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C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-12-18_22142_KRU_2L-313_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22142 KRU 2L-313 50-103-20277-00 LeakPoint Survey 18-Dec-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 198-219 T38250 1/3/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.03 13:36:27 -09'00' Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 11CͲ22 50Ͳ029Ͳ23127Ͳ00 908965028 Kuparuk River Multi Finger Caliper Field & Processed 20ͲNovͲ23 0 1 21DͲ38 50Ͳ029Ͳ22961Ͳ00 908965029 Kuparuk River Multi Finger Caliper Field & Processed 21ͲNovͲ23 0 1 31JͲ107 50Ͳ029Ͳ23366Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 9ͲOctͲ23 0 1 41LͲ03A 50Ͳ029Ͳ21182Ͳ01 908347301 Kuparuk River Multi Finger Caliper Field & Processed 7ͲJanͲ23 0 1 52LͲ313 50Ͳ103Ͳ20277Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 26ͲNovͲ23 0 1 62MͲ24 50Ͳ103Ͳ20171Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 21ͲDecͲ22 0 1 72PͲ415A 50Ͳ103Ͳ20383Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 7ͲOctͲ23 0 1 82PͲ417 50Ͳ103Ͳ20375Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 6ͲOctͲ23 0 1 92PͲ420 50Ͳ103Ͳ20391Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 5ͲOctͲ23 0 1 10 2VͲ05 50Ͳ029Ͳ21051Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 19ͲJulͲ23 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 1. 1C-22 PTD:202-222 T38179 2.1D-38 PTD: 200-077 T38180 3. 1J-107 PTD: 207-107 T38181 4. 1L-03A PTD: 199-037 T38182 5. 2L-313 PTD: 198-219 T38183 6. 2M-24 PTD: 192-050 T38184 7. 2P-415A PTD: 201-226 T38185 8. 2P-417 PTD: 201-069 T38186 9. 2P-420 PTD: 201-182 T38187 10. 2V-05 PTD: 183-176 T38188 12/1/2023 52LͲ313 50Ͳ103Ͳ20277Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 26ͲNovͲ23 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 12:25:47 -09'00' ! "##$ % & '()'(' )) " ( )'*"+,-'( )'* +,-.& ) ) ' ' ' ./ ' )' )''' 0 !' ( ) ! (.(( ! '(' ) (' 1 )) 23 3 +( ) '4( ./ '(' ( ( ) '( ( )!' ' ' . 5+ ! + ! # 26$#2$ 6 )4 41 . 4 + ! 5( 7 ! 48' ( By Samantha Carlisle at 8:48 am, Mar 30, 2021 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021.03.27 06:40:14-08'00' Foxit PhantomPDF Version: 10.1.0 Roger Mouser !"# $#$%& '( #)*+,*+" "( "' "- +. +/ + ($ ! "!#!$%%&'&&'()%!&%*%!(*+%'*,- !& &%&!-#- &- &%&!!"!'$%%&'&&((%%%!'(%$&'+!#*,- !& &%&!(- &- &%&!!."!!*$%%&'&---)%%&%(!)('$&-*,- !& &%&!$!- &- &%&!&/"-!-$%!%-&%&))%%!'*&!'0 &!,# &* &%!'*- &# &%&!&1"#!$%!%-&%)'%%%&!*!$!%-#,$ !%,) -! &%&%&- &# &%&!& "&%*$%!%-&%$!*%%&%$!*))(,%$!&,- &- &%&!*!- &- &%&!& "-)$%!%-&%&&)%%!'$!%!-%,%&%&(,- &- &%&!')- &- &%&! #"-%# $%!%-&%$$$%% &%)!-& &%+$%2 #*, - &# &%&! !% - &# &%&! STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ph- oe�,..,.:...,.. ,... JUIN 2 0 2019 Performed: Suspend ❑ Perforate Full tubinga �W&R&e,4i Atdown ❑ Plug for Redrill ❑ Perforate New Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ ❑ Pool 2. Operator Repair Well ❑ Re-enter Susp Well El Other: Conductorextension0 Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 3. Address: 198-219 Stratigraphic ❑ Service ❑ 6. API Number: P.O.Boz 100360, Anchorage, Alaska 99510 7. Property Designation (Lease Number): 50-103-20277-00-00 8. Well Name and Number: ADL0380051 KRU 2L-313 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A 11. Present Well Condition Summary: Ku aruk River/ Tarn Oil Pool Total Depth measured 11112 feet Plugs 9 measured N/A feet true vertical 5758 feet Junk measured N/A feet Effective Depth measured 10982 feet Packer measured 10284 feet true vertical 5690 feet true vertical 5310 feet Casing Length Size MD TVD Structural Burst Collapse Conductor 80' 16" 108' 108' Surface 2578' 7.625" 2607' 2300' Production 11091' 5.5" 10284' 5310' Production 830' 3.5" 11112' 5758' Liner Perforation depth Measured depth 10676-10716 feet True Vertical depth 5527-5538 feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 10300' 5319' Packers and SSSV (type, measured and true vertical depth) BAKER 80-40 SEAL ASSEMBLY 10284' 5310' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Prior to well operation: N/A Gas-Mcf Water-BblI Casing Pressure Tubing Pressure Subsequent to operation: N/A N/A N/A N/A N/A 14. Attachments (required per 20 anc 25.070, 25.071, a 25283) N/A N/A N/A N/A 15. Well Class after work: Daily Report of Well Operations ED Copies Exploratory ❑ Development p ❑ Service ❑ Stratigraphic ❑ of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ Well Status after work: Oil 0 Gas ❑ WDSPL ❑ 17. I hereby certify that the foregoing is true and GS OR S�SPExempt: SPLUG ❑ WiNJ❑ WAG ❑SundrylNNum❑ber correct to the best of my❑knowl knowledge. or N/A f C.O. Authorized Name: Roger Mouser Contact Name: Roger Mouser/Roger Winter Authorized Title: Wel Integrity Field Supervisor Contact Email: N1927@conocoi)hillios.com Authorized Signature: L� /! Date' Contact Phone: 659-7506 I/ //i,7 Form 10-404 Revised 4/2017 r//s// 7�7L( 1313DWE211 SUN 2 12019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 14, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski: Enclosed please find the 10-404 Sundry from ConocoPhillips Alaska, Inc. well 2L-313, PTD# 198-219, Sundry # 318-563 for conductor extension. Please contact Roger Mouser or Roger Winter at 659-7506 if you have any questions. Sincerely, 4 Roger Mouser ConocoPhillips Well Integrity Field Supervisor Date Event Summary Executive Summary 2L-313 conductor extension 04/28/19 Welder welded 14" OAL of 16" 0.500 wall conductor extension on top of existing conductor 9 JJjj �c °Cl - s 2L4 �f dam.` il� r • q s � hts reser „ raph is provided td„ACC6Gv�iith '°' rtS own use. Co for any other purj���septl�a`.as':? ' r ' � •' x �K•�`�N. 'mss_ �r.6" y Is consent of ConocoPhillips Ala'kay Al. r 0 F = r /O,y _ w In "Copyright 2019. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying M for any other purpose or by other party is prohibited without the express consent of ConocoPhillips Alaska, Inc." • • t WELL LOG TRANSMITTAL DATA LOGGED �o i2,60✓20i5 K.BENDER To: Alaska Oil and Gas Conservation Comm. October 15, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 ;; 11,4, Anchorage, Alaska 99501 isF3i ,,' RE: Temperature Survey: 2L-313 Run Date: 9/10/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2L-313 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20277-00 Temperature Survey Log 1 Color Log 50-103-20277-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ,iQ�____74�v 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. //?~'- ~)~ 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: Beverly Mildred Dareth~owell Date: ~//L,,/ Is, ~ [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: ~si • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2L-313 Run Date: 11/26/2009 December 1, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2L-313 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20277-00 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.barreto a halliht~t~a~~ ~~. .~ ~ ~~ Date: DEC ~ `-1 2009 ~t~ska i~ir ~ ~~s ~o~as. ~ Fcr'-~ssicg; ~~r~orac ~ ~ ~ _ ~l~ 1~~~~ Signed: • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATES 1.Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ Other ~A~~~~~ .. Alter Casing ^ Pull Tubing ^ Pedorate New Pool ^ Waiver ^ Time Extension ^ `~~ A°'`% Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ / ~ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. I?evelapment ~ Exploratory ^ 198-219 3. Address: Stratigraphic ^ service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20277-00. 7. KB Elevation (ft): 9. Well Name and Number: RKB 146' 2L-313 8. Property Designation: 10. FieldlPool(s): ADL 380051 ' ALK 4599 Kuparuk River Field !Tarn Oil PSI • 11. Present Well Condition Summary: Total Depth measured 11140" feet true vertical 5773' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural ` CONDUCTOR 108' 16" 108' 108' SURFACE 2461' 7-5/8" 2607' 2299' PRODUCTION 10136' S-1/2" 10282' 5309' PRODUCTION 830' 3-1/2" 11112' 5758' Pertoration depth: Measured depth: 10676-10716 y~w' ~'~~ ~' ~ ~Q~U ~~, I true vertical depth: 5526-5548 Tubing (size, grade, and measured depth) 3_112" , L-80, 10282' MD. 3-112" WFT Patch 5128` - 5148` Packers &SSSV (type & measured depth) Seal =Baker GSA 80-40 Seal = 10282' SSSV= NIP SSSV= 487' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation n/a n/a n/a n/a n/a Subsequent to operation n/a na n/a n/a n/a 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: • Ga~ WAG^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. sundry Number or NiA if C.o. Exempt: N/A contact Brent Rogers/Martin Walters Printed Name M rtin Walters Title Problem Well Supervisor signature ~~~~~ j~ ~ Phone 659-7224 Date 11 /1512008 ~(~ Form 10-404 Revised 04/2004 t ~ ~ ~~ ~ ~ _ ca~~ Submit Original Only f ~ ~ ~~- ~~~~ ~i ~ X006 • • 2L-313 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/18/08 07/19/08 10/16/08 10/24/08 10/29/08 11/04/ PULLED 20' WEATHERFORD UPPER PATCH ASS'Y @ 5127' SLM & LOWER ER PKR @ 5143' SLM. PULLED JET PUMP @ 10173' RKB TAGGED @ 10365' SLM. SET 2.75" CA-2 PLUG @ 10275' RKB; PASSED 2500 PSI COMBO MIT. PULLED PLUG. CLOSED CMU @ 10173' RKB. WELL READY FOR FCO. LOGGED PDS CALIPER /MTT f/10350' WLM TO SURFACE. RECOVERED GOOD DATA. SET 2.75" CAT SV Cc~ 10275' RKB. COMBO MIT TO 3500 PSI GOOD. OPENED CMU @ 10273' RKB,.PULLED CAT SV @ 10275 RKB. SET 3" RC JET PUMP (a7 10173' RKB ELINE. SET WFT ER 3-1/2" LOWER PATCH PACKER ASSEMBLY AT 5148'. READY FOR SLICKLINE TO SET UPPER ASSY. ENGAGED LOWER ER PACKER @ 5148' RKB WITH UPPER TBG PATCH (ER PKR, )8 SPACER, SNAP LATCH ASS'Y: 19.81' OAL, MIN. ID 1.75"). TOP OF PATCH Cad 5128' RKB. PRESSURE TESTED UPPER ER PACKER GOOD PULLED TUBING PATCH AND JET PUMPTO RUN CALIPER AND MTT LOGS AND Summary PERFORM TxIA CMIT. RERAN JET PUMP @ 10173' RKB AND TUBING PATCH FROM 5128' - 5148. WALL L ~~~ TR~/Uf~fl°~i4L .4* __~____-_ ~_ ProActive Diagnostic Services, Inc. ~..~- To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 '.~.,`'~4.r%~~D cG i7 `tr+aS1 1 i~S ~ j • 4'- ~ 1 V l~ ~:~: RE : Cased Hole/Open Hoie/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Rol~rt A. Richey 130 West Internatronal Airport Road Suite C Anchorage, AK 99518 Fax: (907 245-8952 1) Caliper Report / MTf 16-0ct-08 2L--313 1 Report / EDE 2) Caliper Report 22-0ct-08 1 G17 1 Report / EDE 1~9-0~~ t3~~ Signed Print Name: 40-103-20277-00 50-029-22945-00 PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)2458952 E-MAIL: ~t~~~r~~Is~r~t~C~r~ertt~r~la~~.c~r~ WEBSITE: ~,riv°~v.s~rrsari~iag.c~,n ~~ C:\DocumenCS and Settings\Owner\Desktop\Traz~smit_Conoco.doc Memory Multi-Finger Caliper &MTT Results Summa.. Company: ConocoPhillips Alaska, Inc. Well: 2L~13 Log Da#e: Oc#ober 16, 2008 Field: Tam Log No.: 7271 State: Alaska Run No.: 2 API No.: 50-103-20277-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE-8RD Top Log Intel.: Surface Pipet Use: Tubing Bot. Log Intel: 10,282 Ft. (MD) Pipet Desc.: 5.5" 15.5 Ib. L-80 EUE-8RD Top Log Intel: Surface Pipet Use: Production Casing Bot. Log Intel: 10,282 Ft. (MD) Pipe3 Desc.: 3.5" 9.3 Ib. L-80 EUE-8RD Top Log Intel: 10,282 Ft. (MD) Pipe3 Use: Production Casing Bot. Log Intel: 10,346 Ft. (MD)) Pipe4 Desc.: 7.625" 29.7 Ib. L-80 SCT-MOD Top Log Intel.: Surface Pipe4 Use: Surtace Casing Bot. Log Intel: 2,597 Ft. (MD) Pipes Desc.: 16" 62.581b. H-40 WELDED Top Log Intel.: Surface Pipes Use: Conductor Bot. Log Intel: 89 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS The data in this iog is tied into the Camco D-Nipple ~ 10,275' (Driller's Depth). This is the second time a PDS Multi-Finger Caliper and 12 Arm Magnetic Thickness Tool (MTT) has been run in this well. The MTT responds to the total thickness of metal of the 3.5" tubing, 5.5" production casing, 7.625" surface casing and 16" conductor. A single pass at 8Hz was made at 20 fpm from surface to 10,344'. The previous MTT log (12-Nov-07) was pulled at 40 fpm and logged at 10 Hz. This current MTT log was pulled at 20 fpm and recorded at SHz. These operational changes have been made as part of a continuous effort to improve the data quality and value of the MTT logs. The lower pull speed and recording frequency have both had a positive effect on the log quality of the MTT. While the indications of overall general metal loss indicated by the MTT between the current and previous log are very similar, the lower pull speed and recording frequency used in the current log support a higher confidence level in identifying and commenting on isolated metal loss events recorded by the MTT. The lower pull speed and recording frequency used in this current log also enable an interpretation of the MTT recordings over the interval that includes the 7.625" surface casing and 16" conductor. The operational procedure changes made between the previous and current MTT log of this well prevent any direct comparisons of the two data sets. INTERPRETATION OF CALIPER LOG RESULTS The caliper recordings lndir.a#e the 3.5" #ub~ng logged is ua good #o poor condition wath respect to uatemal corrosive and mechanical damage, with a probable hole recorded in joint 162 (5,139'). A 3-D log plot of the caliper recordings across this interval is included in this report. The remainder of the tubing logged appears ' to be in good condition with respect to intemal corrosive and mechanical damage, with na other significant wall penetrations, areas of cross-sectional wall loss, or I.D. restrictions recorded. This is the second time a PDS caliper has been run on this well. A comparison between the current and previous log (April 1, 2007) indicates an increase in corrosive damage during the time between logs. A comparison graph illustrating the maxirr~m-recorded penetration on a joint-by joint basis for the current and previous log is included in this report. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com ' Prudhoe Bay Field Once Phone: (907) 659-2307 Fax: (907) 659-2314 1 ~ a ~- a I`~t ~ ~~- ~ • • ' 3.5" TUBING & CASING -MAXIMUM RECORDED WALL PENETRATIONS Probable Mole { 98%) Jt. 162 ~ 5,139 Ft. {MD) No other significant wail penetrations (> 19%) are recorded. 3.5" TUBING ~ CASING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas o#cross-sectional wall loss (> 4%) are recorded, 3.5" TUBING 8~ CASING -MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. INTERPRETATION OF MTT LOG RESULTS The MTT recordings indicate a relative general metal loss ranging from 1 % to 6% throughout the logged interval, as illustrated in the included Average Metal Thickness Relative to the Calibration Point graph. These results indicate that there appear to be no intervals of severe volumetric metal loss that would extend over a large surface area of any of the pipe strings in the MTT's field of influence. The change in metal volume over the interval that indudes only the 3.5" tubing and 5.5" production casing (2,597' -10,282') is referenced to a calibration depth of 6,088'. The change in metal volume over the interval that indudes the 3.5" tubing, 5.5"production casing and 7.625" surface casing (89' - 2,597) is referenced to a calibration depth of 719'. The change in metal volume over the interval that includes the 3.5" tubing, 5.5" production casing, 7.625" surface casing and 16" conductor pipe (surface - 89') is referenced to a calibration depth of 53'. In the log interval between the bottom of the 7.625" surface casing (2,597') and the bottom of the tubing (10,282'), the quality of the MTT data appears to be relatively high, with some degradation due to irregular tool speed. In the interval that indudes only the 3.5" tubing and 5.5" casing, there are numerous indications of isolated metal loss events that appear to represent pitting damage on the outside of the tubing string. This is supported by the high frequency nature of these recordings that are indicated on only a few of the MTT's 12 radial receivers. Metal loss features of inner most concentric strings tend to appear as higher frequency responses than features of outer strings. The MTT log shows an isolated high frequency response at the same location as the 98% wall penetration recorded by the caliper in Jt. 162 ~ 5,139'. However, the MTT response at this location is a change of positive 85% metal thickness, rather than a negative change. Using these values as a reference far the MTT's range of possible responses to a small hole in the tubing under these logging conditions, we created a "Maximum Isolated Metal Thickness Deflection" graph depicting maximum signal deflection at isolated events. This should relate to the severity of potential isolated pitting on the outside of the tubing Several values in the graph exceed the value that was recorded at the location of the known hole in the tubing, and may represent areas of similar volumetric metal loss that are broader and less invasive than the damage where the hole is recorded. Log plots of the MTT data recorded over the intervals (5,112' - 5,186') and (10,096' -10,265') are included in the report. The data recorded above the bottom of the 7.625" surface casing interval (surface - 2,597') exhibits a higher signal-to-noise ratio than the data recorded below this interval, but appears to be valid for assessing relative overall metal loss within the interval. The recordings over this interval indicate general overall metal loss ranging from 1 % to 6% - similar to that recorded below this interval. The higher signal-to-noise ratio over this log interval leads to a decreased confidence in discerning individual isolated metal loss events from data spikes, but variations in apparent signal-to-noise levels throughout this interval appear to mimic common ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 7749' Phone: (281) or (888) 565-9085 Fax: {281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: {907) 659-2314 ~ • ~ corrosive damage pattems. The absence of these pattems in the data recorded below the surface casing point to a probability of correlation to features of the surface casing. A log plot of the MTT data recorded over the interval (1,840' - 2,040'}, depicting the variations in signal-to-noise patterns is included in this report. The MTT data recorded over the interval that includes the 16" conductor pipe (surface - 89') is the fast set of interpretable MTT data recorded by PDS over an interval that includes four concentric strings of pipe. This lends significant support to the practice of pulling the MTT at slower logging speeds and recording at lower frequencies in order to improve data quality and obtain interpretable data in in#ervals of three or more concentric strings. The data recorded over this interval indicates general overall metal loss volumes ranging from 0% to 2%. The signal-to-noise ratio appears slightly higher in the interval that includes the conductor pipe than the data recorded below the conductor. A pattern area of higher signal-to-noise ratio is indicated on sensors 1 through 8 over the interval (74'-88'), which may correlate to an area of corrosive damage in one of the outer pipe strings. A log plot of the MTT data recorded over the interval (surface -105') is included in the report. I' The Delta Metal Thickness (%} curves in these plots refer to total metal surrounding the MTT tool, which includes the tubing and casing strings. Due to the concentric pipe strings in the log interval, the MTT i response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not ' positively distinguishing in which pipe string the change in metal thickness occurs. !n this log, the MTT was calibrated downhole (53', 719' and 6,088'}, where the readings are assumed to represent undamaged tubing and casing. .~ J ',' Field Engineer: W. McCrossan Analyst: C. Waldrop (MIT), HY Yang & J. Burton (MTT) Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: {281) or {888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com ' Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: (907) 659-2314 '~ ~ • n er Cali er 3D PDS Mult g p Lo Plo g t ~_ . Company : ConocoPhitlips Alaska, Inc. Field : Tarn Well : 2L-313 Date : October 16, 2008 Descriptio 5 139 n : Detail of Caliper Recordings Across a Probable Hole ( ') Recorded in 3.5"Tubing 1 - ~ .~ 0 50 0 `~+V _ ' X500 Min ID (1!1000 in_) 350( ~2500Natninal I_D- ~1/1000 in_t350 ) 0 300 + ~ Joint 159 5050 1 5060 - - -- - >„ _, -_- _. __-_~ 5070 Joint 160 5080 -- - _ __ ~:.; ' 5090 = M 5100 .. ' Joint 161 5110 . ,~~ :.~ - 5120 Joint 16z 5130 - - - Probable ' Hole (5,138 5140 5150 .r ~:~ ~.T -- 5160 _ ~, Joint 163 ti~ 5170 .~ 5180 ~~ ,. 5190 _ Joint 1sa ~- 5200 ' 5210 5220 ' Joint 165 ~~ ~` 5230 r. l i~ of Recorded Dama e to Borehole Profile Correlat n g Pipe 1 3.5 in (9.8' - 10343.5') Well: 2L-313 Field: Tarn Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: October 16, 2008 ^ Approx. Tool Deviation ^ Approx. Borehole Profile 1 37 ~~~ 50 ', ,_'' i 1585 100 ~. 3166 ~U 1~ I 4744 _ I d ~ ~ GLM 1 ~ y I ~ .c 200 ~ 6355 ~ ' v o - p 250. ~ 7935 300 9511 GLM 2 _ i ~ _ 324 __ _ 10344 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 324 • • ~ ~~ Well: 2L-313 Field: Tarn Company: ConocoPhillips Alaska, Inc. Country: USA Maximum Recorded Penetration Comparison To Previous Survey Date: October 16, 2008 Prev. Date: April 1, 2007 Tool: UW MFC 24 No. 211387 Tubing: 3.5" 9.3 Ib L-80 EUE-8RD Overlay Max. R ec. Pen. (mils) 0 1 00 2 00 0.1 7 16 26 36 46 56 66 76 86 96 106 116 126 136 d 146 156 Z 166 ~ 176 ' o 183 193 203 213 223 233 - 243 253 263 273 283 _ 293 303 313 321.1 ^ October 16, 2008 ^ April 1, 2007 Difference -5 D 0 -2 iff. in Max. Pen. (mil 5 0 2 s) 5 5 0 7 16 26 36 46 56 ~ ~ 66 76 86 ~ 96 - 106 116 126 136 ' 146 ' ~ f 156 Z 166 ~ ' 176 o ~' 183 193 203 213 223 233 243 253 263 273 283 293 303 313 321.1 -32 -16 0 16 32 Approx. Corrosion Rate (mpy) • • PDS Report Overview ~~ S . Body Region Analysis Well: 2L-313 Survey Date: October 16, 2008 Field: Tarn Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE-8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 250 200 --- 150 - - 100 -- 50 - 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 8$% 8$% Number of ~oints anal sed total = 334 pene. 2 97 234 0 0 1 loss 98 236 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 1 0 0 0 0 1 Damage Profile (% wall) ~ penetraton body ire metal loss body 0 50 100 n GLM 1 GLM 2 Bottom of Survey = 324 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD Well: 2L-313 Body Wall: 0.254 in Field: Tarn Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 16, 2008 Joint No. Jt. Depth (Ft.) Pc~n. U)~sc~t Ilns.) Pen. Body (Ins.) Pen. % Metal Loss %> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 10 0 0.01 5 0 2.93 PUP .2 13 O 0.02 7 (1 2.88 PUP .3 21 O 0.01 6 1 2.94 PUP .4 29 0 0.01 4 2 2.90 PUP 1 37 0 0.02 9 ? 2.93 Lt. De sits. 2 68 0 0.01 5 2 2.92 3 100 l) 0.03 11 1 2.91 4 131 l) 0.03 11 2 2.93 5 163 0 0.03 13 2 2.91 6 195 0 0.04 15 2 2.91 Lt. De sits. 7 227 l) 0.03 10 1 2.94 8 259 0 0.03 13 2 2.91 9 290 0 0.03 12 1 2.91 Lt. De sits. 10 321 0 0.03 12 2 2.93 Lt. De sits. 11 353 U 0.04 18 2 2.93 Lt. De sits. 12 385 0 0.04 14 1 2.91 13 417 l) 0.03 12 2 2.91 14 448 O 0.04 16 2 2.92 Lt De sits. 14.1 480 O 0 0 0 2.88 Camco DS-Ni le 15 482 0 0.03 1 1 2 2.91 Lt. De sits. 16 513 0 0.03 12 1 2.92 17 545 O 0.01 6 1 2.92 18 577 l) 0.03 12 2 2.92 19 608 0 0.02 7 2 2.93 20 640 0 0.04 14 2 2.92 21 671 0 0.04 14 2 2.93 Lt. De sits. 22 703 0 0.02 7 1 2.93 23 733 0 0.03 13 1 2.92 Lt. De sits. 24 765 O 0.03 11 3 2.92 Lt. De sits. 25 797 0 0.03 11 2 2.93 26 827 0 0.03 11 1 2.90 27 859 O 0.03 13 0 2.91 28 891 (1 0.03 11 2 2.93 29 922 __ 0 0.03 12 2 2.91 30 954 0 0.03 13 2 2.91 31 9_86 (> 0.03 11 2 2.92 32 1017 0 0.03 10 2 2.92 33 1049 0 0.03 12 1 2.91 Lt. De sits. 34 1081 _ O 0.03 13 2 2.93 35 1111 0 0.03 13 2 2.93 36 1143 0 0.04 15 2 2.92 Lt. De sits. 37 1175 0 0.03 11 2 2.91 38 1206 O 0.03 13 2 2.91 39 1238 O 0.03 12 1 2.91 40 1270 O 0.03 13 2 2.90 41 1301 O 0.03 13 1 2.93 42 1333 0 0.01 6 1 2.92 43 1365 U 0.03 13 2 2.93 44 1396 0 0.02 8 1 2.93 45 1427 l) 0.03 13 Z 2.91 Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD Well: 2L-313 Body Wall: 0.254 in Field: Tarn Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 16, 2008 Joint No. Jt. Depth (Ft.) I'c~n. Ut~sc~t (Ins.) Pen. Body (Ins.) Pen. % Metal Loss %, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 46 1458 a 0.03 13 1 2.91 47 1490 l) 0.03 13 2 2.91 48 1522 0 0.04 14 1 2.90 49 1553 0 0.03 12 2 2.90 50 1585 O 0.04 15 2 2.93 51 1617 U 0.03 11 2 2.92 52 1648 0 0.03 11 2 2.92 53 1679 0 0.04 14 2 2.93 Lt. De sits. 54 1711 0 0.02 9 0 2.91 55 1743 () 0.04 14 2 2.93 56 1775 U 0.03 13 2 2.93 57 1806 U 0.02 t3 2 2.92 58 1838 0 0.04 14 1 2.92 59 1870 0 0.04 15 1 _ 2.92 60 1901 0 0.03 10 1 2.91 61 1934 0 0.03 12 1 2.91 62 __ 1965 0 0.03 10 1 2.93 63 1997 0 0.03 12 2 2.93 64 2028 0 0.04 14 1 2.93 65 2060 U 0.04 14 2 2.93 66 2091 t) 0.04 17 2 2.92 Lt. De sits. 67 2122 () 0.03 13 2 2.91 68 2154 0 0.02 9 2 2.91 Lt De sits. 69 2185 0 0.03 1 1 1 2.92 Lt. De sits. 70 2217 0 0.03 11 2 2.92 71 2249 U 0.03 11 1 2.92 72 2280 0 0.01 4 0 2.91 73 2312 0 0.02 7 2 2.95 74 2342 0 0.04 15 2 2.92 75 2374 0 0.03 13 1 2.92 76 2405 0 0.03 12 1 2.92 Lt. De osits. 77 2437 () 0.03 11 2 2.91 78 2469 U 0.04 14 1 2.94 79 2501 U 0.03 13 2 2.92 80 2532 0 0.04 16 2 2.91 81 2563 U 0.04 14 2 2.91 82 2595 0 0.04 18 2 2.93 83 2627 0 0.04 14 2 2.94 84 2659 0 0.04 14 Z 2.91 85 2690 0 0.04 15 2 2.91 86 2723 0 0.03 13 2 2.90 Lt. De sits. 87 2754 U 0.03 13 2 2.93 88 2786 0 0.03 12 1 2.93 89 2817 0 0.04 14 ? 2.91 90 2849 0 0.04 17 2 2.91 Lt. De sits. 91 2880 0 0.02 9 2 _ 2.91 92 2912 l) 0.04 14 3 2.94 Lt. De sits. 93 2944 0 0.03 11 2 2.92 94 2976 0 0.02 8 _ 2 2.96 95 3007 t1 0.03 13 2 2.92 Penetration Body Metal Loss Body Page 2 ~ ! PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD Well: 2L-313 Body Wall: 0.254 in Field: Tarn Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 16, 2008 Joint No. Jt. Depth (Ft.) Pen. Ups<~t (Ins.) Pen. Body (Ins.) Pen. % lvletal Lass °ib Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 3039 (1 0.04 15 2 2.91 Lt. D sits. 97 3071 U 0.03 12 2 2.93 98 3103 O 0.04 16 1 2.92 99 3134 (1 0.03 11 2 2.93 Lt De sits. 100 3166 0 0.04 14 2 2.91 Lt. De sits. 101 3198 t) 0.04 16 2 2.90 102 3229 t) 0.04 16 2 2.92 103 _ 3261 0 0.04 15 2 2.93 Lt. De sits. 104 3292 0 0.03 13 2 2.93 105 3324 (1 0.03 12 2 2.93 106 3356 0 0.02 8 1 2.96 107 3387 0 0.03 11 1 2.92 108 3419 0 0.04 14 2 2.92 109 3450 0 0.04 14 2 2.90 110 3482 0 0.04 16 2 2.90 111 3514 0 0.02 7 2 2.92 112 _3546 O 0.04 15 2 2.91 Lt. De sits. 113 3577 0 0.03 13 2 __ 2.92 114 3609 0 0.03 10 2 2.96 115 3640 0 0.04 16 2 2.92 116 3672 U 0.03 12 2 2.91 117 3704 O 0.03 13 1 2.92 118 3735 O 0.03 11 2 2.92 119 3767 U 0.04 14 2 2.93 120 3799 0 0.03 10 2 2.94 121 3831 O 0.03 13 2 2.93 122 3862 O 0.02 8 1 2.95 123 3894 l) 0.02 9 2 2.96 124 3926 p 0.02 9 2 2.93 125 3958 l) 0.04 17 2 2.92 126 3989 O 0.02 9 2 2.96 127 4020 O 0.03 10 2 2.91 128 4052 O 0.04 14 2 2.93 129 _ 4082 O 0.02 8 2 2.89 Lt. De sits. 130 4114 U 0.01 6 2 2.96 131 4146 O 0.03 12 1 2.90 Lt. De osits. 132 4176 U 0.03 11 2 2.91 133 4208 U 0.01 5 2 2.93 134 4240 0 0.03 13 3 2.91 Lt De sits. 135 4271 l) 0.04 15 1 2.91 136 4301 I) 0.03 12 2 2.91 137 4333 t) 0.03 11 2 2.92 138 4364 O 0.04 16 2 2.93 139 4396 0 0.03 13 2 2.92 140 4428 l) 0.04 14 2 2.93 141 4459 0 0.04 15 3 2.93 142 4491 l) 0.04 14 2 2.92 143 4522 l) 0.03 13 1 2.92 Lt De sits. 144 4554 0 0.04 15 2 2.93 145 4586 0 0.(34 17 2 2.92 Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD Well: 2L-313 Body Wall: 0.254 in Field: Tarn Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 16, 2008 Joint No. Jt. Depth (Ft.) P~~n. OI>set (Ills.) Pen. Body (Ins.) Pen. % Metal Loss °i~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 146 4618 U 0.02 9 ~' 2.97 147 4649 t) 0.03 12 Z 2.93 Lt. De sits. 148 4681 l) 0.03 13 2 2.93 149 4713 l) 0.03 13 Z 2.92 150 4744 0 0.04 14 2 2.94 151 4775 U 0.02 9 1 2.92 152 4807 U 0.03 13 2 2.93 153 4839 0 0.04 15 1 2.93 154 4871 0 0.04 16 2 2.92 155 4902 0 0.04 14 1 2.91 156 49_33 0 0.04 15 2 2.92 157 4964 U 0.04 14 Z 2.90 158 _ 4995 0 0.04 15 2 2.91 159 5027 O 0.03 13 3 2.91 160 5058 U 0.03 13 3 2.92 161 5088 (1 0.04 16 2 2.91 162 ___5120 0 0.25 98 2 2.93 Probable Hole! 163 5152 0 0.04 14 2 2.92 164 5183 () 0.04 18 ? 