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198-103
Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: 3 / AOGCC j, ATTN: Natural Resources Technician 11 1—' Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 -, Anchorage, AK 99501 19 8103 TRANSM17TAL DATE . - TRANSMITTAL# FORMS Please return via courier or sign/scan and email a copy Date mberger and CPA]. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. 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O N N N O N N O N N N CO 0 0 01 r 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 yd M C 0 rim 000 to to to U, 0 In N to to 0 0 0. -0 0 C CID CC wMD I- tcr,o m a) c • U m. zm E a) no c W 0 W e '^ E E Y cc ii AO �' al �^-1 C r h 1� r CO N co in o M ate+ a) C • Z Y m M z N r r O M r M N O r M F�+ E QJ N 0) c = 0.. < o cc VI CO N .J.) - M W N M ' N M eU- ._ VC) Z CU o o W N �' r' c ^ 3 �rI c v E E O CO a La Q f- a` a I- H ConocoPhillips Alaska AUG 2 9 2816 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC August 25, 2016 Commissioner Cathy Foerster SCANNED SEP 3 0 2016 Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: 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 conductor. These voids were filled with cement and 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 attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter at 907-659-7006 or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ! Roger Winter ConocoPhillips Well Integrity Field Supervisor • r ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field Date 8/25/2016 1 D,2A,2L,2N&2W PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1D-09 50029228750000 1980650 14" NA 14" NA 7 8/24/2016 2A-19A 50103201970100 2010830 11" NA 11" NA 4.25 8/24/2016 2L-306 50103206300000 2101820 12" NA 12" NA 2.55 8/24/2016 2N-341 50103202630000 1981030 14" NA 14" NA 6.8 8/24/2016 2N-347 50103203370000 2000630 13" NA 13" NA 10.2 8/24/2016 2W-10 50029212390000 1842230 10" NA 10" NA 6 8/24/2016 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Conductor Extention fj 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Fro Exploratory r 198-103 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20263-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0375074 KRU Tarn 2N-341 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 12339 feet Plugs(measured) None true vertical 5194 feet Junk(measured) None Effective Depth measured 12004 feet Packer(measured) 11526 true vertical 5038 feet (true vertical) 4773 Casing Length Size MD ND Burst Collapse CONDUCTOR 73 16 109 109' SURFACE 4197 7 5/8 4227 2301' PRODUCTION 11499 51/2 11527 4774' PROD LINER 789 3 1/2 12316 5183' Perforation depth: Measured depth: 11870-11885,' 12025-12065' True Vertical Depth: 4969-4977', 5048-5068' Tubing(size,grade,MD,and TVD) 3.5, L-80, 11525 MD,4773 TVD ; . Packers&SSSV(type,MD,and ND) NIPPLE-CAMCO DS NIPPLE @ 491 MD and 491 TVD SEAL ASSY-BAKER 80-40 CASING SEAL ASSY @ 11526 MD and 4773 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): SCANNED i r` Treatment descriptions including volumes used and final pressure: " � ` 202 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA _ Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 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: 316-103 Contact MJ Loveland Email: n1878(C7conocophillips.com Printed Name MJ Loveland Title: NSK Well Integrity Project Supervisor Signature —' Phone:659-7043 Date 7 47 77. --7 S-- 4 /6' vTL ' // // Form 10-404 Revised 5/2015 4f e°4</ RBDMS LL JUN 0 2 2016 Submit Original Only • • ConocoPhillips Alaska P.O. BOX 100360 MAY 3 1 2016 ANCHORAGE,ALASKA 99510-0360 AOGCC May 26, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 2N-341, PTD 198-103 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • 2N-341 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/11/16 Conductor Extension (In Progress) Initial T/I/O = SI/1050/265 Initial and continuous gas test 02-20.9/CO-0/LEL-0/H25-0 While welding a 14" conductor extension for a future RG2401 job a portion of soil and corrosion fell from near the burst seam. Noticed that the burst seam was split open 1/2" (widest point). Took a gas test at burst seam and received 50% LEL. Opened well house doors and left the heater in place to vent out well house. Notified Pad Operator and did a 1 hour fire watch. Final T/I/O = SI/1050/265 05/22/16 Proceeded to finish welding conductor extension on from 3/11/2016. (COMPLETE) '...',.:,F„; ;:„,, n 4 p ..,,,,,,,,..,,,,,,,,,....0.0000i, ,A..„ Z H x EMI 101\.' , ^'4 i ». K. z a tib { ,`9I a ".Md#.. � f ,� te',,.,',,',,,,,:-..,:=,'. — ` . -. '-',,,...,,,,,:;i'',..,,,,.,.. ..:,'''' - --,:or.--. , Y '..*er- '-L'''''"'"' et, , '. - ' - .8 . `..4^:". ',?"','!...,.:: � �.. s M� ..,,,,, , --4,-4.-,.....„ -,-,Isik, t ., 7 ,'",...,,,,.„.: .A,. ; .:--', —,..",; ;;,-;:.Ap%:ii":P.'44,-.- —4;'';*Ar'' -14',11`'', ,,* 7..'tV '' ; ' 1 7' 4N"Ot47"-'''t ' ��) x+n c l.A ...it','',1:„.417, ,,,,,,,;:'`' ,- , ., ..',,,,,:;":":' ' ,Nt.kr"..:"--:- /4,7A, t to44,,,,iA,*,,,:ill - $ , -- iii . 4 Aott.W ' �` 2N- 41 PTD 198-103 :` ' "Copyright 2016 All rights reserved. This . photograph is provided to the AOGCC•with permission to copy for its own use. Copying for any other purpose or by any other party is ' � •` =ohibited without the express consent of onocoPhiIIips Alaska, 'Inc." e lbw„ ..� a. r +N' , 4 !� '' a +`c may. ti"tet � ..., Ar r.. n+ASM ^w . 44 ". r. H z f, , , Sr .•„..,,,,,,,,,,„, a • . „ xk r5,` 'i S ice^' ,� ,,. • y 41. i • t L f v !ea-p ''ae 2N=3 '1' PTD 1913 , -.""Copyright 20,;16 All righ s - _� .--.� is ;. phcatograph is' provided to the AOGCC with. t .4:.'-' ission •to copy fo.r. its own use. .-C• opying ! f •ori any other p-u11,pose'o y °`�! Cn.y othne par v`}lLf '��1{��•c,�� kt`prohibitecl without the expre.ss� f. ConocoP'hillips Alaska, Inc." • IP vct%- X 0 3 ti®F T� I yyy, A THE STATE Alaska Oil and Gas F ,;,s� OfA LASKA Conservation Commission 333 West Seventh Avenue "L — Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 SCANNED 4-- 2 2 2016 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU Tarn 2N-341 Permit to Drill Number: 198-103 Sundry Number: 316-103 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster , �. Chair DATED this/U day of February, 2016. RBDMS L L FEB 1 1 2016 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 5 2016 APPLICATION FOR SUNDRY APPROVALS ocr_s 24 z 81 20 AAC 25.280 AOGC 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing (y7• Other: Conductor Extention P.• 2.Operator Name: 4.Current Well Class: . l 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ` Exploratory r Development Il 198-103 • 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20263-00 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No P. 1 KRU Tarn 2N-341 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0375074 Kuparuk River Field/Tarn Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12339 • 5194 • 12004' • 5038' 3400' None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 108' 108' SURFACE 4197 7 5/8 4227' 2301' PRODUCTION 11499 51/2 11527' 4774' PROD LINER 789 3 1/2 12316' 5183' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11870-11885,' 12025-12065' • 4969-4977',5048-5068' 3.5 L-80 11525 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE-CAMCO DS NIPPLE • MD=491 TVD=491 SEAL ASSY-BAKER 80-40 CASING SEAL ASSY • MD=11526 TVD=4773 12.Attachments: Proposal Summary !. WellBore Schematic r 13. Well Class after proposed work: 40 -1 Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development (i� Service I 14.Estimated Date for 15. Well Statu after proposed work: 02/25/16 OIL ‘11) WINJ r WDSPL r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG i GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: MJ Loveland Printed Name MJ Loveland Phone:659-7043 Email: n1878(a�conocophillips.com //JJ�/� 7Title: NSK Well Integrity Project Supervisor Signature /�'• "f /rzfeic Date: 0-2/5//K Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Rug Integrity r BOPTest r Mechanical Integrity Test r Location Clearance r Other: photo cG v 6 v�-v�t Z vt IV Sv b.S/ci-t v� c t a n repa I 1, Post Initial Injection MIT Req'd? Yes r No ,/ Spacing Exception Required? Yes r No [7 `Subsequent Form Required: r ---4 ^� APPROVED BY Approved by: �/7a,/ COMMISSIONER THE COMMISSION Date: Z -I O—/, y T` Z /`1'�i"", �' ��f'(O Submit Form and Form 10-403 Revised 11/2015 Quell&liIarSti'A for 12 months from the date of approval. Attachments in Duplicate RBDMS '-'- FR 1 1 2016 • • RECEIVED ✓ ConocoPh i l l i ps FEB Q 5 2016 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 3, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2N-341, PTD 198-103 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska,Inc. Kuparuk Well 2N-341 (PTD 198-103) SUNDRY NOTICE 10-403 APPROVAL REQUEST 02-03-16 This application for Sundry approval for Kuparuk well 2N-341 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 14". With approval,the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage if it is exposed. 3. Extend the conductor to starter head. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP PROD • 2N-341 ConocoPhillips 2 Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl I") MD(ftKB) Act Btm(ftKB) cr,nor.dq,ilrps 501032026300 TARN PARTICIPATING AREA PROD 74.55 2,369.65 12,339.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 2N-341.31112 01 5 10,439 AM SSSV:NIPPLE 100 10/4/2009 Last WO: 36.00 7/6/1998 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,074.0 2/19/2015 Rev Reason:TAG lehallf 3/1/2015 HANGER,169 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 108.0 108.0 62.58 H-40 WELDED Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len g..."Grade Top Thread �1 * SURFACE 75/8 6.875 _ 30.0 4,227.1 2,301.1 29.70 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(NKR) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 512 4.950 27.5 12,317.7 5,184.1 15.50 L-80 EUE8rd 5.5"x3.5"@11527' Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 16.9 11,544.2 4,784.1 9.30 L-80 EUE8rdMOD Completion Details .. u4aweua.mur Nominal ID Top(ftKB) Top(ND)(ftKB) Top'noir) Item Des Com (in) 16.9 16.9' 0.00 HANGER FMC GEN V TUBING HANGER 2.992 i 491.4' 491.0' 6.42 NIPPLE CAMCO DS NIPPLE 2.875 ,.. CONDUCTOR_36D-109.0 - ,M./vt/v 11,414.3 4,708.7 55.77 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 11,515.8 4,767.3' 53.97 NIPPLE CAMCO'D'NIPPLE 2.750 NIPPLE;491.4In 11,525.4 4,773.0 53.83 LOCATOR BAKER LOCATOR 2.985 11,526.2 4,773.4 53.87 SEAL ASSY BAKER 80-40 CASING SEAL ASSY 2.985 Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (NKB) (ftKB) Zone Date t) Type Com 11,870.0 11,885.0 4,969.2 4,977.2 S-7,2N-341 12/25/2005 6.0 APERF 2.5"HSD,60 deg phase 12,025.0 12,045.0 5,048.7 5,058.5 S-5,S-3,2N- 7/29/1998 4.0 IPERF 2.5"HC,BH,180 PH,90 341 ORIENT 12,045.0 12,065.0 5,058.5 5,068.3 S-3,2N-341 7/28/1998 4.0-IPERF 2.5"HC,BH,180 PH,90 ORIENT Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(ND) 3 (ftKB) OMB) (ftKB) (ftKB) • Type Date Com SURFACE;30.04,227.1-4 1 13 11,870.0 11,885.0 4,969.2 4,977.2 FRAC 12/28/200 Re-Frac completed thru flush,placed 195895#of 5 16/20 prop in the formation w/10#ppa at the perts. Frac was completed per design using 50#XL Gel and SLEEVE;11,414.3 12/Br28/20cket 05 Mandrel was pumped in front of the Frac stage. Mandrel Inserts St .--1 ati N Top(TVD) Valve Latch Port Size TRO Run • Top(ftKB) (MB) Make Model OD(in) Sew Type Type - (in) (psi) Run Date Com GAB LIFT;11,464.2 fi 11,464.2 4,737.2 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 6/18/2010 9 Notes:General&Safety End Date Annotation 6/12/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 NIPPLE;11,515.8 .0 LOCATOR;11,525.4 a S SEAL ASSY;11,526.2 • I APERF;1i,8 11,70.0 t'� FRAC;AC;11,8075.01 L (PERF;12,025.0-12,045.0 s (PERF;12.045.0-12,065.0 PRODUCTION Al lib 5.51/3.514)1152T;27.5-- 12,317.7 • • Bettis, Patricia K (DOA) From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Friday, February 05, 2016 5:05 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU Tarn 2N-341: Sundry Application (PTD 198-103) Patricia, Apologizes—2N-341 is a gas lifted oil well—so it is a development well and will be a development well when the work is completed. I regretfully made the error. Should I re file or can the error be fixed by hand? Thank you Mi Loveland MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 MJ's Cell (907) 943-1687 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, February 05, 2016 4:31 PM To: NSK Well Integrity Proj<N1878@conocophillips.com> Subject: [EXTERNAL]KRU Tarn 2N-341: Sundry Application (PTD 198-103) Good afternoon, AOGCC records show that the KRU 2N-341 well class is a development well. On Form 10-403, Box 4 and Box 13, ConocoPhillips shows the well class as a service well. Please verify the well class for KRU 2N-341. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential 1 • • • and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 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. / ~-"/05 File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by:~Mildred Daretha Nathan Lowell -- [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Damtha Nathan Lowell Date: Is/ 0 • WELL LOG TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /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: Robert A. Richey u t, 3 �� ` I 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 25-Apr-11 2N-341 1 Report / EDE 50- 103- 20263 -00 2) rY '' r s am = Signed : (J� ` ZElate : S© j(D '/ :;2-:t72:',?,.] ;°, -) - Print Name . ,; z r PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 .88952 C \Documents and Settings\Diane Williams \Desktop \CPAI_Transmit.docx 1 • ill Memory Multi-Finger Caliper Log Results Summary I Company: ConocoPhillips Alaska, Inc. Well: 2N -341 Log Date: April 25, 2011 Field: Kuparuk (Tarn) Log No.: 10259518, ZX70 State: Alaska I Run No.: 1 API No.: 50-103-20263-00 Pipet Desc.: 3.5" 9.3 Ib. L -80 EUE 8RD MOD Top Log Intv11.: Surface Pipet Use: Tubing Bot. Log Intv11.: 11,856 Ft. (MD) 1 Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : 1 This caliper data is correlated to tubing tally This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. I Multiple holes are recorded in 64 joints from —8,120 ft to — 11,110 ft. A 3 -D log plot of the caliper recordings across this interval is included in this report. The caliper recordings indicate the 3.5" tubing logged appears to be in good to poor condition with respect to I corrosive and mechanical damage. Additional wall penetrations ranging from 20% to 85% wall thickness are recorded in 198 joints of the 386 joints logged. Recorded damage appears as multiple holes recorded in a deep line corrosion and line of pits ( -3,300 ft. - — 11,800 ft.) on the low side of the tubing. No significant 1 areas of cross - sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. This summary report is an interpretation of data provided by Halliburton Well Services. I MAXIMUM RECORDED WALL PENETRATIONS: Multiple Holes ( 100 %) Jt. 336 @ 10,503 Ft. (MD) Hole ( 100 %) Jt. 338 @ 10,573 Ft. (MD) 1 Multiple Holes Multiple Holes (100 %) Jt. 348 @ 10,877 Ft. (MD) (100 %) Jt. 289 @ 9,033 Ft. (MD) Multiple Holes ( 100 %) Jt. 343 @ 10,718 Ft. (MD) 1 MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant cross - sectional wall loss (> 12 %) are recorded throughout the tubing logged. 1 MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. 1 1 1 I ( Field Engineer: Biery /Cheysobhon Analyst: HY. Yang Witness: B. Boehme ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565-1369 E -mail: PDS,amemorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 II 1 19 Is - 03 zsgfr eoci I • • I Ciii-S- PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk (Tarn) Well : 2N -341 Date : April 25, 2011 I Description : Detail of Caliper Recordings Across Multiple Holes from - 8,180' to - 11,11 Comments Depth Maximum Pen. Maximum I.D. 3 -D Log Image Map IIIIMINIK 1 1ft:500ft a % 100 2.5 inches 3.5 90° 0° 90° 180° 270° 0° I Minimum I.D. I - 1 2.5 inches 3.5 Nominal I.D. 1 - 2.5 inches 3.5 I Joint 262 8200 II I �■ I Joint 263 Ill� - ��� 8250 ell mg Ili Joint 264 � MIA F_ Joint 265 In m.._ liii - I 8300 E t�■ t -- - 11 0u t....,,, [1111■ I Joint 266 rl Li■ - sim _ — I Joint 267 J 8350 � ' — F ■ Joint 268 Z .= t i _..... ' 8400 = F II Joint 269 [IIIIII-_ g _ I _ v. ■11 Hole 8450 _� ■�� _ • 11111111 — _ A A, . _IE , ■ GI I Joint 271 I I I __ rri ■ ■ • • 8500 1 I Hole ,491 4 ;Tip_ I Possible Hole — � ■� l 8550 [ II , , ___ 'I _ Hole ` 1 iii!..:...... � ' ,• I - -�a�� +e- i. 8600 11141 — Joint 275 - — x 1— _ I Multiple Holes +■ "mil y - _iii 8650 1i _ WV— I Multiple Holes - = 1 �� r MIMI Multiple Holes 8700 _ 11111 _ i IP 7 31111:-..M. ; _ s r f Joint 279 - N I II MI _ - -� — G 8750 Joint 280 - `` tip. j i _ _ I Hole �� i i i! 8800 - _ I / . F ■■ Joint 282 � _- 8850 i. 1 _ Joint 283 - 1 L. 1 ., _ ___ ... I Joint 284 1 ,, _ .. _- . . 8900 5. _ r --- irr,,../ id " ME - I I J • 0_ 1 Joint 285 +!L ■ - - -r 1111111•111 _ i r ■■i ` tr..■ _ J 286 8950 �, ■■■F1■ �■■ 1 _,� F _ � a - .- ■ ■ ■/ � ��� Hole ■ ■■tt■ral _ 1 ■■■ilti■■ �� � - 9000 = ■ _ I Imo Hole - ` ■ i :- „_ ■ ■ ■` — Multiple Holes PI !i .H' thi — , I- E i uniiiu i I7■■■ 111! H ole 1 111111111111 1 Hole 1 ii 11111r1111 ' 6-61 ... Ilinilhil I Joint 292 E+' ■ ■ ■1 ■e �■ -- .. 9150 ■■■ri1C, �_ Mini '1111 Joint 293 ,� ■■ ■t il I 11111 +III - Possible Hole 9200 k'� ' -.7.-.. ■ ■ ■I■ � .- - NW - INE J oint 2 95 �p ■ ■■ � ■ 1 1 i ■■■1 _■ 9250 -_— 1 Hole — � - 1 _ � i — Hole _ 9300 _______ - 1 I I t imm- A Possible Hole j 1 I I • 0 I 9350 -. lb :i illiih ■i. _ Hole ! ■ III EdBii -_ °Tei III Hole C -mi ■■ ■F1F11r1r��■ - ■ 9400 I - -- t■ 7■ -� Joint 301 1: !! - •• � r � ■ � � 1111111N.• ' Joint 302 9450 ` - 111, • - ■■11111_x■■ I Hole 111��� I 9500 _ ��` �� - Hole i -1/1�; ° .41 Joint 305 - ........ I EE � IN 9550 �_ E __ .if I Multiple Holes - � al I ' -4111 i, IMIlliMr 6—...-- lEs ITO. — I Hole 9600 � tI i � � It ,111411111111 _- I �� ■a■ - Hole r . i - tI■,1i ■ 9650 - ! t• � E_- _ _ Multiple Holes — It row - Al ' Multiple Holes 9700 C f ■- _ _ . 11 1 -. 11111;1 ■ Possible Hole G- —E 1� -.- ■ - ■ I i 9750 -- J oint 312 - 1 - ■��■ = _ u_ F�! rilli I Multiple Holes �1■ c � __,.... ___ ..._,.. 9800 _ _ 9 1■■■ ■ - I &-71-0101111- ■! -- =-. Hole ■ ■ _ '• I Multiple Holes 985 ■ f - i ■ ■ ■ Hole I Ai■■ l _.• s � 9900 _ U - •• ► -- NO�_ E ' Probable Hole _�� r�_ F111 I E� , ;.- Ill I Probable Hole _ 9950 th ____■■� Ilk= _ ! _ ' 1- __ Hole kill I - 'i.;.iiNINE 4111 10000 P _ Multiple Holes �1' r I■ F NM I ii Hole - _ _ I �- 10050 ���, -_ Eik ° 11■ ' - I Multiple Holes - tit OE - -- Hole 10100 II■��■ =— 1 p iT� �� -_ Multiple Him Possible Holes r` oral .- 10150 ilk ii ■ 1 ■ 0 0 Jomt's[5 I — Y ■ ■p �� 4 ■ ■■t -J- _ . -1. ,. Multiple Holes — � ■ ■■I ��� I 10200 � - . ■ Holed 1. I 10250 '_ -- - Joint 328 � Ilillra _, Joint 329 ~ 1 1 . — '�. I. •. IF I 10300 = Joint 330 II"-- I r_ I1!1 N4: x _ Joint 331 10350 -41 itil .4: - iitii i ' Joint 332 — ■ ■L, Ip I 10400 -! Multiple Holes 1 ..111! —��mii Illi_! MOWP----- -= -o w MN - Multiple Holes _ � � ..r 10450 _�= - NM Multiple Holes - li I Multiple Holes 10500 II!I = r ' Multiple Holes I t 31 — - 10 I IC�� 1 ,4 Hole mid- I ai- -- I I 0 0 111111■■ - - -ur1�M t l,. - I Hole 10600 �t =� - _ _ -,_ ■■iA■■ y _ ■ ■r4tMUU Multiple Holes ■ ■EJP■■ _ I 10650 •iw -- - -al — Multiple Holes n= 'i ■.1 i -;-- I ■■E ■! N M= id - 1 Multiple Holes C - - , - i =I - _ F OM 10700 y ' �� _ I Multiple Holes , _= II KIE _ai■ ■ I �!� li' 10750 ��-- Multiple Holes -'N I ■ _ 1 __ - NM I Multiple Holes -' ■" ° + � i 10800 _ _: ■ -- -- LI i 711111111 II _ - Multiple Holes E!! _An. -. 11 . 1 . 11 — - ii ;�! —. _� � E rill" 1911 - I Hole 10850 y = Multiple Holes - - ' ,,■ri I 10900 w.. -- 110/ Hole : ill illa- - 1 = , I!. I Multiple Holes 2 1„ RNLI! � - _ 10950 --,-„,..11 1- Hos _ I Joint 351 e� It i■ _ - � -� P:: I • 0 11000 Hole �O 1 - mt.. ie ! I Ine C I _C�• -- - - Hole � :- 11050 I Hole ^A _ Joint 355 3 11100 I L_ � - r • Nominal I.D. 2.5 inches 3.5 Minimum I.D. I I I 2.5 inches 3.5 Comments Depth Maximum Pen. Maximum I.D. 3 -D Log Image Map 1ft.500R I 0 % 100 inches 3.5 90° 0° 90° 180° 270° 0° I I I I I I I I I I I • . Correlation of Recorded Damage to Borehole Profile I U Pipe 1 3.5 in (12.3'- 11817.7') Well: 2N-341 Field: Kuparuk (Tarn) Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 25, 2011 I I ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 48 1 I 50----,.......______ 1576 I 100 3120 — _i \,\\\s\t 150 4677 a I _o LL c z 200 6241 t I c si o I 250 7809 410-ir SEIM I 300) 9372 I 3 50 10925 I GLM 1 M 376 11818 0 50 100 I Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 376 I I • • PDS Report Overview s,.. Body Region Analysis I' Well: 2N -341 Survey Date: April 25, 2011 Field: Kuparuk (Tarn) Tool Type: UW MFC 24 No. 10000429 (Hal) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 EUE 8RD MOD Analyst: HY. Yang Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf L -80 EUE 8RD MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration(% wall) Damage Profile (% wall) I 150 ■ Penetration body II INN Metal loss body 0 50 100 0 I 100 I 50 46 0 I 0 to 20 to 40 to over 96 20% 40% 85% 85% Number of joints analysed (total = 386) I 124 91 107 64 146 I Damage Configuration ( body) 1 9 150 - I _ 1.) 100 1 50 296 ■ 0 I Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole 346 GLM 1 I Number of joints damaged (total = 292) 117 1 111 0 63 Bottom of Survey = 376 I I I I I • S PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD MOD Well: 2N -341 Body Wall: 0.254 in Field: Kuparuk (Tarn) I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 25, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 12 (1 0.01 6 0 2.93 Pup 0.2 15 0 0.03 11 4 2.91 Pup 0.3 19 0 0.03 11 3 2.88 Pup 0.4 28 0 0.02 9 2 2.91 Pup 0.5 38 0 0.03 12 3 2.91 Pup I 1 48 0 0.01 6 1 2.92 2 79 0 0.02 9 2 2.90 3 111 0 0.02 8 1 2.92 4 142 0 0.02 9 2 2.90 I 5 173 0 0.03 11 2 2.91 6 204 0 0.01 6 2 2.92 7 236 0 0.02 7 2 2.91 8 267 0 0.02 8 2 2.91 U 9 299 0 0.02 6 1 2.91 10 330 0 0.02 9 2 2.92 11 361 0 0.02 8 2 2.91 12 393 0 0.02 8 2 2.92 13 424 0 0.02 8 2 2.91 I 14 455 0 0.02 7 2 2.92 14.1 487 0 0 0 0 2.88 Camco DS Nipple 15 488 0 0.02 7 1 2.91 16 520 0 0.02 8 2 2.93 I 17 551 0 0.02 8 1 2.92 18 581 0 0.01 6 2 2.89 19 613 0 0.02 7 1 2.91 20 644 0 0.02 8 1 2.91 I 21 675 0 0.02 7 2 2.93 22 707 0 0.02 6 1 2.92 23 738 0 0.02 7 2 2.92 24 769 0 0.02 7 2 2.91 I 25 798 0 0.02 6 2 2.91 26 830 0 0.02 7 2 2.92 27 860 0 0.02 9 2 2.93 28 891 , 0 0.01 6 1 2.92 29 922 0 0.02 7 1 2.91 I 30 954 0 0.02 7 1 2.92 31 985 0 0.02 8 2 2.92 32 1017 0 0.02 7 2 2.92 33 1048 0 0.03 10 I 2.91 I 34 1078 0 9 2 2.92 35 1109 0 0.03 11 I 2.90 36 1141 0 0.02 8 2 2.92 37 1172 0 0.01 6 1 2.91 I 38 1204 0 0.01 6 2 2.92 39 1235 0 0.02 7 2 2.92 40 1267 0 0.01 6 2 2.90 41 1298 0 0.03 12 1 2.93 42 1330 0 0.02 7 1 2.91 I 43 1360 0 0.02 7 1 2.93 44 1392 0 0.02 7 2 2.92 rat I Metal Loss ion Body I Page 1 Penet I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD MOD Well: 2N -341 Body Wall: 0.254 in Field: Kuparuk (Tarn) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: April 25, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 45 1423 0.14 0.02 7 2 2.92 46 1453 0 0.02 7 1 2.92 47 1485 0 0.01 6 I 2.92 48 1515 0 0.02 7 1 2.95 49 1545 0 0.02 8 2 2.92 I 50 1576 0.04 0.03 12 1 2.92 51 1607 0 0.02 8 2 2.95 52 1636 0 0.02 8 2 2.92 53 1668 0.03 0.03 12 2 2.95 I 54 1698 0.06 0.03 12 2 2.92 55 1729 0 0.02 9 2 2.91 56 1761 0 0.02 7 1 2.94 57 1791 0 0.02 7 2 2.91 I 58 1821 0 0.01 6 2 2.91 59 1852 0.04 0.02 6 2 2.92 60 1884 0 0.02 9 2 2.94 61 1916 0 0.03 10 1 2.91 62 1947 0 0.02 7 2 2.92 I 63 1978 0 0.02 7 1 2.91 64 2010 0 0.01 6 2 2.92 65 2042 0 0.01 5 1 2.94 66 2072 0 0.02 7 2 2.94 I 67 2103 0 0.01 6 2 2.90 68 2135 0 0.02 7 I 2.91 II 69 2166 0 0.02 8 2 2.90 70 2198 0 0.02 8 2 2.91 I 71 2226 0 0.02 8 2 2.92 72 2257 0 0.03 11 2 2.91 73 2288 0 0.03 10 2 2.91 74 2318 0 0.02 7 2 2.90 I 75 2349 0 0.02 9 2 2.90 Lt. Deposits. 