Tape Verificati'on Listi'ng Schlumberger Alaska Computing Center 28-APR-1996 12:59 PAGE: 6504.5 6503.0 6495.0 6490.0 6489.0 6488.0 6481.0 6480.5 6478.5 6469.0 64 68.5 6463.0 6462.5 6454.0 6452.5 6434.5 6432.5 6417.0 6416.5 6413.5 6403.0 6376.5 6374 5 6372 0 63 62 5 6358 5 6356 5 6355 0 6354 5 6345 5 6338 5 6335 5 6332 5 6323.5 6316.0 6314.0 6308.5 6307.5 6298.5 6298.0 6296.5 6286.0 6285.5 6282.5 6276.5 6272.0 6270.5 6266.0 6260.0 6256.5 6251.5 6249.0 6244.5 6237.0 6232.0 6505.5 6503.5 6496.5 6489.0 6479.5 6470.0 6463.5 6453.5 6434.0 6418.0 6404.5 6376.0 6364.5 6356.0 6347.5 6334.5 6325.5 6316.0 6307.5 6298.0 6285.5 6278.0 6274.0 6272.5 6267.5 6258.5 6246.5 6232.5 6489.0 6479.5 6453.5 6413.5 6375.5 6338.5 6297.5 6286.0 6249.5 6489.0 6479.5 6467.5 6461.0 6451.5 6433.5 6415.5 6375.5 6370.5 6361.5 6358.0 6355.0 6353.0 6335.0 6312.5 6306.5 6297.5 6295.0 6286.0 6282.5 6259.5 6251.0 6236.0 LIS Tape Verificati'on Listing Schlumberger Alaska Computing Center 28-APR-1996 12:59 PAGE: 6219.0 6210 0 6209 5 6204 5 6202 0 6189 5 6181 5 6176.5 6174.5 6170.0 6166.5 6165.5 6159.0 6151.5 6142.0 6123.0 6122.5 6112.0 6105.0 6102.5 6099.5 6085.5 6078.5 6069.0 6064.5 6062.5 6060.0 6049.0 6037.5 6035.0 6031.0 6027.5 6019.5 6017.0 5990.5 5987.0 5976.5 5974.0 5966.5 5955.5 5953.5 5952.5 5951.0 5947.0 5941.0 5936.0 5924.0 5923.0 5914.5 5905.0 5899.5 5891.0 5889.0 5887.5 5885.5 6221.0 6205.0 6192.0 6179.0 6169.0 6161.0 6144.0 6125.0 6114.0 6107.5 6102.0 6088.0 6072.0 6066.5 6062.0 6051.0 6037.5 6029.5 6020.0 5989.5 5976.5 5969.0 5958.5 5956.0 5953.5 5949.5 5939.0 5926.0 5917.5 5907.0 5890.5 5888.5 6209.5 6166.0 5976.5 6209.5 6204.0 6181.5 6174.0 6169.0 6151.0 6122.5 61 O1.5 6077.5 6061.5 6035.5 6029.0 6017.5 5988.5 5954.5 5942.0 5924.0 5899.0 5890.5 5888.5 5886.0 LIS Tape Verificati'on Listing Schlumberger Alaska Computing Center 28-APR-1996 12:59 PAGE: 5874.5 5870.0 5862.0 5855.0 5847.0 5842.5 5837.0 5835.0 5834.0 5830 5 5827 0 5814 5 5814 0 5793 0 5785 0 5776 0 5764.5 5762.0 5758.0 5746.0 5734.5 5731.5 5722.5 5721.0 5719.5 5712.0 5705.5 5695.5 5689.5 5682.0 5662.0 5660.5 5660.0 5658.0 5654.5 5651.0 5650.0 5645.5 563 6.5 5636.0 5634 0 5630 5 5628 5 5621 0 5608 0 5606 5 5606.0 5604.0 5597.0 5591.5 5587.0 5573.5 5551.5 5540. 0 5522.0 5877.0 5857.0 5850.5 5844.5 5837.0 5833.5 5817.0 5795.0 5789.0 5780.0 5761.5 5752.5 5735.5 5726.0 5723.5 5722.0 5714.5 5691.5 5684.5 5665.5 5662.5 5652.5 5648.0 5636.0 5630.5 5623.5 5611.5 5606.5 5600.5 5588.5 5575.5 5555.0 5524.5 5837.0 5762.0 5696.5 5636.5 5630.0 5606.0 5870.0 5861.0 5834.0 5827.5 5814.0 5764.0 5734.5 5705.5 5660.5 5658.5 5653.5 5649.0 5636.5 5606.0 5591.0 5539.5 LIS Tape Verification Listi'ng Schlumberger Alaska Computing Center 28-APR-1996 12:59 PAGE: 5514 5511 5505 5504 5492 5489 5 5485 0 5467 5 5462 5 5458 0 5446.5 5445.5 5431.5 5413.0 5411.0 5398.0 5376.5 5375.5 5373.5 5358.5 5357.0 5349.5 5341.5 5341.0 5339.0 5333.0 5314.0 5307.5 5296.0 5291.0 5289.5 5274.5 5266.0 5259.5 5258.0 5249.5 5236.0 5233.5 5229.5 5515.0 5507.0 5494.0 5491.5 5464.5 5459.0 5412.0 5399.0 5378.0 5358.5 5350.5 5341.0 5335.0 5316.0 5292.5 5275.5 5260.5 5236.0 5445.0 5375.5 5358.5 5341.0 5234.0 5513.0 5504.5 5484.5 5467.0 5445.0 5431.5 5412.0 5375.5 5373.5 5358.5 5341.0 5307.0 5295.5 5289.5 5266.0 5257.5 5248.5 5229.5 TABLE TYPE : CONS TUNI CN FN WN APIN FL SECT TOWN RANG COUN STAT VA L U ARCO ALASKA, INC. WILDCAT TEMPTATION #1 50-103-20233-00 0539 FWL & 1891 FSL 16 12N 4E NORTH SLOPE ALASKA DEFI Company Name Field Name Well Name API Serial Number Field Location Section Township Range County State or Province LIS Tape VerificatiOn List£ng Schlumberger Alaska Computing Center 28-APR-1996 12:59 PAGE: 10 TUNI VALU DEFI NATI USA LATI 70. 