2.92 165 5215 t) 0.04 14 2 2.92 166 5247 U 0.04 15 2 2.91 167 5278 0 0.03 13 1 2.93 168 5310 l) 0.04 15 2 2.91 169 5341 U 0.04 17 2 2.90 170 5373 0 0.02 9 1 2.96 171 5405 t) 0.03 12 2 2.92 172 5437 l) 0.03 10 1 2.93 173 5468 () 0.05 18 2 2.92 174 5500 0 0.03 12 1 2.91 175 5532 0 0.02 9 1 2.93 176 5563 0 0.03 13 1 2.91 177 5595 U 0.03 12 1 2.94 178 5627 0 0.02 9 2 2.96 179 5658 O 0.04 14 1 2.90 180 5690 0 0.04 17 2 2.92 180.1 5722 0 0.01 2 1 2.96 PUP 180.2 5736 0 0 0 0 __ N A GLM 1 Latch ®4:00 180.3 5743 0 0.01 4 2 2.96 PUP 181 5757 0 0.02 9 2 2.98 182 5788 U 0.04 14 3 2.92 183 5820 0 0.04 18 2 2.93 184 5852 O 0.04 16 2 2.92 Lt. De sits. 185 5883 U 0.04 14 2 2.93 186 5915 O 0.03 13 2 2.91 187 __ 5947 0 0.04 18 2 2.92 188 _5978 l) 0.04 16 1 _._ 2.92 189 6010 (1 0.04 14 1 2.92 190 6042 O 0.03 13 2 2.92 191 6072 O 0.04 18 2 2.93 _ 192 6104 l) 0.04 17 1 2.92 Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE$RD Well: 2L-313 Body Wall: 0.254 in Field: Tarn Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 16, 2008 joint No. Jt. Depth (Ft.) Pen. Ul~sc~t (Ins.) Pen. Body (Ins.) Pen. % Metal Loss '% Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 193 6135 () 0.03 11 2 2.93 194 6166 U 0.05 18 2 2.92 Lt. De sits. 195 6197 0 0.03 10 2 2.95 196 _ 6229 0 0.03 13 2 2.91 Lt. De sits. 197 6261 0 0.02 8 2 2.97 148 62 92 0 0.03 12 3 2.91 199 6324 0 0.04 16 2 2.92 Lt. De sits. 200 6355 () 0.02 8 2 2.96 201 6387 (1 0.04 15 2 2.92 202 6419 0 0.04 17 2 2.91 203 6451 l) 0.03 13 3 2.91 204 6483 0 0.02 9 2 2.96 205_ 6514 O 0.05 18 3 2.88 Lt. De sits. 206 6546 U 0.03 13 3 _ 2.93 207 6578 U 0.03 10 2 2.97 208 6609 a 0.03 11 2 2.95 209 6640 t) 0.04 17 2 2.93 210 6672 l) 0.04 15 2 2.92 211 6704 O 0.02 t3 2 2.94 212 6735 () 0.03 1 1 1 2.92 Lt. De sits. 213 6767 U 0.02 9 2 2.97 214 6799 0 0.02 9 3 2.96 215 6830 t) 0.05 19 ? 2.90 216 6862 0 0.04 16 2 2.92 217 6894 0 0.03 13 4 2.92 218 6926 O 0.02 8 2 2.96 219 6957 O 0.03 13 2 2.92 220 6989 O 0.01 2 2 2.97 221 7020 O 0.03 1 1 1 2.91 Lt. De sits. 222 7052 t) 0.03 13 2 2.92 223 7084 () 0.04 14 1 2.91 224 7115 l) 0.03 13 1 2.92 225 7147 l) 0.02 f3 2 2.98 226 7179 U 0.04 14 2 2.90 227 7211 O 0.03 11 2 2.94 228 7242 l) 0.03 11 2 2.93 229 7274 0 0.03 13 2 2.92 230 7306 U 0.02 9 3 2.96 231 7337 0 0.05 18 2 2.91 232 7368 U 0.03 13 2 2.94 233 7399 11 0.04 17 2 2.93 234 7431 0 0.04 17 1 2.93 235 7462 0 0.02 9 1 2.92 236 7494 t) 0.04 14 3 2.92 237 7525 O 0.03 12 2 2.93 238 7557 0 0.03 10 2 2.93 239 7588 t) 0.03 13 2 2.93 240 7620 l1 0.03 13 1 2.93 241 7651 O 0.03 11 L 2.93 242 7683 (1 0.02 7 2 2.97 Penetration Body Metal Loss Body Page 5 PD•REPORT JOINT TABULATION'EE1 Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD Well: 2L-313 Body Wall: 0.254 in Eield: Tarn Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 16, 2008 Joint No. Jt. Depth (Et) Pen. Ulxet (Ins.) Pen. Body (Ins.) Pen. % Metal Loss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 243 7714 t) 0.03 13 1 2.90 244 7746 l) 0.04 15 2 2.93 245 7778 11 0.03 13 1 2.93 246 7810 U 0.01 6 1 2.98 247 7842 l) 0.04 14 3 2.94 248 7873 U 0.04 17 2 2.89 249 7904 0 0.04 16 2 2.90 250 7935 t) 0.02 7 2 2.97 251 7967 () 0.03 10 2 2.93 252 7997 O 0.02 8 2 2.96 253 8028 U 0.05 19 2 2.93 254 8060 U 0.02 7 1 2.97 255 _ 8091 U 0.01 4 2 2.92 256 8123 t) 0.04 17 2 2.91 257 8155 (1 0.01 6 1 2.97 258 8186 O 0.04 14 1 2.91 259 8218 O 0.01 2 1 2.98 260 8250 (1 0.02 9 2 2.96 261 8280 O 0.02 8 3 2.96 262 8312 0 0.03 13 1 2.93 263 8344 U 0.03 11 2 2.90 264 8375 (1 0.03 13 1 2.93 265 8407 O 0.04 17 0 2.93 266 8439 l) 0.04 16 2 2.91 267 8470 0 0.02 7 1 2.97 268 8502 O 0.02 9 2 2.92 269 8533 0 0.02 7 2 2.96 270 8564 l1 0.03 13 1 2.93 271 8596 O 0.02 7 1 2.97 272 8627 O 0.04 17 2 2.91 273 8659 tl 0.01 5 1 2.97 274 8691 U 0.01 2 1 2.97 275 8722 O 0.03 13 1 2.92 276 8754 t) 0.04 15 1 2.92 277 8784 U 0.04 14 2 2.92 278 8815 () 0.01 4 1 2.97 279 8846 0 0.04 14 2 2.90 280 8879 l) 0.03 12 1 2.91 281 8911 0 0.03 13 3 2.93 282 8942 0 0.03 11 1 2.93 283 8973 0 0.02 7 2 2.96 284 9005 () 0.03 13 1 2.91 285 9037 () 0.03 13 2 2.91 286 9068 O 0.02 9 2 2.92 287 9100 0 0.03 13 1 2.92 288 9131 (1 0.03 13 1 2.91 289 9163 U 0.03 11 1 2.93 290 9195 Il _ 0.04 17 2 2.91 291 9227 t~ 0.01 5 1 2.97 292 9258 i) 0.00 1 2 2.97 Penetration Body Metal Loss Body Page 6 PD•EPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD Well: 2L-313 Body Wall: 0.254 in Field: Tarn Upset Wall: 0.254 in Comteany: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 16, 2008 Joint No. Jt. Depth (Ft.) I'f~n. ll(net (Irn.) Pen. Body (Ins.) Pen. % Metal Losti °i<> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 293 9289 0 0.04 15 2 2.91 294 9322 l) 0.01 4 2 2.97 295 9352 0 0.03 13 1 2.90 296 9384 0 0.01 5 2 2.98 297 9416 () 0.02 7 2 2.97 298 9447 0 0.04 17 2 2.93 299 9479 0 0.02 B 2 2.95 300 9511 0 0.04 17 2 2.92 301 9543 0 0.02 7 2 2.94 302 9574 0 0.04 15 2 2.92 303 9605 0 0.04 17 2 2.93 304 9637 0 0.03 12 I 2.93 305 9669 0 0.00 1 2 2.97 306 9701 0 0.03 12 2 2.92 307 9732 t) 0.04 14 1 2.91 308 9764 0 0.03 10 2 2.91 309 9795 0 0.03 12 1 2.90 310 9827 0 0.01 4 2 2.98 311 9859 0 0.03 11 2 2.88 Lt. De sits. 312 9890 0 0.01 5 1 2.96 313 9921 0 0.03 13 1 2.93 314 9953 0 0.02 7 1 2.96 315 9984 0 0.02 8 2 2.96 316 10015 0 0.03 11 2 2.96 317 10046 0 0.03 10 2 2.92 318 10078 0 0.01 6 2 2.98 319 10110 U 0.01 5 2 2.96 320 10141 0 0.01 2 2 2.91 320.1 10174 0 0 0 0 2.81 Baker CMU Slidin Sleeve 321 10177 0 0.03 13 1 2.96 321.1 10208 0 0.03 13 3 2.92 PUP 321.2 10223 0 0 0 0 N A GLM 2 Latch ®9:00 321.3 10229 0 0.02 8 ~' 2.96 PUP 322 10243 () 0.03 13 1 2.92 322.1 10275 0 0 0 0 2.75 Camco D-Ni le 322.2 10277 0 0.01 6 0 2.94 PUP 322.3 10282 0 0 0 0 2.98 Baker CSA Seal 322.4 10304 () 0.03 10 2 2.91 PUP To of 3.5" Prod. Casin 323 10314 0 0.01 5 2 2.98 _ 324 10344 0 0.01 5 2 2.93 Penetration Body Metal Loss Body Page 7 ~ i ~ ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~ - ~-~ N V Well: 2L-313 Survey Date: October 16, 2008 Field: Tam Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.51ns 9.3 ppf L-80 EUE-8RD Analyst; C. Waldrop Cross Section for Joint 162 at depth 5138.93 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 95 Tool deviation = 70 ° Finger 6 Penetration = 0.248 ins Probable Hole 0.25 ins = 98% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 Average Recor ed Metal Thickness Relative to Calibration Point 3.5" Tubing / 5.5" Production Casing Well: 2L-313 Field: Tarn Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: October 16, 2008 ^ Decrease ^ Increase 1 37 50 1585 100 3166 i i 150 4744 _ `w ~ ~ GLM 1 LL ~ .~ y 200 6355 a c v 'o p 250 7935 300 9511 GLM 2 324 10344 -50% 0 50% Change in Metal Thickness (%) Bottom of Survey = 324 Maxin~l Isolated Metal Thickness De~tions Su rtin Potent~a Pittin Dama e to the Outside of the Tubin ppo g I I g g g 3.5' Tubing ~ 5.5' Production Casing Wed: 2L-313 Field: Tam Company: ConoooPhiNips Alaska, Inc. Country: USA Survey Date: October 16, 2008 3166 3958 4744 5532 GLM 1 _ D ~ d ~ 6355 ~ 3 Z s_ ~ a _ '~ 7147 7935 8722 9511 GLM 2 324 10344 100% 0 C hange in Metal Thick ness ~%) B ottam o f Su rvey = 324 .` 100 125 150 175 Cali Is per rec olated H orded ole 200 225 in T ubing J t 162 250 275 300 ' 2L-~ Recorded Magnetic Thic~ss Log Data - 8Hz Pass 3.5" 9.3# Tubing, 5.5" 15.5# Production Casing & 7.625" 29.7# Surtace Casing ' ~wK ~~ ~~~. ~~ October 16, 2008 (1,840' to 2,040') Database File: d:\warrior\data121-313121313~2.db Dataset Pathname: 2L-313.1 ' Presentation Format: 2.2 scale Dataset Creation: Wed Oct 2216:27:30 2008 Charted by: Depth in Feet scaled 1:150 ' 0 LSPD (ft/min} -200 3.6 -50 Delta Metal Thickness (%) 50 -5.2 7.625" Casing Collar - Line S e Jt. 58 ' Delta Metal Thickness ' 1860 3.5"Tubing Collar t ' 5.5" Casing Collar 1880 ' 7.625" Casing Collar Jt. 59 ' 1 ~J00 ~~ -- ' 3.5" Tubing Collar ' Jt. 60 5.5" Casing Collar £ 1920 7.625" Casing Collar .5" Tubing Colla 1940 MTTP01 (rad) MTTP12 (rad) n_ce in Signal Noise Der ~s Possible Corrosion F 13.6 4.8 ' :t. 61 1960 5.5" Casing C ollar ' ' .5" Tubi Colla .625" Casing Collar 1 ' -3.5" Tubin Collar 1 ' 5.5" Casinc 7.625" Casin Jt. 62 1980 2000 Collar Collar Jt. 63 ' Defta Metal Thickness 020 ' 3.5" Tubing Collar ' Jt. 64 Line Spee __ ~~~,,. 0 LSPD (ft/min} X00 ' -50 Delta Metal Thickness (%) 50 1 ariance in Signal Noise Densit ~-rr -ram-Indicates Possible Corrosion PattC~~ 3.6 -5.2 MTTP01 (rad} MTTP12 (rad} 13.6 4.8 c ~7 ~.w~ .~~ S~~„ ~~ • Detail of 8Hz MTT Records (5,112' - 5,186') 98°~ Tubing Wall Penetration Recorded by Caliper Log @ 5,139' October 16, 2008 Database Files d:lwarriorldata121-313121313~3.db Dataset Pathname: 2L-313.1 Presentation Format: 2 scale Dataset Creation: Wed Oct ~~ 16:44:01 2008 Charted by: Depth in Feet scaled 1:120 -50 Delta Metal Loss (%) 50 ? MTTP01 (rad} 12 0 Line Speed (ft/min) X00 -6.8 MTTP12 (rad) 3.2 ~ a Delta Metal Thick ness Sen sor 1 Phase Shi _ i I 12 -_ I - " I 3 .5 Tubing Collar Lin e Sp _ eed e nsor 4 P hase Shift _ Jt. 162 4 5 5 " C i C ll . as n o g ar 8% Tubing Wall Penetration 5140 Recorded by Caliper 16-Oc t-08 - -- ~ 3 5" T ubin Co llar . g 5 60 1 82% Isolate d M etal Los s Jt 163 . 5" Casing Collar 5180 ,r 3.5" Tubin Colla r -50 Delta Metal Loss (%) 50 2 MTTP01 (rad) 12 0 Line Speed (ft/min) X00 -6.8 MTTP12 (rad} 3.2 `, ~~ KUP ~ 2L-313 ConocoPhillips !weu attributes _. _ _ A~.,r~...~ In _ Wdlbore llPWWI elO Name WNI Staus In 1 (RIB) Tad M 1 507032027700 TARN PARTICIPATING AREA PROD .83 6,594.65 11,140.0 C~~._..._. NtS IPPmI Dale Amaatlon EnA Dale KB-GM IRI Rlg Release Dde --- -1 vz es so zo?m SSSV: NIPPLE 150 7!1/2008 Las[ WO: _ _ 37.45 1218!1998 dc- kn»i llmatatlon DePw 1~) 6M Dda _ Arclahgon BM Dde _ Last Tag: 10,354.0 9/102008 Rev Reason: PULL PATCH 8 PUMP, TAG 91212008 Casin Strin s SttY1g BnMtg D Set DgH11 SN Depth (1VD) SItM19 Wt Stm19 t,asYg Desalpgm OD BM Pnl Top (mB) IRIBI IRKa BGsffD Cratle amgTap llaU CONDUCTOR 16 15.062 0.0 108.0 108.0 62.58 H-40 WELDED SURFACE 7 5B 6.059 0.0 2,607.0 2,299.2 29. 0 L-80 BTC-MOD PRODUCTION 5 12 4.950 0.0 10,282.0 5.308.8 1 .50 L-80 EUE-8RD PRODUCTION 312 2.992 10,282.0 11,112.0 5.758.3 9.30 L~80 EUE-8RD corvoucro s Tubin Strings Turing Desalpaon stnn9 ODIIN - Stung ID ImI T_op IR1B1 SNDepth (RKB) -- Sd Depgl l'~'DIIMBI SttNig YVt IIDSlIry Stang Grade SMng TOp TIa4 TUBING 3 V2 ~ 2.992 0.0 10,282.0 .308.8 9.30 L- EUE-8RD Other hL Hole All Jewel : 7tirbi Run 8 Retrievable, Flsh etc. T op QII(B) Descrtptlan Comment Run Dde D la4 _ 487.0 NIPPLE --~-- - CAMCO t)5 NIPPLE --~---~ 1121/1998 2.875 NIRPLE. eel 5,737.0 GAS LIFT CAMCO/KB 1/DMYANT/!/Cortment: 919/1999 2.900 _ 10,173.0 SLELl7E-0 BAKER CMU OPENED ~ 32007 1/1/2006 2.813 k" 10.223.0 GAS LIFT CAMCO/KBG29/1/DMY//.25// Comment INT LATCH IN RATHOLE, STEM & COLLET. 4118/2003 2.900 ~ ~ 10,275.0 NIPPLE CAMCO D NIPPLE 1121/1998 2.750 smFACE. _ 10,282.0 SEAL BAKER CSA 80-40 1121/1998 2.985 2.607 SSSV SSSV: NIPPLE 7f18 08 Perforations Top 1T11D) etmlTwl and Detts Top IpBI lnr1IRIBI ImBI P~1 rype gala 1~- Date conalleta 10.676.0 10.696.0 5,526.4 5,537.3 IPERF 4.0 112&1998 2-1/Z HCBH 180 DEG PH cas LCr. 5 737 10,696.0 10,716.0 5,537.3 5,548.1 IPERF 4.0 1128/1998 2-112° HCBH 180 DEG PH , - SLEEVE-O. ~ -I I 10173 GAS L FT, i 10.173 NIPPLE, 10,775 PRODVCTION, 10,282 SEAL. 10,783 -- IPERF, 10,678-10,696--- _-~ IPERF, ~ ~ _ 10.898-10,716--- ~ ' .: PRODUC710N, 11,112 m, n Leo ~~C2 ~~"°~ 21 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION !~ ~ L w ~~ ~Q(~ f REPORT OF SUNDRY WELL OPERATI~,N,~~;, ~, r=~r ,~~ .,,~ a,n~,,,,,;~A;n~, 1. Operations Performed: Abandon ^ Repair Well Q Plug Perforations ^ Stimulate ^ Otl~r.. , ,~ ~] Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhilllpS Alaska, InC. Development ~ Exploratory ^ 198-219 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20277-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 146' 2L-313 ' 8. Property Designation: 10. Field/Pool(s): ADL 380051 ~ ALK 4599 Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 11140' ' feet true vertical 5773' - feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 16" 108' 108' SURFACE 2461' 7-5/8" 2607' 2299' PRODUCTION 10136' S-1/2" 10282' 5309' PRODUCTION 830' 3-1/2" 11112' 5758' Perforation depth: Measured depth: 10676-10716 t~~/~~y~g~ JAN ~ ~ ~~C~ ~i true vertical depth: 5526-5548 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10282' MD. Packers &SSSV (type & measured depth) Seal =Baker CSA 80- 40 Seal = 10282' SSSV= NIP SSSV= 487' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation n/a n/a n/a n/a n/a Subsequent to operation n/a na n/a n/a n/a 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA contact Brent Rogers/Martin Walters Printed Name Brent Rogers Title Problem Well Supervisor Signature Phone 659-7224 Date 12/20/2007 Form 10-404 Revised 04/2004 ~~ , ai °~~ ~*~ ,i~1f~ ~ ~ ,~;;f~~ Submit Original Only • 2L-313 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/09/07 11/10/07 PULLED UPPER ER PACKER & SPACER PIPE; SNAP LATCH SEAL ASS'Y MISSING FROM SPACER PIPE. RAN LIB TO BROKEN STUB OF SPACER PIPE. IN PROGRESS. RECOVERED BROKEN SNAP LATCH SEAL ASS'Y WITH SPEAR. PULLED ER PACKER & RECOVERED 5 OF 7 METAL PACKING SPACERS FROM STINGER & BOTTOM BACKUP RING. SWEPT TBG WITH 2.75" MAGNET TO JET PUMP @ 10173' RKB, NO RECOVERY. READY FOR MTT LOG. 12/01107 SET WEATHERFORD 3-1/2" ER PACKER- PATCH LOWER ELEMENT AT 5150' 12/07/07 Summary PKR, SPACER, STINGER ASS'Y (20' x 1.75" MIN ID). ENGAGED LOWER ER PKR, P/U TO CONFIRM ENGAGEMENT, SET PKR WITH ETD TOOL. COMPLETE. Pulled and re-set 20' Weatherford retrievable tubing patch from 5130' to 5150' to run MTT log on tubing. . RECEIVED 1. Operations Performed: Abandon D Repair Well 0 . Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Ope rat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. 0 " Exploratory D 198-219 - Development 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20277-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 146' 2L-313 ," ./ 8. Property Designation: 10. Field/Pool(s): ADL 380051 ALK 4599 Kuparuk River Field I Tarn Oil Pool - 11. Present Well Condition Summary: Total Depth measured 11140' ./ feet true vertical 5773' " feet Plugs (measured) Effective Depth measured 1 0982' feet Junk (measured) true vertical 5690' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 16" 108' 108' SURFACE 2461' 7-5/8" 2607' 2299' PRODUCTION 10136' 5-1/2" 10282' 5309' PRODUCTION 830' 3-1/2" 11112' 5758' Perforation depth: Measured depth: 10676' - 10716' ~CA.NNfD SEP 1 92007 true vertical depth: 5526' - 5548' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10282' MD. Packers & sssv (type & measured depth) Seal = Baker CSA 80-40 Seal = 10282' SSSV= NIP SSSV= 487' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation 30 " 18 275 161 244 Subsequent to operation 226 63 422 896 222 14. Attachments 15. Well Class after proposed work: Exploratory D 0 -" D Copies of Logs and Surveys run _ Development Service Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowtedge. Sundry Number or N/A it C.O. Exempt: N/A Contact Bob Christensen I Bob Buchholz Printed Name Rob W. Buchholz 0 Title Production Engineering Technician Signature ~:....L~ L ~'Phone 659-7535 Date (/'cf/ol- ,ryv v"'" ., /v ~ "7.4 y . STATE OF ALASKA SEP 0 6 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION j\1 k. 01 & G C C .. REPORT OF SUNDRY WELL OPERATION5 as a I as ons. ommlSSlon Fonn ,<>404 R""','" 0412004 0 R GIN A L f!BDMS BFL SEP 1 9 1007,Át-.. h'i .A.Jr- l' -If. t> 7 ~~~> . 2L-313 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 05/07/07 Tubing Patch - 2.74" Weatherford ER Packer Mid-Element Set at 5148' md, Top of Packer at 5145.7' md 05/11/07 Set Weatherford ER Patch @ 5148' RKB w/ Weatherford ER Packer on Top (16.79' Total Length, 1.75"10) Total Patch length from 5131' to 5148' md. KRU 2l-313 TUBING (0-10282, 00:3.500, 10:2.992) SURFACE -~ (0-2607, 00: 7. 625, Wt:29.70) °ROOUCTION (0-10282, 00:5.500, Wt:15.50) Gas Lift - 'andreVOummy Valve 1 (5737-5738, 00:4.725) NIP --~ (10275-10276, 00:4.470) 10173 r 1027: 10282 I I I ' I I I I I I I I I I I I : 5249 f-ruMP 5249 SLEEVE-O 5305 NIP 5309 I. SEAL Type ~ . . Descri~ NIP CAMCO OS NIPPLE PATCH I TUBING PATCH - 2.74" WEATHERFORD ER PACKER MID-ELEMENT I SET AT 5148', TOP OF PACKER AT 5145.7' set 5/7/2007 I SET WEATERFORD ER PATCH @ 5148' RKB WI WEATERFORD ER PACKER ON TOP (16.79' TOTAL LENGTH, 1.75" 10) set 5/11/2007 2.81" CS LOCK & 3" RC JET PUMP (SER# PN1124, 9A RATIO, #9 NOZZLE. #9 THROAT set 5/3/2007 BAKER CMU OPENED 5/3/2007 CAMCO D-NIPPLE~--- BAKER CSA 80-40 ~_~_~_ 0.000 SLEEVE-O --~ (1017J.10174, 00:4.500) PUMP - (1017J.10174, 00:2.813) -..---.- 2.813 2.750 2.985 Gas Lift- andreVOummy Vaive2 (1022J.10224, 00:4.725) SEAL- (10282-10283, 00:4.000) I I IOROOUCTlON (10282-11112, 00:3.500, ----.-.-- ~~.._.._~._..~~,~,~~_._~~-~-~~.._._-~-- . . Conoc~Phillips Alaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 20, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 iq~-~'~ Dear Mr. Maunder: scJ.\NNEO SEP 0 6 2007 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the còndûêtor. 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 corrosion inhibitor/sealant was pumped between August 12-13,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. 4?t~¿ M.J. Eoveland 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 8/13/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft oal 2L-305 198-240 SF N/A N/A N/A 1.7 8/13/2007 2L-307 198-256 10" N/A N/A N/A 8 8/13/2007 2L-311 203-155 15" N/A N/A N/A 9 8/13/2007 2L-313 198-219 15" N/A N/A N/A 5.9 8/12/2007 2L-315 198-218 23" N/A N/A N/A 5.9 8/12/2007 2L-317 200-210 SF N/A N/A N/A 4.2 8/12/2007 2L-323 198-251 9" N/A N/A N/A 3.4 8/12/2007 2L-325 198-209 24" N/A N/A N/A 9.3 8/12/2007 2L-327 ··207-008 20" N/A N/A N/A 6.8 8/12/2007 2L-329 198-225 24" N/A N/A N/A 6.8 8/12/2007 p'~/C tr;)~ \\ \\ . \r-' \'0" \\ ',3 ~'---., Schlumberger ¡\PR ~; 0 200.-/ i"- r\rrlrn'~3~~(~f~. Iì~G~"scon5.'J"" SCANNED APR 252007 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ,C,Ý-dl~ Well Job# Log Description 1A-10 11638846 INJECTION PROFILE 2L-313 11628996 LDL 1 D-137 11628997 INJECTION PROFILE 2N-311A N/A U51T 2N-337B 11638852 5CMT 1J-184 11638853 5BHP 1H-10 11638844 GL5 2W-03 11649957 MEM LDLlPPROF 1 E-112 11638856 INJECTION PROFILE 1J-156 11638857 INJECTION PROFILE 1J-127 11638859 INJECTION PROFILE 1J-105 11628994 U51T 1J-164 . 11638858 INJECTION PROFILE 1J-164. 11638860 INJECTION PROFILE 04/20/07 NO. 4219 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 04/05/07 1 04/08/07 1 04/09/07 1 04/06/07 1 04/11/07 1 04/12/07 1 03/20/07 1 04/10/07 1 04/14/07 1 04/15/07 1 04/17/07 1 04/06/07 1 04/16/07 1 04/17/07 1 ( Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. t3 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. ._~._"" ,-",.j, To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTr) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) 1 Report / EDE 2) 3) 4) 5) 6) 7) 2L-313 01-Apr-07 Caliper Report sCANNED APR 1 1 2007 ,q 1r .- dl <1 .tt {L/5Cj£{ .... ..~'":" RECEIVED Signed: ~~tt--- APR 1 0 Z007 Da"'''''~<!a1.'jJ 1 ~. """ ,", ~&l1b.-1J '~~i1S~~t::!i ¡,=~:~, .r'ì;~-::>¡ Arocht,"iage Print Name: b (ìJ:, t- ì ~ IL.. V\..olw,~~ PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-89Ii1 FAX: (907)245-8952 E-MAIL: ?DSANCHORAGE@MEMORYLOG.COM WEBSITE : W\f\JW.MEMORYLOG.COM D:'Master _Copy _ 00 ]DSANC-2OxxIZ _ W ord\Dislribution\Trnnsmitta1_ Sheets\Transmit _ Original.doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. April 1, 2007 8586 1 3.5" 9.3Ib. L-80 Tubing 2L-313 Kuparuk Alaska 50-103-20277-00 Suñace 10,289 Ft. (MD) Well: Field: state: API No.: Top Log Intvl1.: Bot. Log Intvl1.: Inspection Type: COMMENTS: Co"osive & Mechanical Damage Inspection This log is tied into the "0" Nipple @ 10,275' (Dríller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The 3.5" tubing logged appears to be in good condition with respect to corrosive damage. No significant wall penetrations, areas of cross-sectional wall loss, or 10 restrictions are recorded. Minor corrosive damage in the forms of shallow pitting and shallow corrosion are recorded in a number of joints logged. The distribution of maximum - recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 17%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. I Field Engineer: K. Mí/ler Analyst: M. Tahtouh Witness: C. Fitzpatrick ProÄ.ctive Diagnostic Selvices¡ rne. l P.O. Box 1.369, Staffmd, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone (907) 659-2307 Fax: (907) 659-2314 # ICJ15-é)A ~ /I.../~<I I I I Well: Field: Company: Country: 2l-313 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 3.5 ins Weight 9.3 f Grade & Thread l-80 I I Penetration and Metal loss (0/0 wall) penetration body metal loss body I 250 200 150 100 50 0 o to 1% 10 to 20 to 40 to over 20% 40% 85% 85'110 I 1 to 10%. I o o I pene. loss I Damage Configuration ( body ) 150 I 100 I 50 o I isolated general line ring hole! poss pitting corrosion corrosion corrosÎon íble hole I o I I PDS Report Overview Body Region Analysis Surwy Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.ID 2.992 ins April 1 , 2007 MFC 24 Ext No. 40665 1.69 24 M. Tahtouh Nom. Upset 3.5 ins Upper len. 6.0 ins lower len. 6.0 ins Damage Profile ("10 wall) penetration body o o metal loss body 50 100 GlM 1 GlM 2 Bottom of Survey = 322.3 Analysis Overview page 2 I I I I Correlation of Recorded Damage to Borehole Pipe 1 3.5 in (0.3' - 10282.0') Well: Field: Company: Country: Survey Date: 2l-313 Kuparuk ConocoPhillips Alaska, Inc. USA April 1 , 2007 I I I Approx. Tool Deviation Approx. Borehole Profile I 50 28 I 1576 I 100 3158 I I 150 4738 W GlM 1 .,.J E lL. ;:¡ C z 200 6351 ..s::: ..- õ.. c ·õ ;¡¡ 0 250 7932 I I I 300 9511 I ClM 2 322.3 o 50 10282 100 I Damage Profile ('Yo wall) / Tool Deviation (degrees) I I Bottom of Survey = 322.3 I I I PDS REPORT JOINT TABULATION SH I I Pipe: Body Wall: Upset Wall: Nominall.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Coun try: Survey Date: 2L-313 Kuparuk ConocoPhillips Alaska, Ine. USA April 1, 2007 I I Joint Jt. Depth l'el1 Pen. Perr :\111' tal Min. Damage Profile No. (Ft.) 'I Body !.D. Comments wall) ) (Ins.) (Ins.) 0 50 100 .1 0 0 0.01 4 1 2.92 PUP III .2 3 0 0.03 11 3 2.87 PUP .3 11 0 0.02 13 2 2.93 PUP .4 19 0 0.D2 1) 2 2.89 PUP 1 28 0 0.03 1/ I 2.92 U. Deoosi ts. 2 58 1 0.02 1) I 2.92 pili 3 90 0.03 11 I 2.91 Shallow nitlinQ. pili 4 121 0.02 9 I 2.91 pili 5 153 0.03 111 1 2.90 Shallow oittinll. U. Deoosits. 6 185 0.03 10 1 2.90 7 217 () 0.03 1( I 2.92 pi! 8 248 0 0.04 1 2.91 Shallow oittinlZ. pi! 9 280 II 0.03 1 2.90 Shallow oitting. pi! 10 312 0 0.03 I 2.92 i 11 343 0 0.04 1 2.90 Shallow oittim!. U. Deoosits. 12 375 0 0.03 I 2.91 13 407 ( 0.04 I 2 2.91 Shallow oittin2. U. Deoosits. 14 439 I 0.03 11 2 2.91 Shallow oittin2. 14.1 470 0 0 0 0 2.88 DS NIPPLE 15 472 0 0.04 15 3 2.92 Shallow oiWml. U. Deoosits. 16 503 0 0.03 11 2 2.91 Shallow oittim;¡. U. Deposits. 17 535 0 0.03 10 " 2.92 ¡ 18 567 0.03 I 2 2.92 Lt. Denosits. pi! 19 598 1 0.02 9 I 2.92 20 630 ( 0.04 4 I 2.92 Shallow niuinQ. Lt. Deoosits. 21 662 0.03 1 1 2.91 Shallow oittin2. Lt. DeDosits. 22 693 0 0.03 0 0 2.92 pi! 23 724 0 0.03 11 I 2.91 Lt. DeDosits. pi! 24 756 I 0.03 2 2.92 Shallow Dittin2-. pi! 25 787 I 0.03 I 2.92 Shallow pitting. Lt. Deposits. pi! 26 818 0 0.03 ì 2.90 Shallow Dittim;¡. Lt Deoosits. pi! 27 850 I 0.04 I 2.91 Shallow Ditting. 28 881 I 0.03 'I 2.92 29 913 ( 0.03 13 1 2.91 Shallow oittin\!. Lt Deoosits. 30 945 ( 0.D2 9 I 2.91 31 976 0 0.02 9 I 2.91 32 1008 0 0.03 1 1 2.91 33 1040 0 0.02 (J 1 2.90 34 1072 0 0.03 10 ^J 2.92 Lt. Denosits. ~ 35 1102 0 0.04 IS 1 2.91 Shallow oittim!. 36 1134 0 0.04 1') 1 2.91 Shallow oinin\!. ~ 37 1166 0 0.03 11 ¡ 2.90 Lt. DeDosits. 38 1197 0 0.03 II ¡ 2.91 39 1229 0 0.03 1 1 2.91 40 1261 0 0.03 2 1 2.90 pi! 41 1292 0.03 ¡ 1 2.90 JC 42 1324 ( 0.02 I 2.91 JC 43 1356 0.03 2 I 2.92 U. DeDosi ts. 44 1386 0.03 2 I 2.92 45 1418 0 0.03 13 I 2.91 Shallow Dinin\!. U. DeDosits. III! I I I I I I I I I I I I Penetration Body Metal Loss Body Page 1 I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2L-313 Kuparuk ConocoPhiliips Alaska, Ine. USA April 1, 2007 I I Joint Jt. Depth Fe' Pen. Fe: ¡"''¡elal Min. Dam age Profile No. (Ft.) .[ Body !.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 46 1450 () 0.Q3 12 II 2.90 Shallow oitlinll. Lt. Deoosits. 47 1481 () 0.04 15 ¡ 2.91 Shallow oittinll. 48 1513 0 0.03 13 ! 2.89 Shallow oittinll. !fIí! 49 1545 0 0.03 12 I 2.89 I.t. Deoosits. "* 50 1576 0 0.03 1 1 2.91 Lt. Denosits. ~ 51 1608 0 0.03 1 2.89 ~ 52 1640 0 0.03 :> 2.91 Shallow nittinl!!. !l" 53 1671 0 0.Q3 I 2.92 Shallow nittinl!!. 54 1703 0 0.03 I 2.91 55 1734 0 0.Q3 I 2.92 56 1766 () 0.03 I I 2.92 Shallow oittinl<. 57 1798 () 0.04 1 1 2.91 Shallow oittimL 58 1R2t} () 0.03 1 I 2.91 Shallow oittinl<. 59 1861 0.03 1 m Shallow oittimz. 60 1893 I 0.03 I 61 1924 ! Jt§i I Lt. Denosits. 62 1956 : 2.92 63 1988 0 0.04 15 Shallow nittinll. C 64 7019 () 0.04 1'1 I 2.92 Shallow oittinl<. 65 2051 () 0.02 7 1 2.91 66 2082 () 0.03 1 1 2.91 !l" 67 2114 () 0.04 1· ~¡ 2.91 Shallow oittim¡¡. ~ 68 2145 () 0.03 1 I 2.90 Shallow nittinq. !l" 69 2177 0 0.03 1 I 2.90 !l" 70 2209 0 0.03 1 I 2.90 71 2240 0 0.03 1 1 2.91 Shallow oittin\!!:. U. Deoosits. ¡¡¡iI 72 2271 0 0.02 q I 2.90 73 2303 0 0.02 q I 2.92 74 2333 () 0.03 1 2.90 Shallow oittin\!!:. Lt. Deposits. 75 2365 0 0.04 I 2.91 Shallow pittim¡¡. 76 2397 0 0.04 I 2.92 Shallow níttinq. 77 2429 () 0.Q3 1 2.91 78 2460 1 0.03 ¡ 2.93 Shallow oittinll. 79 2492 11 0.03 13 I ~ Shallow oittin\!!:. 80 2524 I 0.04 Shallow oittin\!!. 81 2556 ¡ 0.03 Shallow pitting. 82 2587 ! 0.04 2.96 Shallow pitting. 83 2619 0.03 2.93 Shallow corrosion. 84 2651 0.04 1, 2.92 Shallow corrosion. 85 2683 0.03 1 2.93 Shallow nittin\!. iii!! 86 2714 0.03 1 2.89 Shallow nittimI. 87 2746 0 0.04 14 1 2.92 Shallow oittin\!!. Lt. Deoosits. IIIiIfII 88 2778 0 0.04 14 1 2.92 Shallow oittin\!. IIIiIfII 89 2809 0 0.03 12 Î 2.91 II!! 90 2841 () 0.03 1 I 2.91 II!! 91 2873 () 0.03 I. I 2.92 Shallow corrosion. Lt Deposits. II!! 92 2904 U 0.04 I' 4 2.92 Shallow corrosion. !" 93 2936 0 0.D3 1( 2 2.92 94 2968 U 0.ü2 9 I 2.93 95 3000 0 0.03 13 1 2.92 Shallow oíttín\!. II!! I I I I I I I I I I I I I Page 2 I I I REPORT INTTABULATION SH I I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2L-313 Kuparuk ConocoPhillips Alaska, Inc. USA April 1, 2007 I I Joint jt. Depth Pen. Pen. Pen. Mel.al Min. Damag e Profile No. (Ft.) el Body I.D. Comments (% wall) Ilns.) (Ins.) (Ins.) 0 50 100 96 3031 I 0.03 I 2.92 Shallow nitting:. Lt. Deoosits. 97 3063 I 0.03 ¡ TIt! 98 3095 I 0.03 I 99 3127 I 0.03 1 2.93 Lt. Denosits. \III 100 3158 0 0.04 14 2 2.92 Shallow oitting:. Lt. De oosits. \III 101 3190 () 0.04 14 I 2.91 Shallow corrosion. 102 3222 II 0.03 1 I 2.91 \III 103 3253 II 0.03 1 2.93 \III 104 3285 II 0.04 I 2.93 Shallow corrosion. Lt. Deoosits. \III 105 3317 iJ 0.03 I 2.94 Shallow nittíng:. \III 106 3348 0 0.04 I 2.91 Shallow nitting:. Lt. Deoosits. \III 107 3380 () 0.03 I 2.91 \III 108 3412 0 0.03 I 1 2.90 109 3444 0 0.03 1 I 2.90 110 3475 II 0.03 I 2 2.91 Shallow oittimz. Lt. DeDosits. 111 3507 0 0.03 1 1 2.92 112 3538 iJ 0.03 1 ~¡ 2.92 Shallow Ditting. Lt. Deoosits. 113 3570 ( 0.04 ;: 2.92 Shallow corrosion. iii 114 3602 ( 0.03 1 2.91 115 3634 ( 0.04 1 2.93 Shallow corrosion. Lt. DeDosits. !III 116 3665 ( 0.04 I 2.91 Shallow corrosion. Lt. DeDosits. !III 117 3697 0 0.03 1'1 1 2.92 Shallow nitting:. U. Deoosits. !III 118 3729 0 0.03 13 1 2.92 Shallow Ditting. U. Deoosits. 119 3760 0 0.03 12 I 2.93 Shallow corrosion. III 120 3792 () 0.03 1 ;: 2.94 Shallow Dittin\!. III 121 3824 0 0.03 1 2.91 !III 122 3855 0 0.03 ;: 2.92 Shallow corrosion. " 123 3887 II 0.04 I 2.89 Shallow corrosion. Lt. Deposits. !III 124 3919 () 0.03 2.92 !III 125 3950 0 0.04 LS±J 2.92 Shallow DiUím:!. III 126 3982 0 0.03 121 2.91 Lt Deoosits. III 127 4014 () 0.03 1 1 2.91 III 128 4045 II 0.04 IL ¡ 2.93 Shallow oitting. III 129 4076 () 0.04 ¡ 2.90 Shallow oittim;¡. 130 4107 \) 0.03 1 2.93 .. 131 4139 \) 0.03 I 2.90 Lt. Deoosits. .. 132 4171 \) 0.03 I 2.92 .. 133 4203 0 0.02 a I 2.92 .. 134 4234 0 0.04 14 4 2.91 Shallow nittin\!. 135 4264 0 0.03 i~ H 2.91 Shallow oittim:!. .. 136 4295 0 0.03 2.91 III 137 4327 0 0.04 2.92 Shallow corrosion. III 138 4358 \) 0.04 ~¡ 2.92 Shallow corrosion. Lt. Deposits. III" 139 4390 0 0.04 J 2.91 Shallow corrosion. .." 140 4422 0 0.04 I 2.92 Shallow nining:. .." 141 4453 0 0.03 2 3 2,92 Shallow corrosion. Lt. Deoosits. I!I 142 4485 () 0.04 1 2.91 Shallow oitting,. Lt. DeDosits. 143 4517 0 0.04 1 2.90 Shallow oittin\!. III" 144 4548 n 0.04 I ;: 2.92 Shallow corrosion. Lt. Deoosits. .." 145 4580 0 0.04 ) I 2.90 Shallow corrosion. Lt. Deposits. ." I I I I I I I I I I I I Body Metal Loss Body Page 3 I I I I PDS REPORT JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 21-313 Kuparuk ConocoPhii!ips Alaska, Inc. USA April 1 , 2007 I I Joint Jt Depth Pen. Pen. Pen. [ ¡\¡l('tal Min. Damag e Profile No. (Ft.) (~:::(;t Body I.D. Comments (% wall) (Ins.) (Ins.) 0 50 100 146 4612 U 13 " 2.92 Shallow nittin<>. Lt. Denosits. IIIJ I F! 4643 U I 0.04 15 II 2.93 Shallow niHint>. U. Denosits. IIIJ 4675 Ii 0.03 11 tl§ U. Denosi ts. 4707 Ii 0.03 13 'I w nittin<>. 