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Home My WebLink About198-0911. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Conductor Extension Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,134' feet N/A feet true vertical 5,484' feet N/A feet Effective Depth measured feet 8,392' feet true vertical feet 4,977' feet Perforation depth Measured depth 8716' - 8756' feet True Vertical depth 5200' - 5228' feet Tubing (size, grade, measured and true vertical depth) 4 1/2" L-80 8,410' 4,988' Packers and SSSV (type, measured and true vertical depth) SSSV: CAMCO 'DB' NIPPLE 515' MD 514' TVD 8,392' MD 4,977' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 322-627 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Brennen Green & Roger Mouser N1927@conocophillips.com 907-659-7506Well Integrity Field Supervisor Gas-Mcf MD measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureWater-BblOil-Bbl Packer: BAKER 80-70 SEAL ASSEMBLY 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-091 5010320259-0000P.O. Box 100360, Anchorage, AK 99510 3. Address: N/A 5. Permit to Drill Number:2. Operator Name: 4. Well Class Before Work: ADL0375074 / ADL0380054 KUPARUK RIVER / TARN OIL ConocoPhillips Alaska, Inc. KUPARUK RIV U TARN 2N-313 Plugs Junk measured N/A N/A Length 79.83' 3,289' 109.83'Conductor Surface 16" 9 5/8" Size 109.83' 7"Production 9,091' Casing 5,474'9,119' 3,319' measured TVD 2,304' Burst Collapse p k ft t Fra O s 198 6. A G L PG , n Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:32 am, Jun 05, 2023 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E= n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.06.02 18:07:37-08'00' Foxit PDF Editor Version: 12.0.1 Brennen Green Date Event Summary Executive Summary Welded Conductor Extension 11/14/22 Received the signed 10-403 for conductor extension. Sundry # 322-627 03/09/23 ~7.5" Tree rise. 48" cellar. Gas reading in the conductor and cellar are normal. 06/01/23 NES Welder welded a 10" long X 16" diameter X 0.500" wall Conductor extension to the existing Conductor P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 2, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Please find the enclosed 10-404 from ConocoPhillips Alaska, Inc. for well KRU 2N-313 (PTD # 198-091) 10 Conductor extension. Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.06.02 18:06:43-08'00' Foxit PDF Editor Version: 12.0.1 Brennen Green Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,745.0 2N-313 9/14/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Welded a 10" Conductor extension 2N-313 6/2/2023 bsgreen General Notes: Last 3 entries Com Date Last Mod By Obtained SBHP @ 8591'' RKB = 1701 psi & 8736'' RKB = 1706 psi @ 135 deg F. 12/22/2000 Admin Obtained SBHP @ 8736'' RKB = 1510.7 psi. 10/6/2000 Admin Cut paraffin & drift Tbg to 4000'' WLM. 11/3/1999 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.8 109.8 109.8 62.58 H-40 WELDED SURFACE 9 5/8 8.68 29.5 3,319.1 2,303.7 47.00 L-80 BTC PRODUCTION 7.5"x4.5" @ 8395' 7 6.28 27.7 9,118.5 5,473.6 26.00 L-80 BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 17.4 Set Depth 8,409.9 Set Depth 4,988.3 String Ma 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 17.4 17.4 0.00 HANGER 10.000 FMC GEN V TUBING HANGER 4.500 514.6 514.0 6.82 NIPPLE 5.570 CAMCO 'DB' NIPPLE FOR SCSSSV 3.875 8,304.4 4,913.7 44.96 SLEEVE 5.500 BAKER CMU SLIDING SLEEVE 3.812 8,343.6 4,941.5 44.97 GAS LIFT 5.985 CAMCO KBG-2- LS 2.920 8,387.0 4,972.1 45.04 NIPPLE 5.000 BAKER 'DB' NIPPLE 3.750 8,392.2 4,975.8 45.09 LOCATOR 4.875 BAKER LOCATOR 3.875 8,393.2 4,976.5 45.10 SEAL ASSY 4.750 BAKER 80-70 SEAL ASSEMBLY 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) CONDUCTOR SUBSIDENCE: Welded 1'x16" 62.5# H-40 conductor extension on top of existing conductor; raising back to original RKB 8/13/2013 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,343.6 4,941.5 44.97 1 GAS LIFT OV INT 1 9/14/2022 0.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,716.0 8,736.0 5,200.0 5,213.8 S-5, 2N-313 8/31/1998 4.0 IPERF 2-7/8" HC 8,736.0 8,756.0 5,213.8 5,227.5 S-5, 2N-313 8/29/1998 4.0 IPERF 2-7/8" HC Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,716.0 8,756.0 1 FRAC 9/6/1998 0.0 0.00 0.00 2N-313, 6/2/2023 4:56:59 PM Vertical schematic (actual) PRODUCTION 7.5"x4.5" @ 8395'; 27.7-9,118.5 FLOAT SHOE; 9,116.7-9,118.5 FLOAT COLLAR; 9,022.3- 9,023.7 IPERF; 8,736.0-8,756.0 FRAC; 8,716.0 IPERF; 8,716.0-8,736.0 CSR; 8,395.2-8,415.6 SEAL ASSY; 8,393.2 LOCATOR; 8,392.2 NIPPLE; 8,387.0 GAS LIFT; 8,343.6 SLEEVE; 8,304.4 SURFACE; 29.5-3,319.1 FLOAT SHOE; 3,317.4-3,319.1 FLOAT COLLAR; 3,233.5- 3,235.0 NIPPLE; 514.6 CONDUCTOR; 30.8-109.8 HANGER; 29.5-31.2 HANGER; 27.7-29.8 HANGER; 17.4 KUP PROD KB-Grd (ft) 36.31 RR Date 8/2/1998 Other Elev 2N-313 ... TD Act Btm (ftKB) 9,134.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032025900 Wellbore Status PROD Max Angle & MD Incl (°) 61.12 MD (ftKB) 6,426.71 WELLNAME WELLBORE2N-313 Annotation Last WO: End DateH2S (ppm) 150 Date 11/2/2014 Comment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y Anne Prysunka at 9:02 am, Oct 27, 2022 'LJLWDOO\VLJQHGE\%UHQQHQ*UHHQ '1& 862 &RQRFR3KLOOLSV&1 %UHQQHQ*UHHQ( Q #FRQRFRSKLOOLSVFRP 5HDVRQ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ 'DWH )R[LW3')(GLWRU9HUVLRQ %UHQQHQ*UHHQ ; $'/ '/% '65 %-0 '/%*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.11.14 11:53:58 -09'00' RBDMS JSB 111422 32%2; $1&+25$*($/$6.$ &RPPLVVLRQHU-HVVLH&KPLHORZVNL $ODVND2LO *DV&RPPLVVLRQ :HVWWK$YHQXH6XLWH $QFKRUDJH$. 'HDU&RPPLVVLRQHU&KPLHORZVNL 3OHDVHILQGWKHHQFORVHGDSSOLFDWLRQIRU6XQGU\$SSURYDOIURP&RQRFR3KLOOLSV $ODVND,QFIRUZHOO.58137'WRH[WHQGWKHFRQGXFWRU 6XPPDU\&RQGXFWRUKDVVXEVLGHGRUZHOOKDVJURZQa´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a´ :LWKDSSURYDOWKHFRQGXFWRUH[WHQVLRQZLOOUHTXLUHWKHIROORZLQJJHQHUDOVWHSV 5HPRYHODQGLQJULQJIURPFRQGXFWRULIQHFHVVDU\ ([WHQGWKHFRQGXFWRUWRVWDUWHUKHDG )LOHZLWKWKH$2*&&SRVWUHSDLU Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ?m°'. O~ / File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds [] Other COMMENTS: Scanned by:~Mildred Daretha Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ ~ Y~I~,I~T, L,~~~ 1 ~'~~~1`i~i~i~?Tii ~'~~ 1~~-~q ~ ~~~s~~~ '~i'ao 1~laslca ~il and ~as ~oras~r~ra~i~~a ~~~~, ~~~~.: ~hris~~~e l~/Iahnlc~,n 333 ~~ILs~ 7~h 1~v~nue, ~ui~~ 1~~ I~~~h~~~g~9 ~laska ~95~1 RE: Gas Lift Survey 2N-313 J~al;~ 2~~ 2~~9 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 21~t-313 Digital Data in LAS format 50-103-20259-UO ~' ` ~~i~ ~ ~~'<.t '~{.4.~d:..c . ~'4~~,,, ~ -- 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.b arreto@halliburton. com i)ate: ~~ r~ Signed: ~l~ ~/~/ • „ • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~Iy~~ N~V ~ ~ ~~~~ ~~g~oq~ Enclosed please find a (revised 10/3/07)spreadsheet with a-kst of-~ue+lls~from the Kuparuk field (KRLT). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. This spreadsheet is a revised format for the original submitted on 9/28/07 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, on Arend ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/28/2007 Well Name PTD # lnitia! top of cement Vol. of cement um ed Fina! top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-303 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 20" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9!27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" nla 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 18" n/a 18" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 ConocoPhiliips ~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~B R~~~Y ~ V T ~ ~ LVYI Dear Mr. Maunder: • ~q~~~~ Enclosed please find a (revised 10!3/07}spreadsheet with a list of wells from the I~uparuk field (KRIn. Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. This spreadsheet is a revised format for the original submitted on 9/28/07 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, - =~ on Arend ConocoPhillips Well Integrity Field Supervisor • ConocoPhillips Alaska fnc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Fieid Date 9128/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-303 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16!2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 1$" 9/9/2007 2N-335 198-204 20" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9!2712007 2N-304 201-130 10" n/a 10" nia 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n!a 14" n1a 4.5 9/27!2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n!a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n!a 10 9/27!2007 2N-313 198-091 18" n/a 18" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n1a 9.5 9/27/2007 • ConocoPhillips ~~~ P.Q. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 NQV ~ ~ 20Q~ ~h~~~~~~ Dear Mr. Maunder: ~~e~ o~T !VED A/,~~ke Di~~ G ~ 2 ~~Q~ Ancho a~ns Canir~;s . ~~ Sipq ~,a~l Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRII). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annulaz space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitorlsealanttyas pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, ;' M.J. vel d ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Fieid Date 9/28/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitors sealant date ft bbls ft al 2L-~03 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9!9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 9" na 20" na 13 9/16!2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9!16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" nsa 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" nsa 12" n!a 7.5 9127!2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" nsa 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9!27/2007 2N-313 19&091 5" n/a 5" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9!27!2007 2N-317 198-143 5" Na 5" nla 1 9/27/2007 2N-318 200-100 10" n/a 10" nJa 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 • • R~c~ COI''1000~`11~~1 S ~~'r JV~d A/$sk$ Qi> ~ 2 ?0 Alaska $ ~$ p~ AN ORAGE~ AIASKA 99510-0360 Anch° age Criss, On September 28, 2007 ~~ ``°~ Mr. Torn Maunder ~~ ~~~ n Alaska Oil & Gas Commission ~~~ ~' ~ 333 West 7~' Avenue, Suite 100 ~ 1 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRtn. Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 200?. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, ~. M.J. vel d ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/28/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor! sealant date ft bbls ft al 2L-~03 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9!16/2007 21-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9!2007 2N-335 198-204 9" na 20" na 13 9!16!2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9!16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9!2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27!2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27!2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 2a8-179 12" n/a 12" n/a 10 9/27/2U07 2N-313 198-091 5" Na 5" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9!27/2007 2N-315 198-190 6" n!a 6" n/a 3 9/27/2007 2N-317 198-143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n!a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9!27/2007 .. .~" ......- . .... ...~ .."- _.".-....~.._... 06/14/07 Schlullberger {qõ-ifìl sCANNED JUN·! 1 ZOD7 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO. 4300 2 0 200l Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Commlssiœù Field: Kuparuk Well Job# Date CD BL Color Log Description 2M-16 11629024 SBHP SURVEY 06/06/07 1 2N-306 11629025 SBHP SURVEY 06/06/07 1 2H-07 11638870 PRODUCTION PROFILE 06/07/07 1 2N·323 11629027 SBHP SURVEY 06/08/07 1 2N-313 11629027 SBHP SURVEY 06/08/07 1 2M-29 11638871 SBHP SURVEY 06/08/07 1 1C-104 11638872 LDL 06/08/07 1 1 G-08A 11629026 PRODUCTION PROFILE 06/09/07 1 2N-308 11638874 SBHP SURVEY 06/09/07 1 2M-10 11629031 SBHP SURVEY 06/10/07 1 1A-27 11638876 PRODUCTION PROFILE 06/10/07 1 2M-12 11629030 SBHP SURVEY 06/10/07 1 2L-311 11638881 SBHP SURVEY 06/11/07 1 2N-317 11638878 SBHP SURVEY 06/11/07 1 2B-08 11629032 INJECTION PROFILE 06/11/07 1 1 H·08 11638882 INJECTION PROFILE 06/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Well Compliance Report File on Left side of folder 198-091-0 MD 09134 ~ Microfilm Roll KUPARUK RIV U TARN 2N-313 50- 103-20259-00 PHILLIPS ALASKA INC TVD 05484 ~ Completion Date: '~8/2/98 Completed Status: 1-OIL Current: / - Roll 2 / Name Interval Sent Received D 8730 3-6 SPERRY MPT/GR/EWR4 OH 11/11/98 11/12/98 L CMTVOL Gri~AL 8450-8950 ~}/~O/~ OH 2 8/11/98 8/20/98 L DGR/EWR4-MD c.~' 3350-8862 '~ ~/[]t~r~ OH 11/11/98 11/12/98 . L DGR/EWR4-TVD -~6 2320-5300 ~ OH 11/11/98 11/12/98 L DSI ~qAL BL(C) 3300-9150 ~/~/~ OH 1/2 8/11/98 8/20/98 / L FLDLEVEL c-~FI~AL 8400-9018 ql [ 8 CH 5 11/9/98 11/13/98 L FLWGBHP ,~I'4NAL 8700-8990 g/~t/~ CH 5 11,9,98 11,13,98 L PEX-CN ~NAL 3318-9068 -j[~/a~ OH 8/11/98 8/20/98 L PEX-CN/3DD '~INAL 3318-9081 / OH 8/11/98 0/20/98 L SSTVD ,/~INAL 3310-9100 ~ OH 8/11/98 8/20/98 T/C/D R DIR SRVY ~Y 108-9134. OH T 8624 t~~' SCHLUM DAS/SDN/CNT/FMS/PDC OH Daily Well Ops"-~/~ ~/?~9 ~0/~//~ ff Are Dry Ditch Samples Required? yes Was the well cored? (~ye~'~o Analysis Description Received? (~ no 9/25/98 9/28/98 8/11/98 8/20/98 ---~ And Received? Sample Set # ] Comments: Tuesday, August 01, 2000 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor FROM: John Crisp,q/~,/,,. C,, SUBJECT: Petroleum Irt'spector DATE: July 20, 2000 Safety Valve Tests Kuparuk River Unit Tarn Field 2N & 2L Pads July 20, 2000: I traveled to Phillips Alaska's Kuparuk River Unit Tarn Field to witness the semi-annual Safety Valve System tests on Pads 2N & 2L. Testing went well with only one failure on 2L Pad witnessed. No failures were witnessed on 2N Pad. The AOGCC test report is attached for reference. SUMMARY: I witnessed the semi-annual SVS tests on KRU's Tarn Pads 2N & 2L. 2N Pad, 9 wells, 18 components tested. No failures. 2L Pad, 6 wells, 12 components tested. 1 failure. 8% failUre rate. Attachments: SVS Tarn KRU 2N & 2L 7-20-00jc cc; NON-CONFIDENTIAL SVS Tam KRU 2N & 2L 7-20-00jc.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tam, KUparuk River, 2N Separator psi: LPS 94 HPS 7/20/00 'Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GnSorC¥C[E 2N-307 1990170 2N-308 1990100 94 70 65 P P OIL 2N-309 1990210 -2N;31'3~ '-~;'._ /~1980910 94 70 70 P P OIL 2N-315 1981900 2N-317 1981430 94 70 70 P P OIL 2N-319 1981970 2N-320 1990010 94 70 65 P P OIL ~2N-321A 1981730 2N-323 1980710 94 70 70 P P OIL 2N-325 1981630 2N-329 1980670 94 70 70 P P OIL 2N-331 1981170 2N-335 1982040 94 70 70 P P OIL 2N-337A 1981220 2N-339 1981000 2N-341 1981030 94 70 65 P P OIL 2N-343 1980920 2N-345 1981130! 2N-347 2000630 94 70 60 P P OIL Wells: 9 Components: 18 Failures: 0 Failure Rate: 0.0% ~ 9o my Remarks: 7/97/00 Page 1 of 1 SVS Tarn KRU 2N 7-20-00jc.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Emie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tam, Kupamk River, 2L Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, G/NJ, Number Number PSI PSI Trip Code Code Code GASorC¥CLW 2L-305 1982400 94 70! 60 P 4 OIL 2L-307 1982560 94 70 70 P P OIL 2L-313 1982190 94 70 65 P P OIL 2L-315 1982180 94 70 70 P P OIL 2L-321 1982620 2L-323 1982510 2L-325 1982090 94 70 65 P P OIL 2L-329A 1982250 800 700 700 P P GAS Wells: 6 Components: 12 Failures: 1 Failure Rate: 8.0% [-] 90 Day Remarks: 7/27/00 Page 1 of 1 SVS Tam KRU 2L 7-20-00jc'xls ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re' Kuparuk Area Annular Injection, Third Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the third quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 1999. Amzular hzjection during the third quarter of !999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 1C-25 520 100 0 620 34316 34936 CD 1-40 20079 100 0 20179 12171 32350 CD 1-01 4905 100 0 5005 0 5005 1 C-23 24865 100 0 24965 9605 34570 CD 1-23 16079 100 0 16179 0 16719 CD 1-37 17173 100 0 17273 0 17273 CD 1-39 3917 100 0 4017 0 4017 1D-12 4305 100 0 i 4405 0 4405 Total Volumes into Annuli for which h~jection Authorization Expired during tile quarter Well Name Total h(1) Volume Total h(2) Total h(3) Volume Volume ~ 0 Total Volume Injected 32640 Status of Annulus Open. Freeze Protected 1D-09 32540 i 100 2N-337A 30539 ' 100 i 0 30639 i Open. Freeze Protected 2N-313 32758 i 100 i! 0 i 32858 ', Open. Freeze Protected : 2N-321A 27507 ~ 100 ! 