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Home My WebLink About201-095FROM: Sandra D. Lemke, ATO -704 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Core Photo well list DATE: 11/15/2019 "WMI .. RECEIVED Conte Phillips NOV 15 2019 TRANSMITTAL AOGCC TO: Meredith Guhl AOGCC 222 W. Th Ave., Suite 100 Anchorage, Alaska 99501 Transmitted: Transmittal instructions: please promptly sign, scan, and e-mail to Receipt: Date: [ f I I g I l Alaska/IT-GGRE I Co ocoPhil s Alaska I Office: 907.265 6947, Mobile 907 440,4512 2 01 -Oa 6 314L4?-. dente 210-417 Core photos 3 1 4 4 5 103- 0f- 3S-16 Core Photos 31444, ?01- y AWE 1 Core photos 3 1 4 4 3 !Dl -0 5 CG? -24 Core Photos 3 1 4 4 2 DI -2 y Cirque 3 Core photos - Tt 0 -N 7- 100-1 12 Meltwater North 1 UV WL photos—T2_5(9(00 01(o Shark Tooth 1 Corephotos—T2-H149 ,pp- c 17.E 1004025835 Meltwater-N-1,pdf-'_25(o D 9S,U�* Q 1004278632 3S-16.pdf 3 1 4 4 4 W -O zi WI 1604282603 Rendezvous-A.pdf 3 1 4 4 6 Transmittal instructions: please promptly sign, scan, and e-mail to Receipt: Date: [ f I I g I l Alaska/IT-GGRE I Co ocoPhil s Alaska I Office: 907.265 6947, Mobile 907 440,4512 2 01 -Oa 6 314L4?-. STATE OF ALASKA • ,. AKA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor Treatment LI 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 201-095 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20377-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 387212, 387207 CRU CD2-24 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 14301 feet Plugs measured None feet true vertical 7202 feet Junk measured None feet Effective Depth measured 14301 feet Packer measured 9954 feet true vertical 7202 feet true vertical 7013 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' iCANKE "ani a 2 U1.( Surface 2756' 9.625" 2792' 2372' Intermediate Production 10776' 7" 10811' 7232' Liner RECEIVED Perforation depth Measured Depth: Open Hole Completion 10811'- 14301' .,AN 0 8 201 True Vertical Depth: 7232'-7202' AOGCC Tubing(size,grade,measured and true vertical depth) 4.5", L-80, 10030' MD and 7047'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker S-3 Packer, 9954'MD and 7013'TVD SSSV: Camco WRDP-2, 2137'MD and 1969'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10811'- 14301' Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 310 24 541 1001 228 Subsequent to operation: 156 7 565 873 213 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work. Daily Report of Well Operations Q Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. 'Sundry Number or N/A if C.O.Exempt: None Contact Kerry Freedman Email Kerrv.C.Freedmanacop.com Printed Name Kerry Freedman Title Principal Production Engineer Signatureq/ -cYi14 � Phone 265-6579 Date 7 ' b yr- ///3 /1G Aii t/, 3i1d RBDMSY1AN 1 1 2016 Form 10-404 Revised 5/2015 Submit Original Only • • CD2-24 Scale Inhibition Treatment 12/10/15—12/11/15 Aqueous Scale Inhibitor Squeeze Job pumped from 07:59 on 12/10/15 to 03:08 on 12/11/15. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA—207/984/611 - ACF pumped 30 bbls seawater for a tubing flush at .9—3 bpm,TBG/IA/OA-268/942/551 - LRS pumped 12.7 bbls WAW5206 at.2 bpm while ACF pumped 114.5 bbls seawater at 1.85 bpm, TBG/IA/OA-0/1174/150 - LRS pumped 19 bbls SCW3001 scale inhibitor at .3 bpm while ACF pumped 109 bbls seawater at 1.85 bpm,TBG/IA/OA—0/1365/0 - ACF pumped 1394 bbls seawater overflush at 1.13—1.85 bpm,TBG/IA/OA-528/1835/2 Interval treated: 10811'—14301' ` WNS PROD • CD2-24 • Conoa P1 fillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl 0) MD(ftKB) Act Btm(ftKB) [...._.,ifulkps 501032037700 ALPINE PROD 93.84 14,239.99 14,301.0 ..- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date CD2-24,3/2620159'.43'.20 AM SSSV:WRDP Last WO: 44.16 6/29/2001 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:CTMD 10,840.0 4/18/2010 Rev Reason:RESET WRDP lehallf 3/26/2015 CasingStrings HANGER,333- g Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND).,, Wt/Len(I...Grade Top Thread I I CONDUCTOR Insulated 16 15.062 37 0 114.0 114.0 62.58 H-40 WELDED 42" g. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.835 36.9 2.792.4 2,372.0 40.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 1 I- PRODUCTION 7 6.276 35.2 10,811.4 7,231.9 26.00 L-80 BTC 1 . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread OPEN HOLE 6 1/8 10,810.4 14,301.0 0 0 Tubing Strings '' -tit Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR Insulated 42, , )' F. TUBING 41/2 3.958 33.3 10,030.1 7,047.1 12.60 L-80 IBTM 37 0-114 0 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 33.3 33.3 0.00 HANGER FMC'DUAL PORT'TUBING HANGER 4.500 2,137.0 1,969.1 51.73 NIPPLE CAMCO BAL-0 NIPPLE 3.812 Y, 9,899.1 6,985.7 59.92 NIPPLE HES X NIPPLE 3.813 NIPPLE,2,1370 _ waow,z.137 0' 9,954.3 7,012.7 61.43 PACKER BAKER S-3 PACKER 3.875 10,012.1 7,039.3 63.86 NIPPLE HES XN NIPPLE 3.725 10,028.7 7,046.6 64.56 WLEG BAKER WIRELINE GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inel Top(ftKB) (ftKB) C) Des Com Run Date ID(in) 2,1320 1,969.2 51 73-WRDP 3.813"CAMCO WRDP-2(S/N:HSS-243) 3/25/2016 2-125 k Stimulations&Treatments Min Top Max atm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com SURFACE;37.0-27924-+ 10,811.4 13,685.0 7,231.9 7,218.7 Surfactant Wash 5/10/2002 ARDS Surfactant Treatment 10,811.4' 14,301.0' 7,231.9 Open Hole FRAC 2/26/2005 FRAC STIM w/244,825#12/8 CARBOLITE Mandrel Inserts st GAS LIFT.4,430.7 ati N Top(ND) Valve Latch Port Size TRO Run d Top(ftKB) (ftKB) Make Model Oh (in) Sery Type Type (in) (psi) Run Date Com 1' 4,430.7 3,431.4 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 5/21/2008 2 7,111.2 5,220.0 CAMCO KBG-2 1-GAS LIFT +GLV BK 0.188 1,681.0 5/21/2008 3 9,838.1 6,954.4 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 5/21/2008 Notes:General&Safety End Date Annotation 8/30/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT,7,111.2 4_ GAS LIFT;9,838.1 NIPPLE,9899.1 rtow PACKER,9.954.3 m NIPPLE,10,012.1 WLEG.10,028.7 PRODUCTION;35 2-10,811.4 Surfactant Wash,10,811.4 0 1 t Open Hole FRAC,10,811.4 , I fill t , OPEN HOLE;10.810414,301 0 Imag~l~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. ~-.~ {~) ! - D~' Well History File Identifier RE/~CAN 71TAL DATA OVERSIZED (Scannable) Color items: Diskettes, No. I [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: [] Logs of various kinds [] Other BY: BEVERLY ROBIN VINCENT SHERY~ WINDY DATE:~(~/'/O 5 /S/ ~V~ '~ Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL ~WINDY Scanning Preparation ~)_x 30 = /~ + ' /5 = TOTAL PAGES ._~,.~ Production Scanning Stage 1 PAGE COUNT FROM SCANNED F,LE: .) ~ PAGE COU.T MATC.ES .UMBER ,. SC^..,.G PREP^RAT,O.: ~_ YES BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY OATE:~-)9'~/S!~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: , , YES BY: ~EVERLY ROBIN VINCENT SHERYL MARIA WINDY DA,~-/?-~S/ ~ (SC~NING 18 ~M~ETE AT THIS ~1~ UNLE~ 8PECI~ A~TION IS REQUIRED ~ ~ INDI~DUAL PAGE ~81S DUE TO QUALI~, G~YS~LE OR C~OR IMAGES) NO NO RESCANNEDB¥; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /$/ General Notes or Comments about this file: Quality Checked 12110/02Rev3NOTScanned.wpd • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED D April 01, 2011 F\P,; 4 APP (18 Z011 Misske & Gas Cans. Commission Commissioner Dan Seamount 'AnCtOrbgC Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 0 � , n ©I O Q S Anchorage, AK 99501 ag--oTt Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD2 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD2 -14 50103203900000 2011770 4" n/a 16" n/a 5.4 3/14/2011 CD2 -16 50103204260000 2021440 4" n/a 14" n/a 3.6 3/14/2011 CO2 -17A 50103204060100 2051700 4" n/a 14" n/a 3.6 3/14/2011 CD2 -24 50103203770000 2010950 6" n/a 14" n/a 3.4 3/15/2011 CD2 -25 50103204180000 2020740 4" n/a 14" n/a 3.9 3/28/2011 CD2 -26 50103203970000 2012320 4" n/a 16" n/a 2.7 3/27/2011 CD2 -33B 50103203810200 2011250 4" n/a 15" n/a 2.7 3/27/2011 CD2 -41 50103204240000 2021260 4" n/a 14" n/a 4.3 3/28/2011 CD2 -50 50103204150000 2020490 8" n/a 16" n/a 3.5 3/27/2011 CD2 -51 50103204410000 2022490 510" 0.80 15" 3/21/2007 3.9 3/27/2011 CD2 -56 50103204980000 2041500 SF n/a 15" n/a 3.8 3/27/2011 CD2 -58 50103204570000 2030850 6" n/a 6" n/a 3.5 3/28/2011 CD2 -59 50103205050000 2042480 6" n/a 6" n/a 5 3/27/2011 CD2 -60A 50103205110100 2091150 6" n/a 6" n/a 5.25 3/27/2011 CD2 -74 50103205910000 2081970 10'9" 1.20 9" 3/26/2011 1.7 3/27/2011 CD2 -76 50103206030000 2090980 32" n/a 32" n/a 9.7 3/27/2011 CD2 -78 50103206010000 2090660 6" n/a 6" n/a 1.7 3/27/2011 CD2 -466 50103205760000 2080950 8" n/a 17" n/a 3.4 3/27/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ ~IAF~ 2 3 2009 REPORT OF SUNDRY WELL OPERATIONS~iasica Gi# ~ Gras Ci~ris. Commission t. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate 0 Other ra~~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 201-095 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20377-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 3T CD2-24 - 8. Property Designation: • 10. Field/Pool(s): ADL 387212 & ADL 387207 Colville River Field /Alpine Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 14301' • feet true vertical 7202' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse CONDUCTOR 81' 16" 117' 117' SURFACE 2755' 9.625" 2792' 2372' PRODUCTION 10776' 7" 10811' 7232' Perforation depth: Measured depth: Open hole completion from 10811' - 14301 ~ ~ -~~ ~.' .;: t ~. ~~~~~, ~~~ ~ ~ ,,} jannr± true vertical depth: Tubing (size, grade, and measured depth) 4.5" L-80 @ 10030' MD Packers &SSSV (type & measured depth) Baker S3 Packer @ 9954' Camco SSSV @ 2136' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1200 • 757 85 1030 251 Subsequent to operation 577 459 63 1180 251 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development O Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oi10 Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: N/A Contact Tim Schneider Printed Name Tim chneider Signature .,. ..~ ~ Title Phone Production Engineer 265-6859 Date 3 -- rCj' ~U ~ . ~ / , s` /' ~`~'G Pre are b eanne L. Haas 263-4470 Form 10-404 Revised 04/2006 ¢~ %~ j~~ Submit Original O , ~~~ WSR -Well Service Report • • Well Service Report Page 1 of 1 Well Job Scope CPAI Rep CD2-24 Scale Inhibition Brake, Jared Date Daily Work [Jnit Number 3/I2/2009 44 Initial & Final Pressures: Field: ALPINE 2~ ~"' Summary- Pumped 897 bbl, non-aqueous scale inhibitor squeeze. STARTTIME flP ERATIflN 07:00 PM Start pumping stage 1, of 110yCrude 7.5 BPM 1050 psi. 08:00 PM Pumped stage 2, of 22 bbls of crude w/ WAW-5206 6 bpm. 08:09 PM Pumped stage 3 of 148 bbls of MEG/SCW-3001 WC 5.8 bpm. 08:39 PM Pumped stage 4 of 22 bbls crude w/ WAW-5206 08:48 PM Over displace well w/ 451 bbls of crude. Started pumping @ 5 bpm, w/ 200 away well pressured up to 1650 psi, reduced rate to 1.5 bpm 1300 psi. Fluid Type To `Fell From Well Non- recoverable Tote http://akapps. conocophillips.net/alaskawelleventquery/worklog.aspx?ID=BDD8EE... 3/19/2009 i Cco`Phsllips IpL~°,! ~i4,.i. H"K.. WRDP-2 Min Top Maz Bhn 10,81 ~s~ 629!2001 End Date 6!8!2008 oPEN < HOLE, ~ 10,811 TD ~ (C0444). ~, 3 t 3,136 1 open nae ~` ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 SCANNED APR 2 7 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ;.lO' - oqS Dear Mr. Maunder: Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~.!:~----_/ ConocoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft ç¡al CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-109 6" na 6" na 2.5 2/18/2007 CD2-404 206-054 6" na 6" na 1.8 3/22/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17/2007 CD2-14 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 CD2-28 202-217 29" na 29" na 11 3/8/2007 CD2-30 203-135 8" na 8" na 3 3/8/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 CD2-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 CD2-37 202-211 29" na 29" na 13.8 2/18/2007 CD2-38 202-171 18" na 18" na 8.5 2/18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18/2007 CD2-44 202-165 13" na 13" na 6.2 2/18/2007 CD2-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 CD2-47 201-205 25" na 25" na 11.9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2/18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 13" na 13" na 6 2/18/2007 CD2-57 204-072 8" na 8" na 1 3/8/2007 CD2-58 203-085 6" na 6" na 1 3/8/2007 CD2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . Conoc~illips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 \-Vest 7th Avenue, Suite 100 Anchorage, AK 99501 aÞ \"" 0 qS" Dear Mr. Maunder: 5tìANNEO APR C () î{){)7 .:"'\ J i3t Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by-surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft gal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-109 6" na 6" na 2.5 2/18/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/812007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/812007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/812007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/812007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 CD2-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 CD2-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 CD2-47 201-205 25" na 25" na 11.9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 318/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 e e (~,. "'.\ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker. doc ) ) Mike Mooney . Wells Group Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 March 21, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED MAR.2 9 2005 Alaska Oil & Gas C . , Anchor:;:- ¡; omfi;;~· 8ml, Subject: Report of Sundry Well Operations for CD2-24 (APD # 201-095) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Alpine well CD2-24. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, it jlJ ()1~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad , 'f" 6j,b~~~~íÇi:, þJ)R 1 8 20m1 ~~Jð~~~", ~~\~"\ ,., ~w RECEIVED STATE OF ALASKA MA 6} 9 ALASKA OIL AND GAS CONSERVATION COMMISSION R IJ Z005 REPORT OF SUNDRY WELL OPERA TION~laska Oil & Gas Cons. Commissìo~ Abandon D Repair Well D Plug Perforations D Stimulate 0 Other An@rage Alter Casing 0 Pull Tubing D Perforate New Pool D Waiver D Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 201-095 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20377-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 37' CD2-24 1. Operations Performed: ) ) 8. Property Designation: ADL 387212 & 387207 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION OPEN HOLE Perforation depth: 10. Field/Pool(s): Colville River Field 1 Alpine Oil Pool measured 14301 ' feet true vertical 7202' feet measured 14301 ' feet true vertical 7202' feet Length Size MD 114' 16" 114' 2792' 9-5/8" 2792' 1 0811' 7" 1 0811' 3490' 14301' Plugs (measured) Junk (measured) TVD Burst Collapse 114' 2372' 7231' 7202' Measured depth: open hole completion from 10811'-14301' true vertical depth: 7231'-7202' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10030' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'S3' PACKER 9954' Bal-O SSSV nipple @ 2136' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 10811'-13685' 244,825# of 12/18 carbolite 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 1875 0 2605 0 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Oil-Bbl 2306 3323 Casinq Pressure Tubinq Pressure 356 725 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Contact Printed Name Signature WDSPL D Mike Mooney @ 263-4574 Mike Mooney M· I!/ CðIW) Title Phone Wells Group Team Leader 0 ;nn, ::<ed:' s~!!. ó,?"UP-D,ake 263-4612 t<ðDMS SFi. .', 'oil RBDMS 8Ft MAR ? ~ 7005 Form 10-404 Revised 04/2004 Submit Original Only ) CD2-24 Well Events Summary ) Date Summary 02/20/05 ATTEMPTED TO PULL DHSIT @ 10,012'RKB, JOB IN PROGRESS [Frac-Refrac] 02/21/05 PULLED DHSIT @ 10,012'RKB & ATTEMPTED TO SET XN PLUG @ 10012'RKB, PRE- FRAC IN PROGRESS [Frac-Refrac] 02/22/05 PULLED 1" GLV'S @ 4430',7111', AND 9838'RKB SET 1" DV'S @ 4430' AND 7111'RKB, PUMPED 200 BBLS DIESEL DOWN lA, MADE SEVERAL ATTEMPTS TO SET 1" SPARTEC GAUGE @ 9838'RKB WERE UNSUCCESSFUL DO TO FINES IN TUBING ABOVE MANDREL @ 9672'WLM. 02/24/05 SET 1" SPARTEC GAUGE @ 9838'RKB, PT IA 3500#, SET 3.81" FRAC SLEEVE @ 2033'RKB, WELL READY FOR FRAC [Frac-Refrac] 02/26/05 FRAC ALPINE FORMATION W/12/18 CARBLlTE & DIESEL GEL YFGO-III. IA TO TUBING COMMUNICATED ONE WAY LEAK QUIT AFTER PUMPING AND BLEEDING ON BOTH IA AND TUBING. SUSPECT SPG OR DV LEAKING BY MAY HAVE RESEATED. SCREANED OUT, 379 bbls into the 8PPA STAGE TP = 6471 PSI. TOTAL OF 289469# OF 12/18 CERAMIC PROPPANT PUMPED, 244895# INTO FORMATION 8 PPA Permitto Drill 2010950 MD 14301 --~' TVD DATA SUBMITTAL COMPLIANCE REPORT 7~8~2003 Well Name/No. COLVILLE RIV UNIT CD2-24 Operator CONOCOPHILLIPS ALASKA INC 7202 "~ Completion Dat 6/28/2001 ~ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-103-20377-00-00 UIC N REQUIRED INFORMATION Mud Log N_.~o Sample N_.~o Directional Survey ~ ~//~,q,, DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments Var LIS Verification Var LIS Verification Var LIS Verification Var LIS Verification QC Plot-DSI 2 Directional Survey Directional Survey 10289 ~T~Resistivity 2/5 /~I'D Resistivity 2/5 ~Density Meutron 2/5 c.~T~D Density Neutron 2/5 10345 -~ Den. Neu 2/5 ~D Res. 2/5 Bset Dt 5 10348 DEN / NEU 2/5 .~:~'I'VD 2/5 FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL 2802 2793 2793 2802 2802 2802 2791 2000 2793 9550 9550 9550 9550 2793 10822 10822 2600 2791 0 2791 10822 14299 10054 10822 9856 9856 10054 10050 10054 10054 10054 10054 10054 14299 14257 14257 10050 10054 10054 10054 Open 3/20/2002 ,,f~684 Open 9/28/2001 /.,~3~45 Open 8/15/2001 ,~289 Open 3/20/2002 U.~0683 Open 3/20/2002 c,,r~686 open 3/20/2002 ,~10685 Open 10/2/2001 ~0348 OH 7/30/2001 oh 6/27/2001 oh 6/18/2001 OH 8/21/2001 /~O20289 · OH 8/21/2001 OH 8/21/2001 OH 8/21/2001 OH 8/21/2001 OH 9/28/2001 (~0345 oh 9/28/2001 oh 9/28/2001 CH 9/28/2001 OH 10/4/2001 OH 101412001 OH 10/4/2001 2793-14299 2793-10054 PB1 PB1 2791-10054 2000-10050 Color Print Directional Survey Paper Copy Directional Survey 2793-10054 digital data 9550-10054 BL, Sepia 9550-10054 BL, Sepia 9550-10054 BL, Sepia 9550-10054 BL, Sepia 2793-14299 Digital Data 10822-14257 BL, Sepia 10822-14257 BL, Sepia 2600-10050 Color Print 2791-10054 Digital Data 0-10054 BL, Sepia 2791-10054 BL, Sepia Permit to Drill 2010950 DATA SUBMITTAL COMPLIANCE REPORT 718/2003 Well Name/No. COLVILLE RIV UNIT CD2-24 Operator CONOCOPHILLIPS ALASKA INC APl No. 50-103-20377-00-00 MD 14301 'I'VD 7202 Completion Dat 6/28/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N ~~h-e~ir 10/4/2001 2791-10054 BL, Sepia Sonic 5 FINAL 2791 1 0054 CH , ' Imager Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? ~ N Chips Received? '~ N Analysis Y / N R~.c~.iwd _'? Daily History Received? ~ N Formation Tops ~)/N Kuparuk and Alpine Annular Disposal during the third quarter of 200~ ' ~ ~h(1) h(2) h(3) Total f~r Fr~eze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-32 12701 100 0 12801 379 18636 31816 June 2002 July 2002 CD2-19, CD2-23, CD2-41 CD2-50 31530 100 0 31630 370 0 32000 July 2002 Sept 2002 CD2-41, CD2-19, CD2-16, CD2-38 1C-18 27969 100 0 28069 379 4276 32724 June 2002 July 2002 1C-104 CD2-39 1966 100 0 2066 379 27500 29945 Oct. 2001 Sept 2002 CD2-15, CD2-47, CD2-44 CD2-15 10459 100 0 10559 371 20722 31652 March Sept 2002 CD2-50, CD2-25, CD2-44 2002 CD2-26 13802 100 0 13902 380 0 14282 Sept2002 Sept2002 CD2-38, CD2-44, CD2-29 c'ootc Inter Annutar 19tsposat aurm~; me mira ~,uarter of 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 Hansen #1 52255 100 0 52355 0 14869 67224 January Sept 2002 Hansen gl 2002 Total Volumes into Annuli for which Di~ 9osal Authorization Expired during the third quarter 2002: ~ ~ Freeze P;otect To~al 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 CD2-24 33524 100 0 375 33999 Open, Freeze Protected July 2001 Oct 2001 CD2-33, CD2~39, CD2- 14, CD2-15 1C-26 34160 100 0 0 34260 Open, Freeze Protected August September 1C-123, lC-119, 1C-102 2001 2001 2N-332 31453 100 0 325 31878 Open, Freeze Protected August 2001 Sept 2001 2N-348, 2N-350 1C-16 32017 100 0 0 32117 Open, Freeze Protected Sept 2001 Oct 2001 1C-102, 1C-131, 1C-125 ECEIVED OCT 2 2002 Alaska 0it & Gas Oons. Commission Anchoraoe PHILLIPS AlaSka, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY CD2-24 (0-10o30, 0D:4.50O, ID:3.958) ~ODUCTION (0-1O811, OD:7.0O0, Wt26.00) Gas Lilt ~landrel/Valv~ 2 (7111-7112, 0D:5.984) Gas Lift ~landrelNalv~ 3 (9838-9839, OD:5,984) NIP (9899-9900. OD:5,000) PKR (9954-9955. 0D:5.970) NIP (10012-10013, OD:5.000) GUIDE (10O28-1OO29. OD:5.000) Surfactant Wash (19811-13685) OPEN HOLE (10811-14301, OD:6,125) ALPINE CD2-24 APl SSSV Type: Annular Fluid: Reference Log: Last Tee 501032037700 WRDP Well Type: Orig Completion: Last W/O: Ref Log Date: TD: PROD 6/29/2001 14301 ftKB Angle @ TS: Angle @ TD: Rev Reason: Last Update: deg@ 94 deg@14302 Stimulation, GLV, pull plug, set WRDP by ImO 5/24/2002 Last Tag Date: Max Hole Angle: 94 de9 (~ 14301 ICasing String - ALL STRINGS Description Isize I Top Bo.om I ~vD I wt I Grade] Thread CONDUCTOR ] 16.000 I 0 114 ~ I 62.58 I H-40 l WELDED SURFACE I 9.625 ] 0 2792 ..J._ 2372_ J I 40.oo I L-80 I UTC-MOD PRODUCTION I 7.000 I 0 10811 ]' 7~1 I 26.00 I L-80 ] UTC OPEN HOLE I 6.125 I 10811 14301 ! 14301 I o.oo I o I o ITubing String - TUBING Size I Top Bottom I TVD Wt GradeI Thread 4.500 ] 0 10030 I 7047 12.60 L-80 IBTM Stimulations & Treatments Interval I Date ' I Type I Comment 10811 - 13685 I 5/10/2002 ISurfactant Wash lARDS Surfactant Treatment Gas: Lift Mandrels/Valves stI MD I TVD I Man I Man I'V Mfr I vType I v OD I Latch I Port I TRo I Date I v,v 1 4430 3431 CAMCO KBG-2 GLV 1.0 BK 0.188 1708 7/23/2001 2 71111 522°1CAMC° KBG'2 I I GLV I1.0 I BE 10.188 1171017/23/20011 3198381 69541CAMCOI KBG-2 I I OV I 1.0 I BK 10.2501 0 15/5/20021 Other (plugs, equip., etc.) - JEWELRY Depth lTVD] Type I Description ID 2136 ] 1968 I NIP ]BAL-O SSSV Nipple 3.812 2136 I 1968 I SSSV ]WRDP SSSV reset 5/11/2002 2.250 9899 16985 I NIP ]HES'X'NIPPLE 3.813 9954 ]7013 I PER ]BAKER'S3'PACKER 3.875 10012 ] 7039 ] NIP ]HES 'XN' NIPPLE 3.725 100281 7046 I GUIDE ]BAKERWIRELINEGUIDE 3,875 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. L. Crabtree Phone (907) 265-6842 Fax: (907) 265-6224 June 4, 2002 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations CD2-24 (201-095) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation treatment operations on the Alpine well CD2-24. If there are any questions, please contact me at 265-6842. Sincerely, C. L. Crabtree, P.E. Production Engineer Phillips Alaska, Inc. CRP/skad RECEIVED .IUI'I 'l 2 2002 Alaska Oil & Gas Cons, Gt}mm~ss~m Anchorage ,., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _XX Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1804' FNL, 1533' FEL, Sec. 2, T11N, R4E, UM At top of productive interval 290' FNL, 2181' FWL, Sec. 3, T11N, R4E, UM At effective depth At total depth 2284' FNL, 4828' FEL, Sec. 34, T12N, R4E, UM 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service_ (asp's 371706, 5974552) (asp's 364888, 5976187) (asp 's 363212, 5979502) 6. Datum elevation (DF or KB feet) RKB 37 feet 7. Unit or Property name Colville River Unit 8. Well number CD2-24 9. Permit number / approval number 201-095 / 10. APl number 50-103-20377 11. Field / Pool Alpine Oil Pool 12. Present well condition summary Total depth: measured true vertical 14302 feet 7202 feet Plugs (measured) Effective depth: measured 14302 feet true vertical 7202 feet Junk (measured) Casing Length CONDUCTOR 114' SURFACE 2792' PRODUCTION 10811' OPEN HOLE 3490' OPEN HOLE Perforation depth: measured NOne Size 16" 9-5/8" 7" Cemented 10 cu yds Portland Type 3 379 sx AS III Lite, 235 sx Class G 160 sx Class G Measured Depth 114' 2792' 10811' 14301' True ve~ical Depth 114' 2372' 7231' 7202' RECEIVED true vertical None Tubing (size, grade, and measured depth) 1 .... 4,/z, 12.6#, L-80 Tbg @ 10030' MD. Packers & SSSV (type & measured depth) BAKER 'S3' PACKER @ 9954': MD, BAL-O SSSV @ 2136' MD. JU;,I 1 2 002 Alaska 0JJ & GaS C011S. Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) ::: :::: 1~811::!,:1i3685, Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing :Pressure i: :;:15~0 1: : : 98~ : i i : ::;:;i: :i:;:?: i';i ::;:: ;; : :;: ~:2i:;: 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: Alpine Engineer C. Crabtree Questions? Call Cliff Crabtree 265-6842 Date Prepared by Sharon Al/sup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE CD2-24 Event History Date 3/25/2002 5/5/2OO2 5/6/2002 5/7/2002 5/8/2002 5/9/2OO2 5/1 O/2OO2 5/11/2002 5/13/2002 Summary PULL SCSSSV @ 2136' RKB & SET 3.813 PXN PLUG @ 10012' RKB & PULL 1" OV FROM BOTTOM GLM @ 9838' RKB LEFT POCKET EMPTY. LRS TO CIRCULATE KILL WEIGHT FLUID TOMORROW. PUMPED 350 BBL DIESEL DOWN IA WITH RETURNS UP TUBING, RECOVERED 225 BBL 9.6 PPG BRINE. SET 1/4" OV @ 9838' RKB. DROPPED IA TO 100 PSI W/600 PSI ON TBG, GOOD TEST. PULLED PRONG F/PXN PLUG @ 10012' RKB. ATTEMPT PULL 3.813 PXN PLUG, NO SUCCESS. PLAN TO USE .125" WIRE IN MORNING.E] [GLV] PULLED 3.813 PXXN PLUG FROM 10011' RKB. FOUND DEBRIS IN LOCK FROM DIRTY FLUID CIRCULATED ABOVE PLUG. RIGGED UP ON WELL; CONDUCTED BOP TEST--GOOD. CONTINUED ON NEXT WSR. RIH W/WF BHA (MHA, CENTRALIZER, VIBRATOR, WGT BAR, 2.25" JETSWIRL NOZZLE). ONLY ABLE TO WORK DOWN TO 12,483' CTM (MIDWAY THRU OPENHOLE). POOH AND FOUND CENTRALIZER PACKED W/MUD/ROCKS. RE-CONFIGURED STRING TO MHA, VIBRATOR, STABILIZER, 2.25" JETSWIRL NOZZLE AND SET DOWN AT 12,446'. BEGAN TREATMENT, SUBSEQUENTLY GOT TO 13,685' DURING 1ST 290 BBL STAGE. PUMP 290 BBL OF TREATMENT, SHUT DOWN TO MAKE PLANNED ADJUSTMENT TO SURFACTANT COCKTAIL IN UPRIGHTS. CONT'D ON NEXT WSR.E] [Other Stim] TREATED OPENHOLE SECTION FROM 13,680'- 12,090' WITH ARDS SURFACTANT COCKTAIL AT WHICH POINT BOTH PUMPS BROKE DOWN. TREATED AT 1.25 BPM IN ONE PASS PULLING 2.5 FPM, PLACING ~0.5 BBL/FT, OR 24" RESERVOIR PENETRATION. TOWARD END OF REPORT TIME, BACK ON LINE WITH SURFACTANT. CONT'D ON NEXT WSR.E] [Other Stim] TREATED 12,100' - 10,800' W/710 BBL OF ARDS SURFACTANT IN 1 PASS WHILE PUH AT 2.5 FPM. SIZED FOR 24" PENETRATION. DISPLACED REMAINING TREATMENT FLUIDS FROM WELLBORE W/NEAT DIESEL ON THE WAY OUT, THEN PUMPED ONLY HOLE FILL ONCE IN TBG. WELL S-I TO SOAK. NOTE: LAST RIH TO DISPLACE, WE WERE ABLE TO DRIFT THRU OPENHOLE W/O PUMPNIBRATOR ASSIST; ACTUALLY ABLE TO MAKE IT APPROX. 200' DEEPER THAN PRIOR ATTEMPTS TO 13,860' CTM. E] [Other Stim] SET 3.812 CAMCO WRDP SCSSSV @ 2100' WLM GOOD CLOSURE TEST FLOWED BACK WELL AFTER SURFACTANT TREATMENT. WELL WAS SHUT IN & SOAKING FOR 72 HOURS. FLOWED BACK 790 BBL OF FLUID (EST 30 BBL WATER, 350 BBL DIESEL, 410 BBL CRUDE) AT -3000 BPD. NO EMULSION OR FOAMING SEEN, SAMPLES SHOW GOOD CRUDE WITH SURFACTANT SMELL. TIMING OF WATER ARRIVAL (EARLY) INDICATES IT MAY HAVE BEEN LEFT OVER FROM RECENT WELL SUSPENSION. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Offioe Box 100360 Anohorag~, Alaska 99510-0560 C. Crabtree Phone (~07) 2sfas42 Fax: (907) 2656224 March 24, 2002 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7'~ Avenue, Suite 100 Anchorage, Alaska 99501 Subject: CD2-24 Application for Sundry Approval (APD 201-095) Dear Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to stimulate the Alpine well CD2- 24. If you have any questions regarding this matter, please contact me at 265-6842. Sincerely, C. L. Crabtree, P. E. Alpine Production Engineer CC/skad 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 _XX Other _ Change approved program _ Pull tubing _ Variance _ Perforate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 36.8 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Colville River Unit 4. Location of well at surface 8. Well number 1805' FNL, 1534' FEL, Sec. 2, T11 N, R4E, UM CD2-24 At top of productive interval 9. Permit number/,approval number 290' FNL, 2181' FWL, Sec. 3, T11N, R4E, UM 201-095 ~/ At effective depth 10. APl number 50-103-20377 At total depth 11. Field / Pool 2287' FNL, 452' FWL, Sec. 34, T12N, R4E, UM Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: measured 14301 ~v feet Plugs (measured) true vertical 7202 feet Effective depth: measured 14301 feet Junk (measured) true vertical 7202 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 77' 16" lO cu yds Portland Type 3 114' 114' Surface 2755' 9.625" 379 sx AS IIIL, 235 sx Class G 2792' 2372' Production 10774' 7" 160 sx Class G 10811' 7232' I:ii C I V',,,,, D Description summary of proposal ~ Detailed operations program __ BOP sketch __ 1 3. Attachments 14. Estimated date for commencing operation 15. Status of well classification as: April 30, 2002 16. If proposal was verbally approved Oil _X Gas _ Suspended __ Name of approver Date approved Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Cfiff Crabtree 265-6842 Signed e~,J~ Title: Alpine Engineer Date ~"~'~,~ ~..._, C. Crabtre Prepared by Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witnessII Approval n°' '~C:~ "~'---'" c:~ "' Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- I,~ ~ _ Approved by 0r..d...e.r....0! the commission ~[Nllllly Oechsli Taylo~ Commissioner Date ................................... Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Surfactant Stimulation Well CD 2-24 4/22/02 APl Number: Surface Location: Permit Number: 50-103-20377-00 1806' FNL, 1535' FEL, Sec.2, T11 N, R4E UM 201-095 OBJECTIVE- improve well performance by removing near-wellbore water block. This will be the Ist Surfactant Stimulation in the Alpine reservoir. RU Slickline. Test lines and lubricator. Load the tubing with hot diesel. Drift for wax. Retrieve the SSSV. Drift deeper for wax if needed. Pull the orifice check valve and displace casing to diesel. Tubing Cleanout (If required) 2. RU Dowell coil and Hot Oil truck. . RIH with 3.50" OD jet swirl nozzle with 10' stinger on 1-3/4" CT to 200' MD. Establish circulation at 1-2 BPM. Circulate, wash and jet with hot diesel down the tubing to clean out paraffin to the tubing tail. 4. Make sure the production casing is loaded. Stimulation Treatment Note: Regardless of which mixing recipe below is used, it is essential the treatment mixture be agitated continuously to avoid separation of chemicals!!! 5. Arrange for treatment fluids and tanks onsite. 6. Mix the surfactant cocktail. , MU BHA of (approx 16' not counting nozzle or blaster) 3-1/2" jet swirl nozzle, 5.75" OD Hydraulic centralizer, 2-3/8" dampener, FDR (friction-drag reducer) tool ported for 1-1/2 bpm rates, Rupture disk sub, Hydraulic disconnect, Dual check valves, And MHA. 8. Assemble injector to wellhead and PT. Open well and record tubing and casing pressures. Adjust depth indicator. 9. RIH to the casing shoe while allowing the well to stabilize. 10. Continue into open hole to TD. Circulating diesel as needed. Check string weight every 500'. With tools at PBTD, circulate down a 90 bbl diesel spacer followed by diesel/surfactant treating fluid blend. Expect treating fluid density to be equivalent to diesel, 6.8 ppg. Load the 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. entire open hole with diesel while taking returns at the surface through the coil tubing x tubing annulus. Hold 350-400 psi back pressure on the coil tubing x tubing annulus while taking returns. Begin pumping surfactant-diesel down the coil at 1-1/2 bpm. Taking returns at the surface, load the entire open hole section from the nozzle depth to the casing shoe with treating fluid while holding 300 psi back pressure on the tubing x coil tubing annulus. Do not let the surface treating pressure readings for coil ever exceed 1750 psi (based on a 0.60 psi/ft fracture gradient) plus some reasonable and Iow estimate for diesel friction in the coil at the applicable rate. Once the entire open hole section is loaded, close in the coil x tubing annulus and begin to inject the treatment into the formation while slowly working the coil back and forth through the open hole section from heel to toe. Do not inject with a surface coil pressure above fracture gradient (.60 x 7231 ft TVD) plus some very Iow estimate for coil friction. Record all injection rates and pressures during the job and look for declining pressure trends that would indicate damage removal. Once the entire treating fluid pill exits the nozzle, RIH to the starting nozzle depth and bullhead all the surfactant from the wellbore with diesel as the coil is pulled out of the open hole to the casing shoe. The nozzle retrieval rate should be no faster than what can be pumped. For example at 1.5 BPM pump rate (1.5/.03826=39 FPM). POOH pumping neat diesel slowly to assure the coil does not plug. Leave the well SI to soak for 24 hours minimum. RU Slickline. Reset redressed SSSV. It may be appropriate to perform this step while the well is SI to soak. Flow treatment back to tanks. When ready to flow to plant, go directly to the test separator for the entire flowback period and monitor water production. It would probably be best to drain all plant water vessel levels as Iow as possible to avoid potential water entrainment problems that could drive up BS&W Determine the mixture of fresh water and ARDS 9846 sufficient to break the resulting emulsion with the 10 samples taken during the flowback. Use combinations of different ARDS 9846 concentrations, freshwater, and heat to break the emulsion. Once the appropriate mixture has been determined, sweep the surfactant and brines out of the oil phase and trap them in the water phase for disposal in the Class 1 well. Be prepared to keep the plant loaded with fresh water as needed to combat separator pads or emulsions. Unload the gas lift annulus very slowly to avoid fluid cutting the gas lift mandrels. Test in the plant test separator at line pressure approximately at least 24 hours after the well has cleaned up. Transmittal Form BAKER HUGHES Baker Atlas Canada GEOSciences Centre To State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Phone: (907) 279-1433 Attention' Lisa Weepie Reference: CD2-24Alpine North Slope Alaska Contains the following: 1 - Propagation Resistivity Gamma Ray RWD - Measured Depth Print 1 - Propagation ResiStivity Gamma 'Ray RWD - True Vertical Depth Print ii'.~il:i,~:.iRolled'.Sepia:"of: .. ~.: :'.::. ~..:~'/. -'::pr0pagati0n.Resiistivity ?.'Melasured. Depth :i ':: :: ~,.~:: Pr0Pag~tibn ~esi:S~!Vity: "::.:.: Tme ye~ical,~ Depth :: .': Ray RWD Ray RWD 1 - CD ail: digital..:da~ai :.: .: Sent By: JosefBerg Received ~~~~) Date: Mar 14, 2002 !g ........... ._,~ ,,;' ,, ,, ~.~ z:::~ ..... :?; .......... x..._: .......... ~2.. :.~: ',..: ?._.::. ..... [ ,~ [,5~, ~,,,, i .. ........... ...~ ...................... '. [ .2.. ..... · ...... 2~:.' .....: ......................... :.._ J iZ.. . :': .'..' "1'" ......................... ..... ..... ~ ...... .'...:}~_..~ ........ . ,;'.[[:-2 .... :Y .......... · '?;r -':~ .................. .... ::;~... .::?.. .......... .... .. ~.,. .:.!.. : .. .... -;~}~.:-.--:--. .... . 2'' .., ........,,. .. ...... ' -' .. ',~ 'v .. -1 ...G:2~: 2...5~5:i..-.iE..-5: Date: · ,,. ..;.2~L_: .... '..~,. ~_.2,, '... · ..--.:~ ............... .~_... 2 0 2002 :"'-'" ..... -......_.~: ......................... ~.. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING .._-:.i.'....=::.. ........ :_..:.........-.. OR FAXING YOUR COPY ~askaOi~&OasCons. Com~ FAX: (403) 537-3767 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada .......... T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 Transmittal Form BAKER HUGHES Baker Atlas Canada GEOSciences Centre To State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Phone: (907) 279-1433 Attention: Lisa Weepie Reference: CD2-24PB 1 Alpine North Slope Alaska Contains the following: 1 - Propagation ReSiStivity Gamma Ray RWD - Measured DepthPrint 1 - Propagation Resistivity Gamma Ray P~WD - True Vertical Depth Print :~.::~ :, 1: :~ ~Rolled:: Sepia o f: ~,~ ~r0Pagaticn!.::ResiSti~'i~Y Gmma Ray RWD : '~+ PrOpag.ation~: Resi:.stiyity Ray RWD · ::.; iTme ive~ical DePth :".': : :: i::,'! .~: i 'ROM of all digit l!da~al i'~: .... ::i ... : :: !: : ?i " :' ::: 1 - CD :. :: a ..... :i.:: ,~ .,: i'?i.: .i:i:~,.: ::'~ .... ;'.. Sent By: Josef Berg ReceivedB _~~~ ' !~ - ! Date: Mar 14, 2002 c ....:: ,::~: ::. . ..... [~., ·: : i.....'.~.:~::..~2 .... [;"%1 i.~.....;.~ ...... ~_._: ....... , ~,'~. , ,,.,~ ., ~-- . ... J ........... 7 '.-"~ ...... . : ...... .:...~ ..:..~ :E.zE.i:Z .::_:~:_'=:::::.'.:- : ... .... ....................... ..................................... 'z..' 'Z ...... '-": ........ : ~'' .... .. ,..8. .~> .......... . ................................... [,....."~,.,,, ............... ~, .... ..[. ..:.:2 .......... ;.~.::c. ..... . . ......,. .; . ::i2ii ..... ~ : ..... ':: . .. 2~ ....... .27.:.".' "~ . .' ......... . . .;2 ............. x ........... . Z.Rz':Z:2. ...z-ri:. v.'--::: L'-7-:" .................. ,. :'~::. 2~: :' ':'..":z:'":' :ry"c::: ............. :,, ........ -.'"~ :'.'"' T?'~-' ' ' '..~.'."7 .._:!:~:.' -..__..' ...,.... 2002 ---'..-.-' ...... l.'I, 2 ,._ 0 -i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING "::':'::' OR FAXING YOUR COPY FAX: (403) 537-3767 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 AnYone PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 'Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2001 ,, Dear Commissioner: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2001. Please call me at 265-6830 should you have any questions. Sincerely, R. Thomas Greater Kuparuk Team Leader RT/skad CC' Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Annular Disposal durin ~ 2001: 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 CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 1C-16 12338 100 0 12438 0 19679 32117 Sept 2001 October 1C-131, 1C-125, 1C-102 ~ 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 CD2-14 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 2001 2001 1C-14 22389 100 0 22489 0 0 22489 Oct 2001 Nov 2001 1C-109 2P-438 30331 100 0 30431 212 0 30643 Oct 2001 Dec 2001 2P-420, 2P-415, 2P-429 CD2-15 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only CD2-47 10315 100 0 10415 375 0 10790 Dec 2001 Dec 2001 CD2-34 which ~al Authori. ,ired durin 2001: Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec 2000 2L-317, 2L-307 1D-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1D-42, 1D-34 CD1-31 6698 100 0 392 7190 Open, Freeze Protected Feb 2001 March CDI-14 2001 2N-305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect volumes only 1D-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec 2000 1D-32, 1D-40A 2N-349A 0 0 0 0 0 Open, Freeze Protected ...... 1D-42 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 1D-37, 1D-39 m Record Of Shipment Of Confidential Information District: Alaska To: AOGCC 333 West 7th Avenue, #100 Anchorage, AK 99501 Attn: Steve Davies From: Phillips Alaska, Inc. P. O. Box100360 Anchorage, Alaska 99510-0360 Attn: Jeanne L. Haas (907) 263-4470 ( x ) Enclosed Subject: Quantity 1 ( )Under separate cover ()Via Description CD2-24PB1 Core Chip Description described on 6/11/01 Note - Please verify and acknowledge receipt by signing and returning this transmittal or faxing it, Fax number 265-1515 Signed by Date Jeanne L. Haas 1/21/2002 Received by Date Remarks: ,, PHILLIPS Alaska, Inc. Core Chip Description Operator and Well Name: Phillips Alaska,Inc. CD2-24PB1 Section of 1 I4 Location: Alpine Field CD2 Pad Date January 21,2002 Core #: 1 I Recovered: 95'/cored 99' I Depth Rec. Description Oil Oil Fluor Cut Cut Show ft. in, Stain Od~ % Intensity Color color fluor color sum 9856 3,~,, SS It. brown, mod.sorted, subang.,Lf 100% Mod. 80 Mod. Milky gr.,qtz 75%, dk.gr. Glauc. 10%, qtz. % wh.- Cement 5-10%, firm., mud 10% yel 9859 2" SS It.brown-grey, moder-well std., 100% Strong 100 Mod. Pale subang.,Lf gr, 85%qtz, 5-7% % yel. dk.gr.glauc.,trace mudst-biomixed, cemented ( siderite/qtz?) ~ ?~"'~ 9861 1" SS br-gy, well-mod std, subang, 100% Mod. 95 Mod.- Pale ",~., ::: ....~ minor outsized med.,subr, qtz grains. % Stron yel .... ,~ ~:~. qtz 90%, dk. gr. glauc 3-5%, clay -tr. g 9864 1" SS, Brown,well-mod. std, subang., vf 100% Mod- 95 Mod. Pale gr., firm, qtz 90-95%, trace-3% vf gr Strong % yel. ' :~: ~-~ glauc., trace clay, bioturbated J~,~' ' "~ "'""= 9867 1 1/~" SS, Brown, mod-well std, subang.,Lvf 100% strong 100 Mod. Pale gr.,firm,friable with pressure, Qtz-90%, % yel. tr. Glauc, biomixed mud 10% 9870 1" SS,Brown, well std, subang-subr., Lvf 100% Strong 100 Mod. Yel. gr., Qtz. 95%, tr. Glauc, 4% biomixed % mudst., minor cement, firm 9873 3" Ss, Brown,well std, subang-subr., Lvf 100% Strong 100 Mod. Yel. gr., Qtz. 95%, 1-3% gr. Glauc.,minor % chert-bi,br., biomixed mud 1% 9876 3" SS,brown-It gry, well std., subang- 85% Strong 100 Mod. Yel. subr.,Lvf gr., burrow linings -less % stained(cemented?), Qtz-95%, minor Lyf gr. Glauc., biomixed mud 5% 9879 3" SS, br, well std., subang-subr., Lvf gr., 100% Strong 100 Mod. Yel. % Qtz. 95%, 1-3% gr. Glauc.,Tr. mud 9882 2" SS,br, well std., subang,subr., Lvf gr., 100% Mod- !00 Mod. Yel. Qtz. 95%, 3-55 gr. Glauc., Tr. Biomxed Strong % mud and minor disc., wispy dk. gy lamin's. , Remarks No Chlorethane to test for cut fluor., no grain size card at rig so gr. Size is estimated only Described by Meg Kremer 6/11/01 AR3B-2389-B RECEIVED L U ..:,/, Alaska 0ii & Gas 0ohs. Oommissi0~'~. Ancb0fage PHILLIPS Alaska, Inc. Core Chip Description Operator and Well Name: Phillips Alaska,Inc. CD2-24PB1 Section of 2 14 Location: Alpine Field CD2 Pad Date June 11,2001 Core #: 1 Recovered: 96.8'/cored 99' Depth Rec. Description Oil Oil Fluor Cut Cut Show ft. in. Stain Ob' % Intensity Color color fluor color sum 9885 2" SS brown-gr.,Mod std., Subang- 85% Stong. 