150 4738 n 0.03 11 2 2. Shallow oiUin2. P 151 4770 ( 0.02 9 {) 2.92 fMI 152 4802 ( 0.03 1 ., 2.91 Shallow oittin2. fMI ¡ 153 4834 0.03 2.91 Lt. Deoosits. 154 4865 0.03 I 2.91 . 155 4897 0.04 1 2.90 Shallow corrosion. III 156 4927 () 0.03 3 "1 2.91 Shallow nittinO'. U. Denosits. ro 157 4958 () 0.03 3 ! 2.90 Shallow nittint>. It. Denosits. ro 158 4990 H 0.03 13 2.90 Shallow nittinq. Lt. Denosits. 159 5021 0.02 9 I 2.91 160 5053 0.03 13 ) 2.91 Shallow nittin2. Lt. Deoosits. !III 161 5083 Ii 0.04 Fi ;> 2.90 Shallow nittín2. !III 162 5115 Ii 0.04 =*= I 2.92 Shallow oittim.z. ro 163 5146 () 0.03 I 2.91 !III I 1(,4 5178 0 0.04 1 2.91 Shallow nittinO'. !III 165 5210 )1 0.03 13 "5 2.91 Shallow corrosion. Lt. Denosits. III 166 5242 () 0.03 it OJ 2.91 Shallow nittin<>. Lt. Denosits. 167 5273 Ii 0.03 1 2.91 !íIí 168 5305 Ii 0.04 2.89 Shallow oittin2. !íIí 169 5337 n 0.03 2.89 Shallow oittim2. Lt. Deoosits. !III 170 5368 () 0.03 7.89 !III 171 5400 () 0.ü3 2.91 ro 172 5432 () 0.03 I 2.90 U. Denosits. 173 5463 { 0.04 I 1 2.89 Shallow nitti0l2. 174 5495 ! 0.04 I· I 2.90 Shallow oittin2. Lt. Deoosits. 175 5527 ! 0.03 H I 2.90 176 5558 ( 0.03 1 2.89 Shallow oittim2. 177 5590 0.03 1 2.90 Shallow oittin2. 178 5622 0.02 I 2.89 U. Denosits. III 179 5653 0 0.03 2 ;> 2.88 180 5685 0 0.03 0 1 2.91 ro 180.1 5717 0 0.02 {3 /1 2.92 PUP , 180.2 5731 [) 0 () ¡y N/A GLM 1 (Latch @ 2:301 180.3 5738 Ii 0.04 I' 4 2.91 PUP Shallow oittin2. !!!! 181 5752 0.04 1 2.90 Shallow oitti02. U. Denosits. III II! 182 5784 0.03 2 2.91 Shallow corrosion. III 183 5816 0.03 1 7 q1 I Shallow oittím2. III 184 5847 0.03 1 2.91 Shallow corrosion. U. DeDosi ts. 185 5879 0.04 ) 2.92 Shallow corrosion. ~ 186 5910 [) 0.02 9 1 2.88 Lt. Deoosits. 187 5942 0 0.04 1 2.89 Shallow corrosion. Lt. Deoosits. 188 5974 n 0.04 1 2.89 Shallow oittio2. 189 6005 () 0.03 1 " 2.90 190 6037 C 0.03 1 '1 2.90 Lt. Deoosits. 191 6067 0 0.ü3 1 " 2.91 Lt. Deoosits. 192 6099 0 0.ü3 12 1 2.90 U. Deoosi ts. I I I I I I I I I I I I Body Metal Loss Body Page 4 I I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: NominaILD.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2 L-313 Kuparuk ConocoPhillips Alaska, Inc. USA April 1 , 2007 I I Joint Jt Depth I'Pi Pen. Pen. ~ii'tiif Min. Damag e Profile No. (Fl.) Body 1.0. Comments (% wall) (Ins) (Ins.) (Ins.) 0 50 100 193 6130 () 0.04 14 1 2.90 Shallow corrosion. Lt Denosits. 194 6162 () 0.03 13 " 2.91 Shallow corrosion. 195 6193 0 0.04 14 1 2.90 Shallow corrosion. 196 6225 0 0.03 I 1 2.89 Shallow corrosion. 197 6257 ( 0.03 1 ( 2.89 Shallow oiWnQ. III 198 6288 ( 0.03 1 2.89 Shallow oittinQ. Lt Deoosits. III 199 6320 ì 0.03 I 2.88 III 200 6351 0.02 ¡ 2.93 201 6384 0 0.03 ¡ 2.91 !II 202 6415 () 0.03 ] I 2.90 !II 203 6447 0 0.02 ) 2.89 !II 204 6479 0 0.03 ¡ ~¡ 2.89 !II 205 6510 () 0.03 13 ) 0:::>R 7 Shallow corrosion. Lt Deoosits. 206 6542 ¡ 0.03 ¡ "1 2.90 Shallow nittìn<>. U. Dennsits. 207 6574 í 0.03 1. 1 2.89 Shallow corrosion. Lt Deoosits. 208 6605 í 0.03 1 ) 2.91 Shallow corrosion. U. Deoosits. 209 6637 0.03 1 1 2.91 Shallow corrosion. U. Deoosits. 210 6669 0.03 1 I 2.89 Shallow corrosion. 211 6700 () 0.03 1 } 2.90 Shallow corrosion. 212 6732 0 0.03 13 ) 2.91 Shallow nittin<>. Lt Denosits. 213 6763 0 0.03 13 ¡ 2.86 Shallow corrosion. U. Deoosits. 214 6795 0.03 ¡ ) 2.89 !II 215 6827 0.03 I 2.88 Shallow corrosion. !II 216 6859 0.03 2.88 Shallow corrosion. Lt. Deoosits. 217 6890 0.04 2.89 Shallow corrosion. ! t Denosits. IiI 218 6922 0 0.03 2.89 Shallow nittin\!. U. Deoosits. 219 6954 0 0.03 2.91 220 6985 0 0.03 12 1 2.89 Shallow nittinQ. Lt. Dennsits. 221 7017 0 0.04 5 ..¡ 2.88 Shallow nittinQ. Lt Denosits. 222 7049 0 0.04 14 I 2.88 Shallow nittinQ IiI 223 7081 í 0.04 I 2.90 Shallow nittinQ. 224 7112 í 0.02 I . :2 2.92 225 7144 í 0.03 1 1 2.93 ¡ 226 7175 ì 0.02 I 2.92 227 7208 ( 0.03 ~! 21t Shallow corrosion. U. Denosits. 228 7240 0 0.03 13 ¡ 2. Shallow nitting. 229 7271 0 0.03 12 oJ 2. 7303 0 0.03 ) 2.88 I t. DenosÎ ts. ~ 7334 í t&&t 1 I 2.88 Shallow corrosion. U. Denosits. 23 7365 ( I I 2.90 Shallow corrosion. U. Deoosi ts. 233 7397 í 0.04 ¡ ) 2.89 Shallow corrosion. 234 7428 ì 0.04 I ) 2.88 Shallow corrosion. U. Deoosits. 235 7459 ( 0.03 I 1 2.88 Shallow nittìn<>. 236 7491 0 0.03 13 :; 2.90 Shallow nittínQ. 237 7522 ¡ 0.03 I I 2.90 Shallow nittin<>. 238 7554 í 0.03 :2 2.90 Shallow corrosion. 239 7586 ì 0.04 I 2.89 Shallow oittìml. 240 7617 ¡ 0.03 "j 2.88 ~ 241 7649 0 0.04 ) 2.87 Shallow nittin<>. ~ 242 7681 0 0.03 12 ") 2.89 ~ I I I I I I I I I I I I Body Metal Loss Body Page 5 I I I I PDS REPORT JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2 L- 313 Kuparuk ConocoPhillips Alaska, Inc. USA April 1, 2007 I I Joint Jt Depth F\ Pen. Pen. ¡\¡\etal Min. Damag e Profile No. (Fl.) 'I Body I.D. Comments (% wall) .) (ins.) (Ins.) 0 50 100 243 7712 n 0.03 ¡ 1 .) 2.88 244 7743 0 0.02 ') ) 2.89 tf~ 7775 n 0.04 !'i 1 2.90 Shallow corrosion. 7808 0.02 1 2.93 71n9 0.03 2.92 248 7870 0.02 2.86 It. Deoosits. 249 7900 0.02 2.88 250 7932 0.02 J 2.85 It. Denosits. 251 7963 0 0.02 J 1 2.93 252 7994 0 ~ I 2.91 253 8026 n 1 2.91 254 8058 n 0.03 ;) 2.86 Shallow corrosion. 255 8089 ¡ 0.031 ) 2.89 Shallow corrosion. 256 8121 0.03 1 ;; 2.89 Shallow corrosion. Lt. Deoosits. 257 I'll <:;1 ¡ 0.03 I 2.94 258 8185 ' ( 0.02 ) 2.91 259 8216 0 0.03 13 -:; 2.87 Shallow nittínº. 260 8247 n 0.03 I) -:; 2.84 261 8279 n 0.02 B ;) 2.91 262 8310 n Wt± 3 2.89 Shallow oHtinº,. 263 8342 n j1f Lt. Deoosits. 264 8373 n 0.02 265 8405 0 0.02 2.86 266 8436 0 0.03 13 1 2.85 Shallow corrosion. 267 8469 0 0.03 12 "1 2.87 268 8500 0 0.03 2 .? 2.87 269 8531 0 0.D2 .) 2.90 Pi ttinº,. 270 8563 ( 0.03 2.86 Shallow oilling. 271 8594 n )'i 0.02 2.9~[ Pitting in uoset 272 8625 0.03 2.86 Shallow corrosion. 273 8658 0.02 2.90 274 8690 0.02 I 2.91 275 8721 0 0.02 ) 2.92 276 8753 0 0.02 ') ) 2.87 277 8783 0 0.04 !4 ") 2.85 Shallow corrosion. 278 8814 0 0.04 i4 I 2.87 Shallow corrosion. Lt Deoosits. I 279 8845 0 0.03 11 2.83 Lt. Denosi ts. 280 8878 ow, 0.02 n I 2.90 Pittinl! in unset. 281 8909 0 0.02 ') 2.90 282 8941 0 0.04 '1 2.89 Shallow corrosion. 283 8973 0 0.03 11 2.89 284 9005 0 0.02 ') ) 2.87 285 9036 0 0.02 1 2.91 286 9068 0 0.02 2.90 287 9099 0 0.02 2.90 288 9131 0 0.02 2.88 289 9162 0 0.02 2.91 290 9194 II 0.03 13 2.86 Shallow nittinQ. 291 9226 0 0.03 13 2.86 Shallow oíttilw. 292 9258 0 0.02 ß ) 2.91 I I I I I I I I I I I I Body Metal Loss Body Page 6 I I I I PDS REPORT JOINT I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2L-313 Kuparuk ConocoPhillips Alaska, Inc. USA April 1, 2007 I Joint Jt. Depth !'e: Pen. Pen. ¡"'k'lal Min. Damag e Profile No. (Ft.) ,( Body 1.0. Comments (% wall) (Ins) (Ins.) (Ins.) 0 50 100 293 9289 n 0.D3 2.90 294 9321 n 0.03 2.91 295 9352 n 0.04 2.85 Shallow nittinQ. =lli= 9384 n 0.03 2.90 Shallow nittinQ. 9415 0 0.02 2.90 298 9448 n 0.03 i 2.89 Shallow corrosion. 299 9479 ()~ 2.86 Shallow corrosion. U. Deoosits. 300 9511 0 2.90 Shallow oittim!. ~ 9542 n 0.03 2.86 Shallow corrosion. 9574 n O'i 0.02 2.88 in uoset. 9605 ( 0.D3 I 2.86 304 9637 ( 0.02 ii 2.88 305 9668 ( 0.04 'ì 2.85 ittinQ. 306 9701 ( 0.02 :¡ 2.91 307 9732 0 0.03 10 2 2.89 308 9763 0 0.04 1'ì 4 2.82 Shallow oitting. 309 9795 n 0.03 I I 2.87 Shallow oittim!. 310 9826 ( 0.03 2.88 U. Deoosits. 311 9857 I 0.02 2.89 I 112 9889 ( 0.02 2.90 313 9920 ( 0.03 i 2.82 Shallow niWnQ. Lt. DeDosits. 314 9951 n 0.04 1 i 2.85 Shallow corrosion. ~ 315 9984 n 0.02 q 2 2.83 316 10014 0 0.04 15 2 2.87 Shallow corrosion. ~ 317 10046 ( 0.03 I (I 2 2.89 318 10077 ( 0.04 5 'j 2.86 Shallow corrosion. j 319 10110 ( 0.02 2.90 320 10141 ( 0.02 2.89 320.1 10173 ( 0 2.81 SLIDING SLEEVE 321 10177 0 0.03 2.90 II! 321.1 10208 n 0.03 1 2.90 PUP 321.2 10219 0 0 0 0 N/A GLM 2 (Latch @ 9:(0) 321.3 10230 ( 0.04 1 2.87 PUP Shallow oiUing. III" 322 10244 ( 0.03 J 2.92 322.1 1027'1 ( 0 2.75 D NIPPLE 322.2 1 02 77 I. 0.02 2.87 PUP 322.3 10282 ( 0 ( N/A PACKER I I I I I I I I I I Body Metal Loss Body I I I Page 7 I I I I I SURFACE (0-2607, 00:7.625, Wt:29.70) I I I , RODUCTION (0-10282, 00:5.500, Wt1550J I I SLEEVE-O (10173-10174, 004.500) PUMP (10173-10174, 002.813) I I GasLiit andrei/Dummy Val\¡¡¡ 2 (10223-10224, 004.725) I I I NIP (10275-10276, 00 :4470) I I I SEAL (10282-10283, 004.000) I ) RODUCTION I (10282-11112, 00:3.500, I KRU 2L-313 o o 9/9/1999 4118/2003 (I) 2.875 0.000 Ç) 11/10/06 Sc~luIIIbepg. NO. 4034 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth NOV 1 3 2006 B, (~~~ (~!\\, (~mÎssion A¡:¡~~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 / 00 - dl ~ Kuparuk Field: Well Job# Log Description Date BL Color CD 1 R·26 11416225 INJECTION PROFILE 10/23106 1 1 R-22A 11416224 PROD PROFILE WIDEFT 10/22/06 1 2K.28 N/A INJECTION PROFILE 10/19/06 1 3G-09 11415642 PROD PROFILE W/DEFT 10/24/06 1 3G~16 11416226 INJECTION PROFILE 10/24/06 1 2P.-427 11415637 INJECTION PROFILE 10/20/06 1 2P-429 11415640 INJECTION PROFILE 10/22/06 1 1J·101 11445123 GLS 11/06/06 1 2~-432 11415644 INJECTION PROFILE 10/26/06 1 3G-09 11415645 PROD PROFILE W/DEFT 10/27/06 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFILE WIDEFT 11/05/06 1 1 R-19A 11416228 INJECTION PROFILE 10/27/06 1 3J·05 1141630 INJECTION PROFILE 10/28/06 1 1 D-04 11445121 PROD PROFILE W/DEFT 11/04/06 1 30-07 11416222 INJECTION PROFILE 10/20/06 1 2N~305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GLS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1 2L:-313 11445119 FLOWING BHP SURVEY 11/02/06 1 2Kr27 11416234 FLOWING BHP SURVEY 11/02/06 1 2l-307 11296734 FLOWING BHP SURVEY 11/04/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Re: Jet Pumped Wells Subject: Re: Jet Pumped \Vells From: "NSK Problem Well Supv" <n 1617@eonoeophillips.com> Date: Sat, 7 Dee 2002 14:07:01 -0900 To: Tom tvlaunder <tonl nlaunder(Q)adn1in.state.ak.us> - "--' CC: "nI617" <nI617@conoeophillips.eom> Tom: I requested a list of surface powered jet pump wells from our PE's. The following should be the current total for the Kuparuk area: vJest Sak wells: 1C-123 (PTD 2010840) was recently S1 for high watercut 1C-135 (PTD 2012200) is a huff and puff well and was recently put on water injection cycle CPF 2 are as follows: 2L-307 (PTD 1982560) ~ 2 L - 313 (PTD 1982190) 2L-315 (PTD 1982180) 2L-321 (PTD 1982620) 2L-325 (PTD 1982090) 2N-303 (PTD 2001690) 2N-304 (PTD 2011300) 2N-305 (PTD 2001350) 2N-318 (PTD 2001000) 2N-319 (PTD 1981970) 2N-332 (PTD 2000790) 2N-337 (PTD 1981220) 2N-339 (PTD 1981000) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. 1 hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder < tCom mallndE:rl'~\admi n . state. ak. us> 12/06/2002 09:00 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Jet Pumped Wells Pete and or Jerry, 1 have some emails f h'l b rom aWl e ack regarding the wells out there on jet pumps. Would lOU please provide an updated listing of the wellE presently on jet pumps in greater KRU?? Thanks in advance. To r i p • ' . . ' ' ' '''''' ' ' ' ' • d f , 4,,::::: '',.. ',, .,' ' , '::: '_...., 7_,,,,,,f,.,,,,,l,,,:,,,,:-, , ', --',.•.''',',':,1_- .i .... . . . ter y k « � ^F s ,x 'ga , . � � fi x , a �� s a f t � � ! > +tip } FxL S.`�9ky,2'.ywr 3 • MIC ?/30/02 DO NOT PLACE ANY NEW MATERIA 1 UNDER THIS PAGE Saved as MJweep marker.doc I '\ 1~1~: Casing Detail 7.625" Surface Casing ¡q8-JJq WELL: TARN 2L-313 DATE: 11/14/98 1 OF 1 PAGES \ ~ ARCa Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RKB to LR = 28.50' TOPS Above RKB 7 5/811 Landing Joint 28.50 FMC GEN V- Prudhoe 7 5/811 Csg Hgr 2.50 28.50 jts. 39-61 75/811,29.7#, L-80 BTC-mod(23 jts) 973.13 31.00 TAM 7 5/811 Port Collar 2.47 1 004.13 its. 3-38 75/8",29.7#, L-80 BTC-mod (36 its) 1517.07 1006.60 Gemeco Float Collar 1.31 2523,,67 its 1-2 7 5/811, 29.7#, L-80 BTC-mod(2 its) 80.99 25'24.98' Gemeco Float Shoe 1.47 2605.97 Casing shoe @ 2607.44,./ f /' ,.' T.D. @ 2617' leavina 10' of rathole . v"" 29 Gemeco Bow Sprina CENTRALIZERS Run centralizers in center of Jts. .1.2. 38. 39. over stop collars and over casing collars on Jts. 3-14 and over collars of its. 17,20,23,26,29,32,36,42,45,48,51,54,57. Joints 62 - 71 (10 joints) will remain in the pipe shed. Remarks: String Weights with Blocks: 75K Up, 68K On, 12k Blocks. Ran 61 joints of casing. Drifted casing with 6.75011 plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 ~CANWE\D Mj~R 1. 5 2.00¿\ Drilling Supervisor:D. P. BURLEY ...1It.. ~" ARCO AI k C f D 1 as a, nc. ernen Ing etal s Well Name: 2L-313 Report Date: 11/14/98 Report Number: 3 Ria Name: DOYON 141 AFC No.: AK9429 Field: Tarn Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 7-518" 9.7/8" 2607 2524 Centralizers State type used. inteNals covered and spacing Comments: Detailed on casing talley Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 10.4 /10.2 31 21 24 14 Gels before: Gels after: Total Volume Circulated: 10122 5/8 1100 Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 bbls 8.5 Spacer 0 Type: Volume: Weight: Comments: ARCO 40 /\ 10.5 Lead Cement 0 Type: Mix wtr temp: r~Of s~'s: Weight: Yield: Comments: ASIIILW 70 ,.280 10.7 4.43 Additives: "'---7\ standard blend \ Tall Cement 0 Type: Mix wtr temp: r~f S~1 Weight: Yield: Comments: G 70 230 15.8 1.17 Additives: \...../ 1 % S1, 0.2% D46, 0.3% D65 Dlspl¡¡cement 0 .' Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: Còrnrnents: 8bpm 8bpm 75 " Reciprocation length: Reciprocation speed: Str. WI. Down: 25 10 fpm 68 Theoretical Displacement: Actual Displacement: Str. WI. in mud: 115.8 bbls 116.6 bbls Calculated top of cement: ,./~P: Bumped plug: Floats held: Returns to surface /' Date:1 -14-98 yes yes Time:21 'Js5 hrs. R'm"k,,,One .lagejob with Tam port ,01'" ,onl(9on",. 37 1~ 7 ppg "menl "tu.., 10 ,urta". Cement Company: Rig Contractor: Approved By: DS DOYON D.P.BURLEY ...... ~~ ARCa Alaska, Inc. Daily Drilling Report AFC No, I Date RptNo IRi9 Accept - hrs Days Since AccepUEst: 1.9/3 Rig Relase - hrs: AK9429 11/14198 3 11/13/9802:00:00 AM Well: 2L.313 Depth (MDnvD) 2617/2301 Prev Depth MD: 2336 Progress: 281 Contractor: DOYON Daily Cost $ 248036 Cum Cost $ 451541 Est Cost To Date $ 4425000 Rig Name: DOYON 141 Last Csg: 7-5/8" @ 2607" Next Csg: 3-1/2" x 5-1/2" @ 11251' Shoe Test: Operation At 0600: Testing BOPE. Upcoming Operations: MU BHA #2, test casing, LOT, drill 6-3/4" production hole. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO, BIT NO, INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 2617 1 N TST 11/10/98 11/13/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 10.2ppg 70 9.875 10/28/98 11/09/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 56sqc 80 HTC N SPACE 10/31/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 21/14 60 MX1 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1485 5/8/ 10 V12YD APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1000 6.2 20 2617 11/13/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 100 ml/30 min 2500 108 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 12% 2000 2509 2L-329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 8 102bbl 2900 III 7.1/2.9 / 2L-313 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 5 20 1121 I 30 - 40 - 2.3 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 0° 8.5 61611 90 - 163 500 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 3.80 10% 70170 II 0.595 Water Base Muds 1152 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 50 294129411 10 115115 115 I I 11111 45 Diesel 110 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $7034 III 8747 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $33662 III 1121WTIA III 1307 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 13 BAROID III E II I NO I TD III 8442 PERSONNEL TOTAL 46 TIME I '.'.'ENp HOUR.s I OPS CQDE I HOLE SECT 'IPHASEOPS I ,.." OPERATIOf\jS FROM 0000 ~ 0000 " '., 12:00 AM 03:30 AM 3.50 DRIL SURF Making Hole PJSM. Drill from 2236' to 2617', ART=0.8 hrs, AST-0.7 hrs. 03:30 AM 04:30 AM 1.00 CIRC SURF Making Hole Pump high vis sweep and clrc clean, monitor well, pump dry job. 04:30 AM 08:30 AM 4.00 WIPERTRP SURF Making Hole Wiped hole to 370', worked tight spot from 1436' to 1655'. 08:30 AM 10:00 AM 1.50 CIRC SURF Making Hole CBU, max gas 1250 units, Pump high vis sweep and circ hole clean. Monitor well, pump dry job. 10:00 AM 11 :00 AM 1.00 TRIP_OUT SURF Making Hole POH, no problems. 11:00 AM 01 :30 PM 2.50 BHA SURF Making Hole Laid down dc's, mwd and motor, cleaned rig floor. 01 :30 PM 02:30 PM 1.00 CASG SURF Casing and Rig up GBR casers, held safety and operations meeting Cementing with crews. 02:30 PM 05:00 PM 2.50 RUN_CSG SURF Casing and Run 7-5/8" casing, MU landing joint and cement head. Cementing 05:00 PM 07:30 PM 2.50 CIRC SURF Casing and Stage pumps up to 8 bpm and conditon mud for cementing. Cementing Held safety meeting with crews. 07:30 PM 10:00 PM 2.50 CMT_CSG SURF Casing and Performed single stage cement job as per program. Had 30 Cementing bbls of 10.7 ppg cement retuns to surface. Plugs bumped / floats held. Flushed surface lines and equipment & laid down landing joint and cement head. 10:00 PM 12:00 AM 2.00 NU_ND SURF Casing and NO Divertor system. Cementing 24.00 Supervisor: D.P.BURLEY Daily Drilling Report: 2L-313 11/14/98 Page 3 CASING TEST and FORMATION INTEGRITY TEST Well Name: 11/14/1998 2L-313 Date: Supervisor: D.P .BURLEY Casing Size and Description: 7 5/8", 29.7 ppf, L-80, BMTC Casing Setting Depth: 2,607' TMD 2,305' TVD Mud Weight: 9.1 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 2,325' TVD 830 psi + 9.1 ppg LOT = (0.052 x 2,305') EMW = 16.0 ppg Fluid Pumped = 0.7 bbl Pump output = 0.1000 bps ~TlME LINE 2,300 psi I I! I I .. - lONE MINUTE TICKS 2.200 psi Ii' ¡ .. .. .1.1 ¡. . . .. . .L -.l 2,100 psi \ I I I i I 2,000 psi I ,. 1,900 psi '1 ,..¡..~ " I. I 1 i 1.800 psi I II I I 1,700 psi .! I i I 1,600 psi I I I I I I 1,500 psi i IT ! , ! ! I I I I I I I j W 1,400 psi I I I I a: 1.300 psi I IT I I ~ 1,200 psi I I I I I I I I I m 1.100psi I 4. I I I i m a: 1,000 psi i 'l I! I I i I ' ~LEAK-OFF TEST D. 9OOpsi ! ""'CASING TEST 800 psi I loJ I ! I I ¡ I I . I n...,,,... LOT SHUT IN TIME 700 psi " i I '"' "'" I i J I I! I -ok- CASING TEST SHUT IN TIME ¡ ! ¡ ¡ I I I i -+- TIME LINE 600 psi i' ! I I I I i ! 500psi ,. '¡ , ¡! I I I i i 400 psi I I I I i I I ! 300 psi I ,i i 200 psi J, T I ¡ 'I, I I I ! I ! I 100 psi I. " I I I ! I I 1 -.L ! I I I I I Opsi" i I I ! I I i \ ! ! 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 70 72 74 76 78 80 82 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR FIT STROKES PRESSURE CSG TEST STROKES PRESSURE C~~====~=~=~~~~-=~1==Q_~l=~~] [~-==~~=~~~~=r~~=~~~~~=-~~==[~~~=~~=~~=] i ! 1 stks ! 50 psi i i ! 1 stks i 100 psi i [=-_--==J--2~!!~S __L~-11~~šT~~~~ \C\t=~~==~==~]~=~~!~~~~==¡=~~~Q~p.~]~ ! ! 3 stks ! 300 psi I ' I 3 stks : 470 psi: }----------------~---------+--------------I \ ~-----------~---------------+--------------I L------J--~-!.~!...-l--!~-p_~!_-J \ Ii ~--------------L---~-~~~-----L--!~.Q-J?_~!_---J L__________1__'§"~~~~___i___570 p-~}---jq û---------------_J._--~~~~~____L__!~_~_J?_~!__.J !-----------J---~!.~~!..._¡___r~_~J?~L__j ~ ~------------------!-----~-~~-~~----¡-__!~!J?!L__j ! ! 7 stks i 830 psi! ! ! 7 stks ! 1,040 psi! r------------¡---------T-------------' r--------------Y-------------"-r---"-""--""---":--, I I I I I : 8 stks I 1 ,180 pSI I ~~=:j r===~~~Ei~~f~~~B ! i ! ! ! ! 11 stks ! 1,600 psi! [~~~~~--~--I~~==~~=~==] [~=~~~~-~~~~~~J~~j!~!~~~=¡~1~Z~~p.!!] !--------____~_1__-~î'L--------------j L---------------¡---~~-~~~~--~-_!!~~~_P.~l-l L---------..J---------------.l--------------J L-----------------L--~~-~~-~~---L-~!Q~Q_p'si .J ~--------------~---------t---------------~ ~-------------i------------------~--------------~ I I I I . I . . ~====t::=:====~==~i f==-~=~::=F==:==t=::::::==-~ ¡---------¡--------"---r-""-------------¡ ¡--------..--------t----------------- I I t----------i------------+---------------~ i i ------------------- i i : I I I : SHUT IN TIME: , : t=~=~~-=J=~~=~=~=--=L~~-=~~~=-~~~J t=~~~~2~[~=~~t=~~=~~~~~~=~t~~~~~q~Ë~i_J ! ! ! ! i 1.0 min ! ! 2,000 psi! !-----------r-----------r----------~l [~~3~~~i!!~=J~~~~~~~~~==~~~~~~~t-=~~~~~p.~CJ ! 3.0 min ! ! 1,970 psi! F=~~~~f~~~~~t~~~=~~=~~=~~=~~t~~~~~~~~~r-l t----6:õ-mfñ----r----------------r--1~94Õ--sï-1 [=]]~~[~=~]~~==~~~~~~=~=~I=~~~~~~[J ! 8.0 min ! ¡ 1,930 psi! C~~~!!![~~~=t~~~=~~=~~~~~~~=~t=!~~~QE~[J ! 10.0 min ! ! 1,930 psi! ...---------------.....------------------¡--------------.... ! 15.0 min ! : 1,920 psi! L_----------------t-_._-------------1------------------' ! 20.0 min I I 1,910 psi! ~-------------------f---------------i----.-----------.f l-~-~;Q_!n~~----!---------------__-t-_l!~~.!>_P.~~-.J L._~Q;2_!n~~____L______---------___J..__l!~QQ_P.~~_.l l~t'~_!.!.N_!~~j_---------~~':I_!~~~~~~~~E L...Q;.Q-~!~-------------_J__~9.2_R~1___j ! 1.0 min ! i 800 psi! ~------------~-----------------+---------------f L-~Q.~~--J-------------.l-- 79_Q_.p_~--J i- 3. 0 f!!Ð..._.L-----__.___L___r~~_'p'~!_--j ! 4.0 min ! ! 770 psi! t--------;--i---------------+-------------- ~-_!?':Q.~!~---!---------___-.i-_r~_QJ?_~L_-i L---~Q..f!!!~--..l---------------l--.?~.Q-.P_~!-.J ! 7.0 min i ! 750 psi! L______----.--------------...---------------t ¡ 8.0 min ! i 750 psi I ~--------~-------------+---------------I ! 9.0 min ¡ ¡ 750 psi ¡ [~.1_~~ñii~__I=~~====~=r~~~r~~QJ?~~~] NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ...1t8... ...." ARCO Alaska, Inc. Daily Drilling Report AFC No, /Date RptNo I :i9 Accept - hrs Days Since AccepUEst: 2.9 / 3.5 Rig Relase - hrs: AK9429 11/15/98 4 11/13/9802:00:00 AM Well: 2L-313 Depth (MDnvD) 360412720 Prev Depth MD: 2617 Progress: 987 Contractor: DOYON Daily Cost $ 117114 Cum Cost $ 568655 Est Cost To Date $ 570000 Rig Name: DOYON 141 Last Csg: 7-5/8" {B12607" Next Csg: 3.1/2" x 5-112" @ 11251' Shoe Test: 16.0 Operation At 0600: Drilling 6.3/4" Production hole from 4300'. Upcoming Operations: Drill pproductlon hole, wiper trip @ 5400'. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO, BIT NO, INCIDENT LAST BOPIDIVERT LAST BOP/DRILL LSND 3604 2 N TST 11/15/98 11/15/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.1ppg 55 6.75 10/28/98 11/09/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 44sqc 70 HTC N SPACE 10/31/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 13/15 50 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1485 4/5/ 20 0322873 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1400 7.2 25 11/15/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 114 ml/30 min 2300 2617 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 5% 2000 987 2L-329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 7 145bbl 2500 I II 3.5/1 / 2L.313 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 4 10 11211 5 -15 2.3 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 180° 9.0 61611 90 - 300 497 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 7.00 4% 170 II .518 Water Base Muds 497 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 600 129411 131131131131 I 11111 135 Diesel 120 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $14245 20140 II 11118 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $47908 400 11040 I I III III 752 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 9 BAROID 9.11 I I III III 9194 PERSONNEL TOTAL 42 TIME I END HOURS I OPS CODE I HOLE SEC T I PHASE OPS I OPERATIONS FROM 0000 - 0000 12:00 AM 05:30 AM 5.50 NU_ND SURF Casing and PJSM. ND Divertor, install speed head and tubing spool, Cementing NU BOPE. 05:30 AM 09:00 AM 3.50 BOPE SURF Casing and Test BOPE 250/3500, Chuck Sheve (AOGCC) waived Cementing witnessing test. Install wear bushing. 09:00 AM 12:00 PM 3.00 BHA PROD Making Hole MU BHA #2, initialize tools and load sources. 12:00 PM 12:30 PM 0.50 RIGS PROD Making Hole PJSM. Service rig. 12:30 PM 01 :30 PM 1.00 TRIP IN PROD Making Hole Shallow test tools, RIH, tagged cement @ 2500'. 01 :30 PM 02:00 PM 0.50 CIRC SURF Casing and Circulate out cement contaminated mud. Cementing 02:00 PM 02:30 PM 0.50 TEST_CSG SURF Casing and Test casing to 2000 psi for 30 min. Cementing 02:30 PM 03:30 PM 1.00 CLN_OUT SURF Casing and Clean out cement and float equipment, drill 20' of new hole Cementing to 2637'. 03:30 PM 04:00 PM 0.50 CIRC SURF Casing and Change well over to new 9.1 ppg LSND mud. Cementing 04:00 PM 04:30 PM 0.50 TEST SURF Casing and Peñorm FIT to 16.0 ppg. Cementing 04:30 PM 12:00 AM 7.50 DRIL PROD Making Hole Drill 6-3/4" hole from 2637' to 3604'. ART=2.5 hrs AST=1 hr. 24.00 Supervisor: D.P.BURLEY Daily Drilling Report: 2L-313 11/15/98 Page 4 Casing Detail 5-1/2" X 3-1/2" Production Casing WELL: TARN 2L-313 DATE: 11/20/98 1 OF 1 PAGES ARca Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LDS = 25.25 TOPS 5 1/211, LANDING JT. 34.0' OVERALL LENGTH 25.25 -4.50 Landed on slips. Cutoff 4.5' of jt.# 242. 20.75 Jts. 1-242 5-1/211,15.5# L-80, LTC MOD (242 joints) 10253.92 20.75 PUP 5-1/2", 15.5# L-80, LTC MOD 10.93 10274.67 Baker Csg Seal Receptacle (CSR), SIZE 80-40, 5-1/211 x 411 19.42 10285.60 XO 3-1/211 9.3# L-80 8rd EUE X 5 1/211 EUE 8rd (XO) .60 10305.02 pup 3-1/211 9.3# L-80 8rd EUE 10.13 10305.62 Jts.271-275 3-1/211 9.3# L-80 8rd EUE (5 joints) 157.55 10315.75 pup 3-1/211 9.3# L-80 8rd EUE (marker) 6.09 10473.30 Jts.254-270 3-1/211 9.3# L-80 8rd EUE (17 joints) 534.36 10479.39 Weatherford Gemoco Float Collar 1.16 11013.75 Jts.251-253 3-1/211 9.3# L-80 8rd EUE (3 joints) 95.12 11014.91 Weatherford Gemoco Float Shoe 1.82 11110.03 Bottom of Shoe @ 11111 .85 ACTUAL TD= (11140') 281 RA THOLE. Bypass plug latch in receptical @ 10982.14'. (top of jt. #254) (25) 3-1/211 x 6-1/211 straight blade centralizers(Jts.251-275) (12) 5 1/2" x 6 3/411 bow spring centralizers (Jts.1-12) . (14) 5-1/2" x 6-1/2" centering guidess on jts Jts.195, 198,201, 204,207,210,213,216,219,222,225,228,233,238. Remarks: String Weights with Blocks: 135k Up, 40K Dn, 12K Blocks. Ran 25 Joints 3-1/211 and 242 Joints of 5-1/211 casing. Drifted 5.511 (4.7511)& 3.511 (2.86711) casing with plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor: D.P.BURLEY ...1It.. ~" ARCO AI k c f D t "I as a, nc. ernen Ing e als Well Name: 2L-313 Report Date: 11120198 Report Number: 9 Rio Name: DOYON 141 AFC No.: AK9429 Field: Tarn Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 5-112" x 3-112" 6.75 11112 10982 Centralizers State type used, inteNals covered and spacing Comments: Detail on casing tally. Mud Weight: PV(prior con d): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.8 11 10 15 16 Gels before: Gels after. Total Volume Circulated: 7/10 6/9 550 bbls Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 bbls 8.5 Spacer 0 Type: Volume: Weight: Comments: ARCO 40 bbls 12.0 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: Additives: Tall Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: G 65 254 15.8 1.2 Additives: 2 gps D600, 0.1 gps D135, 0.1 gps D47, 3% D53, 0.8% D65, 0.12% D800. Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: Comments: 4.0 bpm 4.0 bpm 135 Reciprocation length: Reciprocation speed: Str. WI. Down: 25 10 fpm 40 Theoretical Displacement: Actual Displacement: Str. WI. in mud: , ,, 251.4 bbls 253.9 bbls Calculated top of cement: CP: Bumped plug: Floats held: 9805' Date: 11-20-98 no yes Time:2025 hrs. Remarks:Condltloned mud @ 3.5 bpm 520 psi, pipe stuck 8' off bottom after 100 bbls of mud pumped. Batched mixed cement, pumped 5 bbls of fresh water, 20 bbls of Arco wash, 40 bbls of spacer and 54.3 bbls of cement. Displaced with 10 bbls of fresh water and 253.9 bbls of seawater. Did not bump plugs, floats held. Had full returns while circulating and cementing casing. Cement Company: Rig Contractor: Approved By: DS DOYON D.BURLEY ~... ~" ARCa Alaska, Inc. Daily Drilling Report AFC No, I Date RptNo I :i9 Accept - hrs Days Since AccepUEst: 7.9 /9 Rig Relase - hrs: AK9429 11/20/98 9 11/13/9802:00:00 AM Well: 2L-313 Depth (MDITVD) 11140/5773 Prev Depth MD: 11140 Progress: 0 Contractor: DOYON Daily Cost $ 229974 Cum Cost $ 1254804 Est Cost To Date $1500000 Rig Name: DOYON 141 Last Csg: 5-1/2" x 3-1/2" Next Csg: Shoe Test: 16.0 @ 11112' Operation At 0600: Running 3-1/2" Completion. Upcoming Operations: Finish Completion, ND BOPE, move rig. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO, INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 2 N TST 11/18/91: 11/15/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8ppg 6.75 1 0/28/98 11/19/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 44sqc HTC N SPACE 10/17198 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 10/16 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 2380 6/91 0322873 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 450 4.8 11140 11/20/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 116 mV30 min 2617 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 8.0% 8523 2L-329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADT/AST SOURCE WELL TEMP of 1 214bbl 2750 III 37.75/4.6 I 2L-313 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 8 15 1121 I 5 -15 - 2.