0 27607 I Open. Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader RECEIVED 0il & Gas Cons. Commission Anch0ra~e CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental' Engel / Snodgrass Momson and Winfree Sharon Allsup-Drake Well Files Ms. Wendy Mahan AOGCC Third Quarter 1999 Annular Injection Report Page Two 0 I::! I I--I-- I i~l G S E I:IL/I r' El S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 March 04, 1999 RE: MWD Formation Evaluation Logs 2N-313, AK-MM-80298 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention ot~ Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way,/tG, Anchorage, AK 99518 2N-313: 2" x 5"MD Resistivity & Gamma Ray Logs: 50-103-20259-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20259-00 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia Note: MWD logs replace any previous logs for well ( 2N-313 ). 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company C! P1 ! I_1_ I !~1 I~ To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 11, 1998 RE: MWD Formation Evaluation Logs 2N-313, AK-MM-80298 1 LDWG formatted Disc with verification listing. APl#: 50-103-20259-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATrACHED COPY OF THE TRANSMITYAL LETYER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage,..Alaska.;9:9518 Date: )~:.....'... /,, WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 11, 1998 RE: MWD Formation Evaluation Logs 2N-313, AK-MM-80298 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-313: 2" x 5" MD ResistiviW & Gamma Ray Logs: 50-103-20259-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20259-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 SiIverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 11/9/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12034 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk & Tarn Pool Well Job # Log Description Date Blueline Sepia 2H-02 INJECTION PROFILE 980905 I 1 2H-03 INJECTION PROFILE 980822 1 ] 2H-15 INJECTION PROFILE 980905 I 1 2N-313 FLOWING B.H.P. W/FLUID SAMPLE 980831 1 1 2N-313 FLUID LEVEL DETERMINATION 980902 1 1 2T-36 INJECTION PROFILE 980828 I ] 2W-09 MEMORY INJECTION PROFILE W/PSP 980909 1 1 3G-22 PRODUCTION PROFILE 980924 I 1 3G-22 GAS LIFT SURVEY 980924 1 1 3G-22 DIGITAL FLUID ENTRY TOOL 980924 I I SIGN o~o $i~n and to,urn OhO ¢op¥ o! ~hi~ tran~miflal to Shorrio a! tho ~bo¥o addro$$, lhank you. DATE: I'~10 V ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 25, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-313 (Permit No. 98-91) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on Tam 2N-313. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tarn Drilling Team Leader PM/skad RECEIVED SEP 2 8 !998 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [] GAS E~ SUSPENDED [] ABANDONED~ SERVICE [~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-91 3 Address 8 APl Number P.O. Box 100360, Anchora0e, AK 99510-0360 ,~,-!~',. 50-103-20259 4 Location of well at surface ~'~::5~'~'.'?:/--Ar.7~:'":¥'~ 9 Unit or Lease Name ~ __ ,,~,~t,,~?q ! ~ Kuparuk River Unit 34' FNL. 646' FEL, Sec. 3, T9N, RTE, OM ~[ ~[~ ~ ~ ~ 10 Well Number At Top Producing Inte~al ~ 315'FSL, 1464'~L, Sec. 27, T10N, R7E, UM ~ ] ~ ........ ~: At Total Depth 11 Field ~d Pool 675' FSL, 1278' ~L, Sec. 27, T10N, RTE, UM Kuparuk River Reid 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Sedal No. Tarn Oil Pool RKB 28', Pad 121'~ ADL 380054 ALK 4802 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ~ 15 Water Depth, if offshore 16 No. of Completions 20-Ju1-98 30-Ju1-98 02-Aug-98~ NA feet MSL 1 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Dire~ional Su~ey 20 Depth where SSSV set 21 ~ickness of permafrost 9134' MD & 5484' ~D 9022' MD & 5409' ~D YES ~ NO ~ NA feet MD 1050 APPROX 22 Type Electdc or Other Logs Run G~Res, GR/CCL, Dipole SonidFMS 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58~ H-40 SURF. 108' 24" 10 cu. yds High Early 9.625" 40.0~ L-80 SURF. 3319' ] 2.25" 374 sx ASIIILW, 362 sx Class G, 60 sx ASI 7' x 26~ L-80 SURF. 8395' 8.5" 356 sx Class G 4.5' 12.6~ L-80 8395' 9119' 8.5' (included above) 24 Pedorations open to Production (MD+~D of Top and Bo~om and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH S~ (MD) PACKER SET (MD) 4.5' 8410' 8395' (CSR) 8716'-8756' MD 5200'-5227' ~D 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8716'-8756' MD refer to a~achments 27 PRODUCTIQN TEST Date First Production ~Method of Operation (FIo~ng, gas lift, etc.) 9/9/98J Flowing Date of T~t Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BB[ CHOKE SIZE ~ GAS-OIL RATIO 9/11/98 8.00 TEST PERIOI: ] 480 508 5 88~ 343 Flow Tubing Casing Pressure CALCU~TED OIUBBL GAS-MCF WATER-BB[ OIL GRAVIS-APl (corr) Pr~s. 570 0 24-HOUR RATE: ~9 1523 16 0 28 CORE DATA Brief description of lithology, porosity, fracture, apparent dips and pr~ence of oil, gas or water. Submit core chips. SEP 2 8 t998 Nas 0il & ~as Cons. Commission Anchorage Form 10-407 Submit in duplicate Dnv 7-1-8f') CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Reservoir (T3) 8579' 5106' Base Reservoir (T2) 8819' 5271' Annulus left open - freeze protected with diesel, 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. I ~ ~ ' Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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 Date: 9/1/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-313 WELL_ID: AK9397 TYPE: AFC: AK9397 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:07/20/98 START COMP: RIG:DOYON RIG 141 WI: 0% SECURITY:0 API NUMBER: 50-103-20259-00 BLOCK: FINAL: 07/19/98 (D1) TD: 108' (108) SUPV:R.W. SPRINGER 07/20/98 (D2) TD: 1306' (1198) SUPV:R.W. SPRINGER 07/21/98 (D3) TD: 3330'(2024) SUPV:D.P. BURLEY 07/22/98 (D4) TD: 3330' ( 0) SUPV:D.P. BURLEY 07/23/98 (D5) TD: 3330' ( 0) SUPV:D.P. BURLEY 07/24/98 (D6) TD: 5346' (2016) SUPV:D.P. BURLEY MW: 9.6 VISC: 97 PV/YP: 46/20 DRLG @ 350' APIWL: 9.2 Move rig from 2N-345 to 2N-313. NU diverter system and function test. Accept rig @ 1600 hrs. 7/19/98. Clean conductor out to 85'. Drill MW: 10.0 VISC: 75 PV/YP: 33/34 APIWL: 8.4 PJSM. Drilled from 108' to 726'. POH. Repair hi-drum drive chain. Drill from 726' to 1306' POH. MW: 10.2 VISC: 63 PV/YP: 29/30 APIWL: 5.8 Drill 12.25" hole from 1306' to 3330'. Pump low/high vis sweeps and circulate hole clean. Moderate gas breaking out at bell nipple, well stable. Wiped hole from 3330' to 1164' Worked through several tight spots from 1690' to 1164' MW: 10.1 VISC: 62 PV/YP: 25/24 NU BOPE. APIWL: 5.7 Pump low/high vis sweeps and circ clean. Monitor well, stable. Run 9-5/8" casing. Pump cement. MW: 9.1 VISC: 50 PV/YP: 16/16 POH FOR DRLG ASSY. APIWL: 7.5 ND diverter system. NU BOPE and test to 250/3500 psi. Attempted to test upper and lower kelly valves, both failed. Changed out both valves retest, both failed again. Clean out cement to 1610' Drilled out stage tool. Clean to 3191' Cleaned out cement and insert baffle @ 3196' MW: 9.2 VISC: 49 PV/YP: 19/20 WIPER TRIP FOR FOOTAGE DRILLED FROM 6028' APIWL: 6.7 Cleaned out cement and float equipment from 3196' to 3330' Drill from 3330' to 3350' Change well over to 9.1 ppg 07/25/98 (D7) TD: 7730' (2384) SUPV:D.P. BURLEY 07/26/98 (DS) TD: 8410' (680) SUPV:D.P. BURLEY 07/27/98 (D9) TD: 8658' (248) SUPV:D.P BURLEY 07/28/98 (D10) TD: 8748'( 90) SUPV:D.P BURLEY 07/29/98 (Dll) TD: 8845'( 97) SUPV:D.P BURLEY 07/30/98 (D12) TD: 9134' (289) SUPV:D.P BURLEY 07/31/98 (D13) TD: 9134' ( 0) SUPV:D.P BURLEY 08/01/98 (D14) TD: 9134' ( 0) SUPV:D.P BURLEY 08/02/98 (D15) TD: 9134'( 0) SUPV:D.P. BURLEY bland LSND mud and circ clean. Perform LOT, EMW of 16.0 ppg. Drill 8.5" hole from 3350' to 5346' MW: 9.2 VISC: 41 PV/YP: 14/ 9 DRILLING 8-1/2" PRODUCTION HOLE. APIWL: 6.5 Drill 8.5" hole from 5346' to 7730' MW: 9.8 VISC: 43 PV/YP: 16/17 DRILLING 8-1/2" HOLE @ 8532' APIWL: 5.4 Drill 8.5" hole from 7730' to 8349'. MADD pass from 8316' to 8349' Drill from 8349' to 8410' MW: 9.9 VISC: 49 PV/YP: 19/21 POH W/ CORE ASSY. ~ 1. APIWL: 5.1 Drill 8.5" hole from 8410' to 8570' RIH with coring assembly. Cut 8.5" x 4" core from 8570' to 8658' MW: 9.9 VISC: 49 PV/YP: 19/22 / ~CORING @ 8750' APIWL: 4.6 POH with core. RIH w/core assembly #2. Core from 8658' to 8748' MW: 9.9 VISC: 51 PV/YP: 14/20 APIWL: 4.4 oH FOR E-LINE LOGS. re from 8748' to 8838'. POH. Laid down coring assembly. Drill 8.5" hole from 8838' to 8845' MW: 9.9 VISC: 47 PV/YP: 14/17 POH TO PU LWD. APIWL: 4.6 Drill from 8845' to 9134' Platform express with dipole sonic. Run FMS. MW: 10.0 VISC: 46 PV/YP: 11/15 CHANGE PIPE RAMS TO 7", RIG UP GBR CASERS. APIWL: 4.0 Obtain MAD pass log from 8560' to 8850'. Pump low/high vis sweeps. Circ and condition mud. Monitor well, static. MW: 10.0 VISC: 48 PV/YP: 15/15 RUN 4-1/2" COMPLETION. APIWL: 4.2 Run 4.5" casing, change running tools to 7" and run 7" casing. Run 7" casing. Staged rate up to 6.5 bpm, began losing mud. Reduced rate to 4 bpm adh conditioned mud, 80% returns. MW: 0.0 VISC: Moving to 2N-317 0 PV/YP: 0/ 0 APIWL: 0.0 Finish displacing cement, did not bump plugs, floats held. Run 4.5" completion. Freeze protect. ND BOPE, NU tree adapter and master valve and tested to 5000 psi. Released rig @ midnight 8/3/98. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~' K1(2N-313(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-313 FRAC, FRAC SUPPORT 0903980508.1 DATE DAILY WORK UNIT NUMBER O9/O6/98 FRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES DS-YOKUM RIGGS FIELD AFC# CC# Signed ESTIMATE K85101 180 KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1845 PSI 450 PSI 250 PSI 250 PSIt 960 PSII 200 PSI DAILY SUMMARY [Frac-Refrac] PUMPED THE FRAC PER PROCEDURE W/50# XL GEL @ 15 BPM AND AVG. PRESSURE OF 3300 PSI. PROPANT WAS 2 PPG TO 10 PPG 20/40 AND 12/18. SCREENED OUT 90 BBL INTO THE FLUSH. PUMPED 185,717 LBS.OF PROP W/ 173,592 9.9 PPG TO PERFS. LEFT 12,125 LBS. IN 4.5 TUBING SHOULD TAG @ 7300' TIME LOG ENTRY 08:40 MIRU, TGSM 16 PEOPLE ON LOCATION. PT TO 9500 PSI 09:15 PUMPED BREAKDOWN SATGE @ 30 BPM AND 2250 PSi SHUT IN AND GOT ISIP OF 1040 PSI PULSE TEST @ 5O PSI DROPS 09:40 PUMPED THE DATA FRAC @ 5 BPM AND 2438 PSI W/50 # XL GEL PREFORM STEP DOWN AND GOT ISIP OF 1185 PSI. 11:10 PUMPED 800 BBL PAD OF 50 # XL GEL W/J 478 FLUID LOSS AGENT @ 15 BPM AND 3738 PSI. PUMPED THE MAIN FRAC W/2 PPG 20/40 100 4.5 PPG 12/18 800 BBL 7 PPG 12/18 160 BBL 8.5 PPG 15 BBL 10 PPG 12/18 45 BBL GEL FLUSH AND 90 BBL WATER. 13:40 SCREENED OUT 90 BBL INTO THE FLUSH. PUMPED 185,717 LBS. OF PROPANT W/173,592 9.9 PPG TO PERFS. LEFT 12,125 LBS. IN 4.5 "TUBING EXPECT TAG @ 7300' 14:00 RDMO DS. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~-- K1(2N-313(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-313 PERFORATE, PERF SUPPORT 0815981833.2 DATE DAILY WORK UNIT NUMBER 08/29/98 PERFORATE IN N2 - OIL SAMPLE 8305 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 NOI NO SWS-ELMORE JONES FIELD AFC# CC# Signed ESTIMATE K85101 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 2840 PSI 1890 PSI 150 PSI 60 PSII 280 PSII 280 PSI DALLY SUMMARY SWS RAN GR/CCL LOG FROM 8925' TO 8275'. GUN GR/SAFE DID NOT FIRE. PERFED FROM 8736' TO 8756' USING 1900 PSI N2 WHP. 2ND RUN UNABLE TO GET GOOD ENOUGH COLLARS TO PERF, RD.[Perf] TIME LOG ENTRY 10:30 SWS MIRU, HELD TGSM. MU SAFE GUN & PT LUB TO 3000#. 12:15 MIH W/PETROLINE ROLLER, 20' - 2 7/8" HC, 4 SPF, ALTERNATING BH & DP BOTH SIDES, 180 DEG PHASED, 90 DEG ORIENT, SAFE, MPD, CCL/GR, SWIVEL, HEAD. 13:45 CORR TO SPERRY SUN ROP/DGR/EWR4 8-1-98 & OBTAINED GR/CCL LOG FROM 8925' TO 8275'. 14:30 BLEED N2 WELL HEAD PRESSURE TO 1900 PSI. 15:30 CORR TO SWS GR/CCL LOG 8-29-98, PERF DEPTH 8736' TO 8756'. NO SIGNS GUN FIRED. 16:15 POH. 17:15 LD GUN, GUN DID NOT FIRE, PERF GUN CARRIER PRESSURED UP W/N2. SAFE TOOL WAS BAD ? 18:45 MU NEW GUN & PT LUB TO 1900#. 18:00 MIH W/PETROLINE ROLLER, 20' - 2 7/8" HC, 4 SPF, ALTERNATING BH & DP ON EACH SIDE, 18- DEG PHASED, 90 DEG ORIENT, SAFE, MPD, SWIVEL, HEAD. CORR 'FO SWS GR/CCL LOG 8-29-98. PERF FROM 8736' TO 8756' USING 1900 PSI N2 WHP. 20:30 POH & LD GUN, ALL SHOTS FIRED. 22:00 MU SAFE GUN & PT LUB TO 1900#. 22:30 MIH W/PETROLINE ROLLER, 20' - 2 7/8" HC, 4 SPF, ALTERNATING BH & DP ON EACH SIDE AS ABOVE. ATTEMPT TO CORR TO SWS GR/CCL, UNABLE TO GET GOOD ENOUGH COLLARS TO PERF. 02:00 ~OH & LD GUN, WE DID NOT FIRE GUN. 03:15 RIG DOWN. 04:00 RELEASE SWS. ARCO Alaska, Inc. KUPARUK RIVER UNIT ~, WELL SERVICE REPORT '~ K1(2N-313(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-313 PERFORATE, PERF SUPPORT 0815981833.2 DATE DAILY WORK UNIT NUMBER 08/31/98 N2 PERFORATION-SAMPLES 8305 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 4 NOI YES SWS-ELMORE JONES FIELD AFC# CC# Signed ESTIMATE K85101 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1890 PSI 1830 PSI 50 PSI 50 PSII 275 PSII 275 PSI DALLY SUMMARY SWS PERFED FROM 8716' TO 8736' W/2 7/8" HC, 4 SPF, ALTERNATING BH & DP BOTH SIDES, 180 PHASED, 90 ORIENT. RAN PRESS, TEMP, GRADIO & OILPHASE SAMPLER, BLED BHP @ 8736' FROM 2238 PSI TO 2175 PSI, FLUID RISE FROM 8898' TO 8858' IN 40 MIN. TOOK SAMPLE @ 8900', FINAL FLUID LEVEL 8829'. RECOVERED GAS & 1/8 TEASPOON OIL. [Perf] TIME 08:00 10:00 13:00 14:00 14:30 18:00 19:15 20:15 20:30 21:45 23:15 LOG ENTRY SWS MIRU, HELD TGSM, SECURED RADIO SILENCE. MU GUN & PT LUB TO 1900# W/N2. MIH W/PETROLINE ROLLER, 20' - 2 7/8: HC, 4 SPF, ALTERNATING BH & DP BOTH SIDES, 180 DEG PHASED, 90 DEG ORIENT, MPD, TOOL SAVER, CCL/GR, SWIVEL, ROLLER. CORR TO SWS GR/CCL LOG 8-29-98 & PERF FROM 8716' TO 8736' W/1890 PSI N2 WHP. POH & LD GUN, ALL SHOTS FIRED. MU TOOLS & PT LUB TO 1900# W/N2. MIH W/OILPHASE 1 3/4" SAMPLER, SWS 1 11/16" ROLLER, PTG, GR/CCL, ROLLER. FOUND FLUID @ 8898' = 142' BELOW BTM PERF. SET PRESSURE SENSOR @ 8736', BHP - 2238 PSI. BLED BHP TO 2190 PSI & SHUT IN WELL TO WATCH BHP, BHP DROPPED TO 2175 PSI WHILE SHUT IN. FOUND FLUID @ 8859': 102' BELOW BTM PERF, 40' FLUID RISE IN 40 MIN, .9 BBL/HR RATE. TOOK FLUID SAMPLE @ 8900', FBHP = 2186 PSI, TEMP = 140 DEG, GRADIO = .7120 FINAL FLUID LEVEL = 8829', POH & LD TOOLS. CAUGHT SAMPLE IN PLASTIC CONTAINER, RECOVERED GAS & 1/8 TEASPOON OIL. RIG DOWN. RELEASED SWS. ARCO ALASKA, INC. KUPARUK RIVER UNIT DOYON 141 2N-313 50-103-20259-00 AK-MM- 80298 RKB= 149.70' SPERRY-SUN DRILLING SERVICES (TARN POOL) ORIGINAL Page 1 JULY, 1998 MagUTM VALUES: DECLINATION= 26.86x DIP ANGLE= 80.44x TOTAL FIELD STRENGTH= 57226nT DATE OF MAGNETIC DATA= 07/19/98 MEASURED ANGLE DIRECTION DEPTH DEG DEG TIE-ON SURVEY: 108.00 0.00 0.00 VERTICAL DEPTH (RKB) 108.00 LATITUDE DEPARTURE VERTICAL DOG FEET FEET SECTION LEG 0.00 0.00 0.00 0.00 167.26 0.41 258.36 0.51 350.76 2.21 436.45 4.33 168.17 269.39 306.00 313.76 167.26 258.36 350.73 436.28 0.21 S 0.04 E -0.20 0.69 0.53 S 0.30 W -0.32 0.78 0.51 N 2.15 W 1.50 1.98 3.72 N 5.82 W 6.09 2.52 524.89 7.15 622.71 10.86 713.58 16.13 807.58 19.33 894.06 23.16 319.18 324.09 328.31 330.54 331.80 524.26 620.86 709.19 798.72 879.31 10.20 N 11.83 W 14.68 3.24 22.27 N 21.22 W 29.80 3.87 39.96 N 32.88 W 50.93 5.90 64.62 N 47.39 W 79.54 3.48 92.08 N 62.48 W 110.87 4.46 978.16 27.83 1073.75 32.98 1167.94 36.74 1262.00 41.72 1355.13 46.44 332.53 330.16 331.34 330.73 330.29 955.20 1037.62 1114.89 1187.73 1254.61 124.09 N 79.36 W 147.04 5.57 166.49 N 102.61 W 195.40 5.53 213.46 N 128.89 W 249.22 4.06 265.48 N 157.70 W 308.69 5.31 321.85 N 189.59 W 373.46 5.08 1447.75 49.92 1540.68 53.65 1632.79 55.08 1725.29 58.52 1818.75 58.46 330.01 330.77 330.12 331.12 331.02 1316.36 1373.84 1427.50 1478.15 1526.99 381.71 N 223.95 W 442.46 3.76 445.18 N 260.01 W 515.46 4.06 510.30 N 296.93 W 590.32 1.66 577.74 N 334.89 W 667.71 3.83 647.48 N 373.43 W 747.39 0.11 1909.83 58.38 2002.97 58.29 2098.40 58.07 2189.87 57.58 2282.74 57.25 331.43 331.68 331.91 332.41 333.30 1574.69 1623.58 1673.90 1722.61 