80 Mod. Yel. subr., Lyf gr., Qtz. 95%, 1-3% glauc., % w/10% whispy dk gy mudst, burrow linings / laminae 9888 2" SS.brown, well std., subang.-subr.,Lvf 100% Strong 95 Mod. Yel. gr, 95%qtz, 3% gr.glauc.,5% mudst- % biomixed, tr. Carbonaceous debris(?) 9891 1.5" SS br.,well-mod std,subang-subr.,Lvf 100% Strong 95 Mod. Yel. gr., qtz 90%, dk. Gr. Glauc 3%, % bioturbated dk. gy.clay disrupted laminae - 3-5% 9894 1.5" SS & interlamin. Sh., (70/30) 100% Mod- 50 Mod. Yel. It. Brown,well-mod. std, subang-subr.., Strong % Lvf gr., firm, qtz 90%, trace-3% vf gr in ss glauc., 10% cly, Dk gy cly lamin. Bioturbated in ss 9897 1,, SS, Lt. Brown, mod std, subang- 100% strong 100 Mod.- Yel. subr.,Lvf gr.,firm, Qtz-90%, tr. Glauc, % Bright mud matrix 10%, bioturb. 9900 2.5" SS & Mudst interlam. (50-50) 100% Mod.- 30 Mod. Yel, SS,Brown-Lt. Br.,, moder. Strong % Std.,subang-subr., Lvf gr., 90% qtz., 1- 3 % gr. Glauc.,5-7% clay. Br- Gy mudstone is biomixed, disc. 9903 1" Ss, Brown,well std, subang-subr., Lyf 100% Strong 100 Mod. Yel. gr., Qtz. 95%, 1% gr. Glauc.,minor % chert-bl,br.,wh, firm-hard, cemented. 9906 1.5" SS,brown-It gry, well std., subang- 80% Strong 70 Bright Yel. subr.,Lvf gr., Qtz-95%, 1-2% dk. gr. % Glauc., firm with br-gy cly-ey sltst partings, bioturbated 9909 2" SS & Sltst interlam. (50/50) SS br, 80% Strong 30 Mod. Yel. slty.,mod. Std., subang-subr., Lvf % gr.,Qtz. 85%, 1-3% gr. Glauc.,10%slt. Sltst br, firm, sandy,disrupted laminae; burrow lining 9912 1.5" Slty SS 35% br, poor-mod std,, 70% Mod- 35 Mod. Yel. subang-subr., Lyf gr., Qtz. 75%, 15% % sit, 5% cly matrix. Biomixed mud and br. Sltst predom. About 65% of chip. 'Remarks No Chlorethane to test for cut fluor., no grain size card so gr. sizes are approx, only Described by Meg Kremer · 6/11/01 PHILLIPS Alaska, Inc. Core Chip Description Operator and Well Name: · Phillips Alaska,Inc. CD2-24PB1 Section of 3 14 Location: Alpine Field CD2 Pad Date June 11, 2001 Core #: 1 Recovered: 96.8' / cut 99' Alpine C & A ?? Depth Rec. Description Oil Oil Cut Cut Show Fluor ft. in. Stain Oder % Inten Color color fluor sum sity color 9915 1.5" SS br,clyey, mod.std,suba-subr., Lvf 70% Strong 70 Mod. Yel. gr.,Qtz 85%, cly 5%, sit 5%, trace % glauc, carbon. Debris, firm. SLTST is br, clyey, hard, bioturb, whispy. 9918 1.5" Interlaminated SS & Sltst,(50/50)SS 60% strong 60 Mod. Yel. br, poorly std, suba-subr.,Lvf gr, slty. % Pred. Qtz., SLTST br, hard, clyey. 9921 .75" Clyey Sltst. Br, firm, micaceous, minor none faint 10 Mod. Yel. qtz. grains. No P &P % 9924 2" SltySS/Sltst, Br., Mod std, suba-subr., 50% Mod 60 Mod Yel. Qtz 75%, cly 25%, boimixed, micro- % lamin. Sltst Br., clyey, sandy hard. Low P&P 9927 3" Slty SS/Sltst, Br, Firm, Poorly . 45% Mod- 45 Mod. Yel. std,suba-subr.,Lvf gr.,60%ss, faint % 40%sltst, clyey, pred. Qtz.,micro- lamin., bioturb. 9930 2.25" Sltst, sandy, clyey, br, hard, poorly Std.60% Mod. 40 Mod. Yel. 30% Lvf gr ss discont, lamin.,pred. % Qtz. Low P &P 9933 1.5" Sltst/minor ss Br., Coarse sltst, hard, 50% faint 35 Mod Yel. pred. Qtz., clyey. SS br, Lvf gr, slty, % clyey. Qtz rich, biotrubated 9936 3" SS/Sltst Br, Mod-poorly std., suba- 40% Mod. 45 Mod. Yel. subr.,Lvfgr to Crs.slt. Pred. Qtz, % micaceous, clyey. Firm. Br., sandy,clyey sltst. 9939 2.5" SS slty,clyey to Crs Sltst. Br., poor- 50% Faint 30 Mod Yel. mod. Std.,Subang., whispy bedding, % pred. Qtz, micaceous,firm, Low P&P 9942 1" SS (30%) to Coarse Sltst(70%),Br, 60% Faint 50 Mod Yel. firm ,micaceous, Lvf gr., poorly std., % suba.,pred. Qtz. Low P&P Remarks Described by M. Kremer June 11,2001 @ Doyen 19 AR3B-2389-B PHILLIPS Alaska, Inc. Core Chip Description Operator and Well Name: Phillips Alaska,Inc. CD2-24PB1 Section of Location: Alpine Field CD2 Pad Date June 11, 2001 Core #: 1 Recovered: ' 96.8'/cored 99' Depth Rec. Description Oil Oil Fluor Cut Cut Show ft. in, Stain Ccitt % IntensityColor color fluor color sum 9945 3" SS,Br.,Slty, Clyey, poorly std., suba.,Lvf 20% Faint 45% Mod. Yel. gr to Crs. Sit. Pred qtz grains in a to Nil clayey, slty matrix, blot., Low P&P 9948 1.5" Sltst, Crs gr., mod Std., Clyey, firm trace Nil 25% Mod. Yel. Bioturb.some Lyf gr. Qtz component Low P&P 9951 1.5" Sltst/Slty Clyst. Dk br, sli. Fissile, 60% None Nil 0 0 0 cly, 40% fine silt content. LOW P&P Remarks No Chlorethane to get cut fluores., no grain size card so grain size is est. only Described by M. Kremer June 11,2001 @ Doyen 19 AR3B-2359-B 10~02~01 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATI'N: Sherrie NO. 1497 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD2-24 PBI 21321 DSI/DENSITY NEUTRON 06115/01 1 .~1~ CD2-24 PB1 21321 DSl 06115/01 1 1 CD2-24 PBI 21321 PEX DENSITY/NEUTRON 06115101 1 1 C~ CD2-24 PB1 21321 PEX TVD 06115101 1 1 I '%L,_' ,.tl,...I V L, OCT I Alaska G! & Gas Cons. Commi~ion Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. J~fflchol~Je 09/27/01 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1488 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD -,~1~ CD2-33A 21395 Mt 0,CDR,N/D (PDC) 08/13101 1 CD2-33A 21395 CDR RESISTIVITY MD 08/13101 1 1 CD2-33A 21395 CDR RESISTIVITY TVD 08/13/01 I 1 CD2-33A 21395 VISION DIN MD 08/13101 1 1 CD2-33A 21395 VISION DIN TVD 08/13/01 1 1 CD2-39 PB1 21400 N/D & ARC (PDC) 09109101 1 CD2-39 PB1 21400 VISION RESISTIVITY MD 09/09/01 1 1 CD2-39 PB1 21400 VISION RESISTIVITY 'I'VD 09/09/01 1 1 CD2-39 PBI 21400 VISION DIN MD 09/09/01 1 1 CD2-39 PB1 21400 VISION DIN TVD 09/09/01 1 1 CD2-24 PBI 21322 PROCESSED DSl 06/15/01 CI:_IVED Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 09/18/01] Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1457 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD2-24 21335 IMPULSEIADNIGR 06/26/01 CD2-24 21335 MD VISION RES. 06126101 CD2-24 21335 MD VISION DEN/NEUTRON 06/26/01 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-831~7,.,.T. hank ~ ~..!.;~ ;:~ ..~, ~....... '-,' PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 August 22, 2001 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-24 {201-095) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-24. If you have any questions regarding this matter, please contact me at 265-6120 or Scott Reynolds at 265-6253. Sincerely, G. C. Alvord Alpine Drilling Team Leader PAI Drilling GCA/skad RECEIVED AUG 24 2001 Alaska 0il & Gas Co'ns. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification o! Service Well Oil [~] Gas D Suspended [-'] Abandoned r-~ service D 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 201-095 / 3~ Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20377-00/50-103-20377-70 4. Location of well at surface 9. Unit or Lease Name 1805'FNL, 1534'FEL, Sec. 2, T11N, R4E, UM (ASP: 371706,5974552) ~ uu ....... t0N ~ Colville River Unit AtTop Producing Interval ~ ~..~.3~,.~_%// ! 10. Well Number 290' FNL, 2181' FWL, Sec. 3, T11 N, R4E, UM (ASP: 364888, 5976187)t ~-~' [ CD2-24 & CD2-24 PB1 At Total Depth I _._~V~'.~'~ ~:J~ [ 11. Field and Pool 2287' FNL, 452' FWL, Sec. 34, T12N, R4E, UM (ASP: 363212, 5979501) t-~-~~;7,~j Colville River Field 5. Elevation in f~et (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool RKB 36.8' feetI ADL 387212 & 387207 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. NO. of Completions June 2, 2001. June 25, 2001 June 28, 2001 I N/A feet ESL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 14301' MD /7202' TVD 14301' MD /7202' TVD YES [~] No [~]I 2137' feet MD 1637' MD 22. Type Electric or Other Logs Run GR/Res/Neut/Dens 23. CASING, LINER AND CEMENT.lNG RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 40# L-80 '1 Surface 2792' 12.25" 379 sx AS III Lite, 235 sx Class G 7" 26# L-80 Surface 10811' 8.5" 160 sx Class G CD2-24 PB1 cement plug dressed off to 8780' to start CD2-24 sidetrack 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) 4.5" 10030' 9954' open hole completion from 10811' - 14301' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ,, 10054' - 9341' Plug #1:90 bbls 15.8 ppg Class G 9341' - 8734' Plug #2:65 bbls 17 ppg Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Waiting on Facility Hook-up Date of Test .Hours Tested Production lor OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') 24-Hour Rate > 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. See attachment Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE (~ I5 Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. CD2-24 PB1 Top Alpine D 9839' 7195' Top Alpine 9857' 7212' Base Alpine 9919' 7268' CD2-24 Top Alpine D 10490' 7192' Top Alpine 10583' 7208' N/A TD 14301' 7202' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Core Description 32. I hereby certify that the following Is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6253 Signed ~ '~ ~'~ Title AlplneDrillln,qTeamLeader Date ~IZ-;[/OI Chip Alvord INSTRUCTIONS Prepared by Sharon A//sup-Drake 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. Item 28: If no cores taken, indicate "none". Form 10-407 Operations Summary CD2-24 Rpt Date 06/01/01 12:00 AM 06/02/01 12:00 AM 06/03/01 12:00 AM 06/04/01 12:00 AM 06/05/01 12:00 AM Comments Move rig from CD2-42 to CD2-24 Nipple up to 20" diverter, continue to move GIS unit Take on spud mud - Install riser donut & turn buckles - finish general rigging up - Accept Rig @ 00:01 hrs P/U 9 jts. 5" DP from pipe shed & stand back in derrick M/U BHA #1 - bit - motor - xo - lead collar -stab - MWD Perform Diverter test - Witnessing of test waived by Chuck Scheve AOGCC Held Pre-Spud meeting - fill conductor - check for leaks - establish circ RIH to 114' - work through ice plug @ 48' Spud-in Drill 12 1/4" hole f/114' to 2220' MD (2022 TVD), ART 2.0, AST-9.13 Drill f/2220' to2696' Make connection - no returns - Pull & std back 1 std. - Re-establish circ @ 2598' - pump Iow vis/high vis sweep full circ. circ hole clean Drill f/2696' 2802' TD - 2378' TVD - ADT4.5 - AST - .41 Pump sweep & circ hole clean - monitor well Wiper trip to 1090' - RIH to 2707' - safety wash & ream to 2802' Pump sweep & circ hole clean for 9 5/8" csg - Monitor well - pump dry job Pull out to BHA - hole in good shape Handle BHA - sdt back HWDP - change out drilling jars - lay down - stabs - lead collar - MWD - motor & bit - House keeping rig floor Rig to run 9 5/8" csg - Held PJSM - Ran 9 5/8" csg: Float shoe - 2 jts. 9 5/8" 40# L- 80 BTC - Float collar - 65 jts 9 5/8" 40# L-80 BTC - Total 67 jt. Landed on mandrel hanger w/shoe @ 2792' & Float collar @ 2708' L/D fill up tool - M/U cmt head - Break circ. - circ & condition for cmt job Circ and condition for cmt job PJSM - cement 9 5/8" csg - Pumped 40 bbls viscosified water w/nut plug marker - 5 bbls water - test lines to 2500 psi - drop btm plug - pumped 50 bbls 10.5 ppg Arco Spacer- Mixed & pumped 300 bbls 10.7 ppg lead slurry - observerd nut plug mark @ shakers L/D cmt head - landing jt - elevators & long bails Flush flow line & diverter N/D diverter system - install & test wellhead to 1000 psi - N/U BOP Install test equipment - held PJSM on testing BOPE Test BOPE - Pipe rams, blind rams, choke manifold valves, kill and choke line valves, floor valves kelly valves on top drive to 250 psi Iow & 5000 psi high - Hydril to 250 psi Iow - 3500 psi high - accumulator closure test - test gas detectors - wittnessi Pull Test plug & run wear bushing Pick up elevator bails and 5" dp elevators Pick up 5" drill pipe & rack in derrick, 162 jts picked up, 27 stds racked, 27 stds in hole, 48 jts more to pick up. Cont. P/U DP f/pipe shed - 2600' POOH & std back DP in derrick P/U DP f/shed - 1500' POOH & Std back DP in derrick M/U BHA# 2 - Baker AutoTrak PJSM - Surface program tools RIH w/NMDP & HWDP RIH w/BHA # 2 picking up remain 5" DP f/shed to 2663' Cut & slip 60' drill line - service top drive Circ btms up for csg test 'il Operations Summary i'" CD2-24 R/U & test 9 5/8" csg to 2500 psi for 30 mins.