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 180° 9.5 61611 90 - 300 500 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -14.24 4.9% 170 II .518 Water Base Muds 1043 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 800 129411 131131131131 I 11111 20 Diesel 25 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $1819 20140 II 11118 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $116544 560 11120 I I 1 2IcTIA III 1088 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 11 BAROID 9.8111 xli I NO I TD III 14779 PERSONNEL TOTAL 44 TIME I END HOURS T OPSCODE T HOLE SECT IPHASEOPS I OPERATIONS FROM 0000 ~ 0000 12:00 AM 12:30 AM 0.50 BHA PROD Making Hole PJSM. Laid down mwd and motor. 12:30 AM 02:00 AM 1.50 CASG PROD Casing and Pulled wear bushing, RU GBR Casers and held safety Cementing meeting with crews. 02:00 AM 07:30 AM 5.50 RUN_CSG PROD Casing and Run 3-1/2" and 5-1/2" casing to 4500'. Cementing 07:30 AM 08:00 AM 0.50 CIRC PROD Casing and CBU @ 4 bpm, full returns. Cementing 08:00 AM 10:30 AM 2.50 RUN_CSG PROD Casing and Run casing to 7800'. Cementing 10:30 AM 11:30 AM 1.00 CIRC PROD Casing and CBU @ 3.5 bpm, full returns. Cementing 11 :30 AM 03:00 PM 3.50 RUN_CSG PROD Casing and Run 5-1/2" casing, MU landing joint and cement head. Cementing 03:00 PM 06:30 PM 3.50 CIRC PROD Casing and Stage pumps up to 3.5 bpm, circ and cond mud. Pipe stuck Cementing 8' high, pulled 100k over, no good. Maintained full returns while conditioning mud. 06:30 PM 09:00 PM 2.50 CMT_CSG PROD Casing and Cemented casing as per program Cementing displaced with seawater did not bump plugs. Monitor well static - RD cement head flushed surface lines. 09:00 PM 12:00 AM 3.00 OTHER PROD Casing and ND BOPE Cementing set emergency slips and cutoff casing. 24.00 Supervisor: D.P.BURLEY Daily Drilling Report: 2L-313 11/20/98 Page 9 ......... ~" ARCa Alaska, Inc. Daily Drilling Report AFC No, I Date RptNo IRi9 Accept - hrs Days Since AccepUEst: 8.9/10 Rig Relase - hrs: 11/21/9807:00:00 PM AK9429 11/21/98 10 11/13/98 02:00:00 AM Well: 2L-313 Depth (MDITVD) 11140/5773 Prev Depth MD: 11140 Progress: 0 Contractor: DOYON Daily Cost $ 175651 Cum Cost $ 1421455 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 5-1/2" x 3-1/2" Next Csg: Shoe Test: 16.0 I@ 11112' Operation At 0600: Released rig @ 1900 hrs. Upcoming Operations: Move rig to well 2L-305 MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO, BIT NO, INCIDENT LAST BOP/DIVERT LAST BOP/DRILL SW N TST 11/18/98 11/15/98 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 8.5ppg 10/28/98 11/19/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 28sqc N SPACE 10/17/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER / GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 2000 / / APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 400 11/21/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 111 mJ/30 min INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & % 2L-329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADTIAST SOURCE WELL TEMP of 2 Obbl III / I 2L-313 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 0 11211 - - 2.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 61611 - - 550 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 2.00 % 170 II Water Base Muds 750 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 0 III 11111 I1111 255 Diesel 160 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $500 III 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $117044 III III III 1165 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 12 BAROID III III III 15944 PERSONNEL TOTAL 45 TIME I END HOURS I OPS CODE I HOLE SECT I PHASE OPS I OPERATIONS FROM 0000 - 0000 12:00 AM 01:30 AM 1.50 OTHER PROD Casing and PJSM. Install packoff and NU BOPE. Tested packoff and Cementing csg I tbg flanges to 3500 psi. 01 :30 AM 02:00 AM 0.50 RUN_COMP COMP Completion RU to run completion, held safety meeting with crew. 02:00 AM 11:00 AM 9.00 RUN_COMP COMP Completion Run 3-1/2" completion, PU space out pups, hanger and landing joint. 11:00AM 12:30 PM 1.50 CIRC COMP Completion Displace well with 275 bbls clean seawater @ 3.5 bpm. 12:30 PM 01 :00 PM 0.50 TEST_CSG COMP Completion Test casing to 3500 psi for 30 min. 01 :00 PM 03:30 PM 2.50 OTHER COMP Completion Freeze protect tubing and 5-1/2" casing to 2000' TVD with 45 bbls of diesel. Land hanger, tested tubing to 3500 psi, 10 min. and 5-1/2" x 3-1/2" annulus to 3500 psi, 10 min. LD landing joint and installed TWC. 03:30 PM 07:00 PM 3.50 NU_ND COMP Completion ND BOPE, installed adaptor flange and master valve, tested hanger to 5000 psi. Released rig @ 1900 hrs. 19.00 Supervisor: D.P.BURLEY Daily Drilling Report: 2L-313 11/21/98 Page 11 CASING TEST and FORMATION INTEGRITY TEST Well Name: 2L-313 Date: 11/15/1998 Supervisor: D.P.BURLEY Casing Size and Description: 75/8",29.7 ppf, L-80, BMTC Casing Setting Depth: 2,607' TMD 2,305' TVD Mud Weight: 9.1 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 3,366' TVD 730 psi + 9.1 ppg EMW LOT= (0.052 x 2,305') = 15.2 ppg Fluid Pumped = 5.0 bbl Pump output = 0.1000 bps ~TIME LINE ;1 I I! I I I í .... lONE MINUTE TICKS I I I I ! i I j J J . . I I I I I I I '. J I! IJ .1, 1 I I ! I 'I I I r ~I I I I I I . I I ! ,/1 ! I i IT! ¡ i ! 1 : 1 I I I II I I I I I 1£, i I I I ~ I.. t "'-.J I I I i J. I .Ib "~ "" ! I I 1.1 I '... ~"\I" I I II I I I ' /... ~LEAK-OFF TEST ~ í'= III I I i I I / I I ~CASING TEST I Ir! I I ~ III I I ..+>-,.LOT SHUT IN TIME i- .....,¡- CASING TEST SHUT IN TIME - , I " ~- I , i!' I -+- TIME LINE - += J 1/ i' I I f Jr I I I i I I I I I I I I I J I Y I ! I I i I I I V1 ! 'I I I ! -""'1 I ¡I I ! I! 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1 ,600 psi 1,500 psi W 1,400 psi a: 1,300 psi ~ 1,200 psi æ 1,100psi a: 1,OOOpsi c. 900psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 2 4 6 8 10 12 14 16 18 20 22 24 26 26 30 32 34 36 38 40 42 44 46 48 50 52 54 56 56 60 62 64 66 68 70 72 74 76 78 60 82 84 86 88 90 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE ,---------'-----------T-----------------' ~-------J----__Q._~tks ----L---Q.R~---j ! ! 2 stks ! 30 psi! '-------¡-4 stkš----r----9õ-pšr-l ¡-------------¡-- 6 stks--¡-"21Õ-psi --1 ~------------~----------+-------------I ! ! 8 stks ! 340 psi! r----l-Tõs'fkš-r;¡sõ-pšf-l ¡--------I--T2-siï<š-T620 p-šr-1 ~------f----------+----------------I ! i 14 stks ! 730 psi! r-----1-1š stks -¡--¡1opšr--l r----------I--16si-kST--šsõ--pšf--l t-------------i-------+------------ ! i 17 stks ! 660 psi! r-----------T-1ã-Si-ks!Š40 psf--l r------------'--19 stks-r-Š40 pSi---l ¡-------r-2õSi-ks ---¡--63Õ--PšT-1 "'---------~--------~---------I i ! 25 stks ! 610 psi! r------1---30 ši-kš--T-šõõ-pSi---l t------------I--a5-ŠtkS!----6"õõpšT-1 ""'-------~--------+---------------f i ! 40 stks ! 590 psi! r------------r---~ï5stkš--r--S9Õ- psi-l r---------r--50 stkS!--s7õpšr-l f~~-~:~f~~;~~ i.!J:I-':'.! IN TIM~_____---~':I_!_!~~~~!,.!~~E L_g.:Q_~!~___L______--_-.L_--~Z9._p.~l.._j i 1.0 min ! ! 510 psi! r~=Iõ mJ~~=~t~====-t~=~ffp~I~J L- 3.0 _f!1in --J-----------L--~~-~_J?_~)---.J i 4.0 min ! ! 500 psi! [~=~~Q_!ñiñ-~J=~=~~=-_-=--=t~i~~j?~I=J L--~.:..Q..!!1J!!_-J.---------L--~~-J?_~----J ! 7.0 min ! ! 500 psi! 1-8-:0 min---I----------¡---sõõ-PšT-1 ~-----------~-----------------+-------------I ! 9.0 min ! i 490 psi! [Jg.:2_~~-T~-=~===:C=~~J?_~~~] CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r--------------I---------------'-----------------' I I I I E=====EI~~I1I~] ~----------------¡-----~.!~~~----~----~?_QJ?_~~--~ i ! 4 stks ! 640 psi! F===~EI~I~l~jil ! I 7 stks ! 1,040 psi I f"--------------T---ä-š¡ks----r1~:¡ãõr;šr-l -----------------.----------------J..---------------.. ! i 9 stks ! 1,300 psi! t----------------i---------------+-------------- ~----------------J.-_.!~-~~~----~_l1~QJ~~!---i ! ! 11 stks i 1,600 psi ¡ C~~~===~===~C~=f~~~!E~~~~~~j~!.~~~R~Cl ~---------------_.¡-----~~-~~~---~-_!!~~Q_P.~.!---i r=:::=--==~======:=t:=!!~.L~ ~~=~~~~~~=~~~=~t~~~~~~~~~~~~~~~~=~t~~~=-~~~==~=~1 I I I I t------..---------t------------..-...... I I , I I ' i i - ---------- I i ~!?~.':I_!_!~_!~~~J-------------------~----------------~ ! 0.0 min ! i 2,020 psi i r~=I~~-ñi[~~~~J=~~~~==~=~~~~~~¡=~~~J!~piTl ~____3~~_~~~----¡-------------------~--_!!~~~_e~~--i ! 3.0 min ! ! 1,970 psi! [~~3=~~!!![~=~~I~~~~~~~=~=~~=~~[j~~~~R~[J ! 5.0 min ! ¡ 1,950 psi i ~---------------i------------------~------------f ! 6.0 min ! ! 1,940 psi! r-----------------'------------------r---------------' ! 7.0 min ! : 1,940 psi! [=~~~Q~~[~~~~~I~~~~~~~=~=~=~~~[~h~~~~~J ! 9.0 min ! ! 1,930 psi! r------------------'--------------------r---------------.. ! 10.0 min ! I 1,930 psi! r-15~oñifn-r----------------r-1~92õ-pšil ~------------;-----t----------------t-------------:--1 ~-_?Q.:..Q_!!!~~--~---------------__~___h~!Q_p.~!_-~ L--?§.:Q-~~~-.1------------------L--!!~QQ£~U L__~Q.:Q-~~~_.J_----------______L_1~_~Q£~!"j NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ...~ ~" ARCO Alaska, Inc. Daily Drilling Report AFC No. I Date RptNo I ;i9 Accept - hrs Days Since AccepUEst: 3.9 1 4.4 Rig Relase - hrs: AK9429 11/16/98 5 11/13/9802:00:00 AM Well: 2L-313 Depth (MDITVD) 6329/3721 Prev Depth MD: 3604 Progress: 2725 Contractor: DOYON Daily Cost $111675 Cum Cost $ 680330 Est Cost To Date $ 725000 Rig Name: DOYON 141 Last Csg: 7.5/8" @ 2607" Next Csg: 3.1/2" x 5-1/2" @ 11251' Shoe Test: 16.0 Operation At 0600: Drilling Production hole from 6950'. Upcoming Operations: Drill Production hole, wiper trip @ 7900'. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO, BIT NO, INCIDENT LAST BOP/DIVERT LAST BOPIDRILL LSND 6329 2 N TST 11/15/98 11/15/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.1ppg 65 6.75 10/28/98 11/16/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 50sqc 90 HTC N SPACE 10/16/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 17/18 55 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 2320 7/81 25 0322873 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1350 6.2 35 11/16/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 102 mll30 min 3000 2617 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 5.5% 2700 3712 2L.329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 6 252bbl 2450 III 14.711 1 2L-313 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 2 12.5 1121 1 5 -15 2.3 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 180° 9.5 61611 90 - 300 525 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 6.00 5.1% 170 II .518 Water Base Muds 962 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 600 129411 13113\131131 I 11111 180 Diesel 100 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $15565 20140 II 11118 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $63473 625 11370 I I III III 1242 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 11 BAROID 9.11 I I III III 10436 PERSONNEL TOTAL 44 'TIME I 'END HOURS I OPSCODE I HOLE SECT I PHASE OPS I OPERATIONS FROM 0000 ~ 0000 12:00 AM 12:00 PM 12.00 DRIL PROD Making Hole PJSM. Drill from 3604' to 5080'. ART=6.7 hrs. 12:00 PM 02:30 PM 2.50 DRIL PROD Making Hole PJSM. Drill from 5080' to 5394'. ART=1.2 hrs 02:30 PM 03:15 PM 0.75 CIRC PROD Making Hole Circ low I high vis sweeps around, monitor well, pump dry job. 03:15 PM 04:15 PM 1.00 WIPERTRP PROD Making Hole Wiped hole to shoe, no problems. 04:15 PM 04:45 PM 0.50 TEST PROD Making Hole Performed LOT, established EMW=15.2 ppg. 04:45 PM 05:45 PM 1.00 WIPERTRP PROD Making Hole RIH to 5394', no problems. 05:45 PM 12:00 AM 6.25 DRIL PROD Making Hole Drill from 5394' to 6329'. ART=3.3 hrs. 24.00 Supervisor: D.P.BURLEY Daily Drilling Report: 2L-313 11/16/98 Page 5 011 PHILLIPS PHILLIPS Alaska, Inc. V 6 A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510 -0360 R. Thomas Phone (907) 265 -6830 Fax: (907) 265.6224 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2001 Dear Commissioner: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2001. Please call me at 265 -6830 should you have any questions. Sincerely, R. Thomas Greater Kuparuk Team Leader RT /skad cc: Marty Lemon D Mike Mooney � Paul Mazzolini via Chip Alvord ZOd2 Kuparuk Environmental: Engel / Snodgrass pN B. Morrison and M. Cunningham cocitd f0 Sharon Allsup -Drake P�� kaO`�& e Well Files Annular Dis ~osal durin the fourth quarter of 2001: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Voimne Volume Quarter Protect Total Total Date Date Volumes CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 IC-16 12338 100 0 12438 0 19679 32117 Sept 2001 October .1C-131, 1C-125, 1C-102 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD247 2001 2001 CD2-14 14359 100 0 14459 376 0 14835 November December CD245, CD2-47 2001 2001 '1C-14 22389 100 0 22489 0 0 22489 Oct2001 Nov2001 IC-109 ~-' 2P-438 30331 100 0 30431 212 0 30643 Oct 2001 Dec 2001 2P-420, 2P-415, 2P429 CD2-15 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only CD2-47 10315 100 0 10415 375 0 10790 Dec 2001 Dec 2001 CD2-34 1 oral Volttmes trtto Annutt for wntcn L~tSposat Autnortzatton r.x:otrea aurmg tnejourtn q'uarter zc~ctl' Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec 2000 2L-317, 2L-307 I D'36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1D-42, 1D-34 CI) 1-31 6698 100 0 392 7190 Open, Freeze Protected Feb 2001 March CDI-14 2001 '---~N-305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect volumes only ID-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec 2000 1D-32, 1D-40A 2N-349A 0 0 0 0 0 Open, Freeze Protected ...... I I}-42 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 1D-37, 1D-39 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 23, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2000 (Revision 1) Dear Ms. Mahan: Please find the revised report below with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2000. The revision is for the annulus of Well 1D-42. An annular disposal report for 12/26/00 of 2437 barrels was not counted in the total for the Quarter. The revised total for Well 1D-42 is 15,118 from 12,681 barrels as noted in the table below. Annular Disposal during the fourth quarter of 2000: h(1) h(2)' h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 100 0 26547 4807 31354 CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 0 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 1D-36 30104 100 0 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 15018 100 0 15118 0 15118 f ~?-// ? PHILLIPS Alaska, inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 25, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Second Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the second quarter of 2000, as well as total-volumes injected into annuli for which injection authorization expired during the second quarter of 2000. Annular Injection during the second quarter of 2000: h(1)' h(2)- h(3) Totalfor previous New Well Name Volume Volume Volume Quarter Total Total 2N-341 20406 100 0 20506 0 20506 2L-313 4640 100 0 4740 12533 17273 CD1-40 108 100 0 208 32669 32877 CD1-23 16751 100 0 16851 17135 33986 CDI-16 25 0 0 25 29025 29050 CD1-32 82 100 0 182 33331 33513 CD1-38 11056 100 0 11156 9164 20320 CD1-27 32333 100 0 32433 381 32814 1L-28 5853 100 0 5953 3984 9937 ~-' 1D-11 135 100 0 235 0 235 1D-14 1337.6 100 0 1437.6 0 1437.6 CD1-25 8141 100 0 8241 386 8627 CD1-34 278 100 0 378 0 378 198-219-0 KUPARUK RIV U TARN 2L-313 50- 103-20277-00 PI/ILL[PS ALASKA INC Roll #1: Start: Stop Roll #2: Start Stop MD 11140 TVD 05773 Completion Date: 11/21/98 Completed Status: 1-OIL Current: Name ?b~.:~. Interval Sent Received T/C/D D 9143 ~2 SPE~Y ~T/G~4/~/SLD OH 5/8/99 5/11/99 L DGR/CNP/SLD-MD ~/FINAL 2617-11140 L DGR/CNP/SLD-TVD ~INAL 2304-5772 L DGR/EWR4-MD t,//FINAL 2617-11140 L DGR/EWR4-TVD ~"/FINAL 2304-5772 R SRVYCALC v// BH 108-11140 OH 5/20/99 5/21/99 OH 5/20/99 5/21/99 OH 5/20/99 5/21/99 OH 5/20/99 5/21/99 OH 2/26/99 3/5/99 Tuesday, January 09, 2001 Page 1 of 1 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMpANy Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 19, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes injected into annuli for which disposal authorization expired during the fourth quarter of 2000. AnnUlar Disposal during the-fourth quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 100 0 26547 4807 31354 CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 0 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 1D-36 30104 100 0 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 12581 100 0 12681 0 12681 ~c~- Io'q- Ms. Wendy Mahan AOGCC Fourth Quarter 2000 Annular Disposal. Report Page Two Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of AnnulUs CDI-16 28950 100 0 29050 Open, Freeze Protected CD1-45 32236 100 0 32336 Open, Freeze Protected CD 1-32 33413 100 0 33513 Open, Freeze Protected CD1-42 31234 100 0 31334 Open, Freeze Protected CD 1- 36 33567 100 0 33667 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC'. Marry Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Dan Seamount, d.,~/~/~ Commissioner ~, Blair Wondzell, ~ P. I. Supervisor -~to'~ FROM' John Crisp?/~,/u,. C,,, SUBJECT: Petroleum Irfrspector 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 Tarn 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& Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2N-307 1990170 2N-308 19901001 94 70 65 P P OIL 2N-309 1990210 2N-313 1980910 94 70 70 P P OIL 2N-315 1981900 2N-317 1981430 94 70 70 P P OIL 2N-319 1981970 ~N-320 1990010 94 701 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 oIL1 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% ~] 90 var Remarks: '7/97/(~ Page 1 of 1 SVS Tam 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, Kuparuk River, 2L 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 GAS or C¥CI~V, 2L-305 1982400 94 70 60 P 4 OIL 2L-307 1982560 94 70 70 P P OIL ~3-t;3..' -~.:~, :-:~' 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 GAS1 Wells: 6 Components: 12 Failures: 1 Failure Rate: 8.0% Remarks: 7~7m0 Page 1 of 1 SVS Tam KRU 2L 7-20-00jc.xls ARCO Alaska, Inc. Well Proximity Risks: \S — D, We v The nearest well to 2L -313 is 2L -325. The wells are 180.1' from each other at a depth of 700'. Drilling Area Risks: The primary risk in the 2L -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 9.6 -10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" 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. APR 2011 Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class 1I disposal well. (Note that cement rinseate will not be iniected 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 fluid during any extended shut down (> 4 hr) in pumping operations. The • 2L -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 2L -313 be 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 100' 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 ARCO Alaska, Inc. 0 This pressure is conservative, since frictional losses while pumping have not been Aft 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 7 -5/8" 29.7 L -80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5 15.5 L -80 3 LTC -Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 31" 9.3 L -80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 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). • • O w�!? QQ ,`- h \\ `C 'c*-. 5 Uv l . C,,\ - \--- \--) c - 5 � �, ` M c7 33' -t vac . CASING TEST and FORMATION INTEGRITY TEST T\ �CVds� vv c,._s Va ES \ . - < C c �Q` � 4 o � -I k‘\ o 7 , LEAK -OFF DATA CASING TEST DATA Well Name: 2L -313 Date: 11/15/98 MINUTES MINUTES FOR FOR Supervisor: D.P.BURLEY FIT STROKES PRESSURE CSG TEST STROKES PRESSURE i r r 1 ry Y T 0 stks 0 psi i - r 2 stks 30 psi s r i 1 stks 4 100 psi Casing Size and Description: 7 5/8 ", 29.7 ppf, L -80, BMTC t P >j6o i tt 4 stks + 90 psi } ; 1 2 stks 1 320 psi 4 Casing Setting Depth: 2,607' TMD 2,305' TVD s 6 stks 1 210 psi r C 4 3 stks 1 470 psi j 4 8 stks 1 340 psi t-- : : 4 stks 640 psi I Mud Weight: 9.1 ppg EMW = Leak -off Press. + MW 10 stks ? 480 psi X4 4 800 psi 0.052 x TVD * 12 stks I 620 psi 4, 1 5 stks 6 stks ; 910 psi j 1110 Hole Depth: 3,366' TVD { 14 stks 730 psi " ?04 7 stks 1,040 psi I 15 stks 710 psi 4 t I 8 s 1 1,180 psi j 730 psi + 9.1 ppg EMW 4 16 stks 680 psi 4 li. t 9 stks ' 1,300 psi LOT = (0.052 x 2,305') = 15.2 ppg 4 17 stks 4 660 psi ; 10 stks 1 1,450 psi ; 1 18 stks s 640 psi L t 11 stks s 1,600 psi Fluid Pumped = 5.0 bbl Pump output 0.1000 bps : 19 stks : 640 psi 1 12 stk J 1,750 psi T 20 stks 4 630 psi i L 1 13 stks 4 1,920 psi TIME UNE 1 25 stks ' 610 psi I i 14 stks 1 2,020 psi i 2.300 psi " UNE . MINUTE TICKS'., i t 30 stks t 600 psi I t I 1 . 2'2°°ps' ■■■■■■■ wwwwwwwwwwwwwwwwwwwwwwwwwwwwwwwwwwmei T 35 stks t 600 psi 1 ' z ■■ ■ ■•■R M■■u••■■■■■■••■■■■■■••■•••■■ uuIuu•■■ 40 stks 590 - - - p 1 1 1 ; psi 4 1.700 psi ■•••■ ■Li i' iiCET s!!wi!IAPI 1.111111■ ■■ ■ ■11■■■ ■■■■■ MIII MMUNI• 4 � 59 si i 45 stks p � ; 4 � 50 stks 570 ps ' [ S HUT INTIME I 1 I ; 4 � 0.0 min 4 2,020 psi , s4, 1,403 psi t i i 1.0 min t 1 2,000 psi , l 1.300 psi i a ,coops' 1111i 4 s 4 4 2.0 min j 1 psi ' ' SHUT IN TIME; S HUT IN PRESSURE 4 3.0 min 1 ' 1 970 psi I Psi a ,,000 psi psi ± T , i• t 700 psi ivai■ ■■ ■■■u■■uuuiu••i• f- LEAK -OFF TEST 1••• 0.0 min , . 570 psi. _ 4.0 min 4 , 1,960 psi 800 ,„, ENFAUI■E UUI INNEM■000USE♦■ CASING TEST OMEN 1 .0 min ! - 510 si 5.0 min 4 1,9 si • 700 - , ••fii•••!1•11MMI •i••••••• ■•• -° LOT SHUT IN TIME 1111 1 P p 6130 psi IW y+� ■AU iiirwhoUA■MUUUUA� CASING TEST SHUT IN TIME •U • 2.0 min 5 psi 6.0 min i 1,940Qsi gyp ■fiO•; rAINNI ■ ■r■I11�111■•e■IIe ;,, U E MIR. 3.0 min } { 510 psi 7.0 min 1,940 psi = 400 ps' 4.0 min i 1 500 psi : I F 8.0 min 1 I 1,930 psi 1 300 ps' II + t 1 t 1 1 f 5.0 min 500 psi 4 i 9.0 min 4 1,930 psi 100 psi 6.0 min � I 500 psi 4 I 10.0 min I 1,930 psi ° p y 7.0 min 1 r 500 psi 15.0 min 1 1,920 psi I 0 2 4 6 8 10 1214 16 18 20 2224 2628 30 32 34 3638 40 42 44.46 48 50 52 54 56 58 60 62 64 6668 70 72 74 76 78 80 82 84 8688 90 stk Mk - -4 3 stk stk stk stk k stk slk stk stk „k slk sit ,.k slk ,5� Mk ask ,,k ,ik ,,k 41k 414 stk stk ,6k .1k ,1k a& a* stk stk sit stk ,1k stk stk a& silt stk stk stk slk stk slk slk min I I 500 psi 1 L 20.0 min IL i 1,910 psi I STROKES 9.0 min ¢ I 490 p si 4 � 2 min 1,900 psi i 10.0 min 1 490 psi 30.0 min , 1,900 psi NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME ":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY • RC v �! lei/) O .. CASING TEST and FORMATION INTEGRITY TEST NOV 2 2 2000 Alaska O LEAK -OFF DATA CASING TEST DATA Well Name: 2L -313 ' A � „ m1S$jpflMINUTES MINUTES r+dla ge FOR FOR vl Supervisor: O.P.BURLEY FIT STROKES PRESSURE CSG TEST STROKES PRESSURE a 0 stks I 0 psi I Casing Size and Description: 7 5i8 ", 29.7 ppf, L -80, HMTC 1 stks I 50 psi ' 1 1 stks I 100 psi I 2 stks ; 110 psi I 2 stks i 320 psi Casing Setting Depth: 2,607' TMD 2,305' TVD 3 stks + 300 i 9 3 stks a 470 psi , 4 stks I 430 psi �Ci, i 4 stks 640 psi I Mud Weight 9.1 ppg EMW = Leak-ofl Press. + MW j 5 stks 1- 570 ! `- + - 5 s k s j - 800 psi 0052 x TVO 6 stks 760 ps Hole Depth_ 2,325' TVD 7 stks r 830,psi ( I 7 stks i 1,040 psi ip ��`\ � s 8stks I 1,180 psi 830 psi + 9.1 ppg EMW `1L0 6 ` I i 9 stks i 1,900 psi a LOT = t0. 052 x 2,305•) =16.0 ppg `USZ Ca30 -S '- i I ' 10 stks 1,450 psi a D I. 11 stks 1,600 psi ? x Fluid Pumped = 0.7 bbl Pump output = 0.1000 bps i 12 stks + 1,750psi . 1 o i 13 stks I 1,920 I Ps 2.:+n�e - -, ONE 11NUfE 'TICKS • !- i y 14 s tk s , I a A1 Psi 2 020 psi • X 111 ■ i { ,.POJf�i Hr.� m - _ -- - -i _ - -i.- d..,.���1 L. 1AW Ce itt �•.- �� I - • - -�� r -- - - �- - •- S Q �m T R tE 190:1 os, ' it, -- - 7_ • a t - -}- '--� � � � ! -� � p xaoi - t --.. – - r - F • - - � –• � - � � Y - - - .____•_.__--i i- -- + � 2 020 , ma Z."- '._; . - - . I - 1 I - • . I i 1 -0 min 2,000 psi i ,-,-�• . }-- �� ._�Y __ -• _. .�.._ _ +. � _ � - {-� ; 1 _ �� _ _ I_ , I 20 mm _ � r 1,980 psi Lk , ,.,0,t9 -p 1 - l . r __._ - • ■r ■ I SHUT IN TIME SHUT IN PRESSURE ' 3.0 min * 1 970 ai 1 a 1: $ i ■ ■ ■ 4 1EA K•CFF TEST - voce Mill. � '� 00 min 83 ps i � r 4 min � 1 , 9 80 psi .. _ ■■■■■mam � �' CASINGTEST � y -.._ _ a • °. + i i �' ; 1 i I ' " ° ■■ L f _ LOT SHUT IN TIME ■� 1.0 min E 800 p S! 5.0 min 1,9r50�S81 _. t Komi IVJ ,a■ I . ill ■ ----- CASING- TESr SHUT IN TIME 2.0 min 790 s 6.0 rnin 194fl si • more a ■■■ I ■�■ III = TI lip ■ � s1�� ■ p -- s - - - s p ao� 3.0 min 7fl0 psi 7.0 min 1,940 psi MEE MI 1111. , I I 4.0 min 770 psi B.0 min 1,930 psi , ( I I I ` 4 ( 5.0 min 760 i 9A min 1 930 psi ice os. - ' T - ---- - ( - - -' 4- !--4--4-4---!-4-1-4 . 4 t - -• � -• . - - - - • i , - - 6.0 min 760 psi 0 10 min 4.. 1.930 psi , 1 < • ° s r r c. k << r .> ?_ :•'< - 2< "+ c .: K s _c S: !s '.[ !< •[ s ._ .... -. %s.-= iv 1- ^i L ___- _____._._ -_ - -� 70 min 50 psi 15 0 min 1.920 ps N <.> :•: ,v �.... „ •. :: „ r: �.._ ,� _.:..•<, -. ,e ,.. < ,•< , .,. „ ;, 8.0 min • 750 psi 20.0 thin 1,910 psi m STROKES 9.0 min ° 754 psi ° 25.0 min I 1 1,900psi ' m 1 0 0 min 740 psi 30.0 min 1,900 psi m scl NOTE: STROKES TURN TO MINUTES DURING 'SHUT IN TIME':see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY u m D v cm w FROM PHILLIPS AK FAX NO. : 9072651535 11 -21 -00 06:01P P.01 Phillips Alaska lnc. 70o G Street, Anchtage, AK 99501 Alaska Date: Number of pages including cover sheet: • ■ To: From: r7 Wells Group Phone: Phone: 'L °S �1 Fax phone, Fax phone: CC: Location: • REMARKS: ❑ Urgent ❑ For your review ❑ Reply ASAP ❑ Please comment Z L- 3 l 3 71„), rz 1,1 -- .1k7 c i'► .a c ") .S .45/, — / a 0 0 .0 RECEIVE' Nov 22 2000 pc1 e I f C o v e n Alaska Oil & Gas Cons. Comrri Anchor a Est }i 4111 • • • cD NABORS RIG 19E - DAILY ANNULAR INJECTION RECORD Page of - DATE: r 5 -/ / - 0,0 1 INJECTING INTO ANNULUS OF WELL:1 2 C - 3, 3 I 4D00 TO safl►a I RS FLUIDS CAME FROM WELL:1 21- - 3/i— , , Page of BARRELS INJECTED T (List under proper fluid type) FOR MUD ONt.Y: PUMP STATIC INJECTION TOTAL START RATE PRESSURE PRESSURE OTHER CUMULATIVE WEIGHT FUNNEL TIME END TIME ISPM) (PSI) (PSII MUD WATER DIESEL (specify) VOLUME (PPG) VISCOSITY COMMENTS 0 2 /0 O2/ Z. 460 S ?S o 0 ._._ ,2ig> . 7v-s re )S()CP z 0 1015 /4D I.5 50o i30o Soo -PO , c7'� 45 )4oa /435, 3 500 /to I tan , _ - , /cgs -- /,5 , /025 b?-5 4-5' lo$S . - , M d ... f�► 'g . . E I i 7 i. Y { 7 N m , r.„, 0, tt , ... i i ` cp .5 x a CC A • Tote for Csaarculaftve Tad ROM , Total far this Annaba MUD WATER DIESEL OTHER Today ?raviolis Day Y TOTAL VOLUMES FOR DAY: t 1 / co J 5S _ 645 R 6 /3 j88 . GEL ! Q-GEL X -TND BICARB PH 6 ADDITIVES; NIGHTS .._. /6) , USED; DAYS — / U g "' �l 1 R: � i L, r NABORS RIG 19E - DAILY ANNULAR INJECTION RECORD Page _ DATE: J 5- J 2_pU 1 INJECTING INTO ANNULUS OF WE' LL: 2. - L - 3j3 0000 TO 2400 HRS FLLJIDS CAME FROM WELL: J j L 3 Page of BARRELS INJECTED ( List under proper fluid type) FOR MU ONLY: " PUMP STAT1C (�1JECTIOtd TOTAL START RATE PRESSURE PRESSURE OTHER CUMULATIVE WEIGHT FUNNEL T1ME END TIME (SPM) (P51) {PSI) MUD In. DIESEL (specify) VOLUME (PPG) VISCCDSI7Y CDMMENTS r'Jr' _______ . _ nr �►���� =i `Q ___ ______________ . Tot f fat Cw !muftty To from NeW Tatat star !!?1f A,mntua Mub W, TE! D)ESEL OTHER j Today Primus Day �} Y TOTAL VOLUMES FOR DAY. [/oo 5 j � t 1 5 J 3 jet i ,,' 7' 3� Q � � GEL Q-GEL X -TND; BICARB pH B 2.- AL�D/TNES NIGHTS /0 - z USED. , DAYS - �. "' °u VrSOR: DAY C7ION WSOR: �;' • • NABORS RIG 1 19E - DAILY ANNULAR INJECTION RECORD Page 01 DATE:) 5 -43 -a) I INJECTING INTO ANNULUS OF WELL: I L. - 3/,.3' 000©TO2400HRS i FLUIDS CAME FROM WELL:1 , .G. -- 3J7- I Page of BARRELS INJECTED Last under pro er fluid . - FOR MUD ONLY PUMP STATIC INJECTION TOTAL STMT RATE PRESSURE PRESSURE OTHER CUMULATIVE WEIGHT FUNNEL TIME END TIME IBPM) (PSI) (PSI( MUD N DIESEL (specify) VOLUME (PPG) VISCOS COMMENTS MIME. 500 D MIN 111111111111 11111111.11111111111111111111101 • ,►t . • O Cobh $ 2 MEM In INEPI M�E f �. � ���� 10. 