1772.62 715.49 N 410.78 W 824.98 0.39 785.19 N 448.54 W 904.24 0.25 856.65 N 486.87 W 985.32 0.31 925.11 N 523.03 W 1062.72 0.71 994.74 N 558.73 W 1140.91 0.88 2375.44 59.18 2462.69 59.32 2562.60 59.54 2659.30 59.62 2749.03 59.55 332.05 332.09 332.86 333.66 334.16 1821.45 1866.06 1916.87 1965.84 2011.26 1064.74 N 594.90 W 1219.66 2.38 1130.99 N 630.03 W 1294.63 0.17 1207.27 N 669.78 W 1380.61 0.70 1281.74 N 707.30 W 1463.92 0.72 1351.24 N 741.33 W 1541.18 0.49 2835.03 59.73 2933.49 59.55 3027.46 59.10 3119.27 58.86 3212.49 58.69 331.01 331.43 331.60 331.95 332.72 2054.74 2104.51 2152.45 2199.76 2248.08 1417.10 N 775.49 W 1615.34 3.17 1491.56 N 816.39 W 1700.29 0.41 1562.60 N 854.94 W 1781.11 0.50 1631.92 N 892.15 W 1859.77 0.42 1702.52 N 929.16 W 1939.46 0.73. SPERRY-SUNDRILLING SERVICES Page 2 ARCO ALASKA, INC. KUPARUK RIVER UNIT DOYON 141 2N-313 50-103-20259-00 AK-MM-80298 RKB= 149.70' (TARN POOL ) JULY, 1998 MagUTM VALUES: DECLINATION= 26.86x DIP ANGLE= 80.44x TOTAL FIELD STRENGTH= 57226nT DATE OF MAGNETIC DATA= 07/19/98 MEASURED ANGLE DEPTH DEG 3286.99 58.38 3356.79 58.89 3453.70 58.67 3546.90 58.93 3638.35 59.12 DIRECTION DEG 332.47 331.83 331.18 331.06 330.83 VERTICAL DEPTH (RKB) 2286.97 2323.30 2373.53 2421.81 2468.88 LATITUDE DEPARTURE VERTICAL DOG FEET FEET SECTION LEG 1758.94 N 958.41 W 2002.97 0.51 1811.63 N 986.25 W 2062.55 1.07 1884.47 N 1025.79 W 2145.42 0.62 1954.28 N 1064.29 W 2225.14 0.30 2022.82 N 1102.37 W 2303.55 0.30 3731.32 59.10 3824.44 58.98 3918.53 58.97 4011.67 59.05 4104.35 59.07 329.95 330.97 330.53 330.42 330.86 2516.61 2564.52 2613.01 2660.97 2708.62 2092.18 N 1141.79 W 2383.33 0.81 2161.65 N 1181.16 W 2463.18 0.95 2232.00 N 1220.56 W 2543.81 0.40 2301.48 N 1259.91 W 2623.65 0.13 2370.76 N 1298.88 W 2703.14 0.41 4196.11 58.99 4287.86 58.85 4379.69 58.84 4474.85 59.26 4568.33 59.48 330.18 330.47 330.56 330.44 330.53 2755.84 2803.20 2850.71 2899.65 2947.28 2439.25 N 1337.60 W 2781.82 0.64 2507.52 N 1376.50 W 2860.40 0.31 2575.93 N 1415.18 W 2938.98 0.08 2646.96 N 1455.37 W 3020.59 0.45 2716.96 N 1495.00 W 3101.03 0.25 4660.83 59.79 4753.13 60.19 4846.86 60.29 4940.62 60.02 5031.04 59.91 330.48 329.64 330.06 332.32 332.31 2994.04 3040.20 3086.73 3133.39 3178.65 2786.42 N 1534.29 W 3180.84 0.34 2855.68 N 1574.18 W 3260.76 0.90 2926.04 N 1615.05 W 3342.11 0.40 2997.29 N 1654.24 W 3423.43 2.11 3066.61 N 1690.61 W 3501.68 0.12 5123.92 59.73 5216.79 59.42 5310.98 59.37 5403.56 59.24 5496.33 59.23 332.46 331.73 331.75 331.52 331.31 3225.34 3272.37 3320.33 3367.58 3415.04 3137.75 N 1727.83 W 3581.94 0.24 3208.52 N 1765.30 W 3661.99 0.76 3279.93 N 1803.69 W 3743.05 0.06 3349.98 N 1841.51 W 3822.65 0.26 3419.98 N 1879.65 W 3902.36 0.19 5587.62 59.02 5681.89 58.96 5774.48 59.05 5867.29 58.88 5959.58 58.92 331.20 330.05 330.11 329.22 329.29 3461.89 3510.45 3558.13 3605.98 3653.65 3488.68 N 1917.33 W 3980.71 0.25 3559.08 N 1956.96 W 4061.50 1.05 3627.87 N 1996.55 W 4140.87 0.11 3696.51 N 2036.71 W 4220.38 0.84 3764.43 N 2077.11 W 4299.37 0.08 6052.98 59.19 6146.15 59.47 6239.21 60.00 6332.09 60.34 6426.71 61.12 329.82 329.88 330.41 330.87 330.49 3701.68 3749.21 3796.11 3842.31 3888.57 3833.49 N 2117.70 W 4379.46 0.57 3902.78 N 2157.95 W 4459.59 0.31 3972.49 N 2197.96 W 4539.96 0.75 4042.72 N 2237.47 W 4620.53 0.56 4114.68 N 2277.89 W 4703.07 0.90 Page 3 SPERRY-SUN DRILLING SERVICES ARCO ALASKA, INC. KUPARUK RIVER UNIT DOYON 141 2N-313 50-103-20259-00 AK-MM-80298 RKB= 149.70' (TARN POOL) JULY, 1998 MagUTMVALUES: DECLINATION= 26.86x DIP ANGLE= 80.44x TOTAL FIELD STRENGTH= 57226nT DATE OF MAGNETIC DATA= 07/19/98 MEASURED ANGLE DIRECTION VERTICAL DEPTH DEG DEG DEPTH (RKB) 6517.91 60.53 328.47 3933.03 6612.10 60.76 328.33 3979.21 6704.93 58.45 328.13 4026.17 6798.04 58.25 327.94 4075.03 6890.99 58.57 327.88 4123.72 LATITUDE DEPARTURE VERTICAL DOG FEET FEET SECTION LEG 4183.28 N 2318.32 W 4782.68 2.04 4253.20 N 2361.34 W 4864.70 0.28 4321.27 N 2403.49 W 4944.69 2.50 4388.51 N 2445.45 W 5023.86 0.28 4455.59 N 2487.51 W 5102.94 0.35 6983.33 58.79 327.07 4171.72 7074.78 58.78 327.20 4219.12 7167.55 58.74 326.67 4267.23 7262.31 58.96 326.40 4316.25 7355.01 59.28 328.53 4363.83 4522.10 N 2529.93 W 5181.69 0.79 4587.80 N 2572.37 W 5259.75 0.12 4654.27 N 2615.64 W 5338.89 0.49 4721.92 N 2660.36 W 5419.77 0.34 4788.99 N 2703.15 W 5499.19 2.00 7445.47 59.42 328.88 4409.94 7541.38 59.39 328.69 4458.76 7633.21 59.34 328.78 4505.55 7724.88 58.00 329.82 4553.22 7817.29 55.49 330.08 4603.89 4855.49 N 2743.57 W 5576.96 0.37 4926.10 N 2786.36 W 5659.470.17 4993.63 N 2827.36 W 5738.43 0.10 5060.96 N 2867.34 W 5816.71 1.75 5127.84 N 2906.04 W 5893.97 2.73 7910.63 54.08 330.35 4657.71 8003.33 52.03 330.68 4713.43 8096.13 49.69 330.80 4772.00 8189.14 47.40 331.52 4833.57 8282.96 44.95 331.73 4898.53 5194.02 N 2943.92 W 5970.22 1.53 5258.51 N 2980.39 W 6044.30 2.23 5321.30 N 3015.56 W 6116.27 2.52 5382.35 N 3049.19 W 6185.98 2.53 5441.90 N 3081.36 W 6253.65 2.62 8380.45 44.98 331.76 4967.51 8472.42 45.84 332.70 5032.08 8533.83 46.35 332.61 5074.66 8743.81 46.72 332.90 5219.11 8839.19 46.80 332.86 5284.45 5502.59 N 3113.98 W 6322.53 0.04 5560.54 N 3144.49 W 6388.01 1.18 5599.84 N 3164.81 W 6432.23 0.84 5735.33 N 3234.58 W 6584.54 0.20 5797.18 N 3266.25 W 6653.97 0.09 8932.19 47.02 332.38 5347.98 9024.47 47.65 332.13 5410.52 9067.55 47.94 332.44 5439.46 SURVEY PROJECTED TO TD: 9134.00 47.94 332.44 5483.98 5857.49 N 3297.49 W 6721.85 0.45 5917.54 N 3329.08 W 6789.69 0.71 5945.79 N 3343.92 W 6821.59 0.86 5989.53 N 3366.75 W 6870.90 0.00 THE DOGLEG SEVERITY IS IN DEGREES PER 100.00 FEET THE VERTICAL SECTION WAS COMPUTED ALONG 330.76x (TRUE) BASED UPON MINIMUM CURVATURE TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 6870.91 FEET, IN THE DIRECTION OF 330.66x (TRUE) SURFACE LOCATION: ASP ZONE 4 X: 460947.050 W Y: 5911973.740 N 8/1 1/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11415 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool (Open Hole) Well Job # Log Description Date BL RF Sepia Color US Print Tape KRU 2N-313 98402 JRELABELED DSI 980730 1 KRU 2N-313 98403 PEX-CNL 980'/30 I 1 ~r ' KRU 2N-313 98403 ~q~{;-~ 3 ]3BZ'.Z:Ii~S:ITZ'Y 980730 I 1 KRU,2N-313 98403 ~ 980730 I 1 KRU 2N-313 98403 CEMENT VOLUME LOG 980730 I 1 KRU 2N-313 ~.. '~~ 98403 PEX-DAS,SDN,CNT 980'730 I DATE: RECEIVED SIGNED. Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. AUG 2. 0 1998 Naska 0ii & Gas Cons. C0mlllissJ0n Anchorage 1. Type of Request: Abandon__ Alter casing _ Repair well _ Change approved program __ -- .... STATE OF ALASKA " ~ A~Dvflo~.,^~ ALASKA OIL AND GAs CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Suspend_ Operation Shutdown __ Re-enter suspended well_ Plugging __ Time extension __ Stimulate _ Pull tubing__ Variance__ Perforate_ Other X Annular Iniection 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory _ Stratigraphic _ Service 4. Location of well at surface 34' FNL, 644' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 412' FSL, 1429' FWL, Sec. 27, T10N, R7E, UM (projected) At effective depth At total depth 676' FSL, 1269' FWL, Sec. 27, T10N, R7E, UM 12. Present well condition summary Total Depth: measured 9134 (approx) true vertical 5484 Effective depth: measured 9022 (approx) true vertical 5409 Casing Length Size Structural Conductor 80' 16" Surface 3291' 9.625" Intermediate Production 9091' 7"x4.5" Liner feet feet feet feet Perforation depth: measured NONE true vertical NONE Tubing (size, grade, and measured depth) 4.5", 12.6#, L-80 @ 8410' Packers and SSSV (type and measured depth) Baker Csg Seal Receptacle (CSR) @ 8395', no SSSV 13. Attachments Description summary of proposal __ Contact Tom Brassfield at 265-6377 with any questions. 14. Estimated date for commencing operation Auqust 1998 16. If proposal was verbally approved Name of approver Date approved Plugs (measured) None Junk (measured) 6. Datum elevation (DF or KB) 28' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2N-313 9. Permit number 98-91 10. APl number 50-103-20259 11. Field/Pool Kuparuk River/Tarn Pool Cemented Measured depth 10 yds High Early 108' 374 sx AS IIILW, 3319' 422 sx Class G 356 bbls Class G 9119' Trueverticaldepth 108' 2304' 5474' feet Detailed operation program __ BOP sketch__ LOT test, surface cement details and casing detail sheets X 15. Status of well classification as: Oil X Gas_ Suspended__ Service 17. I her(~by certify that th._..,,,_e foregoing is true and correct to the best of mv knowledge. Title Ta'~n Drilling Team Leader Commissioner FOR COMMISSION USE ONLY IApprOval N~32 ~) Date Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test_ Location clearance Mechanical Integrity Test_ Subsequent form~¢j,,~require,, -/" 1 Approved by the order of the Commission 0ri~iiq?~l Sigr~ed David vv. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Casing Detail 9.625" Surface Casina ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL: TARN 2N-313 DATE: 7/21/98 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RKB to Pad = 29.5' TOPS Above RKB 9 5/8" Landing Joint 29.50 FMC GEN V- Prudhoe 9 5/8" Csg Hgr 1.75 29.50 jts. 44-83 9 5/8", 40#, L-80 BTC 1539.41 31.25 jr. 90 9 5/8", 40#, L-80 BTC (Thread Locked Collar) 39.29 1570.66 Gemeco 9 5/8" Stage Collar (BAKERLOK) 2.82 1609.95 jr. 89 9 5/8", 40#, L-80 BTC (Thread Locked Collar) 41.13 161 2.77 jts. 3-43 9 5/8", 40#, L-80 BTC (shutoff baffle on top of jt #3, BAKERLOK) 1579.63 1653.90 Gemeco Float Collar 1.45 3233.53 jts 1-2 9 5/8", 40#, L-80 BTC 82.41 3234.98 Gemeco Float Shoe 1.70 331 7.39 3319.09 INSERT BAFFLE @ 3196 38 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1,2, 89, 90 over stop collars and over casing collars on Jts. 3-14 and over collars of jts. 17,20,23,26,29,32,35,38,41,46,49,52,55,58,61,64,67,70,73,76,79,82. Joints 84-88 (5 joints) will remain in the pipe shed. Remarks: String Weights with Blocks: 120K# Up, 80K# Dn, 12k# Blocks. Ran 85 joints of casing. Drifted casing with 8.679 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor:DAVE BURLEY ARCO Alaska, Inc. Cementing Details Well Name: 2N-313 Report Date: 07~23~98 Report Numben 5 Rig Name: DOYON 141 AFC No.: AK9397 Field: Tam Casing Size Hole Diameter:. Angle thru KRU: Shoe Depth: I LC Depth: % washout: 9- 518" 12.25" nla 3319I 3196 Centralizers State type used, intervals covered and spacing Comments: 38 Gemeco bow spring centralizers, detailed on casing tally. i Mud Weight: PV(pdor cond): PV(affer cond): I YP{prior cond): YP(after cond): :Comments: 10.1 34 20I 28 17 Gels before: Gels after:. Total Volume Circulated: 8/14 3/4 960 bbls I 840 bbls Wash 0 Type: Volum e: Weight: Comments: !Spacer 0 Type: Volume: Weight: comments: ARCO 30 bbls/30 bbls 10.5110.5 1St Stagel2nd Stage LeadCement 0 ' ' Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: AS III LW 70170 94 1280I 10.5 4.42 1st Stagel2nd Stage : Additives: . . · . . Standard blend Tail cement 0 ' : Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: 70170 362160I 10.8110.9 1.1710.93 1st stage/2nd stage · G Additives: 1% si, 0.2% 1:)46, 0.3"/. D65 ///Artic Set t Di~acernent:: 0 ': Rate(before tail at shoe): Rate(tail around shoe): Str. Wi. Up: comments:. . 9 bpm 110 bpm 9 bpm 110 bpm 120 1st Stage/2nd. Stage Reciprocation length: Reciprocation speed: Str. Wf_ Down: 20 15 fpm 80 · .. 'Theoretical Displacement: Actual Displacement Str. VVt. in mud: ·: : 242.25 bbls 1 122 bbls 241.9 bbls ! 122.7 bbls 112 Calculated top of cement: I CP: Bumped plug: Floats held: Surface thru stage collar (~ 1610'.I Date:7-22-98 yes I yes yes Time:2143 hrs Remarks:lst Stage: Conditioned mud at 9 bpm, pumped 5 bbls water, 30 bbls of 10.5 ppg spacer, 74 bbls of 10.5 ppg AS3 Lite lead and 75 bbls of t5.8 ppg G tail cement. Displaced with 20 bbls water, 90 bbls of mud, 29 bbls of spacer and 102.9 bbls of mud. Reciprocated pipe unfill last 41 bbls of displacement, had full returns while circulating and cementing. 2nd Stage: Conditioned mud at 10 bpm, pumped 5 bbls of water, 220 bbls AS3 Ute lead and 10 bbls of Arfic set I tail cement. Displaced with 20 bbls of water and 102.7 bbls of mud, had full returns while circulating and cementing. Displaced out 110 bbls of 10.5 ppg cement at surface. ICement Company: I Rig Contractor: IApproved By: DS DOYON ID.P. BURLEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N 313 Supervisor: D.BURLEY Date: 7~24~98 Casing Size and Description: Casing Setting Depth: Mud Weight: Hole Depth: LOT: 9 5/8", 40 ppf, L-80, BTC 3,319' TMD 9.1 ppg 2,320' TVD 850 psi (0.052 x 2,320') Fluid Pumped = 4.2 bbl 2,303' TVD EMW = Leak-off Press. + MW 0.052 x TVD + 9.1 ppg EMW = 16.1 ppg Pump output = 0.1010 bps 2,300 psi 2,000 psi -- -jJ ~ :~ !!¢ ~: ~:~. ,.~. '.')m r~.' '¢: 'Z~ .~ ~-'Ct. '~.r '~ 1,900 psi. 1,800 psi j -- -- -- 1,700 psi ........... f 1,600 psi ~ 1,500 psi LU 1,400 psi -- ~ ~, _ ~.~1,300 psi (/)1,200 psi J tY 1,000 psi O. 900 psi ~ 800 psi 700 psi tlr k ___ _ 600 psi J~ {I .... ~LEAK-OFF TEST 500 psi ~J ] -- ~- --~'CASING TEST 4OO psi ::'= ":", .':~'".;:': :".'~: .... ::.... LOT SHUT IN TIME 300 psi -- -- 200 psi~.-~ .... .--&,.. CASING TEST SHUT IN TIME 100 psi .~ .... 0 psi!~ ---~' TIME LINE 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 72 74 76 78 U0 U2 84 U6 [~8 90 92 94 96 st st st st st st st sL st st sL st st st si st st st st st st st si st si st st st st st st st sL sL si st st ,st sL st st st si st st st st st st k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE i .................................... ...,. k .................. 0 stks 0 psi i .................. -,- .................. ~. .................. .1 1 stks 150 psi ........................ ~-~-i~-~ ......... '~-~-i~'~ ..... 3 stks 300 psi ........................ ~__~_t__~.s_ ......... ~J__O___p_~_! ..... ........................ &_~.t__~.~_ ......... _.4Z.o__e._~.~ ..... 6 stks 560 psi i .................. -4- .................. ~ .................. 4 7 stks 650 psi 8 stks 740 psi 9 stks 830 psi ....................... J__O.._~.t_~.s' ........ ~_o._p._s.i ..... ....................... JJ___~.t__~ ........ ~_o.__p..~_i ..... 12 stks 460 psi ....................... '~'¥'~'t'~ ........ '~'~'i,'~ ..... ....................... -~'~'t'~ ........ ',f~iri,'~ ..... 27 stks 460 psi , .. 32stks ~ 450 psi ! ..................... ~¥'~'t'l~ ....... '~'[~'~i .... [ ...................... -4~-~-t~ .... i'"-4'4o'i~'~ ..... F .................. i CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 0 stks 0 psi ........................ -i-~- ......... ~'~'~'i~a'--i ........................ '~'~' ......... ~'f~'~-F--i 8 stks 920 psi 12 stks 1,280 psi ........................ .i-~-~ii~-~- ....... .i-,-~i~--~,-~i--'~ ....................... ..z.o._~t..~2. ....... _2_,.o..2..o.._p~!.. ,,, SHUT IN TIME SHUT IN PRESSURE 1.Omen : : 2,020 ps[ : SHUT IN TIME ............ · - ..... + .................. F ............. = .... t ..... p.._m.!.%.i .................. .,, ....~_.s__o.._p~., .... j , 9.0min j j 350 psi j E!~Pii~!EiXXZXZZXEZ.~i~iE.~i~!ii] i l.. .................. I. .................. .I .................. ., SHUTIN PRESSURE 3.0 min i 2,010 psi j .... -,~:~-R-,-ix ....................... i'"~',~'-~,'~i"i .... 'Eo'~,'i~ .... r .................. r--~,','~i~--F~r--~ .... '~:~'~'i~ .... ' .................. l'"f,'~"Fa'" ............ -. ...... r .................. ~ ............... =--' .... l:.O_..m.j.n. .... ... .................. j..j_,~.o.£~,... .... ._~:.o_..m.j.n. ....................... Lj_,~.o_~L.. 9.0 min j 1,990 psi .... ~'o:u'F~;i~ ...................... i'"f,~iiiO'-mY~i"' .... ~'~:6'F~iT~ ...................... i'--'i-,'~ii~'-I~-~i--' ............. ~ ..... I' .................. 4 ............... ,....29...°._.m.'.n.._..,' .................. .L._?_,.9.l_O__e.s.!..j L 25.0min .,, ] 1,970psi j '"~'o:o'~i~"" .................. K'f,'~¥~"~'~i" ' NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY { COREL./~I.Bl eom Laborator,~a - A,aska From: Core Laboratories 600 W. 58th Ave., Unit D Anchorage, Alaska 99518 To: Alaska Oil & Gas Conservation Commissio~ 3001 Porcupine Drive Anchorage, Alaska 99501 Date: 6-Aug-98 Well Name: ARCO ALASKA - TARN 2N-313 Number of Samples: 3 Cores - 250 ft total recovery Contact: Doug Hastings -ARCO Geologist Description of Material: Core Chip Samples Depths: Core 1' 8570.00 - 8661.80 ~ Core 2:8661.80 8751.00 ft ~ Core 3:8751.00 8820.00 ft ~/ Sent By: Received By: Core "~'aboratories MEMORANDUM TO: State of Alaska ~ Alaska Oil and Gas Conservation Commission / /_ David Johns~, DATE: July 23, 1998 Chairman THRU' Blair Wondzell, ~ P. I. Supervisor 7/¢9/'~i' FROM' Larry Wad e, ~,,.,..,,.