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201-024
Imag~i' ~roject Well History' File Cover i .ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _~0_/_ - _0 ~,,'~ Well History File Identifier RESCAN _ D,~,~ITAL DATA [] Color items: Iz~ Diskettes. No. ~ OVERSIZED (Scannable) [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL~INDY [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYI(~WINDY Scanning Preparation L~x 30 = ~'~,~+. BY: BEVERLY ROBIN VINCENT SHERY,~WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: .-'~ YES BY: I Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: __ YES (SCANNING IS coMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNEDB?'; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: ~SI Quality Checked 12/10/02Rev3NOTScanned.wpd • COI'lOC ~ ~ ~ oPh~llips Alaska F.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 • S~P 0 2 2009 A1~~k~ 9i! ~ C,~~ ~~r~~e .Go 'ssion An~hor~ a,p I- D~~- ,~~~.p3 ,~ E~ 1~,t~°~ 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 cement if needed 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 cement was pumped August 15~' and 23rd 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;~ and 29~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions Sincerely, ~ ~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ~` ~ ~, ~,,~ ~ ~ ~~~~ ~ ~ ~k ~sEf' ~~ ~ ?fln~~ ConocoPhillips Alaska Inc. ~i~ , °~ ~~ ~ ~ e-~ ~,~tC3?~?39cSrg~=:~E ~~~.>~..~ ~~R~ ~ ~ ~ sa`• t.:. ~i4<?RFq;,€ , Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field ell Name PI # TD # Initiai top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor , ~ Corrosion inhibitod sealant date ft bbls ft al 1J-03 50029230020000 2010240 22" N!A 22" N/A 4.1 8/29/2009 iJ-09 50029230060000 2010440 28" N/A 28" N/A 6.2 8/29/2009 1 J-10 50029230100000 2010710 12" N/A 12" N/A 2.3 8/29/2009 1J-133 50029233150000 2061060 3' N/A 3' N/A 23.8 8/30/2009 3~-24 50103201450000 1901340 18" N/A 18" N/A 5.1 8/30/2009 1A-19 50029221110000 1901610 30" N/A 30" N/A 3.8 8/30/2009 2Z-04 50029209650000 1830860 19" N/A 19" NJA 3.5 8l30/2009 2Z-05 50029209560000 1830760 12" N/A 12" N/A 2.1 8/30/2009 2Z-07 50029209460000 1830640 9" N/A 9" N/A 8.5 8/30/2009 2Z-15 50029213620000 1851080 9" N/A 9" N/A 2.8 2Z-21 50029218770000 1881250 3' N/A 3' N/A 19.6 8/30/2009 1J 3G 1A & 2ZPAD • 1/i/LL L.~G' ?°~~4 /1//t/1/1~l"~4 L 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 130 West International Airport Road ~i~,~~~~~`t:. ~~,~~ ~'. ~` ~~~ Suite C Anchorage, AK 99518 Fay (907) 245-8952 1) leak Detection - WLD 28-Dec-08 1 J-03 1 Color Log / EDE 50-029-23002-00 2) ~o r- oa~-i t~-3~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-IYIAIL: Kscl~~rma~lyoracl~Cc~en~anorylocy.colri WEBSITE:~rvwvd.~nvmr~o~°ydoe~.i;~rr3 ~~ C:\DocumenTs and Settings\Owne[\Desktop\Transmit_Conoco.docx Page 1 of 1 • i Regg, James B (DOA) Pi1rj 2C~ ~ z,~,Z~=- From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, October 11, 2008 9:31 AM ~ f G~ t ~~~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) ~~~(~( Attachments: 1J-03 Schematic.pdf; 1J-03 90 day TIO.jpg Tom & Jim Kuparuk gas lifted producer 1 J-03 (PTD 2010240), failed a TIFL on 10/10/08 and has been added to the SCP report. The TIO immediately prior to SI for the TIFL was 190/1345/200. A leaking GLV check is suspected. Slickline will troubleshoot the tubing leak and repair if possible. ''--' Attached are the schematics and 90 day TIO plots. Please let me know if you have any questions. «1J-03 Schematic.pdf» «1J-03 90 day TIO.jpg» Perry L Greenwood Problem Wells Supervisor 659-7224 10/13/2008 N M O ~ i ~ ~"' O '-' N ,,w~ Q ~r a ;~ ~ ,~ 'Cc~rx~c©F#~illi s ' I KUP Well Attributes __ _ ~ 1J-03 I Walloore i~Fb UVrI F Id Name _ Well Status Inclination (-) MD (NKB) (oral ~eptn (rthB) '. ~ ~ J • 500292300261 KUPARUK RIVER UNIT PROD 102.50 13,585.99 13,585.0 Comment H25 (ppm) Data Annotation End Date KB-Grd (k) Rig Releaae Deta - ---- - SSSV: NIPPLE ... 85 7/1/2008 Last WO: 9/6/2005 39.51 3!7/2001 `„ ii~_ ,, -- -- ~ r. A t lion Daplh (NKB) Entl Date Annotation Entl Date 4L st Tag: 11,992.0 7/11/2005 Rev Reason: PU LL DIVERTE R TRAY 9/3/2008 ___ Casln Strings 'CONDUCTOR, 120 SSSV, 539 GAS LIFT, - - - Casing Description OD (in) ID (in) Top (NKB) Sat Deplh (kKB) Sel Depth (ND) (kKB) Wt (Iba/k) Oratle Top Thread CONDUCTOR 20 19.020 0.0 120.0 120.0 91.50 H-40 WELDED SURFACE 9 5/8 8.697 0.0 7,784.0 4,269.8 40.00 L-80 BTCM PRODUCTION 7 6.151 0.0 11,255.0 6,272.3 26.00 L-80 BTCM LINER 31/2 2.992 11,101.0 12,214.0 6,815.4 9.30 L-80 SLHT LINER TOP Lt 23/8 1.992 11,591.0 11,597.0 6,473.3 4.60 L-80 STL 3534 ~..-) " Y ._._ TUbing $trln(~]s S 1 De pll ~ (HKB) bi i T T T D oAS _ u ng oscr p ~~n t TUBING ,~, III ~ H-L.I 1 i (ftK6) /f[ ~ g 30 ~ ~ ~3 O 11 O 1610 6215 4 ~~ Gr d L 80 e o EU MOD ~,~~ 6910 y . _ , ~ . . - Other In Hule BAH Je w e Iry: Tubing Run-& Retrievable, Fish, etc.) _ ' SURFAGE J - Top (fIKB) _ ' Description _ _ Gomment Run fide I ID (in) ,_ ].]e4 - 539.0 SSSV SSSV: NIPPLE CAMCO'DS' nipple with NO GO profile 3/8/2001 2.875 ' 3,534.0 GAS LIFT CAMCO/KBUG/1/GLV/BK/.125/1318/Comment: STA1 1/11/2008 2.920 cns uFT. 9 091 ,. ~. 6,910.0 GAS LIFT CAMCO/KBUG/1/GLV/BK/.156/1326/Comment: STA2 1/16/2008 2.920 , 9,091.0 GAS LIFT CAMCO/KBUG/1/GLV/BK/.156/1302/ Comment: STA 3 1/16/2008 2.920 ~_ 10,229.0 GAS LIFT CAMCO/KBUG/1/GLV/BW.188/1314/Comment: STA4 1/16/2008 2.920 cns uPr, 10,229 ~ ~ 11,028.0 GAS LIFT CAMCO/MMG/1.5/OV/RK/.25// Comment STA 5 1/11/2008 2.920 11,078.0 NIPPLE CAMCO'DS' nipple w/NO GO profile 3/8/2001 2.812 11,101.0 TIE BACK L7 LINER TIE BACK SLEEVE 3/8/2001 5.250 Gns uFT, 11,028 , . ~ ~ 11,109.0 PACKER LINER BAKER 5"X7" ZXP LINER TOP PACKER TKC COUPLING 3/8/2001 4.438 - 11,115.0 HANGER Lt LINER BAKER 5" x 7" FLEX-LOCK LINER HANGER 3/8/2001 4.250 [ 11,122.0 LOCATOR BAKER NO GO LOCATOR 3l8Y2001 3.000 NIPPLE. 11,9]6 ~ {t[° 11,124.0 SEAL BAKER GBH-22 35' Seal Assembly 3/8!2001 3.000 I I 11,129.0 SBE L1 LINER BAKER SBE 80.40 ~ 3/8/2001 4.000 rIE encK. ' I 11.161.0 SHOE BAKER mule shoe 3/8/2001 3.000 11,582.O~L 11,1 1 SEAL, 11,124 SBE. 11.129 SHOE, 11,161 JIPPLE, 11,18] 1 PRODUCTION, 11,255 L1 PACKER, 11 582 LINER TOP, 11,590 Li Deploy SUb, r :`~ 11,590 511 INER TOP L1, 11,597 WINDOW L1, 11,59] APERF, 11,606-11,616 FRAC, 11,606 IPERF, 11,833-11,843 _ COLLAR, 1 - i 12,146 COLLAR, 12,1]9 LINER, 12,214 TD (iJ-03), 12,214 -~ SHOE, 12,214, LINER Li SLOTS, 12,921 Pertorations Shot Top (ND) Btm (ND) Dens Top IkK6) Btm tftKB) I (kKB) I (kKB) Tvoe Zone (shot... Date Dommene Stimulations & Treatments -_ --- Nh„ f..p a, arm Depth 'aDepth (kKB) (ftKB) Dab Typo Comment 11,606.0 11,616.0 6/28/2001 FRAC C-SAND FRAC, 58,000#, 16/20 CARBOLITE, 7 ppa ON PERFS Notes: General & Safety e e ç~, .~:,\, '\ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFiche\CvrPgs _ Inscrts\Microfilm _ Marker.doc Schlumberger NO. 3429 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth 07/08/05 ~D (- O--~lf ,5C,ANNEL> SEP Û 2 2005 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL ¿ 2G-02 I ~ '-i -j). { 11047334 BHP SURVEY 06/30/05 1 , 2G-13 I~ ¿¡ - i).~' 11047336 BHP SURVEY 07/01/05 1 J. 2G-11 ¡g'./-; ('7 11047337 BHP SURVEY 07/01/05 1 y 1Y-14)8~~ Gl\ 11022907 LEAK DETECTION LOG 06/30/05 1 ìJ 3H-19/8"7 ../)) 11022907 PRODUCTION PROFILE 06/28/05 1 ¡j, 1 J-03 ~~Gí - C ).. if 11022893 PRODUCTION PROFILE 06/17/05 1 'J 1L-09 ¡'iO.· v jC( 11022895 PROD PROFILE W/DEFT 06/19/05 1 ./, 3S-10 .J- 0;" - 1:\ L 11001235 PROD PROFILE W/DEFT 06/14/05 1 j 3F-04 18:J' . ,1.18 11022891 INJECTION PROFILE 06/15105 1 1Y-26A ¡JJ'II~ 11022892 PROD PROFILE W/DEFT 06/16/05 1 ;.J 1E-112J\ii1·()'1I 11047339 INJECTION PROFILE U i (. 07103105 1 j 1E-102 J..\;~"J.JI 11047340 INJECTION PROFILE \';lC 07/04/05 1 í/ ~ l/ I (¡ SIGNED: rli~ J. ¡ LJ!JvY DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color - CD --- L ~J :-;},. ~ -- :¿~ J--- K~: ll'WU: .L\...UparuK lJ WeulesungJ ) ) Subject: Re: [Fwd: Kuparuk IJ Well Testing] From: John Hartz <jack_hartz@admin.state.ak.us> Date: Wed, 10 Aug 2005 13:10:58 -0800 To: Brian Seitz <Brian.Seitz@conocophillips.com> CC: Thomas E Maunder <tom_maunder@admin.state.ak.us> . ~O\-O~~ dO t - 0 l{ '-\ dO \ - o'\. \ Brian, Your request appears to be an operational necessity for a short period until the 1J Pad facility is commissioned. Your proposal to test ~and test 1J-09 & 1J-10 if monitoring data indicate performance changes is acce~e. Notify me if the schedule is significantly delayed beyond November 1. Thank you for the notification. Jack Hartz, P.E. Sr. Reservoir Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave. Suite 100 Anchorage AK 99501 907-793-1232 Fax: 907-276-7542 . G ...~ '1 ?G05 S····C'I:ì.NNED AU ."- 1 ... ~~. in Thomas Maunder wrote: Jack, For your reply. Torn -------- Original Message -------- Subject: Kuparuk 1J Well Testing Date: Wed, 10 Aug 2005 09:02:50 -0800 From: Seitz, Brian <Brian.Seitz@conocophìllips.com> To: tom maunder@admin.state.ak.us CC: C·ËïFl.......p"I::·od...···Eng·r··...··~·r1:i·2..6..9(¡~·ë·õï;o·ë·ophil1 ips. com>, "Spenceley, Neil" .:5.~.~.~..~....~...~..::...?.p.~.~.s::.~..~_~.Y~.s:.9..~.~~.~:e..þ..~..~...~...~.p...§...:...~..9..~.?'.., 'I John stone, S am II < Sam. Johnstone@conocophi.llip¡:; . com> Torn- The three existing Kuparuk producing wells on 1J pad are currently tested monthly as twinned well tests using the test facility on 1D pad. In addition, we obtain single well tests every 6 months with a portable test separator to verify individual well production. In mid-September, these wells will be tied into the new 24" production line recently installed from 1J pad to CPF-1 and we will lose our ability to test the wells through the 1D pad facility. The new 1J pad separator is scheduled to be placed in service on November 1, 2005. CPAI requests a waiver from the monthly well testing requirement for wells 1J-03, 1J-09, and 1J-IO until the new 1J test facility is in service. We will be testing 1J-03 with a portable test separator following a coiled tubing sidetrack scheduled for August, and will retain the option of testing 1J-09 and 1J-10 should pressure and temperature trends indicate significant changes in well performance. Please let me know if this plan is acceptable, or give me a call if you wish to discuss it in further detail. Regards, Brian Seitz CPF-1 Lead Drillsite Petroleum Engineer 265-6961 8/1 0/2005 1: 17 PM Permit to Drill 2010240 DATA SUBMITTAL COMPLIANCE REPORT 613/2003 Well Name/No. KUPARUK RIV UNIT 1J-03 Operator CONOCOPHILLIPS ALASKA INC APl No. 50-029-23002-00-00 MD 12214 ~ 'I'VD 6816 ~' Completion Dat 5/23/2001 --- Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Sample N._~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name (data taken from Logs Portion of Master Well Data Maint) Log Scale Log Media Run No Interval Start Stop OH I Dataset CH Received Number Comments j. Directional Survey .pi~ectional Survey ~5~P/PSP 5 ....-'10125 --'El~S Verification ...,NI~D Directional Survey ~MWD Directional Survey ~T~D GR/ BAT 5 ~'rVD GPJ EWR 5 (,,MD GR/ROP/EWR 5 ,.~ GR/CNP/CTN/ 5 SLD. /,,~D GR/CNP/CTN/ 5 SLD /./WID GR/BAT 5 FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL 99 11500 99 120 120 120 120 120 120 12159 11634 12159 12214 12214 12214 12214 12214 12214 Open 5/1/2001 ~125 99-12159 4/12/2001 Directional Survey Paper Copy 4/12/2001 Directional Survey Digital Data OH 7/30/2001 11500-11634 BL, Sepia CH 5/1/2001 ~'25 99-12159 Digital Data CH 5/1/2001 LIS Verification 4/12/2001 MWD Directional Survey Paper Copy 4/12/2001 MWD Directional Survey Digital Data OH 5/7/2001 120-12214 BL, Sepia OH 5/7/2001 120-12214 BL, Sepia OH 5/7/2001 120-12214 BL, Sepia OH 5/7/2001 120-12214 BL, Sepia OH 5/7/2001 120-12214 BL, Sepia OH 5/7/2001 120-12214 BL, Sepia Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill 2010240 DATA SUBMITTAL COMPLIANCE REPORT 6/312003 Well Name/No. KUPARUK RIV UNIT 1J-03 Operator CONOCOPHILLIPS ALASKA INC APl No. 50-029-23002-00-00 MD 12214 'I'VD 6816 Completion Dat 5/23/2001 Well Cored? Chips Received? ~ R ec.~.ivP, d ? Completion Statu 1-OIL Current Status 1-OIL Daily History Received? ~ N Formation Tops ~_~ N UIC N Compliance Reviewed By: Annular Disposal durin the first quarter of 2002: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 2P-417 25534 100 0 25634 887 5431 31952 October March 2P-448, 2P-422A, Grizzly 2001 2002 2P-451, 2P-441, 2P-420 CD2-14 16138 100 0 16238 376 14459 31073 November March CD2-32, CD2-47, CD2-45 2001 2002 1C-14 9626 100 0 9726 0 22489 32215 October January 1R-36, 1C-24, 1C-109 2001 2002 CD2-15 10346 100 0 10446 371 0 10817 March March CD2-50 2002 2002 CD2-47 16459 100 0 16559 375 10415 27349 December January CD2-34, CD2-26, 2001 2002 CD2-45 22514 100 0 22614 377 0 22991 January February CD2-49, CD2-17 2002 2002 2P-415A 4843 100 0 4943 52 0 4995 March March Grizzly gl, 2P-431, 2P-441 2002 2002 CD2-26 0 0 0 0 380 0 380 .... Freeze protect only for CD2-26 CD2-49 0 0 0 0 386 0 386 Feb 2002 Feb 2002 Freeze protect only Total Volumes into Annuli for which Disposal Authorization Expired during the first quarter 2002: Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 1D-32 23162 100 0 337 23599 Open, Freeze Protected January February 1D-39 2001 2001 1J-03 30024 100 0 0 30124 Open, Freeze Protected March 2001 May 2001 1J-09, 1J-14, 1J-10 Annular Disgosal durin the second 'uarter of 2001' h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date / 1C-17 33139 100 0 33239 0 33239 May01 Jun01 1c-133, 1c-121, 1c-123, 1c-127 :~ 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar 01 May 01 1J-09, 1J-14, 11-10 " 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 ~ CD2-42 18034 100 0 18134 0 18134 May01 Jun01 CD2-24 ~ 1C-27 3533 .100 0 3633 0 3633 Jun 01 Jun 01 1C-127 t' Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2001: v . Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus ~ 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 ' 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- / 2000 35, CD 1-32, CD1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only -- CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 200'1 CDI-10, CD1-28, CD1- 33, CD1-NQ1 PI-[ , LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. R. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 October 15, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue ,,3,..,~ ~-\. Suite 100 Anchorage, Alaska 99501 Subject: Core Descriptions for Wells 1J-03, 1J-09 and 1D-107 Dear Commissioner: Phillips Alaska, Inc. submits the attached core descriptions for the Kuparuk wells 1J-03, 1J-09 and the West Sak well 1D-107. These reports follow the completion reports which we submitted earlier this year. If there are any questions, please contact Sharon Allsup-Drake at 263-4612. Sincerely, C. R. Mallary Drilling Engineering Supervisor Phillips Drilling CRM/skad RECEtVED OCT 1 6 ~001 Al~k~ 0it & Oas Cons. Con~nission ^ncho~age Well 1J-03 Sidewall Core Descriptions v-frae sand = 0.062-0.125, silt = 0.004-0.062, clay = <0.004 Sample Depth ID (~.) Zone 32450 6185 D 32451 6195 D 32452 6205 D 32453 6215 D 32454 6225 D 32455 6235 D 32456 6245 D 32457 6255 D 32458 6265 D 32459 6355 B 32460 6362 B 32461 6367 B 32462 6375 B 32463 6385 B 32464 6395 B 32465 6405 B Description olive gray to olive black, very f'me light reddish brown, frae with a few dark red to black orthorhombic looking clasts med. to dark gray with light brown clasts, very fine mud with one large (0.5 cm) clast med. grayish brown, very fine med. grayish brown with traces of darker elements, very fine light grayish brown, very fine mica flake light brown, very fine with minor upper fine to coarse grained clasts mostly mud:med, grayish brown, silt matrix with very fine clasts 32466 6465 A4 32467 6475 A4 32468 6485 A4 32469 6495 A4 32470 6506 A4 light brown with minor gray, silt dark gray to black, very fine dark grayish brown, very fine dark grayish brown, very fine dark grayish brown, very fine dark grayish brown, very fine dark gray, silt dark gray to black, silt 32471 6548 A3 32472 6565 A3 32473 6572 A3 32474 6599 A3 32475 6603 A3 32476 6617 A3 32477 6621 A3 32478 6650 A3 32479 6672 A3 32480 6678 A3 32481 6725 A2 32482 6735 A2 32483 6745 A2 32484 6752 A2 32485 6763 A2 32486 6768 A2 32487 6794 A2 32488 6804 A2 32489 6815 A2 32490 6825 A2 32491 6835 A2 32492 6860 A2 32493 6863 A2 dark gray with a few specs of med. brown, silt dark brownish gray, silt with 20% very fine gray, silt med. 8ray, silt med. gray, silt dark gray with a few specs of med. brown, silt dark gray, mud and silt mix dark gray, mud and silt mix dark gray, silt dark grayish brown, very fine yellowish brown, very fine with handful of small black isogonal clast dark gray silt matrix with 20% very fine brown clast dark gray, silt and mud mix dark ~;rayish brown, silt with some very fine clast dark grayish brown, silt with some very fine clast rich gray, mud matrix with minor silt gryish red with sparse light brown, silt with ocassional mica flakes grayish red with light brown, silt med. gray, silt dark gray silt matrix with 20% very fine brown clast med. gray with brown specs, silt No Sample No Sample RECEIVED med. to dark gray, silt, mica rich dark gray, silt med. gray, silt with 30°/6 very fine light brown clast OCT 1 6 2 01 dark ~rayish brown, fine Alaska Oil & Gas Cons. Commission Anchorage PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 31, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 - REVISED Dear Ms. Mahan: Please find attaChed the revised report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. We have revised the amount for CD2-42 because the original manifest incorrectly reported the CD2-24 annulus used for the disposal. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC: Marty Lemon Mike Mo°ney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Annular Disposal durin the second 'uarter o~2001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May01 Jun01 1c-133, 1c-121, 1c-123, 1c-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar 01 May 01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May ,01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 '-13-o45 Total Volumes into Annuli ~or which Disposal Authorization Expired during the second quarter 2001: Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume VOlume Volume Status of Annulus 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-~8, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD 1-32, CD 1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD I~NQI Zoo -o i :i 7/19~2001 Schlumberger NO. 1303 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color 1J-03 ~c~r. O~Z/ SBHP 06/27101 1 1 1D-101 Z~I~NF'~-,-/~'~,INJECTION PROFILE 06/21/01 I 1 1D-107 _Z~ -I'~"Z INJECTION PROFILE 06/24/01 1 1 ID-128 I¢~ -./~ ~ INJECTION PROFILE 07/06/01 IR-26 lq/" d~?Z INJECTION PROFILE 06/02/01 1 t 2A-19A 2~--! --O~'~ SBHP STOPS 06/17/01 1 t 2G-9 GAS LIFT SURVEY 07103/01 2G-09 PRODUCTION PROFILE 07114101 2N-326 ?J3~ ./~'.~ PRESS & TEMP BASELINE 07/02/01 2N-326 ~ et~IS.~ WFL/RST/PSP 07104101 1 1 2V-03 ~-~- f~¥ WFL/RST-A 06/09/01 3H-31 /~lf- Ol~ INJECTION PROFILE 06/30/01 3J-07A ~'~1~_ I- ~ SBHP SURVEY 06/19/01 3M-01 /~r/--~12. INJECTION PROFILE 06/29101 I 1 30-05 /'~,- O~ INJECTION PROFILE 06/24/01 1 1 30-10 /~;- ~;~J INJECTION PROFILE 07/05/01 1 1 30-19 I~'/' O~O RST BORAX/LDL 06104101 1 1 SIGNE DATE: RECEIVED JUL 50 2001 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-83~7. Thank you. STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status o! well Classification of Service Well Oil [~] Gas [~ Suspended D Abandoned D Service 2. Name of Operator . ~ ~" 7. Permit Number Phillips Alaska, Inc.~.[~"~1~'~'.. 201-024 3. Address '_'~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360~ 50-029-23002-00 4. Location of well at surface ~, 9. Unit or Lease Name 2107' FSL, 2419' FEL, Sec. 35, TllN, R10E, UM (ASP: 558790, 5945920) I ~J~'": :"-":' 0!~ i Kuparuk River Unit At Top Producing Interval ~ ,~ 1 L: 10. Well Number 1105' FNL, 1456' FWL, Sec. 36, TllN, R10E, UM (ASP: 562645, 5948019) ',. -- ~ 1J-03 [/[:RIr,,-~} 11. Field and Pool At Total Depth I ' ~ "'- 1448' FNL, 738' FWL, Sec. 31, T11 N, R11 E, UM (ASP: 567210, 5947715) [ ,__.z~'~ _~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 34 feetI ADL 28248 / 25661 ALK 591 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions I February 11 2001 March 3, 2001 ~1'2 N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 12214' MD / 6816' TVD 12146' MD / 6778' TVD YES r~l No E]I N/A feet MD 1473' .22. Type Electric or Other Logs Run I GR/Res/Neu Dens, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 137' 24" 400 sx AS I 9.625" 40# L-80 Surface 7784' 12.25" 770 sx AS Lite & 486 sx LiteCrete 7" 26# L-80 Surface 11255' 8.5" 170 sx Class G 3.5" 9.3# L-80 11101' 12214' 6.125" 256 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 11162' 11109' 11833'-11843' MD 6606'-6612' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11606'-11616' MD 6479'-6484' TVD 6 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11833'-11843' 31aced total of 60400# 16/20 carbolite and 42317# 12/18 carbolite behind pipe, left 27429# 12/18 carbolite in the wellbore 11606'- 11616' 31aced 58067# prop behind pipe 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 5, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 7/9/2001 12.0 Test Period > 218 690 5 176I 338 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. 225 psi not available 24-Hour Rate > 416 1415 10 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. To be sent under separate coverRECEIVED JUL 2, Alaska Oil & Gas Cons. Commission Anchnr2n,~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 11569' 6457' Base Kuparuk C 11645' 6501' Top Kuparuk A 11795' 6586' Base Kuparuk A 11943' 6668' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily O):~erations, Direction~l"Survey 32. I hereby certify.th/,,ai"the following is true'nd correct to the best of my knowledge. Questions? Call Todd Mushovlc 265-6974 Signed .~~'~'; ~' ~,,,f/.,~'"/~ j Title Interim Ddllln,q En,q noedng Supervisor Date / - , ~,. ---~ ~,.- , , Tom Brockway , ¢'~'" Prepared by Sharon AIIsup-Drake 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 JUL ~ 3 ~001 Alaska 0il & Gas Cons, Commission Operations Summary 1J-03 Rpt Date 02/08/01 12:00 AM 02/08/01 12:00 AM 02/08/01 12:00 AM 02/09/01 12:00 AM 02/09/01 12:00 AM 02/09/01 12:00 AM 02/09/01 12:00 AM 02/09/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/10/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/11/01 12:00 AM 02/12/01 12:00 AM 02/12/01 12:00 AM 02/12/01 12:00 AM Begin Time 04:30 08:30 18:00 00:00 17:00 20:30 21:30 23:00 00:00 03:00 05:00 09:00 16:00 18:30 21:00 22:00 00:00 05:00 07:00 08:00 12:00 13:00 13:30 14:00 20:30 21:00 00:00 04:00 04:30 End Time 08:30 18:00 00:00 17:00 20:30 21:30 23:00 00:00 03:00 05:00 09:00 16:00 18:30 21:00 22:00 00:00 05:00 07:00 08:00 12:00 13:00 13:30 14:00 20:30 21:00 00:00 04:00 04:30 18:00 Comments Clean out cellar, Cut 4" collars off conductor, Disconnect service lines at stair tower, Separate modules, Prep. sub module for move Pull sub module away from power module. Turn power module 90 degrees & set down on mats, Prep. to remove bogey wheels, Pull bogey wheel off drillers side & attach to booster assy. Disconnect service lines to rig floor, Skid rig floor to center of rig, Move booster wheel assy. to back of rig, L/D BOP stack in frame Move rig modules off 1D pad & move to 1J pad Remove front & rear bogey wheel assy.'s & reinstall left rear aux. axle Pick up BOP w/BOP hoist & remove carrier, Stand BOP on stump in cellar & chain cellar Place mud cross f/surface hydril on condutor, Hang surface hydril & riser on BOP hoist, Install left side wind walls Jockey substructure into position for placement over 1J-03 Hold pre-spud meeting w/all rig personal, Position rig over well, level rig, button up cellar Install bogey wheel cover on, Move power module and marry up w/sub module, Skid rig floor over hole Install cattle shoot and secure, Install hand rails & ect. Accept rig @ 0900 hrs, Install & nipple up diverter stack & line Complete pre-spud check list, clean & organize rig floor, Place strip-o-matic over hole PJSM, Rig & pick up 5" DP & stand in derrick Function test diverter system- witnessed & approved by AOGCC Pick up 5" DP Pick up 5" DP & stand in derrick Pick up HWDP & Jars, Stand back same Pick up DC's & Stand back Pick up & adjust motor, M/U MWD & BHA Pressure test pump lines, Fill hole & check diverter stack f/ leaks-OK Spud well, Drill f/,137' to 176' Repair top drive Drill f/176' to 731' Ball mill & Inj. pits full- Wait on late arriving vac. truck Drill f/731' to 970'MD/963' TVD Drill f/970' to 1298' ART= .25 hrs AST= 2.5 hrs Change out suction screens on both pumps Drill f/1298' to 2512' ART= 3.75 hrs AST= 5.25 hrs Operations Summary 1J-03 02/1 2/01 12:00 AM 02/12/01 12:00 AM 02/1 2/01 12:00 AM 02/13/01 12:00 AM 02/13/01 12:00 AM 02/13/01 12:00 AM 02/13/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/14/01 12:00 AM 02/15/01 12:00 AM 02/15/01 12:00 AM 02/15/01 12:00 AM 02/15/01 12:00 AM 02/15/01 12:00 AM 02/15/01 12:00 AM 02/15/01 12:00 AM 02/15/01 12:00 AM 02/16/01 12:00 AM 02/16/01 12:00 AM 02/16/01 12:00 AM 02/16/01 12:00 AM 02/16/01 12:00 AM 02/16/01 12:00 AM 02/16/01 12:00 AM 02/17/01 12:00 AM 02/17/01 12:00 AM 02/17/01 12:00 AM 02/17/01 12:00 AM 18:00 19:30 23:00 00:00 12:00 13:00 23:30 00:00 01:00 06:00 06:30 08:00 08:30 10:00 14:30 15:30 21:30 22:30 00:00 02:00 05:30 07:30 09:30 14:00 15:00 16:00 00:00 01:00 02:00 14:00 15:30 18:00 19:00 00:00 11:00 13:00 17:30 19:30 23:00 00:00 12:00 13:00 23:30 00:00 01:00 06:00 06:30 08:00 08:30 10:00 14:30 15:30 21:30 22:30 00:00 02:00 05:30 07:30 09:30 14:00 15:00 16:00 00:00 01:00 02:00 14:00 15:30 18:00 19:00 00:00 11:00 13:00 17:30 22:00 Pump sweep, Monitor well, Pump dry job Pull to 1950' w/10-30K drag (hole swabbing), Pump out 2 stands, Finish pulling to HWDP w/10-30K drag, RIH to 2150' (pipe stopped), Wash f/2150' to 2200', RIH to 2512' - OK Circ. hole clean Drill f/2512' to 3739' ART= 6 hrs AST= 3 hrs Change liner & swab in #1 pump Drill f/3739' to 5100' ART= 5.5 hrs AST= .75 hrs Pump sweep & circ. hole clean Circ. sweep around & hole clean, Monitor well POOH max drag 20K, Change bits Down load MWD Change BHA, P/U LWD Program LWD Cut drilling line 78', Service top drive Load source in LWD, RIH fill pipe @ 2000', RIH took wt. @ 2150' & 3200', Wash f/4600' to 4700', RIH to btm. Circ. btm's up & hole clean Control drill w/LWD f/5100' to 5625' ART= 3 hrs AST- .5 hrs Lost 300 PSI pump press. & MWD signal- Check surface pumps & lines OK- Cycle MWD & regain signal- Circ. & monitor f/wash out- No further loss in pump press. Drill f/5625' to 5721' ART- .5 hrs AST- .25 hrs Drill f/5721' to 5910' (Possible 50 PSI drop in pump press.) ART= 1.5 hrs AST= 0 Monitor well, POOH wet - no tight spots Remove source, Inspect BHA, Clean & check bit- OK Break reducer sub- jet missing, L/D reducer, Fish jet out of top of motor, Oreint tools, replace source RIH, Fill pipe @ 3190', Periodic down drag of 10 to 20K Circ.