76 2379 0.03 0.03 11 2 2.92 Lt. Deposits. 77 2410 0 0.03 10 2 2.93 Lt. Deposits. 78 2442 0.04 0.02 9 2 2.94 79 2472 0 0.02 9 2 2.93 Lt. Deposits. I 80 2501 0 0.04 16 2 2.93 Shallow Pitting. Lt. Deposits. 81 2533 0 0.03 11 2 2.92 Lt. Deposits. 82 2564 0 0.05 20 2 2.91 Shallow Line of Pits. Lt. Deposits. 83 2595 0 0.02 9 2 2.91 Lt. Deposits. I 84 2627 0 0.03 13 2 2.94 Shallow Pitting. 85 2657 0 0.05 19 2 2.91 Shallow Line of Pits. Lt. Deposits. 86 2689 0.04 0.03 13 2 2.92 Shallow Pitting. Lt. Deposits. 87 2720 0 0.03 13 2 2.93 Shallow Pitting. I 88 2751 0 0.03 11 2 2.90 Lt. Deposits. 89 2782 0 0.04 15 2 2.94 Shallow Line of Pits. 90 2812 0 0.04 17 2 2.94 Shallow Pitting. 91 2840 0 0.04 14 2 2.90 Shallow Pitting. Lt. Deposits. 92 2872 0 0.03 11 2 2.90 Lt. Deposits. I 93 2904 0 0.04 17 2 2.92 Shallow Line of Pits. Lt. Deposits. 94 2934 0 0.04 17 2 2.92 Shallow Pitting. Lt. Deposits. rat I Metal Loss ion Body I Page 2 Penet I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD MOD Well: 2N -341 Body Wall: 0.254 in Field: Kuparuk (Tarn) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: April 25, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 95 2966 0 0.04 14 2 2.93 Shallow Pitting. Lt. Deposits. • I 96 2996 0 0.03 11 S 2.91 Lt. Deposits. ■ 97 3028 0 0.03 11 2 2.94 98 3057 0 0.03 12 2 2.91 Lt. Deposits. • 99 3089 0 0.04 15 2 2.93 Shallow Pitting. Lt. Deposits. • I 100 3120 0.04 0.04 14 2 2.92 Shallow Line of Pits. Lt. Deposits. • 101 3152 0.04 0.03 12 2 2.87 Lt. Deposits. • 102 3183 0.04 0.04 15 2 2.92 Shallow Pitting. Lt. Deposits. • 103 3214 0.04 0.04 15 2 2.91 Shallow Line of Pits. Lt. Deposits. • I 104 3246 004 0.03 11 2 2.90 Lt. Deposits. • 105 3278 0 0.04 15 2 2.91 Shallow Line of Pits. Lt. Deposits. • 106 3308 0 0.04 16 2 2.93 Shallow Line of Pits. Lt. Deposits. ■ 107 3337 0 0.04 15 2 2.91 Shallow Line of Pits. Lt. Deposits. • I 108 3368 0.03 0.05 19 3 2.94 Shallow Line of Pits. • 109 3399 0 0.03 13 2 2.92 Shallow Pitting. Lt. Deposits. • 110 3431 0 0.04 16 2 2.94 Shallow Pitting. • 111 3461 0 0.04 16 2 2.92 Shallow Pitting. Lt. Deposits. • 112 3493 0 0.05 18 2 2.95 Shallow Line of Pits. • 113 3524 0 0.05 20 2 2.91 Line of Pits. Lt. Deposits. • 114 3556 0 0.06 24 2 2.93 Line of Pits. ■ 115 3587 0 0.06 22 3 2.91 Line of Pits. Lt. Deposits. • 116 3618 0 0.05 19 2 2.91 Shallow Line of Pits. Lt. Deposits. ■ 1 1 17 3650 0.04 0.04 14 2 2.93 Shallow Pitting. • 118 3681 0 0.05 20 2 2.92 Line of Pits. Lt. Deposits. • 119 3713 0 0.05 20 , 2 2.92 Shallow Line of Pits. Lt. Deposits. • 120 3744 0.06 0.05 20 2 2.92 Shallow Line of Pits. Lt. Deposits. • I 121 3775 0 0.06 22 3 2.93 Line of Pits. Lt. Deposits. • 122 3807 0 0.06 24 2 2.94 Line of Pits. • ■ 123 3838 0 0.05 21 2 2.92 Line of Pits. Lt. Deposits. • 124 3870 0 0.06 22 2 2.90 Line of Pits. Lt. Deposits. • 125 3901 0 0.06 24 2 2.95 Line of Pits. ■ I 126 3931 0.05 0.06 22 2 2.90 Line of Pits. Lt. Deposits. • 127 3963 0.03 0.05 20 3 2.90 Line of Pits. Lt. Deposits. ■ 128 3994 0 0.06 22 3 2.91 Line of Pits. Lt. Deposits. • 129 4025 0.05 0.06 23 2 2.94 Line of Pits. • I 130 4056 0.04 0.05 19 3 2.89 Shallow Line of Pits. Lt. Deposits. • 131 4087 0.04 0.05 21 2 2.92 Line of Pits. Lt. Deposits. • 132 4118 0.05 0.05 21 0 2.89 Line of Pits. Lt. Deposits. i 133 4148 0.06 0.06 22 4 2.89 Line of Pits. Lt. Deposits. ■ I 134 4179 0 0.05 19 2 2.94 Shallow Line of Pits. • 135 4210 0.03 0.05 21 2 2.90 Line of Pits. Lt. Deposits. • 136 4241 0.04 0.06 24 3 2.91 Line of Pits. Lt. Deposits. • 137 4273 0.04 0.05 21 2 2.94 Line of Pits. • I 138 4304 0.04 0.06 24 1 2.92 Line of Pits. Lt. Deposits. • 139 4334 0.05 0.06 24 2 2.92 Line of Pits. Lt. Deposits. • 140 4365 0.04 0.05 20 3 2.92 Shallow Line of Pits. Lt. Deposits. • 141 4395 0.06 0.05 21 6 2.91 Line of Pits. Lt. Deposits. ■ 142 4425 0.04 0.05 21 4 2.94 Line of Pits. • I 143 4456 0.04 0.06 22 5 2.93 Line of Pits. • 144 4487 0 0.06 24 4 2.91 Line of Pits. Lt. Deposits. I Penetration BoBody dy I Page 3 I I ! • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD MOD Well: 2N -341 Body Wall: 0.254 in Field: Kuparuk (Tarn) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: April 25, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 145 4519 0 0.06 24 4 2.92 Line of Pits. Lt. Deposits. �■ 146 4550 0 0.06 22 ( 2.92 Line of Pits. Lt. Deposits. a■ 147 4582 0 0.06 22 3 2.92 Line of Pits. Lt. Deposits. No 148 4613 0.05 0.06 22 4 2.91 Line of Pits. Lt. Deposits. all 149 4645 0.03 0.06 23 3 2.92 Line of Pits. Lt. Deposits. ■■ I 150 4677 0.04 0.06 23 3 2.91 Line of Pits. Lt. Deposits. ■■ 151 4707 0.04 0.06 24 3 2.95 Line of Pits. ■ 152 4738 0.04 0.08 30 3 2.94 Line of Pits. ■■ 153 4769 0.03 0.06 23 3 2.95 Line of Pits. ■■ I 154 4800 0.04 0.06 24 4 2.91 Line of Pits. Lt. Deposits. ■■ 155 4832 0.06 0.06 22 2 2.93 Line of Pits. Lt. Deposits. ■■ 156 4863 0.04 0.07 28 4 2.92 Line of Pits. Lt. Deposits. e■ 157 4893 0.05 0.08 30 3 2.92 Line of Pits. Lt. Deposits. N■ I 158 4925 0.05 0.07 28 4 2.94 Line Corrosion. �■ 159 4956 0.06 0.09 35 4 2.91 Line Corrosion. Lt. Deposits. no 160 4987 0.06 0.07 27 3 2.93 Line of Pits. Lt. Deposits. o■ 161 5019 0.04 0.07 29 3 2.93 Line of Pits. Lt. Deposits. ■■ 162 5050 0.03 0.07 26 4 2.93 Line of Pits. .■ I 163 5081 0.04 0.07 27 4 2.94 Line of Pits. B■ 164 5113 0.04 0.07 28 4 2.93 Line of Pits. Lt. Deposits. ■■ 165 5144 0.05 0.07 26 4 2.91 Line of Pits. Lt. Deposits. s■ 166 5175 0.03 0.07 28 4 2.93 Line Corrosion. N■ 167 5206 0 0.07 27 3 2.93 Line of Pits. Lt. Deposits. •■ 168 5237 0.05 0.07 26 5 2.93 Line of Pits. M■ 169 5269 0.04 0.07 27 4 2.91 Line of Pits. Lt. Deposits. ■■ 170 5301 0.04 0.08 30 4 2.90 Line of Pits. Lt. Deposits. E■ I 171 5332 0.06 0.07 28 4 2.92 Line of Pits. Lt. Deposits. mil 5363 0.04 0.07 28 5 2.91 Line of Pits. Lt. Deposits. ■■ 173 5395 0.07 0.07 29 3 2.92 Line of Pits. Lt. Deposits. o■ 174 5426 0.04 0.07 26 5 2.91 Line of Pits. Lt. Deposits. ■■ I 175 5457 0.05 0.09 34 4 2.90 Line Corrosion. Lt. Deposits. �■ 176 5489 0.04 0.07 27 3 2.90 Line of Pits. Lt. Deposits. ■■ 177 5520 0.04 0.07 29 3 2.90 Line Corrosion. Lt. Deposits. N■ 178 5552 0.04 0.07 26 4 2.94 Line of Pits. u■ 179 5583 0.08 0.08 31 4 2.91 Line Corrosion. Lt. Deposits. ■■ I 180 5616 0.03 0.06 23 3 2.93 Line of Pits. Lt. Deposits. E■ 181 5647 0.06 0.09 33 4 2.93 Line Corrosion. Lt. Deposits. E■ 182 5677 0.03 0.07 29 2 2.90 Line of Pits. Lt. Deposits. ■■ 183 5709 0.05 0.07 28 4 2.91 Line of Pits. Lt. Deposits. II■ I 184 5741 0.06 0.10 38 4 2.91 Line Corrosion. Lt. Deposits. �■ 185 5772 0.08 0.11 43 4 2.91 Line Corrosion. Lt. Deposits. ■■ 186 5804 t).0 i 0.08 31 4 2.93 Line Corrosion. ■■ 187 5835 0.00 0.10 40 4 2.94 Line Corrosion. ■■ I 188 5866 0.07 0.09 34 4 2.94 Line Corrosion. ■■ 189 5897 0.04 0.07 28 2 2.91 Line of Pits. Lt. Deposits. ■■ 190 5929 0,06 0.10 41 4 2.92 Line Corrosion. Lt. Deposits. ■■ 191 5960 0.07 0.11 43 3 2.91 Line Corrosion. Lt. Deposits. ■■ 192 5991 0.07 0.09 34 3 2.91 Line of Pits. Lt. Deposits. ■■ I 193 6023 0.07 0.10 37 4 2.93 Line Corrosion. Lt. Deposits. ■■ 194 6054 0.07 0.09 35 4 2.93 Line Corrosion. Pration Body I I Meta Loss Body Page 4 I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD MOD Well: 2N -341 Body Wall: 0.254 in Field: Kuparuk (Tarn) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: April 25, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 195 6086 0.07 0.10 40 4 2.93 Line Corrosion. Lt. Deposits. ■�� 196 6117 0.07 0.10 39 4 2.93 Line Corrosion. Lt. Deposits. ■ m 197 6148 0.05 0.11 43 3 2.92 Line Corrosion. Lt. Deposits. ■ i 198 6179 0.06 0.08 33 4 2.93 Line of Pits. Lt. Deposits. ■EEIN 199 6210 0.08 0.11 44 4 2.89 Line Corrosion. Lt. Deposits. ■IEN I 200 6241 0.06 0.09 35 4 2.92 Line Corrosion. Lt. Deposits. ■NE 1 201 6273 0.08 0.10 40 4 2.91 Line Corrosion. Lt. Deposits. ■��r 202 6304 0.07 0.11 42 4 , 2.89 Line Corrosion. Lt. Deposits. LEEK 203 6336 0.00 0.11 43 4 2.93 Line Corrosion. Lt. Deposits. INENN I 204 6367 0.07 0.11 45 4 2.92 Line Corrosion. Lt. Deposits. mom 6399 0.07 0.11 44 4 2.90 Line Corrosion. Lt. Deposits. ■NEE 206 6431 0.07 0.11 44 4 2.90 Line Corrosion. Lt. Deposits. ■ENE 207 6461 0.05 0.12 46 4 2.90 Line Corrosion. Lt. Deposits. ■mENN I 208 6493 0.11 0.12 47 4 2.92 Line Corrosion. Lt. Deposits. ■��� 209 6524 0.07 0.13 52 4 2.90 Line Corrosion. Lt. Deposits. mown 210 6556 0.08 0.11 43 5 2.90 Line Corrosion. Lt. Deposits. ■ENE 211 6588 0.09 0.12 46 5 2.91 Line Corrosion. Lt. Deposits. mow 212 6619 0.07 0.11 43 4 2.90 Line Corrosion. Lt. Deposits. ■um I 213 6651 0.07 0.12 48 5 2.91 Line Corrosion. Lt. Deposits. MINN 214 6682 0.06 0.13 50 6 2.90 Line Corrosion. Lt. Deposits. NUMMI 215 6714 0.10 0.13 51 5 2.91 Line Corrosion. Lt. Deposits. Rolm 216 6745 0.06 0.12 47 4 2.90 Line Corrosion. Lt. Deposits. MIMI I 217 6777 0.08 0.14 56 4 2.90 Line Corrosion. Lt. Deposits. ■��, 218 6807 0.09 0.10 39 4 2.90 Line Corrosion. Lt. Deposits. Nummi 219 6839 0.05 0.11 42 4 2.92 Line Corrosion. Lt. Deposits. M.. 220 6872 0.08 0.11 44 4 2.91 Line Corrosion. Lt. Deposits. MOMS I 221 6902 0.09 0.12 46 4 2.91 Line Corrosion. Lt. Deposits. ■��� 222 6934 0.07 0.13 50 4 2.88 Line Corrosion. Lt. Deposits. ■ENE 223 6965 0.08 0.12 48 4 2.89 Line Corrosion. Lt. Deposits. ■■N■ 224 6996 0.09 0.12 46 5 2.90 Line Corrosion. Lt. Deposits. ■ENE 225 7028 0.09 0.12 48 4 2.89 Line Corrosion. Lt. Deposits. NM MM I 226 7060 0.06 0.12 46 4 2.89 Line Corrosion. Lt. Deposits. mom 7091 0.11 0.13 50 4 2.90 Line Corrosion. Lt. Deposits. ■a.. 228 7122 0.09 0.11 44 4 2.90 Line Corrosion. Lt. Deposits. ■WEN 229 7154 0.09 0.13 50 5 2.90 Line Corrosion. Lt. Deposits. 11111111111 I 230 7185 0.07 0.13 49 4 2.89 Line Corrosion. Lt. Deposits. ���� 231 7216 0.07 0.13 50 5 2.90 Line Corrosion. Lt. Deposits. ■NNE 232 7248 0.08 0.16 61 5 2.89 Line Corrosion. Lt. Deposits. BIM 233 7278 0.08 0.14 55 6 2.90 Line Corrosion. Lt. Deposits. MIMI I 234 7309 0.07 0.12 47 5 2.90 Line Corrosion. Lt. Deposits. ■IIIIIIM 235 7341 0.08 0.13 53 5 2.88 Line Corrosion. Lt. Deposits. MUM 236 7372 0.15 0.15 59 5 2.89 Line Corrosion. Lt. Deposits. MIMI 237 7404 0.12 0.18 71 6 2.87 Line Corrosion. Lt. Deposits. IMMO I 238 7432 0.09 0.14 56 6 2.89 Line Corrosion. Lt. Deposits. IINEE 239 7464 0.08 0.14 55 6 2.91 Line Corrosion. Lt. Deposits. mo■ 240 7495 0.11 0.12 48 4 2.88 Line Corrosion. Lt. Deposits. ■owa 241 7526 0.09 0.13 52 5 2.90 Line Corrosion. Lt. Deposits. ■... 242 7558 0.10 0.13 50 5 2.89 Line Corrosion. Lt. Deposits. ■ENE I 243 7590 0.11 0.14 57 5 2.90 Line Corrosion. Lt. Deposits. MIN 244 7621 0.07 0.13 52 5 2.89 Line Corrosion. Lt. Deposits. I Prati M enet e n Loss on Body I Page 5 I I 0 • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD MOD Well: 2N -341 Body Wall: 0.254 in Field: Kuparuk (Tarn) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: April 25, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 245 7652 0.11 0.16 63 6 2.90 Line Corrosion. Lt. Deposits. 411111111111111111111 ' 246 7684 0.10 0.22 85 5 2.90 Line Corrosion. Lt. Deposits. 1111111•11111•1111 247 7715 0.10 0.16 61 6 2.90 Line Corrosion. Lt. Deposits. 1E1MM 248 7747 0.12 0.15 59 6 2.89 Line Corrosion. Lt. Deposits. ammm. 249 7777 0.07 0.13 50 5 2.89 Line Corrosion. Lt. Deposits. om���1 I 250 7809 0.07 0.16 62 5 2.90 Line Corrosion. Lt. Deposits. ����� 251 7841 0.08 0.14 53 4 2.89 Line Corrosion. Lt. Deposits. ■momma 252 7872 0.09 0.13 52 5 2.89 Line Corrosion. Lt. Deposits. soloom 253 7903 U. I3 0.18 70 6 2.88 Line Corrosion. Lt. Deposits. mi 254 7935 0.07 0.14 55 4 2.88 Line Corrosion. Lt. Deposits. ����� I 255 7966 0.11 0.13 50 5 2.88 Line Corrosion. Lt. Deposits. IIMNIIMMI 256 7996 0.08 0.18 71 6 2.89 Line Corrosion. Lt. Deposits. 111111111•11111• 257 8027 0.09 0.16 61 5 2.90 Line Corrosion. Lt. Deposits. ■ommo I 258 8059 0.10 0.19 75 5 2.90 Line Corrosion. Lt. Deposits. ■����� 259 8090 0.10 0.15 60 6 2.89 Line Corrosion. Lt. Deposits. so�mmo 260 8122 0.10 0.24 95 7 2.89 Probable Holes! Lt. Deposits. rmmINE 261 8152 0.13 0.17 68 6 2.89 Line Corrosion. Lt. Deposits. Immmmo 262 8183 0.14 0.18 70 5 2.88 Line Corrosion. Lt. Deposits. mauls I 263 8215 0.12 0.21 82 7 2.89 Line Corrosion. Lt. Deposits. Hoosmoo 264 8246 0.16 0.18 72 6 2.89 Line Corrosion. Lt. Deposits. mmommi 265 8277 0.11 0.17 69 5 2.90 Line Corrosion. Lt. Deposits. moimis 266 8308 0.10 0.19 73 7 2.90 Line Corrosion. Lt. Deposits. IMI MIMIM I 267 8339 0.11 0.16 62 6 2.90 Line Corrosion. Lt. Deposits. ������ 268 8369 (1.10 0.18 69 6 2.90 Line Corrosion. Lt. Deposits. Imm�mo 269 8401 ((.09 0.19 73 6 2.88 Line Corrosion. Lt. Deposits. ■ umwom 270 8433 0.14 0.27 100 8 2.85 Hole! Lt. Deposits. r1111111111•1111111 I 271 8464 0.15 0.17 67 7 2.88 Line Corrosion. Lt. Deposits. mom 8496 0.17 0.30 100 7 2.90 Hole! Lt. Deposits. i��o�■ 273 8527 0.15 0.22 86 6 2.89 Possible Hole! Lt. Deposits. i munno 274 8558 0.17 0.39 100 10 2.88 Hole! Lt. Deposits. ..... 275 8590 0.13 0.19 76 9 2.88 Line Corrosion. Lt. Deposits. ��mm■ I 276 8621 0.16 0.32 100 7 2.89 Multiple Holes! Lt. Deposits. imum 277 8653 0.16 0.45 100 11 2.88 Multiple Holes! Lt. Deposits. ����m 278 8683 0.12 0.33 100 8 2.90 Multiple Holes! Lt. Deposits. rmommo 279 8715 0.14 0.17 65 7 2.90 Line Corrosion. Lt. Deposits. mom I 280 8746 0.11 0.16 65 6 2.90 Line Corrosion. Lt. Deposits. ummi 281 8777 0.12 0.26 100 6 2.90 Hole! Lt Deposits. ilimumm 282 8809 0.08 0.21 81 7 2.89 Line Corrosion. Lt. Deposits. ummo■ 283 8840 0.12 0.21 81 7 2.89 Line Corrosion. Lt. Deposits. HIM III III 11111 I 284 8871 0.12 0.17 68 7 2.88 Line Corrosion. Lt. Deposits. mom 285 8903 0.14 0.20 81 7 2.88 Line Corrosion. Lt. Deposits. loom 286 8934 0.16 0.19 75 7 2.90 Line Corrosion. Lt. Deposits. immum■ 287 8966 0.12 0.28 100 7 2.90 Hole! Lt. Deposits. rmmoms 288 8997 0.10 0.26 100 8 2.89 Hole! Lt. Deposits. 111111111111•MI I 289 9028 0.15 0.51 100 8 2.89 Multiple Holes! Lt. Deposits. i����� 290 9060 0.16 0.27 100 7 2.89 Hole! Lt Deposits. Immo 291 9092 0.11 0.26 100 7 2.89 Hole! Lt. Deposits. unimmul 292 9122 0.12 0.21 82 6 2.89 Line Corrosion. Lt. Deposits. uMMMM I 293 9153 0.18 0.20 79 7 2.90 Line Corrosion. Lt. Deposits. r����� 294 9184 0.09 0.24 93 7 2.90 Possible Hole! Lt. Deposits. I Penetration l Body I Meta Loss Body Page 6 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD MOD Well: 2N -341 Body Wall: 0.254 in Field: Kuparuk (Tarn) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: April 25, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 295 9216 0.10 0.20 78 6 2.90 Line Corrosion. Lt. Deposits. �■ ■■■■■ 296 9247 0. 1 1 0.29 100 6 2.89 Hole! Lt Deposits. 11111111111111111111111111 297 9279 0.21 0.27 100 9 2.89 Hole! Lt. Deposits. '■■■■■ ■ ■■ 298 9311 0.11 0.24 94 6 2.89 Possible Hole! Lt. Deposits. m■ ■ ■■■■■■ 299 9341 0.14 0.29 100 13 2.88 Hole! Lt Deposits. ■■■■■■■■ I 300 9372 0.16 0.28 100 7 2.90 Hole! Lt Deposits. 301 9404 0.1 5 0.19 74 8 2.87 Line Corrosion. Lt. Deposits. m■■■■■ �■■■■■■ . � I 302 9435 0.13 0.17 69 �■ 2.90 Line Corrosion. Lt. Deposits. ■■■■ 303 9464 0.09 0.34 100 9 2.89 Hole! Lt Deposits. NMI ■■■■■ I 304 9496 0.11 0.27 100 9 2.91 Hole! Lt Deposits. 305 9525 0.1 0.20 77 6 2.88 Line Corrosion. Lt. Deposits. ■■■■■■ �■■■■■ ■�' 306 9555 0.12 0.34 100 9 2.87 Multiple Holes! Lt. Deposits. ■■■■■■■■ 307 9587 0.13 0.30 100 10 2.90 Hole! Lt Deposits. ■■■■■■■■ I 308 9618 0.12 0.27 100 8 2.88 Hole! Lt Deposits. ammonia' 9650 0.13 0.26 100 9 2.89 Multiple Holes! Lt. Deposits. ■■■■■■■■ 310 9681 0.13 0.40 100 10 2.90 Multiple Holes! Lt. Deposits. ■■■■■■■ 311 9713 0.13 0.22 86 6 2.89 Possible Hole! Lt. Deposits. mammon's 312 9744 0.21 0.17 69 8 2.90 Corrosion. Lt. Deposits. m■■■■ I 313 9775 0.24 0.36 100 10 2.90 Multiple Holes! Lt. Deposits. ■■■■■■■■ 314 9807 0.11 0.29 100 7 2.90 Hole! Lt Deposits. m■■■■■■■ 315 9836 0.12 0.31 100 7 2.88 Multiple Holes! Lt. Deposits. m■■■■■■■■ 316 9865 0.12 0.34 100 10 2.89 Hole! Lt. Deposits. ■■■■■■■■ U 317 9896 0.13 0.24 95 7 2.89 Probable Hole! Lt. Deposits. �■ ■■■■ ■■■ 318 9927 0.11 0.25 98 2.88 Probable Hole! Lt. Deposits. I■■■■■■■■ 319 9959 0.16 0.29 100 7 2.88 Hole! Lt. Deposits. n■■■■■■■ 320 9990 0.15 0.41 100 9 2.89 Multiple Holes! Lt. Deposits. i■■■■■■■■ I 321 10021 0.12 0.30 100 9 2.89 Hole! Lt. Deposits. i ■ ■■■■■■■ 322 10053 0.13 0.32 100 9 2.92 Multiple Holes! Lt. Deposits. ■■■■■■■■ 323 10084 0.10 0.29 100 7 2.90 Hole! Lt. Deposits. u■■■■■■■ 324 10116 0.17 0.24 94 7 2.90 Multiple Possible Holes! Lt. Deposits. u■■■■■ I 325 10147 0.11 0.19 74 9 2.90 Line Corrosion. Lt. Deposits. ■■■■■■�, 326 10179 0.15 0.35 100 12 2.91 Multiple Holes! Lt. Deposits. ■■■■■■■■ 327 10210 0.14 0.33 100 8 2.91 Hole! Lt Deposits. i■■■■■■ 328 10242 0.12 0.18 71 6 2.92 Line Corrosion. Lt. Deposits. m■■■■ 329 10273 0.10 0.16 61 7 2.90 Line Corrosion. Lt. Deposits. n■■■■■ I 330 10305 0.1 1 0.16 63 6 2.93 Line Corrosion. Lt. Deposits. memo. 331 10335 U. 12 0.16 62 7 2.91 Line Corrosion. Lt. Deposits. i■■■■ 332 10367 0.14 0.13 52 7 2.93 Line Corrosion. Lt. Deposits. ,■■■■ll 333 10400 tl. 19 0.42 100 11 2.92 Multiple Holes! Lt. Deposits. ■■■■■■■■ I 334 10430 0.12 0.37 100 12 2.92 Multiple Holes! Lt. Deposits. ■■■■■■■■ 335 10462 0.21 0.40 100 8 2.93 Multiple Holes! Lt. Deposits. i■■■■■■■■ 336 10492 0.20 0.81 100 9 2.90 Multiple Holes! Lt. Deposits. ■■■■■■■■ 337 10523 0.18 0.38 100 11 2.91 Multiple Holes! Lt. Deposits. ■■■■■■■■ I 338 10555 0.23 0.77 100 5 2.90 Hole! Lt. Deposits. ■■■■■■■■■ 339 10585 0.29 0.34 100 9 2.92 Hole! Lt Deposits. ■■■■■■■■ 340 10617 0.19 0.29 100 9 2.93 Multiple Holes! Lt. Deposits. ■■■■■■■■ 341 10647 0.12 0.35 100 7 2.90 Multiple Holes! Lt. Deposits. m■■■■■■■ 342 10678 0.09 0.33 100 8 2.92 Multiple Holes! Lt. Deposits. III ■■■■■■■ I 343 10710 0.24 0.50 100 10 2.92 Multiple Holes! Lt. Deposits. ■■■■ III ■■III 344 10740 0.25 0.34 100 8 2.92 Multiple Holes! Lt. Deposits. I rat Body Metal Loss ion Body Page 7 Penet I . I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD MOD Well: 2N -341 Body Wall: 0.254 in Field: Kuparuk (Tarn) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: April 25, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 345 10771 0.20 0.41 100 7 2.90 Multiple Holes! Lt. Deposits. i......� I 346 10803 0.23 0.37 100 8 2.92 Multiple Holes! Lt. Deposits. i..••.. mi 347 10834 0.1(1 0.32 100 8 2.91 Hole! Lt. Deposits. i������om 348 10864 0.27 0.60 100 6 2.91 Multiple Holes! Lt. Deposits. unam•mio 349 10895 0.39 0.31 100 6 2.92 Hole! Lt. Deposits. o111111111111111111111M1 I 350 10925 0.15 0.34 100 7 2.91 Multiple Holes! Lt. Deposits. 351 10956 0.08 0.14 54 5 2.91 Line Corrosion. Lt. Deposits. �omm ommi�� 352 10987 0.22 0.28 100 0 2.92 Hole! Lt. Deposits. muumemi 353 11019 0.1 0.28 100 7 2.91 Hole! Lt. Deposits. immonomminii I 354 11050 (.05 0.34 100 6 2.92 Hole! Lt. Deposits. ������� 355 11082 0.13 0.19 76 4 2.92 Line of Pits. Lt. Deposits. •.••• 356 11113 0.08 0.15 59 6 2.92 Line of Pits. Lt. Deposits. Me•1 357 11141 0.16 0.13 52 4 2.93 Line of Pits. Lt. Deposits. ■um "I 358 11171 0.07 0.12 48 5 2.92 Line of Pits. Lt. Deposits. ..�. I 359 11202 0.08 0.20 78 5 2.92 Line of Pits. Lt. Deposits. ■������ 360 11235 0.13 0.16 65 6 2.94 Line of Pits. omm 361 11266 0.12 0.20 80 5 2.94 Line of Pits. ■ iumo 362 11297 0.05 0.17 65 6 2.94 Line of Pits. NM MN I 363 11325 0.10 0.11 45 4 2.93 Line of Pits. Lt. Deposits. ■�� 364 11357 0.08 0.09 36 5 2.92 Line of Pits. Lt. Deposits. u. 365 11388 0.03 0.07 28 1 2.94 Line of Pits. ' 365.1 11419 0 0 0 0 2.81 Baker CMU Sliding Sleeve I 366 11420 0.07 , 0.08 30 4 2.94 Line of Pits. BEd 366.1 11452 0.05 0.08 31 3 2.96 Pup Line of Pits. �� 366.2 11468 0 0 0 0 2.90 GLM 1 (Latch @ 9:30) 366.3 11473 0.10 0.13 51 5 2.97 Pup Line of Pits. NUUM 367 11489 0 0.12 46 4 2.92 Line of Pits. Lt. Deposits. ' 367.1 11519 0 0 0 0 2.75 Camco D Nipple 367.2 11521 0.05 0.06 22 3 2.92 Pup Line of Pits. Lt. Deposits. I 367.3 11526 0 0 0 0 2.98 Baker Locator 367.4 11527 (1 0 0 0 2.98 Baker 80-40 Casing Seal Assembly I 367.5 11550 0 0.07 27 3 2.96 Pup Line of Pits. ■� 368 11558 0.06 0.10 39 3 2.91 Line of Pits. Lt. Deposits. ■�� 369 11588 0 0.08 31 3 2.93 Line of Pits. Lt. Deposits. INN 370 11618 0 0.09 34 3 2.96 Line of Pits. ■11 I 371 11650 0 0.04 17 2 2.95 Shallow Pitting. 371.1 11682 0.07 0.09 33 4 2.95 Pup Line of Pits. ■mI 372 11692 0 0.05 21 2 2.95 Isolated Pitting. 373 11724 0 0.04 14 2 2.96 Shallow Pitting. I 374 11754 0.05 0.08 32 1 2.92 Isolated Pitting. Lt. Deposits. 375 11786 0.08 0.03 13 2 2.93 Shallow Pitting. 376 11818 0.12 0.02 9 2 2.96 I I Pe ne tat0n Metal Loss Body Body I Page 8 I I I • • I PDS Report Cross Sections I Well: 2N -341 Kuparuk (Tarn) Survey Date: April 25, 2011 Field: Tool Type: UW MFC 24 No. 10000429 (Hal) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 EUE 8RD MOD Analyst: HY. Yang I I Cross Section for Joint 336 at depth 10502.770 ft Tool speed = 51 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 90% '\ Tool deviation = 72° \ / I • I 7 1 • ____---) _____K I --, \ ■ I Finger = 10 Penetration = 0.806 ins Multiple Holes 0.81 ins = 100' . "enetration HIGH SIDE = UP I I • • I s„ PDS Report Cross Sections I Well: 2N -341 Survey Date: April 25, 2011 Field: Kuparuk (Tam) Tool Type: UW MFC 24 No. 10000429 (Hal) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 EUE 8RD MOD Analyst: HY. Yang I I Cross Section for Joint 338 at depth 10573.030 ft Tool speed = 50 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 95% Tool deviation = 70° / 1 I / / I Finger = 8 Penetration = 0.773 ins Hole 0.77 ins = 100% Wall Pen:tr. • HIGH SIDE = UP } KUP 2N -341 Conoco Phillips ip$ a ttributes gle & MD TD I Wellboce APINWI Field Name Well Status Intl) NO ptl(B) Act Mtn IRKS) carhooiNrkps 501032026300 TARN PARTICIPATING AREA PROD 74.55 2,369.65 12,339.0 Comment H2S (ppm) Date Annotation End Date KB•Grd p0 Rig Release Date I ... Well coma. -20-341 srorzoto 10 oaso AM SSSV: NIPPLE 36.00 7/6/1998 Schematic - Actual Annotation Depth ptKB) End Date 45 Anrho 1/14/2010 tatlan Last WO: Last Mod... End Date Last Tag: SLM 12,048.0 6/8/2010 Rev Reason: GLV CIO Imosbor 9/6/2010 Casing Strings HANGER, 17 111111,7[ . Casing Description String 0... String ID... Top (5B) Set Depth (f... Set Depth (ND) ... String Wt... String... String Top Thrd 1 CONDUCTOR 16 15062 36.0 108.0 108.0 62.58 H - 40 WELDED I _____ Casing Description Sting 0... String ID ._ Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt_ String ... String Top Tnrd sr SURFACE 75/8 6.750 30.0 4,227.1 2,300.4 29.70 L BTC Casing Description String 0_. String D ... Top (MB) Set Depth (L. Set Depth (NO) ... String Wt... String ... String Top mrd PRODUCTION 51/2 4.950 27.5 12,317.7 5,184.1 15.50 L -80 EUEBrd 5.5 "x3.5" Tubing Strings I ' IN String D Tubing Description String 0... ... Top (5KB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top cord TUBING 3 1/2 2.992 16.9 11,544.2 4,783.8 9.30 L -80 EUE8rdMOD Completion Details Top Depth (ND) Top Ind Nord-. Top (6KB) (MB) 1 Rem ID Description comment pry I 16.9 16.9 -1.22 HANGER FMC GEN V TUBING HANGER 2.992 491.4 491.0 6.42 NIPPLE CAMCO DS NIPPLE 2.875 CONOJCTOR, 11,414.3 4,708.7 55.47 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 38-108 11,515.8 4,767.3 53.97 NIPPLE CAMCO 'D' NIPPLE 2.750 11,525.4 4,773.0 53.83 LOCATOR BAKER LOCATOR 2.985 NPPLE, 401 I g 11,526.2 4,773.4 53.81 SEAL ASSY BAKER 80 -40 CASING SEAL ASSY 2.985 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens _ Top (RKB) Blot (R103) (ftR ( 8 ) Zone Date (.h.