5D . a /6'2 ''+� - is E 1111111_ 660 F esangil MI &co ;OD 1.1111111111M111 ; 5 111111111101 // 7 13 r� v c‘i MN 1111P111111111 11111111111111111111 0111111111111111111111111111111111111111=11111111111111111111111111111111 111111111111111111111111111111111111111111111111111111 1111111111111111111111111 111111111111111111111111111 11111111111111 ��� 11 N 111111111111111111111111111111 111111111111111111111111111111211111r11111111111111111111111111 • row for Cummufal r a Total from Nrw Totem for this Asmukm MUD WA TER DIESEL OTHER TOday Dr! TOTAL VOLUMES FOR DAY ::[30 L 2 00 1 --- 606 14h 1 3 / 47, 9428 GEL 0 -GEL . X -TND BICARB PH 6 ', ADDITIVES k USED: DAYS 5 I -- wrau S RAVOR: 1 DAY c SU R'►asl?R • • ir NABORS RIG 19E - DAILY ANNULAR INJECTION RECORD page of v DATE: 5- 4 -ao 1 INJECTING INTO ANNULUS OF WELL: r 24-315 I 4 0000 TO 2400 HRS FLUIDS CAME FROM WELL: I 21- - 317- I m m Page of BARRELS INJECTED N List under pro , r fluid • = FOR MUD ONLY: PUMP STATIC INJECTION • TOTAL START RATE PRESSURE PRESSURE OTHER CUMULATNE WEIGHT FUNNEL TIME END TIME won) (PSI) ;Psil MUD DIESEL (specify) VOLUME (PPG) MSC • - 1111111114 is i 1 -0 0 : . — 0. i v0 V MN ■ 0 : • 11111111=MilinillINIIIIIIIIIME11111111111 -tizo IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII E 1111111111111111111 EMI 111111111111 1111111MINI- MINI .- 111111111111111111111111111111111111111011111111111111 111111111111111E11.111111 g NM 11111111 MIN 11111 MEIN . � 1111111111111111 111111 IIIIIIIIIIIIIIIIIIIIIIIIIIIIIHIIIIIIIIIIIIIIMIIIIIIIIMIIII , 1.111111111111111111110 1111111111111111111111111111 IMIIIIIIIMIIIUIIIII 111111 IIIIIIIIIIIIIIIIIIIIII NM IIIIIII NM 111111111111111111111111111111 Tob1 anew TIM!*om ,y Total fur rh(s Annulus MUD WATER DESEL OTHER Today . P ,Woos D$y TOTAL, VOLUMES FOR DAY: 1 01 /!X) 1 5 0 1 7" /4 15 5Es'6 t L GEL 4-GEL X -TND BICARB PH 6 -' ADOIT7VES NIGHTS USED: DAYS I � CTIOhf SUPERVISOR: I . J R s 'Z..�, I I pHDT T .. "---- 1 • • NABORS RIG 19E - DAILY ANNULAR INJECTION RECORD Page DATE: I 575-60 1 INJECTING INTO ANNULUS OF WELL: l 24 -313 0000 TO 2400 HRS FLUIDS CAME FROM WELL: L.2 L - 31* J Page of BARRELS INJECTED List under roper fluid . - FOR MUD ONLY: PUMP STATIC INJECTION TOTAL START RATE PRESSURE PRESSURE OTHER CUMULATIVE WEKINT FUNNEEL. Tire END TIME (BPM) IPSI) (PSII MUD DIESEL (specNy( VOLUME (ma =cowl COMMENTS LO_Il 0 IMMUM1111111111111131111111111111=1 MONNEMEI 10 E. O '5 ? Q . Sav P1111=111111111111111111 o /0.2 014 In r 7 1 ! E 3 ,,,,,r' /#n 2 NEI 1111111111111111111111111111 . r ! ..za' - '40 ems 111111111111111EMIIIIIIIIIIMMIIIIIIIIII was 10 Cpl T0 u c: MEN " 11111111111M111111 8 111111 ifrA . f :454 ;. 3 too load 3D A* 4) 1). 7 /icA) (4c:,:2, t MENIMMWMANOMMIEM 111111111111111111111111111111111111111111111111111111 11111111111111111111111111111 11111111111111111111111111111 111111111111111111 Mai= Tow For CormmulatiVe Wit from Maw total lot Mks ann MOD WATER DtE'SEL Mel Today Previous DaY TOTAL. VOLUMES FOR DAY: 1123 1 55 1 . 1 --M 2 0 I I 1 + 38e t t ) 7-1 1 6 GEC. Q-GEL X -TND BICARB PH • ADD nvES NIGHTS USED: DAYS • 1 IDAY)NJE +' SUM VISOR: L. !.5 '0 SENT BY' . 11-20- 0 · 6:04PM ; PHILLIPS AK INC~ STATE OF ALASKA I -- { ALASKA OIL, AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1, Type of request; Ab~don _ Suspend_ Operational shutdown _ Re-enter suspen(lo¢l well _ Alter casing _ R~palr well_ Pit~jgtng. Tirrm ex4'enalon _ SUmulale _ Olher_X Qhange approved pm,.g?.m= ..... Pull tubing _ Variance.. Perforate _ Anltular Injection 2. Name o! operator 6. Type of Well: 6, Datum elevation (DF or KB Phillips Alaska, Inc. Developrn~n! __X RKB 28 feet ,,. 3. Address Exploratory 7. Unit or Property name' P_ O. Box 100360 Straflgra0hl= Anchorage, A..K....g...9510-0360 se~lce _.. Kuparuk. River Unit 4. Location of well at surface 8. Well number 177' FNL, 690' FEL, Sec, 22, T10N, R7E, UM 2L-313 At top of productive interval 9. Permit number / approval number 1569' FSI_, 1320' FWL, Sec. 24, T10N, R7E, UM 98-21g At effective depth 10. APl number 50-103-20277-00 .... At total depth 11. Field / Pool 1313' FSL, 1822' FWL, Sec. 24, T1 ON, R7E, UM Kup,a~k River Field / Tarn Oil Pool 12, Present ~ell condition summary Total depth; measured 11140 feet Plugs (measl~ed) true vertical 5773 feet Effective depth: measured 10982 feet Junk.(measured) ~'ue vertical 5690 loot Casing Length ~ize Cemented Measured Depth Tree vertical Depth Conductor 80' 16" 9 mi. Yds High Early' 108' Surface 2579' 7.625' 280 sx ASIIILW & 230 sx Class G 2607' 2299' Intermediate 10277' 5,5" x 254 sx cass e 10305' 5321' Production 807' 3.5' 11112' $768' Perforation depth: measured 10676'-10716' . true vorUcal . :i . ~ Tubing (size, grade, and measured depth 3.{~', 9.3#, DS0 @ 10300' Pa~kere & $SSV (type & measured depth) Baker Csg Seal Receptacle (CSR) @ 10286', No SSSV 13-.'A'0~a~'hments Oeecrlptlof~ ~'~m~ry ;)f'"~;poaal ~ Detailed operations program ~ BOP sketch __ - .................... Refer to atlached morning drilling report fat LOT test, sub/ace cement de~l~ and easing detail sheets _ · 14. Estimated date for commenoing operation 15, Status. of well classlflcatlor~ as; November 21, 2000 16. If proposal'was verbally approved Oil ~X Gas __ Suspended _ _ Name of approver Date approv .ed.,..,..., 8ewice ~ 17. I hereby cerflf! that Ihs foregoing la true and coerecl' to 1he baal of my knowledge. QUOSlfOI~S? C~tff Bffal~. FOR COMMISSION USE ONLY CondRIons o~ approval: Notify Commission so representative may wilness Approval Plug Integrlly _ UrJp lest _ LOC~lon cteamnce ....-- I', ,__ Mochatl~ca, Integrity To~'I._ . sub~equen, term required ,o- I'-~. ~ .t . T- ~ Form 10-.403 Rev 06/lS/88 * SUBI:dlT IN TRIPLICATE Phillips Alaska, Inc. Post Office Box 100360 · ..... Anchorage, Alask~ 9~S10-0360 November 20, 2000 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage. AK 99501-3192 Re; Application for Sundry Approval for Annular Injection into KRU 2L-313 Dear Mr. Maunder, Phillips Alaska, Inc. hereby files this Application for Sundry, Approval for resuming/?,nnular Injection into KRU 2L-313. Please reference the following documents on file whJchlsupply the information required by 20 AAC 25.080: Original Permit to Drill (permit ~98-219) approved 11/./5/98 Application for Sundry Approval of Annular Injection (permit ~"398-333) approved 12/2:1/98 Cumulative volume Injected to date is 17,27~ bbls. Dates, volumes, and soume v~ells for fluids are as follows: March 1999 8654 bbls from 2L-307 April 1999 3879 bbls from 2L-307 May 2000 4740 bbls [rom 2L-317 If you have questions or require additional information, please contact Brian Noel at 21.~$- 6979 or me at 265-6434 in our Anchorage office. Sir~cerely, .- James Trantham Drilling Engineering Supervisor Attachments: Information as required cc: KRU 2L-313 Well File Re: 2L-313 Resumption of Annular Disposal Subject:' Re: 2L-313 Resumption of Annular Disposal Date: Thu, 30 Nov 2000 10:15:26 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Brian Noel <bnoel@ppco.com> Brian, Thanks for calling back. With regard to gathering the pressure information, what we would like is representative pressure data from 2L-315 and -321 during the disposal pumping on 2L-313. I believe that can be accomplished by taking pressure readings on both wells prior to initiating a disposal batch, a couple of readings while the disposal is taking place and a final set of readings when the batch is finished. These readings would be repeated for each batch. Please give a shout back with any questions. Also please pass this information to Randy. I did put a call in to him and am having difficulty emailing him for some reason. Thanks. Tom Tom Maunder wrote: > Brian, > Thanks for the additional information with regard to the wells > surrounding 2L-313. > By copy of this message, you have approval to resume annular disposal > into 2L-3'13. in addition to the pressure and rate information normally > collected by the disposal pump operator, we also desire that the > pressures on the surface casing x production casing annuli on wells > 2L-315 and 2L-321 be reoorded prior to beginning disposal pumping and > while fluids are being injected into 2L-313. At the oonclusion of the > current well, please submit the disposal operator's information and the > pressure monitoring information to the Commission. > Thank you for working with us and providing the requested information. > Please contact me with any questions. Tom Maunder Petroleum Engineer Tom Maunder <tom maunder~,admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission I nfl 11/30/00 2:30 PM ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 24, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Revised Kuparuk Area Annular Injection, Fourth Quarter, 1999 Dear Ms. Mahan: RECEIVED Anchorage - - Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the fourth quarter of 1999. Annular Injection during the fourth quarter of 1999' h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-37 15214 100 0 15314 17273 32587 CD1-39 27391 100 0 27491 4017 31508 1D-12 27089 100 0 27189 5702 32891 CDI-16 28925 100 0 29025 0 29025 CD1-32 7449 100 0 7549 0 7549 CD1-03 285 100 0 385 0 385 CD1-42 287 100 0 387 0 387 CD1-40 20 0 0 20 32649 32669 CD1-45 274 100 0 374 0 374 CD1-36 293 100 0 393 0 393 CD1-35 217 100 0 317 0 317 CD1-23 20 0 0 20 17085 17105 CDi-13 89 100 0 189 0 189 CD1-01 20 0 0 20 5201 5221 Total Volumes into Annuli for which Injection Authorization Expired during the fourth quarter Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injectedi Status of Annulus 2N-315 25326 100 0 25426 ] Open, Freeze Protected 2L-329A 33971 100 0 34071 I Open, Freeze Protected 2L-325 20280 100 0 20380 I Open, Freeze Protected 2L-313 I 12433 ~ 100 0 12533 i! Open, Freeze Protected Ms. Wendy Mahan AOGCC Fourth Quarter 1999 Annular Injection Report Page Two Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Well Files ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 27, 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, Second Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the second quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the second quarter of 1999. Annular bijection during the second quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 1C-15 34380 100 0 32195 16795 48990 2L-313 3779 100 0 3879 8654 12533 CDI-19 33933 100 0 34033 0 34033 1C-25 34216 100 0 34316 0 34316 CD1-40 12071 100 0 12171 0 12171 1C-23 9505 100 0 I 9605 0 9605 Total Volumes into Ammli for which h~jection Authorization Expired during the quarter Total I Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus ID- 10 35473 100 0 35573 Open, Freeze Protected 2N-323 32696 100 0 32796 Open, Freeze Protected 2N-343 17895 100 0 17995 Open, Freeze Protected 2N-329 9 100 0 109 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader Ms. Wendy Mahan AOGCC Second Quarter 1999 Annular Injection Report Page Two CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Momson and Winfree Sharon Allsup-Drake Well Files PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 25, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, S~ond Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the second quarter of 2000, as well as total volumes: injected into annuli for which injection authorization expired during the second quarter of 2000. Annular Injection during the second quarter of 2000: h(1)- h(2) h(3) Totalfor Previous New Well Name Volume Volume Volume Quarter ' Total Total 2N-341 20406 100 0 20506 0 20506 '~ 2L-313 4640 100 0 4740 1~533 17273 CD1-40' 108' 100 0 208 32669 32877 CD1-23 16751 100 0 16851 1~135 33986 CDI-16 25 0 0 25 29025 29050 CD1-32~ 82 100 0 182 33331 33513 CD1-38 11056 100 0 11156 9164 20320 -, CD1-27 32333 100 0 32433 381 32814 1~-28 5853 100 0 5953 3984 9937 ID-Il 135 100 0 235 0 235 1D-14 ' 1337.6 100 0 1437.6 0 1437.6 CD1-25 8141 100 0. 8241 ~86 8627 · CD1-34 278 100 0 378 0 378 RECEIVED jUL 26 2000 ~:-_..,1o "'.:.; .r, .. ' .~ ~.a (nj & Gas,..,_,,-r,, ,.,.,., Commissiog ~" .... Ms. Wendy Mahan AOGCC Second Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the second quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD 1-19 33933 100 0 34033 Open, Freeze Protected 1 C-25 34836 100 0 34936 Open, Freeze Protected CD1-40 32777 100 0 32877 Open, Freeze Protected 1 C-23 34470 100 0 34570 Open, Freeze Protected 1 C- 18 0 0 0 0 Open, Freeze Protected CD 1-35 217 100 0 317 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Doug Chester Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files jUL £6 ~OOa 0i-i & ,6as 0.or,,s. Commission Anchorage To: State of Alaska May 20, 1999 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. *no or , 99S0 v- c5 RE: MWD Formation Evaluation Logs 2L-313, AK-MM-90017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ Yma Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 2L-313: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20277-00 2"x 5" TVD Resistivity 8: Gamma Ray Logs: 50-103-20277-00 2"x 5" MD Neutron & Density Logs: 50-103-20277-00 2" x 5" TVD Neutron & Density Logs: 50-103-20277-00 t, aAv ? ! 1999 Aia~ 0i! & Gas Cons. C0mmiaai0n An~0rage t Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELL LOG TRANSMITTAL To: State of Alaska May 8, 1999 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2L-313, AK-MM-90017 1 LDWG formatted Disc with verification listing. API#: 50-103-20277-00 PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO ~ ATTENTION OF: Sperry-Sun Drilling Service Attn: fan Galvin 5631 Silverado Way, Suite G. Date: ·" t,.,,~L/,..t,~, '~,~i~} ~'~' ~ ' 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ARCO Alaska, Inc. Post Office Bo;-¢ ~o0360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 9, 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, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular Injection during the first quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-315 25326 100 0 25426 See Note iqJ betow25426 2L-325 8397 100 0 8497 11883 20380 2N-321A 27507 100 0 27607 0 27607 3K-23 15 0 0 15 0 15 3K-25 4202 100 I 0 4302 0 4302 1C-15 16695 100II 0 16795 0 16795 2L-313 8554 100 [ 0 8654 0 8654 Note iql: Well iq 2N-315. The previously re 9orted volume of 220 barrels },,as pumped into this annulus during the drilling of the well. This was the volume required to flush and freeze protect the annulus during initial drilling operations, not a volume of disposalfluids injected prior to the receipt of authorization Jbr annular injection. Total Volumes into Annuli for which b~jection Authorization Expired during the quarter Total . Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus 1C-12 34995 100 0 ] 35095 Open, Freeze Protected 1C-13 26800 100 0I 26900 Open, Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO's, we would like to repeat and supplement information we provided with our letter of February 26,1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26th letter, and are only reported here again for the sake of clarity. ARCO Alaska, inc. is a Submdiarv of Atlantic Richfield Company AR3B-6003-C Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two i ! Total Total h(1) t Total h(2) [ Total h(3) Volume Current Status of Well Name Volume I Volume , Volume Injected Annulus 2A-22 16749 i 100 ! 0 16849 ] Open, Freeze Protected 2F- 19 20725 ] 100 I 0 20825 ! Open, Freeze Protected 3K-27 37173 I [ 0 37273 Open, Freeze Protected 3K-26 33970 I 100 i 0 34070 Open, Freeze Protected 1E-31 33645. 100 i 0 33745 Open, Freeze Protected 1E-32 45205 [ 100 ! 0 45305 Open, Freeze Protected 3Q-22 6245 I 100 0 6345 Open, Freeze Protected 1Q-24 23158 I 100 [ 0 23258 Open, Freeze Protected 1Q-26 25931 ! 100 [ 0 26031 , Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files r'l F:! I I_1_ I IM G WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs February 24, 1999 2N-313, AK-MM-80298 1 LDWG formatted Disc with verification listing. API#: 50-103-20259-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING TltE ATrACltED COPY OF THE TRANSMITYAL LETTER TO THE AITENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: Si Note: This data replaces any previous data for well ( 2N-313 ). 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburion Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 24, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ..? Subject: 2L-313 (Permit No. 98-219) Well Completion Report Dear Mr. Commissioner: Enclosed is a well completion report for the completion on Tam 2L-313. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tarn Drilling Team Leader ORIGINAL PM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS E~] SUSPENDED [~ ABANDONED~ SERVICE [] 2' Name of Operator 7 Permit Number ARCO Alaska, Inc 98-219 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20277 4 Location of well at surface .~~.,,,~,~¢.? 9 Unit or Lease Name ;.~ ~;'~_-: ~ Kuparuk River Unit 177' FNL, 690' FEL, Sec. 22, T10N, R7E, UM ~:'!" At Top Producing Interval !i ..... '~'~j~l~ i .2 10 Well Number 1569' FSL, 1320' FWL, Sec. 24, T10N, R,E, UM .... 2 L-313 At Total Depth t 1~ Field and Pool 1313' FSL, 1822' FWL, Sec. 24, TION, R7E, UM 5 Elevation in feet (indicate KB, DF, etc.) 16 Lea~e~DesiOnation and Serial No. Tarn Oil Pool RKB 28', Pad 117'I ADL 380051 ALK 4599 12 Date13-Nov-98Spudded 13 Date19-Nov-98T'D' Reached 14 21Date-Nov-98C°mp', Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 NO.lOf Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 11140' MD & 5773' TVD 10982' MD & 5690' TVD YES X~ NO U N/A feet MD 1050 APPROX 22 Type Electric or Other Logs Run GR/Res, G PJCCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECOI~D 16" 62.5# H-40 SURF. 108' 24" 9 CY High Early 7.625" 29.7# L-80 SURF. 2607' 9.875" 280 sx ASIII LW & 230 sx Class G 5.5" x 15.5# L-80 SURF. 10305' 6.75" 254 sx Class G 3.5" 9.3# L-80 10305' 11112' 6.75" (included above) 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 10300' 10286' (CSR) 10676'-10716' MD 5526'-5548' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10676'-10716' 100824# proppant to 6.6 ppg 12/18 in perfs. Left 22632# proppant in pipe 27 PRODUCTION TEST Date First Production 2/22/99 Method of Operation Flowing (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 2/16/99 6.00 TEST PERIOI · ] 70 116 15 0 684 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 260 0 24-HOUR RATE: 680 465 60 37.7° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · .--.~.. ~:., ,';, ,.. :- · -, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. _~ 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. T-3 10472' 5414' T-2 10758' 5571' 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. ~ ~ 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: 12/4/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2L-313 WELL ID: AK9429 TYPE: -- AFC: AK9429 STATE:ALASBLA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:il/13/98 START COMP: RIG:RIG % 141 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20277-00 11/12/98 (D1) TD: 0'( 0) SUPV:D.P.BURLEY 11/13/98 (D2) TD: 2336' (2336) SUPV:D.P.BURLEY 11/14/98 (D3) TD: 2617' (281) SUPV:D.P.BURLEY 11/15/98 (D4) TD: 3604' (987) SUPV:D.P.BURLEY 11/16/98 (D5) TD: 6329' (2725) SUPV:D.P.BURLEY 11/17/98 (D6) TD: 9059' (2730) SUPV:D.P.BURLEY 11/18/98 (D7) TD:10900' (1841) SUPV:D.P.BURLEY 11/19/98 (DS) TD:lll40' (240) SUPV:D.P.BURLEY MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 LOADING PIPE SHED AND MIXING SPUD MUD. Move rig to well 2L-313. MW: 10.2 VISC: 68 PV/YP: 30/23 APIWL: 6.6 WIPER TRIP FROM 2617' NU diverter system. Accepted rig @ 0200 hrs. Perform diverter test. Drill 9-7/8" hole from 108' to 2236' MW: 10.2 VISC: 56 PV/YP: 21/14 APIWL: 6.2 TESTING BOPE. Drill from 2236' to 2617'. Run 7-5/8" casing. Pump cement. MW: 9.1 rISC: 44 PV/YP: 13/15 APIWL: 7.2 DRILLING 6-3/4" PRODUCTION HOLE FROM 4300' NU BOPE and test to 250/3500. Clean out cement and float equipment, drill 20' of new hole to 2637'. Perform FIT to 16.0 ppg. Drill 6.75" hole from 2637' to 3604' MW: 9.1 VISC: 50 PV/YP: 17/18 APIWL: 6.2 DRILLING PRODUCTION HOLE FROM 6950' Drill from 3604' to 5394'. Perform LOT, EMW=15.2 ppg. Drill from 5394' to 6329' MW: 9.1 VISC: 45 PV/YP: 13/15 APIWL: 6.2 PREP FOR WIPER TRIP @ 9600' Drill from 6329' to 9059' MW: 9.8 rISC: 52 PV/YP: 14/19 APIWL: 5.0 WIPER TRIP TO SHOE. Drill from 9059' to 10900' MW: 9.8 VISC: 50 PV/YP: 12/14 APIWL: 4.2 RUNNING PRODUCTION CASING. Drill from 10900' to 11140' 11/20/98 (D9) TD:lll40' ( 0) SUPV:D.P.BURLEY 11/21/98 (D10) TD:lll40' ( 0) SUPV:D.P.BURLEY MW: 9.8 VISC: 44 PV/YP: 10/16 RUNNING 3-1/2" COMPLETION. APIWL: 4.8 Run 3.5" and 5.5" casing. Cement casing. ND BOPE. MW: 8.5 VISC: 28 PV/YP: 0/ 0 RELEASED RIG @ 1900 HRS. APIWL: 0.0 Run 3.5" completion. Freeze protect well. ND BOPE, NU master valve and test to 5000 psi. Release rig @ 1900 hrs. 11/21/98. Date 11/28/98 Upcoming ~ Well Name 2L-$13 Job Num Service Type ELECTRIC LINE Unit 1126981747.1 AFC K85108 0 Prop 180KNU2 Uploaded to S Desc of Work PERF Supervisor KRALICK Contractor Key Person SWS-JOHNSON Complete [~ Successful [~ Accident E~ Initial Tbg Press 0 Final Tbg Press 200 Injury E~] Initial Int Csg Press 500 Final Int Csg Press 500 Spill ~] Initial Out Csg Press 0 Final Out Csg Press 0 Summary PERF USING 2.5" HC/BH/180 DEGREE PHASED/4 SPF FROM 10,716' - 10,696' & 10,696' - 10,676' - SHOT W/200 PSI OVERBALANCE ON [Perf] Date printed: 01/29199 at: 14:36:39 Date 11/29/98 Well Name 2L-313 Service Type PUMPING Up~;O"ming Job Num 1129981629.1 Unit Desc of Work INITIAL FRAC Supervisor JOHNS Contractor Key Person Complete C~ Successful [~ Accident I~1 Initial Tbg Press 0 Injury I--1 Initial Int Csg Press 500 Spill I~1 Initial Out Csg Press 200 Summary AFC K85108 0 Prop 180KNU2 Uploaded to S DS-YOKUM Final Tbg Press 1500 Final Int Csg Press 500 Final Out Csg Press 200 FRAC PRESSURED OUT EARLY WITH 100824 # PROPPANT TO 6.6 PPG 12/18 IN PERFS. LEFT 22632# PROPPANT IN PIPE. AVERAGE TREATING PRESSURE 4500 TO 5000 PSI. MAX TREATING PRESSURE 7800 PSI. [Frac-Refrac] Date printed: 01129199 at: 14:37:27 iiii ~1 ii i i I i .__ . ii SURVEY CALCULATION AND FIELD WORKSHEET i ~ Job No. 0451-02317 Sidetrack No. __ 1 of .5 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2L/313 Survey Section Name TARN 2L 313 BHI Rep, j~i~r~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -176.99 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~- Target Description Target Coord. E/W Slot Coord. E/W -689.52 Magnl Declination 26.800 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 30m~ lOm~ Vert. Sec. Azim. 115.83 Magn. to Map Corr. 26.800 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Type Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL (FT) (DD) (DD) (F'r) (FT) (FT) (F'I~ (Per 100 FT) Drop (-) Left (-) · MWD 108.00 0.00 0.00 108.00 0.00 0.00 0.00 TIE IN POINT 13-0CT-98 MWD 134.32 O, 11 77.15 26,32 134.32 0.02 0.01 0.02 0.42 0.42 SPUD @ 10:00 11-13-98 13-0CT-98 MWD 220.01 0.26 194.42 85.69 220,01 O. 12 -0,16 0.06 0,38 O. 18 13-0CT-98 MWD 308.81 0.07 133.20 88.80 308.81 0.21 -0,40 0.05 0.26 -0.21 13-0CT-98 MWD 402,51 .0.20 116.67 93.70 402.51 0,43 -0,51 0,23 O, 14 O. 14 13-0CT-98 MWD 501.57 0.21 73,27 99.06 501.57 0,74 -0.53 0.56 O. i 5 0.01 13-0CT-98 MWD 590.36 0.15 42. i 4 88.79 590.36 0.89 -0.40 0.80 O. 13 -0,07 60'@117M 13-0CT-98 MWD 681,76 1,77 105,28 91.40 681.74 2.31 -0,68 2,24 1,87 ! ,77 30'@117M 13-0CT-98 MWD 772.53 5.11 101,60 90.77 772.34 7.61 -1.87 7,55 3.69 3.68 -4,05 30'20R 13-0CT~98 MWD 863.01 6.52 113,13 90.48 862.35 16.65 -4.70 16,22 2.02 1.56 12.74 30'20R 13-0CT-98 MWD 951.82 8.18 119.42 88.81 950.43 27,99 -9.78 26.36 2,07 1.87 7.08 60'HS 13-0CT-98 MWD 1041,60 10.26 118,14 89.78 1039.05 42.36 -16.69 38.98 2,33 2.32 -1.43 30'20L AI'1%I Ali I A I UKIblNAL 13-0CT-98 MWD 1224.09 16.04 118.07 90,01 1216.46 84.74 -35.91 76.76 2.60 2.52 2.43 60'HS 13-0CT-98 MWD 1317.10 18,98 117,32 93.01 1305.15 112,71 -48.90 101.55 3,17 3.16 -0,81 30'HS 13-0CT-98 MWD 1410.22 22.81 119.04 93.12 1392.13 145,88 -64.62 130,79 4,16 4.11 1.85 30'HS 13-0CT-98 MWD 1504.76 24.88 116.69 94.54 1478.60 184.07 -82.45 164.59 2.41 2.19 -2,49 60'HS 13-0CT-98 MWD 1597,95 27.36 116.98 93,19 1562.27 225.08 -100,97 201.19 2.66 2.66 0.31 30'HS , r'~ ,~-~ ~"., ~ , L, . 13-0CT-98 MWD 1692.52 32.00 115.65 94,57 1644.41 271.89 -121,69 243.17 4,96 4.91 -1.41 30'HS 13-0CT-98 MWD 1786.07 32.65 119.81 93.55 1723.47 321.86 -144.97 287.41 2.48 0.69 4.45 60'HS 13-0CT-98 MWD 1880.79 34.63 118,01 94.72 1802.33 374.25 -170,31 333,35 2.34 2.09 -1.90 30'10L 13-0CT-98 MWD 1971.67 38,77 118.32 90,88 1875,18 428.51 -195,95 381.22 4.56 4.56 0,34 30'10L 13-0CT-98 MWD 2066,15 40.94 117,37 94.48 1947.70 489.01 -224.22 434,76 2.39 2.30 -1.01 45'HS 13-0CT-98 MWD 2157.53 42.58 117.54 91.38 2015,86 549.84 -252.28 488,76 1.80 1.79 0,19 45'HS SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02317 Sidetrack No. Page 2 of 5 '~11~11~11~/~ Company ARCO ALASKA, INC. Rig Contractor & No. Doyen Drilling Co. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2L/313 Survey Section Name TARN 2L 313 BHI Rep. ~l~r~l~ WELL DATA Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -176.99 Grid Correction 0.000 Depths Measured From: RKB ~'1 MSL ~ SS~- Target Description Target Coord. E/W Slot Coord. E/W -689.52 Magn. Declination 26,800 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m[--] 10m~ Vert. Sec. Azim. 115.83 Magn. to Map Corr. 26.800 Map North to: OTHER i SURVEY DATA Survey SUrvey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (FT) '(DD) (DD) (FT) (FT) (FT) (FT) i(Per 100 FT) Drop (-) Left (-) ~.. ~T-98 MWD 2254.29 46.51 119.77 96.76 2084.82 617.61 -284.85 548.28 4.37 4.06 2.30 40'20L 14-OOT-98 MWD 2344.52 50.10 117.59 90.23 2144.83 684.89 -317.15 607.39 4.37 3.98 -2.42 40'15L 14-OCT-98 MWD 2440.24 '53.44 117.23 95.72 2204.05 760.04 -351.75 674.13 3.50 3.49 -0.38 30'HS 14-OCT-98 MWD 2535.07 55.73 119.95 94.83 2259.01 837.21 -388.75 741.96 3.36 2.41 2.87 15-OOT-98 MWD 2649.69 56.47 119.35 114.62 2322.94 932.14 -435.81 824.64 0.78 0.65 -0.52 15-OCT-98 MWD 2745.80 61.28 115.67 96.11 2372.62 1014.33 -473.73 897.60 5.98 5.00 -3.83 15-OCT-98 MWD 2837.52 64.56 113.79 91.72 2414.37 1095.97 -507.87 971.77 4.01 3.58 -2.05 '1 i 5-OCT-98 MWD 2924.21 66.53 113.94 86.69 2450.25 1174.83 -539.80 1043.93 2.28 2.27 0.17 15-OCT-98 MWD 3023.38 66.46 114.06 99.17 2489.80 1265.72 -576.79 1127.01 0.13 -0.07 0.12 15-OCT~98 MWD 3119.08 68.29 114.66 95.70 2526.62 1354.03 -613.23 1207.48 2.00 1.91 0.63 15-OCT-98 MWD' 3213.97 68.65 112.86 94.89 2561.45 1442.23 -648.79 1288.26 1.80 0.38 -1.90 15-OCT-98 MWD 3306.34 68.68 113.27 92.37 2595.05 1528.17 -682.49 1367.42 0.41 0.03 0.44 -- ~. ?)T-98 MWD 3399.61 69.22 114.93 93.27 2628.55 1615.17 -718.04 1446.88 1.76 0.58 1.78 15-OCT-98 MWD 3495.68 67.19 113.65 96.07 2664.22 1704.34 -754.74 1528.18 2.45 -2.11 -1.33 15-OCT-98 MWD 3586.49 67.32 116.18 90.81 2699.34 1788.07 -790.01 1604.12 2.57 0.14 2.79 16-OCT-98 MWD 3678.87 67.53 115.26 92.38 2734.80 1873.37 -827.03 1680.97 0.95 0.23 -1.00 16-OCT-98 MWD 3773.70 67.61 115.88 94.83 2770.99 1961.02 -864.86 1760.04 0.61 0.08 0.65 16-OCT-98 MWD 3868.48 67.79 115.30 94.78 2806.95 2048.71 -902.74 1839.13 0.60 0.19 -0.61 16-OCT-98 MWD 3962.95 68.09 116.50 94.47 2842.43 2136.26 -940.98 1917.89 1.22 0.32 1.27 16-OCT-98 MWD 4057.50 68.53 116.71 94.55 2877.38 2224.11 -980.33 1996.44 0.51 0.47 0.22 16-OCT-98 MWD 4151.76 69.45 115.57 94.26 2911.17 2312.10 -1019.09 2075.43 1.49 0.98 -1.21 16-OCT-98 MWD 4244.92 69.06 115.20 93.16 2944.17 2399.22 -1056.44 2154.14 0156 -0.42 -0.40 16-OCT-98 MWD 4340.61 68.41 115.93 95.69 2978.88 2488.39 -1094.92 2234.58 0.98 -0.68 0.76 16-OCT-98 MWD 4434.42 68.50 114.85 93.81 3013.33 2575.64 -1132.33 2313.41 1.08 0.10 ,-1.15 Company ARCO ALASKA, INC. Rig Contractor &'No. Doyon Drilling Co.- #141 Field ' TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2L/313 Survey Section Name TARN 2L 313 BHI Rep. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -176.99 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -689.52 Magn. Declination 26.800 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft[~ 30m~ 10m~ Vert. Sec. Azim. 115.83 Magn. to Map Corr. 26.800 Map North to: OTHER ii i ii SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+)/W(-) DL Build (+) Right (+) Comment Type (ET) (DD) (DD) (FO (FT) (FT) (FT) (Per lO0, ET)Drop (-) Left (-) -- 1(, ~'r.98 MWD 4527.15 68.31 116.20 92.73 3047.46 2661.86 -1169.48 2391.21 1.37 -0.20 1.46 16-0CT-98 MWD 4623,14 68.36 115.14 95.99 3082.90 2751.06 -1208,13 2471.62 1.03 0.05 -1.10 1,6-0CT-98 MWD 4718.69 68.23 115.85 95.55 3118.23 2839.84 -1246.34 2551.75 0.70 -0.14 0.74 16-0CT-98 MWD 4811.17 68.77 115.17 92.48 3152.13 2925.88 -1283.39 2629.40 0.90 0.58 -0.74 .... 16-0CT-98 MWD 4906.74 68.78 115.44 95.57 3186.73 3014.96 -1321,47 2709.94 0.26 0.01 0.28 16-0CT-98 MWD 5002.69 68.46 115.50 95.95 3221.71 3104.31 -1359;90 2790.61 0.34 -0.33 0.06 16-0CT-98 MWD, 5095.17 68.05 115.76 92.48 3255.97 3190.21 -1397.05 .2868.05 0.51 -0.44 0.28 16-0CT-98 MWD 5189.44 68.34 114.29 94.27 3290.99 3277.72 -1434.07 2947.36 1.48 , 0,31 -1.56 16-0CT-98 MWD 5282.84 68.25 115.28 93.40 3325.53 3364.48 -1470.45 3026.14 0.99 -0,10 1.06 16-0CT-98 MWD 5376.93 68.30 115.69 94.09 3360.36 3451.89 -1508.06 3105.04 0.41 0.05 0.44 16-0CT-98 MWD 5470.18 68.54 115.66 93.25 3394.65 3538.60 -1545.63 3183.20 0.26 0.26 -0.03 16-0CT-98 MWD 5563.59 68,33 115.69 93,41 3428.99 3625,47 -1583.27 3261.49 0.23 -0.22 0.03 -- \ 1 .