& cond. mud prior to drilling Drill f/5910' to 5998' ART= .75 hrs AST- 0 Phase III weather, WOW, Circ & work pipe slow Wait on Phase III weather, Inspect derrick Wipe hole to 5500'- No problems Drill f/5998' to 6850' ART= 8.25 hrs AST= 0 hrs Circ. clean f/short trip Wipe hole to 5100'- No problems Circ. btm's up Drill f/6850' to 7175' ART- 4 hrs AST=0 hrs Drill f/7175' to 7795' ART= 8 hrs AST= 1 hrs Pump sweep, Circ. hole clean, Monitor well POOH- No problems (SLM- no correction) Set back DC's, Remove R.A. sources, Down load MWD/LWD, Lay down MWD/LWD & Mud motor Operations Summary 1J-03 02/17/01 12:00 AM 02/17/01 12:00 AM 02/18/01 12:00 AM 02/18/01 12:00 AM 02/18/01 12:00 AM 02/18/01 12:00 AM 02/18/01 12:00 AM 02/18/01 12:00 AM 02/19/01 12:00 AM 02/19/01 12:00 AM 02/19/01 12:00 AM 02/19/01 12:00 AM 02/19/01 12:00 AM 02/19/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/20/01 12:00 AM 02/21/01 12:00 AM 02/21/01 12:00 AM 02/21/01 12:00 AM 02/21/01 12:00 AM 02/21/01 12:00 AM 02/21/01 12:00 AM 02/21/01 12:00 AM 02/21/01 12:00 AM 22:00 23:30 00:00 03:00 06:00 11:00 12:30 17:00 00:00 03:30 04:00 12:00 16:00 22:00 00:00 09:00 10:30 13:00 16:00 17:30 18:00 19:00 00:00 02:00 05:00 09:30 12:00 13:30 18:00 18:30 23:30 00:00 03:00 06:00 11:00 12:30 17:00 00:00 03:30 04:00 12:00 16:00 22:00 00:00 09:00 10:30 13:00 16:00 17:30 18:00 19:00 00:00 02:00 05:00 09:30 12:00 13:30 18:00 18:30 20:00 Make up 12.25" Hole Opener, Pick up stab, Run BHA RIH w/Hole opener RIH w/Hole opener to 7795' Circ. & cond. mud f/E-logs, Monitor well, Pump dry job POOH to BHA- NO hole problems Set back BHA, Lay down hole opener & stab Rig Schlumberger, Attempt to run Dipole Sonic- Log stopped @ 2200', POOH & lay down same Rig up D.P. Conveyed Sidewall Cores- 45, RIH w/Core guns RIH w/Sidewall core guns to 6795', Break circ every 1000' Circ. to clean up wet connect Rig sheaves, M/U side entry sub, RIH wi wire line, Connect & shoot siewall cores f/6863' to 6725', POOH w/wireline L/D D.P., M/U side entry sub, RIH w/wire line, Connect & shoot sidewall cores f/6678' to 6603', POOH w/wire line L/D D.P., M/U side entry sub, RIH w/wire line, Connect & shoot sidewall cores f/6599' to 6465', POOH w/wire line L/D D.P., M/U side entry sub, RIH w/wire line Pump wet connect down, latch up to core tool and take core shots from from 6465' to 6176'. Pull wireline loose and out of the hole. Laydown side entry sub and 10' pup R/D wireline equipment CBU. Pull 5' of d.p. every 10 min. POOH slow w/sidewall cores Retrieve core samples. 44 out of 45 shots fired. Recovered 44 samples Clean floor and reinstall strip-o-matic P/U holeopener, stab, and 6 d.c. RIH. Fill pipe at 2600'. L/D 2 joints w/galled shoulders: replace. Fill pipe at 4506'. Ream hole where cores were taken from 6100' to 7040' Wash & Ream f/7040' to 7795'(TD) Circ & Condition hole f/9 5/8" casing job, check well, pump dry job, blow down top drive. POOH to BHA, check well, OK. Cut & Slip drilling line 150' & adjust brakes. Work BHA. Stand back HWDP, jars, 2 stands DC. L/D hole opener and bit sub. PJSM, running 9 5/8" casing. Check displ every 10 jts. Run 50 jts, displ lower than calc. Circ bottoms up at 2000'. Resume running 9 5/8" casing, 40#/ft. from 2000' to 3600'. Operations Summary 1J-03 02/21/01 12:00 AM 02/21/01 12:00 AM 02/22/01 12:00 AM 02/22/01 12:00 AM 02/22/01 12:00 AM 02/22/01 12:00 AM 02/22/01 12:00 AM 02/22/01 12:00 AM 02/23/01 12:00 AM 02/23/01 12:00 AM 02/23/01 12:00 AM 02/23/01 12:00 AM 02/23/01 12:00 AM 02/23/01 12:00 AM 02/23/01 12:00 AM 02/23/01 12:00 AM 02/23/01 12:00 AM 02/24/01 12:00 AM 02/24/01 12:00 AM 02/24/01 12:00 AM 02/24/01 12:00 AM 02/24/01 12:00 AM 02/24/01 12:00 AM 02/24/01 12:00 AM 20:00 22:30 00:00 05:00 12:00 16:00 19:00 21:30 00:00 05:00 06:00 10:00 11:00 11:30 17:00 17:30 23:00 00:00 01:00 02:30 03:30 05:30 07:00 08:00 22:30 00:00 05:00 12:00 16:00 19:00 21:30 00:00 05:00 06:00 10:00 11:00 11:30 17:00 17:30 23:00 00:00 01:00 02:30 03:30 05:30 07:00 08:00 08:30 (Displacement lower than calc (total 20 bbls short @ 3600'). Circ casing volume + @ 6 BPM and 600 psi. Continue running 9 5/8" casing 40#/ft. Good displacement. Continue running 9 5/8", 40 #/ft, L-80 casing. Circ @ 6000' f/1 hr. Cont. RIH w/casing, MU hanger, Lnd jr. and land @ 7784'. Circ. & Condition mud and hole for cement job. Circ 2500 BBL's reducing mud wt. to 9.7 ppg. and reducing viscosity. PJSM. Fill lines and test to 3500 psi. Pump 20 bbl water, 20 bbl chemical wash, drop plug, 50 bbl Mud push. Mix and pump 601 bbl Lead @ 10.7 ppg and 201 bbl Tail @ 12 ppg, drop plug, clear tub w/5 bbl Tail and 10 bbl water. Continue displacement w/rig p R/D cement head, flush flow line, L/D landing joint, casing elevators and bales. Wash out surface stack, blowdown lines. N/D Diverter system. NU Speed head and tubing spool. Set BOP stack, start to torque nuts on tubing spool & DSA using torque wrench. Tested metal to metal seal on casing head to 1000 psi f/ 10min. OK. Nipple up 13 5/8" 5M BOPE. Rig up test equipment. Test BOPE, 250 psi and 5000 psi. Test witnessed by AOGCC Insp. John Crisp & Commisioner Julie Heusser. R/D test euipment. Install wear bushing. Blow down lines. Install strip-o-matic, clean rig floor. Hang up bales on derrick leg. Make up BHA, Upload Sperry tools 2 1/2 hr, Check FRT 1 hr., Orient 1/2 hr. RIH 6 stands f/derrick. , PU 120 jts 5" grade "G" d.p. from pipe shed. Surface test tools @ 1205'. OK RIH w/5 .... S" 135 d.p. f/derrick to 5963'. Break circulation @ 3522' and 5397'. Continue RIH to 7668', tag cement. Break circulation, CBU f/9 5/8" casing test. Stand back 1 stand, blow down top drive, RU f/1/2 hr casing test. Test casing to 2500 psi for 30 min. OK. R/D test equip. Make up 1 stand. Drill out 30' cement, F.C., cement,, F.S., and 34' new hole to 7829'. Change over mud system to new clean mud. RU to perform LOT. Test, R/D. EMW 14.8 ppg. Perform PWD baseline test. Operations Summary 1J-03 02/24/01 12:00 AM 02/25/01 12:00 AM 02/25/01 12:00 AM 02/25/01 12:00 AM 02/25/01 12:00 AM 02/25/01 12:00 AM 02/25/01 12:00 AM 02/25/01 12:00 AM 02/26/01 12:00 AM 02/26/01 12:00 AM 02/26/01 12:00 AM 02/26/01 12:00 AM 02/27/01 12:00 AM 02/27/01 12:00 AM 02/27/01 12:00 AM 02/27/01 12:00 AM 02/27/01 12:00 AM 02/27/01 12:00 AM 02/27/01 12:00 AM 02/27/01 12:00 AM 02/28/01 12:00 AM 02/28/01 12:00 AM 02/28/01 12:00 AM 02/28/01 12:00 AM 02/28/01 12:00 AM 02/28/01 12:00 AM 02/28/01 12:00 AM 03/01/01 12:00 AM 08:30 00:00 13:00 14:30 16:00 17:30 18:30 20:00 00:00 18:30 20:30 23:30 00:00 01:30 02:30 04:30 08:30 17:00 20:00 22:30 00:00 09:30 11:00 15:00 19:00 19:30 21:30 00:00 00:00 13:00 14:30 16:00 17:30 18:30 20:00 00:00 18:30 20:30 23:30 00:00 01:30 02:30 04:30 08:30 17:00 20:00 22:30 00:00 09:30 11:00 15:00 19:00 19:30 21:30 00:00 00:30 Directional drill f/7829' to 8810' (981 ') AST= 5.75 hrs, ART-- 4.75 hrs. Directional Drill f/8810' to 9810' (1000') ART- 7 hrs AST= 4 h rs Pump sweep around & moniter hole. Short trip to 9 5/8" shoe @ 7782' (wet), 22 stands, 10 k over @ 9345' & 9535'. Clear floor, Moniter well, Service top drive. TIH to 9810'. Hole in good shape. CBU. Directional drill f/9810' to 9999' (189') Clean both suction screens on pumps. ART-1.2 hrs AST- .5 hrs. Directional drill 8 1/2" hole f/9999' to 11268' (1269') ART= 9 1/2 hr AST= 3 hrs Pump seep around, Ciirc & Condition mud & hole for LOT. Monitor hole, Pump dry job. POOH to 9 5/8" shoe @ 7784' for LOT. Hole in good shape. No tight spots. Circulate and condition mud f/LOT @ 9 5/8" shoe. Even weight out to 9.8+. Circ and cond mud f/LOT @ 9 5/8" Shoe. Even out MW @ 9.8+ RU f/LOT. EMW @ 12.7 ppg w/9.8+ and 925 psi @ 6280 TVD. Adjust crown-o-matic and RIH. Hole is good. Circulate and cond hole for 7" casing. Check well, pump dry job, blow down T.D. POOH, SLM (no Corr), check well @ shoe, con't POOH, stand back HWDP and jars. L/D BHA. Download tools 1/2 hr., Pull strip-o-matic. Pull wear bushing, RU to run 7" casing. PJSM. Run 7" 26#/ft, L-80 BTC-Mod casing. Check floats, ok Running 7" 26 #/ft L-80 casing. Break circ @ 2000', 4000' & 6000'. Circulate 7" casing volume @ 9 5/8" shoe. 5.2 bpm 610 psi. 9.8+ in & out. PU 180 k, SO 140 k Con't running 7" casing. Break circ @ 9830'. Land 7" casing @ 11255'. Circulate and condition mud and hole for cement job. Circ 1282 bbls. L/D filup tool and M/U cement head Pump 10 bbl water, test lines to 3500 psi, Pump 20 bbl CWl00, Drop plug, Pump 30 bbl Mudpush, Mix and pump 35.8 bbl (170 sx) slurry. Drop top plug and Pump 10 bbl water. Displace w/417.8 bbl mud. Bump plug and check floats-Ok. L/d landing jt and set packoff. Clear floor. Tighten Iockdown screws on 7" casing packoff & test to 5000 psi. OK. 03/01/01 12:00 AM 03/01/01 12:00 AM 03/01/01 12:00 AM 03/01/01 12:00 AM 03/01/01 12:00 AM 03/01/01 12:00 AM 03/01/01 12:00 AM 03/01/01 12:00 AM 03/01/01 12:00 AM 03/02/01 12:00 AM 03/02/01 12:00 AM 03/02/01 12:00 AM 03/02/01 12:00 AM 03/02/01 12:00 AM 03/02/01 12:00 AM 03/02/01 12:00 AM 03/02/01 12:00 AM 03/02/01 12:00 AM 03/02/01 12:00 AM 03/02/01 12:00 AM 03/02/01 12:00 AM 03/02/01 12:00 AM 03/03/01 12:00 AM 03/03/01 12:00 AM 03/03/01 12:00 AM 03/03/01 12:00 AM 03/04/01 12:00 AM 03/04/01 12:00 AM 03/04/01 12:00 AM 03/04/01 12:00 AM 00:30 01:30 02:30 03:30 04:30 05:00 14:00 18:00 22:30 00:00 04:00 05:30 06:30 10:00 10:30 14:00 15:30 16:30 17:30 18:00 21:30 23:00 00:00 00:30 20:00 22:00 00:00 00:30 01:30 04:00 01:30 02:30 03:30 04:30 05:00 14:00 18:00 22:30 00:00 04:00 05:30 06:30 10:00 10:30 14:00 15:30 16:30 17:30 18:00 21:30 23:00 00:00 00:30 20:00 22:00 00:00 00:30 01:30 04:00 05:30 Operations Summary 1J-03 Install test plug. Change lower pipe rams to 4". Change over top drive & pipe handling to 4". RU to test BOPE. Test BOPE to 250/5000,Annular to 250/3500psi. Test witness waived by AOGCC Inspector John Crisp. Pull test plug, set W.B. L/D test joint. Blow lines. Change elevators & roughneck, LD 5" d.p. Install strip-o-matic, strap RKB, change elevators to 4" & roughneck, PU 4" HT 38 d.p. & stand back 15 stands. Attach kelly hose to TDS PU BHA. Upload tools (3/4 hr) Load source (1/4 hr). PU 4" HT 38 d.p. f/pipeshed & RIH to 2020'. Test MWD @ 2020'. OK. PU 4" HT 38 d.p. Check MWD @ 5615'. Cut 150' drilling line. Service TDS, blocks, drawworks. Blow TDS. Continue PU 4" HT 38 d.p. to jt # 250. Circ. Con't PU 4" HT38 d.p., jt # 250-338. Tag Cement @ 11,108'. Drill out cement in 7" f/11108' to 11148' (40'). CBU+. Circ 275 bbls. RU to test 7" 26#/ft - L-80 casing @ 11148'. Test to 3500 psi for 30 min. OK. R/D testing equip, Drill cement f/11148' to FC @ 11159'-cement- FS @ 11243'-rat hole to 11268'-new hole to 11290'. Note: Drill pipe measurement to casing depths 10' difference. TD was observed to be correct @ 11268' d.p. measurement. Circ new mud around. New mud weight 11.1 ppg. RU for LOT below 7" shoe. Test @ 11290' (6300' TVD) with 11.1 ppg mud & 1060 psi. EMW -- 14.3 ppg. PWD Baseline test. Directional drill 6 1/8" hole from 11290' to 12214' (924') (TVD 6815' @ 12214' MD). ADT= 15.5 hrs. Note: Hole started taking fluid @ 11536' (6435 TVD) @ 50 bph. Building vol, add barofibre, slowed to 25 bph loss & eventually 10 bph w/pumps on. Stati Pump hi vis sweep around. Hole losing 10 bph while pumping @ 6 bpm. Hole static w/pumps off. Pump out of hole to 7" shoe. Pull 11 stands. Hole fill 11 bbls. Pulling 10 k over @ 11889' & 11616'. Monitor hole, service top drive system. RIH tag bottom @ 12214'. No problems. Break circ slowly. CBU, pump sweep around, condition mud & hole for 3 1/2" liner. Monitor. Pump out of hole to 7" shoe @ 11255'. Monitor. Operations Summary 1 J-03 03/04/01 12:00 AM 03/04/01 12:00 AM 03/04/01 12:00 AM 03/04/01 12:00 AM 03/04/01 12:00 AM 03/05/01 12:00 AM 03/05/01 12:00 AM 03/05/01 12:00 AM 03/05/01 12:00 AM 03/05/01 12:00 AM 03/05/01 12:00 AM 03/05/01 12:00 AM 03/05/01 12:00 AM 03/05/01 12:00 AM 03/05/01 12:00 AM 03/05/01-12:00 AM 03/06/01 12:00 AM 03/06/01 12:00 AM 03/06/01 12:00 AM 03/06/01 12:00 AM 03/06/01 12:00 AM 03/06/01 12:00 AM 03/06/01 12:00 AM 03/07/01 12:00 AM 03/07/01 12:00 AM 03/07/01 12:00 AM 03/07/01 12:00 AM 03/07/01 12:00 AM 03/07/01 12:00 AM 05:30 13:00 16:30 18:00 21:00 00:00 04:30 06:30 07:30 08:00 13:00 14:00 15:00 15:30 16:30 17:30 00:00 02:00 03:00 08:00 09:00 21:30 22:30 00:00 01:00 02:00 03:30 05:30 06:30 13:00 16:30 18:00 21:00 00:00 04:30 06:30 07:30 08:00 13:00 14:00 15:00 15:30 16:30 17:30 00:00 02:00 03:00 08:00 09:00 21:30 22:30 00:00 01:00 02:00 03:30 05:30 06:30 07:30 Pump dry job, drop rabbit, SLM, POOH. L/D BHA. Download sources (1/2 hr), Download tool (3/4 hr). Clean floor. Note: Hole took 34 bbls xtra mud on trip out. RU to run 3 1/2" liner. Hold PJSM. PU 3 1/2" liner (33 jts) and hanger. Circ @ 1213' with hanger made up & one stand of 4"dp. Note: 3 1/2" liner weight approx. 7000 #. RIH w/3 1/2" liner on 4" dp. 32 stands of 4" ran with liner at midnight. RIH w/3 1/2" liner on 4" dp to 7" shoe. Fill pipe every 10 stands. Running slow to prevent surging. Circ & Condition mud @ 11205'. RIH w/3 1/2" liner. Tag @ 12214'. Lay down 2 joints to PU Cement head. PU & MU rotating cement head. Break circ slow, monitor losses (Minimal), Increase rate to 5 BPM @ 1900 psi. Press test lines to 5000 psi. Pump 20 bbls preflush- 20 bbls mudpush XL- 50 bbls slurry and drop plug. Displace with 124.5 bbls mud. Bump plug. CIP @ 14:10 hrs 3/5/01 Set liner hanger & packer w/4500 psi. Release f/liner- TOL @ 11101 '. Unsting &circ @ 104 SPM = 3500 psi. while rotating. Lost power on Rig. # 1 Generator breaker trip. Resume circ. & rotation. Approx 7 bbls cement returns. L/D Rotating cement head- pump dry job. POOH - L/D 4" HT 38 d.p. Lay down 4"DP Service top drive, Drawworks, Change filters on hydralic pumps on lay down machine Lay down 4"DP & Liner running tools Pull wear bushing, Rig up tbg. tongs Pick up & run 3.5" Completion string, Tag seal bore @ 11126', Rig to circ., Note:Performed injectivity test on 7" X 9.625" ann. for AGOCC permiting & freeze protect same w/200 bbls H20 & 65 bbls Diesel Break circ., Test csg. to 3500 PSI- OK Pump 30 bbl Desco sweep, 200 bbls fresh H20, Change over to Sea H20 Change over to Sea Water, Monitor well f/15min- OK Land Completion String, RILDS Test tbg. Press to 3000 PSI f/15 min- OK, Test ann press to 3000 f/15 min- OK, Shear DCR Freeze Protect well by pumping 85 bbls diesel down ann. and let U-tube to tbg., Install BPV Change top pipe rams to 4.5" x 7" Nipple down BOP stack, Change top drive to 5" Operations Summary 1J-03 03/07/01 12:00 AM 03/07/01 12:00 AM 03/07/01 12:00 AM 07:30 08:30 09:30 08:30 09:30 14:00 Change top drive back to 4", Prep. to L/D DP Finish nipple down BOP Nipple up tree & test to 5000 PSI, change top drive back to 5" clean pits - release rig at 1400 hrs. Date Well Na Service Type Desc of Work Supervisor RIEDEL Complet r~ Accident C Iniun/ F P Summon/ 05/23/01 1J-03 ELECTRIC LINE PERFORATING Upcoming C Job Num 0321010716.7 Unit SWS 2145 Contractor Key Perso SWS-GARCIA Successful r~ Initial Tbg Press 750 Initial Int Csg Press 1500 Initial Out Csg Press 1000 AFC AK0147 0 Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 Prop 230DS10J Uploaded to Ser PERFORATE 11,833-11,843 MD WITH 2-1/2" HSD, 6 SPF, 60 DEG PHASED, BH-DP CHARGES. TAKE 30 MIN SIBHP OF 3486 PSI AT PERF. [Perf, Pressure Data] Date printed: 07/11/01 at: 15:02:16 Date 06/21/01 Well Na 1J-03 Service Type PUMPING Desc of Work INITIAL A SAND FRAC Supervisor GOBER Complet r~' Accident r- Injury I-- Spill [-' Summary Upcoming F- Job Num 0321010716.7 Unit Contractor Key Perso DS-GALLEGOS Successful ~ Initial Tbg Press 900 Initial Int Csg Press 1300 Initial Out Csg Press 1035 AFC AK0147 0 Prop 230DS 10J Uploaded to Ser Final Tbg Press 2800 Final Int Csg Press 780 Final Out Csg Press 500 A SAND FRAC - PUMP BREAKDOWN STAGE - MAX PRESSURE 9350 PSI AT 27 BPM - PRESSURE BROKE BACK TO 7850 PSI AT 34. ISIP=2174 - FG=0.77 - XS FRICTION=650 PSI AT 15 BPM - PUMP SCOUR STAGE INCLUDING 50 BBLS 50 # XL GEL W/2 PPA 16/2[ CARBOLITE (2000 LBS) - ISIP=2355 PSI - FG=0.8 - XS FRICTION=250 PSI @ 15 BPM - PUMP 100 BBL DATAFRAC - TC=18 MIN - PC: PSI - EFF=42% - INCREASE PAD BY 10 BBLS TO 190 BBLS - PUMP FRAC - NWBSO 294 BBLS INTO THE 6-10 RAMP STAGE - 8.2 PPA ON PERFS - PLACED TOTAL (INCLUDING SCOUR) OF 60400 LBS 16/20 CARBOLITE AND 42317 LBS 12/18 CARB©LITE BEHIND P LEFT 27429 LBS 12/18 CARBOLITE IN THE WELLBORE - ******NOTE: LEFT 1 TREESAVER RUBBER IN THE TREE****** [Frac-Refrac] Date printed: 07/11/01 at: 15:04:26 Date 06/27/01 Upcoming I-- Well Na 1J-03 Job Num 0321010716.7 Service Type ELECTRIC LINE Unit 2145 AFC AK0147 0 Desc of Work PRE-FRAC PERF - 2.5" HSD @ 6 SPF - ALTERNATE BH &DP Supervisor CHANEY Contractor Key Perso SWS-SPENCER Complet I-~ Successful r~ Accident [- Initial Tbg Press 1000 Injury I-- Initial Int Csg Press 0 Spill I-- Initial Out Csg Press 700 Summary PERFORATED "C" SAND INTERVAL 11606' - 11616'. ALSO OBTAINED SBHP OF 3542 PSI @ 11610'. (Perf] Final Tbg Press 1000 Final Int Csg Press 0 Final Out Csg Press 700 Prop 230DS 10J Uploaded to Set Date printed: 07/11/01 at: 15:05:18 Date 06/28/01 Well Na 1J-03 Service Type PUMPING Desc of Work C SAND FRAC Supervisor CHANEY Complet J'- Accident ['- Injury I- r- Summary Upcoming r'- Job Num 0321010716.7 Unit Contractor Key Perso DS-GALLEGOS Successful J-- Initial Tbg Press 800 Initial Int Csg Press 0 Initial Out Csg Press 700 AFC AK0147 0 Prop 230DS10J Uploaded to Set Final Tbg Press 0 Final Int Csg Press 500 Final Out Csg Press 200 "C" SAND FRAC COMPLETED. NWBSO AS 12/18# PROP WENT THROUGH THE PERF'S. PLACED 58067 LBS OF PROP BEHIND PIP OF DESIGN) W/7 PPA OF 12/18# PROP @ THE PERF'S. LEFT 24562 LBS OF PROP IN THE WELLBORE. LOST 25% OF TREESAVER C [Frac-Refrac] Fluid Summary 1550 SEAWATER Date printed: 07/11/01 at: 15:05:57 Well 1J-03 Sidewall Core Descriptions Sample Depth ID (R.) Zone 32450 6185 D 32451 6195 D 32452 6205 D 32453 6215 D 32454 6225 D 32455 6235 D 32456 6245 D 32457 6255 D 32458 6265 D JUN v-fine sand = 0.062-0.125, silt; 0.004-0.062, clay = <0.004 '- t~laska Oi~ & ,,~as ...... Description , olive gray to olive black, yew fine light reddish bro~, fine wi~. a kw dark red to black o~horhombic loo~ng clas~ med. to dark gray wi~ light bro~ clasts, ve~ fine mud with one large (0.5 cra) clast med. grayish bro~, ve~ fine med. grayish bro~ wi~ ~aces of darker elements, ve~ fine light grayish bro~, yew fmc ~ca flake light bro~, ve~ fine wi~ ~or upper fine to coarse grained clasts mostly mud:med, grayish bro~, silt ~x wi~ ve~ fine clasts 32459 6355 B 32460 6362 B 32461 6367 B 32462 6375 B 32463 6385 B 32464 6395 B 32465 6405 B light brown with minor gray, silt dark gray to black, very fine dark grayish brown, very fine dark grayish brown, very fine dark grayish, brown, very fine dark grayish brown, very fine dark gray, silt 32466 6465 32467 6475 32468 6485 32469 6495 32470 6506 32471 32472 32473 32474 32475 32476 32477 6548 6565 6572 6599 6603 6617 6621 A4 dark gray to black, silt A4 dark gray with a f~w specs of med. brown, silt A4 A4 A4 A3 A3 A3 A3 A3 A3 A3 dark brownish gray, silt with 20% very fine gray, silt med. gray, silt med. gray, silt dark gray with a few specs of med. brown, silt dark gray, mUd and silt mix dark gray, mud and silt mix dark gray, silt dark grayish brown, very fine yellowish brown, very fine with handful of small black isogonal clast 32478 32479 32480 6650 6672 6678 A3 A3 A3 32481 32482 32483 6725 6735 6745 A2 A2 A2 dark gray silt matrix with 20% very fine brown clast dark gray, silt and mud mix dark grayish brown, silt with some very fine clast dark grayish brown, silt with some very fine clast rich gray, mud matrix with minor silt gryish red with sparse light brown, silt with ocassional mica flakes 32484 32485 32486 32487 32488 32489 32490 32491 32492 32493 6752 6763 6768 6794 6804 6815 6825 6835 6860 6863 A2 A2 A2 A2 A2 A2 A2 A2 A2 A2 grayish red with light brown, silt med. gray, silt dark gray silt matrix with 20% very fine brown clast med. gray with brown specs, silt No Sample No Sample med. to dark gray, silt, mica rich dark gray, silt med. gray, silt with 30% very fine light brown clast dark grayish brown, fine 1 l-Apr-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well 1J-03 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 12,214.