- Type Comment 11,870 11,885 4,969.1 4,977.1 S -7, 2N-341 12/25/2005 6.0 APERF 2.5" HSD, 60 deg phase I i 12,025 12,045 5,048.6 5,058.4 S-5, S-3, 2N -341 7/29/1998 4.0 IPERF 2.5" HC, BH, 180 PH, 90 ORIENT 12,045 12,065 5,058.4 5,068.3 S -3, 2N -341 7/28/1998 4.0 IPERF 2.5" HC, BH, 180 PH, 90 ORIENT Stinlatations & Treatments Bottom - Mn Top Max Btm Top Depth Depth I Depth Depth (TVD) (ND) (6KB) (KB) (RKB) MB) Type Date Comment 11,885.0 4,969.1 4,977.1 FRAC 1 2/28/2005 Re -Frac completed thfu flush, placed 195895# of 16/20 prop in the formation w/ 10# ppa at the perfs. ACE suRE J l Frac was completed per design using 50# XL Gel SURFACE and a Bracket Frac was pumped in front of the Frac i zz i stage. 12/28/2005 Notes: General & Safety SLEEVE End Date Annotator 11,717 I 1 6/12/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 i GAS LET 11,484 1 C I NIPPLE, 11516 I .-L' ':1' LOCATOR, 11.525 I SEAL A050 11,526 k I PPERF I 11 870- 11.885 FRAC, 11.870 ' I Mandrel Details Top Depth Top Port (ND) Intl OD Valve Latch Size TRO Rim Stn Top MKS) (SRN 1 Make world (M) Sery TYPe TYPe (in) (Psi) Run Date Coen_. IPERF. 12.025 IPER 1 11 4,737.4 54.73 CAMCO KEG - 2 - 9 1 GAS LIFT DMY BTM 0.000 0.0 6/18/2010 IPERF. 12,045-12.065 I I X3 PRODUCTION • 5 5' 5 28- 12,318 TD, 12,339 1 1 i ~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ~~~., n .... 1 RE: Leak Detection Log: 2N-341 Run Date: 8/12/2010 August 16, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2N-341 Digital Data in LAS format, Digital Log Image file 50-103-20263-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 kinton wood@halliburto 0 a ~, ~.. ~ ~ . ^l! Date: ,~ ; ; i- ~ ~'~ , ; ~ , ~,~ a~ ~~'`~3 l ~~~~~ Signed: • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 2N-341 Run Date: 8/6/2010 August 9, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2N-341 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20263-00 r x`.14 l~'ti ~~ 1+ rt 1,f 5, 3,[ !htr. ,.~~-.Gasv ~ ., 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: ~"~~, ~?~~ ~lii a , s ~ ~ ~ ~D~ ~0~ Signed: ~~ • Page 1 of 1 Regg, James B (DOA) • From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Wednesday, June 02, 2010 8:57 AM ~~~~~ ~~vJ~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: Producer 2N-341 (198-103) P' ~ ~ ~~° I a Attachments: 2N-341 TIO.pdf; 2N-341.pdf 2N-341(198-103) failed a diagnostic TIFL 6/1/10 confirming TxIA communication. A leaking gas lift valve is suspected as the cause. Slickline troubleshooting has been scheduled. This well will be a e o e weekly SCP report. The schematic and TIO are attached. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 ( ~{~F '' f t~'~, r f. 6/2/2010 Date ,Date 2500 2000 1500 .N t1 1000 500 0 Nov-09 6/1/2010 120 211/2010 Feb-10 May-10 <k'ct Z.~ - 54- I 120 100 80 LL 60 y 40 20 0 Aug-10 Bleed History YELL_ID TIME STR-PRES END-PRES 2N-341 3/29/2008 2300 1300 GLO Annular Communication Surveillance Dec-09 Jan-10 Mar-10 Apr-10 May-10 Jun-10 Jul-10 Date "-~~ ~ KUP ~~~~ ~ rWell Attributes - _ __ -- - ~OE'lOCOPFti~ I J w ileo~eaRiiuwi _FlelaName w u I''""'' 501032026300 TARN PARTICIPATING AREA PR( Comment H23 (ppm) Date Annotatiot weu corao'. ~ - 94ia47 PA1 100 1/13/2009 Last WO: ' s. - -.i= _ ~Annotatfon Depth (kKB) End Date Annotation Last Tag SLM 12.066.0 6/4/2009 Rev Reason: TAG _- Casing Strings CONDUCTOR 16 SURFACE 7 5/8 __ _ PRODUCTION 51/2 LINER 3 1/2 __i_ ,Tubing Strings i. Sf g OD ' CONDUCTOR, i T bang D pt on '. (~ ) ~ 1oa TUBING '~ 31/2 ~. ~: c E I, Other In Hole All Jewelr j ToP Depth 1 (ND) Top Intl _ _ Top (ftKB) (ftKB) (°) 0 NIPPLE. 493 493 492.6 6.47 NIP _ 11,416 4,709.7 55.44 SLE _ I 11,466 4,738.4 54.70 GA~ 1, 11,517 4,768.0 53.95 NIP 11,527 4,773.9 53.80 XO suRF4 zzi ~ i 11,544 4,783.7 53.82 S6 GAS LIFT, 11,4fi6 NIPPLE, 11,517 PRODUCTION, 11,527 XO, 11,527 SEAL, 11,544 I {~ Ii I 1 t; l^~ =+ P' t!°°._~ 1 ~ ~~: r I APERF, ~ ~ 11,870-11,885 FRAC, 11,870 IPERF, 12,026-12,046 E F 1 I IPERF, 12,045-12,065 SHOE, 12,315 LINER. 12,318 TD. 12.339 Perforations & Slots Top (ND) Btm (ND) 2N-341 ax Angle & MD STD cl 1-! MD (ttKB) Act BM ((tKBj 74.55 2, 369.65 12, 339.0 KB•Grtl (k) Rig Release Da' 36.00 7/6/1998 triplwj ~ 6/7/2009 Set Depth tTVD1 String Wt String (ftKB) (Ibs/k) Grade I String Top Thrd Set Depth Set Deplh (ND) SUiny Wt St ing 'op (ftKB) (ftKB) (ftKB) (Ibs/tt) i G ada S[ 'ng Top Thrd 0.0 11,544.0 4,743.7 9.301E 80 EUE Run & Retrievable, Fish, etc.} Comment stimulations & Treatments Bonon Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (ftKB) (ftKB) (ftKB) (ftKB) 11,870.0 11,885.0 4,969.1 4,977.1 FRAC 12/28/2005 Re-Prat completed thru flush, placed 195895# of 16/20 prop in the formation wl 10# ppa at the perfs. Frac was completed per design using 50# XL Gel and a Bracket Frac was pumped in front of the Fret stage. 12/2&2005 Notes: General & Safe ~a !~~ 1 ~/ // Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4775 07/10/08 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2W-04 12061711 INJECTION PROFILE ja 06/24/08 1 1 1 L-20A 10215099 PRODUCTION PROFILE QU '~ 06/26/08 1 1 1 G-05 12080389 LDL 06/27/08 1 1 3B-10 12061714 INJECTION PROFILE 'I' - t / - 06/27/08 1 1 2L-327 12061715 SBHP SURVEY 06/28/08 1 1 1J-109 12080390 SBHP SURVEY f 06!28/08 1 1 2N-323 12061716 SBHP SURVEY '~ s- ~ 06/28!08 1 1 2X-15 12080392 SBHP SURVEY G - 06/29/08 1 1 2N-303 12061717 SBHP SURVEY s 06/29/08 1 1 2L-309 12061718 SBHP SURVEY 06/29/08 1 1 2X-14 12080391 SBHP SURVEY / 06/29/08 1 1 2X-11 12080393 SBHP SURVEY ~(- s~ 06/29/08 i 1 iG-09 12080401 INJECTION PROFILE I> -' 1 /~ 07/05/08 1 1 2H-05 12080396 SBHP SURVEY ~° '-.~ 06/30/08 1 1 2H-12 12080395 SBHP SURVEY _ ~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY / 06/30/08 1 1 iD-07 12080398 SBHP SURVEY - .( 07/02/08 1 1 2N-341 12061720 SBHP SURVEY O 06/30/08 1 1 3C-15 11982441 USIT - (~(~ / (a 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE `6 - ' ~ 07/08/08 1 1 1 L-19 12061724 PRODUCTION PROFILE i 0 -b 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - 5 07/09/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. U • . . Conoc~illips Alaska ~ëeE.'VEO SEP 1 2 2007 . . n ~'8$\ta 0\\ & Gas Cons. CommlSSIO Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 07, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED SEP 12 2007 'ò'" I O~ \0\ 34\ ~~/ Dear Mr. Maunder: 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 conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped on September 5,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, \. ~~Çll/- ~end ConocoPhillips Well Integrity Field Supervisor ~ . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft oal 2N-320 199-001 4" n/a 4" n/a 2 9/5/2007 2N-321 198-173 6" n/a 6" n/a 2 9/5/2007 2N-323 198-071 1" n/a 1" n/a 1 9/5/2007 2N-325 198-163 10" n/a 10" n/a 2 9/5/2007 2N-326 200-155 9" n/a 9" n/a 3.5 9/5/2007 2N-337 206-163 6" n/a 6" n/a 1 9/5/2007 2N-339 198-100 8" n/a 8" n/a 2.5 9/5/2007 2N-341 198-103 3" n/a 3" n/a 1 9/5/2007 2N-342 207-068 18" n/a 18" n/a 4.5 9/5/2007 2N-343 198-092 4" n/a 4" n/a 2 9/5/2007 2N-345 204-034 9" n/a 9" n/a 3.5 9/5/2007 Date 9/7/2007 ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocciP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 January 1 L, LUUÖ RECÉ/VtD JA.N 1 7 ;/¡< Alask a" ("'.':) a il&G... as C(,'I')'!' A .' .1., nth'I'k""~' '. " v II:t iI/.:: Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2N-341 (APD # 198-103) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 2N-341. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ¡AI J1ð~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells ,-- .··/A~~.U~Ui:::W) U. A~~, 1 3 2.005 5(;Q'UtJÐ~&f,) ~JI ß'I,: M M/skad 1. Operations Performed: JAN 1 7 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas C C .. REPORT OF SUNDRY WELL OPERATIONS Ancho~~s~ omnvSSIOI o Time Extension 0 o ) Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Operat. ShutdownD Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 28', Pad 121' 8. Property Designation: ADL 375075, ALK 4306 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural SURFACE PRODUCTION PRODUCTION PRODUCTION Perforation depth: measured 12339' 5194' RECEIVED ) STATE OF ALASKA Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Stimulate 0 Waiver 0 Other true vertical measured 12004' Re-enter Suspended Well 5. Permit to Drill Number: 198-1031 6. API Number: 50-103-20263-00 Exploratory 0 Service 0 9. Well Name and Number: 2N-341 10. Field/Pool(s): Kuparuk River Field 1 Tarn Oil Pool feet feet feet feet Plugs (measured) Junk (measured) true vertical Length Size MD TVD Burst Collapse 108' 4199' 11499' 789' 16" 7-5/8" 5-1/2" 3-1/2" 108' 4227' 11527' 12316' 108' 2301' 4774' 5183' Measured depth: 11870'-11885',12025'-12065' true vertical depth: 4969'-4977', 5048'-5068' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 11544' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 493' 12. Stimulation or cement squeeze summary: Intervals treated (measured) refer to attachment RBDMS 8Ft ,IAN 1 7 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Tubinç¡ Pressure Prior to well operation 2360 5548 592 286 Subsequent to operation 1886 5967 1781 88 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAG 0 GINJD WINJ 0 WDSPLD 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: Mike Mooney @ 263-4574 Mike Mooney jJllVfö~ Form 10-404 Revised 0412004 0 R \ G \ N A L Contact Printed Name Signature Title Phone Wells Group Team Lead Date / /J¿,/6Jt. Prepared bv Sharon AI/sup-Drake 263-4612 Submit Original Only ConocoPhillips AlasJa. Inc. 2N-341 TUBING (0-11544, 00:3,500, 10:2,992) ~ROOUCTION (0-4227, 00:7,625, Wt:29.70) ~ROOUCTION (0-11527, 00:5.500, Wt:15,50) Gas Lift Indrel/Oummy Valve 1 '11466-11467, , 00:4.725) NIP :11517-11518, 00:3,500) XO '11527 -11528, , 00:5.500) ~ROOUCTION :11527-12316, 00:3.500, Perf :11870-11885) FRAC 11870-11885) Perf 12025-12045) Perf ,12045-12065) ') KRU ~-341 API: 501032026300 SSSV Type: NIPPLE Angle @ TS: deg @ Angle @ TD: 64 deg @ 12339 Annular Fluid: DSUSW 7.1/8.34 ppg Reference Log: Last Tag: 12004 Last Tag Date: 1/1/2006 Cä$ihg.String··~..'ALL. Description SURFACE PRODUCTION PRODUCTION PRODUCTION TubihQ/StfingW·.TI.JBI NG Size I Top 3.500 0 Pèr'føfätiOns$uml1'iåry Interval TVD 11870 - 11885 4969 - 4977 12025 - 12045 5048 - 5058 12045 - 12065 5058 - 5068 Well Type: PROD Orig 7/6/1998 Completion: Last W/O: Rev Reason: SET OV Ref Log Date: TD: 12339 ftKB Max Hole Angle: 75 deg @ 2370 Last Update: 1/3/2006 Size 16.000 7.625 5.500 3.500 Top o o o 11527 Bottom 108 4227 11527 12316 TVD 108 2301 4774 5183 Wt 62,58 29.70 15.50 9.30 Grade H-40 L-80 L-80 L-80 Thread WELDED BTC LTC EUE Zone Status Ft SPF Date Type Comment 15 6 12/25/2005 APERF 2.5" HSD, 60 deg phase 20 4 7/29/1998 IPERF 2.5" HC, BH, 180 PH, 90 ORIENT 20 4 7/28/1998 IPERF 2.5" HC, BH, 180 PH, 90 ORIENT Stimûlatiøos&··Treåfmaots Interval Date Type 11870 - 11885 12/28/2005 FRAC Gas Lift·Máridfèls/Vålves St MD TVD Man Man Type V Mfr Mfr 1 11466 4739 CAMCO KBG-2-9 CAMCO (Dther..· iÞlugs,éqÚip.,'.êìC;)..W.J. EWEl..RY Depth TVD Type 493 493 NIP 11416 4710 SLEEVE 11517 4768 NIP 11527 4774 XO 11544 4784 SEAL 12316 5183 COLLAR Comment Re-Frac completed thru flush, placed 195895# of 16/20 prop in the formation wI 10# ppa at the perfs. Frac was completed per design using 50# XL Gel and a Bracket Frac was pumped in front of the Frac 12/28/2005 V Type DMY VOD Latch Port TRO 1.0 INT 0.000 0 Description Date Run 1/2/2006 Vlv Cmnt ID 2.875 2.813 2.750 3.500 2.985 0.000 CAMCO 'DS' NIPPLE BAKER CMU W/CAMCO 'DS' PROFILE CAMCO NOGO 'D' NIPPLE CROSSOVER BAKER CASING SEAL ASSY 80-40 PBTD ) 2N-341 Well Events Summary ) DATE Summaryops 12/14/05 JETTED TUBING WITH HOT OIL FROM SURFACE TO 11550', JETTED JEWELRY FROM 11550' TO 11400'. 12/15/05 TAG FILL WI 2.72" CENT & 11' X 2.5" DUMMY DRIFT @ 12083' RKB. IN PROGRESS. 12/20105 SET 2.75" CAT SV @ 11517' RKB. LOADED TUBING & IA W240 BRLS DIESEL. SET 1" (BTM LATCH) DMY VLV @ 11466' RKB. PRESSURE TESTED TBG TO 3500 PSI (HELD GOOD), BLED BACK TO 1500 PSI. JOB IN PROGRESS. 12/21/05 ATTEMPTED TO PULL 2.75" STANDING VLV FROM 11517' RKB. ATTAINED DEPTH OF 9708' WI 73 DEG DEVIATION. IN PROGRESS. 12/22/05 PULLED SV @ 11517' RKB. 12/24/05 SAND DUMP FROM 12083 TO 11955', FIRST ATTEMPT LEFT NO SAND IN LINER, SECOND ATTEMPT RESULTED IN TAG WITHIN WINDOW. TOTAL OF 1400 # SAND 12/25/05 RAN MEMORY GRICCL AND FLAGGED COIL. PERFORATED FROM 11870' -11885' WITH 2 1/2" HSD, 2506 RDX CHARGES, 6 SPF. WELL FP WITH DIESEL AND LEFT SHUTIN. 12/28/05 Re-Frac completed thru flush, placed 195895# of 16/20 prop in the formation wI 10# ppa at the perfs. Frac was completed per design using 50# XL Gel and a Bracket Frac was pumped in front of the Frac stage. 260 psi of net pressure gain was seen. Maximum W 12/30105 CLEANED OUT FRAC GEL & SAND TO 11,965' CTD PUMPING 1.5# BIOZAN & NITROGEN THROUGH THE MI RECYCLE SKID. TAGGED HARD FILL @ 11,916' CTD. HEAVY GEL/SAND CLOGGING THE SHAKERS. 12/31/05 PERFORMED A FILL CLEAN OUT TO 12,167' CTD PUMPING 1.5# BIOZAN @ 1 BPM & NITROGEN @ 300 SCFM. USED THE MI-SKID TO RECIRCULATE BIOZAN - HEAVY SAND TO SURFACE, GOOD 1:1 RETURNS. FREEZE PROTECTED WITH DIESEL TO 3000' CTD. 1/1/06 TAG FILL @ 12004' SLM. SET 2.75" CATCHER SUB @ 12517' SLM. PULLED 1" DV @ 11466' RKB. IN PROGRESS. 1/2/06 SET 1" X .313" OV @ 11466' RKB. PULL CATCHER SUB @ 11517' RKB. WELL IS READY FOR FLOW BACK. RE: OOA Cement Top-offs Subject: RE: OOA Cement Top-offs From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Mon, 27 Sep 2004 16:45:56 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> oil} ~,\ \0\ Tom, There is a couple reasons for the excess cement. The depth is calculated by a string, so if that hang~ up on any debris in the OOA, it may give us a false depth. Also since there is no way to circulate, your right, we rely on the hose to fill up the DCA. We just wanted to make sure we had enough cement to fill to surface. Brad Gathman Problem Well Supervisor 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, September 27,2004 9:44 AM To: NSK Problem Well Supv Subject: OOA Cement Top-offs MJ and Brad, I was looking at the packet recently sent on the 6 wells that had the OOAs topped-off. It appears that the pumped volumes varied anywhere from 1.3 to 2.2 times calculated. Was XS cement circulated to assure that the OOA was full?? That would seem prudent, since it may not have been possible to get the hose all the way down. Thanks in advance for your reply. Tom Maunder, PE AOGCC <-~~à- --...)0 \ ~~E d-c,-C)J \, ~ i- ~O,~Q- ;) ~- ~'-\. \ \ l 0 ~ß-O~ \ \. Y .~ \=- - o(ô d~d ~\=--O,\ \" ~ ?,\-\- 0 ~ ,~<{ 1 of! 10/1/2004 8:28 AM ., , ~ ConocöP'hillips Alaska --) ~ IV ~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 15, 2004 'o?J \~ C?J",. \ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 1 00 Anchorage, AK 99501 RECEIVED SEP 1 7 2004 Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the~~t1;pã~ and Tam fields. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor, or in some cases holes were cut in the conductor to facilitate fill-up. 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 top-fill operation was completed on September 14, 2004. Dowell-Schlumberger batch- mixed Arctic Set I cement to 15.8 ppg in a blender tub. The cement was placed in the conductor from the bottom-up via a hose ran to the bottom of the void. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volume used on each conductor. Note that in most cases thesewells<i}ave been previously reported as having surface casing leaks and have either been repaired by ~xc'avation and patching or injection of sealant material. Please call Marie McConnell or me at 907-659-7224, if you have any questions. Sincerely, Çh' jC~ Jerry Dethlefs ConocoPhillips Problem Well Supervisor ~CANNED NO'V 1 6 20D4 Attachment WELL NAME 2G-02 2N-341 38-06 3F-06 3F-09 3H-05 PTD# 1841210 1981030 1850760 1852440 1852700 1870770 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk and Tarn Fields September 14, 2004 SERVICE CEMENT TOP VOLUME REASON TYPE ft Bbls 1-/ Producer 82 14.5 SC leak @ 32' previously sealant repaired Producer 3 0.5 Wobbly tree Producer 8 2 Post Sc leak patch repair; Sundry 304-225 Producer 40 11.8 SC leak @ 64' previously sealant repaired Producer 17 3.9 SC leak @ 241 previously sealant repaired Producer 8 2 Post SC leak patch repair; Sundry 304-228 All cement pumped is Arctic Set I 15.8 PPG Cement This report is submitted in substitution for Sundry 10-404, Report of Sundry Operations NSK Problem Well Supervisor CJ. 5(;ANNED NOV 1 6 2004 r • • Al l KRU 2N -341 ConocoPhillips Alaska, Inc. 2N -341 API: 501032026300 Well Type: PROD Angle 0 TS: deg 0 SSSV Type: NIPPLE Orig 7/6/1998 Angle @ TD: 64 deg @ 12339 NIP (493 -494, Completion: 00:5.500) I Annular Fluid: DSL /SW 7.1/8.34 Last W /O: Rev Reason: TAG FILL TUBING ppg (0- 11544, Reference Log: Ref Log Date: Last Update: 7/22/2004 00:3.500, Last Tag: 12030 TD: 12339 ftKB ID:2.992) RODUCTION Last Tag Date: 7/11/2004 Max Hole Angle: 75 deg @ 2370 (0- 11527, Casing String - ALL OD: 5.500, ) Description Size Top Bottom TVD Wt Grade Thread W 1 SURFACE 16.000 0 108 108 62.58 H -40 WELDED SLEEVE PRODUCTION 7.625 0 4227 2301 29.70 L -80 BTC 01416- 11417, PRODUCTION 5.500 0 11527 4774 15.50 L -80 LTC 00:3.500) PRODUCTION 3.500 11527 12316 5183 9.30 L -80 EUE Tubing String - TUBING Size Top Bottom ND Wt Grade Thread 3.500 0 11544 4784 9.30 L -80 EUE Perforations Summary Interval ND Zone Status Ft SPF Date Type Comment 12025 - 12045 5048 - 5058 20 4 7/29/1998 IPERF 2.5" HC, BH, 180 PH, 90 ORIENT Gas Lift '. 12045 - 12065 5058 - 5068 20 4 7/28/1998 IPERF 2.5" HC, BH, 180 PH, 90 Mandrel/Valve I ORIENT 1 ;11466 - 11467, Gas Lift MandrelsNaives OD:4.725) St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 11466 4739 CAMCO KBG -2 -9 CAMCO OV 1.0 INT 0.250 0 8/23/1998 Other (plugs, equip., etc.) - JEWELRY Depth ND Type Description ID 493 493 NIP CAMCO 'DS' NIPPLE 2.875 NIP 11416 4710 SLEEVE BAKER CMU W /CAMCO'DS' PROFILE 2.813 01517- 11518, 11517 4768 NIP CAMCO NOGO'D' NIPPLE 2.750 00:3.500) 11527 4774 XO CROSSOVER 3.500 11544 4784 SEAL BAKER CASING SEAL ASSY 80 -40 2.985 12316 5183 COLLAR PBTD 0.000 x0 01527- 11528, 00:5.500) SEAL ;11544- 11545, OD:4.000) Ell 'RODUCTION 01527- 12316, OD:3.500, Perf ;12025- 12045) Perf — — ;12045- 12065) bCANNED NOV 1 6 2004 1 L Re: Tam Annular Injection- Phase 3 - - PTDs #98 -104, #98 -113 • Subject: Re: Tarn Annular Injection- Phase 3 - - P1Ds #98 -103 and #98 -113 Date: Tue, 21 Nov 2000 09:32:21 -1000 From: "Brian D Noel" <BNOEL @ppco.com> - To: tom_maunder @admin.state.ak.us k Forvarded by Brian D Noel /PPCO on 11/21/2000 09:32 AM To: Brian D Noel /PPCO @Phillips cc: Subject: Re: Tarn Annular Injection- Phase 3 - - PTDs #98 -103 and #98 -113 Brian, FYI. Tom Fonnarded by Tom J Brassfield /PPCO on 11/21/2000 09:56 AM Blair Wondzell <blair_wondzell@admin.state.ak.us> on 05/17/2000 10:04:16 AM To: Tom J Brassfield /AAI /ARCO@Arco cc: Randy L. Thomas /AAI /ARCO @Arco, Paul Mazzolini /AAI /ARCO @Arco, Sharon Allsup- Drake /AAI /ARCO @Arco, Nabors 19E Company Man /AAI /ARCO @Arco, aogcc north slope address < aogcc _prudhoe_bay @admin.state.ak.us> Subject: Re: Tarn Annular Injection- Phase 3 - - PTDs #98 -103 and #98 -113 APR 0 201' Tom, I've looked at the well files and reviewed the approved 10 -403s for annular disposal. The approvals are still valid provided: 1) they have not reached the 35,000 barrel limit unless a larger volume was approcved; or 2) unless the annuli of a specific well has been closed Tom, in the future where you have approval for annular disposal and there is remaining capacity, you could just send me an e-mail of intent to dispose, then give the well name, the PTD #, the 403 approval no., the disposal volume available, and approximately when you plan to start disposal. If you have additional questions, please contact me. Sincerely, Blair Wondzell, 5/17/00. Tom J Brassfield wrote: > Blair, as we discussed today we have several wells at the Tarn 2N Pad which were > approved for annular disposal in 98/99. Nabors 19E is moving to 2N 347 this > week and we have two specific wells which we are interested in using for annular > injection at this time: 2N 341 & 2N 345. Specifics are as follows: 11/21/00 9:42 AM Re: Tam Annular Injection- Phase 3 - - PTDs #98 -10. #98 -113 • > 2N 341- Annular injection Sundry 403 approved 7/17/98. Approval No. 398 -183. > Our records indicate that we have not used this well for annular injection in > the past. > 2N 345- Annular injection Sundry 403 approved 8/28/98. Approval No. 398 -217. > Our records indicate that we have not used this well for annular injection in > the past. > As we start Phase 3 drilling at Tarn, there are other annuli Mich have Sundry > approvals and injection volumes less than the 35,000 bbls. Are these existing > Sundry approvals still valid? > Thanks, Tom 9 of 9 11/21/00 9:42 AM ,\\~W)W~j \ - ,- - ---,V~l \....,.~...'l. '- I" ~: - -,,-~-. /. , , ~'" ?: . '--',: ':' /1 ,." ~ - - ' ,--. - -. ~ , / \~/ \. - -,,,) '. '. / ,,~~. j'- .........'...'. . ......J ( ~ ') . ... I . .. .. l . II ~) r; II .--.\ .' ~ / ~ ~ - - / "'J /. ~ - ,/ '\' / . , MICROFILMED 7/30/02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Saved as M:/weepie/microfilm_marker.doc 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 October 13, 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, Third Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the third quarter of 2000, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 2000. /??-/~ / Annular Injection durin$ the third quarter of 2000: h(1)' h(~) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD 1-45 5036 100 0 5136 365 5501 ? CD1-03 33505 100 0 33605 385 33990 ~ 1D-14 33916 100 0 34016 1487.5 35503.6 ~ CD1-25 24860 100 0 24960 8627. 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 34.0 CD1-43 285 100 0 385 0 385 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) Total for 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 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 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kupamk Area Annular Injection, Third Quarter, 2000 :. Dear Ms. Mahan: Please find reposed below the volumes injected into surface casing b~~uction ~ing annuli during the third queer of 2000, as well as total volumes injected into annuli for whch injection authorization expired during the t~rd queer of 2000. Annular Injection during the third quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 CD1-03 33505 100 0 33605 385 33990- 1D-14 33916 100 0 34016 1487.5 35503.6 CD1-25 24860 100 0 24960 8627 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 Zoo- ~) 8 Ms. Wendy Mahan AOGCC Third Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the third quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD1-39 31408 100 0 31508 Open, Freeze Protected 1D-12 32791 100 0 32891 Open, Freeze Protected CD1-37 32487 100 0 32587 Open, Freeze Protected CD1-23 33886 100 0 33986 Open, Freeze Protected CD1-01 5121 100 0 5221 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Marty 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 W e ll'Compliance Report File on Left side of folder 198-103-0 MD 12339 TVD 05193 Microfilm Roll / - KUPARUK RIV U TARN 2N-341 50- 103-20263-00 PHILLIPS ALASKAINC Completion Date: /--~7~98 Completed Status: 1-OIL Current: Roll 2 / -- Name D 8722 L DGR/CNP/SLD-MD L DGR/CNP/SLDP-TVD L DGR/EWR4-MD L DGR/EWR4-TVD Daily Well Ops Was the well cored? yes(~_ Comments: Interval ~ SPERRY MPT/GR/EWR4/CNP/SLD OH Z.F~' 4240-12339 ~/2~/~,/~f ~/////~' OH /~t~AL 4240-12339 OH ~hX~AL 2305-5194 OH Sent Received T/C/D 9/30/98 9/30/98 9/30/98 9/30/98 9/30/98 9/30/98 9/30/98 9/30/98 9/30/98 9/30/98 Dry Ditch Samples Required? yes ~..