- R/D test equip 06/06/01 12:00 AM 06/07/01 12:00 AM 06/08/01 12:00 AM RIH & tag cmt @ 2676' - Drill out cmt - rubber plugs - float collar @ 2708' - drill shoe @ 2792' c/o rat hole to 2802' - Drill 20' new hole to 2822' - AutoTrak tool not pulsing Circ hole clean for LOT R/U & perform F.I.T. to 16.07 ppg EMW - R/D test equip Change well over to 9.6 ppg LSND mud - AutoTrak tool still not functioning Monitor well - pump dry - prep to POOH w/AutoTrak tool POOH to Non mag BHA Stand back non mag DC, test auto trac tool, lay down same Pick Up new Auto Trac system series 2.5, load system data, trip in on BHA to 418' and test system. Trip in hole to 2822' Open & Set Up Autotrac Drill from 2822' to 2952' (2473' TVD), ADT 0.75 hrs. Drill w/Auto Trak assembly from 2952' to 5048' (TVD 3844') Drill from 5048' to 5334' MD (4035 TVD), ADT-1.8 Cycle Auto Trac tool closed, Pump 40 bbl weighted (+2ppg) sweep. # I pump lost piston, lost # 2 pump due to trash in strainer and valve. Finally circulated sweep out with one pump, sweep not effective Pump 2 x 40 bbl hi vis sweeps and circulate til shakers cleaned up. Flow check well, static. Pull 27 stds to shoe, hole condition good, maximum O/P-15-20 K, flow check at shoe Trip back in hole, fill pipe & break circulation at 4190' Wash last stand down, downlink to program Auto Trak, Drill from 5334' to 6925' MD ,5114' TVD. ADT- 11.7 hrs Drill w/Auto Trak from 6925' to 8322' ADT-9.4 hrs 06/09/01 12:00 AM 06/09/01 12:00 AM 06/10/01 12:00 AM Lost 800 psi standpipe pressure, trouble shoot pumps, cleaned suction screen and trash under valve on # 2 pump while circulating hole at 9 bpm/1450 psi w/# I pump Drill w/Auto Trak from 8322' to 8960' (6457' TVD) ADT-7.8 hrs Drill from 8960' to 9856' MD (7211 TVD), core point. ART=9.5 Pumped 40 bbls 12.0 ppg high vis sweep / 300 bbls of mud/40 bbls high vis sweep and circ hole clean, 14.5 bpm @ 3450 psi, final ECD=I 1.2 ppg. Monitor well 15 min, slight flow, continue to circ and balance mud at 9.9 ppg In and out. Monitor well, slight flow lined up to trip tank, gained 1 bbl in 9 min. Intial rate 6.6 bph. Stood back 1st stand to monitor U-tube flow declined to 3.6 bph in 25 min. total pit gain 3.15 bbls. CBU @ 10 bpm, 2350 psi monitored returns throughout no gas cu Downlink to close Auto Trak Tool, blow down choke/kill lines Start trip out for core barrel. Good hole fill, check flow at 10 stds out, static. Pulled to 8650', attempt to work past tight spot at 8650' w/up to 90K O/P Back ream out from 8650' to 8540' Continue trip out conventionally to 3000', flow check at 50 stds out (5094') static Trip out from 3000' to 2762' (inside shoe), flow check & hold PJSM Continue trip out of hole Download and rack Auto Trak Tools Pick up 120' coring assembly Trip in hole to casing shoe Slip & Cut 120' drill line Service top drive Operations Summary CD2-24 06/11/01 12:00 AM 06/12/01 12:00 AM Continue trip in with core barrel to 9796' Circulate, pump hi vis sweep, drop ball & circulate down Cut core from 9856' to 9955' Circulate hi vis sweep Flow check pump out first 2 stds flow check & POOH to 7400'. Flow chk pump dry job. POOH to 3900'. Control trip speeds at 1-1/2 min per std to 6600' then 3 min per std above 6600' POH from 3706' to 1100', control pulling speed to 3 min per stand. POH from 1100' to core barrels, control pulling speed to 6 min per stand. PJSM. LD inner barrels, recovered 95' of core. LD outer core barrels and clear tools from floor. Pull wear bushing and install test plug. Test pipe and blind rams to 250/5000 psi, Annular preventor to 250/3500 psi. Tested mud saver and upper kelly valves to 250/5000 psi. Tested choke manifold and surface safety valves while POH, 250/5000 psi. Pull te MU BHA #5, shallow test tools @ 1076'. RIH to 9600', fill pipe every 2000', no problems. Staged pumps up to 12 bpm / 2470 psi. Attempted to begin MADD pass from 9600', tight hole from 9615' to 9630', slight pack off. Work through tight spot. Log with LWD @ 180 fph from 9600' to 9870', 120 fph from 9870' to 9955'. Drag incresed 30k from 9650' to 9725'. Drill from 9955' to 10010'. ART=0.71 Drill from 10010' to 10054'. TVD 7390' ART= 1.0 Pump high vis sweep, circ and increase mud wt. from 9.9 ppg to 10.1 ppg. Monitor well 10 min, static. Pump out 3 stands and POH to 7868', max overpul115k. Hole fill good, pump dry job. POH to 2648', monitor well, observed slight flow. 06/13/01 12:00 AM Shut in well for 5 min., no pressure build up. Monitored returns to trip tank. Observed steady 1.2 bph rate, shut in well for 15 min, no build up. CBU, had slight oil show and 8.9 ppg gas cut mud. Monitored well, flow continued @ 1.2 bph rate. RIH to 4560', circ and cond mud, observed some 8.6 ppg gas cut mud on bottoms up. RIH to 6464' and CBU, no gas cut mud observed. RIH to 10054', no problems. CBU - no gas cut mud observed. Pumped high vis sweep and balanced mud wt. around to 10.2 ppg. Monitored well had slight flow for 30 min. (1.5 bph) POH to 8840' - monitor well - continued to observe slight flow. RIH to 10054' & begin wt. up to 10.5 ppg. Circ and cond mud, incresed mud wt. to 10.5 ppg, monitor well 15 min - static. Pump out 3 stands and POH to 7930'. Monitor well 10 min, static, pump dry job. Continue to POH, work through tight spot @ 4347', 50k over. POH to 4087', 5 stand hole fill short 1 bbl. Flow check well, observed slight flow. Monitor well 30 min, had constant flow at 1 bph rate. CBU, no gas cut mud in returns. Monitored well 30 min, had constant flow at 1 bph rate. POH to shoe. Shut in well for 1 hour, SIDPP-0, SICP-0. Open well and monitored flow for 1 hour, initial rate 1 bph, final rate < 0.5 bpm. POH to BHA. Stand back hwdp, remove source from LWD, LD and clear tools from floor. Operations Summary CD2-24 06/14/01 12:00 AM PJSM. RU loggers - RIH with Platform Express - unable to pass 9850' (WLM). POH - added hole finder to toolstring for second attempt. RIH with Platform Express, made multiple attempts to pass 9850', unable. POH w/ wireline, RD Schlumberger. MU 8-1/2" clean out assembly and RIH to 2718'. Slip and cut drilling line, service TD. RIH to 5291', CBU, no problems. Monitor well, very slight flow. RIH, set down 20k @ 9850', establish circ and stage pumps up to 10 bpm. 06/15/01 12:00 AM 06/16/01 12:00 AM Work through bridge @ 9850', ream tight spot untill clean. RIH to 10054', pumped High/Low?high vis sweeps and circ hole clean. Monitor well, very slight flow <lbph. POH, top stab pulled 40k over @ 9850', BNHO pulled 75k over @ 9850'. Continue to work tools across tight spot untill clean. RIH to 10054', pump sweeps and circ hole clean. Monitor well, very slight flow. POH, tools pulled slick through problem area. POH to 8300', pump dry job. Continue to POH. Cont. POOH & lay down hole opener Rig up Schlumberger & run wireline logs Pick up mule shoe & 33 jts of 3-1/2 drill pipe for cementing stinger Trip in hole with 3-1/2" stinger on 5" drill pipe to 10054' Pump hi vis sweep and circulate & condition hole for cement plugs. 12 bpm, 1260 psi, 120 rpm, reduce MW to 10.3 ppg Test lines & set 90 bbl. balanced abandonment plug # 1,15.8 ppg, with mule shoe at 10054'. CIP @ 16:30, ETOC @ 9341' POOH to 9341' Circulate & condition at 9341', Dumped 40 bbls of 11.0 ppg cement contaminated mud in returns. Test lines and set 65 bbls balanced sidetrack plug # 2, 17 ppg with mule shoe at 9341'. CIP at 20:15 ETOC @ 8734' POOH to 8739' Circulate out excess cement at 8739'. Cement contaminated mud in returns on bottoms up Flow check - well static - pump dry job and POOH from 8739' to 7787' POH, monitored well @ 5865' and 2723'. Slight flow initially less than 1 bph, steadily decreased. Lay down 33 joints of 3-1/2" drill pipe. 06/17/01 12:00 AM 06/18/01 12:00 AM MU BHA # 7, shallow test Auto Trak tools. Hole completely static while out of hole RIH, no problems, fill pipe every 20 stands, tagged cement @ 8750'. Establish circ and stage pumps up to 13 bpm, 2450 psi clean out cement from 8750' to 8777'. Lost 400 psi pump pressure, checked surface equipment. Circulate & condition mud (a lot of air in mud system) Drill cement from 8777' to 8780' Drill new formation from 8780' to 9140' Circulate with # 1 pump while replacing valve and seat in # 2 pump Drilling from 9140' to 9330' MD (6678 TVD) ADT-7.4 hrs, reducing mud weight to 10.0 ppg. Drill with Auto Trak from 9330' to 10777' MD (7230' TVD) ADT= 18.4 hrs Drill from 10777' to 10822'. ART-1.0 Pumped 40 bbls wt.high vis sweep/40 bbls mud/40 bbls high vis sweep and circ hole clean, 580 gpm / 135 rpm. Monitor well, static. Pump out to 10440', began having slight packoff problems. Operations Summary CD2-24 06/19/01 12:00 AM Troubleshoot and correct electrical problem with shakers. Backream from 10440' to 10182', attempted to pull without reaming, hole conditions not improving, RIH. Pump 12.0 ppg high vis sweep and circ hole clean with 600 gpm / 145 rpm. Pump out to 10370', wipe hole to 8470', 15k-30K over, worked through tight spot from 8601' to 8567' 45K over. Monitor well 10 min, static. RIH to 10757', no problems. Precautionary ream to 10822'. Circulate bottoms up. pump 11.7 ppg weighted hi vis sweep & condition hole for casing. 600 gpm 150 rpm. Circulated a total of 4 x bottoms up. Significant amount of sand across shakers throughout first BU. Flow check static pump out from 10822 to 10376', flow check static POOH conventionally to 7997'. Pump dry job at 7997' and con't POOH to 6099', 75K overpulls at 8150' & 6950'. POH to 2661 ', numerous tight spots from 4785' to 3415', 40k-70k over. Monitor well, static. LD 66 joints of 5" DP, stand back HWDP. LD AutoTrac assembly, clear tools from and clean rig floor. 06/20/01 12:00 AM 06/21/01 12:00 AM MU jet sub and wash BOP stack, pull long bowl protector and install slim protector. RU to run 7" casing, PJSM with crew. Run casing to 2250', no problems. PJSM. Run casing to 2739'. Circ one casing volume @ 8 bpm. Run casing to 5731' Stage pumps up to 8 bpm / 690 psi - CBU+ PUW 210k SOW 130k. Run casing to 8764' - no problems. Stage pumps up to 6 bpm / 680 psi - CBU+ PUW 300k SOW 150k. Run casing - SOW trend changed from 10322' to 10448' - break circ - hole packing off. Work pipe and established partial returns- attempted to gain full returns hole continued to packoff. Continued to run casing to 10570' pumping in hole @ 3-4 bpm returns Continue washing & working 7", 26ppf, L-80 BTC-mod csg to bttm. Land csg at 10811'. Top FC at 10724'. Circ & cond mud/hole for cmtg. (Stage up from 180 gpm to 285 gpm & start losing 40 to 50 bph. Slow to 250 gpm & still losing mud, but less.) R/U to cmt. Cement 7" csg with 160 sx (33 bbls), 15.8ppg, CL "G" cmt with nearly full returns at 6 to 8 bpm. (Lost 8 bbls during cmt job.) Bumped plug. Floats held. Est TOC = 10080' L/O cmtg tools & 7" csg tools. Pull 7" wear ring. Run 7" hanger packoff & test to 5000 psi - ok. Change BOP pipe rams to 4.5" x 7" and 3.5"x 6". Run test plug & test BOPE to PAl specs. (Test rams, BOP valves, floor vlaves, and TD IBOP to 250/5000 psi & annular to 250/3500 psi.) Pull test plug & run wearbushing. R/U handling tools & L/D excess 5" DP from derrick. M/U 6-1/8" Horizontal drlg BHA & RIH. Continue M/U 6-1/8" horizontal drlg BHA & RIH. M/U top drive and test MWD & PDM - ok. Cont RIH picking up 210jts 4", S135, 15.7ppf, XT39 drill pipe. RIH with stands of 4" DP from 7044' to 10119'. Hold PJSM. Slip & cut drlg line. Service top drive. Operations Summary CD2-24 06/22/01 12:00 AM 06/23/01 12:00 AM 06/24/01 12:00 AM 06/25/01 12:00 AM 06/26/01 12:00 AM 06/27/01 12:00 AM Cont RIH to10650'. Wash to 10666'. Circ &cond mud. R/U & test 7" csg to 3500 psi - ok.. (Pressure decreased to 3460 psi in 30 min.) Drill out 7" csg shoe track from 10686' to 10811'. Clean out rathole to 10822'. Drill 6-1/8" hole to 10822' to 10842'. Circ & cond mud for FIT. (10.1 ppg & 40 FV) Perform FIT to 12.5 ppg on 7" csg shoe at 10811' MD/7232' TVD with 910 psi surface pressure. (Pressure slowly decreased to 850 psi in 10 min.) Hold PJSM. Displace 10.1 ppg LSND mud in hole with 9.2 ppg FIo-Pro mud. Clean surface system. Hold pre- reservoir drlg mtg. Drill & survey 6-1/8" horizontal hole from 10842' to 10897'. Drill & survey 6-1/8" horizontal hole from 10897' to 11241' (7233' TVD). (6.8 ADT; 2.8 ART; 4.0 AST) Drill & survey 6-1/8" horizontal hole from 11241' to 11748' (7229' TVD). (6.5 ADT; 6.0 ART; 0.5 AST) Drill 6-1/8" horizontal hole from 11,748' to 12,222'. (5.3 ART; 1.6 AST; 6.9 ADT) (Pipe became stuck after sliding 6'. Work pipe free. Rack back 1 stand DP to 12,194'.) Circ & cond mud/hole. (Rotate pipe at 125 rpm & slowly reciprocate. Circ 4 B/U at 273 gpm. Pump Iow visc/high visc/Iow visc sweep. ECD from downhole APS decreased from 11.28 ppg to 10.7 ppg, prior to going back to drill.) Drill 6-1/8" horizontal hole from 12,222' to 12,680' (7,216' TVD). (5.3 ART; 0.8 AST; 6.1 ADT) Drill & survey 6-1/8" horizontal hole from 12,680' to 13,244' (7,214' TVD). (8.1 ADT; ART. 6.5; AST 1.6) Drill & survey 6-1/8" horizontal hole from 13,244' to 13,800' (7,220' TVD). (7.8 ADT; ART 6.5; AST 1.3) Drill f/13800' t/13816'. ECD Climbing to 11.58 ppg. LSRV @ 16.8. Circulate and condition mud to knock Down ECD's. Pump Low-Hi-Low vis sweeps. Add 125 bbl new FIo-pro for dilution. Reciprocate slow and rotate 130 RPM. ECD dropped to 11.32 ppg. Drill f/13816' t/14103'. TVD-7216' ART=3.3 hrs; AST=1.5 hrs; ADT=4.8 hrs. Drill f/14103' t/14301'. ART=5.2 hrs; AST=0 hrs; ADT=5.2 hrs. Circulate and condition mud and hole. Pumped Iow-hi-low vis sweep at end of 3rd BU. Reciprocate slow and rotate 130 RPM. ECD bouncing back and forth from 11.3 ppg to 11.5 ppg. Continue circulating to clean hole. PJSM on brine displacement. Clean mud pits and kill line with brine. MU & pump 40 bbl Hi-vis spacer. Follow with 9.2 ppg brine. Monitor well. Initial loss rate=40 bph. Final loss rate = 24 bph. POOH to 7" casing shoe @ 10800' MD. Monitor well. Static loss rate--16 bph. Pump dry job. POOH laying down 4" DP to shed. Loss rate while tripping estimated @ 15 bph. Flush BHA w/40 bbls water & 10 gal concour erosion inhibitor. LD HWTDP; Jars; NMDP; remove source; LD MWD/LWD & mud motor. RIH w/53 stds of 4" DP f/derrick. LD same to pipe shead. Loss rate 12 bph. Continue pull out & lay down excess drill pipe Remove pipe spinner - move 22 stds drill pipe to off drill side in derrick Pull wear bushing - rig up to run completion - Held PJSM "i' Operations Summary CD2-24 M/U & run tail pipe wi WLEG - 2 - 4 1/2" pup jts - XN nipple wi RHC plug w/guages attached - 1 jt 4 1/2" tbg - Baker S-3 packer assembly - 1 jt 4 1/2" tbg - XN nipple - 1 jt. 4 1/2" tbg - GLM #1 w/shear valve - run 176 jts 4 1/2" tbg & GLM as per program Rig up Camco equip - attached control lines to SSSV. P/U tbg hanger & landing jt. Attach control line to hanger & test to 5000 psi Land tbg hanger - RILD - test seals to 500 psi - remove Landing jt. A - set two way check - M/U landing jt. B - test metal to metal seals to 5000 psi - L/D landing jt B 06/28/01 12:00 AM Change top pipe rams to 4 1/2" x 7" - change junk sub in top drive - N/D BOPE - flow line - tunrbuckles - bell nipple - N/U tbg head adaptor & tree - test to 5000 psi R/U lubricator & pull two way check - drop packer setting rod & ball R/U steel line to tbg & annulus & floor manifold Complete rigging up lines and manifold - PJSM Test lines to 3600 psi - Pressure up on tubing to set packer and test to 3500 psi for 30 mins. - bleed tbg to 2500 psi - test 4 1/2" x 7" annulus to 3500 psi for 30 mins. - bleed down tbg to shear out DCK-2 shear valve - observed shear @ 1300 psi on tbg Circ 30 bbls 9.6 brine followed by 130 bbls 9.6 ppg inhibited brine - followed by 192 bbls diesel for freeze protection through shear vavle - Observed hgiher than normal pressures while circulating fluids had to cut rate, Clear line w/hydrocarb truck - rig down line and manifold Install