~,~T-98MWD 5657.22 68.27 116.31 93.63 3463.61 3712.47 -1621.40 3339.68 0.62 -0.06 0.66 16-0CT-98 MWD 5752.50 68.37 114.52 95.28 3498.81 3801.00 -1659.40 3419.65 1.75 O. 10 -1.88 16-0CT-98 MWD 5842.19 68.33 115.79 89.69 3531.90 3884.35 -1694.83 3495.10 1.32 -0.04 1.42 16-0CT-98 MWD 5938.38 68.11 115.62 96.19 3567.59 3973.68 -1733.58 3575.59 0.28 -0.23 -0.18 ' : , 16-0CT-98 MWD 6030.74 67.68 115.10 92.36 3602.34 4059.24 -1770.23 3652.91 0.70 -0.47 -0.56 ..... 16-0CT-98 MWD 6123.03 67.06 115.01 92.29 3637.86 4144.42 -1806.30 3730.08 0.68 -0.67 -0.10 . 16-0CT-98 MWD 6217.52 66.83 113.99 94.49 3674.86 4231.34 -1842.36 3809.19 1.02 -0.24 -1.08 .I 17-0CT-98 MWD 6311.51 66.13 114.56 93.99 3712.37 4317.49 -1877.79 3887.75 0.93 -0.74 0.61 25' 30R 17-0CT-98 MWD 6406.75 68.27 116.07 95.24 3749.28 4405.27 -1915.33 3967.11 2.68 2.25 1.59 17-0CT-98 MWD 6501.98 69.16 116.94 95.23 3783.85 4494.00 -1954.93 4046.51 1.26 0.93 0.91 -- 17-0CT-98 MWD 6594.66 69.83 116.58 92.68 3816.31 4580.79 -1994.02 4124.02 0.81 0.72 -0.39 ._ 17-0CT-98 MWD 6689.34 69.64 117.20 94.68 3849.10 4669.60 -2034.19 4203.24 0.65 -0.20 0.65 i i i ii i i i i i ri t rr , SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02317 Sidetrack No. Page 4 of 5~ Im == [m,r~_= I ::(---~j Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD m Well Name & No. TARN DRILLSITE 2L/313 Survey Section Name TARN 2L 313 BHI Rep. ~Nt'F~I~ WELL DATA TargetTVD (FO Target Coord. N/S SlotCoord. N/S -176.99 Grid Correction 0.000 Depths Measured From: RKB~ MSL[-] SS[- Target Description Target Coord. E/VV Slot Coord. E/W -689.52 Magn. Declination 26.800 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 3Om I-] lOm~ Vert, Sec. Azim. 115.83 Magn. to Map, Corr. 26.800 Map North to: OTHER i SURVEY DATA SurveY 'Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date ,tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) . DL Build (+) Right (+) Comment Type (FO (DD) (DD) (FO (FO (FO (FO (Per 100 ET) Drop (-) Left (-) 1' ~1T-98 MWD 6781.60 69.44 117.62 92.26 3881.35 4756,00 -2073.98 4279.98 0.48 -0.22 0.46 17-0CT-98 MWD 6875.19 69.41 117.22 93.59 3914.24 4843.59 -21 '14.33 4357.75 0.40 -0.03 -0.43 17-0CT-98 MWD 6970.69 69.41 116.68 95.50 3947.83 4932.97 -2154.85 4437.44 0.53 0.00 -0.57 17-0CT-98 MWD 7063.28 69.22 117.39 92.59 3980.54 5019.57 -2194.22 4514.60 0.75 -0.21 0.77 17-0CT-98 MWD 7159.11 67.91 116.33 95.83 4015.56 5108,76 -2234..52 4594.17 1.71 -1 ;37 -1.11 15' 150L 17-0CT-98 MWD 7256.68 67.93 115.90 97.57 4052.23 · 5199.17 -2274.32 4675.35 0.41 0.02 -0.44 17-0CT-98 MWD 7345.42 67.8'2 115.72 88.74 4085.66 5281.38 -2310.11 4749.36 0.23 -0.12 -0.20 17-0CT-98 MWD 7439.95 65.57 114.80 94.53 4123.05 5368.18 -2347.16 4827.87 2.54 -2.38 -0.97 15' 170L 17-0CT-98 MWD 7536.30 65.49 115.27 96.35 4162,96 5455.87 -2384.27 4907.32 0.45 -0.08 0.49 17-0CT-98 MWD 7632.60 65.35 116.90 96.30 4203.02 5543.44 -2422.78 4985.97 1.55 -0.15 1,69 17-0CT-98 MWD 7725.55 65.49 115.36 92.95 4241.69 5627.96 -2460.00 5061.86 1.51 O. 15 -1.66 · 17-0CT-98 MWD 7819.66 65.64 117.23 94.11 4280.62 5713.63 -2497.96 5138,67 1,82 O. 16 1.99 I 1' ~T-98 MWD 7913.03 65.85 117.15 93.37 4318.98 5798.74 -2536.86 5214.39 0.24 0.22 -0.09 / 17-0CT-98 MWD 8005.22 66.16 117.94 92.19 4356.47 5882.92 -2575.80 5289.06 0.85 0.34 0.86 17-0CT-98 MWD 8099.35 66.76 118.29 94.13 4394.06 5969.15 -2616.47 5365.18 0.72 0.64 0.37 17-0c'r-98 MWD 8196.27 66.56 117.75 96.92 4432.46 6058.07 -2658.28 5443.73 0.55 -0.21 -0.56 15' 90L 17-0CT-98 MWD 8288,66 66.61 117.88 92.39 4469.17 6142.80 -2697.84 5518.72 0.14 0.05 0.14 ,,. 17-OCT-98 MWD 8476.86 66.46 115.17 93.16 4544.32 6315.33 -2774.06 5673.50 0.72 0.06 -0.78 '! ":~. ~:~. ...... ~ ......... 17-OCT-98 MWD 8572.10 66.29 113.28 95.24 4582.49 6402.55 -2809.87 5753.07 1.83 -0.18 -1.98 17-ooT-98 MWD 8666.73 66.03 115.17 94.63 4620.74 6489.07 -2845.38 5832.00 1.85 -0.27 2.00 17-OCT-98 MWD 8762.25 67.33 114.33 95.52 4658.55 6576.76 -2882.10 5911.66 1.58 1.36 -0.88 15'. 10L... 17-OCT-98 MWD 8855.42 68.25 113.94 93.17 4693.77 6662.98 -2917.36 5990.37 1.06 0.99 -0.42 17-OCT-98 MWD 8950.73 68.58 114.75 95.31 4728.83 6751.58 -2953.90 6071.12 0.86 0.35 0.85 SURVEY CALCULATION AND FIELD WORKSHEET JobNo. 0451-02317 Sidetrack No. Page 5 of 5 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #141 . Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2L/313 Survey Section Name TARN 2L 313 BHI Rep~ IIII I WELL DATA Target 'I-VD (FT) Target Coord. N/S Slot Coord, N/S -176.99 Grid Correction 0.000 Depths Measured From: RKB ~ MSL [-] SS[~ Target Description Target Coord. E/W Slot Coord. E/W -689.52 Magn. Declination 26.800 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 30mD lOm[~ Vert. Sec, Azim. 115.83 Magn. to Map Corr. 26.800 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+)/S(-) E(+)/W(-) DL Build (-I-) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per lO0 FT Drop (-) Left (-) I ~:;T-98MWD 9043,68 68,59 114.57 92.95 4762.77 6838,09 -2990.00 6149.76 O, 18 0,01 -0.19 1 O' 170R 18-0CT-98 MWD 9130.14 68.33 114.16 ' 86.46 4794.52 6918.49 -3023,18 6223.02 0.53 -0,30 -0.47 1 O' 170R 18-0CT-98 MWD 9222.25 68.86 115.27 92.11 4828.13 7004.23 -3059.04 6300.91 1.26 0.58 1,21 18-0CT-98 MWD 9317.33 67,18 114.26 95,08 4863.72 7092.37 -3095.97 6380.97 2.02 -1,77 -1.06 25' 180 18-0CT-98 MWD 9409,51 67,03 i 15.34 92,18 4899.58 7177.28 ~3131.59 6458.05 1,09 -0.16 1,17 18-0CT-98 MWD 9503,05 67.52 113,76 93,54 4935.72 7263.53 -3167,44 6536.53 i .64 0.52 -1.69 118-0CT-98 MWD 9598,54 67,70 115.73 95.49 4972,09 7351.80 ' -3204.39 6616.71 1.92 O. 19 2.06 18-0CT-98 MWD 9691,34 66.63 113.13 92.80 5008.11 7437,29 -3239,77 6694,57 2.83 -1,1 5 -2.80 31' 180 18-0CT-98 MWD 9785,61 63.37 113,42 94.27 5047.95 7522.63 -3273.52 6773.04 3,47 -3.46 0,31 31' 180 18-0C'1'-98 MWD 9882.27 60,41 112,93 96.66 5093.49 7607,79 -3307,07 6851.41 3.09 -3,06 -0.51 20' 165R 18-0CT-98 MWD 9977.49 57,92 115,34 95,22 5142.29 7689.50 -3340.48 6926.02 3.40 -2.61 2.53 20' 150R 18-0CT-98 MWD 10071,87 56.80 114,07 94,38 5193.20 7768,95 -3373,70 6998.21 1.64 -1,19 -1.35 20' 165R 1 ~[iiT-98MWD 10167.29 56.61 118.09 95.42 5245.60 7848,68 -3408.75 7069.83 3.53 -0.20 4,21 20' 90R -- 18-0CT-98 MWD 10256.64 56,57 117,91 89,35 5294.79 7923,22 -3443.76 7135.68 0.17 -0.04 -0,20 18-0CT-98 MWD 10356.08 56,42 118.01 99.44 5349,69 8006.08 -3482.64 7208,92 O. 17 -0.15 0.10 18-0CT-98 MWD 10452.57 56.06 117.59 96.49 5403.31 8086.25 -3520,05 7279,88 0,52 -0.37 -0.44 18-0CT-98 MWD 10541.75 56.35 115,85 89.18 5452.91 8160,34 -3553.37 7346,07 1.65 0.33 -1.95 18-0CT-98 MWD 10634.39 56.92 116.91 92.64 5503,86 8237,71 -3587.75 7415,38 1.14 0,62 1.14 18-0CT-98 MWD 10726.64 57.53 117.53 92.25 5553.80 8315.25 -3623,23 7484,36 0.87 0.66 0,67 18-0CT-98 MWD 10821,56 57.81 116.65 94.92 5604,57 8395.44 -3659.75 7555.76 0,84 0.29 -0.93 19-0CT-98 MWD 10920.13 57,56 117.71 98.57 5657.26 8478.71 -3697,80 7629.87 0.94 -0.25 1.08 19-0CT-98 MWD 11007.64 58.25 116.03 87.51 5703.76 8552,83 -3731,30 7696.00 1.81 0.79 -1.92 19-0CT-98 MWD 11041,01 58,54 117,27 33.37 5721,25 8581.25 -3744.05 7721.40 3,28 0,87 3,72 19-0CT-98 MWD 11140.00 58.54 117.27 98,99 5772.91 8665.66 -3782.74 7796.45 0.00 0.00 0.00 TD-NOT AN ACTUAL SURVEY 1. Type of Request: Abandon STATE OF ALASKA AL,'. -~ OIL AND GAS CONSERVATION COl~ ;SION APPEiCATION FOR SUNDRY APPROVALS Suspend Operation Shutdown -- __ Alter casing Repair well Plugging Change appr-6'ved program __ -- Pull tubin~--~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X -- Exploratory Stratigraphic Service 4. Location of well at surface 177' FNL, 690' FEL, Sec. 22, T10N, R7E, UM At top of productive interval 1569' FSL, 1320' FWL, Sec. 24, T10N, R7E, UM At effective depth At total depth 1313' FSL, 1822' FWL, Sec.24, T10N, R7E, UM Re-enter suspended well -- __ Time extension Stimulate Variance__ P~-rforate -- Other X Annular Injection 6. Datum elevation (DF or KB) 28' RKB feet 7. Unit or Property name Kuparuk River Field 8. Well number 2L-313 9. Permit number 98-219 10. APl number 50-103-20277 . 11. Field/Pool : Kuparuk River Field/Tarn Oil Pool 12. Present well condition summary Total Depth: measured 11140' (approx) true vertical 5773' Effective depth: measured 10982' (approx) true vertical 5690' Casing Length Size Structural Conductor 80' 16" Surface 2579' 7.625" Intermediate Production 10277' 5.5" x Liner 807' 3.5" Perforation depth: measured feet Plugs (measured) feet feet Junk (measured) feet None Cemented 9 Cu High Early 280 sx ASlllLW & 230 sx Class G Measured depth True verticaldepth 108' 108' 2607' 2299' 254 sx Class G 1O3O5' 5321' 11112' 5758' IApproval Date /~;~ ... j/..../ ~ SUBMIT IN TRIPLICATE Approved by the order of the Commission Form 10-403 Rev 06/15/88 ,.~-~al ,~igned By O~vid W. Johnston Commissioner true vertical 5526'-5548' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 10300' Packers and SSSV (type and measured depth) Baker Csg Seal Receptacle (CSR) @ 10286', No SSSV 13. Attachments Description summary of proposal Detailed operation program Contact Paul Mazzolini at 265-4603 with any questions.. X LOT-~est, surface cement details and casing deta-'~-sheets 14. Estimated date for commencing operation 15. Status of well classification as: December 18, 1998 Oil X Gas 16. If proposal was verbally approved -- Name of approver Date approved Service 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Signed ~'"~~~1/')~.,~,~.~..~,.~, Title Tarn Drilling Team Leader Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical In-~grity Test Subseque~-form require 10- Suspended__ 10676'-10716' BOP sketch ARCO Alaska, Inc. Cementing Details Well Name: 2L-313 Report Date: 11114/98 Report Number: 3 Rig Name: DOYON 141 AFC No.: AK9429 Field: Tarn Casing Size 7-518" H°leDiameter: Angle thru KRU: I Sh°eDepth: I LCDepth: 9-7/8" 2607 2524 % washout: Centralizers State type used, intervals covered and spacing Comments: Detailed on casing talley Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.4 / 10.2 31 21I 24 14 Gels before: Gels after: Total Volume Circulated: 10~22 518 1100 Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 bbls !8.5 Spacer 0 Type: Volume: Weight: Comments: ARCO 40 10.5 Lead Cement 0 Type: J Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS III LWI 70 280 10.7 4.43 Additives: standard blend TailCement O Type: ' Mixwtrtemp: ' No. ofSacks: ' Weight: Yield: Comments: GI I 170 230 15.8 1.17 Additives: 1% S1, 0.2% D46, 0.3% D65 Displacement 0 Rate(before tail at shoe): , Rate(tail around shoe): Str. Wt. Up: Comments: 8 bpm 8 bpm 75 Reciprocation length: Reciprocation speed: Str. Wt. Down: 25 10 fprn 68 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 115,8 bbls 116.6 bbls Calculated top of cement: CP: Bumped plug: Floats held: Returns to surface Date:Il-14-98 yes yes Time:2055 hrs. Remarks:One stage job with Tam port collar contingency, 30 bbls of 10.7 ppg cement returns to surface. Cement Company: Rig Contractor: Approved By: DS DOYON D.P.BURLEY ARCO Alaska, Inc. Casing Detail 7. 625" Surface Ca$ina WELL: TARN 2L-313 DATE: 11/14/98 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RKB to LR = 28.50' TOPS Above RKB 7 5/8" Landing Joint 28.50 FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.50 28.50 jts. 39-61 7 5/8", 29.7#, L-80 BTC-mod(23 jts) 973.13 31.00 TAM 7 5/8" Port Collar 2.47 1004.13 its. 3-38 7 5/8", 29.7#, L-80 BTC-mod (36 its) 1517.07 1006.60 Gemeco Float Collar 1.31 2523.67 its 1-2 7 5/8", 29.7#, L-80 BTC-mod(2 jts) 80.99 2524.98 Gemeco Float Shoe 1.47 2605.97 Casing shoe @ 2607.44 T.D. @ 261 7' leaving 10' of rathole 29 Gemeco Bow Sprin~t CENTRALIZERS Run centralizers in center of Jts. 1,2, 38, 39, over stop collars and over casing collars on Jts. 3-14 and over collars of jts. 17, 20, 23, 26, 29, 32, 36, 42, 45, 48, 51, 54, 57. Joints 62 - 71 (10 joints) will remain in the pipe shed. Remarks: String Weights with Blocks: 75K Up, 68K Dn, 12k Blocks. Ran 61 joints of casing. Drifted casing with 6.750" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor;D,P, BURLEY CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 2L-313 D.P. BURLEY 7 5/8", 29.7 ppf, L-80, BMTC Date: 11/15/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.1 ppg Hole Depth: 3,366' TVD LOT: 2,6O7' TMD 2,305' TVD EMW = Leak-off Press. + MW 0.052 x TVD 730 psi + 9.1 ppg EMW (0.052 x 2,305') = 15.2 ppg Fluid Pumped = 5.0 bbl Pump output = 0.1000 bps 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 'J ,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 1 O0 psi 0 psi - --- ©NE MINUTE TICKS: i; '..' .......... :! ! !!! ~ '. !!; ~ ~,. ~ '..' ; ;I ..... ,.I .............. ! I _ .-e-- LEAK-OFF TEST · -,~'- CASING TEST ......... ~.'.~.-.' LOT SHUT IN TIME [ ~~ ~ ,.._~ --/~- CASING TEST SHUT IN TIME i / - : e.~- I TIME LINE I 0246 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 70 72 74 76 78 80 82 84 86 88 90 stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk sfk stk stk STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE .................... i ..... 9. .s_ Lk. .s_ ............ .9.p..sj ...... i 2 stks 30 psi .................... -'r ....................~ ..................... i 4 stks 90 psi .................... T ..... ~'~ii~; ..... i .... ~-~-i~i .... i [ 10stks 480 psi .................... 'I' ......................................... i 12stks 620 psi .................... i .... ~-~-~-~ .... i .... -~-i;~i .... i .................... T .... ~'g-.;i~ .... i .... Y~-i;ii ..... [ 17stks 660 psi .................... T ......................................... : 18stks 640 psi . i 19stks 640 psi ..................... ~ .... ~.5.._s.t__k__s. ......... ~.!.0...p._s_! ..... [ 30stks 600 psi i 35stks , 600 psi .................... ~ .... ~6'~ii~- ........ '~6-i~i ..... .................... ? .... ~-~-~- ......... ~-i;m ..... .................... T .... g6-~'[i~ ......... '~-i;~i ..... .................... T .................... t .................... .................... T .................... t .................... SHUT IN TIME i SHUT IN PRESSURE 0.0min i 570 psi 2.0min [ [ 510 psi ..... §;a'~i-~ .... T .................... i .... -~-~'~i .... 5.0rain i i 500 psi 7.0min [ 500 psi .... l_o_..o__.m_j.n____i .................... [ .... _4_ ?_ _o_ _ _p_ _s_ ! ..... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r I ~ I stks 100 psi , i 2 stks 320 psi F .................... i ..... ~-~ii~ ........... ~,-f6"~-~i- .... ..................... i ..... ~_.s_!.k__s_ .......... ._6__4_9_p.s_.L__. [ 5 stks 800 psi ~ 6 stks 910 psi ~- ................... [ ..... Z_ .s_ !.k_ _s_ .......... !,_O.~.O__.p__s_!__, [ 8 stks 1,180 psi ~. ....................,~ .....................~ .................... : 9 stks 1,300 psi ! 10 stks 1,450 psi F .................... [ .... i-i'~ii~ .... i-:i~i~66'i~i--i ! 12 stks 1,750 psi ;- .................... ~ .................... ~ .................... i 13 stks 1,920 psi ? .................... ~. .................... ~ .................... [ 14stks ~ 2,020 psi .~ .................... ~ .................... : .................... F .................... ~ .................... 1 .................... SHUT IN TIME [ : 1.0min ! i 2,000 psi i ..... ~16-~[~' .... i .................... i'"'1'~§~6'~Ei--~ 3.0min [ : 1,970psi 4.0rain i i 1,960psi ~- .................... ~ .................... ~ .................... 5.0min i [ 1,950psi 6.0min [ : 1,940psi ~ ..................... r .................... ~ .................... 7.0min i i 1,940psi ,. .... .9_..o._.m__Ln_ .... [ .................... j.___l__,_9__3_.o__R_s_!__.~ 10.0min [ [ 1,930psi ! ..................... ,~ .................... ~ .................... 15.0rain i : 1,920psi , ..................... r .................... ~ .................... 20.0min j i 1,910 psi .... .3__o_:_o___mj..n____L .................... .', _. j _,_9__o_.o. _ .p..s. L _ _, NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 5, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2L-313 Sundry Application ORIGINAL Dear Mr. Commissioner: Enclosed is a sundry to change the bottomhole location for KRU 2L-313. In order to provide our Operations personnel additional rathole on completed Tarn wells, AAI will be drilling an additional 100' (normally 200' below the C35 marker- now 300' below the C35) on all Tarn wells. Future Permits to Drill will reflect these changes in the proposed BHL. This additional rathole should prevent the requirement of a coiled tubing clean out below the float collar which has been necessary on several wells. Sincerely, P. Mazzolini Tarn Drilling Team Leader Tarn Development PM/skad ..... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter casing __ Repair well _ Change approved program __ Operation Shutdown__ Plugging __ Pull tubing ~ Re-enter suspended well __ Time extension _ Stimulate__ Variance__ Perforate__ Other X 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 177' FNL, 690' FEL, Sec. 22, T10N, R7E, UM At top of productive interval 1271' FSL, 1318' FWL, Sec. 24, T10N, R7E, UM At effective depth At total depth 1037' FSL, 1764' FWL, Sec.24, T10N, R7E, UM 6. Datum elevation (DF or KB) 28' RKB feet 7. Unit or Property name Kuparuk River Field/Tarn Oil Pool 8. Well number 2L-313 9. Permit number ,~,~ 10. APl number 50- 11. Field/Pool Kuparuk River Field/Tarn Oil Pool 12. Present well condition summary Total Depth: measured 11251' feet (approx) true vertical 5837' feet Effective depth: measured 11251' feet (approx) true vertical 5837' feet Casing Length Size Structural Conductor 90' 16" Surface 2569' 7.625" Intermediate Production 10267' 5.5" x Liner 956' 3.5" Plugs (measured) Junk (measured) None Cemented 9 Cu High Early 220 sx ASIIILW & 240 sx Class G 260 sx Class G Measured depth True vertical depth 118' 118' 2597' 23OO' 10295' 11251' 5288' 58¢7' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3.5", L-80 Packers and SSSV (type and measured depth) N/A N/A 13. Attachments Description summary of proposal Contact Paul Mazzolini at 265-4603 with any questions. Detailed operation program BOP sketch__ 14. Estimated date for commencing operation November 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Tarn Drilling Team Leader Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No'~¢~ ~ Plug integrity_ BOP Test_ Location clearance__ C~O~,~ ~~ I - -'-'/''') -- ,5, Mechanical Integrity Test Subsequent form require 10- q,¢)7 ....-.,~" .-' ' ~k.¢~ loner Approved by the order of the Commission ~na! Signed By avi¢ W. Johnston Form 10-403 Rev 06/15/88 Date SUBMIT IN TRIPLICATE ARCO Alaska, Inc. '-- ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 5, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 DUPLICATE Subject: 2L-313 Sundry Application Dear Mr. Commissioner: Enclosed is a sundry to change the bottomhole location for KRU 2L-313. In order to provide our Operations personnel additional rathole on completed Tarn wells, AAI will be drilling an additional 100' (normally 200' below the C35 marker- now 300' below the C35) on all Tarn wells. Future Permits to Drill will reflect these changes in the proposed BHL. This additional rathole should prevent the requirement of a coiled tubing clean out below the float collar which has been necessary on several wells. Sincerely, P. Mazzolini Tarn Drilling Team Leader Tam Development PM/skad ' STATE OF ALASKA ALAS~.' OIL AND GAS CONSERVATION COMMI~SIoN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend__ Alter casing __ Repair well _ Change approved program__ Operation Shutdown __ Re-enter suspended well __ Plugging__ Time extension_ Stimulate__ Pull tubing__ Variance__ Perforate__ Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X_ Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) 28' RKB feet 7. Unit or Property name Kuparuk River Field/Tarn Oil Pool 4. Location of well at surface 177' FNL, 690' FEL, Sec. 22, T10N, R7E, UM At top of productive interval 1271' FSL, 1318' FWL, Sec. 24, T10N, R7E, UM At effective depth At total depth 1037' FSL, 1764' FWL, Sec.24, T1 ON, R7E, UM 8. Well number 2L-313 9. Permit/~,um.ber 10. APl number 50- 11. Field/Pool Kuparuk River Field/Tarn Oil Pool 12. Present well condition summary Total Depth: measured 11251' feet (approx) true vertical 5837' feet Effective depth: measured 11251' feet (approx) true vertical 5837' feet Casing Length Size Structural Conductor 90' 16" Surface 2569' 7.625" Intermediate Production 10267' 5.5" x Liner 956' 3.5" Plugs (measured) Junk (measured) None Cemented 9 Cu High Early 220 sx ASIIILW & 240 sx Class G 260 sx Class G Measured depth 118' 2597' 10295' 11251' True vertical depth 118'~!~ 52881 5837~ -~ Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3.5", L-80 Packers and SSSV (type and measured depth) N/A N/A DUPLICATE 13. Attachments Description summary of proposal __ Contact Paul Mazzolini at 265-4603 with any questions. Detailed operation program BOP sketch __ 14. Estimated date for commencing operation November 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Tarn Drilling Team Leader Date ~c~ ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test Location clearanc.¢ Mechanical Integrity Test_ Subsequen~form require 10-/--~¢ Original By Signed Approved by the order of the Commission David W, Johnston Form 10-403 Rev 06/15/88 IIAppr°val N°' %?fi~'c'-~'h? Commissioner Date ////1/,~'~ ~, SUBMIT 11'4' TRIP'LICATE II-IO-DD I ARCO Alaska, Inc .... ~ .... Pos[ Office Box 100360 Anchorage, Alaska 99510-0360 November 16, 1998 DUI Z/Q IO~.4.,R- // O r12 q -2.19 OV,.l 6 1998 Blair Wondzell Alaska Oil and Gas Conservation Commission 300l Porcupine Drive Anchorage, AK 99501-3192 Re: 2L 313 Bottom Hole Location Modification Dear Blair, As a follow up to your telephone conversation 1'1/16/98 with Paul Mazzolini, AAI would like to request verbal approval to modify the bottom hole location for 2L 313 currently being drilled by Doyon 141. As a ~esult of the Porosity information received after drilling the 2L 325 Tam well (Completed l 1/12/98), the AAI Geologists requested a change of approximately 280' to the NNE of the Target location indicated in the existing Permit To Drill 4/98-219. The new Target location will bc 1509' FSL, 1455' FWL, Sec. 24, T10N, R7E with a new BHL of 1296' FSL, 1912' FWL, Sec. 24, T:ION, R7E. A verbal approval to proceed with this drilling plan will allow continuous operations for the Doyen 141 rig. Thank you for your cooperation in this requcat for BHL modification. Tom Brassfie~ Fax # 265-6224 S taft Engineer Blair Wondzell ~/ ARCO ~2~0 1600 j 4O00 ARCO Alaska, Inc. / 51rMaf~re: T~m Drill S~e 2L W~I : ~1~ / East (feet) -> · ! i i i i I & I. i d I I I ~ I t ! i i L i ___L_. ~i ! i i i SURr~ LOCATIOH: 1 177' mC 690' i SEC. ~, TI ON, R7~ 12.~ ~Ba~ a. ~,~ Sak~nd~ 18.~ ~op ~ We~ ~k ~nd~ 7 ~ _ 24.00 27.0D ,~.~ l 15.~ AZIMUTH E~ ***Plane of Proposal*** . l~CT L~ATIO~ T~ [~gl Drop t~t ~ Mrd ~mu~ ~~ MAXIMUM ANG~ ~ - ~r.~ 68 DEG J ID ~Tl~: ~. 24, T1GN, I V r i TARGET ANGLE 55 DEG · ~ i r i i q ' ~ i' i · i -~-"~" '~' .... l ' i · I "1' i · i ~ i" i | I-~11 Ti' 'ill] ]. IL I · I II Vertical Section (feet) -> Azlmufh 115.83 with r~fm'ence 0.00 N, O.~ E from s~l t313 67.'¢g B~gln A~gle Oro~ 63~9 59.19 C~f: 2.00 ~ ~ I0~ f~ 05.24] £nd Arkie D~ap i · r [ i · i · 75O0 8~30 84O0 ~00 ~E, IN 1 ARCO Alaska, Inc. iii Into J! dj · i,.. ...... · ~llltll N ~ · Ii lyf II · I~,., ...... 11 I w I,.I, .dm ! H mi Illl, I Il N ~ lip · II ii lip Ill~ Imlf 1~1 II Il) wi ii idll Kuparuk Development P. O. BOX 100360 ANCHORAGE, AK 99510-0360 FAX At 907 265-6224 ATO-1279 Il -~ · I ' -- mu _ill · - ! qL i I ... , . -" i i . ii I 1TI --. J _ . Il . i - - H0V-1 6 1998 TONY KNOWLE$, GOVERNOR November 5. OIL AND GAS ~NSERVATION COMMISSION James Trantham. Drilling Team Lcadcr ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re~ Kupamk River Unit 2L-313 ARCO Alaska, Inc. Permit No: 98-219 Sur Loc: 177'FNL. 690'FEL. Sec. 22, T10N. R7E. UM Btmhole Loc. 1075'FSL. 1691'FWL. Sec. 24. T10N, R7E, UM Dear Mr. Trantham: Enclosed is the approved application for permit to drill the above referenced well. Your request to transport waste from this well to the 2N pad for disposal will not be approved unless sufficient evidence is presented to confirm the inadequacy of thc 2L-329A well for annular disposal. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that anv disposal of fluids generated from this drilling operations which are pumped down the surface/production casing annulus of a well approved for annular disposal on either drill site must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill docs not authorize disposal of drilling waste in a volume greater than 35.000 barrels through thc annular space of a single well or to usc that well for disposal purposes for a period longer than one year. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipmcnt (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a rcprcscntative of the ~.'it_,ncss a test of BOPE installed prior to drilling new hole. Notice may be given field inspector on the North Slope pager at 659-3607. David W. J'o~ston ~ ~ Chairman BY ORDER OF THE COMMISSION dl/TEnclosures Department of Fish & Game. ! Iabitat Section w/o cncl. Department of Enviromnental Conservation w/o eacl. STATE OF ALASKA ALA%=KA OIL AND GAS CONSERVATION COMi~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redriil ~ lb Type of Well Exploratory StratigraphicTest Development Oil X Re-Entry DeepenI Service Development Gas 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 117' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380051, ALK 4599 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 177' FNL, 690' FEL, Sec.22, T10N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1271' FSL, 1318' FWL, Sec. 24, T10N, R7E, UM 2L-313 #U-630610 At total depth 9. Approximate spud date Amount 1075' FSL, 1691' FWL, Sec. 24, T10N, R7E, UM 11/8/98 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property lineI 2L-325 11151' MD 1075' @ TD feet 180.1' @ 700' feet 2560 5780' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 67.9° Maximum surface 1357 psig At total depth (3-VD) 1610 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOB 2569' 28' 28' 2597' 2300' 1) 220 Sx Arcticset III L & 240 Sx Class G 6.75" 5.5" 15.5# L-80 LTC-M 10267' 28' 28' 10295' 5288' 260 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 856' 10295' 5288' 11151' 5780' (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 Sudace Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat [~ BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r~ Refraction analysis [~ Seabed report [~ 20 AAC 25.050 requirements X 21. I here~y certify that the foregoingis true and correct to the best of my knowledge Signed ~,~,~\ (~~ ~ ~ ~~¢,,,~,4~ ~/~~ Title Drilling Team Leader Date "' ' I ' Commission Use Only Permit {~Nrl;Lber__ _ APl number cover 50- ./~(~) ~_~'-''" 2._~ I Approval date / I_~,~.~ ~g ISee letter for ?'~j'~ .2.-/'" other requirements Samples required [-~ Yes ~ No Mud log required [2 Yes '~ Uo Hydrogen sulfide measures J~ Yes ,J~ No DirectionaJ survey required ,j~ Yes J--J No Required working pressure for DOPE J~ 2M r-J ~(~ r'J 5M r-J 1OM E{ 15M Other: !-~,",'~ii:!¢.J ~i~i~,~ my Oavid W, ,Johnston by order of //... Approved by' Commissioner the commission Date Form 10-401 Rev. 7-24-89 DUPLICATE Submit in triplicate STATE OF ALASKA OO.S VA ,O. PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill / lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen/ Service Development Gas Single Zq~,~ 0ii & Operator 5. Datum Elevation (DF or KB) 10. Field and Pool 2. Name of ARCO Alaska, Inc. RKB 28', Pad 117' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380051, ALK 4599 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 177' FNL, 690' FEL, Sec.22, T10N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1271' FSL, 1318' FWL, Sec. 24, T10N, R7E, UM 2L-313 #U-630610 At total depth 9. Approximate spud date Amount 1075' FSL, 1691' FWL, Sec. 24, T10N, R7E, UM 11/8/98 $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 2L-325 11151' MD 1075' @ TD feet 180.1' @ 700' feet 2560 5780' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 67.9° Maximum sudace 1357 psig At total depth ('rVD) 1610 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOE 2569' 28' 28' 2597' 2300' 1) 220 Sx Arcticset III L & 240 Sx Class G 6.75" 5.5" 15.5# L-80 LTC-M 10267' 28' 28' 10295' 5288' 260 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 856' 10295' 5288' 11151' 5780' (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 Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat [~ BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Timevs depth plot [~ Refraction analysis F-~ Seabed report Bi 20 AAC25.050 requirements X 21. I here~y certify that the foregoing is true and correct to the best of my knowledge Signed ~\ O~~"~""~,,~.