392N LONG 150 . 153W WITN CAMPAIGN SON 630382 PDAT MSL EPD FT O . LMF RKB APD FT 33.6 EKB FT 33.6 EDF FT 32.1 EGL FT 2. TDD FT 7750. TDL FT 7750. BLI FT 7742. TLI FT O . DFT GEL FRESHWATER DFD G/C3 10. 2 DFPH 8. 800001 DFV S 42. DFL F3 5. RMS OHT4M 1.83 MST DEGF 70. RMFS OtlM~I 1.48 MFST DEGF 70. RMCS OH~4M 1.71 MCST DEGF 70. TCS 14: 05 i-APR-96 BHT DEGF 149. Nation La ti tude Longi rude Wi tness 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 Sampl Mud Cake Sample Temperature Time Circulation Stopped Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth RA CDR ATTN RESISTIVITY RP CDR PHSF RESISTIVITY VRA QRO VERY ENHANCED AMPLITUDE RESISTIVITY VRP QRO VERY E1FHANCED PHASE RESISITIVTY DER DIELECTRIC RESISITIVTY ROP RATE OF PENETRATION FET TIME AFTER BIT GR Gamma Ray DEV Hole Deviation AZ Hole Azimu th DT DELTA- T DTSH SCRA RATIO SHEAR TO COMPRESSIONAL DELTA T GR Gamma Ray ~4RES MUD Resistivity MTEM Mud Temperature LIS Tape VerificatiOn Listing Schlumberger Alaska Computing Center 28-APR-1996 12:59 PAGE: 11 DEFI TENS Tension TEND Head Tension RHOB Bulk Density DRHO Del ta RHO PEF PhotoElectric Factor CALl Cat iper NPHI Neutron Porosity ENPH Epi thermal Neutron Porosity CPHI Thermal Neutron Porosity FCNT RAW FAR CNT COUNTS NCNT RAW NEAR CNT COUNTS 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 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 140 4 66 1 $ 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 7 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verificatio~ Listing Schlumberger Alaska Computing Center 28-APR-1996 12:59 PAGE: 12 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI.~SS MOD NUMB SgMP EL~Vl CODE (HEX) DEPT FT 630382 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0HZ4~630382 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD Otff4M630382 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD 0I~4~630382 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~4~ 630382 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD 0H~f630382 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630382 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630382 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630382 O0 000 O0 0 1 1 1 4 68 0000000000 DEV MWD DEG 630382 O0 000 O0 0 1 1 1 4 68 0000000000 AZ MWD DEG 630382 O0 000 O0 0 1 1 1 4 68 0000000000 DT DAS US/F 630382 O0 000 O0 0 1 1 1 4 68 0000000000 DTSH DAS US/F 630382 O0 000 O0 0 1 1 1 4 68 0000000000 SCRADAS 630382 O0 000 O0 0 1 1 1 4 68 0000000000 GR DASGAPI 630382 O0 000 O0 0 1 1 1 4 68 0000000000 I~ES DAS 0H~630382 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMDAS DEGF 630382 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DAS LB 630382 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DAS LB 630382 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 630382 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 630382 O0 000 O0 0 I 1 1 4 68 0000000000 PEF SDN BN/E 630382 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN 630382 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 630382 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 630382 