BPV - secure well Finish injecting return brine and cleaning pits - break out injection line - Release Rig @ 1300 hrs 6/28/2001 - Move to CD2-33 BAKER I CORING SUMMARY NOTES I INTEQ Core #1: I WE PICKED UP A 120' ASSEMBLY WITH AN ARC425C3 COREBIT ON THE BOTTOM. THE TEMPERATURE DIFFERENCE WAS 64 DEGREES. THE LEAD WAS ADJUSTED TO 1" OFF THE BIT. THE ASSEMBLY WAS RUN IN THE HOLE. THE HOLE WAS lIN GOOD CONDITION AT 24 DEGREES INCLINATION. BOTTOM WAS FOUND AND THE MUD CIRCULATED TO REMOVE TRIP GAS AND TUNE UP THE MUD SYSTEM. THE BALL WAS DROPPED, AND A 330 PSi INCREASE WAS OBSERVED FIFTEEN MINUTES LATER. NUMBERS WERE RECORDED AND THE CUT WAS STARTED. THE CORE TOOK RIGHT OFF AND THE HOLE IWAS ADVANCED TO 9955' WITH THE CORE BARREL, MAKING ONE CONNECTION AT 9949'. THE RUN WAS CALLED SHORT AT THE GEOLOGISTS REQUEST, AS THE FORMATION PLAYED OUT. A BOTTOMS UP WAS CIRCULATED AND THE STRING WAS HOISTED. RECOVERY WENT WELL AND THE BARREL WAS LAID OUT. INOTES: THE GEOLOGIST WAS TRYING TO GET A 6' SHALE TRANSITION PRIOR TO BREAKING INTO TO SAND. THE CORE RUN STARTED ALMOST IMMEDIATELY IN THE SAND WITH VIRTUALLY NO SHALE CAP. THE TRANSITION AT THE END WAS IRECOVERED AND THE ONSITE GEOLOGIST WAS PLEASED WITH THE QUANTITY (THE MISSING THREE FEET OF CORE . WAS PROBABLY LEFT ON BOTTOM. BUT MEG KREMER HAD ENOUGH OF THE TRANSITION FOR TESTING, AS WELL AS ALL OF THE SAND SECTION). THERE IS A POSSIBILITY OF CUTTING MORE CORE ON THIS PAD. THE TOOLS ARE EXPECTED I TO REMAIN ON LOCATION AS A RESULT. THE BARREL WAS WELL RINSED BUT NO BEARING SERVICE WAS PERFORMED, AS WELL THE LEAD IS PRESET AT 1" FOR A SIXTY-FOUR DEGREE TEMPERATURE DIFFERENTIAL. :INTEQiREPRESENTATIVE:' :IFRED ANTONSEN I MIKE TILTGEN d ~~ ( ( IJ°bN°' I 154857 BAKER I~1~ J Core Job Summar~ J INTEQ Customer. Phillips Alaska Hole Size: 8 112" Date On: 08-Jun-01 i Well: CD #2-24 Hole Angle: 24 De~l. Date Off: 1 l-Jun-01 Rig: DOYEN #19 Last Cs~l Size: 9 5/8" Pmp/Lnm: 12" x 6" Engineer:. Fred Antonsen / Mike Tiltgen Csg Shoe Depth: 2752' Mud Type: LSND Run Depth(ff.) Depth(ff.) Size Inner Tub~ Catcher Length Cut Recover Recovery Hours ReP No. From To Type Type (feet) Ft/Hr 1 9856 9955 6 3/4" X 4" X 120'Aluminum Low Inv. Sprin~ 120 99 96 97% 2.66 37.22 I1~'" :: ': L :' "' ' CuMULATIvE PERJ=oRMANCE : ; ' ': '; :~ ~""~'~'.r :~ 99 96 97% 2.66 37.22 J .:COreheadUsage:. ::: : I i , . . , . ' Corel, SERIAL NO.. SIZE.,, ' :,..,,' TYPE'; ': ,.TFA FEET HOURS ROp:r': ": i "': .': :CUT Ft/Hr BefOre,. '.After. .Run 1 1902201 8 1/2" X 4" ARC425C3 0.75 99 2.66 37.22 1% 2% UKER CO ,- IINTEQ BARREL ASSEMBLY #1 2 2'59'L-~ -24 2.32~-~ Complete Coring ~b-'~urley / John Cole 3.75:-~ BHA Length ]Fred Antonsen / Mike Tiltgen 4' ~ 134.06' I I B H I Core Barrel HT30 120' Feet 18 K. Ibs 325 Parameters KftLbs. K. Ibs' K. Ibs! r.p.m., g.p.m. Coreheads on Location 'Se~ No. 1902201 1902200 Cond. USED NEW Comments: Hughes Christensen ARC425C3 S/N 190220t, .6' TFA .77 26'--~ 26'--~ 26'--~ 26'--~ FLOAT SUB TOP SUB LD ADJUST SUB STABILIZER 8 15/32" OUTER BARREL 6 3/4' O.D. X 5 3/8' I.D. STABILIZER 8 15/32' OUTER BARREL 6 3/4" O.D. X 5 3/8" I.D. STABILIZER 8 15/32" OUTER BARREL 6 3/4" O.D. X 5 3/8" I.D. STABILIZER 8 15/32" OUTER BARREL 6 3/4" O.D. X 5 3/8" I.D. STABILIZER 8 15/32" ARC425C3 I ~. - ,,.,.,°,.# I BAKEI~ BAKER HUGHES INTEQ co... HU(GHES BOTTOM HOLE ASSEMBLY B,A No: INTEQ [~=: o~u~o~ I PHILLIPS Al~$1~ cm-~ DO¥O~ #~ N_m~£ ~OR'rH St.O~=, N{ USA " Illin Bit # 81ze MiT. TYPE Serial No. TFA Gauge L Depth in Depth out Bit Length(It) t 5 8 1/2 HC ^RC425C3 1902201 .77 0.4 9,856 9,955 1.4 ~ Mint1 ' CmTtPmmnt Down Up Mfr. Serial No. Gauge OD Body OD Body ID Fish Neck Length(It) Total Length(It) I STABILIZER HT30 PIN HT30 BOX BHI 8 15/32" 6 3/4" 5 3/8" 2.36 4.00 5.4 , m I OUTER TUBE HT30 PiN HT30 BOX BHI 2004 6 3/4" 5 3/8" 26.00 31.4 ~ 4 ~ STABILIZER HT30 P~N HT30 BOX BH~ 8 15/32" 6 3/4" 5 3/8" 2.37 4.00 35.4 I 'OUTER TUBE HT30 PIN HT30 BOX BHI 2004 6 3/4" 5 3/8" 26.00 61.4 ~ ' t STABILIZER HT30 P~N HT30 BOX BHi 8 15/32" 6 3/4" 5 3/8" 2.39 4.00 65.4 !~ ~'.. 7OUTER TUBE HT30 PIN HT30 BOX BH~ 2004 6 3/4" 5 3/8" 28.00 9t.4 · I STABILIZER HT30 PIN HT30 BOX BHI 8 15/32" 6 3/4" 5 3/8" 2.37 4.00 95.4 lB ' · S OUTER TUBE HT30 PIN HT30 BOX BHI 2004 6 3/4" 5 3/8" 26.00 121,4 I i'. t0STABILIZER HT30 PIN HT30 BOX BHI 8 15/32" 6 3/4" 5 3/8" 2.37 4.00 125.4 _ ~::ii :t~I, LD. EXT. SUB HT30 P~N HT30 BOX BH~ 6 3/4" 5 3/8" 3.75 129.15 ~ '~.'. i]_~' TOP SUB HT30 PIN 4.5 IF BHI 6 3/4" 5 3/8" 2.32 131.47 ~" i' FLOAT SUB 4.5 IF 4.5 IF BHI EW15243 6 1/4" 2 3/4" 2.59 134.06 .,,, · ·,'14' HWDP(3) 4.5 ~F 4.5 ~F R~6 5" 3" 89.48 223.54 ~ ~;.'. l!JARS 4.5 IF 4.5 ~F DLY ~8210086 6 4/4" 2.25" 33.27 256.81 ' .~__. !ei~. HWDP(2$) 4.5 ~F 4.5 ~F R~G 5" 3" 783.06 1039.87 m ', t7' ~ Di~m~'~i -17.56 PR£¥1OUSBHA 1057.43 BFi&l-en~th':: ~ :';':'"'~i","' : STABILIZER 8 15/32" RWM 1.00 2.25" 0.80 X ._ ~', 41- STABILIZER 8 15132" RWM 1.00 2.25" 0.80 X ~ 'i',.',.'i"','~' i". sTABILIZER 8 15/32" RWM 1.00 2.25" 0.80 X '~ ,i;,.i, .,~'~: :,.!' ~'~; STABILIZER 8 15/32" RWM 1.00 2.25" 0.80 X . i!'i:'t0 STABILIZER 8 15/32" RWM 1.00 2.25" 0.80 X ~.,,.,:.:. ,,,,r ,:, '.. +Ot.,:'."~'",: _ ~CT~ ~Or ru..i.; B~i''; ,." ICUT 120' O~ CO.E ~11BItA"RESULTS:' ';: ICut'99'of Core, Recovered 96'of Core Baker Hughes:lNTEQ, R_~epr_.eSentative:,: Fred Antonsen / Mike Tiltgen ! .~-~so. ~ mo.: · ~i~ I SalesO~er No:.,,I ~4~s7 BAKER i' CORE RUN LOG ~' INTEQ [CORE #:. COMPANY PHILLIPS ALASKA DEPTH IN(FT.): 9856 FORMATION' D SHALE/C SAND RIG: DOYON # 19 DEPTH OUT(FT.;): 9955 DESCRIPTION: SAND/SILTSTONE WELL No.' CD #2-24 HOLE SIZE: 8 1/2" FTG: THIS RUN: 99 DATE: 11-Jun-01 HOLE ANGLE: 24 DEG PREV. FOOTAGE: 0ITOTAL-IFTI 99 EQUIPMENT ~RREL SI~F_: 6 3~4" X 4" COREHEAD/BIT# ' ARC425C3 SURF ~ ~-MP 70 LENGTH (fi): 120 SERIAL No, ' 1902201 DH TEMP. 134 INNER' TUBE TYPE: ALUMINUM :SIZE:. :,., ~ ,~. 8 1/2" X 4" SPACING 1" L.$HOE/CATCHER: LOW INV. SPRING DAFD TOOL:.~: NO CORE JAM, INDICATOR: INNER :I'UBE ~TABILIZEE,' IYES BIT END'BEARING:' N~-~- COREHEAD CONDITION: IR oR DC LOC" ' BlS G/16 DC R P! , o 0 NO A X ~ NO , 0 0 NO A X ~ NO ROP I BIT CONDITION AT RUN START: ;' 1% WORN BIT CONDITION AT 'RUN END.'.: ,'~:'] 2% WORN , ii ,,,,, .~c~,.ou.~,,.~,=~,..s. -:,':. = ' '~:/ ING::WTS":'' !i BALL VALVE; PRESS INC, PRESSURE,:.BALLSEATED~ : UP (Klbs) 320 'OFF BOTTOM] 18 FLOWRATE I 288 I GPM; FLOW RATE 326 GPM ROTATING (Klbs) 225 iON BOTTOM I 19-21 PRESSURE INC. I 330 I PSI OFF BOTTOM 1260 ~SI' :i :::i::..' .' ' '" : °N aO'rl'0M!,';: ~300 , . i :: ; ' MuD:PROpERTIES '1 :' LSND 45 9.7 14 23 9/10/11 13 Trace 7.5 TIMINGs:::. :i!,I:' ::::.: '. ':.: :' :' i.'~: i: :~ :' ;" ':::.~ 'i: :: :::' ::; :: :~': ,.::i:' ~ ~' :: (' 24 :i:~H O UR).:: :'?i:: .::i::':'i:.: ,~.::: :~ :: i i :.': i::~ i:~ ': :?:ii!!il i::~ :i:i~i'; iiil !:i~:!~ii?:: i~: :i.i i' ::: .: iDAY O F ~ S TART :. ~::: !~: ::. :::: ::' i :: :':~:::: :"::': :.r:: i ::: ':' ?. i: ::~ :: '::: '::::: ::::i':: ;...::: i:' !i;: :. :::~ ;::': ?..?i :' 'i :,. LAY DOWN '..' ...~. :. ': '.....'.'.. " .'..' ... ..... eeL.'. ' ':::HOLE/'. '""".':'.:':' ;..:" ':..:,BACL.".':" ' CONNS. SERVICE eeL ... S'rD ec'~:' eeL .. ..' I' ~T~*i'" '.'...:'.... 3:00 5:00 13:45 14:30 19:00 03:30 ~::: :: =:~: :,,~,,~,,,: ,',::,, ·: I 14:05, 17:30 3:30 05:30 "' ,;:':,,:','~ ::=:': ,~ :::, ~ :~,::= 5:00 12:00 , : : ~.~..,........~.~:.~°" o.~.:................., .....o,~o...,:.1, , . '/i''''''''''~'-'' ~0~..~,on:~..i.........~...~ ..... .I ' ~''' '~'~':"""'~"""t:':'."'" "~:~ '".'""'.r """"'"' !" '~ t '~ '""'"!.~':' ' ''''' .... ..... , . .... I : ' ' :'i~;!~i,::,, ::,: :::Dem~O~: :::/Feet'C~?' ':ii;: ::'!C~'~ng ~:: :':';'?):ii'!!::::i' :,":: ROP,FT/HR :: :;~:, ~, ::: :..:: '~::.::.':: ..:.::: ::::...:.:..,:.. :.: :..:.. :..::: '?/:...:.:.-:.~.'.' ..:..:.::-:::...i.iH.oU:~:..i:;:::.:..:::;..:i.i:~ :.: .......:., . :.': ........ ........;.. - · :. , · ':. ,.... · . ..: · . _ 9856 9955 99:, :.~: 37.22 96 97% EFFICIENCY:I 80% IREAS'ON';FOR.'STOPPING,CORING: :IROP - OUT OF FORMATION .-. ~ .- , , , :: = ~PA ' 'P TSUSED:':' ";:: r::::,;:: :'!4 ALUMINUM:INNER BARRELS :' 4 I NNER::BBL STABS , IEA: SPRING :CORE CATCHER IEA LOW'INV SHOE::' I EAUPPER:SHOE CustOrmer :Representative: :,': :::'~,~: ':?,:lOave Burley I John Dole IBH:INTEQ,:Repi!: : :,:::= .., IFred, Antonsen/Mike Tiltgen ! I NTEQ ·HI ~ #: ---, COMPANY: Phillips Alaska :CORE EIARRE1. ~7;::: 6 3/4" x 4" x t20' DATE lO. Jun-01 CO~E ~ RIG No. ' - Do, on ~9 CORE INTERVAL : 9~56-.99~ 99' REC.% : 97% u~o ~r~_,~n , , DEPTH NO. R.O.P PENETRATION RATE, FT/HR. OPERATING CONDfTIONS FORMATION FT. CORED. Min/Ft Ftfl-lrs W.O.B R.P.M F. RATE PRESS. TORQUE TYPE K. Lbs GPM Psi KLBS ,, 9857 1 13.00 4.6 ~ a · I't--I-I- 4 50 325 1200 20-21 ALPINE ~1 ~ 1.oo ~o.o a a· Bm l II ~ ~ 32~ 1~0 1.21 ALPINE ~2 ~ 1.oo ~o.o / al la l Il ..... ~ 50 32~ 1= 1.21 ALPINE ~,~ 12 1.oo ~0.0 ~ 21~=~= III , 60 325 1200 1,21 ALPINE __ 9869 13 1.00 60.0 ~ a· 7 60 325 1200 1'21 ALPINE 98,0 1, 2.00 ~o.o / II , 60 .325 1.200 19-21 ALPINE 9871 15 1.oo 60.0 ~ mi a· ..... 5 75 325 120o 1,21 ALPINE __ 9872 16 1.00 60.0 / II II 5 75 325 1200 19-21 ALPINE __ 9873 17 1.00 60.0 I II II · 5 75 325 1200 1'21 ALPINE _ 987,~ 18 2.00 ~o.o / II I1~-- 5 75 325 1200 1'21 'ALPINE 9875 19 1.00 60.0 I II IIIII 5 75 325 1200 1,21 ALPINE 9876 20 1.00 60.0 / II IIIII 5 75 325 1200 1,21 ALPINE 987-~ 21 1.oo 60.0 / II IIIII 5 75 325 1200 1'21 ALPINE __ 9878 22 1.00 60.0 I II IIIIi 5 75 325 1200 1'21 ALPINE 9879 23 1.00 60.0 mm· la· ,i 5 75 325 12001'21 ALPINE .... ~ 24 ZOO 30.0 IIIi~a~-' 5 75 325 1200 19-21 ALPINE ~ 27 1.oo 60.0 lll I I liii 5 75 325 ,1.200 1'21 ALPINE _ ~ 28 0.50120.0 /I I1 1 IIII 5 75 325 12001,21 ALPINE ~ 29 0.50 120.0 II· I IIII 5 75 325 '1200 1'21 ALPINE __ -- 30 1.00 60.0 /11 I lllll 5 75 325 12001'21 ALPINE __9887 31 ~.oo~0.0 /I · I · ·ii 5 75 325 1'200 1'21 ALPINE ~ 32 1.00 60.0 la · ~ · ·1 1 5 75 325 12001,21 ALPINE -- 9889 33 2'00 30'0 la· i!---- 5 75 325 1200 19-21 ALPINE ~0 ~ 2.00 ~0.0 II · 5 75 325 1200 1'21 ALPINE __ 9891 35 2.00 30.0 /I · 5 75 325 1200 19-21 ALPINE 98; 30 1.oo 60.0 II I IIII I 5 75 325 1200 1'21 ALPINE 9893 37 2.00 30.0 ~a · la '- - 5 75 . 325 1200 1'21 ALPINE. __ 9894 30 1.00 60.0 la· lllll 5 75 325 1200 1'21 ALPINE 9895 39 1.00 60.0 "a·I lll"l 575 325 1200 1,21 ALPINE 9896 40 1.00 60.0 ~ I 5 75 325 1200 19-21 ALPINE ' _ 9898 .2 1.oo 00.0 .11 II111 5 75 ,325 1200 1.21 ALPINE _ ~ ,,3 1.00 60.o Ill Iliii 5 75 325 12001,21 ALPINE ~00 ,, 1.oo 60.0 Ill Il I II , 5 75 325 120019-21 ALPINE _ ~01 '.5 1.00 00.0 III II I II 5 75 :325 12001'21 ALPINE _ ~2 ,~ 3.00 20.0 III I - -- 5 75 325 1200 1,21 ALPINE _ 9903 47 2.00 30.0 / II II ------ ...5 75 325 1200 1'21 ,ALPINE _ ~ ~ 2.00 ~o.o / II II --~- 5 75 325 1200 19-21 .ALPINE _ 9905 49 2.00 30.0 / a · I a '- -- - 5 75 325 1200 1'21 .ALPINE _ ~98 50 2.00 30.0 ~ a· la~--- 5 75 325 12001,21 ,ALPINE ~o7 51 1.oo 60.0 / IlI· Ill 5 75 325 12001,21 ALPINE ~98 52 1.00 60.0 / II IIIII 5 75 325 1200 1,21 _~LPINE ~ ~ 2.00 30.0 / II II--- 5 75 325 12001,21 ALPINE 981o .~ 1.oo 60.0 /11 lllll 5 75 325 12001,21 _A..LPINE ,11 ~ 1.oo 00.0 /"1 l"Illl 5 75 325 12001,21 ALPINE ~12 .~ 1.00 00.0 IIIIi IIII 5 75 325 12001,21 ALPINE ,1~ 57 1.oo 60.0 III !! IIII 5 75 325 12001,21 ,ALPi,E _ ~14 ~ .1.0000.0 /I II I III I 5 75 325 12001,21 ALPINE __ _ ~15 59 ~:00 60.0 /I I II · II I 5 75 325 12001,21 ALPINE 9916 60 1.00 60.0 III "lll=l 5 75 325 1200 1'21 ALPINE ~1~ ~1 1.00 60.0 II · ' 5 75 325 1200 1,21 ALPINE Total 'l~me 94 Minutes ..... m m m INTEQ BI-ti JQB #: C:OMPAbtY: Phillips Alaska CORJE ~ ~: G 3/,4" x 4' x 120' DATE 10-Jun-.01 c:~E ~ WELLNo.: CD2-24 BIT SIZE & TYPE : 81/2"X4" ARC4 ,25~3 ICORENo: I Page2 FredAmor~en R~ NO. ' DO~O~ ~E19 CO~E INTERVAL .' 98~ 99' REC.% .' 9~ Mike T'd~gen DEPTH NO. R.O.P PENETRATION RATE, FT/HFL OPERAllNG CONDmONS FORMATION FT. CORED. Min/Ft Ft/Hrs W.O.B R.P.M F. RATE PRESS. T~E TYPE , K. Lbs GPM Psi KLBS 9917 5 75 325 1200 19-20 ALPINE ~2~ ~ 4.oo ~o.o Ill I II I s ?5 325 1200 19-20 ALPINE .s. ,.