~~(.,,,~ '~/'P~. Title Drilling Team Leader Date ~,~ I " Commission Use Only Permit N,~n~r ~--//¢ I API number 50- //4:~.~--, .~-O-~ ~>,.~ IAppr°valdate ) i--5-(~ Isee cOver letter f°r - other requirements Conditior~s of approval Samples required [~ Yes [~ No Mud log required [] Yes ~ No Hydrogen sulfidemeasures [] Yes [~ No Directional surveyrequired [~ Yes E~ No Required working pressure for DOPE 2M E?~,~M~[~'~- 5M [~ 10M [] 15M Other: Original Signed By byorder of Approved by 0avid W. g0h~s?f'¢~, Commissioner the commission Date // '-' Form 10-401 Rev. 7-24-89 Submit in tripl cate ORIGINAL ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2L-313 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. . Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 7-5/8" casing +~_000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. , Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 7. Drill 6.75" hole to TD 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). . Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod 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. Secure well. ARCO Alaska, Inc. Rig down and move out. Hydrocarbon intervals will be tested after the rig move. ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2L-313 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.O- 1 O.2 ppg 15-35 25-50 70-120' Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 10-25 15-40 5-7 9.5-10 +10% 2-6 4-8 4-6 through Arete & Tarn 9.0-10 <11% Drillinq Fluid System- Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator Trip Tank Fluid Flow Sensor Fluid Agitators (Visual and Audio Alarm) *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 production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,357 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 2L pad are expected to be -2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 2L-313 is 2L-325. The wells are 180.1' from each other at a depth of 700'. Drillinq Area Risks: The primary risk in the 2L-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 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" 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 an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected 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 fluid during any extended shut down (> 4 hr) in pumping operations. The 2L-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 2L-313 be 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 100' vertically below the base of the West Sak into the head 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 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 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5½" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3½" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,836 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). TARN TAM Port Collar UtiliZation Decision Tree Cement / above Port Collar / (1000' ']'VD)/ to Surface / Cement below Port Collar (1000' TVD)/ Cement to Surface Nipple Up and Test BOP's Continue with Completion Perform Top Job ! as per I .............................................. · Open Port Collar requirements of ! If Top Job is ineffective or I using drillpipe ~ unacceptable to AOGCC AOGCC Nipple Up and Test BOP's Continue with Completion Circulate Cement to Surface and close Port Collar Nipple Up and Test BOP's Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Continue with Completion ARCO Alaska, Inc. Diverter Schematic Doyon 141 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / / BSA 13-5/8" 5,000 psi WP --"~L x 11" 3,000 psi WP \ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple b 1 3" 5,000 psi WP Shaffer GATE VALVE ~_J r~/~~~raulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL L]'~-.~ w/two 3" 5M psi WP outlets I I SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams I DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 60O 600 1200 1800 2400 5000 `3600 4-200 I v 4800 c~,~ ~ ~..,~ For: BRASSFIELD Dote plotted : 7-0ct-98 True Vedlc~l Oepthe ore reference R~ (~7on 141). SURFACE LOCATION: 177' FNL, 690' FEL SEC. 22, TI ON, R7E 5400 60O0 6600 ARCO Alaska, Inc. Structure : Tarn.Orill Site 2L Well : Field : Tarn Development Field Location : North Slope, Alaska East (feet) -> 800 0 800 1600 2400 .3200 4000 4800 5600 6400 7200 8000 8800 I I T ! II II I I I I I I I I I ! I ; I I II [ 800 (~L.KOP Base Permafrost 0 % . Base West Sak Sands 7 5/8 Casing Pt ~ I 1271' FSL, 1318' FWL I SEC. 24, TI ON, R7E - ~ TVD=5484 ""-~C50 TMD= 10636 ~ DEP=8233 ~ C40 SOUTH 3832 EAST 7287 ~ Beg_in Angle Drop ___ ""~. End A ........_.. r~ g le Drop TARGET - Mid Bermuda ~ T2 - Base Bermuda ~ TD - Casing Pt TD LOCATION: 1075' FSL, 169i' FWL SEC. 24, TI ON, R7E 800 1600 2400 I. `3200 V 4000 4800 RKB ELEVATION: 145' ~o~ Tv~:?oo TMD=?oo D~.P=O 117.74 AZIMUTH isooBASE PERMAFROST TVD=l195 TMD=I_201 DEP_=..6~5 -,o 8833' (TO TARGET) · TOP WEST SAK SANDS -i-V0=1239 TMD=1246 DEF=/o 21.00 27.00 BLS: 5.00 deg per 100 ft 33.00 39.00 BASE WEST SAK SANDS TYD=1899 TMD=lgg6 DEP=423 45.00 ~ 51 .00 ~ 60 O0 7 5/8" CASING PT TVD=2300 TMD=2597 DEP=867 ' ~ ~OC TV0=2470 TMD=2965 OEP=1193 ~D=2§~7 DEP=1195 67 94 BEG ........ '"--.~~D=3815 TMD=6546 DEP=4512 · ~84 TMD=7528 DEP=5422 6600 DLS' 200 deg per 100 f( O0 /J/~k~ T4 TVD=5282 TMD=1028¢ DEP=/94~ ~.00 ' ' C35 TVD=5665 TMD=10951 DEP=8491 -.~'~ TD - CASING PT ~t~FD=57§O TMD=lliSl DEP=8655 i i i i i i i i i i i i i i i I i i I i i i I i i i i i i t J i i 600 0 600 1200 1800 2400 `3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 Vertical Section (feet) -> Azimuth 117.74 with reference 0.00 N, 0.00 E from slot #313 Created ~y fioch For: BRASSFIELD Dote plotted : 7-Oct-g8 Plot Reference ~s 313 Version ~14. JCoordinates are in feet reference slot [True Vertical Depths ore reference RKB (Ooyon A] CO Alaska, ][nc. Structure: Tarn Drill Site 2L Well : 513 Field : Tarn Development Field Location : North Slope, Alaska East (feet) -> 60 40 20 0 20 40 60 80 1 O0 12(] 140 160 180 200 220 240 260 280 300 320 340 360 i i i i i i i i i i i ) i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i ..... ............ '" " ~oo ......... -"-. ............ -f6SJ- ~ ~oo ,," / 800 ' -?-: ~-6o ~oo ,"~oo ,' e ':]:-' - ........... ,' ,, ~ ~.~ ..... 700 " 0 ~ ~7oo 9 ,~ soo .~ : ~ 500 ,,--, 5_0() 8b-~) 900 1000 11 O0 1200 zu i eS. fl O. ~8_ _0_0_ _ _ _ }~ ~] ~_0_.~] ~n~] _]Z ] ]-f -~¥~ ........... f~)-~ ........................................... 1~00 20 : (~ t~ .............. Lt~-~ ..-~.~ ............... - ............ 14.00 ~ 1600 .,. ..... 500 800 ~^=~: .......... ;;,-,;;,- ....... -'2 ......... 1500 ............. I +-2' 500 8Ob' .......... ~uu ...... , uuu ~'l-~)-C--::'-'-z;-_-.-.-.,.,.. - ............. o [~500 ~ s~°° 900 ....... :-:,-~.. .... ~f:' ........ ~2oo .... --~-.-__.~,._..).~oo ................ ~ o + ,*. "- 900 / uuu .... '-- "='- ..... 1 '^~ ' -~'~- ~ '"' ' .... ' .... " 1 4n~ .... :"-: ........ '~uu t "' 500'~."'"- "'-.., 1000 ........ 1000 ....... ~ - .......7: .......... , ~. (~ 500 go0 ..... .... "-. 11 O0 ........ ' ........ 1 ~ ' ........ ' ............. 1500 1000 "- '"-,.. 11 O0 ..... ' ..... ~ uu ' 1500" ...... ' ........ =o -r'~ 6oo ..... ' .... ' ..... ' ..... - ...... I --'-, loo .... '--, ' .... ' ...... ' ...... '"~ 4/~-. ",,,. 700 ...... '"-.., 1200 , ~;,"'-- ' ..... ' ...... ~ "-. 1206"' ..... ' .... ,zuu ........ ' .........1.200 1605 ....... ~ ] '"'-... 100(~'"-. 130~)" ...... '"'"-. 0 .......... ' ............ 0 ~0 '"- '"" 800 ...... '"" 1.30 ...... ' ........ 40 0/3 '+- - '"'" '""' gOO 14'~ ...... "'"-. ......... 1300 ........... -.. 1300 ® '--... ~o,:;"-... ' ....... ~--....~,~oo ........... ' ................ "-"' 60 ~ 60 23- ~" .. 1200 "-. "- 1500 "--."'-. "'-.... '"---.. ,'"'-, = .... --.... -...... . .... .-.::.~... . ..... -~ _.,. 0 80 '""- "'".. 1200'"'".! 000 1600"--",'::.... 1500 ......... 80 "'",, 1300 "'"'. ""'- '":";";~- "'""-... 1400 I -,, "., "-, 1700 '"'-.'-.. "-... I V 100 '".,, '",.,.1 300 '""-, 1 l O0 '"~"z~,, 1600 "....... ~ 100 V "".. 1400 '"-,.. '"-,.. 18 ~)""~'".,,~, 120 '",., '"'.. '"'.. '"~"~,,. 120 '",,, ""... 1400 "',.. ~ 1700 ",. '".. '"-., 1199.99 1900 "%,,,,, ~40 140 '",,, 1500 ",,,. ".,.. '~ "~'"~.-. % ...... ....... 160 __ %' '""" 1 '" '""',."' "'"'-. "~"' """";;;:,~-. 160 "', '"',. 600 '"", '"'-. ~80 'x 1500 ',, "-, ".. 1300 "-'.'~.. ~8o 200 '"' .~% 210(~'~t % '"",,% ,% i i i f i i i i i---i-~--i i i" 'r-'- i i i i--~'r i i -i i f i i i --i- i i i i i i i i i i i i i T-- i m 60 40 20 0 20 40 60 80 1 O0 120 14.0 160 180 200 220 240 260 280 300 520 ~40 360 East (feet) -> ICreoted by finch For: BRASSFIELD Date plotted : 7-0ct-98 Plot Reference is 515 Version Coordinotcs ore in fcet rcferencc slot True Vertical Depths ore rei'erence RKB (Doyon ARCO Alaska, Inc. Sirucfure : Torn Drill Slte 2L Well : 313 IField : Torn Development Field Location : Norfh Slope. Alosko East (feet) -> 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 1120 280 320 360 400 440 480 120 I i i i i i i i L_.J..___ I %h I I I I I t I I I I I i I . __L I I I I I I f I I _ I I I [ I , I 120 ~. %%. ,zoo ~ _~b. 2ooo ~ ~..~ 160 2~)' .... ""%""".'- ' ..... '"'. ...... ' ........]:::::'" "col':ii]iii: ............... 21 O0 160 ~oo 2~oo'%.~9oo ,, ...... 2~oo ..... .... ' ............ ' ........... '""-','-- ' ...... ~l ........ ' ........... ' ....... .2200 200 240 ~ '"'"'22~'~Q]]]'"' 2000 i '" ..... ....!600 L~""--,. --,,::: ..... i ........ I 22&- ......' ........... _1700 2.0 ~-"-.-C--- .......... ~-.~'~:.~. ................. --"',:~ .............. 280 - 1800" '" ', ~'' '"~. 2100 .... ii ..... 280 ..... - '". '"- 1500 ,~"'¢¢~.~ "-. '-. ' "'-. '-.. '-.. ,z..'l r/~,~ _.,_...'... '-... --..j '-..-,~ 320- '-,."... ,, t;~ ~ '-... '-... i"'- 2300r~'"- ~ _<~%. 1900'"'.. '".. J 2400 '-... ' .... .,. 2200 ~ _ '",. 2000 "'"-, "'"-,I ""-., '"' .... i ........ ,:- "-,, "-... =a-. "--.. ...... -~- 400 ~ ", 200_0 ", "-. "-, '"-. ~ ',., ............................. <~'] .......... ~q;-1B00 ~4.' ........ ~'<J~i "- ~ ~,-~-~":Z-"'r ...... -~ .......... ~-.-~~ ......... o _ ",.,, i"-.. ""-.. '"'-... !.:"-.2°~ *"~,¢,., ......... , ,,o- '"".. i i ..... '-.. ,-¢:'~,,f.,,~_~u " ....... ",.,.2100 !, '"'.. '"'-. 1'"'.. "' .... ' ...... v . ... i ~ o~"--. '"'-. ~o~".-.. " .... .. ' ....... 48O - ",,,,%,,,. "'" '"" '"" "'"' 2400 "",. 1800 48O ", 2200 '"- 56O '" '"",,,,, 2200%., '"",.,,. 2700'"-. "'"-,. · " 560 '". 2200 ", ',., '" '" ""',. 1700 600 '"' '"' " 600 640 '.. ~.2.300 -. '-.. '"" · '. 2800 "-. 640 · % ·% '"'% 680 , , ~ ~ ~ , , , , , -a- ~ -' ' ~ ' ~ , , ~ , , , ~ - , , ~ , , ~ ~ , ----a , ~ ~ ~ , , 680 280 320 560 400 440 480 520 560 600 640 680 720 760 0 84.0 880 920 960 1000 1040 1080 1120 East (feet) -> 320 O 360 440 V Created by finch For: BRASSFIELI) Dote plotted : 7-0ct-98 Plot Reference is 315 Version ~4. Coord;natcs oru in fcct reference ~lot ~1,5. [ARCO A] '- ISirucfure : Tarn Drill Site 2L Well : 313 Field : Torn Development Field Location : Norfh Slope, Alaska East (feet) -> 800 - _ 900 - 1000 - 1100 1200 I V 1300 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 lgO0 2000 2100 2200 2..300 2400 2500 2600 2700 2800 2900 3000 i I i i i i i i i i i i i i i i i i i i i i i i i i i i i i i I i i i i i i i i i i i % %. "-......'~-~ .... - ........ - .... . .... - ...... ::: .......... .. -., 2500 ........ '1900 ....... 2500 .......... ' .......... 2100 ..~ ........ - ..... .~. 2=fOg ......... 600 '- "- "- -. "-... "'"-.. 280~'"'-.. "'"-... '-. -, 23'9,0 '-,,. ' .... , '-...I~z~'~ ..... -.. - .......... ' ........... 2200 ~ "- "' .... 2800 ......... '"',, '"'-. '"'-,, '""-., 2600 "'"'-.. " 700 ",, "-.. "-, 2900 "-,, "., 2000 '"'--. '"' .... ' ..... "-... '"--. 2600 ......... 2 '"'-.. "'".. 1800 ""'-. "'"-- ' '"" '".. 2,{,00. '-.. 5000 2700 '"-. '"-. · .. '-. '- '", '" "-... 2100 '"'- "..-. "-... 51 O0 '"" "' '" '"""- '" '" 2700 '" "'-,. '"'-,. '"-... "'-,.. 2800 ""-... ""' '""-,, '""-., 1900 " '"'-........ '"'- 2200 "'-- '".. 2500 '"'"... 3200 ""-- "' '"",,,, '"'-.. 2~ ............... " "' '"'"-.. '"""-. '"'"'.. 3300 · '",. '-.. 2500 2800 / '"".. '"'-,. 2000 ' '" '" " "",, 2600 '"-...3400 '""-., ~000 '"-... "' , "",,,,,.,,, '"-... 260b'-,. '"'- '""- ' .... "' '- "-,, 2400 /'"'"--. ",, 2700 "-,, "'"- "',, ,,, %, '-.. 3500 '-- '-. '..... ' '- ].............. "-... 31 O0 "- .' .. 1400 1500 1600 1700 1800 2800 ',,, 2900 '. 2700 "".. 2800 '.~ '"'% 2900 '"'. ".. ".. 2800 '...3000 '... · " ",. 21 O0 '"',.,. 3600 '-. ""-?"~500 '"'-, 2700"-, '""-., 5200 ,,'" / "-, 3500 .. .. '.,. 3800 .' -........ '"'. ~ ~ '..'~"'-... 2200 '" " '-... z~uu ,. '% / '"::-....~9oo / '"-~./29 O0 "-,,,2300 ",, 2900 '"' ,,., ,,% ,% ,.% i i ~ i i - i i i i '-i'---'-T- i i i i i i i i i i i i i - i i i i i i i i i i i i i i i i " 800 go0 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 East (feet) -> 500 600 700 800 90O lOOO CO 0 1100 1200 1.500 V "'. 1400 1500 1600 1700 1800 Creoted by finc~ For: I]RASSFIELD Dote plotted : 7-0ct-98 Plot Reference is 315 Version /,,,,~ w,,ico, Depths ore refer ..... RKB a .,ka, n .Structure : Tern Drill Site 2L Well : Field : Tarn Development Field Location : Norih Slope, Alaska East (feet) -> 1400 1600 1800 2000 _ 2200~ /-"' 2400- -i-- %,__ ~ 2600 -i-- O 2800 I V 3000 3200 3400 5600 3800 4000 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 i i i [ i J i i i i i i i _~_ i i f i i i l_._J L__J. I I I I I I I I I I I J I I I ~___~ 1 .... ~~ ~ ~._ ~oo ~,oo ~ ¢ ...... .......... . .......... ............ ~ 3300 3900 ~""'""" "'"'"' "'"'"'" '"'"'"' '"'"'"" 3300 ....... " ........ --.. 4300 "-,, "'-.. "'-,, 4300 "'--... 3700 '"--.. '"'-.. ' ......... "",. '"'-,. '"".. '""'.. '"'"-. 31 O0 '"'"-.. ' ..... "%, 31~'~',,.2500 "",~,,4500 '""-,., '"" .... "'" .... ",, "-, "., "-.. 3900 '"-. "'-,. '"'",. '""'- "'""- ......... ' ........ ... 3300 ....... ..~.~oo '-.. 4700 '-. ", "-. 4100 '"'-.. " %. "-. 2700 '"" 4900 """- "-. "-... '"', '"' '"",... 3500 <~ "., 3300 '"., -...,,... ',,,,,,,,,,,,,,,,,% ",,...,,,,, "-, '"'""'-, '" '"'-,. 3700 · '"'"'-. 51 O0 ,, 4300 ""'-.. '% <~ "- 3700 ' ,., -, 5300 "'- '"' '"" "x 3500 "- '--, '-, "-.. 4500 '""-.. '-.. " '-,,. 2900 "- '- ' "" " '" '. 5500 "'-. --... 3900 '"x 3900",, ",, 3500 .. '"-... "-...... ,,,,,,,,., ,,,,.,,,,, ,,,,,,.,.., .. -,-.., ,... .. '-, ""-,.. 4700 '"-.. '""x 4106",., 3700 '"' '",,. 3100 '"- '"-.. 4100 -- 71004300 ".. "-.. 5100 '., 4500",, ['%"~0~ "' '"% '"'x 3900 '" 00 "" '-,. 3300 ~ ~9~o,, '"'"'-... ~ 500x,3900 '- ",, 450~',, '"',, % '% -% .% -.% i i ~1 I .... I'---r--- i i i i i i i ~'I-~-'T~---[ i i i i -i "' i i i i i i i i i i i i i i---i---- i i -[---1 l- T' i ' 2600 2800 3000 3200 3400 3600 ,:5800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 East (feet) -> 1400 1600 1800 2OOO 22OO 2400 fJ) 0 2600 2800 ..~ 3000 V 3200 3400 3600 3800 4000 ARCO Alaska Structure : Tarn Drill Site 2L Well : 51.5 !Field · Tarn Development Field LocaHon : North Slope, Alaska WELL PROFILE DATA o.oo o.~ o.co 040 o.co o.co o.c~ o.~ ?C~.CO O.~ 117 74 7~0.C0 O.CO o.~ o.co o.~ I S647.52 67.g~117.74 4gTg.gl -3437.50 6~7.547~E6.! go.~ 10294.5555.~ 117.74 5288.28 -3701.50 703g.52 7g53.~5 2.~ 1063~.7755.~ 117.7~ 5484.00 -3831.58 7287.C2 &232.S6 0.~ 10951.3~55.~ 117.74 ~665.:0 -Jg51.88 7515.~1 84~I.~5 0.~ 11151.5(55.~ 117.74 5779.72 -~28.1376~.826~55.~S 0.~ 320 33O 34O 35O 5i0 300 290 ~ ~s~ TRUE NORTH 0 !.~0 1 I0 3O ; 1300 C-'~=e~ ~, :;.~ch For: BRASSFIELD Cx3~.e plotted : 7-0ct-98 iTrue VerSccl Depths cra reference 40 5O 270~,,' .~:;'1700 ¥© 280 270 260 2 0 180 1}0 l zO ~g o 70( 5Lo 500, 500 T \ 1 ~oo 8O 250 110 ,' 240/' ~ 700 / ~250 ? 220 ,' ,, ~oo~ 10 2O0 19© Normal Plane Travelling Cylinder - Feet !20 ,. "~..1700 : 150 '-~ ~ 160 All depths shown are Measured depths on Reference We!' 180 ARCO Alaska, Inc. Tarn Drill Site 2L 313 slot #313 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Bakes Hughes INTEQ Your ref : 313 Version #4 Our ref : prop2881 License : Date printed : 7-Oct-98 Date created : !5-Mar-98 Last revised : 5-Oct-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on n70 12 49.742,w150 18 33.414 Slot location is n70 12 48.001,w150 18 53.431 Slot Grid coordinates are N 5927668.165, E 460961.255 Slot local coordinates are 176.99 S 689.52 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath 311 Version #3,,311,Tarn Drill Site 2L 308 Version #2,,308,Tarn Drill Site 2L 307 Version #3,,307,Tarn Drill Site 2L 317 Version #4,,317,Tarn Drill Site 2L 321 Version #2,,321,Tarn Drill Site 2L 327 Version #2,,327,Tarn Drill Site 2L 323 Version #2,,323,Tarn Drill Site 2L 329 (Arete) Version #10,,Arete,Tarn Drill Site 303 Version #3,,303,Tarn Drill Site 2L 310 Version #1, 309 Version #2, 301 Version #1, 315 Version #3, 318 Version #3, 319 Version #1, 325 Version #3, ,310,Tarn Drill Site 2L ,309,Tarn Drill Site 2L ,301,Tarn Drill Site 2L ,315,Tarn Drill Site 2L ,318,Tarn Drill Site 2L ,319,Tarn Drill Site 2L ,325,Tarn Drill Site 2L 305 Version #3,,305,Tarn Drill Site 2L PMSS < 0 - 7650>,,Tarn#2,TARN #2 PMSS < 0 - 6150'>,,TARN#4,TARN #4 PMSS < 2250 - 7162'>,,3A,TARN #3 Tarn #1 (Straight Hole),,1,TARN #1 Closest approach with 3-D Minimum Distance method Last revised Distance 23-Aug-98 23-Aug-98 21-Aug-98 23-Aug-98 28-Sep-98 28-Sep-98 28-Sep-98 28-Sep-98 1-Oct-98 1-Oct-98 1-Oct-98 1-Oct-98 1-0ct-98 2-0ct-98 1-Oct-98 28-Sep-98 5-Aug-98 7-Oct-98 12-Aug-97 13-Jul-98 12-Aug-97 30.2 75.0 90.0 60.1 114.5 210.2 150.1 240.0 149.8 45.1 59 7 179 9 25 8 51 1 71 3 180 1 119 7 1191 2 12805.5 10367.4 19120.9 500.0 400 0 400 0 700 0 1125 0 700 0 600 0 500 0 300 0 500 0 400 0 300 0 1223.6 800.0 1150.0 700.0 400.0 758O.O 11151.3 4760.0 700.0 Diverging from M.D. 500 400 400 5780 1125 700 600 500 300 500 400 300 0 1223 6 800.0 1150.0 700.0 6980.0 7580.0 11151.3 4760.0 700.0 0 0 0 0 0 0 0 0 0 ~- ' ARCO Alaska, Inc. ~t GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD- PRODUCER KRU 2L-313 1. Move in and rig up Doyon 141. 2. Install diverter system. . . Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string t° surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 7-5/8" casing +:tO00' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. . Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 7. Drill 6.75" hole to TD 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). . Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod 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. ..... ARCO Alaska, Inc. Secure well. Rig down and move out. ]3. Hydrocarbon intervals will be tested after the rig move. ~- .... ARCO Alaska, Inc. ,----~ DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2L-313 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casin9 point Drill out to TD 9.0-10.2 ppg 15-35 25-50 70-120' 8.5 - 10.0 ppg 12-24 15-30 45-60 10-25 15-40 5-7 9.5-10 _+10% 2-'6 4-6 through Arete & 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 production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,357 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 2L pad are expected to be -2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 2L-313 is 2L-325. The wells are 180.1' from each other at a depth of 700'. Drillinq Area Risks: The primary risk in the 2L-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 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" 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 an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected 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 fluid during any extended shut down (> 4 hr) in pumping operations. The 2L-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 2L-313 be 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 100' 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 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 7-5/8"29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5~" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 31/2" 9.3 L-80 2 8rd EUE Mod 10,530 psi8,951 psi 10,160 psi8,636 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). TARN TAM Port Collar UtiliZation Decision Tree. Cement / above Port / Collar / (1000' TVD)~ Begin Primary OneI Stage Cement Job ] to Surface Cement below Port / Collar (1000' TVD) / ._ as per .............................................. · Open Port Collar If Top Job is ineffective or- requirements of I unacceptable to AOGCC ' using drillpipe · Circulate Cement Nipple Up and ' Test BOP's ! to Surface and · i close Port Collar ~r ' Continue with ' Nipple Up and Completion i Test BOP'$ I I - Continue with Completion . Cement to / Surface j, . Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top ' 1, Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface ARCO Alaska, Inc. Diverter Schematic Doyon 141 211~" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline I 21 lA" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS L~ L 3" 5,000 psi WP OCT [--] MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / / BSA 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 3" 5,000 psi WP Shaffer GATE VALVE ~~T~~raulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL L]w/two 3" 5M psi WP outlets I J SINGLE 13-5/8'' 5,000 psi WP, HYDRIL MPL BOP w/pipe rams I 600 600 ~ 1200 .-I-- ~ 1800 (D 2400 rm 3000 3600 I-- 4200 I 4800 c~,. ~ ~,~ For: BRASSFIELD O~te plotted: 7-Oct-~t8 C~rdinotes are in feet reference slot #313. rru, Vertical Oegthm are reference RKB (Doyon 141). 5400 6000 IARC0 Alaska, Inc. Structure : Tarn Drill Site 2L Well : 313 Field : Tarn Development Field Location : North Slope, Alaska SURFACE LOCATION:I 177' FNL, 690' FEL SEC. 22, TION, RTE ,ak, East (feet) > 800 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 i J I i i i ~ i I ) i ~ I ~ ) e i m I i m ~ ~ I 800 (~L~OP Bose Permafrost 0 ~, Bose West Sok Sands ~ 7 5/8 Casing Pt ~.....E%o · I TARGET LOCATION: I ~ 1271' rSL, 1318' rwL J SEC. 2~, TION, R7E - TARG~ ' ~ WD=5484 ~C50 TMD= 10636 ~ DEP=8233 ~ C4n SOUTH 3832 ~ E~T 7287 ~ Ee~n Angle Drop _ __ _ ~~~~gle Drop TAEGg- MJ~ermuda ~ T2 - Ease Bermuda ~ TD - Casing Pt 800 U') 0 160O 2400 ~ J. 3200 V 4000 4800 600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 Vertical Section (feet) -> Azimuth 117.74 with reference 0.00 N, 0.00 E from slot #515 TD LOCATION: 1075' FSL, 1691' FWL SEC. 24, TION, RTE RKB ELEVATION: 145' I · I KOP TVD=700 TMD=700 DEP=O I ~.oo 117.74 AZIMUTH 9.00 \ 1500BASE PERMAFROST TVD=1195 TM0=1201 D.~EP~.---~6~5 .- 8233 (TO TARGET) ~ ' TOP WEST SAK SANDS TVD=1239 TMO=12,~o u~=/~ ~. 21.00 '~k DLS: 3.00 deg per 100 ft. 27.00 \ ~.oo - ~. 39.OOBASE WEST SAK SANDS TVD=lB99 TMO=199e DEP=423 "x 45.00 .",~,,,~ 51.00 60 O0 7 5/8" CASING PT TVD=2300 TMD=2597 OEP=867 · ~ ~OC TV0=2470 TMD=2965 DEP=1193 MD=2967 DEP=1195 67.94 DEG TARGET ANGLE o ~ ~ ~oo alS- ~oo ~e~ per 100 ~ ' P 79 C35 TVD=5665 TM0=10951 DEP=8491 ',~'",.'~ TD - CASING PT TVD=5780 TMD=llISI DEP=8655 ' ICreoted by finch For: BRASSFIELD Oate plotted : 7-0ct-98 I Plot Reference is 313 Vets;on ~4. ~d;flol~ ore ;n f~t rcfc~nca slot Trna Ve~ical Depths ara reference RKB (Oo~n 140.I I AI CO Alaska, Inc. Structure: Tarn Drill Site 2L Well: 315 Field : Tarn DevelopmenJ Fleld Location : North Slope, Alaska Ak, East (feet) -> 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 540 .360 f I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ;" /' 500 ......... '"-. ............. '1'~'~'"' , ,oo / 800 i,8oo , .?.:. ...... - .......... ; /700 e ....'~'~o 900 40 ! ,, ~) ......... 700 : ~"~o /, 700 ~ ~ 500 20 = (~ 500 (~500 8~0 900 1000 11 O0 1200 I ,-.~nn 800 '90~ 70~'~ ....... fi'0~ ........... ;~ ............................... 1300 20 ~ ~.,-,, ............ '_-..~. ................... ,/_ ,..,,..., .............. i ' 600 .,. ~ ..... ~%-~6' ..... %'~ti-'-'_~'-~ .......... "-.-~::::::-:::: ......... ~ 300 ...................... ~ too I +,~ 500 80b' ........... ~uu ....... [uuu ~'fD-d":"":""'-'-' ......... ' ................ . = .... -~ c:~ 500 900 .............. 9~' .... 1200 .... ~__ "' i [ ouu '" ~ .... 1000 ..... ' .... '~"-" ..... ~ 0 , .~. ~ '-...?uu ........ ' .... -.. 14~;~''''~:~ ........ 1400 : -- 500":.""-- "'-,,. 1000 ........ 1000 ': ..... ~ ' ....... : ........... ~. ~ 500 900 ...... "-. 11 O0 ....... ' ..... . 11 ......... ' ........... 1500 20 ~..~-~J. 600 1000" ..... '"-.,. 1100 ....... ' ....... 00 ' ' 150'0' ....... ' ........... 20 --""' 700 ' ''~' ..... ' ...... ' ........... ' ............. ~ "'-.... ;;a- ..... '"-.IL°° ,~oa- ........... - .............. '"'"" I "-,. 1000 "-. 1300 '"-... '"--., ~ u '"--. ........ 40 .+_ 40 -1 '"", '"',, 800 . · '"'""~ "'"" 1 "O'" '"""" (D O ~ I~ ""'. '""- 900 ,~'5~ ...... '"'-.. ......... ~oo ........... . '"" ,o -t".~h' "'-.. , ~o(Y'--.. ' ....... ~"-.. ~,~oo ......... '"' ........ ~o :r ~ '"-'- "- '-. ,500 ..... ' .... ...... -I "-..,200 "-... ".... ..... :::... '", ...... " ...... ::3 80 '"" """ 120';'"' 1000 16~)'~2222''. ......... 0 - '... '-.. ,,. "-.'.'-,. 1500 _ .-....,.~oo '-....... ",-...... ,';-';~...........' ...... I I V 1 O0 - ',.,.., "-...] 300 "'"... 11 O0 . "~"'~',,~,, 1600 '-........ ~ 100 V '"'",,1400 '"'"'., ""~".. 18 ;~'~'~.. '"',,, ""-,, 1400 "'"', ~~ 1700 140 "-, ~ "-.. "'-, 1199.99 1900 · 'x 1500 .,.. ,..,. ~'"',~ 140 '"'- '"'-., 1500 ""', '",, '"., '"-,, 200(~ ::=.,,..,1. §00 160 160 ~ '", "',, '"-, ~8o '"~ 1500 ,.,,~600 '"'-,. ""-,. 1300 '":"~.':.. ~80 ,oo -,% i i i i i i i i i i i i i i i i i i i I i i '1 i i i i i i i '1 i i i i i i i i i i i i / 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 East (feet) -> Croated by finch For: BRASSFIELD I ' oo~. ,,oft.: ?-o=t-gs [ I Plot Refartnce {m '~1..~ V~;on {4. { Coord;nat .... in 'eel ret ....... Iai 1313. I JTrue Ve~lcal Depthz are reference fiK8 (Do~n 141).I 120 16O 200 240 280 320 -I--, ~ 360 · e- 400 0 ~40 I v 480 520 560 6O0 640 680 IARCO A]askI ] nc. Structure: Tarn Drill Site 2L u,I : Field : Torn Development Field Location : North Slope. Alaska East (feet) -> 2110 320 560 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 1120 I I I I I I I I I I I I I I I I I t I ! ! I I I I I I I I I I I I I I I I I I I I I I w.~j,,,,,.~? 800 '"" ..... :'::'-- ' ........ 21 O0 ~ooo ....... ........... --'--....__.?.~.o?._ - ............... ~,o;?"~-'~ ~oo ........ ~,o;~' ..... L'.; ............. ................. ";.'.-.. ' .... . ........ ' ............ ' ........ 2200 ,~ 2200 "-'."--. zu u -.. ..... " '-" ' /~ "~"" --0- '"-.. 1600 '"-. ' ..... ;. '"~ :~'-.,. '"-::: .... -. ' ..... ~ 220~)' ...... .............. . 1700 .... ~"--.... "'--..'::::...... - ..... : .... ... ................ ................ ~,~o~ -... "-.... "--..'."--.Z~oo ...... .. ' ......... "--.... "---... , oo ---..... .... ,. - ........ ~-~ ,~oo--. '--.. ~oo-.... ..... . ~oo ..... . ---~:~ '""' 000 '"'"- "'"'- '"'"- '"'"- "'"'- 1700 '"-. 20'~)'- '"'" 25&"-.. ' ...... '" ..... '",. 2100 '"'-. '"'-., '"',, '""-.. "'"'-. "'.. ~, ;;~'... ""-. ~o'~"--. " ...... ": ..... ' '"'-. '"'-'."'"-.. '""-.. .... ' .... 2,~oo ...... j..aoo ",. 2200 '"'. '"',, 220(J"-,, '"'-, 270(~'"-.. .... "-. ", 2200 ", " '"' '"" 1700 "' % %. · I i i i i I i I ! i i I I I i i i i i I i i i i i i i i i I i i i i i I I i i I i i i 280 320 360 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 1120 East (feel) -> 120 160 20O 240 280 320 U3 0 360 400 440 480 520 560 60O 640 680 ICreated by finch For: BRASSFIELI) Dote plotted: 7-0ct-98 Plat Reference {e Coordlnote$ ere iff feet reference slot ~31.'~. I 500 60O 7O0 BO0 goo 1000 11oo 1200 I V '~3oo 1400 1500 1600 1700 1800 IStructure : Torn Drill Site 2L Well : IFleld : Torn Development Field Location i North Slope, Alaska East (feet) 800 gOO 1000 11 O0 i 200 1,300 1400 1500 1600 1700 1800 1900 2000 21 O0 2200 2300 2400 2500 2600 2700 2800 2900 3000 t I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I % .....% ..... '"-.27 ' '-... " ..... ' ....... ' ....... :.': .......... ' ~ "'--.... '" .... ,.~.~oo .......... ,~oo ..... '~0° .......... :::::.:~:..o.o.. %... ....... - .... ..... -- ......... - ............ :.-. ................. - 2'39.0 '-. "-. "--. ..... ' ...... ' ...... 2200 %. '-. "-.. "-.. "-.. '"-.. "' .... 2800 ......... '".. '"-. "-. "'-,... 2600 "--. "'-. ' " ...... ' ......... "- ", '". 2900 "- "-. 2000 "-- ' .... ' ..... '".. '"-. %.. '"-.. '"'-. '"'-.., 2600 ................ ""~ '"-,., ""-,., ~oo'"'-,~ " ...... ' ........ ' .... -... '"-"--:-~.". '"-....~:~. '"-...~ooo " ....... .2700 .... ' ..... ' ......... '"'~) · '" '" " ,., 31 O0 '" '"' "'" ' /'~ '"- '"'-. '"'-. ' "' - ' '""-. ' ....... : ..... ... 