~_~:nd~ Are Analysis Description Rece. lamd2.__ges~-n~, Sam~l~S"gl'g''~: Tuesday, August 01, 2000 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' THRU' Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor FROM: John Crisp?,~,/t,~ C,, SUBJECT: Petroleum Irfspector DATE' July 20,200© 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 Bamdt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tarn, Kuparuk River, 2N Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2N-307 1990170 2N-308 1990100 94 70 65 P P OIL 2N-309 1990210 2N-313 19809101 94 70 70 P P OIL 2N-315 1981900 2N-317 1981430 94 70 70 P P OIL 2N-319 1981970 2N-320 1990010 94 70 65 P P OIL 2N-321A 1981730 2N-323 1980710 94 70 70 P P OIL 2N-325 1981630 2N-329 1980670 94 70 70 P P OIL 2N-331 1981170 2N-335' 1982040 94 70 70 P P OIL 2N-337A 1981220 2N-339 1981000 · i~N'3'41 ' 1981030 94 70 65 P P OIL 2N-343 1980920 2N-345 1981130 2N-347 2000630i 94 70 60 P P OIL Wells: 9 Components: 18 Failures: 0 Failure Rate: 0.0% [] 9o var Remarks: 7/9_7/00 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 Bamdt 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~ Test Test Test Oil, WAG, G~J, Number Number PSI PSI Trip Code Code Code G~SorCVC[~ 2L-305 1982400 94 70 60 P 4 OIL 2L-307 1982560' 94 70 70 P P 2L-313 1982190 94 70 65 P P OIL 2L-315 1982180 94 70 70 P P O~ :2L-321 1982620 2L-323 1982510 2L-325 1982090 94 70 65 P P 2L-329A 1982250 800 700 700 P P GAS Wells: 6 Components: 12 Failures: 1 Failure Rate: 8.0% [~90 my Remarks: 7/27/00 Page 1 of 1 SVS Tam KRU 2L 7-20-00jC.xls ARCO Alaska, Inc. .. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 19, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-341 (Permit No. 98-103/398-183) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on Tam 2N-341. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tarn Drilling Team Leader 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 [] SUSPENDED [~] ABANDONED~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-103/398-183 3 Address 8 APl Number P.O. Box 100360, Anchora~le, AK 99510-0360 50-103-20263 4 Location of well at surface ~ 9 Unit or Lease Name 130' FNL, 1055' FEL, Sec. 3, T9N, R7E, UM .I ~,~!'~ Kuparuk River Unit At Top Produdng Interval ' ~~ 10 Well Number 1277' FNL, 224' FEL, Sec. 5, T9N, R7E, UM '.~,~ _ ~ ~" ;: ' .~ 2N-341 At Total Depth .~ ~,~ ~ ~. ~..~..~ 11 Field and Pool 1314' FNL, 893' FEL, Sec. 5, T9N, R7E, UM Kuparuk River Field 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Sedal No. Tam Oil Pool RKB 28', Pad 121' ADL 375075 ALK 4306 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions I 22-Jun-98 03-Jul-98 06-Jul-98 NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 12339' MD & 5193' TVD 12220' MD & 5155' TVD YES X~ NO U NA feet MD 1050 APPROX 22 Type Electdc or Other Logs Run GR/Res, GR/CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE V~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 62.58# H-40 SURF. 108' 24' 275 sx High Early 7.625' 29.7# L-80 SURF. 4227' 9.875' 532 sx ASIII LW, 240 sx Class G, 60 sx ASl 5.5' x 15.5~ L-80 SURF. 11527' 6.75' 240 sx Class G 3.5' 9.3# L-80 11527' 12318' 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' 11544' 11527' (CSR) 12025'-12065' MD 5048'-5068' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC . ~. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12025'-12065' MD pumped 120,283# proppant in formation, left 27,684~ proppant in pipe. 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBI CHOKE SIZE I GAS-OIL RATIO 8/~4/9~ 8.00 TEST PERIOI: 1890 687 O 176 I 364 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBI OIL GRAVITY-APl (corr) Press. 397 0 24-HOUR RATE: 5669 2062 0 39° 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/~EVEESE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GaR, and time of each phase. Top Reservoir Ct3) 11741' 4898' Base Reservoir (T2) 12112' 5091' Annulus left open - freeze protected with diesel. 31. LIST OF AI:TACHMENTS Summa~ of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knawledge. Signed ~~_ ~/~~ Title 'Drilling Team Leader DATE I (J ~ 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: 7/30/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-341 WELL_ID: AK9469 TYPE: AFC: AK9469 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:06/22/98 START COMP: RIG:RIG ~ 141 WI: 0% SECURITY:0 API NUMBER: 50-103-20263-00 BLOCK: FINAL:07/06/98 06/22/98 (D1) TD: 1316' (1316) SUPV:RWS 06/23/98 (D2) TD: 3164' (1848) SUPV: 06/24/98 (D3) TD: 4240' (1076) SUPV:DB 06/25/98 (D4) TD: 4240'( SUPV:DB 0) 06/26/98 (DS) TD: 4240'( SUPV:DB 0) 06/27/98 (D6) TD: 5688' (1448) SUPV:DB 06/28/98 (D7) TD: 6004'(316) SUPV:DB MW: 9.5 VISC: 95 PV/YP: 30/29 Drilling @ 1756' APIWL: 5.6 Function test diverter system. Rig accepted @ 0300 hrs. 6/22/98. Drill out conductor from 76' to 108' Drill from 108' to 1316' MW: 9.8 VISC: 58 PV/YP: 21/20 Drilling 9-7/8" hole from 3750' APIWL: 5.2 Drill from 1316' to 3164' MW: 10.4 VISC: 47 PV/YP: 22/20 Running 7-5/8" casing APIWL: 4.6 Drill 9-7/8" hole from 3164' to 4240'. Gas breaking out, slight flow. Raise mud weight to 10.4 ppg. MW: 10.1 VISC: 48 PV/YP: 21/15 Testing BOPE APIWL: 6.6 Run 7-5/8" casing to 4227' Pump cement. MW: 8.5 VISC: 42 PV/YP: 11/11 Perform LOT APIWL: 12.0 NU BOPE and test to 300/3500 psi. Drill out cement and stage collar washed to 1616'. Clean out cement to 4080' MW: 8.8 VISC: 42 PV/YP: 12/10 Preparing to POH APIWL: 8.2 Drill out cement, insert baffle and float equipment. Drill 20' of new hole to 4260' Perform FIT, 16.0 ppg. Drill 6-3/4" hole from 4260' to 4966'. Had increase in background gas @ 4920'. Unable to survey, attributed to gas in mud. Drill from 4966' to 5688' No further MWD problems. MW: 9.5 VISC: 40 PV/YP: 12/13 Circulate mud APIWL: 6.4 Drill 6.75" hole from 5688' to 6004'. Attempted to drill, 06/29/98 (D8) TD: 6534' (530) SUPV:DB 06/30/98 (D9) TD: 8320'(1786) SUPV:DB 07/01/98 (D10) TD:10196'(1876) SUPV:DB 07/02/98 (Dll) TD:11603'(1407) SUPV:DB 07/03/98 (D12) TD:12339'(736) SUPV:DB 07/04/98 (D13) TD:12339'( 0) SUPV:DB 07/05/98 (D14) TD:12339'( 0) SUPV:DB 07/06/98 (D15) TD:12339'( 0) SUPV:DPB unable to make hole. POH. Inspect bit and motor and changed out failed motor. Well flowing. Shut in well. Weight up to 10.7 ppg. Lubricated 10.7 mud into well, well stable. MW: 9.5 VISC: 43 PV/YP: 14/13 Drill ahead from 7150' APIWL: 6.4 Circulate 9.5 ppg mud around from 4197' Well static. Circulate mud until weight in and out 9.6 ppg. No problems. Drill 6.75" hole from 6004' to 6532' MW: 9.5 VISC: 51 PV/YP: 19/22 Drill 6.75" hole from 8770' APIWL: 5.2 Drill 6.75" hole from 6532' to 8100' Circ low/high vis sweeps around. Perform LOT, 15.8 ppg EMW. Drill from 8100' to 8320' MW: 9.5 VISC: 49 PV/YP: 14/19 Drill from 10420' APIWL: 5.8 Drill from 8320' to 10196' Max gas observed. MW: 10o0 VISC: 51 PV/YP: 13/21 Drill 6.75" hole from 12,000' APIWL: 4.7 PJSM. Wiped hole to 7990', max 20k over, no problems. Drill from 10196' to 11603' MW: 10.0 VISC: 49 PV/YP: 13/21 Laying down 4" drill pipe. APIWL: 4.2 Drill from 11603' to 12339' TD. Control drill 100 fph thru production zone. PJSM. MW: 10.0 VISC: 50 PV/YP: 13/23 Run production casing from 6200' APIWL: 3.8 PJSM. Repair pipe handling system. Continue to lay down 4" drill pipe. MW: 10.0 VISC: 45 PV/YP: 11/10 APIWL: 4.8 PU 3.5" tubing, RIH with completion string from 6100' PJSM. Ran 5.5" X 3.5" prod casing to 12318' MW: 8.6 VISC: Released rig @ 2000 hrs. 0 PV/YP: 0/ 0 APIWL: 0.0 RIH with completion assembly. Freeze protect well. ND BOPE, install master valve and test to 5000 psi, OK. Released rig @ 2000 hrs. 7/6/98. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '' K1(2N-341(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-341 PERFORATE, PERF SUPPORT 0720981820.4 DATE DALLY WORK UNIT NUMBER 07/28/98 GR/CCL LOG & PERFORATE 8305 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 4 NOI YES SWS-ELMORE JONES FIELD AFC# CC# Signed ESTIMATE K85110 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 60 PSI 160 PSI 0 PSI 160 PSII 280 PSII 280 PSI DAILY SUMMARY ISWS RAN GR/CCL LOG FROM 11,330' TO 12,190'. PERFED FROM 12,045' TO 12,065' W/2.5" HC, BH, 4SPF, 180 DEG PHASED, 90 DEG ORIENT. HAD TO PUMP GUNS DOWN @ 2.5 BPM, 1100 PSI WHP FROM 1500'.[Perf] TIME LOG ENTRY 11:45 SWS & LRS MIRU, HELD TGSM. LRS PUMPED 22 BBLS HOT DIESEL DOWN TBG W/FULL RETURNS SW FROM INNER ANNULAS. MU TOOLS & PT LUB TO 3000#. 13:00 MIH W/GR/CCL, 2.6" ROLLER, WB. RAN GR/CCL LOG FROM 12,190' TO 11,330' & CORR TO SPERRY SUN DGR/EWR4/ROP LOG 7-4-98. 14:15 POH & LD TOOLS. 15:30 MU GUN & PT LUB TO 3000#. PRESSURE TEST LINER & INNER ANNULAS TO 2500 PSI FOR 15 MIN, GOOD. 16:30 MIH W/20' - 2.5" HC, BH, 4 SPF, 180 DEG PHASED, 90 DEG ORIENT, MPD, SAFE, CCL. LRS PUMPED @ 2.5 BPM / 1100 PSI WHP FROM 1500'. VERY DIFFICULT TO GET GUN DOWN. CORR TO SWS GR/CCL LOG 7-28-98 & PERF FROM 12,045' TO 12,065'. 19:45 POH & LD GUN, ALL SHOTS FIRED. 21:00 RIG DOWN SWS & LRS. 21:30 RELEASED SWS & LRS. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '' K1(2N-341(W4-6)) WELL JOB SCOPE JOB NUMBER " 2N-341 PERFORATE, PERF SUPPORT 0720981820.4 DATE DAILY WORK UNIT NUMBER 07/29/98 FINISH PERFORATIONS 8305 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 5 YES YES SWS-ELMORE JONES FIELD AFC# CC# Signed ESTIMATE K85110 180KN U2TN InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann , Initial Outer Ann I Final Outer Ann 500 PSI 470 PSI 400 PSI 400 PSII 1280 PSI 260 PSI DAILY SUMMARY ISWS CORR TO SWS GR/CCL LOG 7-28-98 & PERFED FROM 12,025' TO 12,045' W/2.5" HC, BH, 4 SPF, 180 DEG PHASED, 90 DEG ORIENT. HAD TO PUMP GUN DOWN @ 2.5 BPM, 1000 PSI WHP. TAGGED DOWN @ 12,057', POSSIBLY SAND.[Perf] TIME 07:45 08:45 11:45 12:15 14:45 16:30 17:30 LOG ENTRY SWS MIRU, HELD TGSM, CHECK TOOLS. WAIT ON PUMPER & DIESEL TRANSPORT. MU GUN, LRS MIRU & PT LUB TO 3000#. MIH W/20' - 2.5" HC, BH, 4 SPF, 180 DEG PHASED, 90 DEG ORIENT, MPD, SAFE, CCL. PUMP DOWN GUN W/ DIESEL @ 2.5 BPM 1000 PSI WHP. CORR TO SWS GR/CCL LOG 7-28-98 & PERF FROM 12,025' TO 12,045' USING 1200 PSI WHP. TAGGING DOWN @ 12,057', POSSIBLY SAND. POH, GUN STUCK @ "D" NIPPLE, WORKED FREE & LD GUN, ALL SHOTS FIRED. RIG DOWN SWS & LRS, SPOT EQUIPMENT AT 2N-337. RELEASED SWS & LRS. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~' K1(2N-341(W4-6)) WELL JOB SCOPE JOB NU~IBER " 2N-341 FRAC, FRAC SUPPORT 0720981827.7 DATE DAILY WORK UNIT NUMBER 08/01/98 TARN SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I YESI YES DS-GALLEGOS JORDAN FI ELD AFC# CC# Signed ESTIMATE K85110 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann 490 PSI 0 PSI 500 PSI 500 PSI 270 PSI 330 PSI DAILY SUMMARY I T ARN SAND FRAC PRESSURED OUT EARLY WITH 8.1 PPA AT PERFS. PLACED 120,283 LBS PROPPANT IN FORMATION, LEFT 27,684 LBS PROPPANT IN PIPE. MAX TREATING PRESSURE 6744 PSl.[Frac-Refrac] TIME 07:00 09:29 09:36 10:50 14:10 16:36 19:00 LOG ENTRY MIRU DS FRAC UNIT - GALLEGOS; LRS; APC. TGSM, 17 ON LOCATION. PT LINES 9252 PSI OK. PUMP HIGH RATE BD. MAX PRESS 8025 PSI AT 21 BPM. SHUTDOWN ISIP 1193 PSI. PUMP DATA FRAC. PUMP BD AND SCOUR STAGE. ADJUST FRAC PAD SIZE. PUMP FRAC THROUGH STAGE 5 RAMP. TARN SAND FRAC PRESSURED OUT EARLY WITH 8.1 PPA AT PERFS. SD FRAC. PLACED 120,283 LBS PROPPANT IN FORMATION, LEFT 27,684 LBS PROPPANT IN PIPE. MAX TREATING PRESSURE 6744 PSI. RDMO DS FRAC UNIT. r -, SURVEY CALCULATION AND FIELD WORKSHEET ~ Job No. 0450-98669 Sidetrack No. . ........... Page 1 of 6 I-'LJ_r~-'I=(,--'-~ Company ARCO ALASKA, !_N__C_; .......... Rig Contractor & No. Doyon Drilling Co.- #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2N/341 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ ~r~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -129.46 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. EAN -1055.41 Magn. Declination 26.880 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10Oft[~ 30mr~ lOm~ Vert. Sec. Azim. 263.75 Magn. to Map Corr. 26.880 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 (+) Right (+) Comment Type (ET) (DD) (DD) __ (F-T) (FT) (FT) (FT) (Per 100 F'r) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT , , 22-JUN-98 MWD 108.00 0.00 0.00 108.00 108.00 0.00 0.00 0.00 0.00 0.00 8" M1C 1.4 DEG AKO .... .__- -- 22-J U N-98 MWD 158.56 0.68 284.15 50.56 158.56 0.28 0.07 -0.29 1.34 1.34 22-JUN-98 MWD 247.56 0.27 275.96 89.00 247.56 0.98 0.22 -1,01 0.47 -0.46 -- 22-JUN-98 MWD 340.56 1.58 173.84 93.00 340.54 1.20 -1.03 -1.09 1.78 1.41 -- 22-JUN-98 MWD 425.87 4.23 195.39 85.31 425.74 2,36 -5.23 -1.80 3.31 3.11 -- 22-JU N-98 MWD 517.62 7.29 210.35 91.75 517.02 7.08 -13.52 -5.64 3.69 3.34 16.31 22-JUN-98 MWD 608.36 10,82 206.64 90.74 606,62 15.14 -26.10 -12,37 3.94 3.89 -4.09 22-JU N-98 MWD 699.58 15.12 207.72 91.22 695.49 26.44 -44.30 -21.75 4.72 4.71 1.18 22-JUN-98 MWD 790.04 20.27 209.49 90.46 781.64 42.20 -68.40 -34.96 5.72 5.69 1.96 22-J U N-98 MWD 879.95 23.13 210.35 89.91 865.17 61.83 -97.20 -51.55 3.20 3.18 0.96 22-J U N-98 MWD 968.49 27.50 215.95 88.54 945.20 85.94 -128.77 -72.35 5.62 4.94 6.32 22-J U N-98 MWD 1059.81 30.64 224.51 91.32 1025.04 118.15 -162.46 -101.06 5.70 3.44 9.37 -- -- 22-J U N-98 MWD 1149.69 33.86 232.42 89.88 1101.08 157.30 -194.09 -136.99 5.90 3.58 8.80 22-J U N-98 MWD 1239.42 38.23 241.26 89.73 1173.66 204.36 -222.71 -181.19 7.56 4.87 9.85 -- 23-J U N-98 MWD 1335.24 40.39 246.40 95.82 1247.82 261.41 -249.41 -235.66 4.08 2.25 5.36 23-JU N-98 MWD 1429.24 43.77 251.75 94.00 1317.60 322.32 -271.80 -294.48 5.24 3.60 5.69 23-J U N-98 MWD 1523.95 47.93 254.87 94.71 1383.56 389.13 -291.24 -359.56 4.99 4.39 3.29 23-J U N-98 MWD 1616.71 52.17 260.06 92.76 1443.13 459.77 -306.57 -428.94 6.27 4.57 5.60 23-JU N-98 MWD 1711.04 57.14 263.83 94.33 1497.70 536.63 -317.26 -505.09 6.19 5.27 4.00 23-JU N-98 MWD 1804.53 62.47 263.71 93.49 1544.70 617.40 -326.03 -585.39 5.70 5.70 -0.13 23-J U N-98 MWD 1899.12 67.03 263.28 94.59 1585.04 702.93 -335.73 -670.37 4.84 4.82 -0.45 23-J U N-98 MWD 1993.22 71.39 263.85 94.10 1618.43 790.88 -345.58 -757.76 4.67 4.63 0.61 23-JUN-98 MWD 2086.88 70.99 263.51 93.66 1648.63 879.54 -355.34 -845.88 0.55 -0.43 -0.36 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-98669 Sidetrack No. _ .......... Page ..... 2_.._ of I:t=r~:l~-~ Company A_R_~C~O_0__A___L~S_KA_! IN__C__. .......................................... Rig Contractor & No. Doyon Drilling Co.- #141__ Field TARN DEVELOPMENT FIELD I Well Name & No. TARN DRILLSITE 2N/341 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ ~J~r~/~ WELL DATA _ . Target-I-VD (FT) Target Coord. N/S Slot Coord. N/S -129.46 Grid Correction 0.000 Depths Measured From: RKB ~ MSL D SS~ Target Description Target Coord. E/W Slot Coord. E/W -1055.41 Magn. Declination 26.880 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10mJ~ Vert. Sec. Azim. 263.75 Magn. to Map Corr. 26.880 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 (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 400 FT) Drop (-) Left (-) ___ 23-J U N-98 MWD 2181.88 70.46 263.46 95.00 1679.99 969.21 -365.51 -934.98 0.56 -0.56 -0.05 23-J U N-98 MWD 2276.97 74.50 263.84 95.09 1708.61 1059.87 -375.54 -1025.08 4.27 4.25 0.40 -- -- 23-J U N-98 MWD 2369.66 74.55 263,49 92.69 1733.34 1149.20 -385.39 -1113.87 0.37 0.05 -0.38 -- -- 23-J U N-98 MWD 2463.95 73.80 263.77 94.29 1759.06 1239.92 -395.46 -1204.02 0,85 -0.80 0.30 23-JUN-98 MWD 2556.27 73.53 263.30 92.32 1785.02 1328.51 -405.43 -1292.05 0.57 -0.29 -0.51 _._ _~3-JUN-98 MWD 2650.19 72.90 262.82 93.92 1812.14 1418.42 -416.30 -1381.31 0.83 -0.67 -0.51 --. 23-J U N-98 MWD 2745.37 72,32 263.41 95.18 1840.59 1509.24 -427.19 -1471.48 0.85 -0.61 0.62 ,,, 23-J U N-98 MWD 2835.84 72.05 263.40 90.47 1868.27 1595.38 -437.08 -1557.05 0.30 -0.30 -0.01 ..................... 23-J UN-98 MWD 2930.08 70.83 263.93 94.24 1898.27 1684.71 -446.94 -1645.84 1.40 -1.29 0.56 23-JU N-98 MWD 3025.02 70.76 264.32 94.94 1929.50 1774.37 -456.12 -1735.02 0.39 -0.07 0.41 23-J U N-98 MWD 3117.34 70.22 264,33 92.32 1960.33 1861.38 -464.72 -1821.61 0.59 -0.58 0.01 -- __ 24-J U N-98 MWD 3213.56 71.39 263.99 96.22 1991.96 1952.25 -473.97 -1912.01 1.26 1.22 -0.35 ., 24-J U N-98 MWD 3308.32 73.38 263.34 94.76 2020.64 2042.56 -483.94 -2001.77 2.20 2.10 -0.69 · __ 24-J U N-98 MWD 3402.71 73.11 263.52 94.39 2047.85 2132.94 -494.28 -2091.56 0,34 -0.29 0.19 _~4-J U N-98 MWD 3497.47 72.81 263.38 94.76 2075.62 2223.54 -504.61 -2181.57 0.35 -0.32 -0.15 ._ 24-JUN-98 MWD 3591.45 72.69 264.50 93.98 2103.49 2313.29 -514.09 -2270.82 1.15 -0.1'3 1.19 24-J U N-98 MWD 3687.12 72.36 263,63 95.67 2132.22 2404.54 -523.52 -2361.58 0.93 -0.34 -0.91 24-JUN-98 MWD 3780.86 72.05 262.96 93.74 2160.86 2493.79 -533.94 -2450.23 0.76 -0.33 -0.71 24-J U N-98 MWD 3874.00 72,38 264.20 93.14 2189.31 2582.48 -543.86 -2538.36 1.32 0.35 1.33 24-J U N-98 MWD 3969.56 72.52 264.82 95.56 2218.13 2673.58 -552.57 -2629.05 0.64 0,15 0.65 24-JUN-98 MWD 4065.18 71.23 266.84 95,62 2247.88 2764.39 -559.19 -2719.68 2.42 -1.35 2.11 24-JUN-98 MWD 4159,54 70.74 266.44 94.36 2278.62 2853.49 -564.42 -2808.74 0.66 -0.52 -0.42 24-JUN-98 MWD 4194.56 70.51 266.86 35.02 2290.24 2886.48 -566.35 -2841.72 1.31 -0.66 1.20 24-JUN-98 MWD 4286.42 70.42 268.34 91.86 2320.96 2972.86 -569.97 -2928.21 1.52 -0.10 1.61 4 3/4" M1XL 1.2 DEG AKO r " SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-98669 Sidetrack No. Page 3 of 6 ~ Company _A_R__C_..O__A__L~_S~K~_,. !.N__C_._ ............................ Rig Contractor & No. Doyon Drilling Co.- #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2N/341 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ WELL DATA Target TVD (F0 Target Coord. N/S Slot Coord. N/S -129.46 Grid Correction 0.000 Depths Measured From: RKB ~] MSL[~ SS~ Target Description Target Coord. E/VV Slot Coord. E/W -1055.41 Magn. Declination 26.880 Calculation Method MINIMUM CURVATURE -- Target Direction (DD) Build\Walk\DL per: 10Oft[~ 30mE~ 10m~ Vert. Sec. Azim. 263.75 Magn. to Map Corr. 26.880 Map North to: OTHER SURVEY DATA Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I-VD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FO (DD) (DD) (FO (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) ___ 27-JU N-98 MWD 4392,47 71.62 266.75 106.05 2355.45 3072.92 -574.27 -3028.40 1,81 1,13 -1.50 27-J U N-98 MWD 4477.49 72.22 267,55 85.02 2381.84 3153.59 -578.29 -3109.12 1.14 0,71 0.94 27-J U N-98 MWD 4570.27 72.14 266.67 92.78 2410.23 3241.77 -582.74 -3197.33 0,91 -0.09 -0.95 27-J U N-98 MWD 4670.60 70.54 265.31 100.33 2442.33 3336.75 -589.39 -3292.15 2.05 -1.59 -1.36 27-J UN-98 MWD 4765.36 71.80 265.93 94.76 2472.92 3426.39 -596.23 -3381,57 1.47 1.33 0.65 27-JUN-98 MWD 4858.82 72.37 266.70 93.46 2501.67 3515.22 -601.95 -3470.32 0.99 0,61 0.82 27-JUN-98 MWD 4953.94 73.39 265.35 95,12 2529.67 3606.05 -608.25 -3561.00 1.73 1.07 -1.42 27-J U N-98 MWD 5047.35 70.38 264.33 93.41 2558.71 3694.81 -616.23 -3649.41 3.39 -3.22 -1.09 - 27-JUN-98 MWD 5140.85 70.70 262.91 93.50 2589,86 3782.96 -626.03 -3737.02 1.47 0.34 -1.52 27-J U N-98 MWD 5234.61 71.62 263.52 93.76 2620.14 3871.69 -636.51 -3825.13 1.1 6 0.98 0.65 27-J U N-98 MWD 5330.18 72.65 264.19 95.57 2649.46 3962.65 -646.24 -3915.57 1.27 1.08 0.70 27-JUN-98 MWD 5425.25 71.73 264.51 95.07 2678.53 4053.16 -655.16 -4005.64 1.02 -0.97 0.34 __ -- 27-JUN-98 MWD 5520.22 70.34 265.50 94.97 2709.40 4142.95 -662.98 -4095.11 1.76 -1.46 1.04 27-J U N-98 MWD 5615.20 71.48 262.94 94.98 2740.46 4232.69 -672.02 -4184.40 2.82 1.20 -2.70 ,';' 28-JUN-98 MWD 5702.48 72.35 263.43 87.28 2767.56 4315.66 -681.87 -4266.78 1.13 1.00 0.56 __ -- 28-J U N-98 MWD 5793.73 71.75 264.82 91.25 2795.68 4402.46 -690.75 -4353.13 1.59 -0,66 1.52 28-JUN-98 MWD 5888.34 68,31 265.99 94.61 2827.99 4491.33 -697.89 -4441.75 3.82 -3.64 1.24 29-JUN-98 MWD 5986.95 68.61 264.26 98.61 2864.20 4583.02 -705.68 -4533.14 1.66 0.30 -1.75 29-J U N-98 MWD 6080.67 68.69 264,04 93.72 2898.32 4670.31 -714.58 -4619.97 0.23 0.09 -0,23 29-JUN-98 MWD 6174.87 68.67 264.87 94.20 2932.57 4758.05 -723.06 -4707.31 0.82 -0,02 0.88 29-J U N-98 MWD 6269.31 68.83 264.99 94.44 2966.80 4846.05 -730,84 -4794,99 0,21 0,17 0.13 29-JUN-98 MWD 6363.22 69.42 264.60 93.91 3000.26 4933.78 -738.80 -4882.37 0.74 0.63 -0.42 30-JUN-98 MWD 6457.88 70.51 265.42 94.66 3032.69 5022,69 -746.53 -4970.96 1.41 1.15 0.87 30-J U N-98 MWD 6546,04 71.02 265.51 88.16 3061,73 5105.89 -753.11 -5053.94 0.59 0,58 0.10 i SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0_4_5_~0£9_~8~6~9 Sidetrack No.. ......... Page ._ 4. .... of .6. II ~ [11~-' I :~Llr Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2N/341 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ e~ · ~,a~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -129,46 Grid Correction 0.000 Depths Measured From: RKB ~ MSL L~ SS~- Target Description Target Coord. EAN Slot Coord. E/VV -1055,41 Magn. Declination 26.880 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mE-] 10mu Vert, Sec, Azim, 263,75 Magn. to Map Corr, 26.880 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 (+) Right (+) Comment Type (FT) (DD) (DD) (F'l') (FT) (FT) (FT) (Per m0 F'r) Drop (-) Left (-) 30-J U N-98 MWD 6640.52 71.78 266.51 94.48 3091.87 5195.37 -759.34 -5143.27 1.29 0.80 1.06 i' -- 30-J U N-98 MWD 6734.12 72,48 265.30 93.60 3120,59 5284,39 -765.70 -5232,12 1,44 0,75 -1,29 --_ 30-JUN-98 MWD 6832,81 72.06 263,37 98,69 3150.65 5378.38 -774.98 -5325,66 1,91 -0,43 -1,96 30-JU N-98 MWD 6924.65 70,68 266,01 91.84 3179,99 5465,38 -783,04 -5412,30 3,11 -1,50 2.87 30-J U N-98 MWD 7016,10 70.48 266.08 91,45 3210,40 5551,56 -788.99 -5498.34 0,23 -0,22 0.08 ___ 30-J U N-98 MWD 7109,38 71,12 265,88 93,28 3241.07 5639,58 -795,17 -5586,22 0.72 0,69 -0,21 30-JUN-98 MWD 7205.45 71,88 265,83 96,07 3271.56 5730,63 -801.75 -5677,09 0,79 0,79 -0,05 30-J U N-98 MWD 7293,46 71.74 266,91 88,01 3299,03 5814,15 -807,05 -5760,53 1,18 -0,16 1,23 30-JU N-98 MWD 7387,03 69,90 266,16 93,57 3329.77 5902,42 -812.38 -5848,74 2,11 -1,97 -0,80 30-J U N-98 MWD 7487,09 69.10 265,61 100.06 3364,81 5996,07 -819,11 -5942,22 0,95 -0,80 -0,55 30-JUN-98 MWD 7579,52 69,67 263,67 92,43 3397,36 6082,57 -827.19 -6028.35 2.06 0,62 -2,10 30-J U N-98 MWD 7676,91 70,62 265,70 97,39 3430,44 6174,15 -835,67 -6119,55 2,19 0,98 2,08 30-JUN-98 MWD 7770,34 71.45 264,43 93.43 3460,80 6262,48 -843.28 -6207,57 1,56 0,89 -1,36 30-JUN-98 MWD 7865.05 70.85 265.78 94.71 3491.40 6352.09 -850.93 -6296.87 1.49 -0.63 1.43 30-JU N-98 MWD 7959.98 69,36 266.79 94.93 3523.71 6441.26 -856.71 -6385.95 1.86 -1.57 1.06 30-J U N-98 MWD 8055.18 69.45 267.03 95.20 3557.20 6530.24 -861.52 -6474.93 0.25 0.09 0.25 30-J U N-98 MWD 8150.03 70,28 267.66 94.85 3589.85 6619.12 -865.64 -6563.89 1.07 0.88 0.66 30-JUN-98 MWD 8245.46 71.45 268.04 95.43 3621,13 6709.04 -869.02 -6653.98 1.28 1,23 0.40 30-J U N-98 MWD 8335.46 71.33 266.38 90.00 3649.85 6794.18 -873.17 -6739.17 1.75 -0.13 -1,84 30-JUN-98 MWD 8427.78 71.69 266,83 92.32 3679.13 6881.62 -878.36 -6826.57 0.60 0.39 0.49 30-J U N-98 MWD 8520.17 71,66 265.16 92.39 3708.18 6969.25 -884.48 -6914.06 1.72 -0.03 -1,81 30-JUN-98 MWD 8610.76 71.97 266,58 90,59 3736.45 7055.26 -890.68 -6999.90 1.53 0.34 1.57 30-JUN-98 MWD 8705.69 72.18 265.37 94.93 3765.67 7145.51 -897.02 -7089.99 1.23 0,22 -1,27 01 -JUL-98 MWD 8797.55 71,92 264.82 91.86 3793,98 7232,87 -904.49 -7177.06 0.64 -0.28 -0.60 r SURVEY CALCULATION AND FIELD WORKSHEET No. 0450-98669 Sidetrack No.Page6 of 6 I-'[I[~-'l::~'-~ Company _A_.R_C_O__A__.L~,_S_._K/~_,!