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED DI FJNJT VF Kuparuk River Unit North Slope, Alaska Kuparuk 1J Pad, Slot IJ-03 1J-03 Job No. AKZZlO051, Surveyed: 3 March, 2001 SURVEY REPORT April, Your Ref: APl 500292300200 Surface Coordinates: 5945919.64 N, 558789.96 E (70° 15'46.1408"N, 149° 31' 29.0414" VV) Surface Coordinates relative to Project H Reference: 945919.64 N, 58789.96 E (Grid) Surface Coordinates relative to Structure: 0.00 N, 0.00 E (True) Kelly Bushing: 116.12ft above Mean Sea Level DRILLING SERVICES Survey Ref: svy9409 A Halliburton Company Sperry-Sun Drilling Services Survey Report for 1J-03 Your Ref: APl 500292300200 Job No. AKZZlO051, Surveyed: 3 March, 2001 DEFINITiV Kuparuk River Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -116.12 0.00 201.29 2.190 60.950 85.12 201.24 290.25 2.400 63.910 174.01 290.13 377.02 2.580 68.570 260.70 376.82 471.12 4.540 68.210 354.61 470.73 563.94 6.380 77.610 447.01 563.13 656.58 8.470 72.080 538.87 654.99 747.51 9.880 92.260 628.66 744.78 843.92 10.520 81.980 723.55 839.67 936.60 11.880 75.360 814.47 930.59 1031.32 14.690 71.170 906.64 1022.76 1124.73 17.260 67.890 996.44 1112.56 1217.05 20.300 62.550 1083.84 1199.96 1311.68 25.460 62.610 1171.00 1287.12 1404.34 29.950 60.730 1253.01 1369.13 1501.96 32.190 60.770 1336.62 1452.74 1592.36 36.600 61.050 1411.20 1527.32 1687.00 39.740 60.890 1485.60 1601.72 1780.85 42.650 60.290 1556.21 1672.33 1879.42 46.570 60.290 1626.37 1742,49 1971.13 49.420 60.300 1687.73 1803.85 2064.22 53.180 60.610 1745.93 1862.05 2157.47 56.520 61.040 1799.60 1915.72 2251.92 59.620 60.910 1849.55 1965.67 2346.83 61.750 60.500 1896.02 2012.14 2441.03 64.800 61.220 1938.38 2054.50 2541.58 65.440 61.540 1980.68 2096.80 2630.27 63.610 61.320 2018.82 2134:94 2724.32 63.740 62.140 2060.53 2176.65 2818.89 65.110 63.620 2101.36 2217.48 Local Coordinates Global Coordinates Northings Easfings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5945919.64 N 558789.96E 1.87 N 3.36 E 5945921.53 N 558793.31E 3.51 N 6.52 E 5945923.20 N 558796.45 E 5.02 N 9.97 E 5945924.74 N 558799.89 E 7.18 N 15.40 E 5945926.94 N 558805.30 E 9.65 N 23.85 E 5945929.48 N 558813.73 E 12.86 N 35.37 E 5945932.77 N 558825.23 E 14.61N 49.54E 5945934.64 N 558839.39 E 15.51N 66.52 E 5945935.67 N 558856.36 E 19.10 N 84.13 E 5945939.40 N 558873.94E 25.44 N 104.94 E 5945945.90 N 558894.70 E 34.49 N 128.99 E 5945955.13 N 558918.68 E 47.03 N 155.90 E 5945967.88 N 558945.49 E 63.96 N 188.55 E 5945985.07 N 558978.00 E 84.44 N 226.43 E 5946005.85 N 559015.72 E 109.06 N 270.38 E 5946030.81 N 559059.48 E 133.87 N 315.00 E 5946055.97 N 559103.91 E 162.26 N 366.13 E 5946084.75 N 559154.81 E 192.61 N 419.97 E 5946115.53 N 559208.41 E 226.91N 480.08 E 5946150.30 N 559268.25 E 260.68 N 539.27 E 5946184.52 N 559327.17 E 296.49 N 602.46 E 5946220.83 N 559390.09 E 333.65 N 669.03 E 5946258.50 N 559456.36 E 372.54 N 739.11E 5946297.94 N 559526.14 E 413.03 N 811.28 E 5946339.00 N 559597.99 E 453.99 N 884.76 E 5946380.53 N 559671.15 E 497.68 N 964.83 E 5946424.84 N 559750.87 E 535.97 N 1035.14 E 5946463.68 N 559820.89 E 575.90 N 1109.39 E 5946504.18 N 559894.82 E 614.78 N 1185.31 E 5946543.65 N 559970.43 E North Slope, Alaska Kuparuk 1J Pad Dogleg Vertical Rate Section Comment (°/100ft) 0.00 1.09 3.85 0.27 7.41 0.31 11.16 2.08 16.97 2.20 25.58 2.38 37.25 3.84 50.57 2.00 65.97 2.02 83.19 3.13 104.52 2.92 129.99 3.78 159.63 5.45 196.41 4.94 239.47 2.29 289.84 4.88 340.89 3.32 399.36 3.13 461.15 3.98 530.34 3.11 598.45 4.05 671.07 3.60 747.29 3.28 827.43 2.28 910.17 3.31 994.28 0.70 1085.50 2.08 1165.56 0.79 1249.85 2.02 1335.14 AK-6 BP IFR-AK April, 200~ - 9:23 Page 2 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services- Survey Report for 1J-03 Your Ref: AP1500292300200 Job No. AKZZfOO5f, Surveyed: 3 March, 200'/ Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2913.77 64.730 62.770 2141.58 2257.70 3010.70 66.240 61.640 2181.80 2297.92 3103.00 65.560 60.700 2219.49 2335.61 3200.99 66.380 60.190 2259.39 2375.51 3292.65 65.820 60.450 2296.52 2412.64 3388.16 66.940 60.270 2334.79 2450.91 3482.09 66.250 60.200 2372.10 2488.22 3575.23 66.140 60.330 2409.70 2525.82 3657.59 66.080 59.590 2443.05 2559.17 3760.59 65.120 59.840 2485.60 2601.72 3852.12 64.280 60.050 2524.72 2640.84 3947.45 64.580 61.990 2565.86 2681.98 4039.06 64.750 62.130 2605.07 2721.19 4133.24 65.150 61.660 2644.94 2761.06 4228.51 65.360 61.490 2684.82 2800.94 4325.39 65.960 60.730 2724.75 2840.87 4419.40 66.170 60.710 2762.89 2879.01 4511.22 66.270 62.400 2799.92 2916.04 4604.16 66.110 62.370 2837.44 2953.56 4704.23 66.100 62.150 2877.97 2994.09 4792.09 65.420 62.080 2914.04 3030.16 4884.96 66.620 61.970 2951.79 3067.91 4978.29 66.680 62.130 2988.78 3104.90 5025.90 67.080 61.920 3007.47 3123.59 5088.26 67.210 62.040 3031.69 3147.81 5179.25 65.650 5270.76 66.100 5370.57 65.500 5462.02 64.900 5556.32 64.010 3068.07 3105.48 3146.39 3184.75 3225.41 62.360 62.300 61.960 61.560 61.900 3184.19 3221.60 3262.51 3300.87 3341.53 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 653.53 N 1262.01 E 5946583.00 N 560046.83 E 694.65 N 1340.02 E 5946624.73 N 560124.51E 735.28 N 1413.83 E 5946665.94 N 560198.01 E 779.43 N 1491.68 E 5946710.69 N 560275.51 E 820.92 N 1564.49 E 5946752.75 N 560347.99 E 864.20 N 1640.54E 5946796.62 N 560423.71E 906.99 N 1715.37 E 5946640.00 N 560498.20 E 949.26 N 1789.37 E 5946882.84N 560571.86 E 986.95 N 1854.55 E 5946921.04 N 560636.75 E 1034.26 N 1935.55 E 5946968.98 N 560717.38 E 1075.70 N 2007.18 E 5947010.98 N 560788.68 E 1117.36 N 2082.40 E 5947053.23 N 560863.57 E 1156.16 N 2155.55 E 5947092.59 N 560936.41 E 1196.35 N 2230.81E 5947133.37 N 561011.36 E 1237.54 N 2306.90 E 5947175.15 N 561087.12 E 1280.18 N 2384.18 E 5947218.40 N 561164.07 E 1322.21 N 2459.13 E 5947261.01 N 561238.69 E 1362.23 N 2533.00 E 5947301.60 N 561312.25 E 1401.64 N 2608.35 E 5947341.60 N 561387.28 E 1444.23 N 2689.33 E 5947384.82 N 561467.93 E 1481'.70 N 2760.14 E 5947422.84 N 561538.44E 1521.50 N 2835.07 E 5947463.23 N 561613.07 E 1561.66 N 2910.77 E 5947503.98 N 561688.44E 1582.20 N 2949.44 E 5947524.82 N 561726.95 E 1609.20 N 3000.16 E 5947552.21 N 561777.47 E 1648.09 N 3073.93 E 5947591.68 N 561850.93 E 1686.87 N 3147.90 E 5947631.04 N 561924.59 E 1729.43 N 3228.38 E 5947674.22 N 562004.74 E 1768.71 N 3301.51 E 5947714.07 N 562077.56 E 1809.01 N 3376.45 E 5947754.96 N 562152.18 E Dogleg Rate (°/lOOft) 0.90 1.88 1.19 0.96 0.66 1.19 0.74 0.17 0.82 0.96 0.94 1.86 0.23 0.62 0.27 0.95 0.22 1.69 0.17 0.20 0.78 1.30 0.17 0.93 0.27 1.74 0.50 0.68 0.77 1.00 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 1421.05 1509.23 1593.48 1682.95 1766.72 1854.20 1940.37 2025.55 2100.81 2194.55 2277.26 2363.23 2446.O3 2531.35 2617.87 2706.14 2792.04 2876.06 2961.09 3052.58 3132.69 3217.54 3303.23 3347.02 3404.48 3487.87 3571.39 3662.43 3745.44 3830.52 April, 2001 - 9:23 Page 3 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1J-03 Your Ref: AP1 500292300200 Job No. AKZZfOOSf, Surveyed: 3 March, 200f Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 5651.58 64.600 61.880 3266.72 3382.84 5748.03 66.360 61.810 3306.74 3422.86 5842.10 65.900 61.950 3344.81 3460.93 5933.36 64.730 62.960 3382.92 3499.04 6024.77 66.310 61.660 3420.80 3536.92 6121.30 66.250 61.480 3459.63 3575.75 6216.93 65.600 61.740 3498.64 3614.76 6313.42 65.590 61.790 3538.51 3654.63 6405.04 64.820 62.470 3576.93 3693.05 6500.52 64.540 62.040 3617.77 3733.89 6592.09 63.910 61.950 3657.59 3773.71 6684.72 64.770 62.510 3697.70 3813.82 6777.92 64.580 62.660 3737.56 3853.68 6873.33 65.730 60.250 3777.66 3893.78 6964.87 65.910 60.070 3815.15 3931.27 7062.43 66.490 60.330 3854.52 3970.64 7159.04 66.470 60.370 3893.07 4009.19 7252.46 65.910 60.330 3930.79 4046.91 7344,05 65.450 59.960 3968.51 4084.63 7437.36 65.220 59.930 4007.45 4123.57 7530.87 65.090 61.750 4046.74 4162.86 7624.62 64.850 61.210 4086.41 4202.53 7728.48 65.970 60.870 4129.62 4245.74 7864.95 65.490 64.750 4185.74 4301.86 7959.61 64.080 67.370 4226.07 4342.19 8048.12 62.350 70.630 4265.96 4382.08 8142.08 61.240 73.320 4310.37 4426.49 8234.25 59.550 76.150 4355.91 4472.03 8329.91 57.660 79.210 4405.75 4521.87 8423.24 56.410 81.600 4456.54 4572.66 Local Coordinates Northings Eastings (fi) (fi) 1849.45 N 3452.16 E 1890.86 N 3529.53 E 1931.40 N 3605.39 E 1969.75 N 3678.91E 2008.41 N 3752.57 E 2050.49 N 3830.29 E 2092.00 N 3907.10 E 2133.57 N 3984.51 E 2172.45 N 4058.03 E 2212.63 N 4134.42 E 2251.35 N 4207.22 E 2290.25 N 4281.10 E 2329.04 N 4355.88 E 2370.41N 4431.93 E 2411.96 N 4504.36 E 2456.33 N 4581.82 E 2500.15 N 4658.81E 2542.43 N 4733.08 E 2583.98 N 4805.47 E 2626.45 N 4878.87 E 2667.79 N 4952.96 E 2708.35 N 5027.60 E 2754.08 N 5110.23 E 2810.92 N 5220.86 E 2845.67 N 5299.11 E 2874.00 N 5372.86 E 2899.63 N 5451.58 E 2920.74 N 5528.87 E 2938.18 N 5608.62 E 2951.24 N 5685.82 E Global Coordinates Northings Eastings (ft) (ft) 5947795.99 N 562227.58 E 5947838.00 N 562304.61E 5947879.13 N 562380.17 E 5947918.05 N 562453.38 E 5947957.29 N 562526.73 E 5947999.97 N 562604.12 E 5948042.08 N 562680.60 E 5948084.25 N 562757.69 E 5948123.71 N 562830.91 E 5948164.48 N 562906.98 E 5948203.77 N 562979.48 E 5948243.25 N 563053.05 E 5948282.62 N 563127.53 E 5948324.58 N 563203.24 E 5948366.70 N 563275.35 E 5948411.66 N 563352.46 E 5948456.09 N 563429.10 E 5948498.95 N 563503.05 E 5948541.06 N 563575.11E 5948584.10 N 563648.17 E 5948626.02 N 563721.94 E 5948667.16 N 563796.26 E 5948713.53 N 563878.53 E 5948771.23 N 563988.71E 5948806.60 N 564066.69 E 5948835.50 N 564140.21 E 5948861.74 N 564218.74 E 5948883.45 N 564295.86 E 5948901.52 N 564375.47 E 5948915.18 N 564452.57 E Dogleg Rate (o/'~ooft) 0.62 1.83 0.51 1.63 2.16 0.18 0.72 0.05 1.08 0.50 0.69 1.08 0.25 2.59 0.27 0.64 0.04 0.60 0.62 0.25 1.77 0.58 1.12 2.62 2.91 3.82 2.79 3.24 3.37 2.53 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 3916.36 4004.11 4090.13 4173.05 4256.23 4344.61 4431.92 4519.78 4602.96 4689.26 4771.72 4855.21 4939.45 5026.01 5109.49 5198.71 5287.27 5372.71 5456.13 5540.88 5625.72 5710.67 5805.10 5929.45 6014.85 6093.23 6174.73 6252.83 6331.37 6405.59 11 April, 2001 - 9:23 Page 4 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1J-03 Your Ref: APl 500292300200 Job No. AKZZlO051, Surveyed: 3 March, 2001 Kuparuk River' Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 8517.32 56.060 85.160 4508.84 4624.96 8612.80 55.660 87.510 4562.43 4678.55 8704.07 54.710 91.400 4614.55 4730.67 8798.44 54.000 95.100 4669.56 4785.68 8893.88 '53.720 97.980 4725.85 4841.97 8988.04 53.260 101.020 4781.88 4898.00 9077.33 52.480 105.490 4835.80 4951.92 9175.24 53.240 110.720 4894.94 5011.06 9267.81 53.950 114.450 4949.89 5066.01 9365.12 52.770 118.150 5007.97 5124.09 9458.61 52.390 119.660 5064.79 5180.91 9551.67 52.230 120.270 5121.68 5237.80 9637.95 51.840 120.190 5174.76 5290.88 9738.29 51.750 120.070 5236.82 5352.94 9826.14 52.550 120.830 5290.72 5406.84 9928.04 52.800 120.380 5352.51 5468.63 10022.79 52.640 120.400 5409.90 5526.02 10116.31 52.600 118.650 5466.68 5582.80 10210.05 51.940 121.070 5524.05 5640.17 10303.14 51.970 120.660 5581.42 5697.54 10397.97 51.450 120.250 5640.18 5756.30 10490.99 52.270 119.460 5697.62 5813.74 10584.20 52.560 118.740 5754.48 5870.60 10673.53 53.310 119.070 5808.32 5924.44 10771.01 53.640 118.660 5866.34 5982.46 10865.09 53.020 118.400 5922.52 6038.64 10958.51 53.490 118.270 5978.41 6094.53 11050.57 53.390 118.310 6033.25 6149.37 11142.65 53.100 117.870 6088.35 6204.47 11193.33 52.760 118.240 6118.90 6235.02 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2960.26 N 5763.49 E 5948924.81 N 564530.16 E 2965.31 N 5842.34 E 5948930.48 N 564608.97 E 2966.04 N 5917.25 E 5948931.79 N 564683.87 E 2961.70 N 5993.79 E 5948928.05 N 564760.45 E 2952.93 N 6070.35 E 5948919.88 N 564837.07 E 2940.45 N 6144.98 E 5948907.98 N 564911.80 E 2924.15 N 6214.25 E 5948892.22 N 564981.19 E 2899.89 N 6288.38 E 5948868.54 N 565055.51E 2871.27 N 6357.15 E 5948840.46 N 565124.49 E 2836.71 N 6427.13 E 5948806.44 N 565194.75 E 2800.82 N 6492.13 E 5948771.06 N 565260.02 E 2764.04 N 6555.93 E 5948734.78 N 565324.11E 2729.79 N 6614.70 E 5948701.00 N 565383.14 E 2690.22 N 6682.89 E 5948661.95 N 56545t.64E 2655.06 N 6742.69 E 5948627.26 N 565511.72 E 2613.80 N 6812.43 E 5948586.55 N 565581.78 E 2575.67 N 6877.47 E 5948548.92 N 565647.11 E 2539.05 N 6942.13 E 5948512.81N 565712.05 E 2502.14 N 7006.42 E 5948476.41N 565776.63 E 2464.53 N 7069.35 E 5948439.29 N 565839.85 E 2426.81 N 7133~51 E 5948402.07 N 565904.30 E 2390.39 N 7196.96 E 5948366.15 N 565968.03 E 2354.47 N 7261.50 E 5948330.73 N 566032.85 E 2320.02 N 7323.90 E 5948296.77 N 566095.52 E 2282.20 N 7392.50 E 5948259.49 N 566164.42 E 2246.16 N 7458.80 E 5948223.97 N 566230.99 E 2210.63 N 7524.68 E 5948188.95 N 566297.16 E 2175.58 N 7589.80 E 5948154.42 N 566362.54E 2140.85 N 7654.88 E 5948120.19 N 566427.89 E 2121.83 N 7690.57 E 5948101.45 N 566463.73 E Dogleg Rate (o/looft) 3.17 2.08 3.65 3.27 2.45 2.64 4.09 4.33 3.33 3.28 1.35 0.55 O.46 0.13 1.14 0.43 0.17 1.49 2.16 0.35 0.64 1.11 0.69 0.89 0.48 0.70 0.52 0.11 0.50 0.89 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 6478.31 6550.21 6616.59 6682.02 6745.37 6805.27 6858.63 6912.53 6959.64 7005.02 7045.38 7084.26 7119.90 7161.33 7197.45 7239.46 7278.78 7318.49 7357.75 7395.47 7434.22 7472.96 7512.90 7551.64 7594.27 7635.69 7677.01 7717.86 7758.84 7781.32 April, 2001 - 9:23 Page 5 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for I J-03 Your Ref: APl 500292300200 Job No. AKZZ'IOOSf, Surveyed: 3 March, 200f Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11276.08 52.790 117.050 6168.96 6285.08 2091.26 N 7748.94 E 5948071.33 N 566522.33 E 11369.73 53.670 117.880 6225.02 6341.14 2056.66 N 7815.49 E 5948037.25 N 566589.16 E 11465.01 54.500 118.410 6280.90 6397.02 2020.25 N 7883.53 E 5948001.38 N 566657.48 E 11560.66 54.740 118.610 6336.29 6452.41 1983.03 N 7952.06 E 5947964.70 N 566726.30 E 11660.11 55.250 118.520 6393.34 6509.46 1944.08 N 8023.61 E 5947926.31 N 566798.14 E 11755.52 56.040 117.910 6447.18 6563.30 1906.84N 8093.01E 5947889.61N 566867.84E 11851.40 56.340 117.320 6500.53 6616.65 1869.92 N 8163.60 E 5947853.24 N 566938.72 E 11936.84 56.510 116.850 6547.78 6663.90 1837.51N 8226.98 E 5947821.32 N 567002.35 E 12043.78 56.830 116.590 6606.54 6722.66 1797.33 N 8306.79 E 5947781.77 N 567082.47 E 12137.53 57.060 117.070 6657.67 6773.79 1761.87 N 8376.91E 5947746.86 N 567152.86 E 12142.72 57.050 116.840 6660.50 6776.62 1759.89 N 8380.79 E 5947744.91N 567156.76 E 12214.00 57.050 116.840 6699.27 6815.39 1732.89 N 8434.16 E 5947718.32 N 567210.34E All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Structure. Magnetic Declination at Surface is 26.267° (10-Feb-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Structure and calculated along an Azimuth of 61.830° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of t2214.00ft., The Bottom Hole Displacement is 8610.34ft., in the Direction of 78.390° (True). Dogleg Rate (°/~OOft) 1.15 1.18 0.98 0.30 0.52 0.98 0.60 0.50 0.36 0.49 3.72 0.00 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 7818.34 7860.68 7903.48 7946.32 7991.00 8034.60 8079.40 8119.97 8171.36 8216.43 8218.92 8253.22 Projected Survey April, 2001 - 9:23 Page 6 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1J-03 Your Ref: APl 500292300200 Job No. AKZZlO051, Surveyed: 3 March, 2001 Kuparuk River Unit North Slope, Alaska Kuparuk 1J Pad Comments Measured Depth (ft) 12214.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6815.39 1732.89 N 8434.16 E Comment Projected Survey Survey tool program for 1J-03 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 12214.00 6815.39 Survey Tool Description AK-6 BP_IFR-AK April, 2001 - 9:23 Page 7 of 7 DrillQuest 2.00.08.005 Kuparuk River Unit North Slope, Alaska Kuparuk IJ Pad, Slot 1J-03 I J-03 MWD Job No. AKMM 10047, Surveyed: 3 March, 2001 SURVEY REPORT April, 2001 Your Ref: APl 500292300200 Surface Coordinates: 5945919.64 N, 558789.96 E (70° 15'46.1408"N, 149° 31'29.0414"VV) Surface Coordinates relative to Project H Reference: 945919.64 N, 58789.96 E (Grid) Surface Coordinates relative to Structure: 0.00 N, 0.00 E (True) Kelly Bushing: 116. t2ft above Mean Sea Level Survey Reft svy9412 DRILLING SERVICES A Halliburton Company Sperry-Sun Drilling Services Survey Report for IJ-03 MWD Your Ref: AP1500292300200 Job No. AKMM 10047, Surveyed: 3 March, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -116.12 0.00 201.29 2.190 61.080 85.12 201.24 290.25 2.400 63.920 174.01 290.13 377.02 2.580 68.580 260.70 376.82 471.12 4.540 68.230 354.61 470.73 563.94 6.380 77.640 447.01 563.13 656.58 8.470 72.090 538.87 654.99 747.51 9.880 92.310 628.66 744.78 843.92 10.520 81.990 723.55 839.67 936.60 11.880 75.350 814.47 930.59 1031.32 14.690 1124.73 17.260 1217.05 20.310 1311.68 25.450 1404.34 29.960 1501.96 32.190 1592.36 36.600 1687.00 39.740 1780.85 42.660 1879.42 46.570 71.340 67.84O 62.610 62.45O 60.550 60.520 60.580 60.720 60.100 60.150 60.280 60.610 61.160 61.190 60.730 61.480 60.960 61.650 62.740 63.690 1971.13 49.430 2064.22 53.190 2157.47 56.520 2251.92 59.620 2346.83 61.750 906.64 996.44 1083.84 1170.99 1253.01 1336.62 1411.19 1485.59 1556.20 1626.35 1687.71 1745.89 1799.56 1849.51 1895.97 1938.33 1980.64 2018.78 2060.49 2101.31 2441.03 64.800 2541.58 65.440 2630.27 63.610 2724.32 63.740 2818.89 65.110 1022.76 1112.56 1199.96 1287.11 1369.13 1452.74 1527.31 1601.71 1672.32 1742.47 1803.83 1862.01 1915.68 1965.63 2012.09 2054.45 2096.76 2134.90 2176.61 2217.43 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5945919.64N 558789.96 E 1.86 N 3.37 E 5945921.53 N 558793.31 E 3.50 N 6.53 E 5945923.19 N 558796.46 E 5.01N 9.98 E 5945924.73 N 558799.90 E 7.17 N 15.41E 5945926.93 N 558805.31E 9.63 N 23.86 E 5945929.46 N 558813.74 E 12.83 N 35.38 E 5945932.75 N 558825.24E 14.58 N 49.55 E 5945934.61 N 558839.40 E 15.47 N 66.53 E 5945935.63 N 558856.37 E 19.07 N 84.14 E 5945939.36 N 558873.95 E 25.38 N 104.96 E 5945945.83 N 558894.72 E 34.39 N 129.02 E 5945955.04 N 558918.71 E 46.93 N 155.94 E 5945967.79 N 558945.52 E 63.91N 188.57 E 5945985.02 N 558978.02 E 84.50 N 226.39 E 5946005.91 N 559015.68 E 109.28 N 270.25 E 5946031.03 N 559059.35 E 134.38 N 314.71 E 5946056.48 N 559103.61 E 163.05 N 365.69 E 5946085.54 N 559154.36 E 193.58 N 419.43 E 5946116.48 N 559207.87 E 228.05 N 479.45 E 5946151.43 N 559267.61 E 261.90 N 538.59 E 5946185.74 N 559326.49 E 297.73 N 601.79 E 5946222.06 N 559389.41E 334.82 N 668.40 E 5946259.67 N 559455.73 E 373.46 N 738.62 E 5946298.86 N 559525.64E 413.63 N 810.97 E 5946339.59 N 559597.67 E 454.28 N 884.62 E 5946380.81 N 559671.01 E 498.20 N 964.57 E 5946425.35 N 559750.61 E 536.64 N 1034.80 E 5946464.34 N 559820.54E 575.96 N 1109.36 E 5946504.24 N 559894.79 E 614.40 N 1185.51 E 5946543.27 N 559970.64E Dogleg Rate (°/'~OOft) 1.09 0.27 0.31 2.08 2.20 2.38 3.84 2.01 2.02 3.12 2.94 3.77 5.43 4.96 2.28 4.88 3.32 3.14 3.97 3.12 4.05 3.60 3.28 2.28 3.31 0.79 2.18 1.05 1.71 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 0.00 3.85 7.41 11.16 16.97 25.58 37.25 50.56 65.96 83.18 104.50 129.97 159.62 196.40 239.46 289.83 340.87 399.34 461.13 530.32 598.44 671.07 747.29 827.44 910.18 994.30 1085.51 1165.57 1249.86 1335.14 MWD Magnetic 11 April, 2001 - 9:18 Page 2 of 7 DriilQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1J-03 MWD Your Ref: AP1500292300200 Job No. AKMM 90047, Surveyed: 3 March, 200'/ Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth 2913.77 64.730 62.440 2141.53 2257.65 3010.70 66.240 61.300 2181.75 2297.87 3103.00 65.560 60.430 2219.44 2335.56 3200.99 66.380 59.980 2259.35 2375.47 3292.65 65.820 60.190 2296.48 2412.60 3388.16 66.940 59.290 2334.75 2450.87 3482.09 66.250 58.610 2372.06 2488.18 3575.23 66.140 59.650 2409.65 2525.77 3667.59 66.080 59.760 2447.06 2563.18 3760.59 65.120 60.020 2485.48 2601.60 3852.12 64.280 60.170 2524.59 2640.71 3947.45 64.580 62.310 2565.74 2681.86 4039.06 64.750 62.300 2604.94 2721.06 4133.24 65.140 61.880 2644.83 2760.95 4228.51 65.360 61.760 2684.71 2800.83 4325.39 65.960 61.400 2724.64 2840.76 4419.40 66.170 61.150 2762.78 2878.90 4511.22 66.270 62.420 2799.81 2915.93 4604.16 66.110 61.810 2837.33 2953.45 4704.23 66.090 62.140 2877.87 2993.99 4792.09 65.430 62.560 2913.94 3030.06 4884.96 66.620 62.120 2951.68 3067.80 4978.29 66.680 62.200 2988.67 3104.79 5025.90 67.080 62.140 3007.36 3123.48 5088.26 67.210 62.130 3031.58 3147.70 5179.25 65.650 62.340 3067.97 3184.09 5270.76 66.090 62.400 3105.38 3221.50 5370.57 65.500 62.150 3146.30 3262.42 5462.02 64.900 61.760 3184.66 3300.78 5556.32 64.010 62.180 3225.32 3341.44 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 653.32 N 1262.12 E 5946582.80 N 560046.94 E 694.90 N 1339.89 E 5946624.98 N 560124.38 E 735.92 N 1413.48 E 5946666.58 N 560197.66 E 780.39 N 1491.15 E 5946711.65 N 560274.97 E 822.19 N 1563.78 E 5946764.01N 560347.28 E 866.29 N 1639.37 E 5946798.70 N 560422.51 E 910.75 N 1713.22 E 5946843.73 N 560496.01 E~ 954.47 N 1786.36 E 5946888.03 N 560568.81 E 997.07 N 1859.27 E 5946931.19 N 560641.39 E 1039.56 N 1932.54 E 5946974.25 N 560714.32 E 1080.81N 2004.27 E 5947016.07 N 560785.73 E 1122.18 N 2079.65 E 5947058.02 N 560860.78 E 1160.66 N 2152.96 E 5947097.08 N 560933.80 E 1200.60 N 2228.36 E 5947137.60 N 561008,87 E 1241.46 N 2304.62 E 5947179.05 N 561084.82 E 1283.47 N 2382.25 E 5947221.67 N 561162.12 E 1324.76 N 2457.60 E 5947263.55 N 561237.14 E 1364.49 N 2531.64 E 5947303.85 N 561310.87 E 1404.26 N 2606.80 E 5947344.21 N 561385.71 E 1447.24 N 2687.56 E 5947387.82 N 561466.14 E 1484.42 N 2758:52 E 5947425.55 N 561536.81E 1523.82 N 2833.68 E 5947465.53 N 561611.66 E 1563.83 N 2909.45 E 5947506.14 N 561687.11E 1584.27 N 2948.17 E 5947526.88 N 561725.67 E 1611.13 N 2998.97 E 5947564.14 N 561776.26 E 1649.98 N 3072.76 E 5947593.56 N 561849.75 E 1688.71 N 3146.75 E 5947632.87 N 561923.43 E 1731.06 N 3227.34 E 5947675.85 N 562003.68 E 1770.09 N 3300.61 E 5947715.45 N 562076.64E 1810.08 N 3375.71 E 5947756.02 N 562151.43 E Dogleg Rate (ot,~ooft) 1.26 1.89 1.13 0.94 0.65 1.46 0.99 1.03 0.13 1.06 0.93 2.05 0.19 0.58 0.26 0.71 0.33 1.27 0.62 0.30 0.87 1.35 0.10 0.85 0.21 1.73 0.48 0.63 0.76 1.03 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 1421.05 1509.24 1593.48 1682.94 1766.70 1854.15 1940.24 2025.36 2109.75 2194.39 2277.11 2363.09 2445.88 2531.20 2617.72 2705.99 2791.91 2875.93 2960.96 3052.45 3132.56 3217.41 3303.09 3346.88 3404.34 3487.74 3571.25 3662.28 3745.29 3830.37 April, 200~ - 9:~8 Page 3 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1J-03 MWD Your Ref: AP1500292300200 Job No. AKMM f0047, Surveyed: 3 March, 200f Kuparuk River Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 5651.58 64.610 62.000 3266.62 3382.74 5748.03 66.360 59.620 3306.64 3422.76 5842.10 65.900 62.870 3344.72 3460.84 5933.36 64.730 62.830 3382.83 3498.95 6024.77 66.310 61.860 3420.71 3536.83 6121,30 66.250 61.430 3459.54 3575.66 6216.93 65.600 61.830 3498.55 3614.67 6313.42 65.590 61.870 3538.42 3654.54 6405.04 64.820 62.500 3576.84 3692.96 6500.52 64.530 62.100 3617.68 3733.80 6592.09 63.910 61.880 3657.51 3773.63 6684.72 64.770 62.610 3697.62 3813.74 6777.92 64.580 62.930 3737.48 3853.60 6873.33 65.730 60.430 3777.58 3893.70 6964,87 65,900 60.220 3815.08 3931.20 7062.43 66.490 60.490 3854.46 3970.58 7159.04 66.470 60.530 3893.01 4009.13 7252.46 65.900 60.370 3930.73 4046.85 7344.05 65.450 59.910 3968.46 4064.58 7437.36 65.220 59.820 4007.40 4123.52 7530.87 65.090 61.070 4046.69 4162.81 7624.62 64.850 60.540 4086.35 4202.47 7728.48 65.970 60.820 4129.57 4245.69 7864.95 65.490 64.010 4185.68 4301.80 7959.61 64.080 66.580 4226.01 4342.13 8048.12 62.350 69.920 4265.90 4382.02 8142.08 61.240 72.710 4310.32 4426.44 8234.25 59.540 75.500 4355.86 4471.98 8329.91 57.660 77.730 4405.71 4521.83 8423.24 56.420 80.920 4456.49 4572.61 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (rt) (ft) (ft) 1850.26 N 3451.56 E 5947796.79 N 562226.97 E 1893.06 N 3528.16 E 5947840.19 N 562303.23 E 1934.44 N 3603.56 E 5947882.16 N 562378.31 E 1972.28 N 3677.34 E 5947920.57 N 562451.79 E 2010.90 N 3751.02 E 5947959.76 N 562525.17 E 2052.87 N 3828.80 E 5948002.34 N 562602.61E 2094.36 N 3905.62 E 5948044.43 N 562679.11E 2135.81 N 3983.10 E 5948086.48 N 562756.26 E 2174.62 N 4056.66 E 5948125.87 N 562829.52 E 2214.74 N 4133.07 E 5948166.58 N 562905.61E 2253.46 N 4205.87 E 5948205.87 N 562978.11 E 2292.34 N 4279.76 E 5948245.33 N 563051.69 E 2330.89 N 4354.66 E 5948264.46 N 563126.29 E 2371.96 N 4430.87 E 5948326.13 N 563202.17 E 2413.31N 4503.42 E 5948368.03 N 563274.40 E 2457.46 N 4581.00 E 5948412,79 N 563351.63 E 2501.06 N 4658.10 E 5948457.00 N 563428.39 E 2543.21 N 4732.45 E 5948499.72 N 563502.41 E 2584.77 N 4804.83 E 5948541.84 N 563574.46 E 2627.34 N 4878.17 E 5948564.98 N 563647.46 E 2669.19 N 4951.98 E 5948627.41 N 563720.95 E 2710.63 N 5026.13 E 5948669.43 N 563794.78 E 2756.87 N 5108.47 E 5948716.31 N 563876.75 E 2814.48 N 5218.72 E 5948774.78 N 563986.55 E 2850.27 N 5296.51 E 5948811.18 N 564064.05 E 2879.56 N 5369.87 E 5948841.04 N 564137.18 E 2906.09 N 5448.29 E 5948868.18 N 564215.40 E 2928.05 N 5525.34 E 5948890.74 N 564292.27 E 2946.97 N 5604.76 E 5948910.28 N 564371.54E 2961.48 N 5681.69 E 5948925.39 N 564448.36 E Dogleg Rate (o/,Iooft) 0.65 2.89 3.20 1.28 1.98 0.41 0.78 0.04 1.05 0.49 0.71 1.17 0.37 2.67 0.28 0.66 0.04 0.63 0.67 0.26 1.22 0.57 1.11 2.16 2.87 3.89 2.87 3.21 2.80 3.16 North Slope, Alaska Kuparuk I J Pad Vertical Section Comment 3916.22 4003,95 4089,95 4172.86 4256.04 4344.42 4431.73 4519.59 4602.77 4689.07 4771.52 4855.01 4939.24 5025.81 5109.29 5198.52 5287.08 5372.52 5455.94 5540.69 5625.52 5710.45 5804.87 5929.25 6014.72 6093.22 6174.88 6253.17 6332.11 6406.79 April, 2001 - 9:18 Page 4 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey RePort for 1J-03 MWD Your Ref: APl 500292300200 Job No. AKMM 10047, Surveyed: 3 March, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8517.32 56.060 84.560 4508.78 4624.90 8612.80 55.660 86.800 4562.37 4678.49 8704.07 54.710 90.650 4614.49 4730.61 8798.44 53.990 93.870 4669.51 4785.63 8893.88 53.710 97.040 4725.82 4841.94 8988.04 53.170 100.570 4781.91 4898.03 9077.33 52.480 104.560 4835.88 4952.00 9175.24 53.240 109.700 4895.02 5011.14 9267.81 53.950 113.410 4949.97 5066.09 9365.12 52.770 117.170 5008.06 5124.18 5064.87 5121.77 5174.86 5236.91 5290.82 9458.61 52.390 . 118.680 9551.67 52.220 119.180 9637.95 51.840 119.110 9738.29 51.750 119.190 9826.14 52.550 119.700 5180.99 5237.89 5290.98 5353.03 5406.94 9928.04 52.800 119.190 5352.60 5468.72 10022.79 52.630 119.320 5410.00 5526.12 10116.31 52.610 117.510 5466.78 5582.90 10210.05 51.930 120.450 5524.15 5640.27 10303.14 51.960 120.400 5581.53 5697.65 10397.97 51.450 119.650 5640.30 5756.42 10490.99 52.270 118.230 5697.75 5813.87 10584.20 52.560 116.990 5754.60 5870.72 10673.53 53.310 117.250 5808.44 5924.56 10771.01 53.630 116.400 5866.47 5982.59 10865.09 53.020 116.190 5922.66 6038.78 10958.51 53.490 117.400 5978.55 6094.67 11050.57 53.400 117.360 6033.38 6149.50 11142.65 53.100 117.300 6088.47 6204.59 11193.33 52.760 117.500 6119.02 6235.14 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2971.37 N 5759.26 E 5948935.89 N 564525.85 E 2977.33 N 5838.05 E 5948942.46 N 564604.59 E 2979.01 N 5912.94 E 5948944.72 N 564679.46 E 2976.00 N 5989.55 E 5948942.31N 564756.09 E 2968.67 N 6066.25 E 5948935.59 N 564832.85 E 2957.11 N 6140.97 E 5948924.60 N 564907.66 E 2941.65 N 6210.39 E 5948909.69 N 564977.20 E 2918.66 N 6284.93 E 5948887.28 N 565051.91 E 2891.28 N 6354.20 E 5948860.44 N 565121.39 E 2857.95 N 6424.78 E 5948827.67 N 565192.23 E 2823.18 N 6490.39 E 5948793.41 N 565258.11 E 2787.56 N 6554.83 E 5948758.30 N 565322.83 E 2754.44 N 6614.24 E 5948725.64 N 565382.49 E 2716.03 N 6683.10 E 5948687.77 N 565451.65 E 2681.93 N 6743.51 E 5948654.14 N 565512.32 E 2642.10 N 6814.07 E 5948614.86 N 565583.19 E 2605.26 N 6879.84 E 5948578.53 N 565649.25 E 2569.90 N 6945.20 E 5948543.68 N 565714.88 E 2533.99 N 7010.04 E 5948508.28 N 565780.01 E 2496.87 N 7073.25 E 5948471.66 N 565843.50 E 2459.63 N 7137.69 E 5948434.92 N 565908.23 E 2424.23 N 7201.71 E 5948400.03 N 565972.52 E 2390.00 N 7267.16 E 5948366.31N 566038.24 E 2357.51 N 7330.61 E 5948334.31 N 566101.94 E 2322.16 N 7400.51E 5948299.51N 566172.11E 2288.74 N 7468.15 E 5948266.61 N 566240.02 E 2254.99 N 7534.97 E 5948233.39 N 566307.09 E 2220.98 N 7600.64 E 5948199.89 N 566373.02 E 2187.11N 7666.18 E 5948166.53 N 566438.83 E 2168.50 N 7702.08 E 5948148.21N 566474.88 E Dogleg Rate (°/lOOft) 3.24 1.99 3.62 2.88 2.70 3.07 3.64 4.26 3.32 3.33 1.35 0.46 0.45 0.11 1.02 0.47 0.21 1.54 2.58 0.05 0.82 1.49 1.10 0.87 0.77 0.67 1.15 0.10 0.33 0.74 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 6479.83 6552.11 6618.92 6685.03 6749.19 6809.60 6863.50 6918.35 6966.49 7012.98 7054.40 7094.40 7131.13 7173.70 7210.85 7254.25 7294.84 7335.76 7375.98 7414.18 7453.40 7493.13 7534.67 7575.26 7620.19 7664.04 7707.01 7748.85 7790.64 7813.50 DrillQuest 2.00.08.005 '1'1 April, 2001 - 9:'i8 Page 5 of 7 Sperry-Sun Drilling Services Survey Report for 1J-03 MWD Your Ref: APl 500292300200 Job No. AKMM f0047, Surveyed: 3 March, 200f Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11276.08 52.790 117.730 6169.08 6285.20 2137.95 N 7760.47 E 5948118.12 N 566533.50 E 11369.73 53.670 118.320 6225.14 6341.26 2102.71 N 7826.68 E 5948083.39 N 566599.99 E 11465.01 54.500 117.590 6281.03 6397.15 2066.54 N 7894.85 E 5948047.75 N 566668.43 E 11560.66 54.740 118.130 6336.41 6452.53 2030.09 N 7963.79 E 5948011.85 N 566737.66 E 11660.11 55.240 119.500 6393.47 6509.59 1990.83 N 8035.16 E 5947973.14 N 566809.33 E 11755.52 56.040 115.960 6447.33 6563.45 1954.20 N 8104.86 E 5947937.06 N 566879.32 E 11851.40 56.340 116.040 6500.68 6616.80 1919.28 N 8176.46 E 5947902.70 N 566951.19 E 11946.84 56.510 116.050 6553.46 6669.58 1884.36 N 8247.90 E 5947868.34 N 567022.90 E 12043.78 56.820 115.910 6606.74 6722.86 1848.89 N 8320.71 E 5947833.43 N 567095.98 E 12137.53 57.060 116.360 6657.88 6774.00 1814.28 N 8391.25 E 5947799.38 N 567166.79 E 12142.72 57.050 115.760 6660.70 6776.82 1812.36 N 8395.16 E 5947797.49 N 567170.72 E 12214.00 57.050 115.760 6699.47 6815.59 1786.37 N 8449.03 E 5947771.92 N 567224.79 E All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Structure. Magnetic Declination at Surface is 26.267° (10-Feb-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Structure and calculated along an Azimuth of 61.830° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12214.00ft., The Bottom Hole Displacement is 8635.81ft., in the Direction of 78.062° (True). Dogleg Rate (°/100ft) 0.22 1.07 1.07 0.52 1.24 3.18 0.32 0.18 0.34 0.48 9.70 0.00 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 7850.55 7892.28 7935.3O 7978.87 8023.25 8067.40 8114.04 8160.54 8207.97 8253.81 8256.36 8291.58 Projected Survey April, 2001 - 9:18 Page 6 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 'i J-03 MWD Your Ref: APl 500292300200 Job No. AKMM 10047, Surveyed: 3 March, 2001 Kuparuk River Unit North Slope, Alaska Kuparuk 1J Pad Comments Measured Depth (ft) 12214.