2700 -'-, ' ' " "'-... 2800 '"-.. '-.. "% 2500 '"-. ' " '"'-.. '"'-.., 1900 "'"- '"'-,.. 2200 '" '" '""-. 2,~0.. "-.., 3200 "'"-. %"%% '% 2600 '% 2700 '"-,,, ',, "% 2700 ',, 2800 '"-. 2900 '"',. ".. 2800 2800 "-, '""',,. ~',\,\ ',. 5000 ",, '~ 2900 '"' '", ", ',, 2900 '"-.. 2900 '"'"-. t -. '"' '"'~...3000 '""--.. '"'""--.. / ",.. '"'-., 2000 '"".. 5400 '"-,.. 260'0'-.. ... '"'-.. '""-.. 2400 //'"'"--. ~,,. ""'""" " '"'"" ,.. 3100 '""'" // "'- '-.. 3500 "'- '"'""-- '"'""-~:~500 .. '""'-. '-,..3600 -,, '-,. 2~oo -,, .. / ...... "-%2700 "-.,. "-.... '"'-...3200 /' '"'-.. '""-.. '""-.,, '""-. ,3700 '"""/4 ..... %. '% '-. / '-.. v ",.....~o~',...:.~oo "'-....../ .... .% "'-.. "--,. ,,>'-...3900 ""'-. '""-?' '"".. 4000 "~~-<"2900 "-~.2300 "-... i i i i i i i i i i i i i i i i i i i i i [ i i i i i i i i i i i i i ii i i ii I i 50O ,. 60O 700 800 900 lOOO {J') o 1100 1200 1 ,.300 1400 1500 1600 1700 1800 800 900 1000 11 O0 1200 1300 1400 1500 1600 1700 1800 1900 2000 21 O0 2200 2300 2400 2500 2600 2700 2800 2900 3000 East (feet) -> Created by finch For: URASSFIELD Date plotted: ?-0ct-98 Plot Reference {s 313 Vemlon i~4. Coordinates are ;n feet tolerance slot {31'~. ~True Verficol Depths are reference RKB (Do,on 14 I Structure: Tarn Drill Site 2L Well : Field : Tarn Developmeni Field Location : North Slope. Alaska East (feet) 2600 2800 3000 3200 5400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I t I I I I I I I I I I I I ,4oo ~...~ ...... ~ ....... a~._a~? (~ "--..73oo ......... ' ....... ' ............ ' ............... ,6oo ~. "-- .... ... "---.i~aa .......... ~,oo ' .......... ~ ....... --~? .... <~),.. "-.. '"... "-~.2900 '"-.... ' .... . ...... '"-.. '"-,. '"--,,4~00 '"'-..~70~ ....... . ......~00 --~2~.. 2000 \"\-.. ""'"-.. "'"'".. """"'-. ""'"'-. 5100 '"'""~.. '"\. 31~'"- 2§00'""-~ 4§00 "'"'-.~ ""'-.. "'"'-.. 2200 "\. '"-.. "'-. ..... 5900" ..... ' ...... ' X'.,, "~-.j "'-... '" ..... '" .... ' ...... ~ 3500 ' '-, "-. '--~ 4700 "-,. "-.. 3300 --.. . '""... '""-., '"'"-.. '""-.~ 4100 '""-.. '"'--... '. "'\ '"", ~"'-~ 4900 ~'"'- '"'"- '"". - '""- ~oo '-...~7o -.... ""' .... '""-..~oo ' ........ -\, '"-,. '""-, "'"'-. 5100 '""-~ ~300 ""~-. '-~.~.~00 ~ ','-.. '"'-..."---... ""--...~oo ....... ... ..... ..~.~oo ........... " '" " "' "'- '"-. 4500 '"-. '"-. \\, "X3500 \', '"-~ 2900 "-.. "-.. "-.. "-., · . " ".... " "-.. '"-.. '"-~ 3900 '"',, 3500 ",..~500 -.... "~,3900'~,,. "-.......... -.. '"'- "-. "-.. 3900 "- ",, "x, ",., "-~ 4700 '""'- 3200 ',. ". '-. '"'-.. "A 410~'~ 3700 '"' '"'-~ 3100 '"""-. '"-., 4100 · " '" '"'-~ 4900 '"-... '"'~ 3700 ','"'. 3400 ",\ "%, '""-... '"'-..j~.~...~'°°~oo .. --...... 3600 "' \'\ '"x 3900 .-..,3500 '\',, ",, "..,....,' "..,..\, '"'-,,,~_00 "... · "'"~29~0, 3800 '",.~5~0~ 5900 ""'"""" ",,. 4~o~,,. "'-.,.. ooo% ,%% ! i i i i i ! i i ! i i i i i i i i i i i i i i i i i I i ! i i i i i i i i i i ! ! i 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 ' 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 East (feet) -> /-~ 2400 -I- ~ 2600 o 280o I v aooo 1400 1600 ' 1806 2000 2200 2400 0 2600 2800 ._+. 3000 3200 3400 3600 3800 4000 C 0 Alaska, tructure : Torn Drill Site 2L Well : eld : Tarn Development Field Location : North Slope, WELL PROFILE DATA ~ of ~J~ 2664.69 67,g4117.74 2470,0~ -S5~,021~5.~ 1Tg~.~ 3,~ E~ of ~d 1647~2 67,g~117,74 4g?g,gl -3437.~~7.54 7386.19 a~ [~ at ~ 10294,~s~5.~ 117.74 32~.28 -J~t,~ 7~g,62~51.45 2.~ T~4~ ;L-[ (P) ~d 2 1063~.~ 55.~ 117.74 5484.~ -3831.~7287.02 8232.g~ O.~ (~ of ~d 1~1,3~ ~,~ 117.74 366~,~ -39~1,~7~15.81 8491.45 0.~ T.O. · [nd 01 H~d 11151.3455.~ 117.74 5779.72 -~28.1~76~.628655,29 0.~ 320 330 34-O 350 310 TRUE NORTH 0 10 a 3O i ~5oo c,.cte,~ ~ .nc. For: BRASSFIELD ] ~ate !alotted: 7-0ct-98 ] Plot Reference ;~ 313 Ve~icn ~. Coar~;naTes are ;n feet ~erence aim ~13. Tr~e Ver~ccl De~ths are reference RXB (~cyon 4O 5O 500 290 ~ ~5, 280 700 7O 8O 270 }o+ 9O 260 250 / / / 240 :,,'~7o0 230 i 220 / 2~oo~' 10 2O0 190 Normal Plane Trovelling Cylinder - Feet 100 .110 120 150 ~,~ 1700 150 "'" 180 170 All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Tarn Drill Site 2L 313 slot #313 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Bake~ Hughes INTEQ Your ref ~ 313 Version #4 Our ref ~ prop2881 License ~ Date printed ~ ?-0ct-98 Date created : 15-Mar-98 Last revised : 5-0ct-98 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 12 49.742,w150 18 33.&14 Slot locatlon is nT0 12 48.001,w150 18 53.431 Slot Grid coordinates are N 5927668.165, E 460961.255 Slot local coordinates are 176.99 S 689.52 W Projection type:'alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North Object wellpath 311 Version #3,,311 308 Version #2,,308 307 Version #3,,307 317 Version #4,,317 321 Version #2,,321 327 Version #2,,327 323 Version #2,,323 329 (Arete) Version #10 303 Version #3,,303 310 Version #1,,310 · 309 Version #2,,309 301 Version 91,,301 315 Version #3,,315 318 Version #3,,318 319 Version #1,,319 325 Version #3,,325 Tarn Drill Site 2L Tarn Drill Site 25 .Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L ,Arete,Tarn Drill Site Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L 305 Version #3,,305,Tarn Drill Site 2L PMSS ¢ 0 - 7650>,,Tarn#2,TARN #2 PMSS < 0 - 6150.>,,TARN#4,TARN #4 PMSS < 2250 - 7162'>,,3A,TARN #3 Tarn #1 (Straight Hole),,1,TARN #1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. 23-Aug-98 30.2 500.0 23-Aug-98 75.0 400.0 400 21-Aug-98 90.0 400.0 400 23-Aug-98 60.1 700.0 5780 28-Sep-98 114.5 1125.0 1125 28-Sep-98 210.2 700.0 700 28-Sep-98 150.1 600.0 600 28-Sep-98 240.0 500.0 500 1-Oct-98 149.8 300.0 300 1-0ct-98 45.1 500.0 500 1-0ct-98 59.7 400.0 400 1-Oct-98 179.9 300.0 300 1-0ct-98 25.8 1223.6 1223 2-0ct-98 51.1 800.0 800 1-Oct-98 71.3 1150.0 1150 28-Sep-98 180.1 700.0 700 5-Aug-98 119.7 400.0 6980 7-Oct-98 1191.2 7580.0 7580 12-Aug-97 12805.5 11151.3 11151 13-Jul-98 10367.4 4760.0 4760 12-Aug-97 19120.9 700.0 700 Diverging from M.D. 500.0 .0 .0 .0 .0 .0 .0 .0 .0 .6 .0 .o 2L 21¢ .0 .0 · I~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 October 15, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Al~ka 0il & 8as Cons. O0mmissi0r, Application for Permit to Drill KRU 2L-313 Anchorage Surface Location: 177' FNL 690' FEL Sec 22 T10N R7E, UM Target Location: 1271' FSL, 1318' FWL Sec. 24, T10N, R7E, UM Bottom Hole Location: 1075' FSL, 1691' FWL Sec. 24, T10N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2L-313, located approximately six miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will be completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Due to the fact that 2L-313 will be only the third well drilled on the Tarn 2L pad, a surface/production casing annulus may not be available for waste drilling mud disposal. ARCO requests permission to haul the waste drilling mud from 2L-313 to one of the approved casing annuli on the Tarn 2N pad. Please refer to a separate letter dated 10/7/98, requesting a waiver to 20 AAC 25.080. If an approved annulus is available on Drillsite 2L when 2L-313 is drilled, then waste drilling mud will be disposed of as allowed. If permission is not granted to haul the waste drilling muds to 2N pad, or an approved annulus is not available on 2L pad, then the drilling mud wastes will be hauled to a KRU Class II disposal well. 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 Tarn 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. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany David W. Johnst~,~ Application for Permit to Drill Page 2 KRU 2L-313 However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071 ) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Silcerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2L-313 Well File ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 October 15, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 A. nchorag~. Re2 Application for Permit to Drill KRU 2L-313 Surface Location: 177' FNL 690' FEL Sec 22 T10N R7E, UM Target Location: 1271' FSL, 1318' FWL Sec. 24, T10N, RTE, UM Bottom Hole Location: 1075' FSL, 1691' FWL Sec. 24, 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 2L-313, located approximately six miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will be completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Due to the fact that 2L-313 will be only the third well drilled on the Tarn 2L pad, a surface/production casing annulus may not be available for waste drilling mud disposal. ARCO requests permission to haul the waste drilling mud from 2L-313 to one of the approved casing annuli on the Tarn 2N pad. Please refer to a separate letter dated 10/7/98, requesting a waiver to 20 AAC 25.080. If an approved annulus is available on Drillsite 2L when 2L-313 is drilled, then waste drilling mud will be disposed of as allowed. If permission is not granted to haul the waste drilling muds to 2N pad, or an approved annulus is not available on 2L pad, then the drilling mud wastes will be hauled to a KRU Class II disposal well. 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 Tarn 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. ARCO Alaska, Inc. is a Subsidiary of AflanlicRichfleldCompany DUPLICATE David W. Johnstb, l' Application for Permit to Drill Page 2 KRU 2L-313 However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sir~cerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2L-313 Well File WELL PERMIT '~:~LIST COMPANY ~ c__) _ ADMINISTRATION 1. Permit fee attached ....................... 2. [.ease number appropriate ................... _.,R DATE/ 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well Iocaled proper distance from drilling unit boundary .... 6. Well Iocaled proper distance from other wells .......... 7. Sufficient acreage available in drilling unil ............ 8. If deviated, is wellbore plat included ............... 9, Operator only affected party ................... 10, Operator has appropriate bond in force ............. 11. Permit can be issued wilhout conservation order ........ 12, Permit can be issued without administrative approval ...... 13, Can permit be approved before 15-day wait ........... ENGINEERING !~_ D'AI'E GEOLOGY 14, Conductor string provided ................... !5. Surface casing protects all known USDWs ........... 16. CM¥ vol adequate to circulate on conductor & surf csg ..... 17. CM r vol adequate to tie-in long string to surf csg ........ 18. CM I' will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~ ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84)... ..... 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presenled on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones. ' 33. Seabed condition survey (if off-shore) ............. 34. Con. tact.nam, e/phon,e.for weekly progress reports ....... lexp~ora~ory omyj __P_I~ D~I'E / ANNULAR DISPOSAL 35. APPR DATE GEOL AREA. ~:,:~ N N N Y N (~U //Y N ........................................................................................................................................................... With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will nol impair mechanical integrily of the well used for disposal; (11)) will nol damage producing formation or impair recovery from a pool; and (E,) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: BEW~.~ I1'(~')" WM .............. DWJ__ cc) Co Comments/Instructions' M d'~,')ld,,'d I~!v ()5/29/9,~] PROGRAM: exp [] dev);i~ redrll [] serv [] wellbore seg II ann. disposal para req~ .'~... · WELL PERMIT CHECKLIST FIELD & POOL 'ZT~_~_O____L/~__-~ COMPANY /~.,~¢ _ ,,~ INIT CLASS ,~) ~,' WELL NAME ~,~ .~'- ~_~/'3 ,~:,/"/ GEOL AREA UNIT# /////~:5 ON/OFF SHORE ADMINISTRATION DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper dislance from drilling unit boundary .... 6. Well Iocaled proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If devialed, is wellbore plat included ............... 9. Operator only affecled pady ................... 10. Operator has appropriate bond in force ............. 11. Permil can be issued without conservation order ........ 12. Permit can be issued withoul adminislralive approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING DATE N N N N 14. Conductor string provided ................... N 15. Surface casing protects all known USDWs ........... N 16. CMl- vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ N · 18. CM'r will cover all known productive horizons .......... N 19. Casing designs adequate for C, T, B & permafrost ....... ~ N 20. Adequate tankage or reserve pit ................. N 21. If a re-drill, has a ~0-403 for abandonment been approved... 22. Adequate we,bore separation proposed ............. 23. If diverter required, does it meet regulations .......... (~ N 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ................ N 26. BOPE press rating appropriate; test to '500(~ psmg. L~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. Y (~' GEOLOGY 30. 31. 32. 33. 34. ANNULAR DISPOSAL 35. APPR DATE Permit can be issued w/o hydrogen sulfide measures ..... Y ,N,~_ .... Data presented on potential overpressure zones ....... Y NT"---~ Seismic analysis of shallow gas zones ..... ' ........ ~"1~ Seabed condition survey (if off-shore) ............. J Y N ' Con. tact.nam, elphon.e.for weekly progress reports ....... ,~ Y N · lexp~ora~ory omy] '/ ~1..~ '~'~""~ ~'~ With proper cementing records, this plan (A) will contain Waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... N _~uGb~"7 ~'I'~_O_K.. ~OLf~. J~PPI~.OY'/~'z.- ~'1A'"/U,.S F"'ot-.-.. wiiJ'~bt'impair._mechanical integrity of the well used for disposal; (c) (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumve, .nt 20 AA.C 25...2.52 or 20 AAC 25.412.'--- .:'"., ~'~ N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ........... JDH ...... '"--- RNC CO ~ Comments/Instructions: M chet~lisl ~ev 0512919[J Well HistorY File APPENDIX Information of detailed nature that is not. particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu May 06 16:20:20 1999 Reel Header Service name ............. LISTPE Date ..................... 99/05/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/05/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, TAR/~ POOL MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 2 AK-MM-90017 G. GRIFFIN D. BURLEY 2L-313 501032027700 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 06-MAY-99 22 10N 07E 177 690 146.10 144.50 117.10 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.625 2607.0 6.750 11140.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA R31Y (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DEDE SCHWARTZ OF ARCO ALASKA, INC. ON 09 DECEMBER, 1999. SPERRY-SUN MWD DATA IS PRIMARY DEPTH CONTROL (PDC) FOR WELL 2L-313. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF lll40'MD, 5772'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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). CTNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. CTFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SC02 = SMOOTHED STANDOFF CORRECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: FIXED HOLE SIZE = MUD WEIGHT = MUD SALINITY = FORMATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = $ File Header Service name ............. STSLIB.001 6.75" 9.1 - 9.8 PPG. 350 - 550 PPM. CL- 19149 PPM CL- 1.00 G/CC 2.65 G/CC SANDSTONE Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/06 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 GR 2576.0 FCNT 2605 0 NCNT 2605 0 NPHI 2605 0 FET 2605 0 RPD 2605 0 RPM 2605 RPS 2605 RPX 2605 PEF 2613 DRHO 2613 RHOB 2613 ROP 2617 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 11046 5 11018 0 11018 0 11018 0 11053 5 11053 5 11053 5 11053 5 11053 5 11034 0 11034 0 11034 0 11140 0 EQUIVALENT UNSHIFTED DEPTH ......... BIT RUN NO MERGE TOP MERGE BASE 2 2617.0 11140.0 MERGED MAIN PASS. $ 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 DEPT ROP MWD FET MWD GR MWD RPX MWD RPS MWD RPM MWD RPD MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD Units Size Nsam Rep FT 4 1 68 FT/H 4 1 68 HOUR 4 1 68 API 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 P.U. 4 1 68 CNTS 4 1 68 CNTS 4 1 68 G/CC 4 I 68 G/CC 4 i 68 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT ROP FET GR RPX RPS RPM RPD NPHI FCNT NCNT RHOB DRHO PEF Min 2576 0 28 0 25 38 86 1 11 0 05 0 05 0 05 11 07 82 99 13633.9 1.92 -0.12 0 Max Mean Nsam 11140 6858 17129 2239.11 327.473 17047 4.42 0.845348 16898 224.3 123.325 16942 2000 4.87403 16898 42.74 4.63874 16898 2000 5.49969 16898 2000 5.44496 16898 73.84 38.9524 16827 911.2 231.834 16827 35223.1 20707.2 16827 5.12 2.33555 16843 2.72 0.104695 16843 6.06 2.10986 16843 First Reading 2576 2617 2605 2576 2605 2605 2605 2605 2605 2605 2605 2613 2613 2613 Last Reading 11140 11140 11053 5 11046 5 11053 5 11053 5 11053 5 11053 5 11018 11018 11018 11034 11034 11034 First Reading For Entire File .......... 2576 Last Reading For Entire File ........... 11140 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/06 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 ....... 99/05/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R3~W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2576.0 FCNT 2605 0 NCNT 2605 0 NPHI 2605 0 FET 2605 0 RPD 2605 0 RPM 2605 0 RPS 2605 0 RPX 2605 0 PEF 2613 0 DRHO 2613 0 RHOB 2613 0 ROP 2617 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVA3~ (FT) : 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 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS STOP DEPTH 11046 5 11018 0 11018 0 11018 0 11053 5 11053 5 11053 5 11053 5 11053 5 11034 0 11034 0 11034 0 11140 0 19-NOV-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD 10.87 MEMORY 11140.0 2617.0 11140.0 56.1 69.6 TOOL NUMBER P1071NL4 P1071NL4 P1071NL4 P1071NL4 6.750 6.8 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 TEMPEP~ATURE (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 LSND 9.80 52.0 9.0 350 5.0 2.200 1.326 7.000 4.000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NPHI MWD 2 PU 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NCNT MWD 2 CNTS 4 1 68 40 11 RHOB MWD 2 G/CC 4 1 68 44 12 DRHO MWD 2 G/CC 4 1 68 48 13 PEF MWD 2 BAR/q 4 1 68 52 14 47.6 First Name Min Max Mean Nsam Reading DEPT 2576 11140 6858 17129 2576 ROP 0.28 2239.11 327.473 17047 2617 Last Reading 11140 11140 GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF 38 86 1 11 0 O5 0 O5 0 O5 0 25 11 07 82.99 13633.9 1.92 -0.12 0 224.3 123.325 16942 2000 4.87403 16898 42.74 4.63874 16898 2000 5.49969 16898 2000 5.44496 16898 4.42 0.845348 16898 73.84 38.9524 16827 911.2 231.834 16827 35223.1 20707.2 16827 5.12 2.33555 16843 2.72 0.104695 16843 6.06 2.10986 16843 2576 2605 2605 2605 2605 2605 2605 2605 2605 2613 2613 2613 11046 5 11053 5 11053 5 11053 5 11053 5 11053 5 11018 11018 11018 11034 11034 11034 First Reading For Entire File .......... 2576 Last Reading For Entire File ........... 11140 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/05/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/05/06 Origin ................... STS Reel Name ................ UNKlqOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drillin9 Services LIS Scan Utility Mon Feb 22 15:02:52 1999 Reel Header Service name ............. LISTPE Date ..................... 99/02/22 Origin ................... STS Reel Name ................ UNKI~OWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 99/02/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific 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 NIIMBER: LOGGING ENGINEER: OPER3tTOR WITNESS: (TARN POOL) MWD RUN 3 AK-MM- 80298 PIEPER D. BURLEY 2N-313 (REPROCESSED) 501032025900 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 22-FEB-99 MWD RUN 4 MWD RUN 5 AK-MM- 80298 AK-MM-802 98 PIEPER Z IEMKE D. BURLEY D. BURLEY JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 6 AK-MM- 80298 ZIEMKE D. BURLEY 3 9N 7E FNL: 33 FSL: FEL: 646 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 149.70 DERRICK FLOOR: 27.50 GROU/qD LEVEL: 120.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 16.000 108.0 3RD STRING 12.250 9.625 3319.0 PRODUCTION STRING 6.750 9134.0 REMARKS: 1. THIS DATA IS REPROCESSED AND BEING REDISTRIBUTED. 2. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 3. THE MWD-LDWG/DIGITAL DATA IS DEPTH CORRECTED TO A DIGITAL ARRAY SONIC (DAS). IT WAS LOGGED BY SCHLUMBERGER WIRELINE SERVICES ON JTJLY 30, 1998. IT COVERS FROM 3263.50' TO 9159' 4. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 5. MWD RUNS 3, 4, 5, AND 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. MWD RUN 6 IS A MEASURED AFTER DRILLING (MAD) PASS OVER A CORE INTERVAL. 7. 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 ....... 99/02/22 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) 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 6~67 6579 6588 BASELINE DEPTH GR 0 3304.5 0 3333.5 0 3578.0 0 3581.0 5 3630.0 0 3680.5 .0 3733.5 .5 3744.5 .5 3754.0 .5 3793.0 .5 3831.5 .5 3884.5 .0 3935.5 0 4588.0 0 5079.5 0 5215.0 5 5723.0 5 5775.0 5 6033.0 0 6076.5 5 6083.5 5 6185.0 0 6190.5 0 6348.0 5 6364.5 5 6383.5 0 6407.5 5 6435.0 0 6455.0 0 6519.5 5 6565.0 0 6566.0 0 6581.0 0 6585.5 EQUIVALENT UNSHIFTED DEPTH 6590 0 6601 0 6605 0 6669 5 6782 0 6815 0 7158 0 7159.5 7198 5 7201 5 7365 5 7393 0 7482 0 7518 0 7548 5 7618 5 7740 5 7775 5 7844 5 8048 5 8052 5 8054 0 8061 0 8068 5 8139 5 8142 0 8169 5 8179 0 8181 0 8201.5 8203 5 8207 5 8255 5 8267 5 8395 5 8401 0 8427 5 8434 0 8456 5 8582 5 8584 0 8605 5 8618 5 8623 0 8685 0 8694.0 8706.5 8755.5 8761.5 8776.5 8783.5 8809.0 8818.5 8907.0 8912.0 9136.0 $ 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 8807 5 8816 5 8905 0 8910 5 9134 5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 3 3350.0 8349.0 4 8349.0 8570.0 5 8862.0 9134.0 MERGED MAIN PASS. $ 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 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 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 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 0.16 103.06 Mean Nsam 6222 11657 262.926 11564 122.351 11562 4.57199 11562 5.05497 11562 7.11968 11562 9.2069 11562 1.29221 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 ....... 99/02/22 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 ....... 99/02/22 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 STkRT DEPTH STOP DEPTH 8550.0 8846.0 8550.0 8846.0 8550.0 8846.0 8550.0 8846.0 8550.0 8846.0 8550.0 8852.5 8550.0 8861.5 M3d3 RUN NO. MAD PASS NO. MERGE TOP 6 8570.0 MERGED MAD PASS. $ MERGE BA~E 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 Al)sent value ...................... -999.25 Depth Units ....................... D~tum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 GR MAD AP I 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OPIMM 4 1 68 FET MAD HOUR 4 1 68 4 8 12 16 20 24 28 Name Min Max Mean Nsam DEPT 8550 8861.5 8705.75 624 RAT 2.04 357.11 270.454 624 GR 77.34 177.49 127.293 606 RPX 2.34 37.38 12.0866 593 RPS 2.43 38.87 13.3092 593 RPM 2.37 39.21 13.5689 593 RPD 2.47 41.43 14.9586 593 FET 0.66 103.06 9.25543 593 First Reading 8550 8550 8550 8550 8550 8550 8550 8550 Last Reading 8861.5 8861.5 8852.5 8846 8846 8846 8846 8846 First Reading For Entire File .......... 8550 Last Reading For Entire File ........... 8861.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 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 ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 3304.5 RPD 3304.5 RPM 3304.5 RPS 3304.5 RPX 3304.5 GR 3311.5 ROP 3351.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY 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: $ STOP DEPTH 8301.5 8301.5 8301.5 8301.5 8301.5 8309.0 8349.0 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 LSND/NABR 9.20 41.0 8.5 1350 6.5 1.850 1.394 1.700 2.600 46.1 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 Rep DEPT FT 4 1 68 GR MWD 3 API 4 1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHMM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMM 4 1 68 ROP MWD 3 FT/H 4 1 68 FET MWD 3 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 Max Mean Nsam DEPT 3304.5 8349 5826.75 10090 GR 28.63 233.04 121.077 9996 RPX 0.05 98.14 4.23996 9995 RPS 0.13 2000 4.71893 9995 RPM 0.05 2000 7.09413 9995 RPD 1.41 2000 9.40584 9995 ROP 0.5 879.15 278.199 9996 FET 0.16 63.46 0.78744 9959 First Reading 3304.5 3311.5 3304.5 3304.5 3304.5 3304.5 3351.5 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 ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File ~eader Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW 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 FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 8300.0 8300 0 8300 0 8300 0 8300 0 8307 5 8317 0 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 8549.5 8549.5 8549.5 8549.5 8549.5 8549.5 8549.5 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) 27-JUL-98 INSITE 3.2.12.3 CIM 5.46, EWR4 1.38 MEMORY 8570.0 8349.0 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 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 1.600 1.193 1.700 3.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 RPX MWD 4 OHMM 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OHMM 4 1 68 16 5 RPD MWD 4 OHMM 4 1 68 20 6 ROP MWD 4 FT/H 4 1 68 24 7 FET MWD 4 HOUR 4 1 68 28 8 46.1 First Name Min Max Mean Nsam Reading DEPT 8300 8549.5 8424.75 500 8300 GR 113.9 170.3 139.247 485 8307.5 RPX 1.22 7.19 3.43264 500 8300 RPS 1.25 7.26 3.53418 500 8300 RPM 1.28 7.05 3.52158 500 8300 RPD 1.27 6.82 3.66222 500 8300 ROP 3.82 156.81 36.455 466 8317 FET 0.54 13.4 3.12678 500 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 ~eading For Entire File ........... 8549.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 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 ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 R3tW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 8814.0 8814.0 8814.0 8814.0 8814.0 8822.0 8862.0 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 9087.0 9087.0 9087.0 9087.0 9087.0 9094.0 9134.5 30-JI/L- 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 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 P1060CRG6 8.500 8.5 LSND/NABR 9.90 51.0 7.8 1400 4.4 2.000 1.211 2.150 3.750 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 RPX MWD 5 OHMM 4 1 68 8 3 RPS MWD 5 OHMM 4 1 68 12 4 RPM MWD 5 OHMM 4 1 68 16 5 RPD MWD 5 OHMM 4 1 68 20 6 ROP MWD 5 FT/H 4 1 68 24 7 FET MWD 5 HOUR 4 1 68 28 8 48.9 First Name Min Max Mean Nsam Reading Last Reading DEPT 8814 9134.5 8974.25 642 GR 89.66 167.63 126.595 545 RPX 2.37 8.75 3.8218 547 RPS 2.43 9.21 3.93104 547 RPM 2.47 9.03 3.91321 547 RPD 2.59 9.18 4.10977 547 ROP 1.6 363.52 151.871 546 FET 0.36 0.82 0.573985 547 8814 8822 8814 8814 8814 8814 8862 8814 9134.5 9094 9087 9087 9087 9087 9134.5 9087 First Reading For Entire File .......... 8814 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 ....... 99/02/22 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 ....... 99/02/22 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: MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX RAT $ .5000 6 START DEPTH 8550.0 8550 0 8550 0 8550 0 8550 0 8550 0 8550 0 STOP DEPTH 8846.0 8846.0 8846.0 8846.0 8846.0 8852.5 8861.5 LOG HEADER DATA DATE LOGGED: SOFTWARE 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: MAXIMI/M 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: MI/D 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 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 8.500 8.5 LSND/NABR 10.00 46.0 10.0 1300 4.0 2.000 1.140 2. 150 3.750 53.3 Depth Units ....................... Datum Specification Block sub-type.. DEPT GR RPX RPS RPM RPD RAT FET Name Service Order Units Size Nsam Rep FT 4 1 68 MAD 6 API 4 1 68 MAD 6 OHMM 4 1 68 MAD 6 OHMM 4 1 68 MAD 6 OHMM 4 1 68 MAD 6 OHMM 4 1 68 MAD 6 FT/H 4 1 68 MAD 6 HOUR 4 1 68 .0 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name DEPT GR RPX RPS RPM RPD RAT FET Min 8550 77 34 2 34 2 43 2 37 2 47 2 04 0 66 Max Mean Nsam 8861.5 8705.75 624 177.49 127.293 606 37.38 12.0866 593 38.87 13.3092 593 39.21 13.5689 593 41.43 14.9586 593 357.11 270.454 624 103.06 9.25543 593 First Reading 8550 8550 8550 8550 8550 8550 8550 8550 Last Reading 8861.5 8852.5 8846 8846 8846 8846 8861.5 8846 First Reading For Entire File .......... 8550 Last Reading For Entire File ........... 8861.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/02/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/02/22 Scientific Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Scientific Physical EOF Physical EOF End Of LIS File