~. SUBJECT: Petroleum Inspector /2 FILE NO: .DOC BOP Test Doyon 141 KRU 2N-313 PTD 98-091 July 23,1998' I traveled to Tarn to witness a BOP test on Doyon 141. The test was going well till we picked up the kelly. While filling the kelly we encountered a wash pipe packing leak. Also the upper and lower kelly valves wouldn't pass the pressure test. The packing, u_p.p_..~r a_.nd Iow_,.er valve_s wer___e replaced wit...~h tv3,_o valv____es off the rack and those valves wouldn't pass. They had two rebuild kits and are going to retest before they drill out the float shoe. SUMMARY: I witnessed a BOP test on Doyon 141,2 failures, 6 hours. Attachments' abwggwfe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial X' Workover: Doyon Rig No. 141 PTD # 98-091 ARCO Rep.: 2N-313 Rig Rep.: Set @ 33?7' Location: Sec. Weekly Other DATE: July 23,1998 Rig Ph.# 659-7165 Dave Bur/ey Bobb/e Ingram 3 T. 9N R. 7E Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location yes Standing Order Posted yes BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign yes Drl. Rig yes Hazard Sec. yes Quan. ? Test Press. P/F 250/3, 500 P I 20/3, 500 P 1 250/3,500 F I 250/3,500 P 2 250/3, 500 P 2 250/3,500 P 2 250/3,500 P 1 250/3, 500 P MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X' X Flow Indicator X' X' Meth Gas Detector X X Has Gas Detector X' X' FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quart. Pressure P/F I 250/3, 50O F 250/3, 500 F 250/3, 500 P 250/3,500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 15 250/3,500 P 38 250/3,500 P ? P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3, 050 2,100 minutes 25 sec. 2 minutes 0 sec. x Remote: x 2100-2200-2200 2150-2000 Psig. TEST RESULTS Number of Failures: 2 ,Test Time: 6.0 Hours. NumDer of valves tested 24 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to tl3e AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P, I, Supervisor at 279-1433 REMARKS: Distribution: Grig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade FI-021L (Rev. 12/94 ) Abwggwfe.xls TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION May 27. 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mike Zanghi Drill Site Development Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk Rivcr Unit 2N-313 ARCO Alaska. Inc. Permit No 98-91 Sur. Loc.: 33'FNL. 646'FEL. Sec. 3. T9N. R7E. UM Btmholc Loc: 1170'FSL. 1005'FWL. Scc. 27. TION. R7E. UM Dcar Mr. Zanghi' Enclosed is thc approved application for permit to drill thc above rcfcrcnccd xvcll. Thc pcrmit to drill docs not cxcmpt you from obtaining additional permits rcquircd by law from othcr govcrnmcntal agcncics, and docs not authorize conducting drilling opcrations until all other required permitting dctcrminations arc made. Approval of annular disposal of drilling wastes is contingcnt on obtaining a xvcll ccmcntcd surfacc casing confirmed by a valid Formation Integrity Tcst (FIT). Ccmcnting records. FIT data. and any CQLs must bc submittcd to thc Commission on form 10-403 to cnsurc thc rcquircmcnts of 20 AAC 25.080 arc tact prior to initiating disposal opcrations. Blowout prevention cquipmcnt (BOPE) must bc tcstcd in accordancc with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of thc BOPE tcst pcrfonncd bcforc drilling below the surfacc casing shoe must be given so that a rcprcscntativc of thc Commission may witness the test. Notice may bc givcn by contacting thc Commission pctrolcum ficld inspcctor on thc North Slopc pagcr at 659-3607 David W. Johnston ~ Chairmal] ~_____.~ BY ORDER OF THE COMMISSION dlffcnclosurcs cc~ Dcpartmcnt of Fish & Game, Habitat Scction w/o cncl. Dcpartmcnt of Environmcntal Conscrvation v,'/o cnci. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Redrill [~llb. TypeofWell Exploratory E~ StratigraphicTest [~ Development Oil X Re-Entry [~' Deepen F'[ service ~' Development Gas E single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Unit 3. Address 6. Property Designation Tarn Pool P. O. Box 100360, Anchorage, AK 99510-0360 ALK 4802 ADL 380054 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 33' FNL 646' FEL Sec 3 T9N R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 412' FSL 1,429' FWL Sec 27 T10N R7E, UM 2N 313 #U-630610 At total depth 9. Approximate spud date Amount 1,170' FSL 1,005' FWL Sec 27 T10N R7E, UM 5/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ARCO Tarn #3 (P x A) MD 9,930' 412' @ target feet -500' feet 2,560 TVD 6,049' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 609 Maximum surface 1,835 psig At total depth (TVD) 2,425 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" Welded 80' 28' 28' 108' 108' 230 sx+ Permafrost Cement 12¼" 9-5/8" 40 ppf L-80 BTC 3,297' 28' 28' 3,297' 2,300' 1. 110 sx AS3L, 350 sx Cl G 2. 360 sx AS3L, 290 sx AS 1 8~/~'' 7" 26 ppf L-80 BTC-Mod 8,298' 28' 28' 8,298' 4,896' 800 sxG 8~" 4Y2" 12.6 ppf L-80 NSCT 1,632' 8,298' 4,896' 9,930' 6,049' (included above) 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 ;~'~/~ i?~ ?~' Intermediate Production Perforation depth: measured ; ' ,- ~' true vertical 20. Attachments Filing fee X Property plat r'~ BOP Sketch X Diverter Sketch X ..... ?~D?-'._!'.~-g'-p-rue[Iram X Ddlling fluid program X Time vs depth plot F~ Refraction analysis [~ Seabed report F' 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~-~E~.~ ~ /~,~._ ~/,E ,~tG~/'¢~ Title Drill Site Development Supv. Date ~ (.J ~ - Commission Use Only APl number See cover letter for Permit NuJ~_. ~ 50-/~,,~-'- .2~} ~..,~' ? I Approval date ~,~'--~'O~ ¢'"' ¢ ~ I other requirements Conditions of approval Samples required [~ Yes ~ No Mud log required I~ Yes ~ No .ydrogen sulfide measures []Yes ~ No Directional survey required ~ Yes [-- No Required workin~ pressure for BOPE I~ 2M U 3M '~, 5M [-- 10M I~ Other: 0ri inal $i nea by order of --5'--C2 Approved by .... :,4 \M _tnhrlS~.OB commissioner the commission Date : Form 10-401 Rev. 7-24-89 ~1~~/ Submit in triplicate ARCO Alaska, Inc. Post Office Box~i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 27, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-313 Surface Location: 33' FNL 646' FEL Sec 3 T9N R7E, UM Target Location: 412' FSL 1,429' FWL Sec 27 T10N RTE, UM Bottom Hole Location: 1,170' FSL 1,005' FWL Sec 27 T10N RTE, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N 313, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. Because of an early thaw this year on the North Slope, the drilling order of the wells has changed. The drilling order is in a state of flux because we are trying to optimize rig moves on the pad. Moving well to well is challenging under the present circumstances. This well required a spacing exception. That exception was filed April 14, 1998. The well can be accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c) and 20 AAC 25.061. There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tam formation, which is similar in depth to the Kuparuk Formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the 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 20 AAC 25.033(e, 2, D). The shale density technique does not work well in Alaska because of the variable shale ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C David W. Johnston Application for Permit to Drill Page 2 KRU 2N-313 composition, and the chemical used in the shale density determination is listed as an exceptional health hazard. The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Fred Johnson, Drilling Engineer 265-1492 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Fred Johnson at the number above or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tam Development Group Attachments cc: KRU 2N-313 Well File 2N 313 WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 135' MD / RKB permafrost~.iiiiiii 1,271' MD :i:i:i:i :.:..'.:. -:.:,:.: Stage Collar .:.:.: ;-:.:., 1,500' MD ::5::: Top of :::::::: West Sak 1,329' MD Base of West Sak 2,603' MD 9-5/8" Surface Casing at 3,297' MD Top of Cement at 7,700' MD 7- Production Casing at 8,298' MD 4-1/2" Production Casing at 9,930' MD .:, :,:.:,- · .:.:.:.: :.:.:.:.:.:. :::i:i:i:i:i 8~" Hole Conductor Casing Size I Hole Size Depth: 135' MD Top of Cement Surface Excess Calculated: ! 00% RKB 16" in 2(7' hole Volume Calculations: (135 It) (0.7854 cf/If) (2.00) = 212 cf (212 cf) /'(0.93 cf/sx) = 230 sx Slurry Volume: 212 cf or Arctic Set 1 230 sx Slurry Weight 15.7 ppg rounded Slurry Yield 0.93 ct/sx Surface Casing excess 9-5/8' in 12-1/4' hole Stage 1: Volume (997 If) (0.3132 cf/If) (1.45) = 453 cf Lead (453 cf) /(4.42 cf/sx) = 102 sx Tail (800 If) (0.3132 cf/if) (1.45) = 366 cf shoe joint vol 30 sx + (363 cf) /(1.15 cf/sx) = 346sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% 1353 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI~) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (Cl G crnt + 1% SI(CaCI2} + 0.3% 1365 (disp.) + 0.2% D46 (defoam.) Lead Slurry Volume: 453 cf or 110 sx Slun7 Weight 10.5 ppg Arc#c Set 3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 363 cf or 350 sx Slurry Weight 15.8 ppg C/ass G Slurry Yield 1.15 cf/sx Thlckeninc~ Time 3.5 - 4.5 hours Surface Casing excess Stage 2: Vol. Lead (1,271 If) (0.3132 cf/if) (4.00) = 1,592 cf (~,592 cf) /(4.42 cf/sx) = 360 sx Tail (121 If) (0.3132 cf/if) (4.00) = 152 cf (229 If) (0.3132 cf/if) (1.45) = 104 cf (256 cf) /(0.93 cf/sx) = 275 sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI~) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (Arctic Set 1 cement ) Lead Slurry Volume: 1,592 cf or 360 sx Slurry Weight 10.5 ppg Arctic Set 3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 256 cf or 290 sx Slurry Weight 15.7 ppg Arctic Set 1 Slurry Yield 0.93 cf/sx Thickenin(~ Time 3.5 - 4.5 hours Production Casing Size I Hole Size Depth: 9,930' Top of 4-1/2" casing 8,298' Top of Cement 7,700' Excess Calculated: 75% BHT (Static): 160~ F BHT ( Cim): 130~ F Volume around 7 ' (598 If) (0.1268 cf/if) Volume around 4-1/2' (1,63210 (0.2836 cf/if) and 4-1/2" in 8-1/2" hole (1.75) = 133 cf (1.75) = 810 cf 943 cf shoe jointvol 6 sx ~- (943 cf) /(1.20 cf/sx) 791 sx System: (Class G cement + 2 gps D600 (latex) + 0.1 gps D135 (stabilizer) + 0.1 D47 (defoamer) ~- 3% D53 (Gyp) + 0.7% D65 (disp) + 0.15% D800 (retarder) Slurry Volume: 943 cf or 800 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.20 cf/sx Thickenin~l Time 3.5 - 4.5 hours 4/22/98 Analysis of Horizontal Stress within 2N-323 Prediction of Annular Injection Disposal Zone Tarn Development Michael J. Faust ARCO Alaska, Inc. Dipole Sonic (DSI) and Bulk Density logs were used to calculate four elastic modulus curves for this well from 3350 ft. MD to 9500 ft. MD. The following equations were used to generate the modulus curves: Young's Modulus = E = Density * (Ve)2 Bulk Modulus = K = Density *(Vp)2 Shear Modulus = G = Density * Vs2 Poisson's Ratio = P = (gp)2- 2(Vs)2 2[(Vp)2 - (Vs)2] Using these curves and standard elastic equations to estimate horizontal stress, two curves were generated to show the in-sim horizontal stress. Fracturing of the reservoir should occur first at the minimum horizontal stress. Two such curves are plotted, with Hor2 being the most reliable prediction given the available data. Also plotted for reference is a pore pressure gradient of 0.44 psi/ft and the overburden pressure gradient of 1.0 psi/ft. Based on this analysis from dynamic measurements of the elastic moduli, we believe that the most likely place for annular injected drilling fluids to go is the sandy interval from 3900 ft to 3918 ft MD. Assuming that we have a 3 ft net sand interval with 15% porosity, and an irreducible water saturation of 30%, we estimate that 35,000 BBL of fluid would displace a circular volume with a radius of 480' from the injection wellbore. ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 313 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point (3,297'+ MD 2,300' TVD) according to directional plan. 4. Run and cement 9-5/8" casing, using stage collar placed approximately 200' MD below the base of the permaf~,?,,st. Use lightweight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. AOGCC Casing Test Pressure: (minimum is 1,500 psig) or Min. Test: Csg depth (TVD) * 0.25 psi/ft = (2,300' TVD) * (0.25 psi/R) = 575 psi Maximum Test: 70% of Min. Yield Strength = (0.70) * (5,750 psi) = 4,025 psi 6. Drill out cement and 20' of new hole. Perform leak off test to 16.0 ppg EMW. This establishes a frac gradient equivalent. 7. Drill 81/2'' hole to TD (9,930' MD 6,049' TVD) according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 8. Run and cement 7" L-80 BTC Csg X 4½" L-80 NSCT tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. AOGCC Casing Test Pressure: (minimum is 1,500 psig) or Min. Test: Csg depth (TVD) * 0.25 psi/ft = (6,049' TVD) * (0.25 psi/R) = 1,512 psi Maximum Test: 70% of Min. Yield Strength = (0.70) * (7,240 psi) = 5,070 psi Maximum Test: 70% of Min. Yield Strength = (0. 70) * (8, 440 psi) = 5,910 psi 10. Run 41/~'' L-80 NSCT completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi.- 11. ND BOPE and install production tree. 12. Shut in and secure well. 2N 313 mlp, 04/25/98 ..... ARCO Alaska, Inc. 13. Clean location, RD and move to next well on 21'4 pad. Well will be left ready for perforating. AOGCC Casing Testing Regulation 20 AAC 25.030. (g) Pressure Testing of Casing and Casing Surveys. (1) with the exception of structural and conductor casing, before drilling out the casing or liner after cementing, all casing, liners, and liner laps must be tested to a surface pressure of 1500 psig, or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater; however, surface pressure must not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. If the pressure declines more than 10 percent in 30 minutes, or if there are indications of improper cementing, such as lost returns, cement channeling, or mechanical failure of equipment, corrective measures must be taken. (2) when, in the commission's discretion, casing is subjected to prolonged actual drilling operations the casing must be pressure tested, calipered or otherwise evaluated by a method approved by the commission. (3) for injection wells, a cement bond log must be obtained following the primary cementing of all casing that is 9-5/8 inches or less in diameter, and sufficient notice of pressure tests required by (1) of this subsection must be given, so that a representative of the commission may witness the test. 2N 313 mlp, 04/25/98 "~' ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 313 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.2 ppg 15-35 25-50 130-150* 10-25 15-40 5-7 9,5-10 __.10% Drill out to TD 9.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System' Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the 8Y2" production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0,11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,750 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,400 psi (0.50 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.0 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 4,970'. 2N 313 mlp, 04/25/98 ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 2N 313 is the plugged and abandoned ARCO Tarn #3 about one mile to the north. Drillinc~ Area Risks' The primary risk in the 2N 313 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into a nearby annulus or hauled to the nearest permitted Class II disposal well.. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluidduring any extended shut down (> 4 hr) in pumping operations. The 2N 313 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2 N~ :N :N :N :N :N :N :N :~~ b e permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi 2N 313 mlp, 04/25/98 ARCO Alaska, Inc. This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9.