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 630382 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 630382 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 630382 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 630382 O0 000 O0 0 1 1 1 4 68 0000000000 N-RAT CNTG 630382 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 630382 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 630382 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 630382 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 630382 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 630382 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7750.500 RA.MWD -999.250 RP.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD GR.MWD -999.250 DEV. MWD -999.250 AZ.MWD DTSH.DAS -999.250 SCRA.DAS -999.250 GR.DAS MTEM. DAS -999.250 TENS.DAS -999.250 TEND.DAS DRHO. SDN -999.250 PEF. SDN -999.250 CAL1.SDN ENPH. CNTG -999.250 CPHI.CNTG -999.250 FCNT. CNTC CRAT. CNTG -999.250 NRAT. CNTG -999.250 ENRA.CNTG CNTC. CNTG -999.250 CFEC. CNTG -999.250 CNEC. CNTG -999 250 97 292 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 VRA.MWD FET. MWD DT. DAS MRES. DAS RHOB. SDN NPHI. CNTG NCNT. CNTG CFTC. CNTG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listimg Schlumberger Alaska Computing Center 28-APR-1996 12:59 PAGE: 13 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 96/04/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/04/28 ORIGIN : FLIC TAPE NAME : 96114 CONTINUATION # : 1 PREVIOUS TAPE : COM~]ENT : ARCO ALASKA INC., WILDCAT, TEMPTATION #1, API #50-20233-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/04/28 ORIGIN : FLIC REEL NAME : 96114 CONTINUATION # : PREVIOUS REEL : COF~4ENT : ARCO ALASKA INC., WILDCAT, TEMPTATION #1, API #50-20233-00 Sch2 urr~oerger * S CHL UMB ER G ER * ***************************** SCHLUMBERGER WELL SERVICES ALASKA DIVISION COMPUTER CENTER 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 907/562-2654 Page 2 TAPE VERIFICATION LISTING LIS FORMAT LIS TAPE VERIFICATION FOR RFT FIELD TAPE Job Number 96114 Company Name ARCO ALASKA INC. Well Name TEMPTATION #1 Field Name WILDCAT County NORTH SLOPE State ALASKA Service Order Number 630382 Date Acquired 2-APR-1996 Run Number ONE Date Processed Files Included 30-APR-96 Schlumberger Page LIST Command Listing KEY I LIST SUMMARY ~VEMONICS Summary output is created by LIST/SUM~iARY 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 the 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 the abbrev, on right. Summary Field Labels: REELS Number of logical reels on Number of logical tapes on (L ) TAPES (LR ) FILES Number of logical files on (LRT ) #PR Number of physical records (LRTF) #LR Number of logical records (LRTF) #DR Number of data records ( F) #ENC Number of encrypted records ( F) #FM ( F) PI ( F) PI UNITS ( F) _ MAXPI ( F) MINPI ( F) Number of data frames Primary index channel name Primary index units mnemonic Maximum primary index value Minimum primary index value NOTE - DEPTH OF PRESSURE TEST IS RECORDED AS CHANNEL FDEP. FDEP IS ALSO LISTED IN "CONS" TABLE ON TESTS WHERE THE CSU TABLES WERE DUMPED TO TAPE. FOR FORMATION TEST FILES, "DEPT" INCLUDED IN THESE LISTINGS DOES NOT REFER TO DEPTH OF MF~SUREMENT BUT IS AN INTERNAL COUNTER USED WHEN MEASURING IN TIME. IN ANATTEMPT TO KEEP THIS LISTING TO A REASONABLE LENGTH, ONLY SPECIFIC CHANNELS AND CONSTANTS ARE LISTED. THIS LISTING DOES NOT INCLUDE MANYOFTHE CHANNELS AND CONSTANTS INCLUDED ONTHE FIELD TAPE. S-chlumber'ger LIST $1$DIA2 : [96114. RFT] RFT. LIS;2 Reel header DEFAULT 30-APA-~6 15:59:20 Page 4 ** REEL HEADER ** SERVICE NAMiE : RFTB DATE . 