~ ~.o mmmm ~ 5 75 325 1~19ALPINE mi(mi Phillips Petroleum Co. CD2-24 Colville River Unit CL File No. · 57111 - 01134 CORE ANALYSIS RESULTS 1 9856.3 0.005 0.004 3.2 27.6 54.4 82.0 0.51 2.92 2 9857.3 0.307 0.009 16.3 37.8 37.4 75.2 1.01 2.70 3 9858.0 2.82 1.52 19.4 41.4 26.3 67.7 1.57 2.69 4 9859.3 0.759 0.403 17.6 35.1 31.8 66.9 1.10 2.67 5 9860.3 0.822 0.382 16.6 46.1 30.2 76.3 1.53 2.67 6 9861.3 5.44 6.68 20.6 51.5 20.2 71.7 2.55 2.66 7 9862.3 1.38 2.10 17.1 45.6 25.5 71.1 1.79 2.67 8 9863.3 2.84 1.27 18.7 49.0 20.3 69.3 2.41 2.66 9 9864.3 2.72 1.30 18.4 47.8 20.6 68.4 2.32 2.67 10 9865.3 4.22 2.88 19.0 47.0 18.1 65.1 2.60 2.66 11 9866.3 2.47 1.68 18.6 52.9 15.2 68.1 3.48 2.66 12 9867.3 4.06 1.19 19.4 48.8 16.6 65.4 2.94 2.66 13 9868.3 2.86 5.27 17.7 49.0 20.8 69.8 2.36 2.67 14 9869.3 5.74 1.03 18.2 59.1 12.3 71.4 4.80 2.66 15 9870.3 26.8 31.7 21.3 57.7 11.7 69.4 4.93 2.66 16 9871.3 7.03 2.56 18.8 53.5 16.0 69.5 3.34 2.66 17 9872.3 11.6 14.6 20.4 57.3 14.3 71.6 4.01 2.66 18 9873.3 5.63 4.48 19.0 59.4 13.3 72.7 4.47 2.66 19 9874.3 4.74 2.60 18.4 54.6 15.3 69.9 3.57 2.66 20 9875.3 1.46 2.48 16.6 44.1 25.2 69.3 1.75 2.68 21 9876.3 3.12 0.794 17.3 46.2 24.9 71.1 1.86 2.67 22 9877.3 9.76 5.49 20.1 50.3 18.8 69.1 2.68 2.67 23 9878.3 15.4 2.72 20.4 48.2 17.1 65.3 2.82 2.68 24 9879.3 2.16 1.28 17.3 44.7 21.3 66.0 2.10 2.69 25 9880.3 7.09 3.07 19.7 47.2 19.4 66.6 2.43 2.67 26 9881.3 4.93 3.02 18.9 50.7 20.9 71.6 2.43 2.67 27 9882.3 1.91 2.04 18.9 48.5 20.9 69.4 2.32 2.67 28 9883.3 4.42 1.06 18.7 45.1 21.7 66.8 2.08 2.67 Sst gry-lt tan vfgr vslty It sp stn dgld flu Sst It brn vfgr slty m stn gld flu Sst It brn vfgr slty m stn gld flu Sst It brn vfgr slty m stn gld flu Sst brn vfgr slty dk stn gld flu Sst brn vfgr slty m stn gld flu Frac Sst brn vfgr slty m stn'gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Frac Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Frac Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Seating Pressure -- 2000 psig Confining Pressure = 400 psig Phillips Petroleum Co. CD2-24 Colville River Unit CL File No.: 57111 - 01134 CORE ANALYSIS RESULTS 29 9884.3 3.89 0.422 16.5 46.6 24.8 71.4 1.88 2.69 30 9885.3 11.6 14.1 18.8 53.1 17.4 70.5 3.05 2.68 31 9886.3 12.4 2.71 17.3 51.8 23.9 75.7 2.17 2.68 32 9887.3 6.45 1.10 17.4 48.4 24.5 72.9 1.98 2.68 33 9888.3 14.5 0.699 17.9 50.5 21.7 72.2 2.33 2.68 34 9889.3 1.25 0.329 15.7 42.4 33.8 76.2 1.25 2.69 35 9890.3 3.98 0.805 16.6 44.6 31.2 75.8 1.43 2.68 36 9892.3 7.06 5.82 17.8 47.4 25.9 73.3 1.83 2.69 37 9893.3 7.49 0.472 18.4 43.1 21.1 64.2 2.04 2.68 38 9894.3 0.208 0.231 12.2 57.6 25.0 82.6 2.30 2.69 39 9895.3 0.942 0.476 14.4 33.4 37.2 70.6 0.90 2.68 40 9896.3 1.32 0.188 16.2 37.5 31.3 68.8 1.20 2.68 41 9897.3 0.362 0.175 14.1 33.0 38.7 71.7 0.85 2.68 42 9898.3 0.173 0.084 13.9 34.2 42.6 76.8 0.80 2.68 43 9899.3 0.136 0.084 13.1 28.0 47.7 75.7 0.59 2.69 44 9900.3 0.104 0.072 12.8 25.9 49.8 75.7 0.52 2.70 45 9901.3 0.084 0.052 11.2 20.8 60.3 81.1 0.34 2.74 46 9902.3 0.007 0.004 2.3 22.0 52.8 74.8 0.42 2.74 47 9903.3 0.352 0.133 17.1 33.4 44.7 78.1 0.75 2.67 48 9904.3 0.007 0.004 2.9 20.6 45.6 66.2 0.45 2.74 49 9905.3 0.074 0.102 12.5 31.7 45.7 77.4 0.69 2.69 50 9906.2 0.105 0.085 13.3 76.1 22.7 98.8 3.35 2.68 51 9907.3 0.064 0.044 12.2 32.5 48.5 81.0 0.67 2.69 52 9908.3 O. 134 0.042 12.2 24.3 56.5 80.8 0.43 2.70 53 9909.3 0.083 0.036 13.1 28.2 49.4 77.6 0.57 2.69 54 9910.3 0.181 0.037 11.7 38.1 46.9 85.0 0.81 2.68 55 9913.3 0.061 0.041 14.5 50.3 29.2 79.5 1.72 2.70 56 9916.3 0.065 0.036 12.4 26.5 56.0 82.5 0.47 2.68 Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst brn vfgr slty m stn gld flu Sst tan vfgr vslty m stn gld flu Sst tan vfgr vslty m stn gld flu Sst It brn vfgr vslty m stn gld flu Sst It brn vfgr vslty m stn gld flu Sst tan vfgr vslty m stn gld flu Sst tan vfgr vslty m stn gld flu Sst tan vfgr vslty m stn gld flu Sst tan-gry vfgr vslty m sp stn gld flu Sst gry-lt tan vfgr vslty calc It sp stn dgld flu Sst It brn vfgr vslty m stn gld flu Sst gry-lt tan vfgr vslty calc It sp stn dgld flu SSt It brn vfgr vslty m stn gld flu Sst tan vfgr vslty m stn gld flu Sst gry-tan vfgr vslty calc It sp stn gld flu Sst gry-tan vfgr vslty calc It sp stn gld flu Sst tan-gry vfgr vslty calc m sp stn gld flu Sst tan-gry vfgr vslty calc m sp stn gld flu Sst tan-gry vfgr vslty calc m sp stn gld flu Sst tan-gry vfgr vslty calc m sp stn gld flu Frac Seating Pressure = 2000 psig Confining Pressure = 400 psig Phillips Petroleum Co. Colville River Unit CORE ANALYSIS RESULTS CL File No.: 57111 - 01134 Sst tan-gry vfgr vslty calc m sp stn gld flu Sst tan-gry vfgr vslty calc m sp stn gld flu Sltst gry-tan vfgr sd calc m sp stn gld flu Sltst gry-tan vfgr sd calc m sp stn gld flu Sltst gry-tan vfgr sd calc m sp stn gld flu Sltst gry-tan vfgr sd calc m sp stn gld flu Sltst gry-tan vfgr sd calc m sp stn gld flu Sltst gry-tan vfgr sd calc m sp stn gld flu Sltst gry-tan vfgr sd calc m sp stn gld flu Sltst gry-tan vfgr sd calc m sp stn gld flu Sltst gry-tan vfgr sd calc m sp stn gld flu Sltst gry-lt tan shly calc It sp stn gld flu 57 9919.8 0.983 0.055 11.0 14.2 75.2 89.4 0.19 2.69 58 9922.2 0.133 0.025 10.4 18.5 74.2 92.7 0.25 2.67 59 9923.5 0.056 0.033 14.0 29.4 47.9 77.3 0.61 2.70 60 9928,3 0.166 0.030 12.1 20.1 66.8 86.9 0.30 2.70 61 9931.3 0.120 0.025 11.3 13.9 72.2 86.1 0.19 2.70 62 9934.3 0.121 0.035 12.7 20.0 59.5 79.5 0.34 2.68 63 9937.3 0.061 0.026 12.6 24.8 56.5 81.3 0,44 2.68 64 9940.3 0.189 0.030 11.7 14.5 68.9 83.4 0.21 2.69 65 9943.3 0.068 0.019 10.7 22,6 68.2 90.8 0.33 2.68 66 9946.4 0.076 0.059 11.8 17.6 67.3 84.9 0.26 2.70 67 9949.3 0.043 0.023 11.1 19.3 72.2 91.5 0.27 2.68 68 9952.8 0.053 0.017 9.4 6.8 92.0 98.8 0.07 2.71 Seating Pressure -- 2000 psig Confining Pressure = 400 psig Phillips Petroleum Co. CD2-24 Colville River Unit CL File No. · 571 tl - 01134 Hydraulic Unit Classification 9856.3 0,3661 0,012 9 9857,3 0.2218 0.043 8 9858,0 0.4990 0.120 9 9859,3 0,3061 0,065 8 9860.3 0,3513 0,070 9 9861,3 0,6239 0,161 10 9862,3 0,4311 0.089 9 9863.3 0,5330 0,122 9 9864,3 0,5372 0.121 9 9865.3 0,6289 0,148 10 9866.3 0,5023 0.115 9 9867.3 0,5957 0.144 10 9868,3 0,5877 0.126 10 9869.3 0,7898 0,176 10 9870.3 1,3057 0.353 11 9871,3 0.8264 0.192 10 9872,3 0,9240 0.237 10 7873,3 0,7275 0.171 10 9874,3 0.7076 0.159 10 9875,3 0.4664 0,093 9 9876,3 0,6376 .0,133 10 9877.3 0.8701 0,219 10 9878,3 1,0635 0.273 11 9879,3 0,5318 0.111 9 9880.3 0.7671 0,188 10 9881.3 0,6850 0,160 10 9882,3 0,4262 0,100 9 9883,3 0,6617 0.152 10 :':: i::Fl°W: i : Reservoir Hydraulic : : :Zone: ::: QUality Unit :::IndiCator: Index 9913,3 0,1208 0,020 6 9923,5 0.1220 0.020 6 9900.3 0.1931 0,028 7 9905,3 0,1690 0,024 7 9906.2 0.1816 0,028 7 9907,3 0.1640 0,023 7 9909.3 0,1651 0,025 7 9916,3 0,1611 0,023 7 9937,3 0,1510 0,022 7 9946.4 0,1898 0,025 7 9949,3 0,1555 0,019 7 9857.3 0,2218 0,043 8 9859,3 0,3061 0,065 8 9894.3 0,2937 0,041 8 9897.3 0,3084 0,050 8 9898,3 0.2174 0,035 8 9899.3 0.2134 0,032 8 9901,3 0,2155 0,027 8 9903,3 0,2190 0,045 8 9908.3 0,2354 0.033 8 9910,3 0.2937 0,039 8 9922.2 0.3056 0.036 8 9928,3 0,2654 0,037 8 9931.3 0,2539 0,032 8 9934,3 0.2107 0,031 8 9940.3 0,3033 0.040 8 9943,3 0,2091 0,025 8 9952.8 0.2290 0.024 8 Phillips Petroleum Co. CD2-24 Colville River Unit CL File No.: 57111 -01134 Hydraulic Unit Classification 9884.3 0.7725 0.153 10 9885.3 1.0619 0.246 11 9886.3 1.2746 0.266 11 9887.3 0.9091 0.191 10 9888.3 1.2909 0.282 11 9889.3 0.4736 0.088 9 9890.3 0.7716 0.154 10 9892.3 0.9093 0.197 10 9893.3 0.8898 0.200 10 9894.3 0.2937 0.041 8 9895.3 0.4772 0.080 9 9896.3 0.4621 0.089 9 9897.3 0.3084 0.050 8 9898.3 0.2174 0.035 8 9899.3 0.2134 0.032 8 9900.3 0.1931 0.028 7 9901.3 0.2155 0.027 8 9902.3 0.7117 0.017 10 9903.3 0.2190 0.045 8 9904.3 0.5024 0.015 9 9905.3 0.1690 0.024 7 9906.2 0.1816 0.028 7 9907.3 0.1640 0.023 7 9908.3 0.2354 0.033 8 9909.3 0.1651 0.025 7. 9910.3 0.2937 0.039 8 9913.3 0.1208 0.020 6 9916.3 0.1611 0.023 7 ::: iDepth: :,i :FLOW ~ Reservoir Hydraulic :' :z°ne:ii~ i~ Quality Unit : :.(ft)'i :Indicator: : Index 9856.3 0.3661 0.012 9 9858.0 0.4990 0.120 9 9860.3 0.3513 0.070 9 9862.3 0.4311 0.089 9 9863.3 0.5330 0.122 9 9864.3 0.5372 0.121 9 9866.3 0.5023 0.115 9 9875.3 0.4664 0.093 9 9879.3 0.5318 0.111 9 9882.3 0.4262 0.100 9 9889.3 0.4736 0.088 9 9895.3 0.4772 0.080 9 9896.3 0.4621 0.089 9 9904.3 0.5024 0.015 9 9861.3 0.6239 0.161 10 9865.3 0.6289 0.148 10 9867.3 0.5957 0.144 10 9868.3 0.5877 0.126 10 9869.3 0.7898 0.176 10 9871.3 0.8264 0.192 10 9872.3 0.9240 0.237 10 7873.3 0.7275 0.171 10 9874.3 0.7076 0.159 10 9876.3 0.6376 0.133 10 9877.3 0.8701 0.219 10 9880.3 0.7671 0.188 10 9881.3 0.6850 0.160 10 9883.3 0.6617 0.152 10 Phillips Petroleum Co. CD2-24 Colville River Unit CL File No.: 57111 - 01134 Hydraulic Unit Classification 9919.8 0.7543 0.094 10 9922.2 0.3056 0.036 8 9923.5 0.1220 0.020 6 9928.3 0.2654 0.037 8 9931.3 0.2539 0.032 8 9934.3 0.2107 0.031 8 9937.3 0.1510 0.022 7 9940.3 0.3033 0.040 8 9943.3 0.2091 0.025 8 9946.4 0.1898 0.025 7 9949.3 0.1555 0.019 7 9952.8 0.2290 0.024 8 :i:: :FlOw: : Reservoir Hydraulic :: zone :: : QUality Unit :ii. lndicat°r : Index 9884.3 0.7725 0.153 10 9887.3 0.9091 0.191 10 9890.3 0.7716 0.154 10 9892.3 0.9093 0.197 10 9893.3 0.8898 0.200 10 9902.3 0.7117 0.017 10 9919.8 0.7543 0.094 10 9870.3 1.3057 0.353 11 9878.3 1.0635 0.273 11 9885.3 1.0619 0.246 11 9886.3 1.2746 0.266 11 9888.3 1.2909 0.282 11 Phillips Alaska Inc. Alpine CD2-24 Profile Permeameter Results Interval : 9856.0' - 9952.8 Sample No, 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 Depth (fi) I Ka (md) I II 9856.20 0.993 9856.40 0.547 9856.60 0.420 9856.80 1.08 9857.00 1.34 9857.20 7.41 9857.40 18.7 9857.60 19.5 9857.80 31.3 9858.00 44.9 9858.21 6.49 9858.40 3.98 9858.60 6,58 9858.80 11,3 9859.08 13.3 9859.20 3.13 9859.40 1.68 9859.60 3.88 9859.81 5.57 9860.00 6.24 9860.20 32.6 9860.40 0.963 9860.60 2.33 9860.80 1.21 9861.00 4.60 9861,20 19.8 9861.40 4.27 9861.60 2.82 9861.80 3.35 9862.08 1.27 9862.20 2.12 9862.40 2.13 9862.60 1.30 9862.80 1.59 9863.00 2.94 9863.20 1.56 9863.40 2.21 9863.60 3.17 9863.80 3.24 9863,99 8.55 9864.20 2.41 9864.40 1.79 9864.60 2.31 9864.80 4.17 9865.06 1.54 9865.20 5.15 9865.40 2.74 9865,60 3.07 9865.8O 3.54 9866.0O 11.2 KI (md) 0.649 0.328 0.237 0.719 0.909 5.86 15.9 16.6 27.4 39.9 5.10 3.03 5.17 9.30 11,0 2.32 1.17 2.94 4.34 4.89 28.5 0.629 1.69, 0.820 3.53 16.9 3.27 2.08 2.50 0.857 1.53 1.53 0.880 1.10 2.17 1.08 1.58 2.36 2.42 6.84 1.75 1.26 1.67 3.18 1.07 3.99 2.01 2.29 2.66 9.13 CL(AK) # 57112-2001-10 CL (CA)# 57111-01134 Petroleum Services 4.0" diameter slabbed core Standard Probe Tip Phillips Alaska Inc. Alpine CD2-24 Profile Permeameter Results Interval : 9856.0' - 9952.8 Sample No, 52 53 54 55 57 58 59 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 83 84 85 86 87 88 90 91 92 93 96 97 98 99 101 102 103 104 105 106 107 108 Depth (fi) I Ka (md) I 9866.20 10.0 9866.40 2.15 9866.60 3.92 9866.80 5.32 9867.20 7.05 9867.40 13.5 9867.60 3.69 9867.80 4.78 9868.06 2.54 9868.20 4.41 9868.40 2.14 9868.60 3.11 9868.80 1.04 9869.00 15.4 9869.20 16.4 9869.40 9.14 9869.60 21.7 9869.80 11.8 9870.00 8.27 9870.20 29.1 9870.40 40.9 9870.60 3.32 9870.80 5.66 9871.05 2.46 9871.20 5.20 9871.40 17.0 9871.60 9.17 9871.80 4.25 9871.98 32.9 9872.20 13.4 9872.40 6.06 9872.60 4.68 9872.80 5.68 9873.00 10.6 9873.25 13.4 9873.40 3.00 9873.60 11.7 9873.80 2.55 9874.20 17.6 9874.40 11.1 9874.60 1.23 9874.80 4.75 9875.01 24.4 9875.20 28.7 9875.40 2.25 9875.60 3.24 9875.80 7.47 9876.00 3.27 9876.20 17.9 9876.40 12.1 KI (md) 8.13 1.54 2.98 4.12 5.58 11.2 2.78 3.68 1.86 3.39 1.53 2.32 0.689 12.9 13.8 7.36 18.6 9.68 6.60 25.3 36.1 2.49 4.39 1.79 4.03 14.3 7.39 3.25 28.8 11.1 4.74 3.59 4.41 8.69 11.2 2.22 9.62 1.86 14.9 9.04 0.825 3.65 21.0 24.9 1.62 2.42 5.91 2.44 15.1 9.98 CL(AK) # 57112-2001-10 CL (CA) # 57111-01134 Petroleum Services 4.0" diameter slabbed core Standard Probe Tip Phillips Alaska Inc. Alpine CD2-24 Profile Permeameter Results Interval : 9856.0' - 9952.8 Sample No, 109 110 111 112 113 114 115 116 117 118 119 120 121 123 124 125 126 128 129 130 131 132 133 134 136 137 138 139 141 142 143 144 146 147 148 149 150 151 152 153 154 155 156 157 158 159 160 161 162 163 Depth (md) I 9876.60 12.2 9876.80 8.98 9877.05 4.51 9877.20 3.49 9877.20 3.10 9877.40 5.48 9877.60 4.14 9877.80 4.49 9878.00 20.3 9878.20 8.34 9878.40 11,7 9878.60 4.84 9878.80 3.46 9879.00 1.25 9879.20 13.0 9879.40 9.31 9879.60 13.9 9880.05 8.84 9880.20 4.98 9880.40 1.36 9880.60 1.71 9880,80 11.9 9881.00 4.11 9881.20 12.2 9881.40 8.O5 9881.60 5.24 9881.80 13.8 9882.00 3.02 9882.20 4.58 9882.40 3,07 9882.60 2.95 9882.80 4.37 9883.04 2.17 9883.20 3.21 9883.40 1.19 9883.60 2.50 9883.80 17.7 9884.00 1.66 9884.20 0.993 9884.40 2.24 9884.60 0.894 9884.80 8.04 9885.00 6.76 9885.20 26.4 9885.40 13.0 9885.60 7.16 9885.80 10.3 9886.04 5.54 9886.20 9.10 9886.40 20.7 KI (md) 10.1 7.25 3.45 2.57 2.31 4.27 3.16 3.43 17.3 6.66 9.62 3.72 2.59 0.842 10.8 7.53 11.6 7.11 3.84 0.931 1.20 9.76 3.14 10.1 6.41 4,06 11.5 2.24 3.51 2.28 2.19 3.33 1.55 2.40 0,799 1.82 14.9 1.16 0.651 1.61 0.577 6.41 5.33 22.9 10.7 5.65 8.42 4.32 7.33 17.6 CL(AK) # 57112-2001-10 CL (CA) # 57111-01134 Petroleum Services 4.0" diameter slabbed core Standard Probe Tip Phillips Alaska Inc. Alpine CD2-24 Profile Permeameter Results Interval : 9856.0' - 9952.8 Sample No, 164 165 166 167 168 169 170 171 172 173 174 175 176 177 178 179 180 181 182 183 184 185 186 187 188 189 191 192 193 195 196 197 198 199 200 201 202 203 204 205 206 207 208 209 210 211 212 213 214 215 Depth I Ka (fi) (md) 9886.60 24.4 9886.80 10.4 9887.00 7.67 9887.20 36.5 9887.40 9.77 9887.60 11.6 9887.80 19.2 9888.00 4.18 9888.20 6.05 9888.40 1.87 9888.60 6.81 9888.80 9.95 9889,04 5.37 9889.20 3.81 9889.40 25.9 9889.60 1.84 9889.80 1.63 9890.00 8.14 9890.20 17.3 9890,40 2.64 9890.60 5.31 9890.80 5.03 9891.07 2.04 9891.23 1.34 9891.41 3,46 9891.61 1.60 9891.79 46,1 9892.02 1.78 9892.20 1.08 9892.41 47.4 9892.57 29,0 9892.80 10,4 9893.01 12.1 9893.20 8.35 9893.40 7.96 9893.60 9.60 9893.78 19.0 9894.00 8.52 9894.20 1.48 9894.40 10.0 9894.60 3.65 9894.80 12.0 9895.03 9.01 9895.20 0.484 9895.40 4.11 9895.60 4.11 9895.80 3.42 9896.00 3.49 9896.20 41.6 9896.85 5.87 KI (md) 21.0 8.50 6.09 32.1 7.91 9.52 16.3 3.17 4.72 1.32 5.38 8.06 4.17 2.88 22.4 1.30 1.13 6.51 14,6 1.93 4.12 3.88 1.42 0.915 2.59 1.11 40.9 1.26 0.714 42.2 25.2 8.47 10.0 6.67 6.34 7.78 16.1 6.81 1.02 8.15 2.74 9.84 7.25 0.283 3.14 3.14 2.56 2.60 36.9 4.58 CL(AK) # 57112-2001-10 CL (CA) # 57111-01134 Petroleum Services 4.0" diameter slabbed core Standard Probe Tip Phillips Alaska Inc. Alpine CD2-24 Profile Permeameter Results Interval : 9856.0' - 9952.8 Sample No, 216 217 218 219 220 221 222 223 224 227 230 231 232 233 234 235 236 240 242 243 244 245 246 247 248 249 250 251 252 253 254 255 256 257 258 259 260 261 262 263 264 265 266 267 268 269 270 271 272 273 Depth I Ka (fi) (md) 9896.88 1.71 9897.02 1.89 9897.06 1.72 9897.20 51.8 9897.40 3.69 9897.61 5.40 9897.82 17.7 9898.03 1.02 9898.20 1.30 9898.41 119. 9899.00 52.6 9899.20 22.9 9899.40 5.36 9899.60 44.2 9899.80 130. 9900.00 14.0 9900.20 2.26 9900.80 23.5 9901.03 2.13 9901.20 3.42 9901.40 0.437 9901.59 0.036 9901.79 0.040 9902.00 0.094 9902.20 1.55 9902,40 0.607 9902.60 0.584 9902.80 45.0 9903.00 3.11 9903.20 5.38 9903.39 0.720 9903.60 4.68 9903.80 0.378 9904.02 0.125 9904.20 0.052 9904.40 0.533 9904.60 0.171 9904.80 14.2 9905.00 9.38 9905.20 65.2 9905.40 5,19 9905.60 2.69 9905.80 6.64 9906.00 36.9 9906.20 43.5 9906.40 27.3 9906.60 1.83 9906.80 2.09 9907.04 0.416 9907.20 4.56 KI (md) 1.20 1.33 1.21 46,3 2.79 4.20 15.0 0.673 0.881 109. 47.1 19.6 4.16 39.2 120. 