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6815.59 1786.37 N 8449.03 E Comment Projected Survey Survey tool program for lJ-03 MWD From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 12214.00 Vertical Depth (ft) 6815.59 Survey Tool Description MWD Magnetic 11 April, 2001 - 9:18 Page 7 of 7 DrillQuest 2.00.08.005 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 17, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7t~ Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Second Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader RECEIVED PM/skad JUL 1 9 ZOO1 CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Alaska 0il & Gas Cons. Commission Anchorage Annular Dia oosal durin the second ,uarter ~ 2001' h(1) h(2) h(3) Total for PrevioUs New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1C-133, IC-121, IC-123, 1C-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 21ql-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 16902 100 0 17002 0 17002 May 01 Jun 01 cD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli 3r which Dis posal Authorization Expired during the second quarter 2001: Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down.... CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CDI~NQ1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, Alaska April 24, 2001 RE: MWD Formation Evaluation Logs 1J-03, AK-MM-10047 1 LDWG formatted Disc with verification listing. API#: 50-029-23002-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Gal~ 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED I'IAY 0 1 2001 Alaska Oil & Gas Cons. Commmion And~omge 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 April 24, 2001 RECEIVED ~PR ~ 5 2.00! Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7t~ Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, First Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the first quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the first quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Annular Disposal during the first quarter o[2001. ' h(1) h~(2) h(3~ Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date CD1-44 8929 100 0 9029 22899 31928 Dec. '00 Jan.'01 COl-33, cDI-~Q1, CD1-10, Cm-28 2N-318 12276 100 . 0 12376 1619 13995 Dec.'00 Jan.'01 2N-314 CD1-43 30552 100 0 30652 385 31037 Jan.'01 Feb.'01 CD1-NQ1, CD1-21 CD1-31 6698 100 0 6798 392 7190 Feb.'01 Mar.'01 CDI-14 1D-42 17187 100 0 17287 15118 32405 Dec.'00 Jan.'01 1D-37, 1D-39 ~ 1D-32 23162 100 0 23262 337 23599 Jan.'01 Feb.'01 1D-39 1J-03 13020 100' 0 13120 0 13120 Mar.'01 Mar.'01 1J-09~ 1J-14 Total Volumes into Annuli ~or which Disposal Authorization Expired during the first quarter 2001' Total Voiume Start End Source Wells Total h(1) Total h(2) Total h(3) InjeCted Date Date Well Name Volume Volume Volume Status of Annulus 1L-28 9837 100 0 9937 Open, Freeze Protected March 2000 April 2000 1L-20A, 1L-26A CD1-27 32714 100 0 32814 Open, Freeze Protected May 2000 June 2000 CD1-44, CDI-19A, CD 1-09, CD 1-06 CD1-38 20220 100 0 20320 Open, Freeze Protected March 2000 May 2000 CD1-44, CD1-41, CD1- 19A CD1-05 286 100 0 386 Open, Freeze Protected Jan. 2000 Jan. 2000 CD1-05 CD1-03 33890 100 0 33990 Open, Freeze Protected Aug. 2000 Sept. 2000 CD1-43, CD1-31, CD1- 30 ZoO- O~ _ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing_ Repair well _ Plugging _ Time extension _ Stimulate _ Other _X Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Disposal 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 34 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service_ Kuparuk River Unit 4. Location of well at surface 8. Well number 2107' FSL, 2419' FEL, Sec. 35, T11N, R10E, UM 1J-03 At top of productive interval 9. Permit number / approval number 1193' FNL, 240' FWL, Sec. 31, T11 N, R11 E, UM (proposed) 201-024 At effective depth 10. APl number 50-029-23002-00 At total depth 11. Field / Pool 1264' FNL, 367' FWL, Sec. 31, T11 N, R11 E, UM (proposed) Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured 12214 feet Plugs (measured) true vertical 6815 feet Effective depth: measured 12146 feet Junk (measured) true vertical 6777' feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 84' 16" 400 sx AS ~ 118' 118' Surface 7750' 9.625" 770 sx AS Lite & 486 sx LiteCrete 7784' 4232' Production 11221' 7" 17o sx Class G 11255' 6277' Liner 3.5" 256 sx C~ass G 12214' 6815' Perforation depth: measured Not available RECEIVED true vertical Not available MJ~R Z001 Alaska Oil & Gas Cons. Commission Tubing (size, grade, and measured depth Not available Anchorage Packers & SSSV (type & measured depth) Not available 13. Attachments Description summary of proposal__ Detailed operations program _ BOP sketch _ Schematic I Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets __ X 14. Estimated date for commencing operation 15. Status of well classification as: March 7, 2001 16. If proposal was verbally approved Oil __X Gas __ Suspended Name of approver Date approved Service . 17. I hereby ci rtify that the foregoing is true and correct to the best of my knowledge. Questions? Call Todd Mushovic 265-6974 ~ . Signed :~ ha~`~ I /~ q~/,,,,L.._' Title: Drilling Engineering Supervisor Ja~.~..~ Prepared b~/ Sharon Al/sup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. I (~--'"7 Plug integrity_ BOP Test _ Location clearance_ __ ~ Mechanical Integrity Test_ Subsequent form required 10-~~----~ ~.a ~-~~~ ORIGINAL SIGC,~L L:, D Taylor Searnoun~ _ Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE A ,,ulus Disposal Transmittal m a. Designation of the well or wells to receive drilling wastes; 1J-03 b. The depth to the base of freshwater aquifers and permafrost, if present; No Aquifers;Bpf-1427 tvd - RKB c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission From the 9-5/8" shoe to the Cement top all that finding that the waste will be confined and will not come to the is open is shale or minor Campanian Sands surface or contaminate freshwater; that were not hydrocarbon bearing. d. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste; See Attached Map indicating no wells within 1/4 miles or water wells within 1 mile e. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry; Types of fluids can be mud, diesel, cement, water. Maximum volume to be pumped is 32,000 bbls. f. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operation and calculations showing how this value was determined. Maximum anticipated pressure at casing shoe during disposal operations is 2543 psi. See attached calculation page g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. attached cementing reports, LOT/FIT reports, and casing reports h. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. attached: casing summary sheet and calculation pages. i. Any additional data required by the Commission to confirm containment of drilling wastes. RECEIVED JVIAR ZOOl Alaska Oil & Gas Cons. Commission Anchora§e Phillips Alaska Drilling Cementing Details Well Name: 1J-03 Report Date: 02/28/2001 Report Number: 2 Rig Name: Nabors 16E AFC No.: AK0145 Field: Casing Size Hole Diameter: Angle thru KRU: I Shoe Depth: I LC Depth: % washout: Centralizers State type used, intervals covered and spacing Comments: Spiralator on jts 2, 4-20, Bowsprtng on jts I and 3. Centering guides on 217, 220, 223, 226, 229, 232, 235, 238, 241,244, 247, 250, 253, 256, 259, 262, 265, 270. Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 9.8 14 12I 14 13 Gels before: Gels after: Total Volume Circulated: 6/7 5/6 1282 Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 8.4 Spacer 0 Type: Volume: Weight: Comments: MUDPUSHXL 32 12 Additives: .2% D46, .3% D65, .15% D800 Additives: Diaplacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 6 6 270 · I Reciprocation length: Reciprocation speed: : , Str. Wt. Down: :: : ' 15 15 155 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 417.7 418.9 Calculated top of cement: CP: Bumped plug: Floats held: 10429 Date: 2/28/01 Yes Yes Time:2140 Remarks:Good returns throughout Job. Able to reciprocate throughout Job. Cement Company: Rig Contractor: Approved By: Dowell NABORS G.R. Whitlock/Granville Rizek RECEIVED Alaska Oil & Gas Cons. Comrriissior~ Anchorage i" Casing Detail ii' 7" Intermediate casing WELL: 1J-03 Phillips Alaska Inc. DATE: 02/28/01 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors ]6E RTto LDS=31.75' TOPS 7" Landing Joint (RKB) 31.75 7" FMC GEN V FLUTED MANDREL HANGE~ 2.00 3~ .75 jts 3-274 7", 2~, L-80 BTC-MOD (272 jts) ] ] ~ 35.00 33.75 Gemeco FIo~t Collar ~.22 ~ ~ ] 5q.75 j~s ~-2 7", 25~, L-80 BTC-MOD (2 its) 82.24 ] ~ ~ 70.~7 Gemeco FIo~t Shoe ~.45 ~ ] 253.2] B~M OF SHOE ~ ~ ~254.~ TD of 8-]/2" hole = Run ~ Str=ight bi=de centrilizers per joint on joints 1-20. 2, 4-20 (tot=l 18 on 18 stop b=nds) (Note; joints 1 & 3 will h=ve bow springs due to flo=t equipment) Tofol of 2 bowsprings on ~op b=nds Run ~ centering guide on joints 2~ 7, 220, 223, 225, 229, 232, 235, 238, 241,244, 247,2~, 253, 256, 259, 262, 265, 270. (18 total) ..... Alaska Oil ~ Gas Ooo~, 0~:.., Remoras; ~riog Weights wit~ Bloo~s: 270~ UP Wt ~55~ O~, 70~ Bloo~s. ~o~ 27~ joiots of oosiog. Ori~eO oosiog wit~ 6. ~ 5 ~ "~lostio roOOff. Os~O dot ~uOo t~rooO oomoou~O oo co~ooctio~s. NoOors ~66 Drilliog Suoe~isors: ~.~. W~itloo~/Grooville Casing Detail 9-5/8" surface casing WELL: 1J-03 Phillips Alaska, Inc. Dote: 02/22/01 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors 16E RT to LDS = 34.52' TOPS 34.52 9-5/8" FMC GEN V FLUTED MANDREL HANGER 2.20 34.52 Jts167-190 9.625", 40#, 1_-80 BTC-MOD (24 jts) 968.80 36.72 Tam Port Collar 2.95 1005.52 jts 3-166 :9.625", 40#, L-80 BTC-MOD (164jts) 6690.65 1008.47 Gemeco Float Collar 1.53 7699.12 jts 1-2 9.625", 40#, L-80 BTC-MOD (2 jts) 81.69 7700.65 Gemeco Float Shoe 1.73 7782.34 Shoe @ 7784.07' >>>>> 7784.07 TD of 12-1/4" hole = 7795'MD 1 Weatherford bow spring centralizer on jts. 1 & 3 11 Weatherford SpiraGlider Centralizers on jts. 2 & 4-13 1 Weatherford bow spring centralizer on every 3rd collar starting with it. 16 thru 188 Install TAM Port Collar between jts. 166 & 167 I V LT.. LJ Anuhu~'aqe Remorks: String Weights with Blocks: 330k Up, 140k Dh, 70k Blocks. Ron 190joints of cosing. Drifted cosing with 8.579" plostic robbit. Used Best-o-Life 2000 threod compound on oll connections, Phillips Alaska Drilling Cementing Details Well Name: 1J-03 Report Date: 02/22/2001 Report Number: 1 Rig Name: Nabors 16E AFC No.: AK0145 Field: Kuparuk River Unit Centrsllzers State type used, intervals covered and spacing Comments: 1 Weatherfor bowspring centralizer/jt on jts I and 3 wi stop collars. 11 Weatherford spiragliders (1fit) on jts 2 & 4-13,1 bowsprlng centralizer/it on every 3rd collar starting jt 16 thru 188 (59 Total) Mud Weight: PV(prior cond): Pr(after cond): YP(prior cond): YP(after cond): Comments: 9.7 14 11 12 10 Gels before: Gels after: Total Volume Circulated: 4/5 3/4 2500 BBL's Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 8.4 Spacer 0 Type: Volume: Weight: Comments: MUDPUSHXL 50 10.7 Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: Weight: Yield: Comments: ASLIteI 75 770 10.7 4.45 Additives: G w/50% BWOC D124, 30% BWOC D53,1.5% BWOC S1, .6% BWOC D46, 1.5% BWOC D79, .5% BWOC D65, 9% BWOW D44 MteCRETE Additives: G w/34% BWOC D124, 21% BWOC D164, .6% D65, .35% BWOC D79, .1% BWOC D46 Displacement 0 = Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: : 8 8 330 : : : Reciprocation length: Reciprocation speed: Str. Wt. Down: i' : 20 20 140 · Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 583.8 584.1 264700 Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:2/22/00 Yes Yes Time:16:10 Remarks:Had good returns throughout Job. Circulated 50 bbl cement to surface. , Cement Company: Dowell IRig Contractor: NABORS Approved By: G.R. Wh t ock/Granv e Rizek Alaska Oil ~ Gas Cons, Anc'~o~ a~e Commission CASING TEST and FORMATION INTEGRITY TEST Well Name: 1J-03 Date: 2/24/01 Reason(s) for test: Supervisor: Whitlock/Rizek [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40# L-80, BTC Casing Setting Depth: 7,784' TMD Hole Depth: 4,268' TVD Mud Weight: 8.5 ppg Length of Open Hole Section: 7,829' TMD 4,287' TVD 45' EMW = Leak-off Press. + Mud Weight = 1,400 psi 0.052 x TVD 0.052 x 4,287' EMW for open hole section = 14.8 ppg + 8.5 ppg Pump output = 0.0846 bps Fluid Pumped = 7.6 bbl 3,000 psi 2.900 p~ 2,8O0 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,003 psi 1,9C0 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 3OO psi 200 psi 100 psi 0 psi LEAK-OFF TEST ~i ~ ~'~ ~ ............... ~CASING TEST .). "~ LOT SHUT IN TIME ~" 3: -- CASING TEST SHUT IN TIME ~ TIME LINE : ~ ~ ~ . _ STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ...................... ..... ii' ,]E .... ir ................ ..... .... 1 ................................................. .4 ~- ................................ '4 ........ ~ 4stks ] 125 psi. j J , 4stks ! 140Esi J ................,' ............... ,, ............... .'~',?,O~r, .............. ,, ............... ~, ............ '.-"~, , 8 stks , 225 psL , , . ............ ,....8___s_t_.k.s....,.____2_9__0..l~..sJ___, ................ 1-"i'~'~i~"-i---'~D"l~'~i.~,$;b,~'' ~ 12 stks I 450 [;si i ................ -I-, ............... ~, ............................. .:~,.~q.,'.~ ,F ............... -I, .......... ~ ...... . -I, : 16 stks ~ 500 s~. ~ , _ ............. ,__.1_.6...s.t._k.s.._L_..6..2_.5_. _.si...: ................ T ............... i ......... --P:'-~'),,b~," ! i R. . 20stks , 625ps, , , , 20stks , 800ps~ , ................ T ............... i ............. '~"t,'~,~E ............... i' ............... 1 ............. 24stks , 750psm , , 24stks , 910~sm- ................ -J- ............... + ...............i ................ i. ............... .4 .......... i 28 stks i 850 psi_'~ ~o~,_' ! 28 stks ! 1,060 ps, ................ ,~ ............... ~ ............. ~',~? .............. ," ............... i ............... : 32stks : 950 ps, .... 32stks , 1,200ps~ , I · i i i i · i , 36stks , 1,050nSL, , ~ 36stks ~ 1,350ps~ ................ '{, ................ ~, ........... "' .... .¥~C~ G, ............... ,r ............... ~, ................. . '~, 40stks ~ 1,150ps~.: ~ ~ 40stks ~ 1,500ps~ ~ ................Tll~--~'-~i~; -- -- J ' -- ~l ,l~-- ~'~ ~ ............... ['']~ '~i~:';''i''"i;i:'~'::i' i:; ;i'i ................ T ............... J .............. '"'~' ............... r ............... 1 ............... :'i , 48 stks 1,300 psi , : 48 stks , 1,810 PSI ................Z'-[)';j[;--]":l';~'~]l~-i-_~, , [<~ ............... ,["]~[-~-t'l~;" '] 1,975 ~si ................ , ............................ -.- ................ , ............... , ............... , 54stks , 1,400 s~ , , ; 56stks ; 2,130 s, J 58stks J 900 psi ¢,--tt~O | 60stks J 2,300 psi ................ · ~ ................ ~ ................. -I J ................. I- ............... -I .................. I ' I I ' .................... ~.9. ~ __ i , __ __ __ ~.I .~S__].__ __I r , , .- ............... Jr _.~~ , .~]~..; . . ~:~l?~... ~[ . . ' P 70stks j 875 psi ] i i 65stks i 2,500 psi ................ .~. ................................ ] ! ! i 875 p i i ' ' ' 90 stks s i ' ,' ,' ................ -~ ............... ~ ................. .al] I I I SHUT IN TIME SHUT IN PRESSURE .... ~:gl .~]~-- .................. L__._sz.5___P.S_L..] 1.0min j 850 psi j 2.0min .~ j 840 psi ] :::::::::::::::::::::::::::::::::::::::::::::::::: L_..4.:.O.._m. Ln..l,'' ............... ] I ..]~----~]-- -- -- ] 5.0 min ] 820 psi j SHUT IN TIME , SHUT IN PRESSURE 1.0 min = 2,500 psi~ 2.0 m~n , 2,500 ps ................ r ............... -i ................ L...3:.o...m..i.n___:................... .2_: _5l _0_0_. P..s.i_ _ ] [..114:.Ol_lm_j.n....l ............... L _2_ ' _5_ .0_0.. P_ _S_i__ ] 50min ! 2,500 psi l .... :-' .......... ~ ............... ~ ................. -I ' I I · I 6.0 m~n [ ] 2,500 p_s_[_.~ L..l _7:.0...m..I.n... _ [............... ]__.2_ :_5..0.0.. P._s_L j L... _8:.o__.m._l:n._..,; .................. :_s_9_O_lp..SlLj L.J...o_..m_j.n_...i ................... .2.,lS..o_o_.p..s.[.] .... --6-- --~ 9__-m-] -n. .................. L_.8..1..°...P.S.L.]L_.!.°:.°...m.j-n-..[.................. 7.0min i 800 psi i i 15.0min ! j 2,500 psi l I inI , I ~J J~:~J~ll[ ................ ~J J J~:gJ J~ ..... ~ ................ i___.8_.O_.O_.~.S_ I_ _ _.j j 9.0 minj ] 800psi ]" ..... : .......... ~............... ~ ........... JJJ J:J~ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1J-03 Date: 3/6/01 Reason(s) for test: Supervisor: Whitlock/Rizek [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40# L-80, BTC Casing Setting Depth: 7,784' TMD 4,268' TVD Mud Weight: Estimated Cmt top Hole Depth: 10,500' TMD 5,815' TVD 9.8 ppg Length of Open Hole Section: 2,716' EMW = Leak-off Press. + Mud Weight = 1,250 psi + 9.8 ppg 0.052 x TVD 0.052 x 5,815' EMW for open hole section = 13.9 ppg Pump output = 0.0197 bps Fluid Pumped = 10.2 bbl 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 1,100 psi 1,000 psi 800 psi 700 p,~ 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi !,.-e-- LEAK-OFF TEST j i --a--CASING TEST ....'.. - ..... LOT SHUT IN TIME .~......~_ CASING TEST SHUT IN TIME -.-i ~ TIMELINE '-' ~ ......... . .... ~_.. STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE .....................................................................................................i i . i ~ 0stks ~ 0psi ~ ! 0stks 0psi [ 30 stks _L 400 psi [,fi,,--.. 4 stks 140 psi , 60stks ~ 550 psi , , 8stks : 290 psi ,~ ............... -r ............... F ............................. ~1~) '1, ............... 'i, ................. . t , , 90stks , 650 psi .... 12stks , 450 psi ,= ................ +, ............... 120 stks ,'~' ............... 800 PSI' ~:~ ~"'~,-- ,-. ............. ~,' ............... 16 stks ~,' ................. 625 ps1' t ~ ............... + ............... I- .......... '-- .... M'~ ~, .............. -I ............... -I ................. t I ~ 150stks i 925 psi '~,~, i 20stks ! 800 psi r ............... -~- .............. "r' ................ ! ~J ............... 't ............... 't ................. i i 180 stks i 1,000 psi ,~' i 24stks i 910 psi r- .............. .,- .............. T .............. :-'~ ~C) .............. 1 ............... 1 .............. ';'-, I I 210 stks I 1,050 psi L J,. I 28 stks I 1,060 psi l r ............... ,T .............. "r .............. : - ,'~.!li,- .............. I .............................. ':--; [ '-L 240 stks -L' 1,075 psi,~¢_ .,, 32 stks 1,200 psi : i ............... .............. ..... 390 stks . 1,200 psi .................. ;i~'6'~'&'~ .... ............................ ..................... 450 stks 1,150 psi T510stks [ 1,100psi ............. I__ ................................. C~- ...............~'*~*'"']'~'~'~*'[" .............................. ~ ................ H~ IN TIME SH~ IN PRESSURE .__9~_~J~ ..................... ~_~9_~_L. .... ~:~_~J~ ....................... ~_P_~J .... .___~:~_mJ~ ...................... ~_P_~J .... .___~:~_~J~ ..................... ~_~J .... 4.0 min 800 psi '-'-~:~-~'-'~ ................................ s00 ps~ ............... ~ .............. ~ ................. .__.~:~_~Jp___~ .................. ~_P_~J___. 7.0 min ~ 800 psi ................ ~ ................................. ,__.~:~_~Jp.__~ ................... ~_~ .... ,...~:~.~J~...,~ .................... ~.~ .... ~_J~A~b__~ .................. ~_~_~J .... 52 stks 1,975 psi ................. ,....5.6___s.t_k.s_ ..... ~,.~Ao._.R_s_L 60 stks 2,300 psi ................... ._6_S___s!_k.s_ ..... ~,_~_°_.o___P_.SL_. ' SHUT IN TIME SHUT IN PRESSURE .................. .... ............... j"E~'61J'~,'~i"i _ '-"~:~'~"-] ............... j"~;~'b~'b'a'"~'" .... ~:_o__.m_Ln_ ..................... _2.,_s.o_.o__p__sL_j ,___4_:_o___m_Ln. ..................... ~,._~_°__°___p_?L_i .__~:_o_ __mj _n_ ..................... ~,_~.o_.o__.p_.sL_i .__~:_°___m_Ln_ ..................... ~,_s.°._°___P__sL_i 7.0 min 2,500 psi i .................................................. 8.0 min 2,500 psi i .___9_:_0__.m.j.n.__. 2,500 psi ! ._j_o_._o___m_Ln_ ................. :..~,.s_°._°..?__s.i._i ~_j~:_o___m_!.n. ................. :._.2_,_s.o_.o_._p..sL _[ .___2_o_:g_._m_!_n_ ................. j__.2_,.~.o_ ?_._p._sj._] ....~:.o...m.!~. ................. j..],f&o..?..~j..i ~___3_o_:.o_..m_Ln- ................. .,,__ ~ ,._4&o___p._s£ _ j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ARCO Calculations Char Subject File Sheet number of Date QUALITY LITHO PRINTING, ANCHORAGE, AK (907) 563-4743 Alaska Oil & Gas Cons. Com,missiort ( ~', .',,';.~,, 159-5881 ARCO Calculations Char Subject File Sheet number By Date , :: , QUALITY LITHO PRINTING, ANCHORAGE, AK (907) 563-4743 RECEIVED q Alaska Oil & Gas.Cons .Commission Anchorage 159- 5881 1500 1500 1200 300 o ~0o ~0o 1200 1500 1500 2100 BAKER HUGHES INTEQ Phillips Alaska, Inc. Structure : Pad 1J (WS Pilot) Well : 3 Field : Kuparuk River Unit Location : North Slope, Alasko sc¢~ i.cn-300~t Eastr~ +~.ee,7 1800150Q1200~30 ~ ~ 0 ~ ~ ~ 12~ t~ 1~ 21~ ~ 2~ ~ ~ ~ 3~ ~ 4~ ~ 5t~ ~ 57~ ~ ~ ~ ~0o 2400 ~0O Created ~ flnoh ~te ~lott~: 7-Uu~-2001 240D PlOl Relerenee le PU~ <0-?~'>, c~l~tm, ore In f~ r~aren=e i~{ ~3, true VoK~o~ ~pthm are r~ference RKB 115'(No~m 150. 2700 3000 ....................................... , , , , , , , , , , , 1~ 1~00 1200 900 ~00 300 0 ~00 ~ gao 1200 1~0 1500 2100 2400 2700 ~0 ~00 ~0 ~g0o 42~ 4~00 4~00 5100 ~ ~7~ ~00 ~300 60O0 Scol~ 1 ;rich = 300 fi East (feet) -> leoo 1000 1200 goo 000 aoo o 12oo l~oo 1800 2100 2400 21OO 0OOO Green Lines are proposals RECEIVED 2001 Alaska Oil & Gas Cons. Commission .Anchorage PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 March 9, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval - 1J-03 Dear Mr. Commissioner: As per AOGCC regulations 20AAC25.080, Phillips Alaska, Inc. is submitting this Application for Sundry Approval for annular disposal in the Kuparuk well 1J-03. Also submitted with this application is an Annulus Disposal Transmittal Sheet and attachments to meet the requirements for annular disposal as stipulated by AOGCC. If you have any questions regarding this matter, please contact me at 265,6434 or Todd Mushovic at 265-6974. S, incerely, d. lrantham Drilling Engineering Supervisor PAl Drilling JT/skad Alaska Oil & Gas Cons. Anchorage 1J-03 Revised TD Subject: 1J-03 Revised TD Date: Tue, 6 Feb 2001 16:08:40 -1000 From: "Todd J Mushovic" <TMUSHOV@ppco.com> To: tom_maunder@admin.state.ak.us, "James A Trantham" <JTRANTH@ppco.com> Tom, The final depth for 1J-03 has been changed so that the Kuparuk A sands will be drilled through. To do this the angle and azimuth for the well will remain the same at 53.08 and 119.22 degrees respectively. The extended wellbore would then have a MD of 12,125' and a TD of 6789'. The Kuparuk C sand target location will not change from the submitted APD only the depth of the wellbore is being modified. Since the lateral and vertical depth changes for this wellbore are 175' and 245' respectively under 20 AAC 25.015 (page 4) notification is only required to obtain approval for this change. However, if l am incorrect please let me know as quickly as possible as we are planning to spud this well Thursday (2~8) and already need your help in obtaining a quick response and approval of this APD. Please let me know if there is anything that will expedite the approval of the APD besides my apologies to you and your staff for putting you in this position. Thanks for all of your help. Todd Mushovic 265-6974 I of 1 2/6/01 4:16 PM TONY KNOWLES, GOVERNOR AI,ASKA OIL AND GAS CONSERVA~ION C0Pl~tiSSION J. Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Unit 1J-03 Phillips Alaska, Inc. Permit No: 201-024 Sur. Loc. 2107'FSL, 2419'FEL, Sec. 35, T1 IN, R10E, UM Btmhole Loc. 1264'FNL, 367'FWL, Sec. 31, T1 IN, R11E, UM Dear Mr. Trantham: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are' met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. BlowOut prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this '~ ~'~'---' day of February, 2001 dlf/Enelosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1J-03 Subject: IJ-1:)3 Date: Wed, 31 Jan 2001 09:04:29 -1000 From: '"Todd J Mushovic" <TMUSHOV@ppco.com> To: tom_maunder@admin.state.ak.us CC: "Sharon AIIsup-Drake" <SALLSUP@ppco.com>, "Thomas A Brockway" <TBROCKW@ppco.com> Tom, As we discussed yesterday 1J-03 should be classified as a single zone development well (producer) and not an injector, if you could please make this change to the submitted package I would greatly appreciate it. I have also attached the Drilling Hazards document that will be posted in the rig floor doghouse prior to spud. Thanks again, Todd 265-6974 (See attached file: 1J-03 Drilling Hazards Summary.doc) i Name: 1J-03 Hazards Drilling Summary, doc ~1J-03 Drillinq Hazards Summary.doc Type: Microsoft Word Document (application/msword) Encoding: base64 ............................................................................... ?. ?~ ~ ri_p_ ti_0._n :_.M_a. c___W_o_r._d_.._3..; I of 1 1/31/01 9:34 AM STATE OF ALASKA t, ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: DHI, [~] Redri,I F~ lb. Type of well. Exploratory D Stratigraphic Test F~ Development Cir', Re-entry E~ Deepen BI Service .B Development Gas BI Single Zone r~] Multiple Zone 2. Name of Operator ": ':' 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. . "::..~ RKB 34 feet 3. Address 6. Property Designation CZ.~-~, (' ,,-¢~ Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28248 ALK 591 .,Cb Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.0251) 2107'FSL, 2419'FEL, Sec 35, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1193' FNL, 240' FWL Sec. 31, T11N, R11E, UM 1J-03 59-52-180 At total depth 9. Approximate spud date Amount 1264' FNL, 367' FWL Sec. 31, T11 N, R11 E, UM February 9, 2001 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number o! acres in property 15. Proposed depth (MD and 7'VD) ()Z.¢~i 1 240/~ Target feetI WSP151 19.2' @ 788' feet 2560 11717' MD/6544' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 300 MD Maximum hole angle 65° Maximum surface 2814 psig At total depth (TVD) 3530 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of Cement Hole Casin~l Wei~lht Grade Couplin~l Length MD TVD MD TVD /include sta~e data/ 20" 16" 91.5# Weld 86' 34' 34' 120' 120' 12.25" 9.625" 40# L-80 BTCM 7733' 34' 34' 7767' 4266' 760 sx ASLite, 470 SX LiteCrete 8.5" 7" 26# J-55 BTCM 11229' 34' 34' 11263' 6271' 170 sx Class G 6.125" 3.5" 9.3# L-80 SHLT 604' 11113' 6181' 11717' 6544' 140 SX gASbLOK 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) tree vertical feet Effective Depth: measured feet Junk (measured) tree vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface ProductionRECEIVED I_iner J/~N ~ 6 ~001 Perforation depth: measured Alaska Oil & Gas Cons. Commission true vertical Anchorage 20. Attachme.ts F, .g fee E! Property P at F'I BOP Sketch I--I Dive,erSketch I--I Dri,i.g program El Drilling fluid program El Time vs depth plot ['--]Refraction analysis F[ Seabed report E] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Ca//Todd Mushovic 265-697~ Signed ~¢"~'~_~~ Title: Drilling Engineering Supervisor Date t. ~'o~ ~ J. Trantham Prepared bv Anq Commission Use Onl} PermitNumber'2'4~)/-~2-4 APInumber I App, c~aldate ITMISeec°verletter 50- O ~-.-~' - '~ ._~,~.. ~ ""' ~ -- ~)// other requirements Conditions of approval Samples required E] Yes [~ No Mud logrequired~' r-~ Yes ~] No Hydrogen sulfide measures [~ Yes D No Directional survey required ~, Yes D No Required working pressure for BOPE D 2M; [~? 3M;"' ~ ' D ou;E! El Other: t-~,% '1' ~''"~ ........ [ ~,,~,~ ~J;~-~-~ ~"~ 2 ORIGINAL S~GNED BY byorder of _~ .. Approved by ..a..a,~..u.~,je_~___~_? Commissioner the commission Date~ '"' Form 10-401 Rev. 12/1/85 · Submit in triplicate !,J-03 Drillin_ Hazard,s Summa ,,ry (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detalia,d, Risk Infor ,m.a. tio. n for further discussion of these dsks) .1..2-114" Hole ! 9-518, Casing Interv. al Event Risk Level Hitigation Strategy Conduc't~r Broach Low Monitor cellar continuously during interVal. Well Collision Low Careful well planning and surveying, adherence to anti-collision .policy Gravel and sand 'Low Elevated mud viscosity from spud; Hi dens , sloughing sweeps; contingent 13-3/8" casing string. Shaker/Trough Ball Mill Low Controlled ROP Overflow Shoe 'FractUre/LoSt ...... High Reduced pump rates, and lightweight tail Returns during cement cement job .......................... 8-1/2', Hole ! 7,' Casim3 Interval ...... Event "'RiSk 'Level,,,HitiCJati0n strategy .... "Shale. Stability in HRz Moderate c°ntrol'With higher MW and proper drilling ~ , ~ Practices. ., , , Hole cleanir:tg in I°ng'i Moderate Good drilling practices. ,high angle tangent .......... High ECD and High 'Pumping and rotating out on all trips to swabbing if higher MW reduce swab and barite sag potential. is required ....... ,D-shale gas ....................... ",, LoW'. increase,Mw to +/,1'3 pPg' , ........ 6-118". Hole../3-112". Liner Interval ......... Event ...... Risk Level Hitigati0n,','Strategy" shai'e"stability across K_' High control with higher MW and proper drilling ' 1 interval practiCers.. ........ 'High ECD and ..... High ' ' Pumping and rotating OUt On all trips to swabbing if higher MW reduce swab and barite sag potential. is required Gas related" to GSA gas "Moderate .... May require MW in(~rease to '+/L13 ppg .... injection ....................... 1J-03 Drilling Hazards Summary, doc prepared by Todd Mushovic 1/31/01 Page 1 of 1 GENERAL DRILL AND COMPLETE PROCEDURE EBA INJECTOR KRU 1J-03 General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 150' RKB. Weld landing ring on conductor. 2. Move in / rig up Nabors Rig 16E Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/7767 MD') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run open hole e-line or drill pipe conveyed logs as needed. Obtain sidewall cores on drillpipe as needed to gain additional formation data. 5. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with mud. 6. Nipple down diverter and install wellhead. Nipple up BOPE and test to 5000 psi. Record results. 7. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 9. Directionally drill 8-1/2" hole to base HRZ (11263' MD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. Perform second LOT at to evaluate long string option. If LOT is adequate to long string, drill to well total depth (11717' MD), run 7" 26.0# J-55 BTCM casing to surface and cement, and continue with step #17. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030 10. If LOT is inadequate to long string, Run 7" 26.0# L-80 BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cemen~,,~ will be pumped for isolation in accordance with Rule 20 AAC 25.030 11. Nipple up BOPE and test to 5000 psi. Record results. 12. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 13. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 14. Drill 6-1/8" hole to well total depth (+/- 11717' MD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 15. Run open hole e-line or drill pipe conveyed logs as needed. 16. Run and cement 3-1/2" 9.3# L-80 SHLT liner and Baker ZXP/Flexlock hanger/packer assembly. Set packer +/- 150' above intermediate casing shoe to provide appropriate liner lap. 17. RIH with clean out BHA. Scrape casing. Displace well to completion brine. TJM, 12/19/00, v2 18. Run and land 3-1/2" tubing. 19. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 20. Freeze protect well. Set BPV. Release rig and turn well over to production. 21. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. TJM, 12/19/00, v2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS KRU 1J-03 Drilling Fluid Properties: Spud to 9-5/8" Surface Casin~l Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 8.5-10.2 16-26 25-50 100-200' 10-20 15-40 7-15 9.5-10 6-8% Drill out to 7" Intermediate Casin~ 8.8-9.8 5-25 8-25 35-55 3-10 10-15 5-15 8.5-9.5 6-8% Drill Out to TD 11.3-13.0 25-35 20-30 50-65 4-7 4-8 8-10 8.0-8.5 4-7% Drilling Fluid System - Nabors 16E 3 - Derrick Shale Shakers Desander Desilter Mud Cleaner Centrifuge Degasser Pit Level Indicator (w/visual and audible alarms) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 180-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Two possibilities exist for the possible maximum anticipated surface pressure (MASP) seen by the surface casing string along the 1J-03 well path. 1) MASP can be calculated using an expected leak-off of 13.1 ppg EMW (0.68 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2434 psi. The leak off EMW was chosen based on an open hole LOT on well, 1 D-34, taken to 13.1 ppg (0.68 psi/ft). MASP = (4271 ft)(0.68-0.11) = 2434 psi RECEWED JAN 2 6, 2001 Alaska Oil & Gas Cons. Commission Anchorage 2) If surface shoe LOT is higher than expected and the well is drilled out of surface casing to TD, the MASP can be calculated based on a reservoir pressure of 3550 psi at 6544' TVD (0.54 psi/ft) and a gas gradient of 0.11 psi/ft. In this case, MASP would occur at 2814 psi. MASP = (6544 ft)(0.54 - 0.11) = 2814 psi Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of surface casing. In the event that the well has to be topset above the Kuparuk, the maximum anticipated pressure for the intermediate casing string would continue to 2814 psi as calculated previously. Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of intermediate casing if an intermediate string is needed. Based the anticipated pressures shown, a maximum mud weight requirement for this well is established based no potential charging of the D-shale sands. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.9 ppg can be predicted as the maximum mud weight needed to safely conduct rig operations, assuming a TVD of 6544'. MW = [(6544 ft)(0.54)+150]/6544/.052 = 10.9 ppg In order to allow for a long string design, the minimum LOT in the HRZ or surface casing shoe must be greater than ECD (equivalent circulating density) with a 10.9 ppg drilling fluid as modeled or as measured with the Pressure While Drilling (PWD) sub, plus adequate safety margin. Well Proximity Risks: The nearest existing well to 1J-03 is WSP-151. As designed, the minimum distance between the two wells would be 19.2' at 788' MD. WSP-151 is a West Sak Pilot well that has been plugged and abandoned. Drilling Area Risks: Risks in the 1`1-03 drilling area include surface interval hydrates, lost circulation, and potential borehole instability in and below the permafrost zone as well as through the intermediate shales. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and rheological properties which safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM), reduced circulating rates, and reduced mud weights as needed. Shale instability will be controlled primarily with the planned fluid densities. Additional risk exists with unpredictable charging of the D-shale sands during historic gas injection. These gas pressure risks are mitigated with mid-HRZ LOT's and a top set option above the D- shale based upon those results. Annular Pumping Operations: Incidental fluids developed from drilling operations will be 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 1,1-03 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. At the end of drilling operations, a request for 1`1-03 to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 1J pad, per regulation 20 AAC 25.080, will be submitted. Any zones RECEIVED JAN g 200! Alaska Oil & Gas Cons. Commission Anchorage 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 surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC i3,090 psi NA 5,750 psi 4,888 psi 7" 26 J-55 3 BTCM 4,320 psi 3,672 psi 4,980 psi 4,233 psi 3W'* 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi *ifneeded 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). RECEIVED JAN ?_001 Naska Oil & Gas Cons. Commission Anchorage KRU 1J-03 Injectd Proposed Completion Schematic Topset Base Case PHIllIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY 16" 62.6# @ +/- 120' MD TAM Port Collar Set at +/- 1000' MD Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 7767' MD / 4266' TVD) 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUESRD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above and below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1-1/2" Camco 'MMG' mandrel w/shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. Intermediate csg. 7" 26.0# J-55 BTCM (+/- 11263' MD / 6271' TVD) Future Perforations Production Liner 3-1/2" 9.3# L-80 SLHT (+/- 11717' MD / 6544' TVD) 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'DS' nipple w/2.813" No-Go profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 5.125" x 3" Baker Iocator sub 4-1/2" Baker GBH-22 casing seal assembly w/15' stroke, 3-1/2" L-80 EUE8RD box up Liner Assembly (run on drillpipe), set @ +/- 11,113' MD Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flexlock' Liner Hanger Baker 17' Seal Bore Extension XO Sub, 5" Stub Acme box x 3-1/2" SLHT pin 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Halliburton 'XN' nipple w/2.75" No-Go Profile, 3-1/2" SLHT box x pin 3-1/2" 9.3# L-80 SLHT liner as needed 3-1/2" Baker Landing Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Shoe RECEIVED JAN ?~ 6 Z001 Alaska Oil & Gas Cons. Commission Anchorage TJM, 1/24/01, v2 KRU 1J-03 Injectd Proposed Completion Schematic Long String Contingency Case PHIllIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 16" 62.6# @ +/- 120' MD TAM Port Collar Set at +/- 1000' MD Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 7766' MD / 4266' TVD) Future Perforations Production csg. 7" 26.0# J-55 BTCM (+/- 11717' MD / 6544' TVD) 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUESRD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above and below, EUESRD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple RECEIVED JAN Alaska Oil & Gas Cons. Commission Anchorage 3-1/2" × 1-1/2" Camco 'MMG' Mandrel w/shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'DS' nipple w/2.813" No-Go profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 7" x 3-1/2" Baker 'SAB-3' permanent packer w/KBH-22 seal assembly, 3-1/2" x 6' L-80 EUE8RD handling pup on top 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'D' nipple w/2.75" No-Go Profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 3-1/2" x 10' L-80 EUE8RD pup joint 3-1/2" Baker Shear Out Ball Seat Sub. Tubing tail +/- 50' above top of proposed perforations TJM, 1/24/01, v2 1J-03 Kuparuk Well, Liner Cement loads and CemCADE* summary. Use 60% excess. Drilled with 6 1/8" bit. 3 1/2", 9.3 #casing TMD 11717'. TOC@ 10913' (200' over top of liner top). Liner Top @ 11113' Previous casing 7", 29#, 11263' TMD. 4", 14# DP, 150' liner lap. Volume Calcs: Pump 20 bbls CW100 Preflush, 20 bbls MudPUSH XL Spacer @ 13.0ppg. Cement from 11717' MD to 10913' with Class G + adds @15.8 ppg Slurry Requirements: 15.8 ppg GasBLOK w/Class G + D53, D600, D135, DS00, D047, D065, per lab testing - 3.5 to 4.5 hour thickening time, Yield = 1.2 ft3/sx 3 1/2", 9.34/x 6 1/8" OH: (11717'-11263') x 0.1378 ft3/ft x 1.60 (60% excess) = 100.1 ft3 3 1/2", 9.3# x 7", 29#: (150') x 0.1418 ft3/ft = 21.3 ft3 7", 29#: (200') x 0.2086 ft3/ft = 41.7 ft3 Shoe Joints: (80') x 0.0488 ft3/ft = 3.9 ft3 Total Volume = 167.0 ft3. 167.0 ft3 / 1.2 ft3/sk = 139 sks - Round up to 140 sks CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl CW100 Preflush, 20 bbls 13.0 ppg MudPUSH XL Spacer, 140 sks (30 bbls) Class G + adds. Displacement is approximately 125 bbls. Circulation: Circulation and cementing at or less than 3 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 2 bpm for the last 20 bbls of displacement for bumping the plug. Expected pressure to bump the plug is 1700 psi. At 3 bpm, expect no u-tubing after dropping the top plug. Centralizers: Recommend using at least 1/1 across the entire liner interval to maximize primary success. Recommended Conditioned Mud Properties: 12.0 ppg (preferably lower), Pv = 20 or under, Ty = 20 or under. """' E REC VED JAN g 6 7_001 Alaska Oil & Gas Cons. Commission Anchorage 1J-03 Kuparuk Well Surface Cement loads and CemCADE* summary. Use 45 % excess below the Permafrost and 250 % above. Drilled with 12 1/4" bit. 9 5/8", 40 #casing TMD 7766', Single Stage Design. Tail Slurry TOC is @ 5331' MD ( 800' above the West Sak top). No Port Collar Contingency Base of the Permafrost at 1473' MD Volume Calcs' Pump 20 bbls CW100 Preflush, 50 bbls MudPUSH XL Spacer @ 10.5ppg. Cement from MD to 5331' with LiteCRETE @ 12.0 ppg and from 5331' to surface with ASLite @ 10.7 ppg Lead Slurry Requirements: ASLite @ 10.7 ppg, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1, 1.5%D79 - 4.44 ft3/sk (5331'-1473') x 0.3132 ft3/ft x 1.45 (45% excess) = (1473') x 0.3132 ft3/ft x 3.50 (250% excess) = 1752.1 ft3+ 1614.7 ft3 = 3366.8 ft3/4.44 ft3/sk = 1752.1 ft3 1614.7 ft3 3366.8 ft3 758.3 sks - Round up to 760 sks Have 260 sks of additional Lead on location for Top Out/2nd stage, if necessary Tail Slurry Requirements: LiteCRETE @ 12.0 ppg - 2.46 ft3/sk (7766'-5331') x 0.3132 ft3/ft x 1.45 (45% excess) = Shoe Joints: (80') x 0.4257 ft3/ft = 1105.8 ft3 + 34.1 ft3 = 1139.9 ft3/2.46 ft3/sk = 1105.8 ft3 34.1 ft3 1139.9 ft3 463.4 sks - Round up to 470 sks BHST = 80 deg F CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl CW 100 Preflush, Drop Bottom Plug, 50 bbls 10.5ppg MudPUSH XL Spacer, 760 sks (601 bbl) ASLite Lead, 470 sks (206 bbl) LiteCRETE Tail. Displacement is approximately 583 bbls. Circulation: Circulation and cementing at or less than 8 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug as well as maintaining returns. Run dye marker in the spacer to provide insight into the decision to open the port collar or performing a top job. Expected pressure to bump the plug is 700 psi. At 7 bpm, expect 30 minutes of u-tubing after dropping the top plug. Recommended Conditioned Mud Properties: 10.0 ppg, Pv = 15 or under, Ty = 15 or under. RECEIVED JAN 2, 6 2.001 Alaska Oil & Gas Cons. Commission Anchorage 1J-03 Well Intermediate Cement loads and CemCADE* summary. Use 75 % excess. Drilled with 8 1/2" bit. 7", 26 #casing TMD 11265'. TOC@ 10463' (800' Shoe Tack). Volume Calcs: Pump 20 bbls CW100 Preflush, 30 bbls MudPUSH XL Spacer @ 12.0ppg. Cement from 11263' MD to 10463' with Class G + adds @15.8 ppg Slurry Requirements: 15.8 ppg Class G 0.2%D46, 0.3%D65, 0.1%D800 - 1.17 ft3/sk (adjust retarder to give 3-4 hours thickening time) 7",29#x 8 1/2" OH: (11263'-10463') x0.1268 ft3/ft x 1.75 (75% excess)= 177.5 ft3 Shoe Joints: (80') x 0.2148 ft3/ft = 17.2 ft3 Total Volume = 194.7 ft3. 194.7 ft3 / 1.17 ft3/sk = 166 sks - Round up to 170 sics BHST = 150F (estimated) CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl CW100 Preflush, Drop Bottom Plug, 30 bbls 12.0 ppg MudPUSH XL Spacer, 170 sks (35 bbls) Class G + adds, Drop Top Plug. Displacement is approximately 428 bbls. Circulation: Circulation and cementing at or less than 7 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug. Expected pressure to bump the plug is 1400 psi. At 7 bpm, expect no u-tubing after dropping the top plug. Centralizers: Recommend using at least 1/1 across the entire liner interval to maximize primary success. Recommended Conditioned Mud Properties: 10.0 ppg, Pv = 15 or under, Ty = 15 or under. Kevin Tanner can be reached at the following numbers regarding this job or any other assistance: 265- 6205(w), 336-0067(h), 230-6628(ce11). RECEIVED JAN g 6 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage m Created by finch For: T Dote plotted : 25-Jan-2001 Plot Reference is 1J--5 Version #2 Coordinates ore in feet reference slot - iTrue Vertical Depths ore reference est. '- · i..... Point iKOP iBeg 5/100 Bid iBose Permafrost iBeg 4/100 Bid iEOC MD 300.00 800.00 1472.53 1479.91 2365.48 iTop Ugnu iTorget Top W Sok Bose Ugnu !Bose W Sok 5145. 6131. 6239. 7285. 34 12 31 2O i9 5/8 Csg iBegin Drop/Turn 7766.07 7766.08 8287.51 iEOC !C50 9443;91 9996.07 iC40 ic3o 10334.01 10875.05 iC20 i7 Csg/Bose HRZ K-1 11154.75 11262.91 11409 4O Phillips Alaska, Inc. Structure : Pod 1J (WS Pilot) Well : 3 Locefion : North Slope, Alosko Field : Kuparuk River Unit PROFILE iTop Kup D 11552 59 i iTorget Top C4 11555 92 iTop C5 11567 55 iTop C2 11572 54 i iTop C1 11582 55 iTop B Shale 11592 52 . .I.D.......7._.(2.!.a_.l~._t. ................................................................... 2_1__7__L7_ _5_7. ............................. Inc 0.00 10.00 29.78 30.00 65.42 65.42 65.42 65.42 65.42 65.42 65.42 58.81 53 08 55 08 53 08 53 08 55 08 53 08 55 08 55 08 53 08 53 08 53 08 53 08 53 08 COMMENT Dir 75 O0 75 O0 61 57 61 52 61 52 61 52 61 52 61 52 61 52 61 52 61 52 77 58 11922 11922 11922 11922 11922 11922 11922 11922 11922 11922 11922 119.22 119.22 TVD 300 O0 797 47 1427 O0 1433 59 2019 82 3176 O0 3586 O0 3631 O0 4066 O0 4266 O0 4266 01 4511 O0 5178 31 5510 O0 5715 O0 6038 O0 6194 O0 6271 O0 6359 O0 6435 O0 6435 O0 6454 O0 6457 O0 6465.00 6469.00 DATA North East V. Sect 0.00 0.00 0.00 11.26 42.04 42.38 106.89 247.44 268.59 108.64 250.67 272.27 416.12 817.36 916.99 1621.75 3039.36 5444.96 2049.28 3827.32 4541.42 2096.20 5915.80 4459.81 2549.81 4749.81 5590.93 2758.56 5134.18 5828.23 2758.57 5134.19 5828.24 2920.41 5565.05 6282.81 2797.55 6477.65 7050.98 2581.83 6862.89 7268.91 2449.94 7098.68 7414.52 2238.79 7476.17 7647.64 2137.44 7657.37 7759.54 2087.41 7746.81 7814.77 2030.24 7849.02 7877.89 1982.16 7934.97 7930.97 1980.86 7937.29 7932.41 1968.52 7959.36 7946.04 1966.57 7962.85 7948.19 1962.67 7969.82 7952.49 1958.78 7976.79 7956.80 119._.22 .............. 6.5.~.0~ ........... J...9...!.0~05 ........ 8g.~.~..90 8.0.10.59 Deg/lO0:~ 0.00 2.00 3.00 3.00~ 4.00~ 0.00: 0.00 0.00 0.00 0.00 3,00 5.ooi 3.00:: 0,00 o.oo 0,00 0.00 0,00 0,00 0.00 0,00 0.00 0,00 0.00: 0.00 0.00~, Dote plotted : 25-Jon-2001 Plot Reference is 1J-5 Version #2. Coordineles ore Jo feet refererme slot #5. iTrue Verticol Depths ore reference esi.. rkb.i Phillips Alaska, Inc.i Structure : Pad 1J (WS Pilaf) Well : Field : Kuparuk River Unit Location : North Slope, Alaskai 61.83 AZIMUTH 4341' (TO WS TARGET) ***Plane of Proposal*** TRUE C4 ESTIMATED TARGET LOCATION: TD LOCATION: 1193' FNL, 240' FWL 1264' FNL, 367' FWL SEC. 31, T11N, R11E SEC. 31, T11N, RIlE 9 5/8 Casing Begin Drop/Turn C50~ ~ ~ / Base W ~ / TARG~ LOCATION: J ~ / C20 J 1125' FNL, 1410' ~L J Target Top W Sok Base Ugnu / sec. ;6, *~N, R~OE j ~.t~Bo~Ugh. 7 C~/B~e HR~_1 ~ To~dp D Target To~ C4 Top C5 Top C2 Top Ugnu Top C1 TD - Csg Pt ESTIMATED SURFACE LOCATION: 2107' FSL, 24~9' FEL SEC. 35, T11N, RIOE EOC ~6 Sz ~eg 4/~00 Bid ~ ~a~%; ....Bid frost 400 0 400 800 1200 1600 2000 2400 2800 5200~600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 ~000 Easi (feel) -> 3200 2800 240O 2000 t600 1200 8OO 4O0 4O0 8400 400 8O0 1200 1600 2000 2400 r-' 2800 .+- 3200, ,-- "~ 3600 4000 J 4400 v 4800 520O 5600 IESTIMATED RKB ELEVATION: 116' KOP 2.00 4.00 6.00 DLS: 2.00 deg per 100 ft 8.00 Beg 3/100 12.87 15.78 ~ 18.72 DLS: 3.00 deg per 100 ft ~21.68 ~24.65 '~27.62 Base Permafrost ~32.00 Beg 4/100 Bid h 36.00 '~44.00 DLS: 4.00 deg per 100 ",,%52.00 '-~ ~o.oo EOC MAXIMUM ANGLE 65.43 DEG 6000 Created by linch For: T Mushovie Dote plotted : 23--Jan-2001 i Plot Reference is 1J-3 Version #2. 6400.i Coordinates are in feet reference slot J¢3. i ~True Vertical Depths ore reference est. rkb.} 6800 INTEQ m ~o o c= m ~_. Phillips Alaska, Inc. Structure : Pad IJ (WS Pilot) Well : 3 Field : Kuparuk River Unit Location : North Slope, Alaskai 61.83 AZIMUTH 4341' (TO WS TARGET) · ~**Plane of Proposal*** Top Ugnu WS TARGET ANGLE 65.43 DEG Target Top W Sok Base Ugnu 9 5/8 Casing Begin Drop/Turn Base W Sok C80 64.94 62.22 59.78 DLS: 3.00 deg per 100 tt 57.65 55.87 54.49 53.54 53.04 53.02 E0C C50 C40 C4 TARGET ANGLE 53.08 DEG C30 C20 7 Csg/Bose HRZ K-1 Top C3 Top C2 Top C1 , , , Top B Shale ' J ' ~ ' ' ' ' , , TO - Csg P~ ~ i i , , ~ i i i j t ~ , ~ , , i ~ i ] I , , , [ , , , , 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 Vertical Section (feet) --> Azimuth 61.83 with reference 0.00 N, 0.00 E from slot #$ Creo~ by finch For: T Mushovic Do~e ~o~tea: 23-Jan-200~ Plot Reference ~$ ~J-~ Version ~2. Coord;nates are in f~et reference slot ~5. :~rue Vett;cal ~plhs ore reference est. tkb. INTEO · Phillips Alaska, Inc. Structure : Pad 1J (WS Pilot) Well : 3 : Field : Kuparuk River Unit Location : North Slope, Alaska ,310 320 530 340 TRUE NORTH 350 0 10 2O 30 4O 5O 300 6O 70 280 80 270 9OO 90 260 100 25o~'' 110 240 /?