_N_? .................................................. Rig Contractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD I/ Well Name & No. TARN DRILLSlTE 2N/341 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ J~~--~ ~ WELL DATA Target TVD (F0 Target Coord. N/S Slot Coord. N/S -129.46 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~] SSI- Target Description Target Coord. E/W Slot Coord. E/W -1055.41 Magn. Declination 26.880 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10Oft~ 30mE] 10m[~ Vert. Sec. Azim. 263.75 Magn. to Map Corr. 26.880 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length -I-VD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (ET) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 F'I-) Drop (-) Left (-) 02-JUL-98 MWD 11153.69 63.86 264.04 94.46 4579.76 9450.05 -1067.46 -9389.65 2.20 -1.79 -1.42 . .... 02-JUL-98 MWD 11247.98 61,91 263,99 94,29 4622,73 9533.97 -1076,21 -9473.11 2.07 °2,07 -0,05 !.i 02-JUL-98 MWD 11340.56 58.53 263.45 92,58 4668,70 9614,31 -1084,99 -9552,97 3,69 -3,65 -0,58 03-JUL-98 MWD 11427,68 55.27 264.47 87,12 4716.28 9687.28 -1092,68 -9625,54 3,87 -3,74 1,17 03-JUL-98 MWD 11527,87 53.79 264.26 100,19 4774,41 9768.87 -1100,69 -9706,74 1.49 -1,48 -0,21 __ -- 03-JUL-98 MWD 11615,48 54,24 263.21 87.61 4825.89 9839.76 -1108,43 -9777,20 1,10 0,51 -1,20 -- 03-JUL-98 MWD 11709,67 54,80 259,78 94,19 4880,57 9916,38 -1119.78 -9853,04 3,02 0,59 -3,64 ---- -- 03-JUL-98 MWD 11803,88 56,77 264,08 94.21 4933.56 9994.22 -1130,68 -9930,14 4,31 2,09 4,56 03-JUL-98 MWD 11906,29 58,54 263,90 102,41 4988,35 10080,73 -1139,74 -10016,18 1,73 1,73 -0,18 .... 03-JUL-98 MWD 11992,46 59,84 263,70 86,17 5032,48 10154.74 -1147,73 -10089,76 1,52 1,51 -0,23 -- 03-JUL-98 MWD 12083,82 61,30 265.51 91,36 5077.38 10234,29 -1155,20 -10168,97 2,35 1,60 1,98 03-JUL-98 MWD 12176,71 62,70 264.93 92,89 5120,98 10316.28 -1162,04 -10250.70 1.60 1,51 -0,62 -- -- 03-JUL-98 MWD 12251,78 63,64 263,58 75,07 5154,87 10383,26 -1168,75 -10317,35 2,04 1,25 -1,80 03-JUL-98 MWD 12339,00 64,50 263.00 87,22 5193,01 10461,70 -1177.91 -10395.25 1,15 0,99 -0,67 Projected Data - NO SURVEY ~ -- " SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-98669 Sidetrack No. Page 5 of 6 · -' t ll~'-I =~r.._--~ Company A~RC_O- _A _LA__S__.K-~_,_ !_N__C_- ................................... Rig Contractor & No. Doyon Drilling Co.- #141 ...... Field TARN DEVELOPMENT FIELD ........... Well Name & No. TARN DRILLSITE 2N/341 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ l~rL/~i~ WELL DATA Target'l-VD .................... (_Fi3__ ................ Target Coord. N/S Slot Coord. N/S -129.46 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W -1055.41 Magn. Declination 26.880 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOftL~ 30m~] 10m~ Verl:. Sec. Azim. 263.75 Magn. to Map Corr. __26.880 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 (+) Right (+) Comment Type (ET) (DD) (DD) (FI') (FT) (FI') (FT) (Per 100 FT) Drop (-) Left (-) -- 01 -J UL-98 MWD 8895,67 72.09 264.78 98,12 3824.29 7326.18 -912.95 -7270.00 0.18 0.17 -0.04 01 -JUL-98 MWD 8995.46 72.45 264.16 99.79 3854.68 7421.22 -922.11 -7364.61 0.69 0.36 -0.62 ,-- -- 01 -J UL-98 MWD 9089.51 71.31 262,94 94.05 3883.93 7510.60 -932.15 -7453.42 1.73 -1.21 -1.30 01 -J UL-98 MWD 9182.53 71.52 264.98 93.02 3913.58 7598.77 -941.42 -7541.10 2.09 0.23 2.19 01 -J UL-98 MWD 9276.97 72.31 264.14 94.44 3942.90 7688.53 -949.94 -7630.46 1.19 0.84 -0.89 01 -J U L-98 MWD 9371.33 71.95 263.83 94.36 3971.86 7778.34 -959.35 -7719.78 0.49 -0.38 -0.33 01 -JUL-98 MWD 9465.41 71.55 267.02 94.08 4001.32 7867.63 -966.47 -7808.83 3.25 -0.43 3.39 01 -J U L-98 MWD 9560.21 72.15 265.56 94.80 4030,86 7957.62 -972.31 -7898.72 1,59 0.63 -1.54 01 -J UL-98 MWD 9652,42 73.37 265.44 92.21 4058.18 8045.65 -979.22 -7986.51 1.33 1.32 -0.13 01 -JU L-98 MWD 9747.16 72.96 266.28 94.74 4085.62 8136.26 -985.76 -8076.95 0.95 -0.43 0.89 01 -J UL-98 MWD 9839.50 71.78 264.15 92.34 4113.59 8224.23 -993.10 -8164.64 2.54 -1.28 -2.31 01 -JUL-98 MWD 9933.48 70.97 266.05 93.98 4143.61 8313.26 -1000.71 -8253.37 2.10 -0.86 2.02 01-JUL-98 MWD 10026.35 69.66 268.30 92.87 4174.90 8400.54 -1005.02 -8340.70 2.68 -1.41 2.42 01-JUL-98 MWD 10109.88 70.50 267.05 83.53 4203.35 8478.88 -1008.21 -8419.16 1.73 1.01 -1.50 /' 02-JUL-98 MWD 10215.52 71.76 267.22 105.64 4237.52 8578.67 -1013,21 -8519.00 1.20 1.19 O. 16 02-JUL-98 MWD 10309.10 72.90 267.36 93.58 4265.92 8667.66 -1017.42 -8608.06 1.23 1.22 0.15 02-JUL-98 MWD 10397.59 72.97 266.66 88.49 4291.89 8752.12 -1021,84 -8692.54 0.76 0.08 -0.79 02-JUL-98 MWD 10491.53 70.59 266.61 93.94 4321.26 8841.23 -1027.07 -8781.61 2.53 -2.53 -0,05 02-JUL-98 MWD 10582.76 67.01 267.90 91.23 4354.25 8926.11 -1031.16 -8866.55 4.14 -3.92 1.41 02-JUL-98 MWD 10676.32 66.46 265,61 93.56 4391.21 9011.94 -1036.02 -8952.36 2.32 -0.59 -2.45 02-JUL-98 MWD 10775.89 68.09 266.44 99.57 4429.67 9103.70 -1042.38 -9043.97 1.81 1.64 0.83 02-J U L-98 MWD 10870.51 67.68 266.07 94.62 4465.29 9191.27 -1048.11 -9131.44 0.56 -0,43 -0.39 02-J U L-98 MWD 10965.22 67.14 266.68 94.71 4501.68 9278.63 -1053.64 -9218.71 0.82 -0,57 0.64 02-JUL-98 MWD 11059.23 65.55 265.38 94,01 4539.40 9364.66 -1059.59 -9304.61 2.11 -1.69 -1.38 WELL LOG TRANSMITTAl_, To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 September 30, 1998 ~: MWD Formation Evaluation Logs 2N-341, AX-MM-80268 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: ,Mi Turker, Sperry-Sun Drilling Services. 5631 Silverado Way, #G, Anchorage, AK 99518 2N-341: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20263-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20263-00 2" x 5" MD Neutron & Densiw Loas: 50-103-20263-00 2" x 5" TVD Neutron & Densi~ Logs: 50-103-20263-00 1 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 Dresser Industries. Inc. ComDanv ri I::! I I__1__ i IM G S I~ I~1 IJ I I-- I:::: S To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs September 30, 1998 2N-341, AK-MM-80268 1 LDWG formatted Disc with verification listing. API#: 50-103-20263-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LE'ITER TO THE A'ITEN~ON OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 SEP $ 0 199 3 Date: ~4aska C4i & Gas Cons. Commim0n AnCqorage Si. gnq~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518. (907) 273-3500. Fax (907) 273-3535 A Dresser Industries, Inc. Coml~any TONY KNOWLE$, GOVERNOR ALASK& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 21, 1998 Paul Mazzolini Tam Drilling Team Leader ARCO Alaska Inc. Address City Re; Kupamk River Unit 2N-341 ARCO Alaska Inc. Permit No.: 98-103 Sur Loc: 129'FNL, 1055'FEL, Sec. 3, T9N, R7E, UM Btmhole Loc. 1233'FNL, 667'FEL, Sec. 5, T9N, R7E, UM Dear Mr. Mazzolini: Enclosed is the approved revised application for permit to drill the above referenced well. The revision is for a change in bottom-hole location. The provisions of thc original approved permit dated June 19, 1998, including the spacing provisions of Conservation Order 428 are in effect for this revision. · Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section W/o encl Dcpartmcnt of Environmental Conservation w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill lb Type of Well Exploratory E] Stratigraphic Test E~ Development Oil X Re-Entry Deepen 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 121' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 375074, ALK 4293 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 129' FNL, 1055' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1211' FNL, 374' FEL, Sec. 5, T9N, RTE, UM 2N-341 #U-630610 At total depth 9. Approximate spud date Amount 1233' FNL, 667' FEL, Sec. 5, T9N, R7E, UM 6/22/98 $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 2N-343 12339' MD 374' @ Target feet 25' @ 425' feet 2560 5194' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 71.75° Maximum surface 1660 psig At total depth 2350 psig (TVD) 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" Weld 80' 28' 28' 108' 108' 49.5 sx AS I 9.875" 7.625" 29.7# L-80 BTC MOB 4199' 28' 28' 4227' 2301' 532 Sx AS IIILW, 240 sx Cl G 60 Sx AS1 6.75" 5.5" 15.5# L-80 LTC-Mod 11499' 28' 28' 11527' 4774' 240 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 791' 11527' 4774' 12318' 5184' (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 SGu°r~dacU;t°rR E C E IV E D Intermediate Production Liner JUL 20 '~998 Perforation depth: measured true vertical ~ask~ Oil & Gas Cons. Commission Anchorage 20. Attachments Filing fee ~ Property plat [] BOP Sketch [] Diverter Sketch ~ Drilling program Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements ~ 21. I hereby certify that th_e foregoing is true and correct to the best of my knowledge Sig~,f,~ ~.& I ¢"¢4"~'~ "~or ~)14~rl~l,l ~/~ ~'"/.~..~1~; Title Tarn Drilling Team Leader Date ] ~- ,~u,l~ "' Commission Use Only Permit Number I APl number I Approv_al date , I See cover letter for 98-103 50-103-20263 ,~./'~,~'.//,¢',¢ other requirements Conditions of approval Samples required [-- Yes ~ No Mud log required [-- Yes ~ No Hydrogen sulfidemeasures p-]Yes j~No Directional surveyrequired ~Yes [~ No Required working pressure for BOPE ~]2M [~[~] 5M [-~ IOM ~ 15M Other 0,'i¢~i['la, S'g1~86 ~/ by order of ? .~-~/.,. Approved by I-)avid W. ,1ohnRfnn Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 June 17, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-341 Surface Location: 130' FNL 1,055' FEL Sec 3 TgN R7E, UM Target Location: 1,131' FNL, 705' FEL Sec. 5, TgN, R7E, UM Bottom Hole Location: 1,149' FNL, 998' FEL Sec. 5, TgN, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill KRU 2N 341. The Permit to Drill for this well was previously approved, however, the well has not been spud and we are changing the bottom hole location. Please note that the new bottom hole location for 2N-341 was originally applied for in the Permit to Drill for well 2N-331. That APD is pending. Please disregard that application. The reason for this application is based on a logistical need for stimulation work to be conducted simultaneously with drilling operations on the drillsite. This will allow us to optimize the start of production from Tarn. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or 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. 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 ~. ~ ~.~ \~. ~- ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany David W. Johnston Application for Permit to Drill Page 2 KRU 2N-341 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 James Trantham at 265.6434 or me at 263.4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2N-341 Well File 2N 341 WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 135' MD / RKB Base of ~::i::::::::::i:: perm af r o s t~.:::i::i::i::i:: 1,296' MD ::::::i::::i?:i ..-.:....;.; :.-.:.;.;. Stage ..... 1,600' MD :::::: :::: :::::::::: ,,,,,,,,,, Top of ..... 1,356' MD West Sak 3,032' MD 7-5/8" Surface Casing at 4,268' MD Top of Cement at 11,000' MD 5-1/2" Production Casing at 11,573' MD 3-1/2" Production Casing at 12,367' MD :::::::;:;: "'-'.'.'-'. ;.;.;-:.;,; :!:i:i:i:i: ::::::::::: i:i:i:i:i:i '"'"'"" 7/8" Hole 6.3/4" Hole Conductor Casing Size I Hole Size 16" in 20' hole Depth: 135' MD RKB Top of Cement Surface Excess Calculated: 100% Volume Calculations: (135 If) (0.7854 cf/If) (2.00) = 212 cf (212 cf) /(0.93 cf/sx) = 230 sx Slurry Volume: 212 cf or A~ctic Set I 230 sx Slurry Weight 15.7 ppg rounded Slurry Yield 0.93 cf/sx Surface Casing excess 7-5/8' in 9-7/8' hole Stage 1: Volume (1,868 If) (0.2148 cf/if) (1.45) = 582 cf Lead (582 cf) /(4.42 cf/sx) = 132 sx Tail (800 If) (0.2148 cf/If) (1.45) = 249 cf shoe joint vol 21 cf + (249 cf) /(1.15 cf/sx) = 237 sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (CIG cmt + 1% SI(CaCI2) + 0.3% D65 (disp.) + 0.2% D46 (defoam.) Lead Slurry Volume:582 cf or 140 sx Slurry Weight 10.5 ppg Arctic Set3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 249 cf or 240 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.15 cf/sx Thickening Time 3.5 - 4.5 hours Surface Casing excess Stage 2: Vol. Lead (1,2961f) (O. 2148cf/If) (4.00)= 1,113cf (154 If)(0.2148cf/If) (1.45) = 48cf (1,161 cf) /(4.42cf/sx) = 263sx Tail(0 If) (0.2148 cf/if) (4.00) = 0 cf (150 If)(0.2148 cf/if) (1.45) = 47 cf (47 cf) /(0.93 cf/sx) = 50 sx System: Lead (Amtic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (Arctic Set 1 cement ) Lead Slurry Volume: 1,161 cf or 270 sx Slurry Weight 10.5 ppg Arctic Set 3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume:47 cf or 60 sx Slurry Weight 15.7 ppg Arctic Set 1 Slurry Yield 0.93 cf/sx Thickening Time 3.5 - 4.5 hours Production Casing Size / Hole Size 5-1/2" and 3-1/2" in 6-3/4" hole Depth: 12,387' Top of 3-1/2' casing11,573' Top of Cement 11,000' Excess Calculated: 50% BHT (Static): 1609 F 130~ F BHT (Circ): excess Volume around 5-1/2' (573 If) (0.0835 cf/If) (1.50) = 72 cf Volume around 3-1/2' (7941f) (0.1817cf/If) (1.50)= 21(~cf 288 cf shoe joint vol 4 cf + (288 cf) /(1.20 cf/sx) = 243 sx System: (Class G cement + 2 gps D600 (latex) + 0.1 gps D135 (stabilizer) + 0.1 gps D47 (defoam.) + 3% D53 (Gyp) + 0.8% D65 (disp) + 0.12% D800 (ret.) Slurry Volume: 288 cf or 250 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.20 cf/sx Thickenin,q Time 3.5 - 4.5 hours 611 7/98 ~-~ ARCO Alaska, Inc. -_l~ GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 341 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point according to directional plan. 4. Run and cement 7-5/8" casing, using stage collar placed approximately 200' MD below the base of the permafrost. Use lightweight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. 6. Drill out cement and 20' of new hole. Perform leak off test to 16.0 ppg EMW. This establishes a frac gradient equivalent. 7. Drill 6-3/4" 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). 8. 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 BQPE and install production tree. 12. Secure well. Rig down and move out. 2N 341 jt, 06/17/98 -' ARCO Alaska, Inc. ._i DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Welt KRU 2N 341 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 +10% Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 16 ppg EMW (0.832 psi/fi) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,660 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.832 - 0.11) = 1,660 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N 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'. 2N 341 ~,,.~.~;k~."'" ~:~ (;~-~ (?'~;' ~'~'~ ....... jt, 06/17/98 · ' ARCO Alaska, Inc. '.. Well Proximity Risks' The nearest well to 2N 341 is 2N 343. The wells are 25' from each other at a depth of 425'. Drillinq Area Risks: The primary risk in the 2N 341 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 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into 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 2N 341 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 2N 341 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 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi 2N 341 jt, 06/17/98 ARCO Alaska, Inc. This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 51/2" 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 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). 2N 341 jt, 06/17/98 ................ I S[ructure : lorn Drill Site 2N Well : 341 , I Field : Tarn Development Field Location : North Slope, Alaska <- West (feet) 11000 10500 10000 9500 9000 8500 8000 7500 7000 6500 6000 5500 5000 4500 4000 3500 3000 2500 2000 1500 1000 500 0 500 I I I I I I I [ J L L I I I I [ I I L I i .J. J .J J I I L ] I L I I I I I I I J i L ....J I L .... I TD LOCATION: J 1149' FNL, 998' FEL J SEC. 5, TgN, R7E J AG .,6° .... ¢o2 ~o~~ 5OO 1000 1500 O._ ~ 2000 2500 sooo I-- 3500 I 4000 4500 5000 55OO j TARGET TARGET LOCATION: TVD=4892 . Begin Turn to TargetPY 1131' FNL, 705' FEL TMB=12008 Base Permofrost SEC. 5, TgN, R7E DEP=soUTHwEsT 10258102091001 500 1000 RKB ELEVATION: 149' 1500 "' I KOP TVD=250 'rMD=250 DEP=O lSl'~}o ~64;q- AZI ,MUTI--I ~2~07 BEGIN TURN TO TARGET TVD=7161MD:730 DEP:4,3 102~58 -- ' I 129' FNL 1055' FELI ***Plane of Pro osal*** I per J MAXIMUM ANGLE "~Z2'-~ ..... ~ 7 5/8" CSG PT WD=2300 TUD=4288 DEP=2¢~2 '?i,'(O lJbU 4 TMD=4760 OEP=3459 Creoted by finch For: PRESTRIDGE Dote plott{d ; 12-Jun-98 Plot Reference is 341 Version iS. Coordinote~ ore in feet reference slot ~341. True Verticot Deptha ore reference RKB (Doyen ,'¢ ,,, N N n 71 48 D.L~4. : 3.00 deg per 100 ft. T 55 DEC 500 0 500 1000 1500 2000 2500 3000 3500 4.000 4500 5000 5500 8000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 Vertical Section (feet) -> Azimuth 264..40 with reference 0.00 N, 0.00 E from slot #341 /c,~t~ by t~.ch For: PRESTRIDGE Oet~ pl~ttod : ~ 2-Jun-~8 Plot Re~erence ~s )~1 Ve~i0n ~. Coord~nDtll are ;n flit reflrlflci ilot ~5~1. True Ve~ical Oepthl~g RKB(0a~n ~ / <- West (feet) 800 760 720 680 6¢0 600 560 520 480 440 400 ,360 320 280 2¢0 200 160 120 B0 40 0 40 80 ~ ........... ..................................................................... 1600 1 500 1400 1300 1~-1700 ................................................ 1200 ~- 40 4o .............................. 0 0 ,;. 4O 60 12O 160 200 -.I-- 0 240 I 280 320 360 400 440 2200 2400 2600 ........... 2800 ............ 3000 1800 2-00 1900 .............. 2100 ._.~ .................... 2000 1700 1800 1600 ................ 1700 ............................. 1800 ......................................... 1900 1400 2000 1500 1400 1600 1500 70O 8OO 1000 1200 1 ~00 1600 1100. 1200 .... - .... ,," 14oo 13oo ........... /,~oo 15oo ..................... ......... ....... rf;o 11oo .......... 1000 30O 1100 / 40 '00 / 600 / / 70( 80 900 800// / / 900 /,,/ L qo0 ,." 1300 200 1400 300 1200 ~~ 1 0 1300 170 0 1500 ,,,/' 1800 ~ ............ do',,' ' 320 280 240 200 160 120 0 West (feel) 480 i i i i i I I I I' I I I I I I i i i i i i i i 800 760 720 680 640 600 560 520 480 440 400 360 120 ' 160 ('- 1200 1200 ~' t '-", 1300 ~ 200 -'~ I / , 1400 240 I : 1500 ! 280 i l 600 ; 320 ~1700 ~ 360 1800 ! 400 1900 ~ 440 i 2000 , , 480 0 4'0 80 b~ f~ch For: PRESTRIDGE J O~tl 131atrial : 1 2-Jun-9B I Plot Reference ia 341 Version ~5, I Caora~n~tla are ~n felt reference alot ~341. ~ I .,ARCOAlaska Inc. i~ Cl uTrjr; ToO:vne ~i: :~; e F ~ :Il , 541 Location: North Slope, Alaska <- West (feet) 2600 2500 2400 2300 2200 21 O0 2000 1 gOO 1800 1700 1600 1500 1400 1,300 1200 1100 1000 gO0 leO0 700 GO0 500 200 2400 ~ ................................................ ~.3..0_0_ ..................... ._2200 2100 2000 100 .......................................................... 1go0 1800 7 0 ................ - ............................................................. 40O 0 0 100 200 300 ~00 6OO 700 8OO 9OO 1000 1100 3OO 2OO 100 21~ ~oo 3000 2~_.°-9--2.-f-°'9"-~'~'~' too 3900 3600 ............... _.--(3.'/ 4=,~, 4200 ................. . .......... 4~on 4700 .... ~--~ .......... .~ ............. :;~;~'" 2200 .... 4900 .Z .'-: ......... . ........... '~'~0 2600 .... 18013J 200 ~UUO ............. .'; ......... '~';,';,7,' 25000 o~n~, 1900 51 O0 .......... '.222'-22 ............."3400 "~'~" 210n .... - ............... ........ ~?::~-0-~-6-"'~00 3600 ...........~'- .................. 5200 .... ~;=/7~/"'X200 .............................. '~'~;;" ,.~ ~ .... -~"~'-'~ .... 4600 "" - ................... '-'--- " '"~'~ ~ 3''~ .~- 4800 ........................................ 2500 z~uu ~ ~00 ~.---~'-"~'- .... ........ ooo ,,oo 3~ ....... ~i .......... ~1oo 4.°0 :S' 2100 ............ ~c~uu ~ 2600 2000 2200 ~~~25002400 .~300 800 2600 2500 2400 2~00 2200 21 O0 2000 1900 1800 1700 1600 1500 14.00 1500 1200 11 O0 1000 gOO BOO 700 600 500 <- West (feet) I ¥ 200 lO0 100 200 500 400 5oo I V 6oo 700 800 go0 10o0 1100 by finch For: PRESTRIDGE I Oat~ plotted : 12-Jun-gB I Plot Re~erence i~ 3~1 Vemion ~5. J IARCO Alaska, Inc. ~ rn I Location: North Slope, Alaska <- West (feet) 4200 4100 4000 3900 3800 3700 3600 3500 3400 3300 3200 31 O0 3000 2900 2800 2700 2600 2500 2400 2500 2200 21 O0 2600 2500 200 .......................................................... 2400 lOO lO0 2OO 5100 0 3400 3300 3200 x~nn 3500 .......... 3100 3000 "+' 3800 3700 ~.~ .......................... 4O0 :3- 4500 4~oo 41oo ~S_..27 ........................................ '""... ~ .................................. 2100 5~0 //2200 ..................... 2400 ............................... ~;"'~ ........................... 2~ 2500 ................................. ," 2600 2600 .................... " ............... ,/' 2700 ~4~ 2700 ............................... ~~ ~oo V ~ // 70o 3200~/ ,/ ~ /,// 800 ;~' / 900 / / / / 1000 / / ! 7 11oo I I i i I I I i I ! II I ! [ I I I I ii I I II I I I I I I I I I i I I I I 4200 4100 4000 3900 3800 3700 5600 3500 5400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 2100 <- West (feet) l,TC~al~<~ by ~{,,=h For: PRESTRIDGE Dui" plotted : 12-Jun-9~ Plot Reference is ~41 V~rm}on ~5, Coordinute~ ore in feet re~erence ~lot ~341. rue Vertical Degthl~ AgCO Ale k I s a, nc. r I Location : North Slope, Alaska <- West (feet) 7600 7400 7200 7000 6800 6600 6400 6200 6000 5800 5600 5400 5200 5000 4800 4600 4400 4200 4000 `3800 3600 3400 3200 600 { { I ~ I I I I I I ~ t ~ I,I I { I I i I I I ~ { I ~ t ~ t,t t ~ I I ~ t ~ J I t { t 600 ~... ~3oo 4200 41oo 4000 .... ~ ................. ~!fi~ .... 4oo ........................................................... ~ ...... 2? ~oo ~oo ~oo .............................................................. 2~72 ....... 2~ ....... 2~2° ~ooo ~oo 200 ....................... ~?? ~'<~ 0 200 4000 3800 , r~.J~92._2~ ............... ~" 2700 2600 2500 ...... 3nO0 2900 2800 ............................................ 3200 3100 v ................................ 3-^0 3300 ............................... ~=n~ 3500 ~u .................................... =~^ 320~ 38 ~uu .............. oo ........................... 3~' .............. ~oo ~ ---'--~ 3800 ~ ' 4000 ~ 4300 1200 4600~ 1400 1600 .~~100 4000 1800 /4'~40440043°° '~4~004500 2000 ~~4~004700 4900 4OO ~ 600 -+- 800 0 1000 I V 400 200 0 200 400 0 600 800 '=~ 1000 I 1200 1400 1600 1800 2000 2200 i i i i i i i i i i "l i i i I ~ i i i i i i i ~ i i ~ I i ~ i i i i i ~ i i "l i i i i 2200 7600 7400 7200 7000 6800 6600 6400 6200 6000 5800 5600 5400 5200 5000 4800 4.600 4400 4200 4-000 3800 3600 ,3400 3200 <- West (feet) I ARCO Alaska, Inc. Structure: Torn Drill Site 2N Well: ,,%41 ield : Torn Development Field Locoflon : North Slope, Alosko WELL PROFILE DATA 330 340 35O TRUE NORTH 0 10 · 520 3O 9O0 310 3OO c,,~,~ b~ r.~ For: PRESTEIDGE Date platted : 12-Jun-g8 Plot Ref~e~ ~s 341 ~ ~. Vetch 0~t~ ore r~ ~ (~ 141) 7OO 700 700 80 290 280 270 0 5OO + 5~0 8O 9O 26O 100 250 110 240 120 230 130 220 140 210 150 200 160 190 180 170 T ..... Ii.'.---- /"..1:~1~,.- I~-',-,/-~t' All ,~o,~tH~ ~hr.