-5/8" 40 L-80 3 BTC 3,090 psi 2,627 psi 5,750 psi 4,888 psi 7" 26 L-80 3 BTC-M 5,410 psi 4,599 psi 7,240 psi 6,154 psi 4Y2" 12.6 L-80 3 NSCT 7,500 psi 6,375 psi 8,440 psi 7,174 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 2N 313 mlp, 04/25/98 Diverter Schematic Doyon 141 Flowline ~ 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 21¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO KRU 2N 313 DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS I I 3" 5,000 psi WP OCT r-- MANUAL GATE KILL LINE ~r~ 3" 5,000 psi WP Shaffer GATE VALVE 1 w/hydraulic actuator / J / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP \ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom [_ l CHOKE LINE ~1~~~~3.5,~0 psi WP OCT ~~ MANUAL GATE VALVE 13-5/8" 5,000 psi WP DRILLING SPOOL / L--I ~ W/tWO 3" 5,000 psi WP outlets I J SINGLE 13-5/8" 5,000 psi WP, I HYDRIL MPL BOP w/pipe 2N 313 WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 135' MD / RKB pe rmafrost'~.i:i:!:i~ Stage 1,500' MD Top of West Sak 1,329' MD Base of West Sak 2,603' MD 9-5/8" Surface Casing at 3,297' MD I I ;-;-;. ¥:;.. ¥:;.. ::!:i.: ::::::;: 12~" :::::::: Hole Top of Cement at 7,700' MD 7~ Production Casing at 8,298' MD 4-1/2" Production Casing at 9,930' MD :::i:i:!: .. ... .. .. ,. .. .. .. .. ... '.;.:.:.:.: 8~" Hole Conductor Casing Size ! Hole Size Depth: 135' MD Top of Cement Surface Excess Calculated: 100% RKB 16" in 2(7' hole Volume Calculations: (135 l0 (0.7854 cf/10 (2.00) = 212 cf (212 cf) /(0.93 cf/sx) = 230 sx Slurry Volume: 212 cf or Arctic Set I 230 sx Slurry Weight 15.7 ppg rounded Slurry Yield 0.93 cf/sx Surface Casing excess 9-5/8" in 12-1/4" hole Stage 1: Volume (997 If) (0.3132 cf/10 (1.45) = 453 cf -~ Lead (453 cf) /(4.42 cf/sx) = 102 sx Tail (800 If) (0.3132 cf/10 (1.45) = 363 cf .-~ shoe joint vol 30 sx + (363 cf) /(1.15 cf/sx) = 346sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCl) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCl2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (CIG cmt + 1% SI(CaCI2.) + 0.3% D65 (disp.) + 0.2% D46 (defoam.) Lead Slurry Volume: 453 cf ~ or 110 sx Slurry Weight 10.5 ppg Arctic Set 3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 363 cf for 350 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.15 cf/sx Thickening Time 3.5 - 4.5 hours Surface Casing excess Stage 2: VoL Lead (1,271 If) (0.3132 cf/If) (4.00) = 1,592 cf (1,592 cf) /(4.42 cf/sx) = 360 sx Tail (121 l0 (0.3132 cf/if) (4.00) = 152 cf (229 l0 (0.3132 cf/10 (1.45) = 104 cf (256 cf) /(0.93 cf/sx) = 275 sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% S1 (CaClz) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (Arctic Set 1 cement ) Lead Slurry Volume: 1,592 cf "~or 360 sx Slurry Weight 10.5 ppg Arctic Set 3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 256 cf ~r 290 sx Slurry Weight 15.7 ppg Arctic Set 1 Slurry Yield 0.93 cf/sx Thickening Time 3.5 - 4.5 hours Production Casing Size / Hole Size Depth: 9,930' Top of 4-1/2" casing 8,298' Top of Cement 7,700' Excess Calculated: 75% BH'I- (Static): 160° F BHT ( Circ): 130-0 F Volume around 7 ' (598 If) (0.1268 cf/10 Volume around 4-1/2" (1,632 If) (0.2836 cf/10 7" and 4-112" in 8-1/2" hole (1.75) = 133 cf (1.75) = 810 cf 943 cf ----. shoe joint vol 6 sx + (943 cf) /(1.20 cf/sx) 791 sx System: (Class G cement + 2 gps D600 (latex) + 0.1 gps D135 (stabilizer) + 0.1 D47 (defoamer) + 3% D53 (Gyp) + 0.7% D65 (disp) + 0.15% D800 (retarder) Slurry Volume: 943 cf or 800 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.20 cf/sx Thickeninq Time 3.5 - 4.5 hours 4/22/98 w*;.c" For: M PRESTRIDGE Dote plotted : 24-gpr-98 Plot ReterenCe ;a 313 Version ~4. Coo~in~tes ~r~ ;n ~e~t r~ference slot ~313. Ve~icol Depths cte reference RKB (Doy~ 141). FAil, C0 Alaska, Inc:l IStructure : Torn Drill Site 2N Well : IField : Tarn Development Field Location : North Slope, Alask <- West (feet) 4000 5500 3000 2500 2000 1500 i 000 500 O TD LOCATION: 1170' FSL, 1005' FWL I I SEC 27 TI ON R7E I rT~q ~ ~ . t ....... ---., .__ j %/ t, asmg X-.,c3s (%,.)TARGET - Bermuda Midpoint 330.76 AZIMUTH '~EndAngle 0rap - ,( ) 6061 T0 TARGET ~~ Loc~ ~ ~ eg~n Angle Drop TA ~0=5180 TMD=8700 DEP=6561 ~C50 0 [ RKB ELEVATION: 149' ~ KOP T~=300 TMD=300 DEP=0 ~ ~.00 500 ~ ~ SURFACE Lu~ATION: ~12.00 ~ I 33' FNL, 646' FEL ~%':%0 DLS: ¢.00 deE per 100 ft ~ [ SEC. 3~gN, R7E 1000/ x %36.00 B/ PERMAFROST ~D=i199 TMD=1272 OEP=517 · ~44.00 T/ w SAK SNDS ~D=1243 TMD=1329 OEP=554 ~52.oo ~500 ~ EOC ~0=1534 TM0=1788 DEP=706 2000 J MAXIMUM ANGLE . c~o wo=2~ ~o:~ o~:~2~o ~o~ w~s~ s~ So~ds~ 2500 59.52 DEG 3000 - XEOC Top West 3500 Base Permafrost ~ C50 ~D=3755 TMD=6126 DEP=4444 C40 ~D=3960 TMD=6569 DEP=4826 I V 4000 4500 5000 55OO 6O0O BEGIN ANGLE DROP -I-VD=4-5i 1 TMD=7657 OEP=5765 58.00 54.00 OLS: 2.00 dee per END ANGLE DROP t-VD=¢955 TMD=BZ82 DEP=6336 50.00 T4 7VD=5006 TMD=8455 DEP=6587 4-6.00 T5 - T/BERMUDA TVD=5096 TM0=8582 DEP=6¢77 TARGET - BERMUDA MID TVD=5179 TMD=8700 DEP=6561 T2 - B/BERMUDA TV0=5265 TM0=8819 OEP=6644 C55 TV0=5525 TMD=8906 DEP=6706 TARGET ANGLE 45 DEG 6500 ~ , , , , , , 500 0 500 1000 TD - CSG PT TVD=6049 TMD=9930 DEP=7430 i i i i i i i i i i I i i i i i i i I 1500 2000 - 2500 3000 3500 4000 4500 5000 5500 6000 Vertical Section (feet) -> Azimuth 330.76 with reference 0.00 N, 0.00 E from slot #315 i i i i i i i i 6500 7000 7500 8000 5OO i 7000 k 650o ? 6oo0 5500 5000 4500 40aa 3500 ~ 3000 2500 2000 L1500 i i100o ~ 500 ko F 500 L lO0 ft Z O I o-,,,t,,~ ,~:,. ,~.c:-, For: M PRESTRIDGE Dote plotted: 24-Apr-g8 · P!ot Refezence ;s 31,~ Version ~4. i Coo~:/inotes ore 7n feet ~ference slot r~ue Ve~ce~ Oeoths reference RK8 (Ooy~ 141) I tAEC0 Alaska, InCi! ructure : Tarn Drill Site 2N Well: .513 Alaska Id : Tarn Development Field Location : North Slope, <- West (feet) 560 520 480 440 400 .360 320 280 240 200 160 120 80 40 680 640 6OO 56O 520 %.,.,. ~o ""t>,, '-,'% 2100 1 ~.. '"'"":.'::... ,, 44'0 d " '"'% .~ %. 1900 '"'.,,,,,, '""~., 2700 400 '.'%.,, 3~ , ',, "-,. 1700 ',,, ~20 1 ""'" """ 280 I I I I I I I I I ! I I I I I I I I I I \ \ '\ ",,,,,,,,,,,, ',~1500 '\, ',, 1500 ", · · , ', '~ 1900 · "",;,',3 9oo ', '~ 1300 "~ 1300 '",,,, 0 I I t I I t I ~ '[ 1500 ". 1700 ', ', , · ,, 4O 8O t r ~ [ 680 I ~ 640 I6OO L560 520 k 480 L4~-O t 400 , 360 ~- 32O ! '... 2500 .. , , ,, '~ 300 '" '" "' \ ' 240 Z 24-0 '- "- '" '"' ', , ',~,.15oo '%, 15oo ",, ,,. 1~,q9 ,,, ,,, \ ,.00 ,,, i "~.,~oo ""-.. '"... '".. '"... "-.. 2~o~',, .. '",, '",, , 200 ~ '"-.. '".. ".. ",. '".. "~ i ! O0 ",, ,,, ,,, Ir- 200 '-.. '-. %, 1 500 ',, ',, ', ',, ", ',, ~6o ~ - ........... ~ '-..)3oo...., ,~oo '"'- ',, 15~. ",, ',,, ',~ 1~oo ',, i ,~'~"-_ 150'0""'- ..... ~. 1100 "' '" '" ',. -, 2'1.,u0 ,, \ ': -I ..........' ......."'~ '"-.. "',..",, '", "-, ",, ',, 900 ", ", ]- ~o · ' " ' 1 '~00 ' ' t , oj ............... .... ,,.,..,--...,. '-,..,: ',.,,.',,,,, ',,,, ,-.._ '"--._ '"-.. ~ '"-~ 1'1-00 ", '"' 1x~2'' '" '"' '\ n"" 900 80 ~ ............ - ...... ,..1.~00" ...... '--. ~ '",,,"'% 1100'",,, ,%,~uu '",::',1,go0'",, '",liOu"',, k80 ~.._-'"'-,..1100~...,. aO0 '"-. '"-, "-, '"' '" '"' '" 700 '\' "' J'- ~~. '""-:Z x..~c .-..--.. .., ,,oo .,, ,., .. ,, ,, ; :iiiii .............. .1..3.? 0 ....... '~"'1-~.~!I ~ -' '9'"(~'~::".,..g 0 (~'"-,, "': 100 '"'~; ':7~0~'",,, 50 ;~'~,,, ~ ..... --.. .......... , ""--~._ '"--.. "':.:- '"... 700 '""'"~00'"' ~00 ",. ", ",,50~ '".- b .0 0 ~'-. 90-'(~"-.._ ~ "., % 7~, ",~ 900 ",15~3~ ~ f::'¢ 500 [- 0 00".400 .~oo 'esooe500 ......................... 11 O0 ......... .,~ 900' ...... .,,. 90~)"'-.,,. 7~b-.. 500 e'..~% 500 4-0 .................... go0 ........... '"'"-.. '"'..~OE~ 40 ~ ............................ _u_o__o_____(~ ................ z.o_~-e500'%00 ~ 80 80 i i i i i i i i i , ~ ~ i i ~ I i I i i i , i 810 t , i I ~ t0 560 .520 480 440 400 .360 320 280 24-0 200 160 120 4-0 O 4 80 <- West (feet) c~ot~ ~y ~;.~ For: M PRESTRIDGE Dote plotted : ~¢-Apr-98 Plot Refe~'ence ;s 31~ Vets;on ~4. Coo~Motes are ;n feet reference slot ~513, True Vel;col Oeptha ~re reference RK8 (~y~ 141). , NCO Alas In Structure: Tarn Drill Site 2N Il: 515 F e d : Tarn Development F e d Location : North Slope, AlaskcI A <- West (feet) 3200 5000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 4000 3800 3600 3400 3100 3200 3000 ,, '~ 3300 "', ',. 51 O0 '\ 3700 ,, ', 4900 ,,, 3500 \\ \ · ", ". 4700 '~ 3100 ",~ 2900 " ',, '~ 3300 '~ 4500 ' \,,\,\ 4300 ',., 2700 X , ~ 2900 . ',~ 3100 '., · ,,,,,,,,. ',, '., 410o" \ · · '. \ · , ',~ 2900 ", ",, '~ 3900" ',, 2500 "" ' " ,,, , ',,,.,., ,,,,, , '~\ 2700 ,, '\, \'., 3700 ', ,, ',~ 2700 ",, " ~ 3500 ",, '~ 2500 ", ' \ ,. 2500 ; 3300\,, \ "",, '"',, ""-~ 3300 2400 ",. '"~ ~bqO '~ 2900",, ". "',,, (_ 2200 '"'. ""~003100 ',~ 2300 .% .. '~ '.~.~,.. 0 Z 200O '" ,,..., ,,,,,,,,,,,, ,, '~. "~ 2700'-.".. '" , oo ... -'....... , ,. "-...... '... "..~..',~3oo ',. 21oo "-. ",. s~'~b. ",, ' 1~oo "-.,2700 "'-.. 1400 ~200 i000 800 ~00 400 3200 3000 2800 2600 2400 2200 2000 1800 1~00 1400 1200 1000 800 600 <- West ',~ 3500 ,,; 4100 3300 3900 ~ 3~,o0 v, ,, ~,2C0 4000 3800 3600 3400 ~ 32C0 L '%, "- ". ". '-'- ~,nn " '~ 290(~ 2300 '"'-. '".~ 25~'~ '~'-~00 "" ' 100 \' "' "-.... '.... ~. ",., .,, 2 ",, "'. l -.. -. ....~. ~ '. , ', ', -. -. .~ -A. -,00 . ., , , ~ · ~ 2700 "-.. '.. -.-'... ..... '.. ,. '.2700 I 4o0 '-. 2500 '.. '-..'.%.z~uu '~ go0 ' ', " '-... '-.. , ",, ',,, ",, I- ~ '"-. "', '".'",. 2500 ', "' " \ b i 2CO ~ 2~00 "-... '-.... ~':~,-,~00 ',,, ',, ~900',,, 2~0 ' ~ '-... -,,, 2,.,00.,.% 2700 ", ", \ ~ 2100 3700 ~ "-. ". '%~900 '. ", \ , ~-:--_ ~ 2300 '" O0 '" '" " ' \ ..... '-,.. 23 -- '~.~.-. ', ', ', \ i ~---2"--'--. 3500 -~- . .. ..-.- .....,, ,, , , 000 ........ '---.~ 3300 ~ "' "- ~2~,~,~ 'qToo', ~76~o " ..... .._- ....... "--.. 2'~ oo "--. '".2300 ':'~ t~o , ,,, v, ,. L~-..~.. ""-...~._ OQ..~IO0 ~.. '". ', ~".'- " ', \ " ..................... ..2_.7..0.0.111 ..... '":::::::'-'~--'.'2.'.9'.'O.-.-O. LL.2 '~'-~1900 '"-..21 O0 ...2.: 0~..?k.5.:i3301003,.,, ,,,,, ,,,,2 ~,,,,0,10gO0 800 -...2700 "--... "-.., ",,~.oo "',, ",, ~.~oo'", ~7oo ~oo o "'--.~ "-.~"-:~od?C'~ 400 400 ,---. 200 0 3700 ' [ 3000 ~2gO0 k 2800 , L ~' 35oo i "~ ~ 2600 /% '\ ~ I :~ i 2400 Z ~'\2700 0 --I- ~, ~ 33ooh ~ 2200 ~ ~! 2000 ~ 2500 i~ ~ 1800 ~ ~800 =~ r,~¢~ For: M PRESTRIDGE Dote J21otted : 24-Apr-g8 Plot Reference ;s 313 Version ~4. CcorC;nctes ore tn feet ~eference slot Vel;col Oepth~ are reference RKB [-A RCO kaw: - JStructure : Tarn Drill Site 2N II : .315 JField : Tarn Development Field Location : North Slope, Alaska <- West (feet) 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 t ill 11 , , 111111 II11 1¢11 ' 'l Ill ' 11 6800 \ , 6800 6049 6600 ] ~\ I 6600 6400 '"" '\ !6400 t%, "'°° 6200 . 6(300 5800 5600 54O0 5200 5000 4800 4600 4400 t, '~ 3300 ', '\ I 4200 ,,,,,,,, ,,,, ', J~ ¢200 '. 3900~ I "'% 4300 ' " \ 4000 , '. ' ~000 " h 5100 3800 '~ 3100 '~,.3700 ,,, . 3800 3600 J '" "~ 5100 ',. ",,,,,,,,,,,, ,,,, ~, 4900 3600 t '"'~ 350 '".,. ~ 3500 ,, '. ,, ~ ¢700 '- - , ',~ % 3400 I I I i I t t I I I I I I I I I I I I I I i I I I i t I 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 <- West (feet) '"~";. 5700 - '; ~ 6200 55oo'q,. '",, L ',,,, 5s~~oo '",,,, !6ooo ",~ 4-10o 5~79.5d',, ~ ",, I- "" 530~",. 'x"%5'°° ", ' ,., oo.u ,,,,, ~ i, 4~00 t- 5800 ',, ",, ',, L " 51:;" %¢900 ',, l '" \' "', ~ 5400 ",,,, '"",,, ~ ~oo ",, ;~oo "',. ~o0",, ~- ",, '\, ',,, ~ '\ [- ;2oo ",, ",. "x 4300',, ! ".,,,..oo ",,., ',, ",,, 45oo',,, ~ .... ", i- ~ooo "',,,\,,, ---',,,,,,,. ~'-" ', ,,, ,, "~ i~,o° "",,, "",,,. "%~'bo .oo,,,, %,. ",, ", '\',,%. 3700.3700 [- ,~600 ',, '%, ',,,,,% z '"'""',,,. "\\'\',,,\. -%,...,500 ! 4400 ,, \ ', ', I [AI CO Alaska, InC:] J Structure : Tarn Drill Site 2N Well: 515 Field : Tarn Develo)ment Field Location : North Slope, Alaska. WELL PROFILE DATA ..... ~c~,~t ..... ~o mc o~ tva No~h E~t V. ~ctOeg/1 O0 J~e o~ 0.~ 0.~ 33a. T6 a.aa a.aa o.aa o.~ o.~ ~aP ~.~ 0.~ 3~0.76~.~ o.co o.co 0.~ 0.~ E,d of ~ia 1787.tl 59.52 ~0.76 153+.~8~5.8,-344.72705.784.~ Eno ~f ~d 7~56.51 59.52 3~0.7845~1.49 ~8.92 -$814.98 5783.17 0.~ ~d of ~cg B382.~+ 45.~ ~0.76 495+.5B 5528.~2 -~4.5g 6335.60 2-~ Torget ~-~ (P] ~d 2 87~.4~ 45.~ 3~0,765179.50 572+.69 -~204.,5 ~560.53 0.~ T.O. & End cf ~d 9~0.a9 +5.~ 3~0.76~9.~ 848~.~1 -~6~.157+30.0~ 0.~ 330 340 35O TRUE NORTH 0 10 2O 310 520 1{50 300 For: M 'PRESTRIDGE] True Vertical Depths o~e reference RK8 (goyon 1~1).~ 5O 4O 5O 8300 60 290 7O 280 q~, / 270 !2 260 25O )'.i 50 I 3O 500 100 -% 900 8O 9O O0 i!0 240 11oo 2i,~~j°° ./';? / /' I; t //3oo¢' ~2-a20 ,," : / ! 200 190 Normal Plane Travelling Cylinder- Feet 160 -, ...,;oo 1"3e.~,o° · i'-.,40 '~ ~ .500 150 ~ 180 170 All dep(hs shown ore Measured depths on Reference ARCO Alaska, Inc. Tarn Drill Site 2N 313 slot #313 Tarn Development Field North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 313 Version #4 Our ref : prop2838 License : Date printed : 22-Apr-98 Date created : 2A-Feb-98 Last revised : 22-Apr-98 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is nT0 10 13.631,w150 18 51.492 Slot Grid coordinates are N 5911973.691, E 460947.040 Slot local coordinates are 32.92 S 646.18 W Projection t!rpe: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Tarn Drill Site 2N, 313 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 313 Version #4 Last revised : 21-Apr-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S Dogleg Vert Deg/100ft Sect 0.00 0.00 330.76 0.00 0.00 N 0.00 E 0.00 300.00 0.00 330.76 300.00 0.00 N 0.00 E 0.00 400.00 4.00 330.76 399.92 3.04 N 1.70 W 4.00 500.00 8.00 330.76 499.35 12.16 N 6.81 W 4.00 600.00 12.00 330.76 597.81 27.31 N 15.29 W 4.00 0.00 0.00 KOP 3.49 13.94 31.30 700.00 16.00 330.76 694.82 48.42 N 27.10 W 4.00 800.00 20.00 330.76 789.91 75.38 N 42.19 W 4.00 900.00 24.00 330.76 882.61 108.06 N 60.49 W 4.00 1000.00 28.00 330.76 972.47 146.30 N 81.89 W 4.00 1100.00 32.00 330.76 1059.05 189.92 N 106.31 W 4.00 55.49 86.38 123.84 167.67 217.66 1200.00 36.00 330.76 1141.94 238.71 N 133.62 W 4.00 1271.87 38.87 330.76 1199.00 276.83 N 154.96 W 4.00 1300.00 40.00 330.76 1220.73 292.42 N 163.69 W 4.00 1329.33 41.17 330.76 1243.00 309.07 N 173.01 W 4.00 1400.00 44.00 330.76 1295.02 350.80 N 196.36 W 4.00 273.56 317.25 Base Permafrost 335.12 354.20 Top West Sak Sands 402.02 1500.00 48.00 330.76 1364.48 413.55 N 231.49 W 4.00 1600.00 52.00 330.76 1428.74 480.39 N 268.90 W 4.00 1700.00 56.00 330.76 1487.51 550.97 N 308.41 W 4.00 1787.91 59.52 330.76 1534.40 615.84 N 344.72 W 4.00 2000.00 59.52 330.76 1641.99 775.32 N 434.00 W 0.00 473.94 550.52 631.41 705.76 EOC 888.53 2500.00 59.52 330.76 1895.64 1151.31 N 644.46 W 0.00 2603.22 59.52 330.76 1948.00 1228.94 N 687.91 W 0.00 3000.00 59.52 330.76 2149.28 1527.31 N 854.92 W 0.00 3297.10 59.52 330.76 2300.00 1750.72 N 979.98 W 0.00 3500.00 59.52 330.76 2402.93 1903.30 N 1065.39 W 0.00 1319.41 1408.37 Base West Sak Sands 1750.30 2006.34 9 5/8" Casing Pt 2181.19 3614.48 59.52 330.76 2461.00 1989.38 N 1113.57 W 0.00 4000.00 59.52 330.76 2656.57 2279.29 N 1275.85 W 0.00 4500.00 59.52 330.76 2910.22 2655.28 N 1486.32 W 0.00 5000.00 59.52 330.76 3163.86 3031.27 N 1696.78 W 0.00 5500.00 59.52 330.76 3417.51 3407.26 N 1907.25 W 0.00 2279.84 C80 2612.08 3042.97 3473.85 3904.74 6000.00 59.52 330.76 3671.15 3783.25 N 2117.71 W 0.00 6125.86 59.52 330.76 3735.00 3877.89 N 2170.69 W 0.00 6500.00 59.52 330.76 3924.80 4159.24 N 2328.17 W 0.00 6569.39 59.52 330.76 3960.00 4211.42 N 2357.38 W 0.00 7000.00 59.52 330.76 4178.44 4535.23 N 2538.64 W 0.00 4335.63 4444.09 C50 4766.52 4826.32 C40 5197.40 7500.00 59.52 330.76 4432.09 4911.22 N 2749.10 W 0.00 7656.51 59.52 330.76 4511.49 5028.92 N 2814.98 W 0.00 7732.34 58.00 330.76 4550.81 5085.49 N 2846.65 W 2.00 7832.34 56.00 330.76 4605.27 5158.66 N 2887.61 W 2.00 7932.34 54.00 330.76 4662.63 5230.14 N 2927.62 W 2.00 5628.29 5763.17 Begin Angle Drop 5828.00 5911.86 5993.77 8032.34 52.00 330.76 4722.81 5299.82 N 2966.63 W 2.00 8132.34 50.00 330.76 4785.73 5367.63 N 3004.58 W 2.00 8232.34 48.00 330.76 4851.34 5433.49 N 3041.45 W 2.00 8332.34 46.00 330.76 4919.53 5497.30 