*"150( 22'~ .................. ~o0 ~.,,;:::l ............ 700 .... ,-,....~::;'; 900 ,,-"'"' ¢..- 2 ......... 200 .... "1 ~oo 1.9i} ...... 180 ,0 7OO 90O 170 ....... ~ 300 ~ .......... ~'oo 150 140 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well 120 130 RECEIVED ,Alaska Oil & Gas Coas, Commission Anchorage 220 2OO _ 180 - _ 160 - _ 140 - 120 A - I ~oo- ,+_ ~D 0 20 Dote plotted : 25-Jan-2001 Plot Reference is 1J-.3 Version Coordinates are in feet re[erence slot #3. iTrue Vertical Depths are reference est. rkb.i Phillips Alaska, Inc. Structure ; Pod 1J (WS Pilot) Well : Field : Kuparuk River Unit Location : Norlh Slope, Alaskai East (feet) -> 60 40 20 0 20 40 60 80 1 O0 120 140 160 180 200 220 240 260 280 500 .320 ,340 360 380 I I I i I I I I I I I I I I I i/~ I I I I i I I i I I i I I I i I I I I i I I I I I ~ I 22O / / 200 /2300 / / / / ~ ~o / /2200 / 400/0.~ /- "'1600 160 .-' / i 3go0 ' ./ ? ,,/ /2100 ,,, 3900 /~/f' 140 / / 3800 ,/ 1500 / ..* ~-- / 3700 ," ¢ 2000 /' -~///' 3800 / / 3600,;// 1400~.. ~ ' /' 100 ; oo/ 1900 ~ ~ 1900 ~ ~ ~ /'~ 3700 80 - 7%400 2700% / 3100 ~ ," 1800 '"1~ ' ' // .,~// 60 %.2 00 - .. 200 3,00 ,,. / 1700 ~ ~ ," // 40 --... 3~oo ~/1~oo .--%~oo '..~. 2400 .~300 ~ ~ . 4~oo: _ - - % ooo ./" 3~oo ..... ¢///31 O0 ........... "2500 "~.2300 "-. ¢ ~ ~ ' '" · -. ~oo - -~%oo / / ............... '"~4oo 400 ""- - - -'54oo'.,. .......... "'~oo o- - ~'--.. '~ ~800 //3400/3000 ..... 0 2200 -.~ ',, .~- ..... '"~200 "~.~,. '~ 6200 / / 21 O0 '-.x~)~. 20 // /2900 '~'-' 660,, .,,.~ O0 .// / ...~-~ ....... ' 2000 20 300 ~t '.jooo /~%3oo / ........ '-"~ ~oo ,...: ..... ~ /2800 .~ _.~-----"-?~oo , , i ~ , i , ~ i , i i i i , i i i i 60 60 ' 4'0 ' 2'0 ' 6 ' 2'0 ' 4~0 ' Ob ' 8'0 !00 120 l JO 1~0 1~0 260 2~0 2~0 260 2~0 3~0 3:~0 340 3~0 5BO East (feet) -> z i Creoted by finch For: T Mushovic Dote plotted : 23-Jan-2001 Plot Reference is 1J-3 Version #2_ i Coordinot ..... in feet ret ....... lot #5. i [True VerUcol Depths ore reference est. rkb.i Phillips Alaska, Inc. Structure : Pad 1J (WS Pilot) Well : ,5 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 240 280 320 360 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 520 - _ 480 - _ 440 - _ 400 - _ 360 - A 320 - I _ 280 - - 240 - ~_ _ 0 Z 2oo - _ 16o - ~ 12o o3 800 _0. 8o z 040 23' ~o ~ 3500 . ~ ~ 2100 3400~ ~ · 100 ~ ~ ~ ~ 2000 4000~× /~ / ~ 600 1500¢~/' 1800 700 3000 3200 3400 2800 3600 26002_~...-~. .............................................. -,~._ 3800 .......... ~ .... .,---3900 ...... .4000 2500 2300 2400 ....... ~ .... i , i i ~ ~ i i i i i , i i , i ~ i i i , ~ , , i ~ , ~ i i , , , i , , , , , , , , , 240 280 320 360 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 East (feet) -> 52O 480 440 400 360 320 A Z 28O 0 240 ~ --h ,-4.- 200 ~ 160 120 i Dote p,o.ed : 23-~on-2001 Plot Reference is 1J-3 Version #2. i Coordinates are in feet reference slot #5. i ?rue Vertlcol Depths ere reference est. rkb.} ........................... !?]_'[~-! ............................... 5200 4800 4400 _ 4000- 3600 3200 28oo 2400 2000 1600 1200 800 ? 3700, 2100~ ~ ~ 400 / 1900 ~ ~ ~o--~ 400 I .... , o 400 800 Phillip lask?,I Inc. Structure : Pad 1 J ( S P'o ) e : Field : Kuparuk River Unit Location : North Slope, Alaskai East (feet) -> 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 i i i i i i i i i i i i I i i i I i i i [ i i i i i i i i i i i i I i i i i t i i i i 5200 3900 3300 3100~,,. ~ ~ 2900 ~ ~ 2700 ~ ~ 2500 ~ ~ 2300 ~ ~ ./ 3700 3500 ~ ' 4500 4700 4300 ~- ~ - - ~ - - - --~5100 ~ -~5300 4100 ~ ~ . ~ ' ~.5500 ~ ~ ~ ' ~700 - ~ 6100 -~ 6300 e i i i i i i i i i i i i i i i i i t i i i i i i ~ ~ i i i i i i i i m i i 1200 1600 2000 2400 2800 ~200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 East (feet) -> 4800 440O 4OOO 3600 3200 2800 2400 2000 1600 1200 800 400 400 8800 Phillips Alaska, Inc. Pad 1J (WS Pilot) 3 slot #3 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 1J-3 Version #2 Our ref : prop4360 License : Date printed : 22-Jan-2001 Date created : 20-Dec-2000 Last revised : 22-Jan-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on 561226.769,5943831.650,999.00000,N Slot location is n70 15 46.260,w149 31 29.010 Slot Grid coordinates are N 5945919.876, E 558789.828 Slot local coordinates are 2108.17 N 2420.12 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED J/ N 6 Alaska Oil & Gas Cons, Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),3 - Kuparuk River Unit,North Slope, Alas~ Measured Inclin Azimuth True Vert R E C T A N G U L Depth Degrees Degrees Depth C 00 R D I N A T PROPOSAL LISTING Page 1 Your ref : 1J-3~r ~ion #2 Last revised 22-J~ 301 AR GRID C 0 0 R D S GEOGRAPHIC E S Easting Northing C 00 R D I N A T E S 0.00 0.00 0.00 0.00 0.00N 0.00E 558789.83 5945919.88 n70 15 46.26 w149 31 29.01 100.00 0.00 75.00 100.00 0.00N 0.00E 558789.83 5945919.88 nT0 15 46.26 w149 31 29.01 200.00 0.00 75.00 200.00 0.00N 0.00E 558789.83 5945919.88 n70 15 46.26 w149 31 29.01 300.00 0.00 75.00 300.00 0.00N 0.00E 558789.83 5945919.88 n70 15 46.26 w149 31 29.01 400.00 2.00 75.00 399.98 0.45N 1.69E 558791.51 5945920.34 n70 15 46.26 w149 31 28.96 500.00 4.00 75.00 499.84 1.81N 6.74E 558796.55 5945921.74 n70 15 46.28 w149 31 28.81 600.00 6.00 75.00 599.45 4.06N 15.16E 558804.95 5945924.06 n70 15 46.30 w149 31 28.57 700.00 8.00 75.00 698.70 7.22N 26.93E 558816.70 5945927.31 n70 15 46.33 w149 31 28.23 800.00 10.00 75.00 797.47 11.26N 42.04E 558831.77 5945931.48 n70 15 46.37 w149 31 27.79 900.00 12.87 70.49 895.47 17.23N 60.92E 558850.61 5945937.60 n70 15 46.43 w149 31 27.24 1000.00 15.78 67.61 992.36 26.13N 84.00E 558873.60 5945946.69 n70 15 46.52 w149 31 26.57 1100.00 18.72 65.62 1087.85 37.94N lll.20E 558900.70 5945958.71 n70 15 46.63 w149 31 25.77 1200.00 21.68 64.15 1181.69 52.62N 142.44E 558931.83 5945973.65 n70 15 46.78 w149 31 24.87 1300.00 24.65 63.02 1273.61 70.14N 177.65E 558966.89 5945991.45 nT0 15 46.95 w149 31 23.84 1400.00 27.62 62.12 1363.38 90.45N 216.73E 559005.80 5946012.07 n70 15 47.15 w149 31 22.70 1472.53 29.78 61.57 1427.00 106.89N 247.44E 559036.37 5946028.76 n70 15 47.31 w149 31 21.81 1479.91 30.00 61.52 1433.39 108.64N 250.67E 559039.58 5946030.54 n70 15 47.33 w149 31 21.72 1529.91 32.00 61.52 1476.25 120.92N 273.30E 559062.11 5946043.00 n70 15 47.45 w149 31 21.06 1629.91 36.00 61.52 1559.13 147.58N 322.44E 559111.03 5946070.06 n70 15 47.71 w149 31 19.63 1729.91 40.00 61.52 1637.92 176.94N 376.55E 559164.89 5946099.85 n70 15 48.00 w149 31 18.05 1829.91 44.00 61.52 1712.22 208.84N 435.35E 559223.42 5946132.23 n70 15 48.32 w149 31 16.34 1929.91 48.00 61.52 1781.67 243.14N 498.56E 559286.35 5946167.04 n70 15 48.65 w149 31 14.50 2029.91 52.00 61.52 1845.94 279.67N 565.88E 559353.36 5946204.11 n70 15 49.01 w149 31 12.54 2129.91 56.00 61.52 1904.70 318.24N 636.97E 559424.13 5946243.25 n70 15 49.39 w149 31 10.48 2229.91 60.00 61.52 1957.68 358.68N 711.50E 559498.32 5946284.29 n70 15 49.79 w149 31 08.31 2329.91 64.00 61.52 2004.62 400.78N 789.09E 559575.56 5946327.02 n70 15 50.20 w149 31 06.05 2365.48 65.42 61.52 2019.82 416.12N 817.36E 559603.70 5946342.58 n70 15 50.35 w149 31 05.23 2500.00 65.42 61.52 2075.77 474.46N 924.89E 559710.74 5946401.79 n70 15 50.93 w149 31 02.10 3000.00 65.42 61.52 2283.72 691.31N 1324.55E 560108.59 5946621.86 n70 15 53.06 w149 30 50.47 3500.00 65.42 61.52 2491.68 908.16N 1724.21E 560506.43 5946841.93 n70 15 55.20 w149 30 38.84 4000.00 65.42 61.52 2699.64 1125.01N 2123.87E 560904.28 5947062.00 n70 15 57.33 w149 30 27.21 4500.00 65.42 61.52 2907.60 1341.86N 2523.53E 561302.13 5947282.08 n70 15 59.46 w149 30 15.57 5000.00 65.42 61.52 3115.55 1558.71N 2923.19E 561699.98 5947502.15 n70 16 01.59 w149 30 03.94 5145.34 65.42 61.52 3176.00 1621.75N 3039.36E 561815.62 5947566.12 n70 16 02.21 w149 30 00.56 5500.00 65.42 61.52 3323.51 1775.56N 3322.86E 562097.82 5947722.22 n70 16 03.73 w149 29 52.31 6000.00 65.42 61.52 3531.47 1992.41N 3722.52E 562495.67 5947942.29 n70 16 05.86 w149 29 40.67 6131.12 65.42 61.52 3586.00 2049.28N 3827.32E 562600.00 5948000.00 n70 16 06.42 w149 29 37.62 6239.31 65.42 61.52 3631.00 2096.20N 3913.80E 562686.09 5948047.62 n70 16 06.88 w149 29 35.10 6500.00 65.42 61.52 3739.42 2209.27N 4122.18E 562893.52 5948162.36 n70 16 07.99 w149 29 29.04 7000.00 65.42 61.52 3947.38 2426.12N 4521.84E 563291.37 5948382.43 n70 16 10.12 w149 29 17.40 7285.20 65.42 61.52 4066.00 2549.81N 4749.81E 563518.30 5948507.96 n70 16 11.34 w149 29 10.77 7500.00 65.42 61.52 4155.34 2642.97N 4921.50E 563689.22 5948602.50 n70 16 12.25 w149 29 05.77 7766.07 65.42 61.52 4266.00 2758.36N 5134.18E 563900.92 5948719.61 nT0 16 13.39 w149 28 59.57 7766.08 65.42 61.52 4266.01 2758.37N 5134.19E 563900.93 5948719.62 n70 16 13.39 w149 28 59.57 7800.00 64.94 62.50 4280.24 2772.82N 5161.37E 563928.00 5948734.29 n70 16 13.53 w149 28 58.78 7900.00 63.55 65.46 4323.70 2812.33N 5242.29E 564008.58 5948774.45 n70 16 13.92 w149 28 56.43 8000.00 62.22 68.48 4369.28 2847.16N 5324.18E 564090.18 5948809.95 n70 16 14.26 w149 28 54.04 8100.00 60.97 71.58 4416.86 2877.22N 5406.83E 564172.58 5948840.67 n70 16 14.56 w149 28 51.64 8200.00 59.78 74.75 4466.31 2902.41N 5490.01E 564255.54 5948866.53 n70 16 14.80 w149 28 49.21 8287.51 58.81 77.58 4511.00 2920.41N 5563.05E 564328.43 5948885.12 n70 16 14.98 w149 28 47.09 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #3 and TVD from est. rkb (116.00 Ft above mean sea level). Bottom hole distance is 8287.02 on azimuth 76.67 degrees from wellhead. Total Dogleg for wellpath is 116.16 degrees. Vertical section is from wellhead on azimuth 61.83 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ RECEIVED Alaska Oil & Gas Cons, Commissiorl Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),3 Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 8300.00 58.67 77.99 4517.48 2922.66N 5573.49E 8400.00 57.65 81.31 4570.24 2937.94N 5657.04E 8500.00 56.71 84.70 4624.46 2948.18N 5740.43E 8600.00 55.87 88.16 4679.96 2953.37N 5823.43E 8700.00 55.13 91.69 4736.62 2953.48N 5905.82E 8800.00 54.49 95.28 4794.26 2948.52N 5987.37E 8900.00 53.96 98.92 4852.73 2938.51N 6067.86E 9000.00 53.54 102.60 4911.88 2923.47N 6147.06E 9100.00 53.23 106.32 4971.53 2903.43N 6224.77E 9200.00 53.04 110.06 5031.53 2878.47N 6300.75E 9300.00 52.97 113.82 5091.72 2848.63N 6374.82E 9400.00 53.02 117.57 5151.92 2814.02N 6446.76E 9443.91 53.08 119.22 5178.31 2797.33N 6477.63E 9500.00 53.08 119.22 5212.01 2775.44N 6516.76E 9996.07 53.08 119.22 5510.00 2581.83N 6862.89E 10000.00 53.08 119.22 5512.36 2580.30N 6865.63E 10334.01 53.08 119.22 5713.00 2449.94N 7098.68E 10500.00 53.08 119.22 5812.71 2385.16N 7214.50E 10875.03 53.08 119.22 6038.00 2238.79N 7476.17E 11000.00 53.08 119.22 6113.07~ 2190.02N 7563.36E 11134.73 53.08 119.22 6194.00 2137.44N 7657.37E 11262.91 53.08 119.22 6271.00 2087.41N 7746.81E 11409.40 53.08 119.22 6359.00 2030.24N 7849.02E 11500.00 53.08 119.22 6413.42 1994.88N 7912.23E 11532.59 53.08 119.22 6433.00 1982.16N 7934.97E PROPOSAL LISTING Page 2 Your ref : 1J-3 V~ ~n #2 Last revised 22-Jan~, ~ GRID C 0 0 R D S GEOGRAPHIC Easting Northing C 0 0 R D I N A T E S 564338.84 5948887.47 n70 16 15.00 wt49 28 46.78 564422.26 5948903.41 n70 16 15.15 w149 28 44.35 564505.55 5948914.33 n70 16 15.25 w149 28 41.92 564588.50 5948920.19 n70 16 15.30 w149 28 39.51 564670.88 5948920.98 n70 16 15.30 w149 28 37.11 564752.46 5948916.69 nT0 16 15.25 w149 28 34.73 564833.02 5948907.33 n70 16 15.16 w149 28 32.39 564912.34 5948892.93 n70 16 15.01 w149 28 30.09 564990.19 5948873.53 n70 16 14.81 w149 28 27.82 565066.37 5948849.18 nT0 16 14.56 w149 28 25.61 565140.67 5948819.96 n70 16 14.27 w149 28 23.46 565212.89 5948785.93 n70 16 13.93 w149 28 21.36 565243.88 5948769.50 n70 16 13.76 w149 28 20.47 565283.19 5948747.92 n70 16 13.55 w149 28 19.33 565630.85 5948557.16 n70 16 11.64 w149 28 09.25 565633.60 5948555.65 n70 16 11.63 w149 28 09.17 565867.68 5948427.20 n70 16 10.34 w149 28 02.39 565984.01 5948363.37 n70 16 09.71 w149 27 59.02 566246.84 5948219.15 n70 16 08.27 w149 27 51.41 566334.42 5948171.09 n70 16 07.79 w149 27 48.87 566428.84 5948119.28 n70 16 07.27 w149 27 46.13 566518.67 5948069.99 n70 16 06.77 w149 27 43.53 566621.33 5948013.65 nT0 16 06.21 w149 27 40.56 566684.83 5947978.81 n70 16 05.86 w149 27 38.72 566707.67 5947966.28 n70 16 05.74 w149 27 38.06 11535.92 53.08 119.22 6435.00 1980.86N 7937.29E 566710.00 11567.55 53.08 119.22 6454.00 1968.52N 7959.36E 566732.17 11572.54 53.08 119.22 6457.00 1966.57N 7962.85E 566735.67 11582.53 53.08 119.22 6463.00 1962.67N 7969.82E 566742.67 11592.52 53.08 119.22 6469.00 1958.78N 7976.79E 566749.67 11717.37 53.08 119.22 6544.00 1910.05N 8063.90E 5947965.00 nT0 16 05.73 w149 27 37.99 5947952.84 n70 16 05.60 w149 27 37.35 5947950.92 n70 16 05.58 w149 27 37.25 5947947.08 n70 16 05.55 w149 27 37.04 5947943.23 n70 16 05.51 w149 27 36.84 566837.16 5947895.22 n70 16 05.03 w149 27 34.31 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #3 and TVD from est. rkb (116.00 Ft above mean sea level). Bottom hole distance is 8287.02 on azimuth 76.67 degrees from wellhead. Total Dogleg for wellpath is 116.16 degrees. Vertical section is from wellhead on azimuth 61.83 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ RECEIVED JAN 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),3 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 1J-3 Version #2 Last revised : 22-Jan-2001 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 800.00 1472.53 1479.91 2365.48 5145.34 6131.12 6239.31 7285.20 7766.07 7766.08 8287.51 9443.91 9996.07 10334.01 10875.03 11134.73 11262.91 11409.40 11532.59 11535.92 11567.55 11572.54 11582.53 11592.52 11717.37 3OO 797 1427 1433 2019 3176 3586 3631 4066 4266 4266 4511 00 5178 31 5510 00 5713 00 6038 00 6194 00 6271 00 6359 00 6433 00 6435 00 6454 00 6457.00 6463.00 6469.00 6544.00 00 47 00 39 82 00 00 O0 00 00 01 0.00N 0. 11.26N 42. 106.89N 247. 108.64N 250. 416.12N 817. 1621.75N 3039. 2049.28N 3827. 2096.20N 3913. 2549.81N 4749. 2758.36N 5134. 2758.37N 5134. 2920.41N 5563 2797.33N 6477 2581.83N 6862 2449.94N 7098 2238.79N 7476 2137.44N 7657 2087.41N 7746 2030.24N 7849 1982.16N 7934 1980.86N 7937 1968.52N 7959 1966.57N 7962 1962.67N 7969 1958.78N 7976 1910.05N 8063 00E KOP 04E Beg 3/100 Bld 44E Base Permafrost 67E Beg 4/100 Bld 36E EOC 36E Top Ugnu 32E 1J-41 WS Rvsd il-Jan-01 80E Base Ugnu 81E Base W Sak 18E 9 5/8 Csg 19E Begin Drop/Turn 05E C80 63E EOC 89E C50 68E C40 17E C30 37E C20 81E 7 Csg/Base HRZ 02E K-1 97E Top Kup D 29E 1J-41 C4 Rvsd 4-Jan-01 36E Top C3 85E Top C2 82E Top C1 79E Top B Shale 90E TD - Csg 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 7766.07 4266.00 2758.36N 5134.18E 9 5/8 Casing 0.00 0.00 0.00N 0.00E 11262.91 6271.00 2087.41N 7746.81E 7 Casing 0.00 0.00 0.00N 0.00E 11717.37 6544.00 1910.05N 8063.90E 3 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1J-41 WS Rvsd ll-Jan 562600.000,5948000.000,0.0000 3586.00 2049.28N 3827.32E 15-Jan-2001 1J-41 C4 Rvsd 4-Jan- 566710.000,5947965.000,0.0000 6435.00 1980.86N 7937.29E 12-Sep-2000 RECEIVED JAN 2 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot) 3 slot #3 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 1J-3 Version 92 Our ref : prop4360 License : Date printed : 22-Jan-2001 Date created : 20-Dec-2000 Last revised : 22-Jan-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on 561226.769,5943831.650,999.00000,N Slot location is n70 15 46.260,w149 31 29.010 Slot Grid coordinates are N 5945919.876, E 558789.828 Slot local coordinates are 2108.17 N 2420.12 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated Object wellpath Closest approach with 3-D Last revised Distance Silivertipgl Vers. #7,,Slvrtp,Pad 1J (WS Pilot 10-Jan-2001 652.5 MMS <0-4225'>,,WSP9,Pad 1J (WS Pilot) MMS <0-4182'>,,WSP3,Pad 1J (WS Pilot) MMS <0-4150'>,,WSP7,Pad 1J (WS Pilot) PGMS <0-3950'>,,WSP2,Pad 1J (WS Pilot) PGMS <0-4305'>,,WSP4,Pad 1J (WS Pilot) MMS <0-4130 >,,WSP5,Pad 1J (WS Pilot) PMSS <0-4200 >,,WSP6I,Pad 1J (WS Pilot) MMS <0-4100 >,,WSP10,Pad 1J (WS Pilot) PMSS <0-3976 >,,WSPllI,Pad 1J (WS Pilot) PMSS <0-4000 >,,WSP12,Pad 1J (WS Pilot) MMS <0-4140 >,,WSP13,Pad 1J (WS Pilot) MSS <0-4025'>,,WSP14I,Pad 1J (WS Pilot) MMS <0-4090'>,,WSP15I,Pad 1J (WS Pilot) PGMS <0-4135'>,,WSP20,Pad 1J (WS Pilot) 1J-9 Version #0.a,,9,Pad 1J (WS Pilot) TOTCO <0-4000'>,,WSP8I,Pad 1J (WS Pilot) TOTCO <0-9346'>,,WSP1S,Pad 1J (WS Pilot) PMSS IFR <0-16053'>,,34,Pad iD 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 22-Jan-2001 22-Jan-2001 23-0ct-2000 448.1 )91.6 329.2 )40.0 156.7 211.6 280.2 501.9 576.6 637.8 689.1 748.1 )7.3 239.5 159.0 394.8 76.2 845.3( by an asterisk, e.g. 487.4* Minimum Distance M.D. Diverging 362 855 822 844 80O 775 833 811 877 822 822 855 866 8OO 325 312 811 800 11717 method from M.D. 5 362.5 6 855.6 2 822.2 4 844.4 0 800.0 0 775.0 3 833.3 1 10800.0 8 7250.0 2 822.2 2 822.2 6 855.6 7 8344.4 0 800.0 0 325.0 5 312.5 1 811.1 0 800.0 4 11717.4 RECEIVED J/ N 2 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. ,. Pad 1J (WS Pilot),3 Alask~~ Kuparuk River Unit,North Slope, CLEARANCE LISTING Page 1 Your ref : 1J-3 ~ 'ion #2 Last revised 22-Ja~ 31 Reference wellpath Object wellpath : MMS <0-4182'>,,WSP3,Pad 1J (WS Pilot) M.D. T.V.D. 0.0 0.0 50.0 50.0 100.0 100.0 150.0 150.0 200.0 200.0 250.0 250.0 300.0 300.0 350.0 350.0 400.0 400.0 450.0 449.9 500.0 499.8 550.0 549.7 600.0 599.5 650.0 649.1 700.0 698.7 750.0 748.2 800.0 797.5 850.0 846.6 900.0 895.5 950.0 944.1 1000.0 992.4 1050.0 1040.3 1100.0 1087.8 1150.0 1135.0 1200.0 1181.7 1250.0 1227.9 1300.0 1273.6 1350.0 1318.8 1400.0 1363.4 1450.0 1407.4 Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 0.0N 0.0E 0.0 11.0 88.4S 0.0N 0.0E 38.9 49.9 88.5S 0.0N 0.0E 88.7 99.7 88.5S 0.0N 0.0E 138.7 149.7 88.7S 0.0N 0.0E 188.7 199.7 88.9S 0.0N 0.0E 238.5 249.5 89.0S 0.0N 0.0E 288.5 299.5 89.2S 0.1N 0.4E 338.5 349.5 89.3S 0.5N 1.7E 388.6 399.5 89.5S 1.0N 3.8E 438.5 449.5 89.6S 1.8N 6.7E 488.4 499.4 89.7S 2.8N 10.5E 538.3 549.3 89.8S 4.1N 15.2E 588.0 599.0 90.0S 5.5N 20.6E 637.9 648.8 90.1S 7.2N 26.9E 687.8 698.8 90.2S 34.1E 737.3 748.3 90.1S 42.0E 786.6 797.6 90.0S 51.0E 835.3 846.3 89.9S 60.9E 884.2 895.2 90.0S 71.9E 932.6 943.6 90.2S 9.1N ll.3N 13.9N 17.2N 21.3N 84.0E 981.0 992.0 90.4S 97.1E 1030.4 1041.4 90.5S lll.2E 1081.5 1092.4 90.0S 126.3E 1131.1 1142.0 88.7S 142.4E 1183.7 1194.5 86.3S 26.1N 31.7N 37.9N 44.9N 52.6N 159.6E 1235.2 1245.7 83.0S 177.7E 1288.4 1298.5 78.6S 196.7E 1339.4 1348.9 74.1S 216.7E 1391.7 1400.3 69.6S 237.7E 1441.6 1449.1 65.2S 61.0N 70.1N 79.9N 90.4N 101.6N 62.1E 144.9 108.6 N/A 62.1E 144.9 108.1' )107.5 62.2E 144.9 108.2 )106.9 62.4E 144.9 108.4 )106.4 62.3E 144.9 108.6 )105.9 62.4E 145.0 108.7 )105.4 62.6E 144.9 109.0 )104.9 62.7E 145.1 109.0 )104.2 62.9E 145.8 108.8' )103.3 63.1E 146.8 108.3' )102.1 63.3E 148.3 107.6' )100.6 63.5E 150.3 106.7' )99.0 63.6E 152.7 105.8' )97.3 63.7E 155.8 104.9' )95.6 63.8E 159.3 104.1' )94.0 63.9E 163.3 103.7' )92.7 64.0E 167.8 103.6' )91.8 64.1E 172.8 104.6 )91.8 64.1E 178.3 107.3 )93.6 64.1E 184.0 111.8 )97.1 64.2E 189.7 118.2 )102.6 64.7E 194.9 126.4 )109.9 66.0E 199.5 135.7 )118.9 68.0E 203.6 145.9 )128.7 70.8E 207.3 156.9 )139.2 74.4E 210.6 168.3 )150.2 79.6E 213.4 179.9 )161.4 86.2E 215.6 192.0 )173.0 94.6E 217.4 204.6 )185.2 104.0E 218.7 217.8 )197.8 RECEIVED Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3 and TVD from est. rkb (116.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 61.83 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ JAN 2 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. .. Pad 1J (WS Pilot),3 Alaska~~ Kuparuk River Unit,North Slope, CLEARANCE LISTING Page 2 Your ref : 1J-3 V~' 'on #2 Last revised 22-Jan Reference wellpath Object wellpath : PGMS <0-3950'>,,WSP2,Pad 1J (WS Pilot) M.D. T.V.D. 0.0 0.0 50.0 50.O 100.0 100.0 150.0 150.0 200.0 200.0 250.0 250.0 300.0 300.0 350.0 350.0 400.0 400.0 450.0 449.9 500.0 499.8 550.0 549.7 600.0 599.5 650.0 649.1 700.0 698.7 750.0 748.2 800.0 797.5 850.0 846.6 900.0 895.5 950.0 944.1 1000.0 992.4 1050.0 1040.3 1100.0 1087.8 1150.0 1135.0 1200.0 1181.7 1250.0 1227.9 1300.0 1273.6 1350.0 1318.8 1400.0 1363.4 Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 0.0N 0.0E 0.9 -0.1 29.6S 0.0N 0.0E 50.7 49.7 29.6S 0.0N 0.0E 100.6 99.6 29.7S 0.0N 0.0E 150.6 149.6 30.0S 0.0N 0.0E 200.7 199.7 30.3S 0.0N 0.0E 250.7 249.7 30.7S 0.0N 0.0E 300.6 299.6 31.1S 0.1N 0.4E 350.5 349.5 31.5S 0.5N 1.7E 400.4 399.4 31.8S 1.0N 3.8E 450.4 449.4 32.1S 1.8N 6.7E 500.3 499.3 32.4S 2.8N 10.5E 550.2 549.2 32.7S 4.1N 15.2E 600.0 598.9 33.0S 5.5N 20.6E 649.7 648.7 33.2S 7.2N 26.9E 699.4 698.3 33.5S 9.1N 34.1E 748.9 747.8 33.6S ll.3N 42.0E 798.3 797.3 33.8S 13.9N 51.0E 847.5 846.4 33.9S 17.2N 60.9E 896.4 895.4 34.1S 21.3N 71.9E 945.1 944.0 34.2S 47.9E 121.7 56.3 48.0E 121.7 56.4 48.2E 121.7 56.6 48.4E 121.8 56.9 48.6E 122.0 57.2 48.7E 122.2 57.5 48.7E 122.6 57.8 48.9E 123.1 57.8 49.2E 124.2 57.4* 49.6E 125.8 56.6* 50.0E 128.3 55.1' 50.4E 131.7 53.3* 50.7E 136.1 51.4' 51.2E 141.8 49.3* 51.6E 148.8 47.6* 52.0E 157.2 46.4* 52.5E 166.9 46.3* 52.9E 177.7 47.9 53.2E 188.5 51.9 53.5E 198.4 58.5 26.1N 84.0E 993.4 992.4 34.3S 53.9E 206.5 67.5 31.7N 97.1E 1041.5 1040.5 34.4S 54.2E 213.0 78.8 37.9N lll.2E 1089.2 1088.1 34.5S 54.6E 218.0 92.0 44.9N 126.3E 1136.6 1135.5 34.6S 54.9E 221.9 106.8 52.6N 142.4E 1183.6 1182.5 34.6S 55.4E 225.0 123.2 61.0N 159.6E 1230.1 1229.0 34.5S 55.8E 227.3 141.0 70.1N 177.7E 1276.0 1274.9 34.5S 56.3E 229.2 160.2 79.9N 196.7E 1321.2 1320.2 34.4S 56.8E 230.7 180.8 90.4N 216.7E 1366.0 1365.0 34.4S 57.2E 232.0 202.6 N/A 56.0( 55.9( 55.9( 55.8( 55.8( 55.7( 55.4( 54.7( 53.4( 51.6( 49.4( 47.0( 44.6( 42.3( 40.6( 4O.0( 41.0( 44.5( 50.7( 59.4( 70.2( 83.1( 97.6( 113.7( 131.1( 149.9( 170.1( 191.5( Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3 and TVD from est. rkb (116.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 61.83 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED J/~N ;~ $ ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. CLEARANCE LISTING Page 3 Pad 1J (WS Pilot),3 ,~ Your ref : 1J-3 Ve.,r .... on #2 Kuparuk River Unit,North Slope, Alaska.% Last revised : 22-Jan ., Reference wellpath Object wellpath : PGMS <0-4305'>, ,WSP4,Pad 1J (WS Pilot) M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist SeD'n 0.0 0.0 0.0N 0.0E 1.1 0.1 146.9S 50.0 50.0 0.0N 0.0E 51.2 50.2 147.0S 100.0 100.0 0.0N 0.0E 101.2 100.2 147.1S 150.0 150.0 0.0N 0.0E 151.0 150.0 147.4S 200.0 200.0 0.0N 0.0E 200.9 199.9 147.7S 250.0 250.0 0.0N 0.0E 250.9 249.9 148.0S 300.0 300.0 0.0N 0.0E 300.9 299.9 148.2S 350.0 350.0 0.1N 0.4E 351.1 350.0 148.5S 400.0 400.0 0.5N 1.7E 401.2 400.2 148.6S 450.0 449.9 1.0N 3.8E 451.1 450.1 148.8S 500.0 499.8 1.8N 6.7E 501.1 500.1 148.9S 550.0 549.7 2.8N 10.5E 550.8 549.8 149.0S 600.0 599.5 4.1N 15.2E 600.5 599.5 149.0S 650.0 649.1 5.5N 20.6E 650.2 649.1 149.1S 700.0 698.7 7.2N 26.9E 699.7 698.6 149.2S 750.0 748.2 9.1N 34.1E 749.1 748.0 149.3S 800.0 797.5 ll.3N 42.0E 798.3 797.2 149.4S 850.0 846.6 13.9N 51.0E 847.3 846.3 149.5S 900.0 895.5 17.2N 60.9E 896.1 895.1 149.6S 950.0 944.1 21.3N 71.9E 944.6 943.5 149.7S 1000.0 992.4 26.1N 84.0E 992.6 991.5 150.0S 1050.0 1040.3 31.7N 97.1E 1040.3 1039.3 150.2S 1100.0 1087.8 37.9N lll.2E 1087.8 1086.8 150.5S 1150.0 1135.0 44.9N 126.3E 1134.9 1133.8 150.7S 76.1E 152.6 165.4 N/A 75.9E 152.7 165.4' )165.1( 75.4E 152.9 165.3' )164.6( 74.8E 153.1 165.3' )164.2( 74.2E 153.3 165.3' )163.9( 73.7E 153.5 165.3 73.2E 153.7 165.3 72.8E 154.0 165.3' 72.4E 154.6 165.0' 72.0E 155.5 164.6' 163.6( 163.3( 162.8( 162.2( 161.4( 71.6E 156.7 164.1' 71.3E 158.2 163.5' 71.0E 160.0 163.0' 70.7E 162.0 162.6' 70.5E 164.4 162.4' 70.3E 167.1 162.5 70.0E 170.1 163.1 69.8E 173.4 164.4 69.7E 177.0 167.1 69.6E 180.8 171.1 69.5E 184.7 176.7 69.5E 188.6 184.0 69.5E 192.5 193.0 69.5E 196.2 203.7 160.5( 159.5( 158.6( 157.8( 157.1( 156.7( 156.8( 157.5( 159.6( 162.9( 167.9( 174.5 ( 182.9 ( 193.0( RECEIVED JAN Alaska Oil & Gas Cons. Commission Anchorage Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3 and TVD from est. rkb (116.