~n nr~ Id~am,r~a dPnthq an R~farance WP. Il ARCO Alaska, Inc. Tarn Drill Site 2N 341 slot #341 Tarn Development Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT Baker Hughes INTEQ Your ref = 341 Version Our ref = prop2968 License : Date printed : 12-Jun-98 Date created : 11-Jun-98 Last revised : 12-Jun-98 Field is centred on n?0 12 49.742,w150 18 33.414 Structure is centred on n?0 10 13.955,w150 18 32.772 Slot locatlon is nT0 10 12.681,w150 19 3.347 Slot Grid coord/nates are N 5911879.231, E 460537.370 Slot local coordinates are 129.46 S 1055.41 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 40?.4* Object wellpath 333 to 331 Option #1,,333,Tarn Drill Site 2N PMSS <0-8239~,,339,Tar~ Drill Site 2N PMSS <0-9631',,,343,Tarn Drill 330 Version #3,,330,Tarn Drill 313 Version #4,,313,Tarn Drill PMSS ~O-9690*>,,329,Tarn Drill PMSS <O-9553*),,323,Tarn Drill 317 Version #1,,31?,Tarn Drill 321 Version #3,,321,Tarn Drill 319 Version #2,,319,Tarn Drill 325 Version #3,,325,Tarn Drill 326 Version #2,,326,Tarn Drill 327 Version #2,,327,Tarn Drill 347 Version #1,,34?,Tarn Drill 334 Version #1,,334,Tarn Drill 320 Version #1,,320,TarnDri11 310 Version #1,,310,Tarn Drill 309 Version #1,,309,Tarn Drill 308 Version #1,,308,Tarn Drill 307 Version #1,,307,Tarn Drill 306 Version #1,,306,Tarn Drill 304 Version #1,,304,Tarn Drill 302 Version #1,,302,Tarn Drill 301 Version #1,,301,TarnDri11 315 Version #1,,315,Tarn Drill Closest approach with 3-D Last revised Distance MinlmumDistance method M.D. Diverging £romM.D. 8-Jun-98 120.5 250.0 250.0 1-Jun-98 30.3 100.0 100.0 Site 2N 28-May-98 25.0 425.0 425.0 Site 2N 21-May-98 161.5 550.0 550.0 Site 2N 22-Apr-98 420.5 250.0 250.0 Site 2N 28-May-98 180.4 0.0 0.0 Site 2N 28-May-98 268.7 300.0 300.0 Site 2N 8-Mar-98 360.4 250.0 250.0 Site 2N 8-May-98 300.1 250.0 250.0 Site 2N 8-May-98 330.4 250.0 250.0 Site 2N 8-Ma7-98 240.4 250.0 250.0 Site 2N 2T-Mar-98 225.5 250.0 250.0 Site 2N 27-Mar-98 210.5 250.0 250.0 Site 2N 8-Mar-98 81.7 525.0 525.0 Site 2N 8-Mar-98 105.5 250.0 250.0 Site 2N 8-Mar-98 315.4 250.0 250.0 Site 2N 8-Mar-98 465.4 250.0 250.0 Site 2N 8-Mar-98 480.4 250.0 250.0 Site 2N 8-Mar-98 495.4 250.0 250.0 Site 2N 8-Mar-98 510.4 250.0 250.0 Site 2N 8-Mar-98 525.4 250.0 250.0 Site 2N 8-Mar-98 555.4 250.0 250.0 Site 2N 8-Mar-98 585.4 250.0 250.0 Site 2N 8-Mar-98 600.4 250.0 250.0 Site 2N 8-Mar-98 390.5 250.0 250.0 311 Version #1,,311,Tarn Dril,.~te 2N 314 Version #1,,314,Tarn Drill Site 2N 303 Version #2,,303,Tarn Drill Site 2N 305 Version #2,,305,Tarn Drill Site 2N 335 Version #1,,335,Tarn Drill Site 2N 345 Version #6,,345,Tarn Drill Site 2N 350 Version #1,,350,Tarn Drill Site 2N 337 Version #&,,337,Tarn Drill Site 2N PMSS <0-???>,,337,Tarn Drill Site 2N PMSS < 0 - 7650>,,Tarn#2,TARN #2 PMSS < 2250 - ?162~,,3A,TARN#3 PMSS ~ 0 - 6150~>,,TARN#4,TARN #4 21-Apr-98 21-Apr-98 8-Mar-98 8-Mar-98 8-Mar-98 4-Jun-98 11-Jun-98 13-May-98 12-Jun-98 14-Aug-97 12-Aug-97 12-Au~-97 450.4 405.4 570.4 540.4 90.6 49.7 126.0 60.7 60.7 13065.1 4298.3 6905.6 250.0 250.0 250.0 250.0 250.0 525.0 550.0 250.0 100.0 100.0 250.0 300.0 250.0 250.0 250.0 250.0 250.0 525.0 5340.0 250.0 100.0 100.0 250.0 300.0 ARCO Alaska, Inc. Tarn Drill Site 2N 341 slot #341 Tarn Development Field North Slope, Alaska PROPOSAL LISTING INCr.UDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 341 Version #5 Our ref : prop2968 License = Date printed : 12-Jun-98 Date created : 11-Jun-98 Last revised : 12-Jun-98 Field is centred on n?0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.95§,w150 18 32.772 Slot location is nT0 10 12.681,w150 19 3.347 Slot Grid coordinates are N 5911879.231, E 460537.3?0 Slot local coordinates are 129.46 S 1055.41 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Tarn Drill Site 2N, 341 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 341 Version #5 Last revised = 12-Jun~98 Measured Inclin. Azimuth True Vert R E C T A N ~ U L A R Dogleg Vert Depth Degrees Degrees Depth C 00 R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 B 0.00 0.00 100.00 0.00 200.00 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 200.00 200.00 0.00 N 0.00 E 0.00 0.00 250.00 0.00 200.00 250.00 0.00 N 0.00 E 0.00 0.00 350.00 5.00 200.00 349.87 4.10 S 1.49 W 5.00 1.88 KOP 450.00 10.00 200.00 448.99 16.36 S 5.95 W 5.00 7.52 550.00 15.00 200.00 546.58 36.69 S 13.35 W 5.00 16.87 650.00 20.00 200.00 641.93 64.94 S 23.64 W 5.00 29.86 730.00 24.00 200.00 716.09 93.09 S 33.88 W 5.00 42.81 800.00 25.07 208.03 779.78 119.57 S 45.73 W 5.00 57.18 Begin Turn to Target 900.00 27.28 218.22 869.56 156.31 S 69.88 W 5.00 84.80 1000.00 30.11 226.81 957.31 191.50 S 102.37 W 5.00 120.57 1100.00 33.42 233.96 1042.35 224.89 S 142.95 W 5.00 164.21 1200.00 37.06 239.90 1124.04 256.23 S 191.31 W 5.00 215.41 1296.36 40.81 244.73 1199.00 284.25 S 244.94 W 5.00 271.51 Base Permafrost 1300.00 40.95 244.89 1201.75 285.26 S 247.09 W 5.00 273.75 1355.57 43.20 247.34 1243.00 300.32 S 281.14 W 5.00 309.11 1400.00 45.03 249.14 1274.90 311.77 S 309.86 W 5.00 338.81 1500.00 49.24 252.82 1342.92 335.57 S 379.15 W 5.00 410.09 1600.00 53.56 256.06 1405.31 356.46 S 454.42 W 5.00 487.03 Top West Sak Sands 1700.00 57.95 258.94 1461.58 374.29 S 535.10 W 5.00 569.07 1800.00 62.40 261.57 1511.30 388.92 S 620.58 W 5.00 655.57 1900.00 66.90 263.98 1554.11 400.25 S 710.20 W 5.00 745.88 2000.00 71.43 266.24 1589.67 408.18 S 803.30 W 5.00 839.30 2006.89 71.75 266.39 1591.84 408.60 S 809.82 W 5.00 845.83 EOC 2500.00 71.75 266.39 1746.28 438.07 S 1277.19 W 0.00 1313.85 3000.00 71.75 266.39 1902.88 467.94 S 1751.10 W 0.00 1788.41 3032.31 71.75 266.39 1913.00 469.87 S 1781.73 W 0.00 1819.08 3500.00 71.75 266.39 2059.48 497.82 S 2225.00 W 0.00 2262.96 4000.00 71.75 266.39 2216.07 527.69 S 2698.91 W 0.00 2737.52 Base West Sak Sands 4267.96 71.75 266.39 2300.00 543.70 S 2952.88 W 0.00 2991.85 4500.00 71.75 266.39 2372.67 557.57 S 3172.81 W 0.00 3212.08 4759.67 71.75 266.39 2454.00 573.08 S 3418.93 W 0.00 3458.53 5000.00 71.75 266.39 2529.27 587.44 S 3646.71 W 0.00 3686.63 5500.00 71.75 266.39 2685.87 617.32 S 4120.62 W 0.00 4161.19 7 5/8" Casing Pt C80 6000.00 71.75 266.39 2842.47 647.19 S 4594.52 W 0.00 4635.75 6500.00 71.75 266.39 2999.06 677.07 S 5068.42 W 0.00 5110.31 7000.00 71.75 266.39 3155.66 706.94 S 5542.33 W 0.00 5584.86 7500.00 71.75 266.39 3312.26 736.82 S 6016.23 W 0.00 6059.42 8000.00 71.75 266.39 3468.86 766.69 S 6490.13 W 0.00 6533.98 8500.00 71.75 266.39 3625.45 796.57 S 6964.04 W 0.00 7008.53 8524.09 71.75 266.39 3633.00 798.01 S 6986.87 W 0.00 7031.40 9000.00 71.75 266.39 3782.05 826.44 S 7437.94 W 0.00 7483.09 9012.60 71.75 266.39 3786.00 827.20 S 7449.89 W 0.00 7495.05 9500.00 71.75 266.39 3938.65 856.32 S 7911.84 W 0.00 7957.65 C50 C40 10000.00 71.75 266.39 4095.25 886.19 S 8385.75 W 0.00 8432.20 10500.00 71.75 266.39 4251.85 916.07 S 8859.65 W 0.00 8906.76 11000.00 71.75 266.39 4408.44 945.95 S 9333.56 W 0.00 9381.32 11091.08 71.75 266.39 4436.97 951.39 S 9419.88 W 0.00 9467.77 11091.11 71.75 266.39 4436.98 951.39 S 9419.91 W 0.00 9467.79 Begin Angle Drop All data is in feet unless otherwise stated. Coordinates from slot #341 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 10552.02 on azimuth 264.45 degrees from wellhead. Total Dogleg for wellpath is 104.59 degrees. Vertical section is from wellhead on azimuth 264.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 341 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LiSTIN~ Page 2 Your ref : 341 Version #5 Last revised : 12-Jun-98 Dogleg Vert Deg/100ft Sect 11100.00 71.48 266.39 4439.78 951.92 S 9428.33 W 3.00 9476.22 11200.00 68.48 266.39 4474.01 957.83 S 9522.09 W 3.00 9570.11 11300.00 65.48 266.39 4513.11 963.62 S 9613.94 W 3.00 9662.09 11400.00 62.48 266.39 4556.97 969.27 S 9703.61 W 3.00 9751.89 11500.00 59.48 266.39 4605.48 974.77 S 9790.88 W 3.00 9839.27 11600.00 56.48 266.39 4658.49 980.10 S 9875.49 W 3.00 9924.00 11649.38 55.00 266.39 4686.28 982.67 S 9916.21 W 3.00 9964.78 End Angle Drop 11772.67 55.00 266.39 4757.00 989.02 S 10017.01 W 0.00 10065.71 T4 11849.38 55.00 266.39 4801.00 992.98 S 10079.72 W 0.00 10128.51 T3 - Top Bermuda 12000.00 55.00 266.39 4887.39 1000.74 S 10202.86 W 0.00 10251.82 12008.01 55.00 266.39 4891.99 1001.15 S 10209.41 W 0.00 10258.38 TARGET - Mid Bermuda 12008.03 55.00 266.39 4892.00 1001.15 S 10209.43 W 0.00 10258.39 2N-J(I) 331 Rvsd 8-Jun-g8 12166.69 55.00 266.39 4983.00 1009.32 S 10339.13 W 0.00 10388.28 T2 - Base Bermuda 12273.04 55.00 266.39 5044.00 1014.80 S 10426.07 W 0.00 10475.34 C35 12366.69 55.00 266.39 5097.72 1019.63 S 10502.64 W 0.00 10552.01 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #341 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 10552.02 on azimuth 264.45 degrees from wellhead. Total Dogleg for wellpath is 104.59 degrees. Vertical section is from wellhead on azimuth 264.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,341 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 341 Version #5 Last revised : 12-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 730.00 1296.36 1355.57 2006.89 3032.31 4267.96 4759.67 8524.09 9012.60 11091.08 11649.38 11772.67 11849.38 12008.01 12008.03 12166.69 12273.04 12366.69 716.09 1199.00 1243.00 1591 84 1913 00 2300 00 2454 00 3633 00 3786 00 4436 97 4686 28 4757 00 4801.00 4891.99 4892.00 4983.00 5044.00 5097.72 93.09 S 33.88 W Begin Turn to Target 284.25 S 244.94 W Base Permafrost 300.32 S 281.14 W Top West Sak Sands 408.60 S 809.82 W EOC 469.87 S 1781.73 W Base West Sak Sands 543.70 S 2952.88 W 7 5/8" Casing Pt 573.08 S 3418.93 W C80 798.01 S 6986.87 W C50 827.20 S 7449.89 W C40 951.39 S 9419.88 W Begin Angle Drop 982.67 S 9916.21 W End Angle Drop 989.02 S 10017.01 W T4 992.98 S 10079.72 W T3 - Top Bermuda 1001.15 S 10209.41 W TARGET - Mid Bermuda 1001.15 S 10209.43 W 2N-J(I) 331 Rvsd 8-Jun-98 1009.32 S 10339.13 W T2 - Base Bermuda 1014.80 S 10426.07 W C35 1019.63 S 10502.64 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 4267.96 2300.00 543.70S 2952.88W 7 5/8" Casing 0.00 0.00 0.00N 0.00E 12366.70 5097.72 1019.63S 10502.64W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-J(I) 331 Rvsd 8-J 450324.000,5910930.000,0.0000 4892.00 1001.15S 10209.43W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N, 341 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 341 Version #5 Last revised : 12-Jun-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 00 R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 129.46 S 1055.41 W 0.00 0.00 100.00 0.00 200.00 100.00 129.46 S 1055.41 W 0.00 0.00 200.00 0.00 200.00 200.00 129.46 S 1055.41 W 0.00 0.00 250.00 0.00 200.00 250.00 129.46 S 1055.41 W 0.00 0.00 350.00 5.00 200.00 349.87 133.56 S 1056.90 W 5.00 1.88 KOP 450.00 10.00 200.00 448.99 145.82 S 1061.36 W 5.00 7.52 550.00 15.00 200.00 546.58 166.15 S 1068.76 W 5.00 16.87 650.00 20.00 200.00 641.93 194.40 S 1079.04 W 5.00 29.86 730.00 24.00 200.00 716.09 222.56 S 1089.29 W 5.00 42.81 800.00 25.07 208.03 779.78 249.04 S 1101.13 W 5.00 57.18 Begin Turn to Target 900.00 27.28 218.22 869.56 285.77 S 1125.28 W 5.00 84.80 1000.00 30.11 226.81 957.31 320.97 S 1157.77 W 5.00 120.57 1100.00 33.42 233.96 1042.35 354.36 S 1198.35 W 5.00 164.21 1200.00 37.06 239.90 1124.04 385.69 S 1246.72 W 5.00 215.41 1296.36 40.81 244.73 1199.00 413.71 S 1300.34 W 5.00 271.51 Base Permafrost 1300.00 40.95 244.89 1201.75 414.72 S 1302.50 W 5.00 273.75 1355.57 43.20 247.34 1243.00 429.78 S 1336.55 W 5.00 309.11 1400.00 45.03 249.14 1274.90 441.24 S 1365.27 W 5.00 338.81 1500.00 49.24 252.82 1342.92 465.03 S 1434.55 W 5.00 410.09 1600.00 53.56 256.06 1405.31 485.92 S 1509.82 W 5.00 487.03 Top West Sak Sands 1700.00 57.95 258.94 1461.58 503.75 S 1590.50 W 5.00 569.07 1800.00 62.40 261.57 1511.30 518.39 S 1675.98 W 5.00 655.57 1900.00 66.90 263.98 1554.11 529.71 S 1765.61 W 5.00 745.88 2000.00 71.43 266.24 1589.67 537.65 S 1858.70 W 5.00 839.30 2006.89 71.75 266.39 1591.84 538.07 S 1865.23 W 5.00 845.83 EOC 2500.00 71.75 266.39 1746.28 567.53 S 2332.60 W 0.00 1313.85 3000.00 71.75 266.39 1902.88 597.41 S 2806.50 W 0.00 1788.41 3032.31 71.75 266.39 1913.00 599.34 S 2837.13 W 0.00 1819.08 3500.00 71.75 266.39 2059.48 627.28 S 3280.41 W 0.00 2262.96 4000.00 71.75 266.39 2216.07 657.16 S 3754.31 W 0.00 2737.52 Base West Sak Sands 4267.96 71.75 266.39 2300.00 673.17 S 4008.29 W 0.00 2991.85 4500.00 71.75 266.39 2372.67 687.03 S 4228.21 W 0.00 3212.08 4759.67 71.75 266.39 2454.00 702.55 S 4474.33 W 0.00 3458.53 5000.00 71.75 266.39 2529.27 716.91 S 4702.12 W 0.00 3686.63 5500.00 71.75 266.39 2685.87 746.78 S 5176.02 W 0.00 4161.19 7 5/8" Casing Pt C80 6000.00 71.75 266.39 2842.47 776.66 S 5649.93 W 0.00 4635.75 6500.00 71.75 266.39 2999.06 806.53 S 6123.83 W 0.00 5110.31 7000.00 71.75 266.39 3155.66 836.41 S 6597.73 W 0.00 5584.86 7500.00 71.75 266.39 3312.26 866.28 S 7071.64 W 0.00 6059.42 8000.00 71.75 266.39 3468.86 896.16 S 7545.54 W 0.00 6533.98 8500.00 71.75 266.39 3625.45 926.03 S 8019.44 W 0.00 7008.53 8524.09 71.75 266.39 3633.00 927.47 S 8042.28 W 0.00 7031.40 9000.00 71.75 266.39 3782.05 955.91 S 8493.35 W 0.00 7483.09 9012.60 71.75 266.39 3786.00 956.66 S 8505.29 W 0.00 7495.05 9500.00 71.75 266.39 3938.65 985.78 S 8967.25 W 0.00 7957.65 C50 10000.00 71.75 266.39 4095.25 1015.66 S 9441.15 W 0.00 8432.20 10500.00 71.75 266.39 4251.85 1045.53 S 9915.06 W 0.00 8906.76 11000.00 71.75 266.39 4408.44 1075.41 S 10388.96 W 0.00 9381.32 11091.08 71.75 266.39 4436.97 1080.85 S 10475.29 W 0.00 9467.77 11091.11 71.75 266.39 4436.98 1080.85 S 10475.31 W 0.00 9467.79 Begin Angle Drop All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, RTE and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 10552.02 on azimuth 264.45 degrees from wellhead. Total Dogleg for wellpath is 104.59 degrees. Vertical section is from wellhead on azimuth 264.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, inc. Tarn Drill Site 2N, 341 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N ~ Depth Degrees Degrees Depth C O O R D I N ULAR ATES 11100.00 71.48 266.39 4439.78 1081.38 S 10483.74 W 11200.00 68.48 266.39 4474.01 1087.29 S 10577.50 W 11300.00 65.48 266.39 4513.11 1093.08 S 10669.34 W 11400.00 62.48 266.39 4556.97 1098.74 S 10759.02 W 11500.00 59.48 266.39 4605.48 1104.24 S 10846.28 W 11600.00 56.48 266.39 4658.49 1109.57 S 10930.89 W 11649.38 55.00 266.39 4686.28 1112.13 S 10971.62 W 11772.67 55.00 266.39 4757.00 1118.49 S 11072.41 W 11849.38 55.00 266.39 4801.00 1122.44 S 11135.13 W 12000.00 55.00 266.39 4887.39 1130.20 S 11258.26 W PROPOSAL LISTIN~ Page 2 Your ref : 341 Version #5 Last revised : 12-Jun-98 Dogleg Vert Deg/100ft Sect 3.00 9476.22 3.00 9570.11 3.00 9662.09 3.00 9751.89 3.00 9839.27 3.00 9924.00 3.00 9964.78 End Angle Drop 0.00 10065.71 T4 0.00 10128.51 T3 - Top Bermuda 0.00 10251.82 12008.01 55.00 266.39 4891.99 1130.61 S 11264.82 W 0.00 12008.03 55.00 266.39 4892.00 1130.61 S 11264.83 W 0.00 12166.69 55.00 266.39 4983.00 1138.79 S 11394.54 W 0.00 12273.04 55.00 266.39 5044.00 1144.27 S 11481.48 W 0.00 12366.69 55.00 266.39 5097.72 1149.09 S 11558.04 W 0.00 10258.38 TARGET - Mid Bermuda 10258.39 2N-J(I) 331 Rvsd 8-Jun-98 10388.28 T2 - Base Bermuda 10475.34 C35 10552.01 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, RTE and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 10552.02 on azimuth 264.45 degrees from wellhead. Total Dogleg for wellpath is 104.59 degrees. Vertical section is from wellhead on azimuth 264.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 341 Tarn Development Field,North Slope, Alaska ~ROPOSAL LISTING ~age 3 Your ref : 341 Version #5 Last revised : 12-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 129.46 S 1055.41 W KOP 730.00 716.09 222.56 S 1089.29 W Begin Turn to Target 1296.36 1199.00 413.71 S 1300.34 W Base Permafrost 1355.57 1243.00 429.?8 S 1336.55 W Top West Sak Sands 2006.89 1591.84 538.07 S 1865.23 W EOC 3032.31 1913.00 599.34 S 2837.13 W Base West Sak Sands 4267.96 2300.00 673.17 S 4008.29 W ? 5/8" Casing Pt 4759.67 2454.00 702.55 S 4474.33 W C80 8524.09 3633.00 927.47 S 8042.28 W C50 9012.60 3?86.00 956.66 S 8505.29 W C40 11091.08 4436.97 1080.85 S 10475.29 W Begin Angle Drop 11649.38 4686.28 1112.13 S 10971.62 W End Angle Drop 11772.67 4757.00 1118.49 S 11072.41 W T4 11849.38 4801.00 1122.44 S 11135.13 W T3 - Top Bermuda 12008.01 4891.99 1130.61 S 11264.82 W TARGET - Mid Bermuda 12008.03 4892.00 1130.61 S 11264.83 W 2N-J(I) 331 Rvsd 8-Jun-98 12166.69 4983.00 1138.79 S 11394.54 W T2 - Base Bermuda 12273.04 5044.00 1144.27 S 11481.48 W C35 12366.69 5097.72 1149.09 S 11558.04 W TD - Casing Pt Casing positions in string 'A' ========================= Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 129.46S 1055.41W 4267.96 2300.00 673.17S 4008.29W 7 5/8" Casing 0.00 0.00 129.46S 1055.41W 12366.69 5097.72 1149.09S 11558.04W 5 1/2" Casing Targets associated with this wellpath ============================= ===~___ Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-J(I) 331 Rvsd 8-J 450324.000,5910930.000,0.0000 4892.00 1130.61S 11264.83W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N, 341 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref = 341 Version #5 Last revised = 12-Jun-98 Measured Inclin. Azimuth True Vert R E C T A N ~ U L A R Depth Degrees Degrees Depth C O O R D I N A T E S Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 200.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 200.00 200.00 0.00 N 0.00 ~ 0.00 0.52 0.52 0.30 N/A 250.00 0.00 200.00 250.00 0.00 N 0.00 E 0.00 0.65 0.65 0.38 N/A 350.00 5.00 200.00 349.87 4.10 S 1.49 W 1.88 0.96 0.92 0.53 20.00 450.00 10.00 200.00 448.99 16.36 S 5.95 W 7.52 1.49 1.21 0.68 20.00 550.00 15.00 200.00 546.58 36.69 S 13.35 W 16.87 2.33 1.53 0.84 20.00 650.00 20.00 200.00 641.93 64.94 S 23.64 W 29.86 3.52 1.90 1.02 20.00 730.00 24.00 200.00 716.09 93.09 S 33.88 W 42.81 4.68 2.23 1.19 20.00 800.00 25.07 208.03 779.78 119.57 S 45.73 W 57.18 5.79 2.54 1.35 21.70 900.00 27.28 218.22 869.56 156.31 S 69.88 W 84.80 7.60 2.99 1.60 26.05 1000.00 30.11 226.81 957.31 191.50 S 102.37 W 120.57 9.73 3.47 1.89 31.15 1100.00 33.42 233.96 1042.35 224.89 S 142.95 W 164.21 12.27 4.00 2.22 36.53 1200.00 37.06 239.90 1124.04 256.23 S 191.31 W 215.41 15.33 4.56 2.61 41.85 1296.36 40.81 244.73 1199.00 284.25 S 244.94 W 271.51 18.84 5.14 3.05 46.73 1300.00 40.95 244.89 1201.75 285.26 S 247.09 W 273.75 18.97 5.16 3.07 46.91 1355.57 43.20 247.34 1243.00 300.32 S 281.14 W 309.11 21.35 5.50 3.36 49.51 1400.00 45.03 249.14 1274.90 311.77 S 309.86 W 338.81 23.26 5.78 3.59 51.58 1500.00 49.24 252.82 1342.92 335.57 S 379.15 W 410.09 28.24 6.40 4.20 55.80 1600.00 53.56 256.06 1405.31 356.46 S 454.42 W 487.03 33.90 7.02 4.88 59.59 1700.00 57.95 258.94 1461.58 374.29 S 535.10 W 569.07 40.24 7.61 5.64 62.96 1800.00 62.40 261.57 1511.30 388.92 S 620.58 W 655.57 47.22 8.18 6.47 65.97 1900.00 66.90 263.98 1554.11 400.25 S 710.20 W 745.88 54.76 8.70 7.37 68.67 2000.00 71.43 266.24 1589.67 408.18 S 803.30 W 839.30 62.80 9.17 8.33 71.09 2006.89 71.75 266.39 1591.84 408.60 S 809.82 W 845.83 63.36 9.20 8.39 71.24 2500.00 71.75 266.39 1746.28 438.07 S 1277.19 W 1313.85 104.25 11.11 13.18 77.44 3000.00 71.75 266.39 1902.88 467.94 S 1751.10 W 1788.41 146.40 12.82 18.06 80.09 3032.31 71.75 266.39 1913.00 469.87 S 1781.73 W 1819.08 149.14 12.93 18.37 80.18 3500.00 71.75 266.39 2059.48 497.82 S 2225.00 W 2262.96 188.78 14.49 22.94 81.53 4000.00 71.75 266.39 2216.07 527.69 S 2698.91 W 2737.52 231.26 16.15 27.82 82.44 4267.96 71.75 266.39 2300.00 543.70 S 2952.88 W 2991.85 254.06 17.04 30.44 82.77 4500.00 71.75 266.39 2372.67 557.57 S 3172.81 W 3212.08 273.80 17.82 32.70 83.06 4759.67 71.75 266.39 2454.00 573.08 S 3418.93 W 3458.53 295.90 18.69 35.24 83.30 5000.00 71.75 266.39 2529.27 587.44 S 3646.71 W 3686.63 316.36 19.49 37.59 83.52 5500.00 71.75 266.39 2685.87 617.32 S 4120.62 W 4161.19 358.94 21.18 42.47 83.86 6000.00 71.75 266.39 2842.47 647.19 S 4594.52 W 4635.75 401.54 22.88 47.36 84.13 6500.00 71.75 266.39 2999.06 677.07 S 5068.42 W 5110.31 444.15 24.58 52.24 84.35 7000.00 71.75 266.39 3155.66 706.94 S 5542.33 W 5584.86 486.77 26.29 57.13 84.53 7500.00 71.75 266.39 3312.26 736.82 S 6016.23 W 6059.42 529.39 28.01 62.01 84.68 8000.00 71.75 266.39 3468.86 766.69 S 6490.13 W 6533.98 572.01 29.73 66.90 84.81 8500.00 71.75 266.39 3625.45 796.57 S 6964.04 W 7008.53 614.64 31.45 71.79 84.92 8524.09 71.75 266.39 3633.00 798.01 S 6986.87 W 7031.40 616.69 31.53 72.02 84.92 9000.00 71.75 266.39 3782.05 826.44 S 7437.94 W 7483.09 657.27 33.18 76.67 85.02 9012.60 71.75 266.39 3786.00 827.20 S 7449.89 W 7495.05 658.35 33.22 76.80 85.02 9500.00 71.75 266.39 3938.65 856.32 S 7911.84 W 7957.65 699.90 34.91 81.56 85.10 10000.00 71.75 266.39 4095.25 886.19 S 8385.75 W 8432.20 742.54 36.64 86.45 85.17 10500.00 71.75 266.39 4251.85 916.07 S 8859.65 W 8906.76 785.17 38.38 91.33 85.24 11000.00 71.75 266.39 4408.44 945.95 S 9333.56 W 9381.32 827.81 40.11 96.22 85.30 11091.08 71.75 266.39 4436.97 951.39 S 9419.88 W 9467.77 835.58 40.43 97.11 85.31 11091.11 71.75 266.39 4436.98 951.39 S 9419.91 W 9467.79 835.58 40.43 97.11 85.31 All data is in feet unless otherwise stated. Coordinates from slot #341 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 10552.02 on azimuth 264.45 degrees from wellhead. Vertical section is from wellhead on azimuth 264.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,341 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A Depth Degrees Degrees Depth C 00 R D PROPOSAL LISTING Page 2 Your ref = 341 Version #5 Last revised = 12-Jun-98 NGULAR INATES Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 11100.00 71.48 266.39 4439.78 951.92 S 9428.33 W 9476.22 836.34 40.46 97.20 85.31 11200.00 68,48 266.39 4474.01 957.83 S 9522.09 W 9570.11 844.55 40.85 98.14 85.32 11300.00 65.%8 266.39 %513.11 963.62 S 9613.94 W 9662.09 852.43 41.27 99.04 85.33 11%00.00 62.%8 266.39 4556.97 969.27 S 9703.61 W 9751.89 859.95 41.72 99.90 85.34 11500.00 59.48 266.39 4605.48 974.77 S 9790.88 W 9839.27 867.08 42.20 100.71 85.35 11600.00 56.48 266.39 4658.49 980.10 S 9875.49 W 9924.00 873.79 %2.70 101.48 85.36 116%9.38 55.00 266.39 4686.28 982.67 S 9916.21 W 9964.78 877.00 42.96 101.84 85.36 11772.67 55,00 266.39 4757.00 989.02 S 10017.01 W 10065.71 885.02 43.59 102.75 85.37 11849.38 55.00 266.39 4801.00 992.98 S 10079.72 W 10128.51 890.01 43.99 103.32 85.38 12000.00 55.00 266.39 4887.39 1000.74 S 10202.86 W 10251.82 899.80 %4.76 10%.44 85.39 12008.01 55,00 266.39 4891.99 1001.15 S 10209.41 W 10258.38 900.33 44.80 104.49 85.39 12008.03 55.00 266.39 4892.00 1001.15 S 10209.43 W 10258.39 900.33 44.80 104.49 85.39 12166.69 55.00 266.39 4983.00 1009.32 S 10339.13 W 10388.28 910.65 45.62 105.67 85.40 12273.04 55.00 266.39 5044.00 1014.80 S 10426.07 W 10475.34 917.56 46.17 106.46 85.41 12366.69 55.00 266.39 5097.72 1019.63 S 10502.64 W 10552.01 923.65 46.65 107.15 85.41 POSITION UNCERTAINTY SUMIiARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 12367 ARCO (H.A. Mag) User specified 923.65 46.65 107.15 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. All data is in feet unless otherwise stated. Coordinates from slot #341 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 10552.02 on azimuth 26%.45 degrees from wellhead. Vertical section is from wellhead on azimuth 264.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 341 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref = 341 Version #5 Last revised : 12-Jun-98 Comments in we11path MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 730.00 716.09 93.09 S 33.88 W Begin Turn to Target 1296.36 1199.00 284.25 S 244.94 W Base Permafrost 1355.57 1243.00 300.32 S 281.14 W Top West Sak Sands 2006.89 1591.84 408.60 S 809.82 W EOC 3032.31 1913.00 469.87 S 1781.73 W Base West Sak Sands 4267.96 2300.00 543.70 S 2952.88 W ? 