96/04/02 ORIGIN : DLIS REEL NA~E : DEFAULT CONTINUATION #: 1 PREVIOUS REEL : COMPiENT · PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY Tape header DEFAULT ** TAPE HEADER ** SERVICE NAME : FRFTB DATE : 96/04/02 ORIGIN .. DLIS TAPE NAFIE : DEFAULT CONTINUATION #: 1 PREVIOUS TAPE : CO~4F=NT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY File header RFTB .018 ** FILE HEADER ** FILE NAFiE : RFTB .018 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE · 96/04/02 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU FDEP ALLO F F Formation Depth 67.43333 End of set Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Schlumberger LIST $1$DIA2: [96114. RFT]RFT. LIS; 2 Table type CONS Listing of set 11 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set 30-APR-96 15:59:20 Page 5 Table type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Data format specification record Listing of set 1 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 186 79 2 4 1 66 1 5 1 66 1 6 0 73 4 7 IN 65 2 8 60 73 4 9 .lin 65 4 11 44 66 1 12 -999.25 68 4 13 1 66 1 14 . lin 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NAFIE SERV UNIT SERVICE API API API API FILE NOM~ NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 26 1 1 4 68 0000000000 GR RFTB GAPI 0 26 1 1 4 68 0000000000 End of set Schlumberger LIST $1$DIA2: [96114.RFT]RFT.LIS;2 30-APR-96 15:59:20 Page 6 Data record type 0 DEPT 721980 .liN 6016.5 FT 1833.8292 M ETIM O. GR 98. 9313 File trailer RFTB .018 ** FILE TRAILER ** FILE NAME : RFTB .018 SERVICE NAME : DEPTH- VERSION # : 7C0-428 DATE : 96/04/02 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 40 74 0 13 555 DEPT .liN 721980 688740 DEPT F 6016.5 5739.5 DEPT M 1833.8292 1749.3996 File header RFTB .020 ** FILE HEADER ** FILE NA~E : RFTB .020 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/04/02 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU FDEP ALLO F F Formation Depth 5837. 808 End of set Schlumberger LIST $1$DIA2: [96114. RFT]RFT. LIS;2 Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set 30-APR-96 15:59:20 Page 7 Table type CONS Listing of set 11 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PO]VI DESC VALU End of set Data format specification record Listing of set 3 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 122 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .SMS 65 4 11 67 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELE~ SAMP COD (HEX) Schlumberger LIST $1$DIA2: [96114.RFT]RFT.LIS;2 30-APR-96 15:59:20 Page 8 ETIM RFTB S 63 621 0 28 1 1 4 68 0000000000 SGP RFTB PSI 81 400 0 28 1 1 4 68 0000000000 PONE RFTB 81 400 0 28 1 1 4 68 0000000000 PTENRFTB 81 400 0 28 1 1 4 68 0000000000 PHUNRFTB 81 400 0 28 1 1 4 68 0000000000 PTHO RFTB 81 400 0 28 1 1 4 68 0000000000 End of set Data record type 0 TIFIE 3990938 .5MS ETIM O. SGP 3154.321 PONE 4. PTEN 5. PHUN1. PTHO 3. File trailer RFTB .020 ** FILE TRAILER ** FILE NA~E : RFTB .020 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/04/02 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 52 86 0 26 1720 TIME .5MS 3990938 5022338 File header RFTB .021 ** FILE HEADER ** FILE NAME : RFTB .021 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/04/02 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU FDEP ALLO F F Formation Depth 5878. 