N 3077.17 W 2.00 8382.34 45.00 330.76 4954.58 5528.42 N 3094.59 W 2.00 6073.63 6151.34 6226.81 6299.94 6335.60 End Angle Drop 8455.06 45.00 330.76 5006.00 5573.29 N 3119.70 W 0.00 8500.00 45.00 330.76 5037.78 5601.02 N 3135.22 W 0.00 8582.34 45.00 330.76 5096.00 5651.82 N 3163.66 W 0.00 8700.41 45.00 330.76 5179.49 5724.68 N 3204.44 W 0.00 8700.43 45.00 330.76 5179.50 5724.69 N 3204.45 W 0.00 6387.03 T4 6418.80 6477.03 T3 - T/ Bermuda 6560.52 TARGET - Bermuda Midpoint 6560.53 2N-M (P) Rvsd 21-Apr-98 All data is in feet unless otherwise stated. Coordinates from slot #313 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7430.03 on azimuth 330.76 degrees from wellhead. Total Dogleg for wellpath is 74.03 degrees. Vertical section is from wellhead on azimuth 330.76 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 313 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 313 Version #4 Last revised : 21-Apr-98 Dogleg Vert Deg/100ft Sect 8818.51 45.00 330.76 5263.00 5797.55 N 3245.23 W 0.00 6644.03 T2 - Base Bermuda 8906.20 45.00 330.76 5325.00 5851.65 N 3275.52 W 0.00 6706.03 C35 9000.00 45.00 330.76 5391.33 5909.53 N 3307.91 W 0.00 6772.36 9500.00 45.00 330.76 5744.88 6218.04 N 3480.60 W 0.00 7125.91 9930.09 45.00 330.76 6049.00 6483.41 N 3629.15 W 0.00 7430.03 TD All data is in feet unless otherwise stated. Coordinates from slot #313 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7430.03 on azimuth 330.76 degrees from wellhead. Total Dogleg for wellpath is 74.03 degrees. Vertical section is from wellhead on azimuth 330.76 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,313 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 313 Version #4 Last revised : 21-Apr-98 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300.00 1271.87 1199.00 1329.33 1243.00 1787.91 1534.40 2603.22 1948.00 3297.10 2300.00 3614.48 2461.00 6125.86 3735.00 6569.39 3960.00 7656.51 4511.49 8382.34 4954.58 8455.06 5006.00 8582.34 5096.00 8700.41 5179.49 8700.43 5179.50 8818.51 5263.00 8906.20 5325.00 9930.09 6049.00 0.00 276.83 309.07 615.84 1228.94 1750.72 1989 38 3877 89 4211 42 5028 92 5528 42 5573 29 5651.82 5724.68 5724.69 5797.55 5851.65 6483.41 N 0.00 E KOP N 154.96 W Base Permafrost N 173.01 W Top West Sak Sands N 344.72 W EOC N 687.91 W Base West Sak Sands N 979.98 W 9 5/8" Casing Pt N 1113.57 W C80 N 2170.69 W C50 N 2357.38 W C40 N 2814.98 W Begin Angle Drop N 3094.59 W End Angle Drop N 3119.70 W T4 N 3163.66 W T3 - T/ Bermuda N 3204.44 W TARGET - Bermuda Midpoint N 3204.45 W 2N-M (P) Rvsd 21-Apr-98 N 3245.23 W T2 - Base Bermuda N 3275.52 W C35 N 3629.15 W TD Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3297.10 2300.00 1750.72N 979.98W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 9930.09 6049.00 6483.41N 3629.15W 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-M (P) Rvsd 21-Apr 457772.000,5917714.000,0.0000 5179.50 5724.69N 3204.45W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N, 313 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LISTING Page 1 Your ref : 313 Version #4 Last revised : 22-Apr-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 330.76 0.00 32.92 S 646.18 W 0.00 300.00 0.00 330.76 300.00 32.92 S 646.18 W 0.00 400.00 4.00 330.76 399.92 29.87 S 647.88 W 4.00 500.00 8.00 330.76 499.35 20.75 S 652.99 W 4.00 600.00 12.00 330.76 597.81 5.60 S 661.47 W 4.00 0.00 0.00 KOP 3.49 13.94 31.30 700.00 16.00 330.76 694.82 15.50 N 673.28 W 4.00 800.00 20.00 330.76 789.91 42.46 N 688.37 W 4.00 900.00 24.00 330.76 882.61 75.14 N 706.67 W 4.00 1000.00 28.00 330.76 972.47 113.39 N 728.07 W 4.00 1100.00 32.00 330.76 1059.05 157.01 N 752.49 W 4.00 55.49 86.38 123.84 167.67 217.66 1200.00 36.00 330.76 1141.94 205.79 N 779.80 W 4.00 1271.87 38.87 330.76 1199.00 243.91 N 801.14 W 4.00 1300.00 40.00 330.76 1220.73 259.51 N 809.87 W 4.00 1329.33 41.17 330.76 1243.00 276.16 N 819.19 W 4.00 1400.00 44.00 330.76 1295.02 317.88 N 842.54 W 4.00 273.56 317.25 Base Permafrost 335.12 354.20 Top West Sak Sands 402.02 1500.00 48.00 330.76 1364.48 380.64 N 877.67 W 4.00 1600.00 52.00 330.76 1428.74 447.47 N 915.08 W 4.00 1700.00 56.00 330.76 1487.51 518.05 N 954.59 W 4.00 1787.91 59.52 330.76 1534.40 582.92 N 990.90 W 4.00 2000.00 59.52 330.76 1641.99 742.41 N 1080.18 W 0.00 473.94 '550.52 631.41 705.76 BOC 888.53 2500.00 59.52 330.76 1895.64 1118.40 N 1290.64 W 0.00 2603.22 59.52 330.76 1948.00 1196.02 N 1334.09 W 0.00 3000.00 59.52 330.76 2149.28 1494.39 N 1501.10 W 0.00 3297.10 59.52 330.76 2300.00 1717.81 N 1626.16 W 0.00 3500.00 59.52 330.76 2402.93 1870.38 N 1711.57 W 0.00 1319.41 1408.37 Base West Sak Sands 1750.30 2006.34 9 5/8" Casing Pt 2181.19 3614.48 59.52 330.76 2461.00 1956.46 N 1759.75 W 0.00 4000.00 59.52 330.76 2656.57 2246.37 N 1922.03 W 0.00 4500.00 59.52 330.76 2910.22 2622.36 N 2132.50 W 0.00 5000.00 59.52 330.76 3163.86 2998.35 N 2342.96 W 0.00 5500.00 59.52 330.76 3417.51 3374.34 N 2553.43 W 0.00 2279.84 C80 2612.08 3042.97 3473.85 3904.74 6000.00 59.52 330.76 3671.15 3750.33 N 2763.89 W 0.00 6125.86 59.52 330.76 3735.00 3844.98 N 2816.87 W 0.00 6500.00 59.52 330.76 3924.80 4126.32 N 2974.35 W 0.00 6569.39 59.52 330.76 3960.00 4178.51 N 3003.56 W 0.00 7000.00 59.52 330.76 4178.44 4502.31 N 3184.82 W 0.00 4335.63 4444.09 C50 4766.52 4826.32 C40 5197.40 7500.00 59.52 330.76 4432.09 4878.31 N 3395.28 W 0.00 7656.51 59.52 330.76 4511.49 4996.00 N 3461.16 W 0.00 7732.34 58.00 330.76 4550.81 5052.57 N 3492.83 W 2.00 7832.34 56.00 330.76 4605.27 5125.75 N 3533.79 W 2.00 7932.34 54.00 330.76 4662.63 5197.22 N 3573.80 W 2.00 5628.29 5763.17 Begin Angle Drop 5828.00 5911.86 5993.77 8032.34 52.00 330.76 4722.81 5266.91 N 3612.81 W 2.00 8132.34 50.00 330.76 4785.73 5334.72 N 3650.76 W 2.00 8232.34 48.00 330.76 4851.34 5400.57 N 3687.63 W 2.00 8332.34 46.00 330.76 4919.53 5464.39 N 3723.35 W 2.00 8382.34 45.00 330.76 4954.58 5495.50 N 3740.77 W 2.00 8455.06 45.00 330.76 5006.00 5540.37 N 3765.88 W 0.00 8500.00 45.00 330.76 5037.78 5568.10 N 3781.40 W 0.00 8582.34 45.00 330.76 5096.00 5618.91 N 3809.84 W 0.00 8700.41 45.00 330.76 5179.49 5691.76 N 3850.62 W 0.00 8700.43 45.00 330.76 5179.50 5691.77 N 3850.63 W 0.00 6073.63 6151.34 6226.81 6299.94 6335.60 End Angle Drop 6387.03 T4 6418.80 6477.03 T3 - T/ Bermuda 6560.52 TARGET - Bermuda Midpoint 6560.53 2N-M (P) Rvsd 21-Apr-98 All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, RTE and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7430.03 on azimuth 330.76 degrees from wellhead. Total Dogleg for wellpath is 74.03 degrees. Vertical section is from wellhead on azimuth 330.76 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,313 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 313 Version #4 Last revised : 22-Apr-98 Dogleg Vert Deg/100ft Sect 8818.51 45.00 330.76 5263.00 5764.63 N 3891.41 W 0.00 6644.03 T2 - Base Bermuda 8906.20 45.00 330.76 5325.00 5818.73 N 3921.70 W 0.00 6706.03 C35 9000.00 45.00 330.76 5391.33 5876.61 N 3954.09 W 0.00 6772.36 9500.00 45.00 330.76 5744.88 6185.12 N 4126.78 W 0.00 7125.91 9930.09 45.00 330.76 6049.00 6450.49 N 4275.33 W 0.00 7430.03 TD All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, R7E and TVD from RK~ (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7430.03 on azimuth 330.76 degrees from wellhead. Total Dogleg for wellpath is 74.03 degrees. Vertical section is from wellhead on azimuth 330.76 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,313 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 313 Version #4 Last revised : 22-Apr-98 Comments in wellpath MD TVD Rectangular Coords. Comment 300 1271 1329 1787 2603 3297 10 3614 48 6125 86 6569 39 7656 51 8382.34 8455.06 8582.34 8700.41 8700.43 8818.51 8906.20 9930.09 O0 87 33 91 22 300 00 1199 00 1243 00 1534 40 1948 00 2300 00 2461 00 3735 00 3960.00 4511.49 4954.58 5006.00 5096.00 5179.49 5179.50 5263.00 5325.00 6049.00 32 92 S 243 91 N 276 16 N 582 92 N 1196 02 N 1717 81 N 1956.46 N 3844.98 N 4178.51 N 4996.00 N 5495.50 N 5540.37 N 5618.91 N 5691.76 N 5691.77 N 5764.63 N 5818.73 N 6450.49 N 646.18 W 801.14 W 819.19 W 990.90 W 1334.09 W 1626.16 W 1759.75 W 2816.87 W 3003.56 W 3461.16 W 3740.77 W 3765.88 W 3809 84 W 3850 62 W 3850 63 W 3891 41 W 3921 70 W 4275 33 W KOP Base Permafrost Top West Sak Sands EOC Base West Sak Sands 9 5/8" Casing Pt C80 C50 C40 Begin Angle Drop End Angle Drop T4 T3 - T/ Bermuda TARGET - Bermuda Midpoint 2N-M (P) Rvsd 21-Apr-98 T2 - Base Bermuda C35 TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 32.92S 646.18W 3297.10 2300.00 1717.81N 1626.16W 9 5/8" Casing 0.00 0.00 32.92S 646.18W 9930.09 6049.00 6450.49N 4275.33W 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-M (P) Rvsd 21-Apr 457772.000,5917714.000,0.0000 5179.50 5691.77N 3850.63W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N,313 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 313 Version #4 Last revised : 22-Apr-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 330.76 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 300.00 0.00 330.76 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A 400.00 4.00 330.76 399.92 3.04 N 1.70 W 3.49 1.07 1.05 0.60 330.76 500.00 8.00 330.76 499.35 12.16 N 6.81 W 13.94 1.50 1.32 0.75 330.76 600.00 12.00 330.76 597.81 27.31 N 15.29 W 31.30 2.16 1.62 0.91 330.76 700.00 16.00 330.76 694.82 48.42 N 27.10 W 55.49 3.09 1.96 1.07 330.76 800.00 20.00 330.76 789.91 75.38 N 42.19 W 86.38 4.32 2.33 1.26 330.76 900.00 24.00 330.76 882.61 108,06 N 60.49 W 123.84 5.84 2.74 1.46 330.76 1000.00 28.00 330.76 972.47 146.30 N 81.89 W 167.67 7.67 3.19 1.71 330.76 1100.00 32.00 330.76 1059.05 189.92 N 106.31 W 217.66 9.82 3.68 2.01 330.76 1200.00 36.00 330.76 1141.94 238.71 N 133.62 W 273.56 12.29 4.19 2.36 330.76 1271.87 38.87 330.76 1199.00 276.83 N 154.96 W 317.25 14.29 4.57 2.67 330.76 1300.00 40.00 330.76 1220.73 292.42 N 163.69 W 335.12 15.08 4.72 2.79 330.76 1329.33 41.17 330.76 1243.00 309.07 N 173.01 W 354.20 15.99 4.88 2.93 330.76 1400.00 44.00 330.76 1295.02 350.80 N 196.36 W 402.02 18.19 5.26 3.28 330.76 1500.00 48.00 330.76 1364.48 413.55 N 231.49 W 473.94 21.63 5.81 3.85 330.76 1600.00 52.00 330.76 1428.74 480.39 N 268.90 W 550.52 '25.37 6.34 4.50 330.76 1700.00 56.00 330.76 1487.51 550.97 N 308.41 W 631.41 29.42 6.86 5.22 330.76 1787.91 59.52 330.76 1534.40 615.84 N 344.72 W 705.76 33.20 7.29 5.91 330.76 2000.00 59.52 330.76 1641.99 775.32 N 434.00 W 888.53 42.36 8.34 7.59 330.76 2500.00 59.52 330.76 1895.64 1151.31 N 644.46 W 1319.41 64.09 10.81 11.62 330.76 2603.22 59.52 330.76 1948.00 1228.94 N 687.91 W 1408.37 68.59 11.32 12.45 330.76 3000.00 59.52 330.76 2149.28 1527.31 N 854.92 W 1750.30 85.90 13.28 15.66 330.76 3297.10 59.52 330.76 2300.00 1750.72 N 979.98 W 2006.34 98.87 14.74 18.07 330.76 3500.00 59.52 330.76 2402.93 1903.30 N 1065.39 W 2181.19 107.73 15.74 19.71 330.76 3614.48 59.52 330.76 2461.00 1989.38 N 1113.57 W 2279.84 112.73 16.31 20.64 330.76 4000.00 59.52 330.76 2656.57 2279.29 N 1275.85 W 2612.08 129.57 18.21 23.77 330.76 4500.00 59.52 330.76 2910.22 2655.28 N 1486.32 W 3042.97 151.42 20.68 27.83 330.76 5000.00 59.52 330.76 3163.86 3031.27 N 1696.78 W 3473.85 173.28 23.15 31.89 330.76 5500.00 59.52 330.76 3417.51 3407.26 N 1907.25 W 3904.74 195.14 25.62 35.95 330.76 6000.00 59.52 330.76 3671.15 3783.25 N 2117.71 W 4335.63 217.00 28.09 40.01 330.76 6125.86 59.52 330.76 3735.00 3877.89 N 2170.69 W 4444.09 222.50 28.71 41.04 330.76 6500.00 59.52 330.76 3924.80 4159.24 N 2328.17 W 4766.52 238.86 30.55 44.08 330.76 6569.39 59.52 330.76 3960.00 4211.42 N 2357.38 W 4826.32 241.90 30.90 44.64 330.76 7000.00 59.52 330.76 4178.44 4535.23 N 2538.64 W 5197.40 260.73 33.02 48.14 330.76 7500.00 59.52 330.76 4432.09 4911.22 N 2749.10 W 5628.29 282.60 35.49 52.20 330.76 7656.51 59.52 330.76 4511.49 5028.92 N 2814.98 W 5763.17 289.44 36.26 53.47 330.76 7732.34 58.00 330.76 4550.81 5085.49 N 2846.65 W 5828.00 292.68 36.65 54.07 330.76 7832.34 56.00 330.76 4605.27 5158.66 N 2887.61 W 5911.86 296.80 37.17 54.83 330.76 7932.34 54.00 330.76 4662.63 5230.14 N 2927.62 W 5993.77 300.78 37.70 55.55 330.76 8032.34 52.00 330.76 4722.81 5299.82 N 2966.63 W 6073.63 304.60 38.24 56.24 330.76 8132.34 50.00 330.76 4785.73 5367.63 N 3004.58 W 6151.34 308.27 38.80 56.90 330.76 8232.34 48.00 330.76 4851.34 5433.49 N 3041.45 W 6226.81 311.78 39.35 57.51 330.76 8332.34 46.00 330.76 4919.53 5497.30 N 3077.17 W 6299.94 315.12 39.91 58.10 330.76 8382.34 45.00 330.76 4954.58 5528.42 N 3094.59 W 6335.60 316.75 40.20 58.38 330.76 8455.06 45.00 330.76 5006.00 5573.29 N 3119.70 W 6387.03 319.12 40.61 58.79 330.76 8500.00 45.00 330.76 5037.78 5601.02 N 3135.22 W 6418.80 320.59 40.86 59.05 330.76 8582.34 45.00 330.76 5096.00 5651.82 N 3163.66 W 6477.03 323.27 41.33 59.51 330.76 8700.41 45.00 330.76 5179.49 5724.68 N 3204.44 W 6560.52 327.13 41.99 60.18 330.76 8700.43 45.00 330.76 5179.50 5724.69 N 3204.45 W 6560.53 327.13 41.99 60.18 330.76 All data is in feet unless otherwise stated. Coordinates from slot #313 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7430.03 on azimuth 330.76 degrees from wellhead. Vertical section is from wellhead on azimuth 330.76 degrees. Calculation uses the minimum cuz-vature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,313 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 313 Version #4 Last revised : 22-Apr-98 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 8818.51 45.00 330.76 5263.00 5797.55 N 3245.23 W 6644.03 8906.20 45.00 330.76 5325.00 5851.65 N 3275.52 W 6706.03 9000.00 45.00 330.76 5391.33 5909.53 N 3307.91 W 6772.36 9500.00 45.00 330.76 5744.88 6218.04 N 3480.60 W 7125.91 9930.09 45.00 330.76 6049.00 6483.41 N 3629.15 W 7430.03 330.98 42.66 60.85 330.76 333.84 43.15 61.34 330.76 336.90 43.68 61.87 330.76 353.21 46.51 64.70 330.76 367.25 48.93 67.13 330.76 POSITION UNCERTAINTY S%rM2~tR¥ Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 9930 ARCO (H.A. Mag) User specified 367.25 48.93 67.13 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. All data is in feet unless otherwise stated. Coordinates from slot #313 and TVD from RKB (Do¥on 141) (149.00 Ft above mean sea level). Bottom hole distance is 7430.03 on azimuth 330.76 degrees from wellhead. Vertical section is from wellhead on azimuth 330.76 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,313 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 313 Version #4 Last revised : 22-Apr-98 Comments in wellpath MD TVD Rectangular Coords. Comment O0 87 33 91 22 300 1271 1329 1787 2603 3297 10 3614 48 6125 86 6569 39 7656 51 8382 34 8455.06 8582.34 8700.41 8700.43 8818.51 8906.20 9930.09 300 1199 1243 1534 1948 2300 2461 3735 3960 4511 4954 5006 5096 5179 5179 5263 5325 6049 .00 0.00 N .00 276.83 N .00 309.07 N .40 615.84 N .00 1228.94 N .00 1750.72 N .00 1989.38 N 00 3877.89 N 00 4211.42 N 49 5028.92 N 58 5528.42 N 00 5573.29 N 00 5651.82 N 49 5724.68 N 50 5724.69 N 00 5797.55 N 00 5851.65 N 00 6483.41 N 0 00 E 154 96 W 173 01 W 344 72 W 687 91 W 979 98 W 1113 57 W 2170 69 W 2357 38 W 2814 98 W 3094 59 W 3119 70 W 3163 66 W 3204.44 W 3204.45 W 3245.23 W 3275.52 W 3629.15 W KOP Base Permafrost Top West Sak Sands EOC Base West Sak Sands 9 5/8" Casing Pt C80 C50 C40 Begin Angle Drop End Angle Drop T4 T3 - T/ Bermuda TARGET - Bermuda Midpoint 2N-M (P) Rvsd 21-Apr-98 T2 - Base Bermuda C35 TD Casing positions in string 'A' ........ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3297.10 2300.00 1750.72N 979.98W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 9930.09 6049.00 6483.41N 3629.15W 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-M (P) Rvsd 21-Apr 457772.000,5917714.000,0.0000 5179.50 5724.69N 3204.45W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N, 313 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 313 Version #4 Last revised : 22-Apr-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G E O G R A P H I C Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect C O O R D I N A T E S 0.00 0.00 330.76 0.00 0.00N 0.00E 0.00 0.00 300.00 0.00 330.76 300.00 0.00N 0.00E 0.00 0.00 400.00 4.00 330.76 399.92 3.04N 1.70W 4.00 3.49 500.00 8.00 330.76 499.35 12.16N 6.81W 4.00 13.94 600.00 12.00 330.76 597.81 27.31N 15.29W 4.00 31.30 nT0 10 13.63 wlS0 18 51.49 n70 10 13.63 w150 18 51.49 nT0 10 13.66 w150 18 51.54 nT0 10 13.75 wlS0 18 51.69 n70 10 13.90 wlS0 18 51.93 700.00 16.00 330.76 694.82 48.42N 27.10W 4.00 55.49 n70 10 14.11 w150 18 52.28 800.00 20.00 330.76 789.91 75.38N 42.19W 4.00 86.38 n70 10 14.37 w!50 18 52.71 900.00 24.00 330.76 882.61 108.06N 60.49W 4.00 123.84 n70 10 14.69 w150 18 53.24 1000.00 28.00 330.76 972.47 146.30N 81.89W 4.00 167.67 nT0 10 15.07 w150 18 53.86 1100.00 32.00 330.76 1059.05 189.92N 106.31W 4.00 217.66 nT0 10 15.50 w150 18 54.57 1200.00 36.00 330.76 1141.94 238.71N 133.62W 4.00 273.56 n70 10 15.98 w150 18 55.36 1271.87 38.87 330.76 1199.00 276.83N 154.96W 4.00 317.25 n70 10 16.35 w150 18 55.98 1300.00 40.00 330.76 1220.73 292.42N 163.69W 4.00 335.12 n70 10 16.51 w150 18 56.23 1329.33 41.17 330.76 1243.00 309.07N 173.01W 4.00 354.20 n70 10 16.67 wlS0 18 56.51 1400.00 44.00 330.76 1295.02 350.80N 196.36W 4.00 402.02 n70 10 17.08 wlS0 18 57.18 1500.00 48.00 330.76 1364.48 413.55N 231.49W 4.00 473.94 nT0 10 17.70 w150 18 58.20 1600.00 52.00 330.76 1428.74 480.39N 268.90W 4.00 55'0.52 n70 10 18.36 wlS0 18 59.28 1700.00 56.00 330.76 1487.51 550.97N 308.41W 4.00 631.41 n70 10 19.05 w150 19 00.43 1787.91 59.52 330.76 1534.40 615.84N 344.72W 4.00 705.76 n70 10 19.69 w150 19 01.48 2000.00 59.52 330.76 1641.99 775.32N 434.00W 0.00 888.53 n70 10 21.26 w150 19 04.07 2500.00 59.52 330.76 1895.64 1151.31N 644.46W 0.00 1319.41 n70 10 24.95 w150 19 10.17 2603.22 59.52 330.76 1948.00 1228.94N 687.91W 0.00 1408.37 n70 10 25.72 w150 19 11.43 3000.00 59.52 330.76 2149.28 1527.31N 854.92W 0.00 1750.30 n70 10 28.65 wlS0 19 16.27 3297.10 59.52 330.76 2300.00 1750.72N 979.98W 0.00 2006.34 nT0 10 30.85 w150 19 19.89 3500.00 59.52 330.76 2402.93 1903.30N 1065.39W 0.00 2181.19 n70 10 32.35 w150 19 22.37 3614.48 59.52 330.76 2461.00 1989.38N 1113.57W 0.00 2279.84 nT0 10 33.19 w150 19 23.77 4000.00 59.52 330.76 2656.57 2279.29N 1275.85W 0.00 2612.08 n70 10 36.05 w150 19 28.47 4500.00 59.52 330.76 2910.22 2655.28N 1486.32W 0.00 3042.97 n70 10 39.74 w150 19 34.57 5000.00 59.52 330.76 3163.86 3031.27N 1696.78W 0.00 3473.85 nT0 10 43.44 wlS0 19 40.68 5500.00 59.52 330.76 3417.51 3407.26N 1907.25W 0.00 3904.74 nT0 10 47.14 wlS0 19 46.78 6000.00 59.52 330.76 3671.15 3783.25N 2117.71W 0.00 4335.63 n70 10 50.83 w150 19 52.88 6125.86 59.52 330.76 3735.00 3877.89N 2170.69W 0.00 4444.09 n70 10 51.77 w150 19 54.42 6500.00 59.52 330.76 3924.80 4159.24N 2328.17W 0.00 4766.52 n70 10 54.53 w150 19 58.99 6569.39 59.52 330.76 3960.00 4211.42N 2357.38W 0.00 4826.32 n70 10 55.05 w150 19 59.83 7000.00 59.52 330.76 4178.44 4535.23N 2538.64W 0.00 5197.40 n70 10 58.23 w150 20 05.09 7500.00 59.52 330.76 4432.09 4911.22N 2749.10W 0.00 5628.29 nT0 11 01.93 w150 20 11.20 7656.51 59.52 330.76 4511.49 5028.92N 2814.98W 0.00 5763.17 n70 11 03.08 wi50 20 13.11 7732.34 58.00 330.76 4550.81 5085.49N 2846.65W 2.00 5828.00 n70 11 03.64 wlS0 20 14.03 7832.34 56.00 330.76 4605.27 5158.66N 2887.61W 2.00 5911.86 n70 11 04.36 w150 20 15.22 7932.34 54.00 330.76 4662.63 5230.14N 2927.62W 2.00 5993.77 n70 11 05.06 w150 20 16.38 8032.34 52.00 330.76 4722.81 5299.82N 2966.63W 2.00 6073.63 nT0 11 05.75 w150 20 17.51 8132.34 50.00 330.76 4785.73 5367.63N 3004.58W 2.00 6151.34 nT0 11 06.41 w150 20 18.61 8232.34 48.00 330.76 4851.34 5433.49N 3041.45W 2.00 6226.81 nT0 11 07.06 w150 20 19.68 8332.34 46.00 330.76 4919.53 5497.30N 3077.17W 2.00 6299.94 n70 11 07.69 w150 20 20.72 8382.34 45.00 330.76 4954.58 5528.42N 3094.59W 2.00 6335.60 n70 11 07.99 w150 20 21.22 8455.06 45.00 330.76 5006.00 5573.29N 3119.70W 0.00 6387.03 nT0 11 08.44 w150 20 21.95 8500.00 45.00 330.76 5037.78 5601.02N 3135.22W 0.00 6418.80 n70 11 08.71 w150 20 22.40 8582.34 45.00 330.76 5096.00 5651.82N 3163.66W 0.00 6477.03 nT0 11 09.21 w150 20 23.23 8700.41 45.00 330.76 5179.49 5724.68N 3204.44W 0.00 6560.52 nT0 11 09.92 w150 20 24.41 8700.43 45.00 330.76 5179.50 5724.69N 3204.45W 0.00 6560.53 n70 11 09.92 w150 20 24.41 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #313 and TVD from RKB (Do¥on 141) (149.00 Ft above mean sea level). Bottom hole distance is 7430.03 on azimuth 330.76 degrees from wellhead. Total Dogleg for wellpath is 74.03 degrees. Vertical section is from wellhead on azimuth 330.76 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 313 Tarn Development Field,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 313 Version #4 Last revised : 22-Apr-98 Dogleg Vert G E O G R A P H I C Deg/100ft Sect C O O R D I N A T E S 8818.51 45.00 330.76 5263.00 5797.55N 3245.23W 0.00 6644.03 8906.20 45.00 330.76 5325.00 5851.65N 3275.52W 0.00 6706.03 9000.00 45.00 330.76 5391.33 5909.53N 3307.91W 0.00 6772.36 9500.00 45.00 330.76 5744.88 6218.04N 3480.60W 0.00 7125.91 9930.09 45.00 330.76 6049.00 6483.41N 3629.15W 0.00 7430.03 n70 11 10.64 w150 20 25.59 n70 11 11.17 w150 20 26.47 nT0 11 11.74 w150 20 27.41 nT0 11 14.78 w150 20 32.42 nT0 11 17.38 w150 20 36.74 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #313 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7430.03 on azimuth 330.76 degrees from wellhead. Total Dogleg for wellpath is 74.03 degrees. Vertical section is from wellhead on azimuth 330.76 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,313 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 313 Version #4 Last revised : 22-Apr-98 Comments in wellpath MD TVD Rectangular Coords. Comment 300 00 300.00 0.00N 0.00E KOP 1271 87 1329 33 1787 91 2603 22 3297 10 3614 48 6125 86 6569 39 7656 51 8382.34 8455.06 8582.34 8700.41 8700.43 8818.51 8906.20 9930.09 1199.00 276.83N 154 1243.00 309.07N 173 1534.40 615.84N 344 1948.00 1228.94N 687 2300.00 1750.72N 979 2461.00 1989.38N 1113 3735.00 3877.89N 2170 3960.00 4211.42N 2357 4511.49 5028.92N 2814 4954.58 5528.42N 3094 5006.00 5573.29N 3119 5096.00 5651.82N 3163 5179.49 5724.68N 3204 5179.50 5724.69N 3204 5263.00 5797.55N 3245 5325.00 5851.65N 3275 6049.00 6483.41N 3629 .96W Base Permafrost .01W Top West Sak Sands .72W EOC .91W Base West Sak Sands .98W 9 5/8" Casing Pt .57W C80 .69W C50 .38W C40 .98W Begin Angle Drop 59W End Angle Drop 70W T4 66W T3 - T/ Bermuda 44W TARGET - Bermuda Midpoint 45W 2N-M (P) Rvsd 21-Apr-98 23W T2 - Base Bermuda 52W C35 15W TD Casing positions in string 'A' ...... Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3297.10 2300.00 1750.72N 979.98W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 9930.09 6049.00 6483.41N 3629.15W 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-M (P) Rvsd 21-Apr 457772.000,5917714.000,0.0000 5179.50 5724.69N 3204.45W 6-Aug-97 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3 t 92 Re: THE APPLICATION OF ARCO ) ALASKA, INC. for an order granting ) an exception to spacing requirements of ) 20 AAC 25.055(a)(3) to provide for the ) drilling of the KRU 2N-313 development ) oil well. ) Conservation Order No. 422 ARCO Alaska. Inc. KRU 2N-313 May 5, 1998 IT APPEARING THAT: ARCO Alaska, Inc. submitted an application dated April 14, 1998 requesting exception to the xvell spacing provisions of 20 AAC 25.055(a)(3) to allow drilling the ARCO KRU 2N- 313 development oil well to a producing location that is closer than 500 feet from a quarter- section line. 2. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on April 19, 1998 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: . o The KRU 2N-313 development oil well will be drilled as a deviated hole with a surface location 33' from the north line and 646' from the east line of Section 3, TgN. R7E. Umiat Meridian (UM) to a producing location 412' from the south line and 1,429' from the west line of Section 27, T10N, RTE, UM. Offset owners BP Exploration (Alaska), Inc., Chevron USA Inc., UNOCAL Alaska Resources, Mobil Oil Corporation and the State of Alaska have been duly notified. An exception to the well spacing provisions of 20 AAC 25.055 (a)(3) is necessar~r to allow the drilling of this well. CONCLUSION: Granting a spacing exception to allow drilling of the ARCO KRU 2N-313 development oil well xvill not result in waste nor jeopardize correlative rights. Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The Kuparuk River Unit 2N-313 development oil welt. ARCO Alaska, Inc. by letter dated April 14. 1998 has requested an exception to the provisions of 20 AAC 25.055(a)(3) for the drilling of a developmem oil well within the Kuparuk River Unit on the North Slope. The exception would allow ARCO to drill Kuparuk River Unit 2N-313 development oil well to a producing location that is closer than 500 feet from a quarter section line. The well will be drilled as a deviated hole from a surface location 33' from the north line and 646' from the east line of Section 3. T9N. R7E. Umiat Meridian (UM) to a producing location 412' from the south line and 1.429' from the west line of Section 27, T10N R7E UM. A person xvho may be harmed if the requested order is issued may file a written protest prior to 4:00 PM May 4. 1998 with the Alaska Oil and Gas Conservation Commission. 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 am on May 20, 1998 in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 27%1433 after May 4, 1998. If no protest is filed, the Commission vdll consider the issuance of the order without a hearing. If you are a person with a disability who may- need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 279-1433 no later than May 12. 1998. C~~y echsli~~ Commissioner Published April 19. 1998 ADN AO02814040 - - ENGINEERING · WELL PERMIT CHECKLIST COMPANY~.~r-"~ WEI,I. NAME~ ,_~/~, PROGRAM:exp[3dev~(redrllE'lserv[3wellboreseg[ ann ,-'"'- /"--'~. ....... ! , / FIELD& POOl._ ......... 7'-,~~,~-L~..~_Q_/~, . INl'f CLASS .~---C~' /'--~--~g-/ GEOLAREA ~"~ O 1.1"1¥#._~.~__~-'/.~'._~._~_~_._~_ O,/O, F SI,ORE ... ADMINISTRAT_.!.O_.N_ , ....... ..... 4 Well Iota led ,nadefined pool ........ Y~~ :~ ' ~,/ _.,¢2~._~___/1./¢.-~4~ ¢..-.~. _~_~_.~. 5 Well Iocaled pfope~ dislance from drilling unil boundary ,.:.,c_- ,,,x ~,-- ¢-.../¢v~'-~ ~ ........ _o 6 Well Iocaled proper dislance from olher wells . . ~ N -//~_/ / .,,./ /~ ..~ ~,/' ' V/ .......... 7 Sufficienl acreage available in drilling unil ~ N ~.,~/~,.z-.J//~,,~// (._- ........................................... 8 If devlaled, is wellbore plal irrcluded N (~peralor only affected pad¥. ,~ N ...... ~ ......... .9 10 ()l'~eralor has appropliale bond m force ~~... ,,N~ ,...--_~--__~/, / ~/~ /' 11 ,.'em iii can be issued wilhou, conservalion order' y_..~___.2~ ~.,~ ././~z~-.:~...,,~ ._.... 12 ['ern]il can be issued wilhoul adminislfalive apploval ..~ ......................................... I:~ (,;l~l l){:lrllll be apl)roved before 15-day wail Y(~ 14 (;¢,[Iduclor string provided 15 Surface casing protects all knowl~ USDWs . . N 16 Ck'l' vol adequale lo circulale on conduclo, & surl csg. f ~~-"':~-~ .J~t'~~ ~.j'~'"'-' .... 17 CMl vol adequate lo lie-in long string Io surf csg . . _ 18 CMl will cover' all known produclive horizons 19 Casing designs adequale lot C, '[. B & permaflost ......... .. 21 I! a ~e.drill, has a 10.403 ~or abandonme~d been approved 22 Adeclt~ale wellbo~e sepa~alion proposed.. 23 Il diveder required, does il meel regulations 24 l)lilhnf! flui(I program .~;cl'len'ralic & eqtnp list adequale 26 B()f'E p~ess rating appropriate, lesl lo ig N 27 Choke manilold complies w/APl RP-53 (May 84) N 28 Work will occur wilhoul operalion shuldown. 2fl I~; l~lese~me ot I I:,S gas probable GEOLOGY 30 t~e[mit can be issued w/o hydrogen sulfide measures 31 [.)ala p~esenled on polenlial overpressure zones 32 Sels~mc analysis ol shallow gas zones. Seabed condition sm~ey (if off-shole) . . . (~[~l'lJ;l(:J ~a~]le,/pho~m for weekly progress reports le~plorato~? only] 33 GEOt C)GY ENGINEERING COMMISSION ~r:~i .......... B E ~:¢/-~ ~ WJ----'~-~~-, - co~ Comments/Instructions' ,-~ .............. :. :.:::.- ~:...: Well History File APPENDIX Information Of detailed nature that is not padicularly 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 : KRU 2N-3!3 FIELD NAME : TARN POOL BOROUGH : NORTH SLOPE STATE : ALASKA API NUM~ER : 50-103-20259-00 REFERENCE NO : 98403 AUG 20 1998 Oil & G~ Con~. ~ -~ ~chora~e LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/08/ 6 ORIGIN : FLIC REEL NAM~ : 98392 CONTINUATION # : PREVIOUS REEL : COM~EAFf : ARCO ALASKA INC, KRU 2N-3t3, TARN POOL, API #50-103-20259-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/08/ 6 ORIGIN · FLIC TAPE NAFiE : 98392 CONTINUATION # : 1 PREVIOUS TAPE : COMFiENT : ARCO ALASKA INC, KRU 2N-313, TARN POOL, A_PI #50-103-20259-00 TAPE HEADER TARN POOL OPEN HOLE WIRELINE LOGS WELL NA~E : API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUFiBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: RUN 1 98392 D KIRKBY D BURELY WELL CASING RECORD 1ST STRING 2ND STRING KRU 2N-313 501032025900 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 6-AUG-98 RUN 2 RUN 3 .......... 3 9N 7E 33 646 149.00 147.50 121.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 3319.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-199'~8~i'6 : 04 3RD STRING PRODUCTION STRING REMARKS: CONTAINED HEREIN IS THE MODIFIED LDWG FORMATTED OPEN HOLE DAS, FMI, SDN, AND CNT DATA AQUIRED ON ARCO ALASKA'S KRU 2N-313 WELL. THIS LOG IS THE PRIMARY DEPTH CONTROL. THE SHIFTS SHOWN BELOW REFLECT CORRELATIONS BETWEEN THE RUN #2 FMS GR AND THE RUN #1 GAFk~A RAY, CARRYING ALL FMS CURVES WITH THE GR SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAM~ : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUM~4A~Y LDWG TOOL CODE START DEPTH SDN 9085.0 CNT 9068.0 DAS 9083.0 ~S 8944.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (FiEASURED DEPTH) BASELINE DEPTH 88888.0 8920.5 8914.0 8906.0 8886.0 8880.0 8877.5 8867.5 8865.0 8861.5 8850.5 STOP DEPTH 3318.0 3282.0 3282.0 3318.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... SDN CNT DAS FMS 88887.5 8920 0 8912 5 8907 0 8885 5 8880 0 8877 0 8867 0 8863 0 8861 0 8850.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8846.5 8838.0 8822.0 8815.5 8809.5 8804.0 8797.5 8789.5 8778.5 8774.5 8759.0 8755.0 8740.0 8731.0 8718.0 8712.0 8706.5 8703.5 8699.0 8692.0 8672.5 8661.5 8657.5 8653.0 8645.5 8637.5 8623.0 8617.5 8610.5 8595.5 8583.5 8564.5 8559.0 8552.5 8548 0 8523 0 8513 5 8502 0 8496 0 8486 5 8482 0 8470 5 8453 5 8449 0 8442 5 8435.0 8424.0 8407.0 8393.0 8385.0 8363.5 8355.0 8341.0 8308.5 8281.5 8845.5 8836.5 8821.5 8814.0 8809.0 8802.5 8797.0 8789.0 8779.0 8773.5 8758.5 8755.5 8738.5 8730.5 8718.0 8712.5 8707.0 8704.0 870O.0 8691.5 8673.0 8662.0 8657.5 8653.5 8645.5 8637.0 8623.0 8618.0 8612.0 8594.5 8584.0 8565.0 8558.0 8552.0 8547.0 8521 0 8512 0 8502 5 8495 5 8485 0 8480 5 8468 5 8452 5 8447 0 8441 5 8434 0 8422 5 8405 0 8393 5 8385 5 83 61 5 8352 5 8338 5 8309 0 8283 0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 8276.5 8278.5 8268.5 8268.0 8257.5 8256.0 8233.0 8233.0 8220.5 8221.5 8204.0 8203 . 5 8201.0 8201.5 8194.0 8195.5 8186.5 8187.5 8182.0 8181.0 8179.5 8178.5 8172.0 8172.0 8169.5 8168.0 8163.0 8163.5 8155.5 8154 . 0 8147.0 8146.5 8141 . 5 8142.0 8137.5 8137.0 8116.0 8115.5 8101.5 8103.0 8095.5 8096.5 8089.0 8089.0 8066.0 8066.5 8054.5 8054.0 8048.5 8050.0 8044.5 8044.5 8030.5 8030.5 8027.0 8027.5 8018.5 8021.0 7978.5 7981.5 7967.0 7968.0 7954.5 7956.0 7945.5 7948.0 7931 . 5 7932.5 7910.0 7910.0 7888.0 7887.0 7859.0 7860.5 7842.0 7844.5 7835.5 7836.5 7819.0 7821 . 0 7817.5 7818.5 7809.0 7809.0 7796.0 7798.5 7788 . 0 7788.5 7773.0 7773.0 7769.0 7769.5 7763 . 5 7764.5 7754 . 0 7754.5 7739.5 7740.5 7727.5 7728.0 7724.5 7724.0 7708.0 7709.0 7703.0 7703.5 7693.0 7694.0 7680.5 7681.5 6-Ar.I~-199~'~6 : 04 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 7672.5 7673.5 7668.5 7668 . 5 7659.5 7660.0 7649.0 7648.5 7627.0 7627.0 7617.0 7618.0 7604.5 7605.0 7590.5 7593.0 7583.5 7584.5 7579.5 7582.0 7567.5 7566.5 7563.0 7563.5 7546.5 7548.5 7538.0 7539.0 7524.0 7524.0 7512.5 7515.0 7493.0 7493.5 7482.0 7483.0 7473.5 7474.5 7456.0 7456.5 7452.5 7452.0 7442.5 7443.5 7439.0 7439.5 743 6.0 7434.5 7400.5 7401.5 7379.5 7380.0 7376.0 7376.0 7364.0 73 65.5 7355.0 7356.5 7342.5 7345.5 7321.5 7322.5 7315.0 7316.5 7307.0 7310.0 7289.5 7290.5 7258.5 7257.0 7246.5 7246.0 7230. 