5/8" Casing Pt 4759.67 2454.00 573.08 S 3418.93 W C80 8524.09 3633.00 798.01 S 6986.87 W C50 9012.60 3786.00 827.20 S 7449.89 W 11091.08 4436.97 951.39 S 9419.88 W Begin Angle Drop 11649.38 4686.28 982.67 S 9916.21 W End Angle Drop 11772.67 4757.00 989.02 S 10017.01 W T4 11849.38 4801.00 992.98 S 10079.72 W T3 - Top Bermuda 12008.01 4891.99 1001.15 S 10209.41 W TARGET - Mid Bermuda 12008.03 4892.00 1001.15 S 10209.43 W 2N-J(I) 331 Rvsd 8-Jun-98 12166.69 4983.00 1009.32 S 10339.13 W T2 - Base Bermuda 12273.04 5044.00 1014.80 S 10426.07 W C35 12366.69 5097.72 1019.63 S 10502.64 W TD - Casing Pt Casing positions in string ========================== .... Top MD Top TVD Rectangular Coords. Bot ND Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 4267.96 2300.00 543.?0S 2952.88W 7 5/8" Casing 0.00 0.00 0.00N 0.00E 12366.69 5097.72 1019.63S 10502.64W 5 1/2~ Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-J(I) 331 Rvsd 8-J 450324.000,5910930.000,0.0000 4892.00 1001.15S 10209.43W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N, 341 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 341 Version #5 Last revised ~ 12~Jun-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C O 0 R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 0.00N 0.00E 0.00 0.00 460537.37 5911879.23 100.00 0.00 200.00 100.00 0.00N 0.00E 0.00 0.00 460537.37 5911879.23 200.00 0.00 200.00 200.00 0.00N 0.00E 0.00 0.00 460537.37 5911879.23 250.00 0.00 200.00 250.00 0.00N 0.00E 0.00 0.00 460537.37 5911879.23 350.00 5.00 200.00 349.87 4.10S 1.49W 5.00 1.88 460535.86 5911875.14 450.00 10.00 200.00 448.99 16.36S 5.95W 5.00 7.52 460531.33 5911862.90 550.00 15.00 200.00 546.58 36.69S 13.35W 5.00 16.87 460523.83 5911842.61 650.00 20.00 200.00 641.93 64.94S 23.64W 5.00 29.86 460513.41 5911814.42 730.00 24.00 200.00 716.09 93.09S 33.88W 5.00 42.81 460503.02 5911786.32 800.00 25.07 208.03 779.78 119.57S 45.73W 5.00 57.18 460491.04 5911759.90 900.00 27.28 218.22 869.56 156.31S 69.88W 5.00 84.80 460466.71 5911723.30 1000.00 30.11 226.81 957.31 191.50S 102.37W 5.00 120.57 460434.04 5911688.27 1100.00 33.42 233.96 1042.35 224.89S 142.95W 5.00 164.21 460393.30 5911655.09 1200.00 37.06 239.90 1124.04 256.23S 191.31W 5.00 215.41 460344.78 5911624.00 1296.36 40.81 244.73 1199.00 284.25S 244.94W 5.00 271.51 460291.02 5911596.26 1300.00 40.95 244.89 1201.75 285.26S 247.09W 5.00 273.75 460288.86 5911595.26 1355.57 43.20 247.34 1243.00 300.32S 281.14W 5.00 309.11 460254.74 5911580.37 1400.00 45.03 249.14 1274.90 311.77S 309.86W 5.00 338.81 460225.96 5911569.07 1500.00 49.24 252.82 1342.92 335.57S 379.15W 5.00 410.09 460156.56 5911545.63 1600.00 53.56 256.06 1405.31 356.46S 454.42W 5.00 487.03 460081.20 5911525.12 1700.00 57.95 258.94 1461.58 374.29S 535.10W 5.00 569.07 460000.43 5911507.70 1800.00 62.40 261.57 1511.30 388.92S 620.58W 5.00 655.57 459914.89 5911493.50 1900.00 66.90 263.98 1554.11 400.25S 710.20W 5.00 745.88 459825.21 5911482.63 2000.00 71.43 266.24 1589.67 408.18S 803.30W 5.00 839.30 459732.09 5911475.17 2006.89 71.75 266.39 1591.84 408.60S 809.82W 5.00 845.83 459725.56 5911474.78 2500.00 71.75 266.39 1746.28 438.07S 1277.19W 0.00 1313.85 459258.09 5911447.69 3000.00 71.75 266.39 1902.88 467.94S 1751.10W 0.00 1788.41 458784.09 5911420.23 3032.31 71.75 266.39 1913.00 469.87S 1781.73W 0.00 1819.08 458753.46 5911418.45 3500.00 71.75 266.39 2059.48 497.82S 2225.00W 0.00 2262.96 458310.09 5911392.76 4000.00 71.75 266.39 2216.07 527.69S 2698.91W 0.00 2737.52 457836.09 5911365.29 4267.96 71.75 266.39 2300.00 543.70S 2952.88W 0.00 2991.85 457582.06 5911350.57 4500.00 71.75 266.39 2372.67 557.57S 3172.81W 0.00 3212.08 457362.08 5911337.83 4759.6? 71.75 266.39 2454.00 573.08S 3418.93W 0.00 3458.53 457115.92 5911323.56 5000.00 71.75 266.39 2529.27 587.44S 3646.71W 0.00 3686.63 456888.08 5911310.36 5500.00 71.75 266.39 2685.87 617.32S 4120.62W 0.00 4161.19 456414.08 5911282.89 6000.00 71.75 266.39 2842.47 647.19S 4594.52W 0.00 4635.75 455940.08 5911255.42 6500.00 71.75 266.39 2999.06 677.07S 5068.42W 0.00 5110.31 455466.07 5911227.96 7000.00 71.75 266.39 3155.66 706.94S 5542.33W 0.00 5584.86 454992.07 5911200.49 7500.00 71.75 266.39 3312.26 736.82S 6016.23W 0.00 6059.42 454518.07 5911173.02 8000.00 71.75 266.39 3468.86 766.69S 6490.13W 0.00 6533.98 454044.07 5911145.56 8500.00 71.75 266.39 3625.45 796.57S 6964.04W 0.00 7008.53 453570.06 5911118.09 8524.09 71.75 266.39 3633.00 798.01S 6986.87W 0.00 7031.40 453547.23 5911116.77 9000.00 71.75 266.39 3782.05 826.44S 7437.94W 0.00 7483.09 453096.06 5911090.62 9012.60 71.75 266.39 3786.00 827.20S 7449.89W 0.00 7495.05 453084.11 5911089.93 9500.00 71.75 266.39 3938.65 856.32S 7911.84W 0.00 7957.65 452622.06 5911063.15 10000.00 71.75 266.39 4095.25 886.19S 8385.75W 0.00 8432.20 452148.06 5911035.69 10500.00 71.75 266.39 4251.85 916.07S 8859.65W 0.00 8906.76 451674.05 5911008.22 11000.00 71.75 266.39 4408.44 945.95S 9333.56W 0.00 9381.32 451200.05 5910980.75 11091.08 71.75 266.39 4436.97 951.39S 9419.88W 0.00 9467.77 451113.71 5910975.75 11091.11 71.75 266.39 4436.98 951.39S 9419.91W 0.00 9467.79 451113.68 5910975.75 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #341 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 10552.02 on azimuth 264.45 degrees from wellhead. Total Dogleg for wellpath is 104.59 degrees. Vertical section is from wellhead on azimuth 264.40 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 341 Tarn Development Field,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D i N A T E S PROPOSAL LISTING Page 2 Your ref : 341 Version #5 Last revised : 12-Jun-98 Dogleg Vert G R I D C O 0 R D S Deg/100ft Sect Easting Northing 11100.00 71.48 266.39 4439.78 951.92S 9428.33W 3.00 11200.00 68.48 266.39 4474.01 957.83S 9522.09W 3.00 11300.00 65.48 266.39 4513.11 963.62S 9613.94W 3.00 11400.00 62.48 266.39 4556.97 969.27S 9703.61W 3.00 11500.00 59.48 266.39 4605.48 974.77S 9790.88W 3.00 9476.22 451105.26 5910975.26 9570.11 451011.48 5910969.83 9662.09 450919.61 5910964.50 9751.89 450829.92 5910959.31 9839.27 450742.64 5910954.25 11600.00 56.48 266.39 4658.49 980.10S 9875.49W 3.00 9924.00 450658.01 5910949.35 11649.38 55.00 266.39 4686.28 982.67S 9916.21W 3.00 9964.78 450617.27 5910946.99 11772.67 55.00 266.39 4757.00 989.02S 10017.01W 0.00 10065.71 450516.46 5910941.15 11849.38 55.00 266.39 4801.00 992.98S 10079.72W 0.00 10128.51 450453.73 5910937.51 12000.00 55.00 266.39 4887.39 1000.74S 10202.86W 0.00 10251.82 450330.57 5910930.38 12008.01 55.00 266.39 4891.99 1001.15S 10209.41W 0.00 10258.38 450324.01 5910930.00 12008.03 55.00 266.39 4892.00 1001.15S 10209.43W 0.00 10258.39 450324.00 5910930.00 12166.69 55.00 266.39 4983.00 1009.32S 10339.13W 0.00 10388.28 450194.27 5910922.49 12273.04 55.00 266.39 5044.00 1014.80S 10426.07W 0.00 10475.34 450107.31 5910917.45 12366.69 55.00 266.39 5097.72 1019.63S 10502.64W 0.00 10552.01 450030.72 5910913.01 All data in feet unless otherwise stated. Calculation uses m/nimum curvature method. Coordinates from slot #341 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 10552.02 on azimuth 264.45 degrees from wellhead. Total Dogleg for wellpath is 104.59 degrees. Vertical section is from wellhead on azimuth 264.40 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 341 Tarn Development Field,North Slope, Alaska PROPOSAL LISTIN~ Page ~ Your ref : 341 Version #5 Last revised : 12-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00N 0.00E KOP 730.00 1296.36 1355.57 2006.89 3032.31 4267.96 4759.67 8524.09 9012.60 11091.08 11649.38 11772.67 11849.38 12008.01 12008.03 12166.69 12273.04 12366.69 716.09 1199.00 1243.00 1591 84 1913 00 2300 00 2454 00 3633 00 3786 00 4436 97 4686 28 4757 00 4801 00 4891 99 4892 00 4983 00 5044 O0 5097.72 93.095 284.255 300.32S 408 605 469 875 543 708 573 085 798 015 827 205 951 395 982 675 989 025 992.985 1001.155 1001.155 1009.325 1014.805 1019.635 33.88W Begin Turn to Target 244.94W Base Permafrost 281.14W Top West Sak Sands 809.82W EOC 1781.73W Base West Sak Sands 2952.88W 7 5/8" Casing Pt 3418.93W CS0 6986.87W C50 7449.89W C40 9419.88W Begin Angle Drop 9916.21W End Angle Drop 10017.01W T4 10079.72W T3 - Top Bermuda 10209.41W TARGET - Mid Bermuda 10209.43W 2N-j(I) 331 Rvsd 8-Jun-98 10339.13W T2 - Base Bermuda 10426.07W C35 10502.64W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 4267.96 2300.00 543.705 2952.88W 7 5/8" Casing 0.00 0.00 0.00N 0.00E 12366.69 5097.72 1019.635 10502.64W 5 1/2" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-J(I) 331 Rvsd 8-J 450324.000,5910930.000,0.0000 4892.00 1001.155 10209.43W 6-Aug-97 ARCO KRU 2N 341 DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS I I J 3" 5,000 psi WP OCT r- MANUAL GATE VALVE'~ _ Li KILL LINE 3" 5,000 psi W P Shaffer GATE VALVE ] w/hydraulic actuator / J / 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 DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom CHOKE LINE ~~0 psi WP OCT ~_j~ MANUAL GATE VALVE 13-5/8" 5,000 psi WP DRILLING SPOOL h~ w/two 3" 5,000 psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe Diverter Schematic Doyon 141 Flowline 211,~,, 2,000 psi WP DRILLING SPOOL w/16" Outlet 21 lA" 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) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend _ Operation Shutdown __ Re-enter suspended well _ Alter casing _ Repair well _ Plugging __ Time extension __ Stimulate _ Change approved program __ Pull tubing __ Variance__ Perforate_ Other _~X Annular Iniection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development _~X ARCO Alaska, Inc. Exploratory _ 28' RKB feet 3. Address Stratigraphic_ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 129' FNL, 1055' FEL, Sec. 3, T9N, R7E, UM 2N~341 At top of productive interval 9. Permit number 1211' FNL, 374' FEL, Sec. 5, T9N, R7E, UM 98-103 At effective depth 10. APl number 50-103-20263 At total depth 11. Field/Pool 1233' FNL, 667' FEL, Sec. 5, T9N, R7E, UM Kuparuk River/Tarn Pool 12. Present well condition summary Total Depth: measured feet Plugs (measured) None (approx) true vertical feet Effective depth: measured feet Junk (measured) (approx) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor RECEIVED Intermediate Production Liner Perforation depth: measured dUL. 09 1998 NONE NaS~ Oil& Oas Cons. true vertical AnChorage Conllllis~ion Tubing (size, grade, and measured depth) ~UPL t F ~ Ti~.. Packers and SSSV (type and measured depth) ' 113. Attachments Description summary of proposal __ Detailed operation program ._ BOP sketch Contact James Trantham at 265-6434 with any questions. LOT test, surface cement details and ca,sing detail sheets ~ -- 14. Estimated date for commencing operation 15. Status of well classification as: July 1998 Oil 16. If proposal was verbally approved Name of approver Date approved Service__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned '~"~o..~ ~)/'~o.,,z,~,~ Title Kuparuk Drilling Team Leader Date -/lq/~ ~ ~7 d- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No.~ Plug integrity _ BOP Test Location clearance . ,, ..~ ,. ~ I Mechanical Integrity Test_ Subsequent'form require 10- ~'¢4.f Approved by the order of the Commission Original Signed By Commissioner Date Form 10-403 Rev 06/15/88 David W. Johnston ._,~ o0¢ SUBMIT IN RIP~_ICATE ARCO Alaska, Inc. Cementing Details Well Name: 2N-341 Report Date: 06/26/98 Report Number: 5 Riq Name: DOYON 141 AFC No.: AK 9469 Field: Tarn Centralizers State type used, intervals covered and spacing Comments: (42) 9 718" x 7 5/8" Gemeco bow spring, placement detail on casing talley. Mud Weight: PV(prior cond): PV(affer cond): I YP(prior cond): YP(after cond): Comments: 10.1 26 21J 20 15 Gels before: Gels after: Total Volume Circulated: 8/22 4/9 890 bbls / 680bbls Wash 0 Type: Volume: Weight: Comments: Spacer 0 Type: Volume: Weight: Comments: ARCO 30 bbls / 30 bbls 10.5 ppg 1st stage 12nd stage Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: Weight:. Yield: Comments: AS III LWI 65 1301402 10.5 ppg 4.42 1st stage ! 2nd stage Additives: Comments:. 70 240 ! 60 15.8 / 15.9 1.1710.93 1st stage G cmt 12nd stage AS1 cmt Additives: 1% S1, 0.3% D65, 0.2% D46 I# AS1 standard blend DisplaCement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 8 9 95 1st stage ! 2nd stage Reciprocation length: Reciprocation speed: Str. Wt. Down: 15 30 fpm 55 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 188.3 / 73.4 190.7 / 74.2 85 Calculated top of cement: CP: Bumped plug: I Floats held: Surface thru stage collar @ 1598'. Date:6/26/98 yes / yesI yes I yes Time:1201hrs / 1505 hfs Remarks:Stage 1: Pumped 5 bbls water, 30 bbls of 10.5 ppg spacer, 103 bbls of AS3 lite at 10.5 ppg and 50 bbls of G cmt at 15.8 ppg. Displaced with 30 bbls of 'water, 75 bbls of 10.1 ppg mud, 30 bbls of 10.5 ppg spacer and 55.7 bbls of 10.1 ppg mud. Reciprocated casing untill last 55 bbis of displacement, had full . returns while circulating and cementing. Stage 2: Pumped 5 bbls of water, 30 bbls of 10.5 ppg spacer, 316 bbls of AS3 lite and 10 bbls of AS1 cercenl, Displaced with30 bbls of water and 44.2 bbls of 10.1 ppg mud. Had full returns while circulating and cementing with 93 bbls of 10.5 ppg cement back at surface. Cement Company: Rig Contractor: I Approved By: DS DOYON I D.BURLEY I Casing Detail 7.5/8' Surface Casing ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS jts. 63-99 Lock B Lock A tis. 3-62 jts 1-2 COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 141 RKB to Pad = 30.00' Above RKB 7 5/8" Landing Joint 34' OA. FMC GEN V- Prudhoe 7 5/8" Csg Hgr 7 5/8", 29.7#, L-80 BTC-MOD 7 5/8", 29.7#, b80 BTC-MOD (Thread Locked Collar) JT. #79 Gemeco 7 5/8" Stage Collar (BAKERLOK) 7 5/8", 29.7#, 1_-80 BTC-MOD (Thread Locked Collar) JT. #105 7 5/8",29.7#, L-80 BTC-MOD (shutoff baffle on top of jt #3, BAKE Gemeco Float Collar 7 5/8", 29.7#, 1_-80 BTC-MOD Gemeco Float Shoe Insert baffle @ 4101 '. 42 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1, 2, 105, 106 over stop collars and over casing collars on Jts. 3 thru 15 and over collars of jts. 18,21,24,27,30,36,39,42,45,48,51,54,57,60, 66, 69, 72, 75, 78, 81, 84,87,90,93,96. Joints 100-104 (5 joints) will remain in the pipe shed. WELL: TARN 2N-341 DATE: 6124/98 I OF LENGTH 30.00 2.75 1522.80 42.98 2.80 42.92 2498.98 1.35 81.07 1.42 PAGES DEPTH TOPS 30.130 32.75 1555.55 1598.53 1601.33 1644.25 4143.23 4144.58 4225.65 4227.07 Remarks: String Weights with Blocks: 95K# Up, 55K# Dn, 20k# Blocks. Ran 101 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: 2N-341 Date: 6/27/98 Supervisor: D.BURLEY Casing Size and Description: 7 5/8", 29.7 ppf, L-80, BTC Casing Setting Depth: 4,227' TMD 2,301' TVD Mud Weight: Hole Depth: 8.5 ppg 2,311' TVD EMW = Leak-off Press. + MW 0.052 x TVD 900 psi 8.5 ppg LOT = (0.052 x 2,311') EMW=16.0 ppg Fluid Pumped = 1.9 bbl Pump output = 0.1000 bps 3,000 psi 2,900 psi 2,800 psi 2, 700 psi 2,600 psi 2,500 psi 2,400 psi 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 1,400 psi 1,300 psi 1,200 psi 1, i00 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 L ~' ,~' - ~-: ¥- ~, / --e-- LEAK-OFF TEST ,t' .I1[ -"~-'CASING TEST stks 2 stks 4 stks 6 stks 8 stks 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 stks stks stks stks stks stks stks stks stks stks stks stks stks stks stks stks STROKES CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-341 Date: 6/30/98 Supervisor: D.BURLEY Casing Size and Description- 7 5/8", 29.7 ppf, L-80, BTC Casing Setting Depth: 4,227' TMD 2,301' TVD Mud Weight: 9.5 ppg EMW = Hole Depth: 3,573' TVD Leak-off Press. + MW 0.052 x TVD 1,170 psi + 9.5 ppg LOT = (0.052 x 3,573') EMW=15.8 ppg Fluid Pumped = 6.6 bbl Pump output = 0.1000 bps ~, /' ~ ~ LEAK-OFF TEST Jr ~ --~'-CASING TEST _l ~.~' 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 stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stR stk stk stk stk stk stk stk stk stk stk stk stk S S S S S S S S S S S S $ S S S S S S S S S S S S S S S S S S S S S S S STROKES MEMORANDUM State of Alaska TO' Alaska Oil and Gas Conservation Commission · David John~s~:~', DATE' June 26, 1998 Chairman~ ~- THRU' Blair Wondzell, P. I. Supervisor FILE NO: abwifzfe.doc Confidential: Yes FROM: John Spaulding~.~,~,,, SUBJECT: Petroleum Ins~""' ' No X BOPE Test Doyon 141 KRU / ARCO / 2N-341 PTD 98-103 June 26, 1998' I traveled to ARCO's Kuparuk River Unit to witness the BOPE Test on Doyon Rig 141. The AOGCC BOPE test report form is attached for reference. As noted on the Test Report form I failure was observed, this being the lower kelly IBOP. Repairs were made after my departure and were reported to me by fax on June 27. Summary: I witnessed the BOPE test on, Doyon 141, test tiime 4 hours, 1 failure . , Attachments: abwlfzfe.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 7 5/8" Test: Initia X Workover: DATE: Doyon Rig No. 141 PTD# 98-103 Rig Ph.# ARCO Rep.: Dave Burley 2N-341 Rig Rep.: Bob Ingram Set (~ 4227'md Location: Sec. 3 T. 9N R. 7E Meridian UM Weekly Other TEST DATA 6126/98 659-7165 MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok PTD On Location yes Standing Order Posted BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve (Gen) yes Well Sign yes Drl. Rig ok Hazard Sec. yes Quan. Test Press. P/F P I 250/2,500 I 250/3,500 I 250/3,500 f 250/3,500 I 250/3,500 250/3,500 f 250/3,500 P P P P 2 P P MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly /IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 250/3,500 P 250/3,500 F* 250/3,500 P 250/3,500 P CHOKE MANIFOLD: No. Valves 14 No. Flanges Manual Chokes Hydraulic Chokes I Test Pressure P/F 250/3,500 P 28 250/3,500 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 5 ~ 2100 avg. 3,100 P 1,750 P minutes 52 sec. minutes ~3 sec. X Remote: X Psig. Number of Failures: '/ ,Test Time: 4.0 Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within 1 days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: * Lower Kelly IBOP valve failed, instructed tool pusher to repair or replace the valve and notify the N.S. office prior to drilling out of the shoe. '~ Received Notification from B. Ingram 6-27 on repairs to the IBOP (tested ok) js. Distribution: orig-Well File c- Database c- Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding FI-021 L (Rev.12/94) Abwlfzfe.xls TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 19. 1998 Paul Mazzolini Kuparuk Dilling Team Lcadcr ARCO Alaska. Inc. PO Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 2N-341 ARCO Alaska, Inc. Permit No 98-103 Sur. Loc.: 130'FNL, 1055'FEL, SEC. 03. T09N. R07E. UM Btmhole Loc: 1149'FNL, 998'FEL. SEC. 05, T09N. R07E. UM Dcar Mr. Mazzolini. Encloscd is the approvcd application for pcrmit to drill thc above rcfcrcnced well. Annular disposal of drilling waste will not be approved until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. A Formation Integrity Test (FIT) must confirm the adequacy of cement behind surface casing. Cementing records, FIT data, and any CQLs must be submitted to the Commission with an Application for Sund~' Approvals (form 10-403) prior to initiating disposal opcrations. Thc pcrmit to drill docs not cxcmpt you from obtaining additional pcrmits rcquircd bv law from other govcrnmcntal agcncics, and docs not authorize conducting drilling opcrations until all other rcquircd pcrmitting dctcrminations arc made. Bloxvout prcvcntion cquipmcnt (BOPE) must be tcstcd in accordancc with 20 AAC 25.035. Sufficicnt noticc (approximately 24 hours) of thc BOPE tcst pcrformcd bcforc drilling below the surface casing shoc must be given so that a representative of thc Commission may witness the tcst. Notice may be given by contacting thc Commission pctrolcum ficld inspector on the North David W. I~hnston '~ ~...._._~_ x% Chairman BY ORDER OF THE COMMISSION dlf'enclosures I)eparhnent of Fish & Game. ttabitat Section w:o encl. Department of Enviromnental Conservation w:o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Reddll J lb Type of Well Exploratory F'I StratigraphicTest U Development Oil X Re-Entry DeepenI Serv~ent Gas r~ Single Zone X Multiple Zone [--] 2. Name of Operator j~'r 5. Datum Eleva'{~ (DF or KB) , 10. Field and Pool RKB 28', Pad ~,~' ~, ,~..,,,fe~,.t~, Kuparuk River Field ARCO Alaska, Inc. 3. Address41~/'~' ii 6. Property ~--e~ign~ll~°n ~/ rt~.,~,~- ~- _-".,. ,<.-,~ j.,~'~Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 37507,,'K', ALK41 .)93 4. Location of well at surface ~ ~ Unit or property Nr- :ne 11. Type Bond (see 20 AAC 25.025) 130' FNL, 1055' FEL, Sec. 3, T9N, R7E, UM ~..K~ver Unitj Statewide At top of productive interval (@ TARGET ) 8. '~,I~~/ Number 1131' FNL, 705' FEL, Sec. 5, T9N, R7E, UM 2N-341 ~' #U-630610 At total depth 9. Approximate s~ud date Amount / 1149' FNL, 998' FEL, Sec. 5, T9N, R7E, UI~ 6/1~/98 $200,000 12. Distance to nearest 13. Distance to nea~st well 14. Number of ,~cres in property 15. Proposed depth (MD and TVD) property line 2N-343 I / 12367' MD 705' @ Tar~let feet I 25' @ 425' ,] L feet 2~60 'L 5098' TVD feet 16. To be completed for deviated wells ~ 17. Anticipated press ~re (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole an(. e 71.75° -'~,,~mum surface j 660 psig At total depth 2350 psig (TVD) 18. Casing program L~ ~i~pth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling' ngth MD TVD MD TVD (include stage data) 20" 16" Weld 80'~ LmR' 28' ~ r108' 108' +_230 sx Permafrost cement 9.875" 7.625" 29.7# L-80 BTC MOL4~'r 28'-~ 28'~ 4268' 2300' 1.90 Sx AS IIIL, 240 sx CIG /' ~ / 2. 310 sx ASIIIL,60 Sx CIG 6.75" 5.5" 15.5# L-80 LTC-Mod ~Ca~l' 28'28-~ ! 11649' 4686' 230 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUEf 718''~ 11649' 468~i1~ 12367' 5098'. (included above) 19. To be completed for Reddll, Re-entry, and Des ~n Operations. Present well condition summary, Total depth: measured ~. feet Plugs j neasured) Effective depth: measured fee unk (measured) true vertical feet Casing SurfaceC°nduct°rStructuralLinerPrOductionlntermediate Length ~i ''~- i.. i . ~:II.-' ::"~!_:.':~ ! '~'~/~ ~." ..-:'ii' . . Measured depth True Vertical depth i Perforation depth: measured ~ ..... ; . true vertical i:'; ', ~¥:',:~' ~ '. ~ 20. Attachments Filing fee X Property plat [] BOP Sketch [] Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Kuparuk Drilling Team Leader Date Signed '~/'~.,.,~/~/'?~,~~~_~ Commission Use Only Permit Nu. mber I APl number I Approval date qu~i e!~l~ I See cover letter for c~ (~-.- .