133 End of set Schlumberger LIST $1$DIA2 : [96114. RFT]RFT. LIS;2 Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set 30-APR-96 15:59:20 Page 9 Table type CONS Listing of set 11 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Data format specification record Listing of set 5 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 122 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .SMS 65 4 11 67 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) Schlumberger LIST $1$DIA2 ~ [96114. RFT]RFT. LIS;2 30-APR-96 15:59:20 Page 10 ETIMRFTB S 63 621 0 29 1 1 4 68 0000000000 SGP RFTB PSI 81 400 0 29 1 1 4 68 0000000000 PONE RFTB 81 400 0 29 1 1 4 68 0000000000 PTENRFTB 81 400 0 29 1 1 4 68 0000000000 PHUNRFTB 81 400 0 29 1 1 4 68 0000000000 PTHO RFTB 81 400 0 29 1 1 4 68 0000000000 End of set Data record type 0 TIME 5271201 .SMS ETIM O. SGP 3177.41 PONE 7. PTEN 7. PHUN1. PTHO 3. File trailer RFTB .021 ** FILE TRAILER ** FILE NAM~ : RFTB .021 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/04/02 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUM~3~RY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 54 88 0 28 1861 TIME .SMS 5271201 6387201 File header RFTB .022 ** FILE HEADER ** FILE NAME : RFTB .022 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/04/02 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU FDEP ALLO F F Formation Depth 6335.183 End of set Schlumberger LIST $1$DIA2: [96114.RFT]RFT. LIS;2 Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set 30-APR-96 15:59:20 Page 11 Table type CONS Listing of set 11 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Data format specification record Listing of set 7 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 122 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 67 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) Schlumberger LIST $15DIA2:[96114.RFT]RFT. LIS;2 30-APR-96 15:59:20 Page 12 ETIM RFTB S 63 621 0 30 1 1 4 68 0000000000 SGP RFTB PSI 81 400 0 30 1 1 4 68 0000000000 PONE RFTB 81 400 0 30 1 1 4 68 0000000000 PTENRFTB 81 400 0 30 1 1 4 68 0000000000 PHUNRFTB 81 400 0 30 1 1 4 68 0000000000 PTHO RFTB 81 400 0 30 1 1 4 68 0000000000 End of set Data record type 0 TIME 7279317 .SMS ETIM O. SGP 3422.31 PONE 2. PTEN 2. PHUN 4. PTHO 3. File trailer RFTB .022 ** FILE TRAILER ** FILE NA~E : RFTB .022 SERVICE NAME : STATIO VERSION # : 7C0-428 DATE : 96/04/02 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUM~J~Y #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 53 87 0 27 1775 TIME .SMS 7279317 8343717 File header RFTB .025 ** FILE HEADER ** FILE NAME : RFTB .025 SERVICE NAIVE : STATIO VERSION # : 7C0-428 DATE : 96/04/02 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU FDEP ALLO F F Formation Depth 7181.149 End of set Schlumberger LIST $1$DIA2: [96114.RFT]RFT. LIS;2 Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set 30-APR-96 15:59:20 Page 13 Table type CONS Listing of set 11 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Data format specification record Listing of set 9 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 122 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .SMS 65 4 11 67 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) Schlumberger LIST $15DIA2:[96114.RFT]RFT. 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