0 7232.5 7212.5 7214.5 7209.0 7212.0 7199.0 7201.5 7179.5 7183.5 7156.5 7158.0 7153.0 7152.5 7148.0 7149.0 7143.5 7145.0 7132.5 7133.5 7112.5 7114.0 7099.0 7101.0 7072.5 7075.0 7048.5 7051.5 7031.5 7033.5 7018.5 7020.5 6990.0 6991.0 6982.5 6985.0 6975.0 6976.0 6-AUG-1998 16:04 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6954 0 6943 5 6933 5 6923 5 6919 5 6895 5 6869 5 6858 0 6839 5 6830 5 6813 0 6794.5 6779.5 6770.0 6757.5 673 6.5 6724.0 6691.0 6672.5 6667.5 6661.5 6652.5 6633.5 6631.0 6612.5 6604.5 6598.5 6588.5 6585.5 6581.0 6575.0 6564.0 6560.0 6557.0 6551.5 6547.5 6541.5 6526.0 6519.0 6515.0 6504.5 6496.5 6485.0 6475.0 6458.5 6450.0 6437.5 6430.5 6409.5 6407.5 6400.5 6395.5 6387.0 6378.0 63 68.0 6956.5 6945.0 6934.5 6922 0 6920 0 6893 5 6870 5 6859 5 6842 5 6833 5 6815 0 6796.0 6782.0 6771.5 6758.5 6739.0 6726.5 6693.5 6676.0 6669.0 6663.0 6652.0 6633.0 6631.5 6612.5 6606.5 6601.0 6590.0 6588.0 6583.0 6576.5 6565.5 6563.5 6559.0 6551.5 6548.5 6541.5 6527.5 6520.0 6516.5 6507.0 6498.0 6485.5 6476.5 6460.5 6451.5 6439.0 6433.0 6412.5 6408.0 6402.5 6396.0 6387.5 6380.0 6366.5 6-AUG-1998 16:04 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6352.0 6353.0 6346.0 6347.0 6341.5 6342.5 6329.0 6331.0 6321 . 0 6321 . 0 6309.0 6310.0 6295.5 6297.0 6284.0 6285.0 6273.5 6275.0 6266.5 6267.5 6257.0 6258.5 6248.0 6249.0 6246.5 6246.5 6238.5 6239.5 6234.5 623 6.5 6228.5 6231 . 5 6217.5 6220.0 6208.0 6209.5 6202.0 6205.0 6189.0 6192.0 6186.0 6187.0 6174.5 6174.0 6170. 5 6171.5 6163.5 6163.0 6151.0 6152.5 6146.0 6147.5 6132.0 6132.5 6122.5 6124.0 6121.0 6122.0 6106.5 6107.0 6089.5 6089.5 6079.0 6078.0 6075.0 6076.0 6069.5 6071.0 6054.0 6055.5 6044.0 6045.5 6037.0 6040.0 6019.0 6022.0 6015.5 6017.5 5998.5 5999.0 5986.0 5987.0 5971.5 5973.5 5959.5 5960.5 5958.0 5958.0 5950.0 5952.0 5932.5 5931 . 5 5899.0 5898.5 5888.5 5888.0 5881.5 5883.0 5865.0 5867.0 5848.5 5850.0 5845.5 5846.5 5834.5 5836.0 5827.0 5828.5 5813 . 0 5814 . 5 6-AUG-199~6 : 04 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 5795.5 5772.0 5754.5 5741.0 5735.0 5726.5 5698.0 5692.0 5683.0 5664.0 5658.5 5642.5 5623.0 5618.0 5605.5 5581.5 5571.0 5567.0 5555.5 5548.5 5544.5 5538.0 5533.5 5529.0 5495.0 5486.0 5480.5 5464.5 5439.0 5428.5 5424.0 5404.0 5388.0 5381 5 5373 0 5347 0 5339 0 5323 0 5310 0 5287 0 5277 5 5270 5 5260 0 5255 5 5232 5 5213 0 5177 0 5163 0 5150.0 5141.5 5136.0 5123.0 5108.0 5097.5 5077.5 5797.0 5774.5 5755.5 5742.0 5735.5 5729.0 5699.5 5692.5 5685.0 5665.5 5659.5 5643.5 5625.0 5619.0 5607.5 5583.5 5571.5 5568.0 5556.0 5550.0 5546.5 5539.0 5535.5 5531.5 5495.0 5487.5 5482.5 5466.5 5440 5 5428 5 5424 5 5405 5 5390 0 5383 5 5373 5 5347 0 5339.5 5324.5 5312.0 5287.5 5278.5 5270.5 52 61.5 5255.0 5234.0 5215.0 5179.0 5163.5 5153.0 5142.0 5137.5 5123.0 5109.5 5101.0 5080.0 6-AUG-1998 16:04 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-1998 16:04 PAGE: 5069.5 5059.0 5045.0 5039.0 5030.5 5014.5 5008.5 4988.0 4965.5 4962.5 4957.5 4940.5 4928.0 4916.5 4903 5 4900 0 4891 0 4879 5 4870 0 4858 5 4851 5 4835.0 4828.5 4825.0 4817.5 4816.0 4806.5 4794.5 4790.0 4785.0 4777.0 4770.5 4755.5 4750.0 4740.5 4728.0 4719.5 4711.0 4690.5 4685.5 4677.5 4660.0 4655.5 5072.5 5063.0 5047.5 5040.0 5031.5 5016.5 5010.0 4988.0 4967.0 4963.0 4959.0 4939.5 4928.0 4917 5 4904 0 4900 5 4891 0 4880 0 4870, 5 4859, 5 4850, 5 4835. 0 4827.5 4825.5 4818.5 4816.5 4808.0 4795.0 4789.0 4785.5 4778.5 4771.0 4756.0 4750.0 4740.5 4729.0 4722.0 4712.0 4690.0 4685.5 4679.0 4661.5 4656.5 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 10 TYPE REPR CODE VALUE .............................. 3 73 120 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 8 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** ....................................................................................... NAM~ SERVUNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GR SDN GAPI O0 000 O0 0 1 1 1 4 68 0000000000 TENS SDN LB O0 000 O0 0 1 1 1 4 68 0000000000 TEND SDN LB O0 000 O0 0 1 1 1 4 68 0000000000 FIRES SDN OI-E4~ O0 000 O0 0 1 1 1 4 68 0000000000 MTEMSDN DEGF O0 000 O0 0 1 1 1 4 68 0000000000 DEV SDN DEG O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 FCNTCNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 TNPH CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN OHlV~4 O0 000 O0 0 1 1 1 4 68 0000000000 MINVSDN OHbl~ O0 000 O0 0 1 1 1 4 68 0000000000 FiNOR SDN OHPI~ O0 000 O0 0 1 1 1 4 68 0000000000 DT DAS US/F O0 000 O0 0 1 1 1 4 68 0000000000 DTSH DAS US/F O0 000 O0 0 1 1 1 4 68 0000000000 SCRADAS O0 000 O0 0 1 1 1 4 68 0000000000 C13 FMS IN O0 000 O0 0 1 1 1 4 68 0000000000 C24 FMS IN O0 000 O0 0 1 1 1 4 68 0000000000 AZ FMS DEG O0 000 O0 0 1 1 1 4 68 0000000000 RB1 FMS DEG O0 000 O0 0 1 1 1 4 68 0000000000 GR FMS GAPI O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG- 199~8--~6: 04 PAGE: 11 ** DATA ** DEPT. 9159. 000 GR.SDN -999.250 TENS.SDN -999.250 TEND.SDN M~ES. SDN -999.250 MTEM. SDN -999.250 DEV. SDN -999.250 CNTC. CNT CFTC. CNT -999. 250 FCNT. CNT 753. 466 NCNT. CNT -999 . 250 CRAT. CNT NRAT. CNT -999. 250 NPHI. CNT -999. 250 TNPH. CNT -999. 250 CALl. SDN DRHO.SDN -999.250 PEF. SDN -999.250 RHOB. SDN -999.250 MSFL.SDN MINV. SDN -999.250 f~NOR.SDN -999.250 DT.DAS -999.250 DTSH.DAS SCRA.DAS -999.250 Cl3.FMS -999.250 C24.FMS -999.250 AZ.FMS RB1. FMS -999. 250 GR. FMS -999. 250 DEPT. 3263.500 GR.SDN -999.250 TENS.SDN -999.250 TEND.SDN ~IRES.SDN -999.250 MTEM. SDN -999.250 DEV. SDN -999.250 CNTC. CNT CFTC. CArT -999.250 FCNT. CNT 277.792 NCNT. CNT -999.250 CRAT. CNT NRAT. CNT -999.250 NPHI.CNT -999.250 TNPH. CNT -999.250 CAL1.SDN DRHO. SDN -999.250 PEF.SDN -999.250 RHOB.SDN -999.250 MSFL.SDN MINV. SDN -999.250 FiNOR.SDN -999.250 DT. DAS -999.250 DTSH.DAS SCRA.DAS -999.250 Cl3.FMS -999.250 C24.FMS -999.250 AZ.FMS RB1 . FMS -999. 250 GR. FMS -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 98/08/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 98/08/ 6 ORIGIN : FLIC TAPE NAME : 98392 CONTINUATION # : 1 PREVIOUS TAPE : CO~ : ARCO ALASKA INC, KRU 2N-313, TARN POOL, API #50-103-20259-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-199~6: 04 PAGE: 12 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 98/08/ 6 ORIGIN : FLIC REEL NAME : 98392 CONTINUATION # : PREVIOUS REEL : COMFiEN=f : ARCO ALASKA INC, KRU 2N-313, TARN POOL, API #50-103-20259-00 Sperry-Sun Drilling Services LIS Scan Utility Thu Nov 05 09:45:32 1998 Reel Header Service name ............. LISTPE Date ..................... 98/11/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/11/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: (TARN POOL) MWD RUN 3 AK-MM-80298 PIEPER D. BURLEY 2N-313 501032025900 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 04-NOV-98 MWD RUN 4 MWD RUN 5 AK-MM-80298 AK-MM-80298 PIEPER ZIEMKE D. BURLEY D. BURLEY JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION MWD RUN 6 AK-MM-80298 ZIEMKE D. BURLEY '! SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 3 9N 7E 33 646 149.70 27.50 120.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 12.250 9.625 3319.0 6.750 9134.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY A/W-D ARE NOT PRESENTED. 3. MWD RUNS 3, 4, 5, AND 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. MWD RUN 6 IS A MEASURED AFTER DRILLING (MAD) PASS OVER A CORE INTERVAL. 5. MWD RUNS 1 THROUGH 6 REPRESENT WELL 2N-313 WITH AN API# 50-103-20259-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9134'MD, 5484'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 3308 0 9088.5 RPD 3308 0 9088.5 RPM 3308 0 9088.5 RPS 3308 0 9088.5 RPX 3308 0 9088.5 GR 3315 0 9095.5 ROP 3354 5 9136.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 3308 3337 3576 3578 3628 3679 3733 3745 3753 3791 3829 3882 3934 4587 5080 5215 5724 5774 6034 6078 6086 6185 6192 6347 6364 6383 6408 6435 6455 6520 6565 .0 0 0 0 5 0 0 5 5 .5 5 5 0 0 0 0 5 5 5 0 5 5 0 0 5 5 0 5 0 0 5 GR 3304 3333 3578 3581 3630 3680 3733 3744 3754 3793 3831 3884 3935 4588 5079 5215 5723 5775 6033 6076 6083 6185 6190 6348 6364 6383 6407 6435 6455 6519 6565 5 5 0 0 0 5 5 5 .0 .0 .5 .5 .5 .0 .5 0 0 0 0 5 5 0 5 0 5 5 5 0 0 5 0 EQUIVALENT UNSHIFTED DEPTH -- 6567 6579 6588 6590 6601 6605 6669 6782 6815 7158 7159 7198 7201 7365 7393 7482 7518 7548 7618 7740 7775 7844 8048 8052 8054 8061 8068 8139 8142 8169 8179 8181 8201 8203 8207 8255 8267 8395 8401 8427 8434 8456 8582 8584 8605 8618 8623 8685 8694 8706 8755 8761 8776 8783 o0 0 0 0 0 0 5 0 0 0 5 5 5 5 0 0 0 5 5 5 5 5 5 5 0 0 5 5 0 5 .0 .0 .5 .5 .5 .5 .5 .5 .0 .5 .0 .5 .5 .0 .5 .5 .0 0 0 5 5 5 5 5 6566.0 6581.0 6585.5 6589 5 6599 0 6604 5 6668 0 6780 5 6814 0 7157 0 7158 0 7197 0 7200 0 7363 5 7391 0 7482 5 7517 5 7546 0 7616 5 7738 5 7774 5 7843 0 8047 0 8050 0 8051 0 8057 5 8066 0 8139 0 8142 0 8168 5 8178 0 8180 0 8200 5 8202 5 8206 5 8255 5 8267 0 8396 0 8399 0 8429 0 8435 5 8457 0 8579 0 8581 5 8602 5 8615 0 8619 5 8682 0 8691 0 8702 5 8753 5 8758 5 8774 5 8782 0 88O9.O 88O7.5 8818.5 8816.5 8907.0 8905.0 8912.0 8910.5 9136.0 9134.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 MWD 4 MWD 5 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP 3350.0 8349.0 8862.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 8349.0 8570.0 9134.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD OHMM 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max DEPT 3308 9136 ROP 0.5 879.15 GR 28.63 233.04 RPX 0.05 98.14 RPS 0.13 2000 RPM 0.05 2000 RPD 1.27 2000 FET 0.01 103.06 Mean Nsam 6222 11657 262.954 11564 122.367 11562 4.57511 11562 5.0548 11562 7.11066 11562 9.19014 11562 1.25465 11562 First Reading 3308 3354.5 3315 3308 3308 3308 3308 3308 Last Reading 9136 9136 9095.5 9088.5 9088.5 9088.5 9088.5 9088.5 First Reading For Entire File .......... 3308 Last Reading For Entire File ........... 9136 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation'. ...... 98/11/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: .5000 START DEPTH 8550.0 8550.0 8550.0 8550.0 8550.0 8550.0 8550.0 STOP DEPTH 8896 5 8896 5 8896 5 8896 5 8896 5 8900 0 8900 0 MAD RUN NO. MAD PASS NO. MERGE TOP 6 8570.0 MERGED MAD PASS. Data Format Specification Record Data Record Type .................. 0 MERGE BASE 8862.0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT RAT GR RPX RPS RPM RPD FET Name Service Order Units Size Nsam Rep FT 4 1 68 MAD FT/H 4 1 68 MAD API 4 1 68 MAD 0HMM 4 1 68 MAD OHMM 4 1 68 MAD OHMM 4 1 68 MAD OHMM 4 1 68 MAD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min DEPT 8550 RAT 1.6 GR 77.34 RPX 2.34 RPS 2.43 RPM 2.37 RPD 2.47 FET 0.63 Max 8900 357 11 177 49 37 38 38 87 39 21 41 43 103.06 Mean 8725 254.813 126.961 10.7826 11.8363 12.0566 13.2593 8.3907 Nsam 701 701 701 694 694 694 694 660 First Reading 8550 8550 .8550 8550 8550 8550 8550 855O Last Reading 8900 8900 8900 8896.5 8896.5 8896.5 8896.5 8896.5 First Reading For Entire File .......... 8550 Last Reading For Entire File ........... 8900 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE N-JMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 3304 5 3304 5 3304 5 3304 5 3304 5 3311 5 3351 5 SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8301.5 8301.5 8301.5 8301.5 8301.5 8309.0 8349.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 26-JTJL-98 INSITE 3.2.12.3 CIM 5.46, EWR4 1.38 MEMORY 8349.0 3350.0 8349.0 45.0 61.1 TOOL NUMBER P1060CRG6 P1060CRG6 8.500 8.5 ~,SND/NABR 9.20 41.0 8.5 MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CA/CE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 1350 6.5 1.850 1.394 1.700 2.600 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHMM 4 1 68 12 4 RPM MWD 3 OHMM 4 1 68 16 5 RPD MWD 3 OHMM 4 1 68 20 6 ROP MWD 3 FT/H 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 46.1 First Name Min Max Mean Nsam Reading DEPT 3304.5 8349 5826.75 10090 3304.5 GR 28.63 233.04 121.077 9996 3311.5 RPX 0.05 98.14 4.23996 9995 3304.5 RPS 0.13 2000 4.71893 9995 3304.5 RPM 0.05 2000 7.09413 9995 3304.5 RPD 1.41 2000 9.40584 9995 3304.5 ROP 0.5 879.15 278.199 9996 3351.5 FET 0.16 63.46 0.78744 9959 3304.5 Last Reading 8349 8309 8301.5 8301.5 8301.5 8301.5 8349 8301.5 First Reading For Entire File .......... 3304.5 Last Reading For Entire File ........... 8349 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8300.0 8549.5 RPD 8300.0 8549.5 RPM 8300.0 8549.5 RPS 8300.0 8549.5 · RPX 8300.0 8549.5 GR 8307.5 8549.5 ROP 8317.0 8549.5 $ LOG HEADER DATA DATE LOGGED: 27-JUL-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2.12.3 DOWN-HOLE SOFTWARE VERSION: CIM 5.46, EWR4 1.38 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 8570.0 TOP LOG INTERVAL (FT) : 8349.0 BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8570.0 45.0 46.3 TOOL NUMBER P1060CRG6 P1060CRG6 8.500 8.5 LSND/NABR 9.80 43.0 8.5 1400 5.4 1.600 1. 193 1.700 3.000 46.1 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 RPX MWD 4 OHMM 4 1 68 RPS MWD 4 OHMM 4 1 68 RPM MWD 4 OHMM 4 1 68 RPD MWD 4 OHMM 4 1 68 ROP MWD 4 FT/H 4 1 68 FET MWD 4 HOUR 4 1 68 4 8 12 16 20 24 28 Name Min Max Mean Nsam DEPT 8300 8549.5 8424.75 500 GR 113.9 170.3 139.247 485 RPX 1.22 7.19 3.43264 500 RPS 1.25 7.26 3.53418 500 RPM 1.28 7.05 3.52158 500 RPD 1.27 6.82 3.66222 500 ROP 3.82 156.81 36.455 466 FET 0.54 13.4 3.12678 500 First Reading 8300 8307.5 8300 8300 8300 8300 8317 8300 Last Reading 8549.5 8549.5 8549.5 8549.5 8549.5 8549.5 8549.5 8549.5 First Reading For Entire File .......... 8300 Last Reading For Entire File ........... 8549.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: FILE SUMMARY .5000 VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 8756 0 8756 0 8756 0 8756 0 8756 0 8763 5 8804 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9087 0 9087 0 9087 0 9087 0 9087 0 9094 0 9134 5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 30-JUL-98 INSITE 3.2.12.3 CIM 5.46, EWR4 1.38 MEMORY 9134.0 8862.0 9134.0 46.7 47.9 TOOL NUMBER P1060CRG6 P1060CRG6 8.500 8.5 LSND/NABR 9.90 51.0 7.8 1400 4.4 2.000 1.211 2. 150 3 .75O 48.9 ' o TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 5 API 4 1 RPX MWD 5 OHMM 4 1 RPS MWD 5 OHMM 4 1 RPM MWD 5 OHMM 4 1 RPD MWD 5 OHMM 4 1 ROP MWD 5 FT/H 4 1 FET MWD 5 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 8756 9134.5 8945.25 GR 79.02 167.63 125.602 RPX 2.37 34.41 5.84805 RPS 2.43 36.55 6.17133 RPM 2.47 31.92 6.05411 RPD 2.59 29.97 6.22142 ROP 1.6 911.9 182.836 FET 0.01 0.82 0.500264 First Last Nsam Reading Reading 758 8756 9134.5 662 8763.5 9094 663 8756 9087 663 8756 9087 663 8756 9087 663 8756 9087 662 8804 9134.5 663 8756 9087 First Reading For Entire File .......... 8756 Last Reading For Entire File ........... 9134.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 6 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR RAT $ LOG HEADER DATA DATE LOGGED: SOFTWARE 8550 0 8550 0 8550 0 8550 0 8550 0 8550 0 8550 0 SURFACE SOFTWARE VERSION: DOW/9IqOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8896.5 8896.5 8896.5 8896.5 8896.5 89OO.0 8900.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 31-JUL-98 INsITE 3.2.12.3 CIM 5.46, EWR4 1.38 MEMORY 8862.0 8570.0 8862.0 46.7 46.8 TOOL NUMBER P1060CRG6 P1060CRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.500 8.5 LSND/NABR 10.00 46.0 10.0 1300 4.0 2.000 1.140 2.150 3.750 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MAD 6 API 4 1 68 4 2 RPX MAD 6 OHMM 4 1 68 8 3 RPS MAD 6 OHMM 4 1 68 12 4 RPM MAD 6 OHMM 4 1 68 16 5 RPD M3~D 6 OHMM 4 1 68 20 6 RAT MAD 6 FT/H 4 1 68 24 7 FET M_AD 6 HOUR 4 1 68 28 8 53.3 First Last Name Min Max Mean DEPT 8550 8900 8725 GR 77.34 177.49 126.961 RPX 2.34 37.38 10.7826 RPS 2.43 38.87 11.8363 RPM 2.37 39.21 12.0566 RPD 2.47 41.43 13.2593 R_AT 1.6 357.11 254.813 FET 0.63 103.06 8.3907 Nsam 701 701 694 694 694 694 701 660 Reading 8550 8550 8550 8550 8550 8550 8550 8550 Reading 8900 8900 8896.5 8896.5 8896.5 8896.5 8900 8896.5 First Reading For Entire File .......... 8550 Last Reading For Entire File ........... 8900 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/11/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/11/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File