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 61.83 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CLEARANCE LISTING Page 4 Pad 1J (WS Pilot),3 '~i Your ref : 1J-3~,' 'ion #2 Kuparuk River Unit,North Slope, Alas Last revised 22-Ja~ 01 Reference wellpath Object wellpath : MMS <0-4090'>,,WSP15I,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 0.0E 6.1 0.1 28.5N 34.2E 50.2 44.5 50.0 50.0 0.0N 0.0E 56.3 50.3 28.4N 34.1E 50.3 44.4* 100.0 100.0 0.0N 0.0E 106.3 100.3 28.1N 34.0E 50.5 44.1' 150.0 150.0 0.0N 0.0E 155.8 149.8 27.8N 34.0E 50.7 43.9* 200.0 200.0 0.0N 0.0E 205.6 199.6 27.9N 34.2E 50.8 44.1 250.0 250.0 0.0N 0.0E 255.6 249.6 28.1N 34.6E 50.9 44.6 300.0 300.0 0.0N 0.0E 305.7 299.7 28.3N 35.0E 51.1 45.0 350.0 350.0 0.1N 0.4E 355.8 349.8 28.3N 35.3E 51.0 44.9* 400.0 400.0 0.5N 1.7E 405.8 399.8 28.4N 35.6E 50.5 43.9* 450.0 449.9 1.0N 3.8E 455.8 449.8 28.4N 35.8E 49.4 42.1' 500.0 499.8 1.8N 6.7E 505.7 499.7 28.4N 36.0E 47.7 39.5* 550.0 549.7 2.8N 10.5E 555.7 549.6 28.5N 36.0E 44.9 36.2* 600.0 599.5 4.1N 15.2E 605.4 599.4 28.5N 36.0E 40.5 32.1' 650.0 649.1 5.5N 20.6E 655.1 649.1 28.6N 36.0E 33.6 27.7* 700.0 698.7 7.2N 26.9E 704.6 698.6 28.8N 35.8E 22.4 23.4* 750.0 748.2 9.1N 34.1E 754.1 748.1 29.1N 35.6E 4.3 20.0* 800.0 797.5 ll.3N 42.0E 803.4 797.4 29.4N 35.3E 339.5 19.3' 850.0 846.6 13.9N 51.0E 852.5 846.5 29.5N 35.1E 314.6 22.3 900.0 895.5 17.2N 60.9E 901.4 895.4 29.7N 35.0E 295.6 28.8 950.0 944.1 21.3N 71.9E 950.0 944.0 29.8N 34.8E 282.9 38.1 1000.0 992.4 26.1N 84.0E 998.3 992.3 29.9N 34.7E 274.4 49.4 1050.0 1040.3 31.7N 97.1E 1046.3 1040.3 29.9N 34.7E 268.4 62.4 1100.0 1087.8 37.9N lll.2E 1093.9 1087.8 29.9N 34.7E 264.0 76.9 1150.0 1135.0 44.9N 126.3E 1140.9 1134.9 29.9N 34.7E 260.7 92.9 1200.0 1181.7 52.6N 142.4E 1187.4 1181.4 29.9N 34.6E 258.1 110.2 1250.0 1227.9 61.0N 159.6E 1233.5 1227.4 30.0N 34.4E 256.1 128.9 1300.0 1273.6 70.1N 177.7E 1279.1 1273.1 30.1N 34.2E 254.4 148.9 1350.0 1318.8 79.9N 196.7E 1324.3 1318.3 30.1N 34.0E 253.0 170.1 1400.0 1363.4 90.4N 216.7E 1369.2 1363.2 30.2N 34.0E 251.7 192.5 1450.0 1407.4 101.6N 237.7E 1413.9 1407.9 30.2N 34.0E 250.7 215.9 N/A 43.6( 42.6( 41.7( 41.3( )41.0( )40.7( )39.9( )38.2( )35.7( )32.4( )28.3( )23.6( )18.4( )13.2( )8.9( )7.3( )9.5 )15.4 )24.1 )34.8 )47.2 )61.0 )76.2 )92.9 )110.9 )130.1 )150.6 )172.2 )194.9 RECEIVED dAN 2 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3 and TVD from est. rkb (116.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 61.83 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CLEARANCE LISTING Page 5 Pad 1J (WS Pilot),3 ~ Your ref : 1J-3 Vet 'on ~2 Kuparuk River Unit,North Slope, Alaska. Last revised 22-Jan{ Reference wellpath Object wellpath : 1J-9 Version #0.a,,9,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 50 . 0 50 . 0 0 . 0N 100.0 100.0 0.0N 150.0 150 . 0 0 . 0N 200.0 200.0 0.0N 250.0 250.0 0.0N 300.0 300.0 0.0N 350.0 350.0 0.1N 400.0 400.0 0.5N 450.0 449.9 1.0N 500.0 499.8 1.8N 550.0 549.7 2.8N 600.0 599.5 4.1N 650.0 649.1 5.5N 700.0 698.7 7.2N 0.0E 4.0 0.0 0 . 0E 54 . 0 50 . 0 0 . 0E 104 . 0 100 . 0 0.0E 154.0 150.0 0.0E 204.0 200.0 0.0E 254.0 250.0 0.0E 303.8 299.8 0.4E 352.2 348.2 1.7E 400.5 396.5 3.8E 449.1 445.1 6.7E 497.2 493.0 10.5E 545.1 540.8 15.2E 592.7 588.2 20.6E 640.1 635.3 26.9E 687.1 681.9 44.8N 155.0W 286.1 161.3 N/A 44.8N 155.0W 286.1 161.3 )160.9( 44.8N 155.0W 286.1 161.3 )160.6( 44.8N 155.0W 286.1 161.3 160.2 44.8N 155.0W 286.1 161.3 159.8 44.8N 155.0W 286.1 161.3 44.8N 155.0W 286.1 161.3 45.2N 155.1W 286.2 162.0 46.5N 155.5W 286.3 163.9 48.5N 156.2W 286.5 167.0 159.4 159.1 159.3 160.8 163.5 51.2N 157.2W 286.8 171.3 54.7N 158.4W 287.1 176.9 58.9N 159.9W 287.4 183.8 63.8N 161.6W 287.7 191.8 69.5N 163.5W 288.1 201.1 167.4 172.5 178.9 186.4 195.2 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3 and TVD from est. rkb (116.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 61.83 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED J~N 2 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),3 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 6 Your ref : 1J-3 Version #2 Last revised : 22-Jan-2001 Reference wellpath Object wellpath : TOTCO <0-9346'>,,WSP1S,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 0.0E 1.1 0.1 86.7N 50.0 50.0 0.0N 0.0E 51.1 50.1 86.7N 100.0 100.0 0.0N 0.0E 101.1 100.1 86.7N 150.0 150.0 0.0N 0.0E 151.1 150.1 86.6N 200.0 200.0 0.0N 0.0E 201.2 200.2 86.6N 20.0E 13.0 89.0 N/A 20.0E 13.0 89.0* N/A 20.0E 13.0 89.0* N/A 20.0E 13.0 88.9* N/A 20.0E 13.0 88.9* N/A 250.0 250.0 0.0N 0.0E 251.2 250.2 86.5N 300.0 300.0 0.0N 0.0E 301.2 300.2 86.4N 350.0 350.0 0.1N 0.4E 351.3 350.3 86.2N 400.0 400.0 0.5N 1.7E 401.3 400.3 86.1N 450.0 449.9 1.0N 3.8E 451.2 450.2 85.9N 20.1E 13.1 88.8* N/A 20.1E 13.1 88.7* N/A 20.1E 12.9 88.3* N/A 20.2E 12.2 87.6* N/A 20.2E 11.0 86.4* N/A 500.0 499.8 1.8N 6.7E 501.2 500.2 85.7N 550.0 549.7 2.8N 10.5E 551.0 550.0 85.5N 600.0 599.5 4.1N 15.2E 600.8 599.8 85.3N 650.0 649.1 5.5N 20.6E 650.5 649.5 85.0N 700.0 698.7 7.2N 26.9E 700.0 699.0 84.8N 20.3E 9.2 85.0* N/A 20.3E 6.8 83.2* N/A 20.4E 3.7 81.4' N/A 20.4E 359.9 79.5* N/A 20.5E 355.3 77.9* N/A 750.0 748.2 9.1N 800.0 797.5 ll.3N 850.0 846.6 13.9N 900.0 895.5 17.2N 950.0 944.1 21.3N 34.1E 749.5 748.5 84.6N 42.0E 798.8 797.8 84.4N 51.0E 847.9 846.9 84.2N 60.9E 896.8 895.8 84.0N 71.9E 945.4 944.4 83.8N 20.6E 349.9 76.7* N/A 20.6E 343.7 76.2* N/A 20.7E 336.7 76.6 N/A 20.7E 329.0 77.9 N/A 20.8E 320.7 80.8 N/A 1000.0 992.4 1050.0 1040.3 1100.0 1087.8 1150.0 1135.0 1200.0 1181.7 26.1N 84.0E 993.7 992.7 83.6N 31.7N 97.1E 1041.6 1040.6 83.4N 37.9N lll.2E 1089.1 1088.1 83.2N 44.9N 126.3E 1136.3 1135.3 83.0N 52.6N 142.4E 1183.0 1181.9 82.8N 20.8E 312.3 85.4 N/A 20.9E 304.2 92.1 N/A 20.9E 296.6 101.0 N/A 21.0E 289.9 112.0 N/A 21.0E 284.0 125.1 N/A 1250.0 1227.9 1300.0 1273.6 1350.0 1318.8 1400.0 1363.4 61.0N 159.6E 1229.2 1228.2 82.6N 70.1N 177.7E 1274.9 1273.8 82.4N 79.9N 196.7E 1320.0 1319.0 82.2N 90.4N 216.7E 1364.6 1363.6 82.0N 21.1E 278.9 140.1 N/A 21.2E 274.5 157.0 N/A 21.2E 270.7 175.5 N/A 21.3E 267.5 195.7 N/A Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3 and TVD from est. rkb (116.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 61.83 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED Ji N 6 2001 Alaska 0il 8, Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot) 3 slot #3 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 1J-3 Version ~2 Our ref : prop4360 License : Date printed : 22-Jan-2001 Date created : 20-Dec-2000 Last revised : 22-Jan-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on 561226.769,5943831.650,999.00000,N Slot location is nT0 15 46.260,w149 31 29.010 Slot Grid coordinates are N 5945919.876, E 558789.828 Slot local coordinates are 2108.17 N 2420.12 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED 2 6 O01 Alaska Oil & Gas Cons. Con,mission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),3 ~'[" Kuparuk River Unit,North Slope, Alaska. Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 0.00 0.00 0.00 0.00 0.00 N 0.00 E 100.00 0.00 75.00 100.00 0.00 N 0.00 E 200.00 0.00 75.00 200.00 0.00 N 0.00 E 300.00 0.00 75.00 300.00 0.00 N 0.00 E 400.00 2.00 75.00 399.98 0.45 N 1.69 E 500.00 4.00 75.00 499.84 1.81 N 6.74 E 600.00 6.00 75.00 599.45 4.06 N 15.16 E 700.00 8.00 75.00 698.70 7.22 N 26.93 E 800.00 10.00 75.00 797.47 11.26 N 42.04 E 900.00 12.87 70.49 895.47 17.23 N 60.92 E 1000.00 15.78 67.61 992.36 26.13 N 84.00 E 1100.00 18.72 65.62 1087.85 37.94 N 111.20 E 1200.00 21.68 64.15 1181.69 52.62 N 142.44 E 1300.00 24.65 63.02 1273.61 70.14 N 177.65 E 1400.00 27.62 62.12 1363.38 90.45 N 216.73 E 1472.53 29.78 61.57 1427.00 106.89 N 247.44 E 1479.91 30.00 61.52 1433.39 108.64 N 250.67 E 1529.91 32.00 61.52 1476.25 120.92 N 273.30 E 1629.91 36.00 61.52 1559.13 147.58 N 322.44 E 1729.91 40.00 61.52 1637.92 176.94 N 376.55 E PROPOSAL LISTING Your ref : 1J-3 V~. Last revised 22-Jar~ Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP 2.00 1.70 2.00 6.80 2.00 15.28 2.00 27.15 2.00 42.38 Beg 3/100 Bld 3.00 61.84 3.00 86.39 3.00 115.94 3.00 150.41 3.00 189.72 3.00 233.76 3.00 268.59 Base Permafrost 3.00 272.27 Beg 4/100 Bld 4.00 298.02 4.00 353.92 4.00 415.48 1829.91 44.00 61.52 1712.22 208.84 N 435.35 E 4.00 482.37 1929.91 48.00 61.52 1781.67 243.14 N 498.56 E 4.00 554.29 2029.91 52.00 61.52 1845.94 279.67 N 565.88 E 4.00 630.88 2129.91 56.00 61.52 1904.70 318.24 N 636.97 E 4.00 711.76 2229.91 60.00 61.52 1957.68 358.68 N 711.50 E 4.00 796.55 2329.91 64.00 61.52 2004.62 400.78 N 789.09 E 4.00 884.83 2365.48 65.42 61.52 2019.82 416.12 N 817.36 E 4.00 916.99 EOC 2500.00 65.42 61.52 2075.77 474.46 N 924.89 E 0.00 1039.32 3000.00 65.42 61.52 2283.72 691.31 N 1324.55 E 0.00 1494.02 3500.00 65.42 61.52 2491.68 908.16 N 1724.21 E 0.00 1948.71 Page 1 ion #2 1 4000.00 65.42 61.52 2699.64 1125.01 N 2123.87 E 0.00 2403.41 4500.00 65.42 61.52 2907.60 1341.86 N 2523.53 E 0.00 2858.10 5000.00 65.42 61.52 3115.55 1558.71 N 2923.19 E 0.00 3312.80 5145.34 65.42 61.52 3176.00 1621.75 N 3039.36 E 0.00 3444.96 Top Ugnu 5500.00 65.42 61.52 3323.51 1775.56 N 3322.86 E 0.00 3767.49 6000.00 65.42 61.52 3531.47 1992.41 N 3722.52 E 0.00 4222.19 6131.12 65.42 61.52 3586.00 2049.28 N 3827.32 E 0.00 4341.42 1J-41 WS Rvsd il-Jan-01 6239.31 65.42 61.52 3631.00 2096.20 N 3913.80 E 0.00 4439.81 Base Ugnu 6500.00 65.42 61.52 3739.42 2209.27 N 4122.18 E 0.00 4676.88 7000.00 65.42 61.52 3947.38 2426.12 N 4521.84 E 0.00 5131.58 7285.20 65.42 61.52 4066.00 2549.81 N 4749.81 E 0.00 5390.93 Base W Sak 7500.00 65.42 61.52 4155.34 2642.97 N 4921.50 E 0.00 5586.27 7766.07 65.42 61.52 4266.00 2758.36 N 5134.18 E 0.00 5828.23 9 5/8 Csg 7766.08 65.42 61.52 4266.01 2758.37 N 5134.19 E 3.00 5828.24 Begin Drop/Turn 7800.00 64.94 62.50 4280.24 2772.82 N 5161.37 E 3.00 5859.03 7900.00 63.55 65.46 4323.70 2812.33 N 5242.29 E 3.00 5949.01 8000.00 62.22 68.48 4369.28 2847.16 N 5324.18 E 3.00 6037.65 8100.00 60.97 71.58 4416.86 2877.22 N 5406.83 E 3.00 6124.70 8200.00 59.78 74.75 4466.31 2902.41 N 5490.01 E 3.00 6209.92 8287.51 58.81 77.58 4511.00 2920.41 N 5563.05 E 3.00 6282.81 C80 Ail data is in feet unless otherwise stated. Coordinates from slot #3 and TVD from est. rkb (116.00 Ft above mean sea level). Bottom hole distance is 8287.02 on azimuth 76.67 degrees from wellhead. Total Dogleg for wellpath is 116.16 degrees. Vertical section is from wellhead on azimuth 61.83 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1J (WS Pilot),3 Kuparuk River Unit,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 : 1J-3 Version #2 Last revised : 22-Jan-2001 Dogleg Vert Deg/100ft Sect 8300.00 58.67 77.99 4517.48 2922.66 N 5573.49 E 3.00 6293.07 8400.00 57.65 81.31 4570.24 2937.94 N 5657.04 E 3.00 6373.94 8500.00 56.71 84.70 4624.46 2948.18 N 5740.43 E 3.00 6452.29 8600.00 55.87 88.16 4679.96 2953.37 N 5823.43 E 3.00 6527.91 8700.00 55.13 91.69 4736.62 2953.48 N 5905.82 E 3.00 6600.60 8800.00 54.49 95.28 4794.26 2948.52 N 5987.37 E 3.00 6670.15 8900.00 53.96 98.92 4852.73 2938.51 N 6067.86 E 3.00 6736.38 9000.00 53.54 102.60 4911.88 2923.47 N 6147.06 E 3.00 6799.11 9100.00 53.23 106.32 4971.53 2903.43 N 6224.77 E 3.00 6858.15 9200.00 53.04 110.06 5031.53 2878.47 N 6300.75 E 3.00 6913.36 9300.00 52.97 113.82 5091.72 2848.63 N 6374.82 E 3.00 6964.57 9400.00 53.02 117.57 5151.92 2814.02 N 6446.76 E 3.00 7011.65 9443.91 53.08 119.22 5178.31 2797.33 N 6477.63 E 3.00 7030.98 EOC 9500.00 53.08 119.22 5212.01 2775.44 N 6516.76 E 0.00 7055.15 9996.07 53.08 119.22 5510.00 2581.83 N 6862.89 E 0.00 7268.91 C50 10000.00 53.08 119.22 5512.36 2580.30 N 6865.63 E 0.00 7270.60 10334.01 53.08 119.22 5713.00 2449.94 N 7098.68 E 0.00 7414.52 C40 10500.00 53.08 119.22 5812.71 2385.16 N 7214.50 E 0.00 7486.04 10875.03 53.08 119.22 6038.00 2238.79 N 7476.17 E 0.00 7647.64 C30 11000.00 53.08 119.22 6113.07 2190.02 N 7563.36 E 0.00 7701.49 11134.73 53.08 119.22 6194.00 2137.44 N 7657.37 E 0.00 7759.54 C20 11262.91 53.08 119.22 6271.00 2087.41 N 7746.81 E 0.00 7814.77 7 Csg/Base HRZ 11409.40 53.08 119.22 6359.00 2030.24 N 7849.02 E 0.00 7877.89 K-1 11500.00 53.08 119.22 6413.42 1994.88 N 7912.23 E 0.00 7916.93 11532.59 53.08 119.22 6433.00 1982.16 N 7934.97 E 0.00 7930.97 ToD KuD D 11535.92 53.08 119.22 6435.00 1980.86 N 7937.29 E 0.00 7932.41 1J-41 C4 Rvsd 4-Jan-01 11567.55 53.08 119.22 6454.00 1968.52 N 7959.36 E 0.00 7946.04 Top C3 11572.54 53.08 119.22 6457.00 1966.57 N 7962.85 E 0.00 7948.19 ToD C2 11582.53 53.08 119.22 6463.00 1962.67 N 7969.82 E 0.00 7952.49 Top C1 11592.52 53.08 119.22 6469.00 1958.78 N 7976.79 E 0.00 7956.80 Top B Shale 11717.37 53.08 119.22 6544.00 1910.05 N 8063.90 E 0.00 8010.59 TD - Csg Pt Ail data is in feet unless otherwise stated. Coordinates from slot ~3 and TVD from est. rkb (116.00 Ft above mean sea level). Bottom hole distance is 8287.02 on azimuth 76.67 degrees from wellhead. Total Dogleg for wellpath is 116.16 degrees. Vertical section is from wellhead on azimuth 61.83 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1J (WS Pilot),3 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 1J-3 Version #2 Last revised : 22-Jan-2001 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300. 800.00 797. 1472.53 1427. 1479.91 1433. 2365.48 2019. 5145.34 3176. 6131.12 3586 6239.31 3631 7285.20 4066 7766.07 4266 7766.08 4266 8287.51 4511 9443.91 5178 9996.07 5510 10334.01 5713 10875.03 6038 11134.73 6194 11262.91 6271 11409.40 6359 11532.59 6433 11535.92 6435 11567.55 6454 11572.54 6457 11582.53 6463 11592.52 6469 11717.37 6544 00 0.00 N 47 11.26 N 00 106.89 N 39 108.64 N 82 416.12 N 00 1621.75 N 00 2049.28 N 00 2096.20 N 00 2549.81 N 00 2758.36 N 01 2758.37 N 00 2920.41 N 31 2797.33 N 00 2581.83 N 00 2449.94 N 00 2238.79 N 00 2137.44 N 00 2087.41 N 00 2030.24 N 00 1982.16 N 00 1980.86 N 00 1968.52 N 00 1966.57 N 00 1962.67 N 00 1958.78 N 00 1910.05 N 0 00 E 42 04 E 247 44 E 250 67 E 817 36 E 3039 36 E 3827 32 E 3913 80 E 4749 81 E 5134 18 E 5134 19 E 5563 05 E 6477 63 E 6862 89 E 7098 68 E 7476 17 E 7657 37 E 7746 81 E 7849 02 E 7934 97 E 7937 29 E 7959 36 E 7962 85 E 7969.82 E 7976.79 E 8063.90 E KOP Beg 3/100 Bld Base Permafrost Beg 4/100 Bld EOC Top Ugnu 1J-41 WS Rvsd il-Jan-01 Base Ugnu Base W Sak 9 5/8 Csg Begin Drop/Turn C80 EOC C50 C40 C30 C20 7 Csg/Base HRZ K-1 Top Kup D 1J-41 C4 Rvsd 4-Jan-01 Top C3 Top C2 Top C1 Top B Shale TD - Csg 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 7766.07 4266.00 2758.36N 5134.18E 9 5/8 Casing 0.00 0.00 0.00N 0.00E 11262.91 6271.00 2087.41N 7746.81E 7 Casing 0.00 0.00 0.00N 0.00E 11717.37 6544.00 1910.05N 8063.90E 3 1/2" Casing Target name Targets associated with this wellpath Geographic Location T.V.D. Rectangular Coordinates Revised 1J-41 WS Rvsd ll-Jan 562600.000,5948000.000,0.0000 3586.00 1J-41 C4 Rvsd 4-Jan- 566710.000,5947965.000,0.0000 6435.00 2049.28N 1980.86N 3827.32E 15-Jan-2001 7937.29E 12-Sep-2000 Phillips Alaska, Inc. Pad 1J (WS Pilot) 3 slot #3 Kuparuk River Unit North SloDe, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 1J-3 Version #2 Our ref : prop4360 License : Date printed : 23-Jan-2001 Date created : 20-Dec-2000 Last revised : 22-Jan-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on 561226.769,5943831.650,999.00000,N Slot location is n70 15 46.260,w149 31 29.010 Slot Grid coordinates are N 5945919.876, E 558789.828 Slot local coordinates are 2108.17 N 2420.12 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath MMS <0-4225'>, MMS <0-4182'>, MMS <0-4150'>, PGMS <0-3950'> PGMS <0-4305'> MMS <0-4130'> PMSS <0-4200'> MMS <0-4100'> PMSS <0-3976'> PMSS <0-4000'> MMS <0-4140'> MSS <0-4025'>, MMS <0-4090'>, PGMS <0-4135'> wsPg,Pad 1J (WS Pilot) WSP3,Pad 1J (WS Pilot) WSP7,Pad 1J (WS Pilot) ,WSP2,Pad 1J (WS Pilot) ,WSP4,Pad 1J (WS Pilot) WSP5,Pad 1J (WS Pilot) WSP6I,Pad 1J (WS Pilot) WSP10,Pad 1J (WS Pilot) WSPllI,Pad 1J (WS Pilot) WSP12,Pad 1J (WS Pilot) WSP13,Pad 1J (WS Pilot) WSP14I,Pad 1J (WS Pilot) WSP15I,Pad 1J (WS Pilot) ,WSP20,Pad 1J (WS Pilot) TOTCO <0-4000'>,,WSP8I,Pad 1J (WS Pilot) TOTCO <0-9346'>,,WSP1S,Pad 1J (WS Pilot) Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 19-Jan-2001 460.7 787.5 787.5 19-Jan-2001 103.6 775.0 775.0 19-Jan-2001 341.3 725.0 725.0 19-Jan-2001 46.2 775.0 775.0 19-Jan-2001 162.4 712.5 712.5 19-Jan-2001 223.6 737.5 737.5 19-Jan-2001 283.1 100.0 737.5 19-Jan-2001 514.0 811.1 811.1 19-Jan-2001 581.3 675.0 675.0 19-Jan-2001 641.7 100.0 687.5 19-Jan-2001 701.5 700.0 811.1 19-Jan-2001 759.8 775.0 775.0 19-Jan-2001 19.2 787.5 787.5 19-Jan-2001 241.3 100.0 100.0 22-Jan-2001 394.8 811.1 811.1 22-Jan-2001 76.2 800.0 800.0 Phillips Alaska, Inc. Pad 1J (WS Pilot) 3 slot #3 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 1J-3 Version #2 Our ref : prop4360 License : Date printed : 22-Jan-2001 Date created : 20-Dec-2000 Last revised : 22-Jan-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on 561226.769,5943831.650,999.00000,N Slot location is n70 15 46.260,w149 31 29.010 Slot Grid coordinates are N 5945919.876, E 558789.828 Slot local coordinates are 2108.17 N 2420.12 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Pad 1J (WS Pilot),3 ~ Kuparuk River Unit,North Slope, Alaska~. PROPOSAL LISTING Page 1 Your ref : 1J-3 V%~-=on~ #2 Last revised 22-Jan~ ' Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C 00 R D I N A T E S Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 100.00 0.00 75.00 100.00 200.00 0.00 75.00 200.00 300.00 0.00 75.00 300.00 400.00 2.00 75.00 399.98 500.00 4.00 75.00 499.84 600.00 6.00 75.00 599.45 700.00 8.00 75.00 698.70 0.00 N 0.00 N 0.00 N 0.00 N 0.45 N 0.00 E 0.00 0.00 0.00 0.00 N/A 0.00 E 0.00 0.26 0.26 0.15 N/A 0.00 E 0.00 0.52 0.52 0.30 N/A 0.00 E 0.00 0.78 0.78 0.45 N/A 1.69 E 1.70 1.05 1.05 0.60 N/A 1.81 N 6.74 E 6.80 1.36 1.31 0.75 75.00 4.06 N 15.16 E 15.28 1.73 1.58 0.90 75.00 7.22 N 26.93 E 27.15 2.22 1.86 1.05 75.00 800.00 10.00 75.00 797.47 11.26 N 42.04 E 42.38 2.83 2.16 1.21 75.00 900.00 12.87 70.49 895.47 17.23 N 60.92 E 61.84 3.63 2.47 1.37 73.58 1000.00 15.78 67.61 992.36 26.13 N 84.00 E 86.39 4.67 2.81 1.53 71.86 1100.00 18.72 65.62 1087.85 37.94 N 111.20 E 115.94 5.97 3.17 1.71 70.20 1200.00 21.68 64.15 1181.69 52.62 N 142.44 E 150.41 7.55 3.56 1.90 68.71 1300.00 24.65 63.02 1273.61 70.14 N 177.65 E 189.72 9.44 3.98 2.12 67.41 1400.00 27.62 62.12 1363.38 90.45 N 216.73 E 233.76 11.66 4.43 2.36 66.28 1472.53 29.78 61.57 1427.00 106.89 N 247.44 E 268.59 13.47 4.77 2.56 65.58 1479.91 30.00 61.52 1433.39 108.64 N 250.67 E 272.27 13.66 4.80 2.58 65.51 1529.91 32.00 61.52 1476.25 120.92 N 273.30 E 298.02 15.03 5.04 2.73 65.11 1629.91 36.00 61.52 1559.13 147.58 N 322.44 E 353.92 18.26 5.55 3.07 64.41 1729.91 40.00 61.52 1637.92 176.94 N 376.55 E 415.48 22.02 6.08 3.48 63.87 1829.91 44.00 61.52 1712.22 208.84 N 435.35 E 482.37 26.31 6.61 3.96 63.44 1929.91 48.00 61.52 1781.67 243.14 N 498.56 E 554.29 31.15 7.15 4.51 63.12 2029.91 52.00 61.52 1845.94 279.67 N 565.88 E 630.88 36.52 7.68 5.13 62.86 2129.91 56.00 61.52 1904.70 318.24 N 636.97 E 711.76 42.41 8.19 5.84 62.65 2229.91 60.00 61.52 1957.68 358.68 N 711.50 E 796.55 48.78 8.68 6.61 62.49 2329.91 64.00 61.52 2004.62 400.78 N 789.09 E 884.83 55.62 9.13 7.45 62.36 2365.48 65.42 61.52 2019.82 416.12 N 817.36 E 916.99 58.10 9.29 7.76 62.32 2500.00 65.42 61.52 2075.77 474.46 N 924.89 E 1039.32 67.53 9.88 8.94 62.20 3000.00 65.42 61.52 2283.72 691.31 N 1324.55 E 1494.02 102.77 12.07 13.37 61.95 3500.00 65.42 61.52 2491.68 908.16 N 1724.21 E 1948.71 138.14 14.25 17.83 61.84 4000.00 65.42 61.52 2699.64 1125.01 N 2123.87 E 2403.41 173.56 16.43 22.31 61.77 4500.00 65.42 61.52 2907.60 1341.86 N 2523.53 E 2858.10 209.00 18.60 26.80 61.73 5000.00 65.42 61.52 3115.55 1558.71 N 2923.19 E 3312.80 244.46 20.77 31.29 61.69 5145.34 65.42 61.52 3176.00 1621.75 N 3039.36 E 3444.96 254.76 21.40 32.59 61.69 5500.00 65.42 61.52 3323.51 1775.56 N 3322.86 E 3767.49 279.92 22.94 35.78 61.67 6000.00 65.42 61.52 3531.47 1992.41 N 3722.52 E 4222.19 315.39 25.11 40.27 61.65 6131.12 65.42 61.52 3586.00 2049.28 N 3827.32 E 4341.42 324.69 25.68 41.45 61.65 6239.31 65.42 61.52 3631.00 2096.20 N 3913.80 E 4439.81 332.37 26.15 42.43 61.65 6500.00 65.42 61.52 3739.42 2209.27 N 4122.18 E 4676.88 350.86 27.28 44.77 61.64 7000.00 65.42 61.52 3947.38 2426.12 N 4521.84 E 5131.58 386.34 29.45 49.27 61.63 7285.20 65.42 61.52 4066.00 2549.81 N 4749.81 E 5390.93 406.58 30.68 51.83 61.62 7500.00 65.42 61.52 4155.34 2642.97 N 4921.50 E 5586.27 421.82 31.61 53.76 61.62 7766.07 65.42 61.52 4266.00 2758.36 N 5134.18 E 5828.23 440.70 32.77 56.16 61.61 7766.08 65.42 61.52 4266.01 2758.37 N 5134.19 E 5828.24 440.70 32.77 56.16 61.61 7800.00 64.94 62.50 4280.24 2772.82 N 5161.37 E 5859.03 443.11 32.91 56.46 61.62 7900.00 63.55 65.46 4323.70 2812.33 N 5242.29 E 5949.01 450.18 33.37 57.33 61.68 8000.00 62.22 68.48 4369.28 2847.16 N 5324.18 E 6037.65 457.20 33.83 58.19 61.78 8100.00 60.97 71.58 4416.86 2877.22 N 5406.83 E 6124.70 464.13 34.30 59.02 61.93 8200.00 59.78 74.75 4466.31 2902.41 N 5490.01 E 6209.92 470.93 34.78 59.84 62.12 8287.51 58.81 77.58 4511.00 2920.41 N 5563.05 E 6282.81 476.75 35.20 60.54 62.32 Ail data is in feet unless otherwise stated. Coordinates from slot #3 and TVD from est. rkb (116.00 Ft above mean sea level). Bottom hole distance is 8287.02 on azimuth 76.67 degrees from wellhead. Vertical section is from wellhead on azimuth 61.83 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 1J (WS Pilot),3 ~[' Your ref : 1J-3 Ve;' :on #2 Kuparuk River Unit,North Slope Alaska'~ ~ , Last revised 22-Jan Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C O 0 R D I N A T E S Sect Major Minor Vert. Azi. 8300.00 58.67 77.99 4517.48 2922.66 N 5573.49 E 6293.07 477.58 35.27 60.64 62.35 8400.00 57.65 81.31 4570.24 2937.94 N 5657.04 E 6373.94 484.04 35.75 61.42 62.61 8500.00 56.71 84.70 4624.46 2948.18 N 5740.43 E 6452.29 490.29 36.24 62.19 62.90 8600.00 55.87 88.16 4679.96 2953.37 N 5823.43 E 6527.91 496.30 36.72 62.94 63.23 8700.00 55.13 91.69 4736.62 2953.48 N 5905.82 E 6600.60 502.06 37.20 63.69 63.59 8800.00 54.49 95.28 4794.26 2948.52 N 5987.37 E 6670.15 507.54 37.68 64.42 63.97 8900.00 53.96 98.92 4852.73 2938.51 N 6067.86 E 6736.38 512.72 38.14 65.14 64.37 9000.00 53.54 102.60 4911.88 2923.47 N 6147.06 E 6799.11 517.60 38.60 65.85 64.79 9100.00 53.23 106.32 4971.53 2903.43 N 6224.77 E 6858.15 522.16 39.04 66.56 65.24 9200.00 53.04 110.06 5031.53 2878.47 N 6300.75 E 6913.36 526.39 39.47 67.27 65.69 9300.00 52.97 113.82 5091.72 2848.63 N 6374.82 E 6964.57 530.29 39.88 67.98 66.16 9400.00 53.02 117.57 5151.92 2814.02 N 6446.76 E 7011.65 533.85 40.28 68.68 66.63 9443.91 53.08 119.22 5178.31 2797.33 N 6477.63 E 7030.98 535.35 40.46 68.99 66.84 9500.00 53.08 119.22 5212.01 2775.44 N 6516.76 E 7055.15 537.28 40.68 69.39 67.11 9996.07 53.08 119.22 5510.00 2581.83 N 6862.89 E 7268.91 554.84 42.70 72.89 69.37 10000.00 53.08 119.22 5512.36 2580.30 N 6865.63 E 7270.60 554.98 42.72 72.92 69.39 10334.01 53.08 119.22 5713.00 2449.94 N 7098.68 E 7414.52 567.36 44.13 75.28 70.82 10500.00 53.08 119.22 5812.71 2385.16 N 7214.50 E 7486.04 573.51 44.83 76.46 71.53 10875.03 53.08 119.22 6038.00 2238.79 N 7476.17 E 7647.64 587.98 46.47 79.11 73.03 11000.00 53.08 119.22 6113.07 2190.02 N 7563.36 E 7701.49 592.79 47.02 79.99 73.53 11134.73 53.08 119.22 6194.00 2137.44 N 7657.37 E 7759.54 598.17 47.62 80.94 74.04 11262.91 53.08 119.22 6271.00 2087.41 N 7746.81 E 7814.77 603.29 48.20 81.85 74.52 11409.40 53.08 119.22 6359.00 2030.24 N 7849.02 E 7877.89 609.14 48.85 82.88 75.07 11500.00 53.08 119.22 6413.42 1994.88 N 7912.23 E 7916.93 612.76 49.26 83.52 75.41 11532.59 53.08 119.22 6433.00 1982.16 N 7934.97 E 7930.97 614.08 49.41 83.75 75.53 11535.92 53.08 119.22 6435.00 1980.86 N 7937.29 E 7932.41 614.21 49.42 83.78 75.54 11567.55 53.08 119.22 6454.00 1968.52 N 7959.36 E 7946.04 615.51 49.57 84.00 75.65 11572.54 53.08 119.22 6457.00 1966.57 N 7962.85 E 7948.19 615.71 49.59 84.04 75.67 11582.53 53.08 119.22 6463.00 1962.67 N 7969.82 E 7952.49 616.12 49.63 84.11 75.71 11592.52 53.08 119.22 6469.00 1958.78 N 7976.79 E 7956.80 616.53 49.68 84.18 75.74 11717.37 53.08 119.22 6544.00 1910.05 N 8063.90 E 8010.59 621.63 50.25 85.06 76.19 Ail data is in feet unless otherwise stated. Coordinates from slot #3 and TVD from est. rkb (116.00 Ft above mean sea level). Bottom hole distance is 8287.02 on azimuth 76.67 degrees from wellhead. Vertical section is from wellhead on azimuth 61.83 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1J (WS Pilot),3 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 1J-3 Version #2 Last revised : 22-Jan-2001 POSITION UNCERTAINTY SUMMARY DeDth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 11717 ARCO (H.A. Mag) User specified 621.63 50.25 85.06 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. Comments in wellpath MD TVD Rectangular Coords. Comment ........................................................................................................... 300 00 300. 800 00 797. 1472 53 1427. 1479 91 1433. 2365 48 2019. 