~ 0~ 50- ~ r0 '~ - ~ 0 ~ (~ ~' other requirements Conditions of approval Samples required ~] Yes [~ No Mud log re [-~ Yes J~ No Hydrogen sulfidemeasures i---lYeS [~No~ Directional surveyrequired [~]Yes F-1 No ...u,re. wor*,n pressure fo..O..,.tm,,--rmt 2 F1 FI 10M Fl Other u.,- ~-~ ~l,''-'~'~,'~ ' by order of Approved by ,-'-'3' ..... ,;,~t,~;u ~? Commissioner the commission Date ,~ , ~ ! : . . ~ q~ ...... Form 10-401 Rev. 7-24-89 0avid W. J0i ns[0n mit in triplicate TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION May 27, 1998 Paul Mazzolini Drilling Team Leader 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 Rc: Kuparuk River Unit 2N-341 ARCO Alaska. Inc. Permit No 98-103 Sur. Loc.: 130'FNL. 1055'FEL. Sec. 3. T9N. R7E. UM Btmholc Loc: 2450'FSL. 417'FWL. Sec. 4. T9N. R7E. UM Dcar Mr. Mazzolini' Enclosed is thc approvcd application for permit to drill thc abovc rcfcrcnccd xvcll. Thc permit to drill docs not exempt you from obtaining additional permits required by lax,,' from other governmental agencies, and docs not authorizc conducting drilling opcrations until all other required permitting determinations arc made. Approval of annular disposal of drilling wastes is contingent on obtaining a well cemented surface casing confirmcd by a valid Formation Integrity Tcst (FIT). Ccmcnting rccords. FIT data. and any CQLs must bc submitted to thc Commission on form 10-403 to ensure thc requirements of 20 AAC 25.080 arc met prior to initiating disposal operations. Blowout prcvcntion cquipmcnt (BOPE) must bc tested in accordance with 20 AAC 25.035. Sufficient notice (approximatcly 24 hours) of thc BOPE test pcrformcd bcforc drilling below the surface casing shoc must bc givcn so that a representative of thc Commission may witncss thc test. Notice ma5; be given bv contacting thc Commission petroleum field inspector on the North David W. JOtl~ston Chairman BY ORDER OF THE COMMISSION dlf/cnclosurcs cc: Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation xv/o cncl. STATE OF ALASKA '-' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL la. Type of Work Drill X Redrill [] I lb. Type of Well Exploratory [] Stratigraphic Test [] Developrflef~t'--~l Re-Entry [] Deepen []I 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 121' feet Kuparuk River Unit 3. Address 6. Property Designation Tarn Pool P. O. Box 100360, Anchorage, AK 99510-0360 ALK 4293 ADL 375074 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 130' FNL 1,055' FEL Sec 3 T9N R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2,506' FSL, 625' FWL Sec. 4, T9N, R7E, UM 2N 341 #U-630610 At total depth 9. Approximate spud date Amount 2,450' FSL, 417' FWL Sec. 4, T9N, R7E, UM 616198 $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 2N 343 MD 11,428' 417' @ BHL feet 2,000' feet 2,560 TVD 5,139' feet 16. To be completed for deviated wel s 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 71 o Maximum ~u~face 1,660 psig At total depth (TVD) 2,350 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" Welded 80' 28' 28' 108' 108' 230 sx Permafrost Cement 9-7/8" 7-5/8" 29.7 ppf L-80 BTC-Modl 3,730' 28' 28' 3,730' 2,300' 1. 100 sx AS3L, 240 sx Cl G 2. 260 sx AS3L, 60 sx AS 1 6%" 5½" 15.5 ppf L-80 LTC-Mod 10,866' 28' 28' 10,866' 4,778' 190 sx Cl G 6%" 3½" 9.3 ppf L-80 8rd EUE 562' 10,866' 4,778' 11,428' 5,139' (included above) 19. To be completed for Redrill, Re-entry, and :)eepen Operalions. 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 K [ ~! PeRoration 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 [] Refraction analysis [] Seabed report [] 20AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Drilling Team Leader. Date PermitNumber._~?_/O. ~ I I Approval date ,~,~_ ¢~ other requirements I APl number _ _ 50- /(:::~ .- ~_.0 ~ ,~' I Cond~tiohs of approval Samples required [] Yes ~ No Mud log required [] Yes ,,~ No Hydrogen sulfide measures E]Yes ~ No Directional survey required /~] Yes [] No Required workingpressureforBOPE [] 2M ~ 3M [] 5M [] 10M [] 15M Other: Ori[~ina! Signed By Approved by David W. Johnston Commissioner the commission Bate ~' "~ ~-'~ .~ ~hmit in trinlir,~f¢, Form 10-401 Rev. 7-24-89 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 THE APPLICATION OF ARCO ) ALASKA, INC.for an order granting ) an exception to spacing requirements of ) 20 AAC 25.055(a)(3) to provide for the ) drilling of the Tarn 2N-341, 2N-337, 2N-339 and 2N-345 oil wells to an undefined pool adjacent to the western ) boundary of the Kuparuk River Unit. ) Conservation Order No. 428 ARCO Alaska, Inc. Tarn 2N-341.2N-337.2N-339 and 2N-345 Mav 22, 1998 IT APPEARING THAT: ARCO Alaska, Inc. in correspondence dated April 30. 1998 and Mav 5. 1998, requested exception to the well spacing provisions of 20 AAC 25.055(a)(3). The exception would allow drilling the Tarn 2N-341, 2N-337, 2N-339 and 2N-345 oil wells to a bottomhole location that is closer than 500 feet from a quarter section line. 2. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on May 6. 1998 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: The Tarn 2N-341 oil well will be drilled as a directional hole from a surface location 130' fi'om the north line (FNL), 1055' from the east line (FEL), Section 3, T9N. R7E, Umiat Meridian (UM) to a target location of 2506' from the south line (FSL), 624' from the west line (FWL), Section 4. T9N, R7E, UM, and a bottomhole location of 2161' FSL, 672' FEL, Section 5, T9N, R7E, UM. . The Tarn 2N-337 oil well will be drilled as a directional hole from a surface location 117' FNL. 997' FEL. Section 3, T9N, R7E, UM to a target location of 1032' FSL. 2421' FEL. Section 4, T9N. R7E. UM, and a bottomhole location of 572' FSL. 2047' FWL. Section 4. T9N. R7E, UM. . The Tam 2N-339 oil well will be drilled as a directional hole from a surface location 123' FNL. 1026' FEL, Section 3, T9N, R7E, UM to a target location of 2258' FNL, 616' FEL. Section 4. T9N. R7E, UM, and a bottomhole location of 2462' FNL, 1144' FEL, Section 4. T9N. R7E, UM. . The Tarn 2N-345 oil well will be drilled as a directional hole from a surface location 144' FNL. I 113' FEL, Section 3, T9N, R7E, UM to a target location of 605' FNL. 118' FWT. Section 3. T9N. R7E, UM, and a bottomhole location of 635' FNL. 289' FEL, Section 4. T9N. R7E. UM. Conservation Order No.' 428 May 22, 1998 Page 2 5. Offset owners BP Exploration (Alaska) Inc., Chevron U.S.A. Inc.. Mobil Oil Corporation, UNOCAL Alaska Resources and the State of Alaska have been duly notified. 6. An exception to the well spacing provisions of 20 AAC 25.055 (a)(3) is necessary, to all the drilling of these wells. CONCLUSION: Granting a spacing exception to allow drilling of the Tam 2N-341, 2N-337.2N-339 and 2N-345 oil wells will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: ARCO Alaska's applications for exception to the well spacing provisions of 20 AAC 25.055 ('a)(3) for the purpose of drilling the Tarn 2N-341, 2N-337.2N-339 and 2N-345 oil wells are approved. DONE at Anchorage, Alaska and dated May 22, 1998. )n. Commissioner Alaska Oil and Gas Conservation Commission Camill~ Oechsli, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry, of an order, a person affected by it may file xvith the Commission an application Ibr rehearing. A request for rehearing must be received by 4:30 PM on the 2? da5' following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request tbr rehearing is denied bv nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e.. 10th day after the application for rehearina was filed). ARCO Alaska, Inc. '= ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 2?6 1215 Date: May 2l, 1998 To: Blair Wondzell Subject: 2N-341 Drilling Permit Application Leak Off Test This memo is in regard to our discussion today concerning Icakufftusts for the subject well, Thc drilling procedure indicates that a LOT will be attempted alter drilling 20' below the surface easing shoe. if leak off is established at a 16.0 lb/gal equivalent or below no additional LOT would be done. However, if leakoff is not established at the 16_0 lb/gal equivalent maximum, our plans arc to do an open hole LOT taken to fracture prior to drilling the productive formation. This plan h~s b~en used on previous Tm'n development wells, This procedure is done to suppport o~ request for anllular di.~po.~al. Regards; Fred John on~ Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Tarn accumulation development wells 2N-341 ') .... " . · ..~n-oo/, 2N-339 and 2N-345 ARCO Alaska, Inc. by letter dated April 30, 1998 and May 5. 1998. has requested an exception to the provisions of 20 AAC 25.055(a)(3) for the drilling of four deviated oil wells to an undefined pool adjacent to the western boundarv of the Kuparuk River Unit. The first exception ~vould allow ARCO Alaska. Inc. to drill the Tarn 2N-341 oil well to a bottomhole location that is closer than 500 feet from a quarter section line. The ~vell will be drilled as a directional hole from a surface location 130' from the north line (FNL), 1,055' from the east line (FEL), Section 3, T9N, RTE. Umiat Meridian (UM) to a target location of 2.506' from the south line (FSL), 624' from the west line (FWL). Section 4, T9N, R7E, UM, and a bottomhole location of 2,161' FSL. 672' FEL. Section 5. T9N, R7E. UM. The second exception would allow ARCO Alaska, Inc. to drill the Tarn 2N-337 oil well to a bottomhole location that is closer than 500 feet from a quarter section line. The well will be drilled as a directional hole from a surface location 117' FNL, 997' FEL, Section 3, T9N, R7E. UM to a target location of 1.032' FSL, 2,421' FEL. Section 4. T9N, R7E, UM, and a bottomhole location of 572' FSL. 2.047' FWL, Section 4. T9N. R7E. UM. The third exception would allo~v ARCO Alaska, Inc. to drill the Tarn 2N-339 oil well to a bottomhole location that is closer than 500 feet from a quarter section line. The xvell will be drilled as a directional hole from a surface location 123' FNL, 1,026' FEL, Section 3. T9N. R7E. UM-to a target location of 2,258' FNL, 616' FEL. Section 4. T9N, R7E, UM, and a bottomhole location of 2,462' FNL. 1.144' FEL, Section 4. T9N. R7E. UM. The fourth exception would allow ARCO Alaska, Inc. to drill the Tarn 2N-345 oil ~vell to a bottomhole location that is closer than 500 feet from a quarter section line. The well will be drilled as a directional hole from a surface location 144' FNL. 1.113' FEL, Section 3. T9N. R7E. UM to a target location of 605' FNL. 118' FWL. Section 3. T9N. R7E. UM. and a bottomhole location of 635' FNL. 289' FEL. Section 4. T9N. R7E. UM. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM, May 21, 1998, xvith the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501. and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter xvill be held at the above address at 1:00 PM on June 4, 1998, in conformance with 20 AAC 25.540. If a hearing is to be held. interested parties may confirm this by calling the Commission's office, (907) 279-1433 after May 21. 1998. If no protest is filed, the Commission will consider the issuance of the order without a hearing. If vou are a person with a disabilitv xvho may need a s~on in order to comment or to atten~t the public hearing, 998. David W.(,~.ohnston ~ Chairman Published May 6, 1998 ADN AO02814046 WELL PERMIT CHECKLIST COMPANY ,,,Z~r'c. ~ WELL NAME /~.',,~9,~, 2/4'?/ ,.~gz/,/ PROGRAM: exp [] dev~/redrll [] serv [] wellbore seg F_] ann. disposal para req E~ INITCLASS ,/"~ FIELD & POOL ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING GEOL AREA ~ ~"4~ UNIT# ~ ,~, ON/OFF SHORE Y N ~' ' ' " V~~/-- : ..... v- - Y N Y N Y N Y N Y N Y N N APPR DATE 14. Conductor string provided ................... Y N 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ Y N 18. CMT will cover all known productive horizons .......... Y N 19. Casing designs adequate for C, T, B & permafrost ....... Y N 20. Adequate tankage or reserve pit ................. Y N 21. Ifa re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. Y N 23. If diverter required, does it meet regulations .......... Y N 24. Drilling fluid program schematic & equip list adequate ..... Y N 25. BOPEs, do they meet regulation ................ Y N 26. BOPE press rating appropriate; test to psig. Y N 27. Choke manifold complies w/APl RP-53 (May 84) ........ Y N 28. Work will occur without operation shutdown ........... Y N 29. Is presence of H2S gas probable ................. Y N 30. Permit can be issued w/o hydrogen sulfide measures ..... ~YY N //r /.,,~ 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. GEOLOGY 34. Con, tact,nam, e/phon,e.for weekly progress reports ....... Y N ! expmra~ory omyj ANNULAR DISPOSAL 35. APPR DATE 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 not impair mechanical integrity of the well used for disposal; Y N (P) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UlC/Annular B EW~'~'[~,/ WM Jdh ? COMMISSION: DWJ RNC co Comments/Instructions: M:cheklist rev 05~29~98 dlf:C:\msoffice\wordian\diana\checklist CHECKLIST COMPANY ~r~ (~ (~ WELL NAME · WELL PERMIT FIELD & POOL INIT CLASS ~,, ~ Lt. ,,~/'J '~ ~ I PROGRAM: exp [] dev~edrll [] serv [] wellbore seg LI ann. disposal para req/~ I GEOL AREA ~ c~ 0 UNIT# /L/, ~ , ON/OFF SHORE ADMINISTRATION 1. . 3. 4. 5. 6. 7. 8. 9. 10. 11 DA-IL-E ~-~ 12. I'~ 8w~ ¢ 13. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. · Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for 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. ROPEs, do they meet regulation ................ 26. ROPE 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 ................. GEOLOGY A~ DATE .., 30. Permit can be issued w/o hydrogen sulfide measures, , .~..:....,_..,.~' 31. Data presented on potential overpress~ ..... 32. Seismic analysis of shallow g~ ............ 33. Seabed condition~u~:ve~ff-shore) ............. 34. C~pr gress reports ....... xploratory only] (~N Y N (~_. N N ~) N Y N Y N Y N yU,/l ] ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (.,,~ N (B) will not contaminate freshwater; or cause drilling waste... CY,) N to surface; (C) will not impair mechanical integrity of the well used for disposal; ~ N (D) will not damage producing formation or impair recovery from a ~ N pool; and 20 AAC 25.252 or 20 AAC 25.412. (Y~ N will not circumvent G E O%~.O,...G Y: ENGINEERING: ~l~dl~r COMMISSION: RPC'~ BEV~/'~6 ~'I~/~I~~#'"' RNcDWJ CO Comments/Instructions: M:chel~list rev 05/29/98 dlf: C :\rnsoffice\wordian\diana\cl'~ecklist 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 Sep 24 16:50:01 1998 Reel Header Service name ............. LISTPE Date ................. ' .... 98/09/24 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 ..................... 98/09/24 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, TARN 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: WELL CASING RECORD MWD RUN 2 AK-MM-80268 R. KRELL D. BURLEY SEP ~ 0 '~998 A~a C~i & Gas ¢o,~s. CQmmissior~ 2N-341 Anchorage 501032026300 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 24-SEP-98 MWD RUN 3 AK-MM-80268 K. FERGUSON D. BURLEY MWD RUN 3 AK-MM-80268 K. FERGUSON D. BURLEY 3 9N 7E 130 1055 148.80 147.30 120.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (ET) 1ST STRING 2ND STRING 16.000 108.0 3RD STRING 9.875 7.625 4227.0 PRODUCTION STRING 6.750 12339.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2 AND 3 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD) . 4. A MEASUREMENT AFTER DRILLING (MAD) PASS WAS PERFORMED FOLLOWING MWD RUN 3. THE HOLE WAS LOGGED FROM 12250'MD, 5154'TVD TO l1650'MD, 4846'TVD WHILE PULLING OUT OF THE HOLE. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION WITH DOUG HASTINGS OF ARCO ALASKA, INC. ON 08/10/98. 6. MWD RUNS 1 THRU 3 REPRESENT WELL 2N-341 WITH AN API# 50-103-20263-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12339'MD, 5194'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 = COMPENSATED THERMAL NEUTRON SANDSTONE POROSITY. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (BEST BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (BEST BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (BEST BIN). SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES LABELED "-M" DENOTE MAD DATA. ENVIRONMENTAL PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: 6.75" MUD WEIGHT: 8.5 TO 10.0 PPG FORMATION WATER SALINITY: 19149 PPM CHLORIDES MUD FILTRATE SALINTY: 500-700 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/24 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. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE ROP PEF FET RPD RPM RPS GR RPX DRHO RHOB NCNT FCNT NPHI $ START DEPTH 4100.0 4200.0 4200.0 4200.0 4200.0 4200.0 4200 0 4200 0 4203 0 4203 0 4205 0 4205 0 4205 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 12339.0 12232.5 12252.0 12252.0 12252.0 12252.0 12245.0 12252.0 12232.0 12232.0 12216.0 12216.0 12216.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 4240.0 6006.0 3 6006.0 12339.0 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 Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR NPHI MWD PU-S FCNT MWD CNTS NCNT MWD CNTS RHOB MWD G/C3 DRHO MWD G/C3 PEF MWD BARN 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 12 16 20 24 28 32 36 40 44 48 52 4 5 6 7 8 9 10 11 12 13 14 Name Min Max DEPT 4200 12339 ROP 0.02 5090.63 GR 33.57 232.8 RPX 1.6 2000 RPS 1.33 2000 RPM 0.33 2000 RPD 0.23 2000 FET 0.51 68.15 NPHI 12.64 50.56 FCNT 150.94 993.87 NCNT 1918.02 42710.6 RHOB 0.58 4.02 DRHO -1.7 1.63 PEF 0.24 11.52 Mean Nsam 8269.5 16279 175.787 16279 119~352 16091 6.08968 16105 7.01665 16105 12.1012 16105 8.76179 16105 1.95806 16105 38.1058 16023 233.735 16023 25033.8 16023 2.31467 16059 0.0930129 16059 2.5717 16066 First Reading 4200 4200 4200 4200 4200 4200 4200 4200 4205 4205 4205 4203 4203 4200 Last Reading 12339 12339 12245 12252 12252 12252 12252 12252 12216 12216 12216 12232 12232 12232.5 First Reading For Entire File .......... 4200 Last Reading For Entire File ........... 12339 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE PEF DRHO NCNT FCNT NPHI GR RHOB RPD RPM RPS RPX RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: .5000 START DEPTH STOP DEPTH 11650.0 12150.0 11650.0 12150.0 11650.0 12150.0 11650.0 12150.0 11650.0 12150.0 11650.0 12150.0 11651.0 12150.0 11651.0 12150.0 11651.0 12150.0 11651.0 12150.0 11651.0 12150.0 11739.5 12249.5 MAD RUN NO. MAD PASS NO. MERGE TOP 3 1 11650.0 MERGED MAD 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 MERGE BASE 12249.5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68' 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 NPHI MAD PU-S 4 1 68 32 9 FCNT MAD CNTS 4 1 68 36 10 NCNT MAD CNTS 4 1 68 40 11 DRHO MAD G/C3 4 1 68 44 12 PEF MAD BARN 4 1 68 48 13 RHOB MAD G/C3 4 1 68 52 14 First Name Min Max Mean Nsam Reading Last Reading DEPT 11650 12249.5 11949.8 1200 RAT 0.74 461.43 173.551 1015 GR 89.43 227.29 131.413 1001 RPX 1.71 57.34 13.9339 999 RPS 1.72 58.8 15.1193 999 RPM 1.77 58.36 14.9016 999 RPD 1.77 60.36 15.5241 999 FET 3.2495 16 9.82185 1188 NPHI 14.25 40.98 30.9935 1001 FCNT 218.46 850.52 316.086 1001 NCNT 24528.4 39591.2 27733.6 1001 DRHO 0 1.02 0.393796 1001 PEF 2.4 4.55 3.14238 1001 RHOB 1.78 3.38 2.37122 999 11650 11739.5 11650 11651 11651 11651 11651 11656 11650 11650 11650 11650 11650 11651 12249.5 12249.5 12150 12150 12150 12150 12150 12249.5 12150 12150 12150 12150 12150 12150 First Reading For Entire File .......... 11650 Last Reading For Entire File ........... 12249.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/24 Maximum Physical Record..65535 File Type ............ ~...LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM RPD FET ROP GR PEF DRHO 2 .5000 START DEPTH 4200 0 4200 0 4200 0 4200 0 4200 0 4200 0 4200 0 4203 0 4203 0 STOP DEPTH 5918.5 5918.5 5918.5 5918.5 5918.5 6006.0 5911.5 5900.0 5900.0 RHOB 4203.0 NCNT 4205.0 NPHI 4205.0 FCNT 4205.0 $ 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 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): 5900.0 5883.5 58883.5 5883.5 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 28-JUN-98 5.07 5.46 MEMORY 6006.0 4240.0 6006.0 68.3 73.4 TOOL NUMBER P1029RM4 P1029RM4 P1032NL4 P1032NL4 6.750 6.8 LSND 8.80 42.0 9.0 450 8.2 2.200 2.300 2.000 3.000 .0 24.5 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 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-S 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/C3 4 1 68 44 12 DRHO MWD 2 G/C3 4 1 68 48 13 PEF MWD 2 BARN 4 1 68 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Min 4200 0.03 33.57 1.6 1.33 0 33 0 23 0 51 15 34 150 94 5096 85 -0 42 -2 55 0 24 First Max Mean Nsam Reading 6006 5103 3613 4200 5090.63 220.915 3613 4200 202.77 107.192 3424 4200 2000 8.85106 3438 4200 2000 12.5479 3438 4200 2000 36.4031 3438 4200 2000 19.8815 3438 4200 68.15 2.66506 3438 4200 49.17 42.3228 3358 4205 657.05 183.919 3358 4205 35971.8 22322.2 3358 4205 3.72 2.17901 3395 4203 1.22 0.0469529 3395 4203 10.63 1.63683 3395 4203 Last Reading 6006 6006 5911.5 5918.5 5918.5 5918.5 5918.5 5918.5 5883.5 5883.5 5883.5 5900 5900 5900 First Reading For Entire File .......... 4200 Last Reading For Entire File ........... 6006 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/24 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 5884.0 12216.0 FCNT 5884.0 12216.0 NPHI 5884.0 12216.0 PEF 5900.5 12232.0 DRHO 5900.5 12232.0 RHOB 5900.5 12232.0 GR 5912.0 12245.0 FET 5919.0 12252.0 RPD 5919.0 12252.0 RPM 5919.0 12252.0 RPS 5919.0 12252.0 RPX 5919.0 12252.0 ROP 6007.0 12339.0 $ 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 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 MUD TYPE: 03-JUL-98 5.07 5.46 MEMORY 12339.0 6006.0 12339.0 53.8 73.0 TOOL NUMBER P1029RM4 P1029RM4 P1032NL4 P1032NL4 6.750 6.8 LSND 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 10.00 51.0 9.5 60O 4.7 2.750 1.870 3.100 2.200 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 RPX MWD 3 OHMM 4 1 68 12 4 RPS MWD 3 OHMM 4 1 68 16 5 RPM MWD 3 OHMM 4 1 68 20 6 RPD MWD 3 OHMM 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8. NPHI MWD 3 PU-S 4 1 68 32 9 FCNT MWD 3 CNTS 4 1 68 36 10 NCNT MWD 3 CNTS 4 1 68 40 11 RHOB MWD 3 G/C3 4 1 68 44 12 DRHO MWD 3 G/C3 4 1 68 48 13 PEF MWD 3 BARN 4 1 68 52 14 47.8 First Name Min Max Mean Nsam Reading DEPT 5884 12339 9111.5 12911 5884 ROP 0.02 2959.14 162.926 12665 6007 GR 43.73 232.8 122.638 12667 5912 RPX 1.68 65.98 5.3398 12667 5919 RPS 1.68 60.98 5.53051 12667 5919 RPM 1.74 57.41 5.50529 12667 5919 RPD 1.79 57.65 5.6946 12667 5919 Last Reading 12339 12339 12245 12252 12252 12252 12252 FET 0.57 41.12 1.76617 12667 NPHI 12.64 50.56 36. 9877 12665 FCNT 153.27 993.87 246. 944 12665 NCNT 20806.9 42710.6 25746 12665 RHOB 2 4.02 2. 35024 12664 DRHO -0.07 1.63 0.1047 12664 PEF 0.72 11.52 2. 81575 12664 5919 5884 5884 5884 5900.5 5900.5 5900.5 12252 12216 12216 12216 12232 12232 12232 First Reading For Entire File .......... 5884 Last Reading For Entire File ........... 12339 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 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 PEF DRHO NCNT FCNT NPHI GR RHOB RPD RPM RPS RPX FET RAT $ .5000 3 1 START DEPTH 11650 0 11650 0 11650 0 11650 0 11650 0 11650 0 11651 0 11651 0 11651 0 11651 0 11651 0 11656 0 11739.5 STOP DEPTH 12150.0 12150.0 12150.0 12150.0 12150.0 12150.0 12150.0 12150.0 12150.0 12150.0 12150.0 12249.5 12249.5 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 RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ 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 ....................... 03-JUL-98 5.07 5.46 MEMORY 12339.0 6006.0 12339.0 53.8 73.0 TOOL NUMBER P1029RM4 P1029RM4 P1032NL4 P1032NL4 6.750 6.8 LSND 10.00 51.0 9.5 600 4.7 2.750 1.870 3.100 2.200 .0 47.8 Datum Specification Block sub-type...0 Name DEPT GR RPX RPS RPM RPD NPHI FCNT NCNT DRHO PEF RHOB RAT FET Service Order Units Size Nsam Rep FT 4 1 68 MAD 3 API 4 1 68 MAD 3 OHMM 4 1 68 MAD 3 OHMM 4 1 68 MAD 3 OHMM 4 1 68 MAD 3 OHMM 4 1 68 MAD 3 PU-S 4 t 68 MAD 3 CNTS 4 1 68 MAD 3 CNTS 4 1 68 MAD 3 G/C3 4 1 68 MAD 3 BARN 4 1 68 MAD 3 G/C3 4 1 68 MAD 3 FT/H 4 1 68 MAD 3 HOUR 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 GR RPX RPS RPM RPD NPHI FCNT NCNT DRHO PEF RHOB RAT FET Min 11650 89 43 1 71 1 72 1 77 1 77 14 25 218 46 24528.4 0 2.4 1.78 0.74 3.2495 Max Mean Nsam 12249.5 11949.8 1200 227.29 131.413 1001 57.34 13.9339 999 58.8 15.1193 999 58.36 14.9016 999 60.36 15.5241 999 40.98 30.9935 1001 850.52 316.086 1001 39591.2 27733.6 1001 1.02 0.393796 1001 4.55 3.14238 1001 3.38 2.37122 999 461.43 173.551 1015 16 9.82185 1188 First Reading 11650 11650 11651 11651 11651 11651 11650 11650 11650 11650 11650 11651 11739.5 11656 Last Reading 12249.5 12150 12150 12150 12150 12150 12150 12150 12150 12150 12150 12150 12249.5 12249.5 First Reading For Entire File .......... 11650 Last Reading For Entire File ........... 12249.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/09/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Technical Services Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/09/24 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