5145 34 3176 6131 12 3586 6239 31 3631 7285 20 4066 7766 07 4266 7766.08 4266 8287.51 4511 9443.91 5178 9996.07 5510 10334.01 5713 10875.03 6038 11134.73 6194 11262.91 6271 11409.40 6359 11532.59 '6433 11535.92 6435 11567.55 6454 11572.54 6457 11582.53 6463 11592.52 6469 11717.37 6544 00 47 00 39 82 O0 00 O0 00 00 01 00 31 00 00 O0 00 0O 00 00 00 00 00 00 00 00 0 11 106 108 416 1621 75 2049 28 2096 20 2549 81 2758 36 2758.37 2920.41 2797.33 2581.83 2449.94 2238.79 2137.44 2087.41 2030.24 1982.16 1980.86 1968.52 1966.57 1962.67 1958.78 1910.05 00 N 26N 89 N 64 N 12 N N N N N N N N N N N N N N N N N N N N N N 0.00 42.04 247.44 250.67 817.36 3039.36 3827.32 3913.80 4749.81 5134.18 5134.19 5563.05 6477.63 6862.89 7098.68 7476.17 7657.37 7746 81 7849 02 7934 97 7937 29 7959 36 7962 85 7969 82 7976 79 8063 90 E K0P E Beg 3/100 Bld E Base Permafrost E Beg 4/100 Bld E EOC E Top Ugnu E 1J-41 WS Rvsd il-Jan-01 E Base Ugnu E Base W Sak E 9 5/8 Csg E Begin Drop/Turn E C80 E EOC E C50 E C40 E C30 E C20 E 7 Csg/Base HRZ E K-1 E Top Kup D E 1J-41 C4 Rvsd 4-Jan-01 E Top C3 E Top C2 E Top C1 E Top B Shale E TD - Csg 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 7766.07 4266.00 2758.36N 5134.18E 9 5/8 Casing 0.00 0.00 0.00N 0.00E 11262.91 6271.00 2087.41N 7746.81E 7 Casing 0.00 0.00 0.00N 0.00E 11717.37 6544.00 1910.05N 8063.90E 3 1/2" Casing Target name Targets associated with this wellpath Geographic Location T.V.D. Rectangular Coordinates Revised 1J-41 WS Rvsd ll-Jan 562600.000,5948000.000,0.0000 3586.00 1J-41 C4 Rvsd 4-Jan- 566710.000,5947965.000,0.0000 6435.00 2049.28N 3827.32E 1980.86N 7937.29E 15-Jan-2001 12-Sep-2000 RECEIVED JAN 2 6 2001 Alaska Oil & Gas Cons, Commission Anchorage PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY January 26, 2001 Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 Re: Application for Permit to Drill KRU 1J-03 Surface Location: 2107' FSL, 2419' FEL, Sec 35, T11N, R10E, UM Target Location: 1193' FNL, 240' FWL Sec. 31, T11 N, R11 E, UM Bottom Hole Location: 1264' FNL, 367' FWL Sec. 31, T11N, R11E, UM Dear Commissioner Seamount, Phillips Alaska, Inc. submits this Application for Permit to Drill the development well KRU 1J- Nabors Rig 16e will drill and complete this well as a MW.A~lfic~e~er.., Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be hauled to an approved Prudhoe or GKA Class II disposal well. The following are Phillips' designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon AIIsup-Drake, Drilling Technologist 263-4612 (20 AAC 25.070) 2) Geologic Data and Logs Bill Raatz, Geologist 263-4952 (20 AAC 25.071) If you have questions or require additional information, please contact Todd Mushovic at 265- 6974 or me at 265-6434 in our Anchorage office. Sincerely, James Trantham Drilling Engineering Supervisor Attachments cc: KRU 1J-03Well File RECEIVED JAN B 6; 2001 Alaska 0il & Gas Cons, Commission Anchorage American Express® PAY TO THE ORDER ~' Cash Advance Draft 105 DATE //~/O/ e2~011021 Issued by Integrated Payment System, Inc. Englewood, Colorado Payable at Norwest Bank of Grand Junction - Downtown, Grand Junction, Colorado PERIOD ENDING ': '~O ;~ i, OO [,DO': 5 5 ,,, 0 ~ ? S 0 0 0 S ~ r: ,' 0 &.O S , , WELL PERMIT CHECKL.!ST COMPANY FIELD & POOL 5/'~'~__~/~:~ INIT ADMINISTRATION II APP~R DATE ENGINEERING APPR DATE GEOLOGY APPR DATE . /Z,///~'5' WELL NAME /,.,/ .- O -.~' PROGRAM:exp CLASS ~' ,~E..q M/~ - ~,.),~.~/,'1,/ GEOL AREA . 2. 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling 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 canbe issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... C ~N ,N dev redrll serv wellbore seg Permit fee attached ....................... ~ Lease number appropriatelY: ................. ann. disposal para req 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... ON/OFF SHORE 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Ddlling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating apPropriate; test to ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... ,~) . ,. ~, 31. Data presented on potential overpressure zones ....... ~?,~ ~ ~ 32. Seismic analysis of shallow gas zones ............. ~~ gi~'~ ~ ~/~o ~.,,,.~t .~- ~x~.~,~¥ ~/~'~.~'/~~/~%~ ~'11 33. Seabed condition su~ey (if off-shore) ............ ~ fl~ Y N A~i~ ~t~c'~ .. tS~ ~A~,,~ ~.~t~ ~ ~.~g~~ II ~. Contain name/phone for weekly progress repo~s [explq~ only] Y N z~ [~'~ , ~ ~ ~/~/~'~.~...~A,,.~ .~1~ ~i~' ~:~.~. ,.~ /~~ ,~ ~~ ,,f ANNULAR DISPOSAL35. With proper cementing records, this plan ft,,% ~ ~-~.m~/ ~, ~., ;'~ .~. ~_ .- 5~' ~_e.~;g . ~ (A) will contain waste in a suitable receiving zone~ ........ Y N APPR DATE (B) will not contaminate freshwater; or ~use drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) 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: . UlClAnnular .~Y COMMISSION: Commentsllnstrucfions: J§ I§ c:\msoffice\wordian\diana\checklist (rev. 11/01//00) . 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 APPEN. DIXi .. No 'special'effort has been made to chronologically ., organize this category of information. oo clr3S, { ;2 ùì - oÁ'1 Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe 1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. July 11, 2005 7504 1 3.5" 9.3 lb. L-80 EUE & SLHT Tubing & Liner Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: 1J-03 Kuparuk Alaska 50-029-23002-00 10,914 Ft. (MD) 11,649 Ft. (MD) Inspection Type : Whipstock Placement Inspection COMMENTS: This log is tied into the top of the peñorations @ 11,606' (ELMD). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages to determine the potential for successful whipstock placement. The caliper recordings indicate the interval of 3.5" tubing and liner logged appears to be in good condition with respect to corrosive damage. No significant wall penetrations or areas of cross-sectional wall loss are recorded throughout the interval logged. Although the caliper recordings indicate slight buckling in joint 340 (10,978'), it does not appear to represent a significant 1.0. restriction. No significant 1.0. restrictions are recorded throughout the interval logged. Due to the limited interval logged and good condition of the tubing and liner logged, a 3-D log plot is provided in lieu of the traditional Body Damage Profile. The joint numbering used in this report is an estimate based on the depth logged and the average length of the tubing. MAXIMUM RECORDED WAll PENETRATIONS: No significant wall penetrations are recorded throughout the interval of tubing and liner logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: Although the caliper recorded slight buckling in joint 340, no significant 1.0. restrictions are recorded throughout the tubing and liner logged. S(~/\NNE~) l\UG 3 ]. 2005 I Field Engineer: L. Dawson Analyst: M. Lawrence Witness: T. Senden ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Q, Description : Commentc;; Joint 355 Joint 356 Joint 357 Peñorations (11,606' - 11,616') Joint 358 ( ~ PDS MultlTlnger Caliper 3D Log Plot Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Well: 1 J-03 Date: July 11, 2005 Detail of Caliper Recordings Across Whipstock Placement Location (11,572' - 11,600' I 1500 1500 145 1500 350-.~;' ~ 350ß MIN In (1/1000 inJ MAX In (1/1000 inJ Nominal I.n. 350Q ~ i --.-----=1t~-==----.--~---- >,; . f 11560 ===--== ~-------= . } : I ------,--~. _._~.. _ ~c.C~____ ~ ----- ------------ '< .------,.--..-..-.. ----- ---- f '" ~ f-- ----- 11570 11580 --~---_._--"-- 11590 i ....-.- ~ ~f ._-~ )>- -------If----= ~~ ---~ ----- (: I S~ fll: <.~ (~ .. , I , , .a:~ H r~ 11600 - 11610 11620 11630 . I' 11640 , ¡ . .~ 1; I" .~ !( PDS Multìnnger Caliper 3D Log Plot Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Well: 1J-03 Date: July 11, 2005 Detail of Caliper Recordings Across Proposed Whipstock Interval a Description : ~omments % 1500 ?500 230 '500 10920 Joint 338 10930 10940 10950 Joint 339 10960 10970 10980 Joint 340 10990 11000 Pup Jt. 340.1 11010 GLM6 (Latch @ 8:30) 11020 Pup Jt. 340.3 11030 Joint 341 11040 11050 Pup Jt. 341.1 _ DS Nipple Pup Jt. 341.3 11060 11070 MIN In (1/1000 inJ MAX In (1/1000 inJ 350~..': -} 3500, Nomin~ll.n. 3500 ~: -------,----- ...~ fJ ,... .., , ... --------;'1 ___u________ l~ ----- ---- T~--=---- i/', ~I\ --{i ~j , I ___.___~--...~~ r-- -~=--- ---~~~ ,. . I ¡: ,"" ]. <' þ} - ---)>t ---------..--- -- ..,; ~ I .t , ~: ------"- ,-~._- ---- ~..._. I ~ ~ ,. -. ----------- ~ -- } ~ . ..~, 1 I ~-""i ." . . -- '~p ~ , I: I' :< ,,\ JJ . ~ fT" ~~ 'Ì I : ~~ J ~. ;s. --- _._-- ---- - '._~.- ~._--- ;t. . ----------------.-- ~ 't - 11160 ---.. - ~ -'--- --- .,. -I-I~ "'¡'.ç-- ~, I ¡. I ¡ ~;; ì: " -!- <: :.......- --..------.--...--.- ~. ~ !J 11190 ~~-- -1~- 11080 Joint 342 11090 Pup Jt. 11100 342.1 11110 No Go 11120 Locator I Seal Assembly 11130 11140 ..... Packer Top of 3.5" f \ Liner I 11150 Pup Jt. \ 342.5 I Joint 343 11170 11180 XN Nipple .... 11200 Joint 344 11210 11220 11230 Joint 345 11240 11250 11260 ..Inint ~AI::: -i ===--=~-=----- '~._- ------=--=== !,l------ --- --------- ;""III'. 1 ,~ ~J:--_ ~ S! I, ;:: ==~---- --~- ' ; ----- ~ - __ _ ~ L ~.. ~ ~ 11 ~~ jj --,-~-,- ~ ~ , -,,' ........ . T " ____on?; L._ I -, - : r : . r- ~I" j";: -------- -...-- ~, . _.._____'___n..___.__~~ :~~_ ----- --..,: ~ t f" -_._--,~.- ~. i~ , ,..... ~~ ~: r~ ~i ,... I" ~,i ~ t it' ... ) ~ 1..-t ;, ~ -,"-:'-- t~: - j~ ----- --- ,.-.-- }, ,.; (~ f.. ' , .. ," j ~,~ i~ ,,;¡. 'C ~~ ~; ~ 1 . , ~. ,- ,;., I': ~~ ~ ~, ~; <~ .. t ~ ..:,: :. l- f . ~-- -_._~,.. 'J# ,....- ---, ~, '" ' ~ ~ ~ f· ---- _ . --"-- ~ ~ ----- ~:1 ~ -------- , -J ! ... -- ., , ,.: ,~ ===~:==--_._.._-'~ ~_...- 'I .. - .----....--- ~ ~ , r·' ~) -----.-..-..........-. ... ',' '" ~i <:~ I. .., .-_,______ -,.,__ -------_..- -"-, -~-,,-~ .-... --~_._... --~. ---- ~---- ---- ---.'-'- ,----_. -..-------- ~, >.. ~' " .j f! --".- -~---- == ~:. --,.--.----- - ----- -~-'- ..____ z . -~~=- -tt-- ~ }------- ~~_.--__=_=_-' r ( --------- (i t ,1' --===~:-p---=~ -- ><{ --. =-1t-----~ - ~! --,,-' -~--,---- 11340 11350 11360 Joint 349 11370 11380 11390 Joint 350 11400 11410 11420 Joint 351 11430 11440 11450 Joint 352 11460 11330 Joint 348 --...... - -- 11270 11280 11290 Joint 347 11300 11310 11320 " ..-( ~1 t ~ ..~ ~ ~ '"I., __ __ c.. ____ ~'¡. ----.- ~ , . .. .~ - ."'1{ . ~ ' 11530_~~__ {.___ ----{ ~--- r.~ '-,. r ~ -.~__. s. 11550 _______..__..______~~-.--------.-.- --- . ~=:::~] k::::~:- -==- -=:: ---- ~ ~ .,·1It ------ --' I",,,, ì'" .~ - --. --{ ;--_.-=~=-~~== ~, ~; ~~ ~~.1 ¡-I,,-, ~', \ ,- <11: .. ~~~~---== .. JÞ ,- -....-... ~ -.----- --------~! - -- - ---- --- S~ ~,. ,,~ ~.~ ,,~ ~.~ -- -- tl ~.-- -1~ . '" $ ..~ --- ..------ ~ r- J,; .jø .. ) ~ ~ ~.... 11580 Joint 356 11590 11600 11610 Joint 357 Peñorations (11,606' - 11620 11,616') 11630 Joint 358 11640 11570 11560 Joint 355 11540 Joint 354 11520 11510 11500 11490 Joint 353 ,'I ---- .. -- -- -~ 11470 _ ---~-~1t -----.. -- - ~-- -- ~ --- --.- 11480 l;------~ ------ ~ ~ lUBING (0-11161, 00:3.500, 10:2.992) ilE BACK :11101-11102, 00:5.750) SEAL :11124-11125, 00:4.000) FRAC :11606-11616) Perf :11606-11616) PLUG :11650-12214, 00:2.992) Perf :11833-11843) ( ConocoPhillips Alaska, Inc. 1 J-03 II I I, I I 1 1 t API: 500292300200 SSSV Type: Nipple Well Type: PROD Orig 3n12001 Completion: Last W/O: Annular Fluid: Reference Log: Last Tag: 12005 Last Tag Date: 2/412004 Casing String - All STRINGS Description CONDUCTOR PRODUCTION SURFACE LINER Tubing String - All Size I 3.500 Peñorations Summary Interval TVD 11606 - 11616 6478 - 6484 Ref Log Date: TO: 12214 ftKB Max Hole Angle: 67 deg @ 5088 Size Top Bottom 20.000 0 120 7.000 32 11255 9.625 35 7784 3.500 11101 12214 Bottom TVD Wt 11161 6216 9.30 Top o KRU 1J-03 Angle @ TS: 55 deg @ 11569 Angle @ TO: 57 deg @ 12214 Rev Reason: Adjust TBG top to O' Last Update: 9/512004 TVD Wt Grade Thread 120 91.50 H-40 WELDED 6272 26.00 L-80 BTCM 4269 40.00 L-80 BTCM 12214 9.30 L-80 SLHT I Grade I Thread EU-MOD Zone Status Ft SPF Date Type Comment C-4 10 6 6/27/2001 APERF 2.5" HSD 60 deg BH-DP chgs A-5 10 6 5/23/2001 IPERF 2.5" HSD, 60 deg ph, BH-DP charges 11833-11843 6606-6612 Stimulations & Treatments Interval Date Type 11606-11616 6/28/2001 FRAC Comment C- SAND FRAC, 58,000#,16/20 CARBO LITE, 7 ppa ON PERFS TIE BACK SLEEVE BAKER 5"X7" ZXP LINER TOP PACKER TKC COUPLING BAKER 5" X 7" FLEX-LOCK LINER HANGER W/RS NIPPLE & TKC COUPLING 11129 6196 SBE BAKER SBE 80-40 wrrCK couplings & XO 11187 6231 NIP HOWCO XN NIIPLE WITH 2.75" NO GO SLHT BOX X PIN 11650 6504 PLUG SAND PLUG 12146 6778 COLLAR BAKER LANDING COLLAR, SLHT 12179 6796 COLLAR BAKER FLOAT COLLAR, SLHT 12214 12214 SHOE BAKER FLOAT SHOE, SLHT Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 539 538 NIP 11078 6166 NIP 11122 6192 LOCATOR 11124 6193 SEAL 11161 6216 SHOE General Notes Date I Note 5/23/2001 30 min. of SIBH P of 3486 PSI at mid perf. Gas lift MandrelsNalves St MD TVD Man Man Type Mfr 1 3534 2509 CAMCO KBUG 2 6910 3909 CAMCO KBUG 3 9091 4960 CAMCO KBUG 4 10229 5652 CAMCO KBUG 5 11028 6136 CAMCO MMG Other (plugs, equip., etc.) - LINER Depth TVD Type 11101 6180 TIE BACK 11109 6184 PKR 11115 6188 HANGER VMfr V Type VOD Latch CAMCO GLV 1.0 BK CAMCO GLV 1.0 BK CAMCO GLV 1.0 BK CAMCO GLV 1.0 BK CAMCO OV 1.5 RK Description Description CAMCO 'OS' nipple with NO GO profile CAMCO 'OS' nipple wINO GO profile BAKER NO GO LOCATOR BAKER GBH-22 35' Seal Assembly BAKER mule shoe Port TRO Date Vlv Run Cmnt 0.156 1270 7/212001 0.188 1303 7/2/2001 0.188 1298 7/212001 0.250 1394 7/212001 0.250 0 7/2/2001 ID 5.250 4.438 4.250 4.000 2.750 0.000 0.000 0.000 0.000 ID 2.875 2.812 3.000 3.000 3.000 Sperry-Sun Drilling Services LiS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Apr 19 16:38:57 2001 Reel Header Service name ............. LISTPE Date ..................... 01/04/19 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 ..................... 01/04/19 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 MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-10047 T. MCGUIRE F. HERBERT 1J-03 500292300200 PHILLIPS Alaska Inc. Sperry Sun 19-APR-01 MWD RUN 2 AK-MM-10047 T. MCGUIRE F. HERBERT MWD RUN 3 AK-MM-10047 T. MCGUIRE F. HERBERT JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 4 AK-MM-10047 P. SMITH G. WHITLOCK MWD RUN 5 AK-MM-10047 P. SMITH G. WHITLOCK 35 llN 10E 2107 FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 2419 .00 116.12 81.60 REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 16.000 137.0 8.500 9.625 7784.0 6.125 7.000 11254.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. MWD RUNS 2-3 ARE DIRECTIONAL WITH DGR, EWR4, COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). 4. MWD RUN 4 IS DIRECTIONAL WITH DGR, EWR4, AND BIMODAL ACOUSTIC TOOL (BAT). 5. MWD RUN 5 IS DIRECTIONAL WITH DGR, EWR4, CNP,SLD, AND BAT. 4. MWD DATA IS CONSIDERED PDC PER THE PHONE CONVERSATION BETWEEN J. HARRISON OF PHILLIPS ALASKA, INC. AND R. KALISH OF SPERRY- SUN DRILLING SERVICES ON 04/10/01. 5. MWD RUNS 1-5 REPRESENT WELL 1J-03 WITH API%: 50-029-23002-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12214'MD, 6816'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. DTCP = SONIC COMPRESSIONAL SLOWNESS POST-PROCESSED. DTSP = SONIC SHEAR SLOWNESS POST-PROCESSED. VPVS = COMPRESSIONAL-TO-SHEAR VELOCITY RATIO. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SS MATRIX FIXED HOLE SIZE). SNFA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 12.25"-6.125" MUD WEIGHT: 9.7-11.0 PPG MUD SALINITY: 400-900 PPM CHLORIDES FORMATION WATER SALINITY: 13000 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 ....... 01/04/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPM RPD FET NPHI NCNT FCNT DRHO PEF RHOB DT DTSH SCRA $ .5000 START DEPTH 99.5 122 0 127 0 127 0 127 0 127 0 127 0 5000 0 5000 0 5000 0 5009 5 5009 5 5009 5 7774 0 7799 5 7799.5 STOP DEPTH 12159.0 12213 0 12166 0 12166 0 12166 0 12166 0 12166 0 12111 0 12111 0 12111 0 12128 0 12128 0 12128 0 12083 0 12083 0 12083 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHiFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 99.5 5100.0 2 5100.0 5911.0 3 5911.0 7794.0 4 7794.0 11268.0 5 11268.0 12213.0 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 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 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 DT MWD USPF 4 1 68 56 15 DTSH MWD USPF 4 1 68 60 16 SCRA MWD 4 1 68 64 17 Last Name Service Unit Min Max Mean Nsam Reading DEPT FT 99.5 12213 6156.25 24228 12213 ROP MWD FT/H 0.04 38668.8 158.966 24183 12213 GR MWD API 20.28 431.08 96.5108 24120 First Reading 99.5 122 99.5 12159 RPX MWD OHMM 12166 RPS MWD OHMM 12166 RPM MWD OHMM 12166 RPD MWD OHMM 12166 FET MWD HOUR 12166 NPHI MWD PU-S 12111 FCNT MWD CNTS 12111 NCNT MWD CNTS 12111 RHOB MWD G/CM 12128 DRHO MWD G/CM 12128 PEF MWD BARN 12128 DT MWD USPF 12083 DTSH MWD USPF 12083 SCRA MWD 12083 0 55 0 06 0 12 0 44 0 11 11 69 78.5 2208 1.681 -0.274 1.66 51 116 1.46 830.16 1771.07 2000 2000 165.45 68.68 934 28793.3 3.147 0.545 16.43 146 3O0 2.87 14.1726 24079 18.8838 24079 30.2172 24079 37.049 24079 1.75514 24079 42.2745 7124 550.173 7125 6786.62 7125 2.30468 7158 0.0844315 7158 3.32156 7158 101.299 8619 198.073 8396 1.94356 8396 127 127 127 127 127 5000 5000 5000 5009.5 5009.5 5009.5 7774 7799.5 7799.5 First Reading For Entire File .......... 99.5 Last Reading For Entire File ........... 12213 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/19 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 ....... 01/04/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 99 5 ROP 122 0 RPS 127 0 RPX 127 0 RPM 127 0 RPD 127 0 FET 127 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: STOP DEPTH 5063 0 5100 5 5056 0 5056 0 5056 0 5056 0 5056 0 13-FEB-01 Insite 65.44 Memory 5100.0 2.2 67.1 TOOL NUMBER 1846HWRGV8 1846HWRGV8 12.250 137.0 S PUD MUD 9.60 135.0 9.0 5OO 5.0 1.900 1.364 2.700 4.5OO 65.0 93.2 65.0 65.0 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 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 MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 Last Name Service Unit Reading DEPT FT 5100.5 ROP MWD010 FT/H 5100.5 GR MWD010 API 5063 RPX MWD010 OHMM 5056 RPS MWD010 OHMM 5056 RPM MWD010 OHMM 5056 RPD MWD010 OHMM 5056 FET MWD010 HOUR 5056 Min 99.5 0.38 20 28 1 25 1 29 1 22 0 44 0 11 Max Mean Nsam 5100.5 2600 10003 38668.8 208.871 9958 138.15 69.7388 9928 830.16 26.0014 9859 387.49 36.1062 9859 2000 59.5075 9859 2000 70.0043 9859 6.35 0.521352 9859 First Reading 99.5 122 99.5 127 127 127 127 127 First Reading For Entire File .......... 99.5 Last Reading For Entire File ........... 5100.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/19 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 ....... 01/04/19 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: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI FCNT NCNT RHOB DRHO PEF FET RPX RPS RPD RPM GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5000.0 5000 0 5000 0 5009 5 5009 5 5009 5 5056 5 5056 5 5056 5 5056 5 5056 5 5064 5 5101 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 5866 5866 5866 5866 5873 5911 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA STOP DEPTH 5808 5 5808 5 5808 5 5818 0 5818 0 5818 0 5866 5 5 5 5 5 5 0 15-FEB-01 Insite 65.44 Memory 5911.0 64.0 67.2 TOOL NUMBER 1846HWRGV8 1846HWRGV8 1846HWRGV8 1846HWRGV8 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 Depth Units ....................... Datum Specification Block sub-type...0 12.250 SPUD MUD 9.70 133.0 9.0 6OO 5.6 1.900 1.395 2.700 4.5OO Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 ! 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 65.0 91.0 65.0 65.0 Last Name Service Unit Reading Min Max Mean Nsam First Reading DEPT FT 5911 ROP MWD020 FT/H 5911 GR MWD020 API 5873 5 RPX MWD020 OHMM 5866 5 RPS MWD020 OHMM 5866 5 RPM MWD020 OHMM 5866 5 RPD MWD020 OHMM 5866 5 FET MWD020 HOUR 5866 5 NPHI MWD020 PU-S~ 5808 5 FCNT MWD020 CNTS 5808 5 NCNT MWD020 CNTS 5808 5 RHOB MWD020 G/CM 5818 DRHO MWD020 G/CM 5818 PEF MWD020 BARN 5818 50OO 0 75 32 93 4 28 4 65 3 58 3 38 0 26 21.8 543 2208 1.689 -0.096 1.66 5911 222 94 116 86 85 49 113 48 115 31 370 86 16 73 68 68 731 2768 2.793 0.545 5.32 5455.5 1823 148.671 1621 75.6019 1619 14.0513 1621 16.1715 1621 17.8882 1621 18.1895 1621 1.44538 1621 42.3312 1618 629.281 1618 2468.38 1618 2.19481 1618 0.0717719 1618 2.28049 1618 5OO0 5101 5064 5 5056 5 5056 5 5056 5 5O56 5 5056 5 5000 5000 5000 5009.5 5009.5 5009.5 First Reading For Entire File .......... 5000 Last Reading For Entire File ........... 5911 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/19 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 ....... 01/04/19 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 SUMM£ARY VENDOR TOOL CODE START DEPTH NCNT FCNT NPHI RHOB DRHO PEF RPS RPM RPD FET RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5811 5 5811 5 5812 0 5821 5 5821 5 5821 5 5869 5 5869 5 5869 5 5869 5 5869 5 5876 5 5911 5 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 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ 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: STOP DEPTH 7694.5 7694.5 7694.0 7704.0 7704 0 7704 0 7752 5 7752 5 7752 5 7752 5 7752 5 7759 5 7793 5 17-FEB-01 Insite 65.44 Memory 7795.0 63.9 66.5 TOOL NUMBER 1846HWRGV8 1846HWRGV8 1846HWRGV8 1846HWRGV8 12.250 7784.0 SPUD MUD 9.80 133.0 9.0 600 5.6 1.900 1.353 2.700 4.500 65.0 101.1 65.0 65.0 MATRIX DENSITY: HOLE CORRECTION IIN) : 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 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 MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 Last Name Service Unit Reading DEPT FT 7793.5 ROP MWD030 FT/H 7793 5 GR MWD030 API 7759 5 RPX MWD030 OHMM 7752 5 RPS MWD030 OHMM 7752 5 RPM MWD030 OHMM 7752 5 RPD MWD030 OHMM 7752 5 FET MWD030 HOUR 7752 5 NPHI MWD030 PU-S 7694 Min 5811.5 0.O4 53 59 2 53 2 62 2 69 2 92 0 24 11 69 Max Mean Nsam 7793.5 6802.5 3965 226.31 124.071 3765 144.68 95.6134 3767 89.44 7.97497 3767 106.17 8.79815 3767 95.8 9.36857 3767 80.04 9.5338 3767 14.26 1.29014 3767 61.25 43.8531 3765 First Reading 5811 5 5911 5 5876 5 5869 5 5869 5 5869 5 5869 5 5869 5 5812 FCNT MWD030 CNTS 555 934 7694.5 NCNT MWD030 CNTS 2216 2999 7694.5 RHOB MWD030 G/CM 1.681 3. 147 7704 DRHO MWD030 G/CM -0.156 0.524 7704 PEF MWD030 BARN 1.7 5.8 7704 648.185 2455.59 2.2789 0.0926336 2.35691 3767 3767 3766 3766 3766 5811.5 5811.5 5821.5 5821.5 5821.5 First Reading For Entire File .......... 5811.5 Last Reading For Entire File ........... 7793.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/19 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 ....... 01/04/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START RPM 7753 RPX 7753 RPS 7753 RPD 7753 FET 7753 GR 7760 DT 7774 ROP 7795 DTSH 7799 SCRA 7799 $ LOG HEADER DATA 4 .5000 DEPTH 0 0 0 0 0 0 0 5 5 5 STOP DEPTH 11226.0 11226 0 11226 0 11226 0 11226 0 11216 0 11172 0 11268 0 11172 0 11172 0 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 BAT BIMODAL ACOUSTIC $ 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 (OHHM) 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 Depth Units ....................... Datum Specification Block sub-type...0 26-FEB-01 Insite 65.44 Memory 11268.0 51.5 65.5 TOOL NUMBER PB01831HWGRA6 PB01831HWGRA6 PB01831HWGRA6 8.500 11254.0 LSND 9.80 48.0 9.0 5OO 3.9 4.600 2.564 2.000 2.600 65.0 122.0 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT ROP MWD040 GR MWD040 RPX MWD040 RPS MWD040 RPM MWD040 RPD MWD040 FET MWD040 DT MWD040 DTSH MWD040 SCRA MWD040 FT FT/H AP1 OHHH OHHH OHHH OHHH HOUR USPF USPF 1 68 0 1 1 68 4 2 1 68 8 3 1 68 12 4 1 68 16 5 1 68 20 6 1 68 24 7 1 68 28 8 1 68 32 9 1 68 36 10 1 68 40 11 Last Name Service Unit Reading DEPT FT 11268 ROP MWD040 FT/H 11268 GR MWD040 API 11216 RPX MWD040 OHMM 11226 RPS MWD040 OHMM 11226 RPM MWD040 OHMM 11226 RPD MWD040 OHMM 11226 FET MWD040 HOUR 11226 DT MWD040 USPF 11172 DTSH MWD040 USPF 11172 SCRA MWD040 11172 Min 7753 0.43 50 09 1 03 0 06 0 12 1 07 0 21 53 116 1.63 Max 11268 433.89 431.08 18.79 1771.07 98.59 2000 165.45 146 253 2.46 Mean Nsam 9510.5 7031 133.548 6946 135.013 6913 3.19362 6947 3.63397 6947 3.48336 6947 12.9711 6947 2.75497 6947 103.502 6797 201.151 6745 1.94584 6745 First Reading 7753 7795.5 7760 7753 7753 7753 7753 7753 7774 7799.5 7799.5 First Reading For Entire File .......... 7753 Last Reading For Entire File ........... 11268 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH DT GR RPM RPX RPS RPD FET NPHI FCNT NCNT RHOB DRHO PEF SCRA DTSH ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 11172 5 11216 5 11226 5 11226 5 11226 5 11226 5 11226 5 11244 0 11244 0 11244 0 11244 5 11244 5 11244 5 11258 0 11258 0 11268 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (HEMORY OR REAL-TiHE): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG HINIMUM ANGLE: HAXIMUM 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 BAT BIMODAL ACOUSTIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : STOP DEPTH 12083 0 12159 0 12166 0 12166 0 12166 0 12166 0 12166 0 12111 0 12111 0 12111 0 12128 0 12128 0 12128 0 12083 0 12083 0 12213 0 03-MAR-01 Insite 4.30 Memory 12214.0 52.8 57.1 TOOL NUMBER 1829GR4/1826NL4 1829GR4/1826NL4 1829GR4/1826NL4 1829GR4/1826NL4 1829GR4/1826NL4 6.125 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 Depth Units ....................... Datum Specification Block sub-type...0 LSND 11.10 50.0 9.0 650 3.9 1.700 1.021 1.800 2.800 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 DT MWD050 USPF 4 1 68 56 15 DTSH MWD050 USPF 4 1 68 60 16 SCRA MWD050 4 1 68 64 17 75.0 129.4 75.0 75.0 Last Name Service Unit Min Max Mean Nsam First Reading Reading DEPT FT 12213 ROP MWD050 FT/H 12213 GR MWD050 AP1 12159 RPX MWD050 OHMM 12166 RPS MWD050 OHMM 12166 RPM MWD050 OHMM 12166 RPD MWD050 OHMM 12166 FET MWD050 HOUR 12166 NPHI MWD050 PU-S 12111 FCNT MWD050 CNTS 12111 NCNT MWD050 CNTS 12111 RHOB MWD050 G/CM 12128 DRHO MWD050 G/CH 12128 PEF MWD050 BARN 12128 DT MWD050 USPF 12083 DTSH MWD050 USPF 12083 SCRA MWD050 12083 11172.5 0 26 54 03 0 55 0 65 0 86 1 05 0 57 24 51 78.5 12181.1 1.988 -0.274 3.71 51 142 1.46 12213 336.86 241.17 301.94 940.36 2000 2000 103.05 65.84 562.9 28793.3 3.113 0.383 16.43 126 300 2.87 11692.8 67. 9677 116.125 5.25291 7.49704 27.8664 24.6695 5.69935 38.8002 263.41 20229.5 2.46039 0.0785554 6.33227 93.0812 185.5 1.93424 2082 1890 1886 1880 1880 1880 1880 1880 1735 1735 1735 1768 1768 1768 1822 1651 1651 11172 5 11268 5 11216 5 11226 5 11226 5 11226 5 11226 5 11226 5 11244 11244 11244 11244.5 11244.5 11244.5 11172.5 11258 11258 First Reading For Entire File .......... 11172.5 Last Reading For Entire File ........... 12213 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/04/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. L!STPE Date ..................... 01/04/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Physical EOF End Of LIS File