11.7 1.62 20.2 1.52 2.56 0.251 0.011 0.012 0.038 1.06 0.369 0.353 40.0 2.31 4.18 0.451 3.59 0.212 0.055 '0.018 0.318 0.081 11.8 7.59 58.8 4.01 1.97 5.23 32.5 38.7 23.7 1.29 1.49 0.237 3.48 CL(AK) # 57112-2001-10 CL (CA) # 57111-01134 Petroleum Services 4.0" diameter slabbed core Standard Probe Tip Phillips Alaska Inc. Alpine CD2-24 Profile Permeameter Results Interval : 9856.0' - 9952.8 Sample No, 274 275 276 277 278 280 281 282 284 285 286 287 290 291 292 293 294 295 296 297 298 299 300 301 3O2 303 304 305 3O6 307 308 309 310 311 312 313 314 315 316 317 318 319 322 325 326 327 328 329 330 331 Depth (fi) I Ka (md) I 9907.40 9.31 9907.60 4.66 9907.80 1.48 9908.01 2,24 9908.20 1.85 9908.60 6.26 9908.80 13.4 9909.00 27.9 9909.20 61.1 9909.40 1.66 9909.60 21.2 9909.80 6.81 9910.09 24.3 9910.20 29.1 9910.40 1.75 9910.60 6.83 9910.80 9.25 9911.00 14.7 9911.20 2.38 9911.40 16.8 9911.60 9.51 9911.80 14.1 9912.00 14.5 9912.20 31.5 9912.40 14.0 9912.60 5.27 9912.80 10.5 9913.05 8.64 9913.20 4.17 9913,40 3,15 9913.60 3.13 9913.80 5.67 9914.00 3.63 9914.20 11.2 9914,40 1.33 9914.60 2.56 9914.80 6.70 9915.00 3.77 9915.20 9.57 9915.40 7.08 9915.60 2.78 9915.80 4.46 9916.20 80.5 9916.60 21.5 9916.80 8.09 9916.98 10.2 9917.20 66.4 9917.40 25.4 9917.60 11.2 9917.80 13.6 KI (md) 7,52 3.57 1.01 1.61 1.31 4.88 11.1 24.2 55.0 1.16 18.1 5.37 21.0 25.4 1.23 5.37 7.45 12,3 1.72 14.2 7.70 11.8 12.1 27.5 11.7 4.06 8.56 6.92 3.18 2.34 2.33 4.42 2.73 9.21 0.906 1.86 5.28 2.85 7.73 5.60 2.04 3.40 73.2 18.4 6.45 8.30 60.0 21.9 9.15 11.3 CL(AK) # 57112-2001-10 CL (CA) # 57111-01134 Petroleum Services 4.0" diameter slabbed core Standard Probe Tip Phillips Alaska Inc. Alpine CD2-24 Profile Permeameter Results Interval : 9856.0' - 9952.8 Sample No, 332 333 335 338 339 340 341 342 344 345 346 347 348 349 350 351 352 354 355 357 358 359 360 361 362 363 364 366 367 368 370 371 372 373 374 376 377 378 379 380 382 383 384 386 387 388 389 390 391 392 Depth (fi) I Ka (md) 9918.08 7.81 9918.21 2.95 9918.74 2.31 9919.26 179. 9919.56 131. 9919.71 9.07 9919.85 9.12 9920.00 10.6 9920.51 54.7 9920.75 115. 9921.00 6.20 9921.20 59.6 9921.39 52.8 9921.65 5.00 9921.84 15.0 9922.05 13.4 9922,20 6.10 9922.36 3.01 9922.60 15.6 9922.99 22.4 9923.21 21.6 9923.40 27.5 9923.60 17.0 9923.80 13.5 9924.00 8.71 9924.20 10.9 9924.40 18.6 9924.81 18.1 9925.05 6.49 9925,20 14.0 9925.40 5.14 9925,60 3.52 9925.80 4.46 9926.01 24.4 9926.20 5.21 9926.40 28.1 9926.60 6.32 9926.80 10.6 9927.00 42.4 9927.20 30.9 9927.39 9.33 9927.60 10.1 9927.82 15.0 9928.07 10.7 9928.20 4.13 9928.40 18.2 9928.60 16.0 9928.80 18.3 9929.00 20.7 9929.20 23.8 KI (md) 6.20 2.18 1.65 167. 121. 7.30 7.33 8.69 49.1 106. 4.85 53.6 47.2 3.86 12.5 11.1 4.76 2.23 13.0 19.2 18.5 23.9 14.3 11.2 6.99 8.95 15,8 15,3 5.10 11.7 3.97 2.64 3.40 21.0 4.01 24.4 4.95 8.68 37.6 ' 26.9 7.53 8.18 12.5 8.76 3.13 15.4 13.4 15.5 17.7 20.5 CL(AK) # 57112-2001-10 CL (CA) # 57111-01134 Petroleum Services 4.0" diameter slabbed core Standard Probe Tip Phillips Alaska Inc. Alpine CD2-24 Profile Permeameter Results Interval : 9856.0' - 9952.8 Sample No, 393 394 395 396 397 398 399 400 401 402 403 404 405 406 407 408 409 410 411 412 413 414 415 416 417 418 419 420 421 422 424 425 426 427 428 429 430 431 433 434 435 437 438 439 440 441 442 443 444 445 Depth (fi) I Ka (md) 9929.40 30.2 9929.60 29.8 9929.80 38.6 9930.00 27.0 9930.20 22.0 9930.40 24.3 9930.61 56.3 9930.83 28.1 9931.02 36.2 9931.20 37.1 9931.40 10.7 9931.60 14.7 9931.80 20.2 9932.00 9.35 9932.19 12.1 9932.40 26.7 9932.60 20.5 9932.80 10.0 9933.00 15.5 9933.20 61.6 9933.40 36,2 9933.60 48,4 9933.80 37,7 9934.02 22.0 9934.20 4.16 9934.39 6.43 9934.60 9.59 9934.79 32.0 9935.00 19.3 9935.19 36.6 9935.40 1.95 9935.60 5.53 9935.80 13.4 9936.00 21.9 9936.20 5.61 9936.40 2.32 9936.60 14.1 9936.80 5.06 9937.03 10.1 9937.20 23.0 9937.40 55.6 9937.60 38.9 9937.80 1.84 9938.00 19.6 9938.20 17.4 9938.40 21.4 9938.60 14.9 9938.80 27.9 9939.00 33.8 9939.20 34.1 KI (md) 26.4 25.9 34.1 23.4 18.8 21.0 50.5 24.5 31.9 32.7 8.79 12.2 17.3 7.56 10.0 23.1 17.5 8.17 13.0 55.5 31.9 43.2 33.3 18.9 3.17 5.04 7.77 28.1 16.3 32.2 1.38 4.30 11.2 18.7 4.45 1.67 11.7 3.91 8.21 19.8 49.8 34.3 1.30 16.7 14.7 18.4 12.4 24.2 29.7 29.9 CL(AK) # 57112-2001-10 CL (CA) # 57111-01134 Petroleum Services 4.0" diameter slabbed core Standard Probe Tip Phillips Alaska Inc. Alpine CD2-24 Profile Permeameter Results Interval : 9856.0' - 9952.8 Sample No, 446 447 448 449 450 451 452 453 454 455 456 457 458 459 461 463 466 468 469 471 472 473 476 478 479 481 482 483 484 485 486 488 490 491 493 494 495 496 497 498 499 500 501 507 508 509 510 511 512 513 Depth (fi) I Ka (md) 9939.40 32.3 9939.60 52.5 9939.81 23.8 9940.02 66.8 9940.20 13.8 9940.40 48.6 9940.60 34.9 9940.80 9.50 9941.00 21.6 9941.19 20.1 9941.40 17.6 9941.60 21.6 9941.80 19.0 9941.99 58.7 9942.17 24.9 9942.40 14.6 9942.85 12.7 9943.07 6.82 9943.20 7.86 9943.39 6.22 9943.60 8.07 9943.80 16.2 9944.05 10.4 9944.22 10.2 9944.40 1,66 9944.60 2.05 9944.80 9.41 9945.00 5.77 9945.23 3.16 9945,40 10.6 9945.60 4.11 9945.81 4.85 9946.04 22.3 9946.20 3.48 9946.40 122. 9946.60 52.4 9946.80 62.2 9947.00 8.64 9947.23 14,4 9947.40 17.3 9947.60 27.2 9947.80 37.2 9948.00 56.0 9948.40 4.40 9948.71 5.98 9948.88 10.2 9949.04 6.39 9949.20 25.7 9949.40 25.5 9949.60 16.9 KI (md) 28.2 47.0 20.5 60.3 11.5 43.4 30.7 7.69 18.5 17.1 14.9 18.5 16.1 52.7 21.5 12.2 10.5 5.35 6.25 4.87 6.43 13.6 8.46 8.30 1.16 1.46 7.59 4.48 2.35 8.65 3.13 3.74 19.1 2.61 113. 46.9 56.0 6.92 12.0 14.6 23.6 32.8 50.3 3.36 4.66 8.32 5.01 22.2 22.0 14.3 CL(AK) # 57112-2001-10 CL (CA) # 57111-01134 Petroleum Services 4.0" diameter slabbed core Standard Probe Tip Phillips Alaska Inc. Alpine CD2-24 Profile Permeameter Results Interval : 9856.0' - 9952.8 Sample No, 514 515 516 517 519 520 522 523 524 525 527 528 I Depth I Ka I KI (ft) (md) (md) 9949.80 23.0 19.8 9950.00 13.4 11.1 9950.23 21.0 18.0 9950.40 19.2 16.3 9950.59 22.6 19.5 9950.79 21.2 18.1 9951.00 10.6 8.65 9951.24 26.9 23.3 9951.42 24.0 20.6 9951,84 4.05 3.08 9952.48 4.50 3.43 9952.67 6.38 5.00 CL(AK) # 57112-2001-10 CL (CA) # 57111-01134 Petroleum Services 4.0" diameter slabbed core Standard Probe Tip ANADRILL SCHLUMBERGER Client ................... : Phillips Alaska, Inc. Field .................... : Coville River Survey report Well ..................... : CD2-24 API number ............... : 50-103-20377-00 Engineer ................. : St. Amour 7OUNTY: .................. : Doyon 19 '~STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : MEAN SEA LEVEL Depth reference .......... : Drill Floor GL above permanent ....... : 15.90 ft KB above permanent ....... : DF above permanent ....... : 52.85 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point ~'Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 331.86 degrees 27-Jun-2001 16:02:38 Page ~k of 7 UUL 82oo/ Spud date .............. '..: 2-~!L~kan~_ survey date ......... : 27-Ju~-O1~l~$O~Q~'"~ Last Total accepted surveys...: 151 ~C~0~'~0~/$$1~D~ MD of first survey ....... : 0.00 ft -~ MD of last survey ........ : 14301.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 20-Jun-2001 Magnetic field strength..: 1147.16 HCNT Magnetic dec (+E/W-) ..... : 25.33 degrees Magnetic dip ............. : 80.54 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.16 HCNT Reference Dip ............ : 80.54 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.36 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.36 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 27-Jun-2001 16:02:38 Page 2 of 7 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ depth section +N/S- (ft) (ft) (ft) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2 114.00 0.00 0.00 114.00 114.00 0.00 0.00 3 290.00 0.26 233.58 176.00 290.00 -0.06 -0.24 4 383.00 0.60 259.77 93.00 383.00 0.06 -0.45 5 474.00 1.62 277.25 91.00 473.98 0.95 -0.37 6 564.00 2.78 273.90 7 655.00 4.03 277.14 8 744.00 4.77 279.73 9 833.00 5.20 282.56 10 922.00 5.95 284.58 11 1013.00 8.21 283.48 12 1109.00 11.66 283.19 13 1204.00 14.89 283.62 14 1300.00 16.72 283.82 15 1397.00 19.56 282.10 16 1491.00 23.33 278.93 17 1587.00 28.21 277.04 18 1682.00 32.45 276.17 19 1778.00 36.68 275.48 20 1872.00 41.49 274.52 90.00 563.91 2.85 -0.06 91.00 654.75 5.87 0.49 89.00 743.49 9.94 1.50 89.00 832.15 14.85 3.00 89.00 920.73 20.60 5.04 91.00 1011.03 28.12 7.74 96.00 1105.57 39.08 11.56 95.00 1198.02 53.56 16.62 96.00 1290.39 71.01 22.82 97.00 1382.56 90.83 29.56 94.00 1470.04 112.22 35.75 96.00 1556.47 136.77 41.49 95.00 1638.45 164.08 46.98 96.00 1717.48 194.49 52.49 94.00 1790.43 226.86 57.63 96.00 1859.53 263.12 63.26 95.00 1922.63 302.59 70.24 96.00 1982.73 345.78 79.49 95.00 2040.84 389.95 89.76 95.00 2098.49 434.07 99.77 21 1968.00 46.40 275.15 22 2063.00 50.33 276.11 23 2159.00 52.15 278.06 24 2254.00 52.44 277.65 25 2349.00 52.83 277.58 26 2444.00 52.61 277.74 95.00 27 2539.00 52.64 278.98 95.00 28 2634.00 51.38 279.26 95.00 29 2735.61 50.71 278.35 101.61 30 2907.00 50.66 279.83 171.39 2156.03 2213.70 2272.18 2336.06 2444.65 Displ +E/W- (ft) 0 0 -0 -0 -2 .00 .00 .32 .97 .72 -6 -11 -18 -25 -34 .15 .53 .28 .86 .27 -45 -61 -82 -107 -137 .15 .27 .48 .88 .31 -171.10 -212.42 -260.07 -314.24 -373.26 -439.62 -510.27 -584.54 -659.00 -733.83 Total displ (ft) At Azim (deg) 0.00 0.00 0.40 1.07 2.74 0.00 0.00 233.58 245.18 262.22 6.16 11.54 18.34 26.04 34.63 269.42 272.41 274.69 276.62 278.37 45.81 62.35 84.14 110.27 140.46 279.73 280.68 281.39 281.95 282.15 174.79 216.44 264.28 318.59 377.68 281.80 281.05 280.24 279.48 278.78 444.15 515.08 589.92 665.08 740.59 278.19 277.84 277.74 277.76 277.74 478.29 109.84 -808.75 816.18 277.73 523.19 120.82 -883.44 891.66 277.79 568.52 132.68 -957.36 966.51 277.89 616.01 144.78 -1035.45 1045.52 277.96 696.23 165.73 -1166.37 1178.09 278.09 DLS (deg/ i00f) 0.00 0.00 0.15 0.41 1.17 1.30 1.39 0.86 0.56 0.87 2.49 3.59 3.40 1.91 2.98 4.19 5.15 4.49 4.43 5.16 5.13 4.21 2.47 0.46 0.41 0.27 1.04 1.35 0.96 0.67 Srvy tool type TIP MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- ANADRILL SCHLUMBERGER Survey Report 27-Jun-2001 16:02:38 Page 3 of 7 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 3002.00 50.66 279.13 95.00 32 3098.00 50.70 279.04 96.00 33 3194.00 50.63 277.23 96.00 34 3289.00 50.82 278.07 95.00 35 3385.00 51.06 277.48 96.00 36 3480.00 50.82 276.96 37 3575.00 50.77 277.40 38 3670.00 49.60 276.72 39 3765.00 49.65 277.22 40 3860.00 48.24 276.28 41 3956.00 48.26 276.37 42 4051.00 48.28 276.61 43 4146.00 48.38 276.56 44 4241.00 48.40 276.94 45 4336.00 48.39 276.19 46 4432.00 48.04 277.73 47 4527.00 48.10 278.52 48 4622.00 48.11 279.00 49 4717.00 48.14 278.99 50 4813.00 47.98 278.68 51 4908.00 48.00 280.11 52 5003.00 47.98 279.34 53 5098.00 48.04 279.01 54 5193.00 48.02 278.44 55 5288.00 47.98 277.85 56 5384.00 48.03 276.81 57 5479.00 48.05 276.95 58 5574.00 48.07 277.64 59 5670.00 48.07 277.63 60 5765.00 48.10 278.14 95.00 95.00 95.00 95.00 95.00 96.00 95.00 95.00 95.00 95.00 96.00 95.00 95.00 95.00 96.00 95.00 95.O0 95.00 95.00 95.00 96.00 95.00 95.00 96.00 95.00 TVD depth (ft) 2504.88 2565.71 2626.56 2686.70 2747.19 2807.05 2867.10 2927.93 2989.47 3051.87 3115.79 3179.03 3242.18 3305.27 3368.35 3432.32 3495.80 3559.24 3622.65 3686.82 3750.40 3813.98 3877.53 3941.06 4004.63 4068.86 4132.38 4195.87 4260.02 4323.49 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 741.08 177 786.01 189 829.94 200 872.95 209 916.67 219 959.36 1001.92 1043.99 1085.61 1126.59 1167.12 1207.41 1247.84 1288.47 1328.91 1370.06 1411.87 1454.33 1497.03 1539.98 1582.99 1626.31 1669.12 1711.49 1753.27 1794.67 1835.21 1876.18 1917.93 1959.51 .83 -1238.84 .56 -1312.18 .06 -1385.68 .85 -1458.56 .94 -1532.42 229.21 -1605.60 238.41 -1678.64 247.38 -1751.05 256.16 -1822.89 264.59 -1894.03 272.48 -1965.21 280.49 -2035.66 288.63 -2106.15 296.98 -2176.69 305.10 -2247.26 313.77 -2318.31 323.76 -2388.27 334.53 -2458.16 345.59 -2528.03 356.56 -2598.59 368.08 -2668.23 380.00 -2737.80 391.26 -2807.51 401.98 -2877.32 411.98 -2947.21 421.08 -3017.97 429.54 -3088.11 438.52 -3158.20 448.01 -3228.99 457.70 -3299.01 1251.54 1325.80 1400.05 1473.58 1548.12 278.17 0.57 MWD_M 278.22 0.08 MWD_M 278.22 1.46 MWD_M 278.19 0.71 MWD_M 278.17 0.54 MWD_M 1621.88 1695.48 1768.44 1840.80 1912.42 278.12 0.49 MWD_M 278.08 0.36 MWD_M 278.04 1.35 MWD_M 278.00 0.40 MWD_M 277.95 1.66 MWD_M 1984.01 2054.89 2125.84 2196.85 2267.87 277.89 0.07 MWD_M 277.85 0.19 MWD_M 277.80 0.11 MWD_M 277.77 0.30 MWD_M 277.73 0.59 MWD_M 2339.45 2410.12 2480.82 2551.54 2622.94 277.71 1.25 MWD_M 277.72 0.62 MWD_M 277.75 0.38 MWD_M 277.78 0.03 MWD_M 277.81 0.29 MWD_M 2693.50 2764.05 2834.64 2905.27 2975.86 277.85 1.12 MWD_M 277.90 0.60 MWD_M 277.93 0.27 MWD_M 277.95 0.45 MWD_M 277.96 0.46 MWD_M 3047.21 3117.84 3188.50 3259.92 3330.61 277.94 0.81 MWD_M 277.92 0.11 MWD_M 277.91 0.54 MWD_M 277.90 0.01 MWD_M 277.90 0.40 MWD_M ANADRILL SCHLUMBERGER Survey Report 27-Jun-2001 16:02:38 Page 4 of 7 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD depth (ft) Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 61 5860.00 48.00 277.27 62 5956.00 48.09 277.84 63 6051.00 48.00 276.48 64 6146.00 48.22 276.59 65 6242.00 48.41 278.53 95.00 96.00 95.00 95.00 96.00 4386.99 4451.17 4514.69 4578.12 4641.97 2000.88 467.18 -3369.02 3401.26 277.89 0.69 2042.54 476.56 -3439.80 3472.65 277.89 0.45 2083.36 485.37 -3509.89 3543.29 277.87 1.07 2123.60 493.42 -3580.15 3613.99 277.85 0.25 2165.43 502.85 -3651.22 3685.68 277.84 1.52 66 6337.00 48.36 278.96 95.00 4705.06 67 6432.00 48.35 277.30 95.00 4768.19 68 6526.00 48.37 277.86 94.00 4830.65 69 6621.00 48.33 277.41 95.00 4893.78 70 6717.00 48.38 278.99 96.00 4957.58 2208.06 513.65 -3721.41 3756.70 2250.06 523.69 -3791.69 3827.68 2291.07 532.96 -3861.32 3897.93 2332.57 542.39 -3931.68 3968.91 2375.08 552.62 -4002.68 4040.65 277.86 0.34 MWD_M 277.86 1.31 MWD_M 277.86 0.45 MWD_M 277.85 0.36 MWD_M 277.86 1.23 MWD_M 71 6812.00 48.30 279.93 95.00 5020.73 72 6907.00 48.31 280.64 95.00 5083.92 73 7002.00 48.29 279.49 95.00 5147.11 74 7097.00 48.00 279.09 95.00 5210.50 75 7192.00 48.06 279.78 95.00 5274.03 2418.38 564.28 -4072.69 4111.59 277.89 0.74 MWD_M 2462.47 576.95 -4142.48 4182.47 277.93 0.56 MWD_M 2506.33 589.34 -4212.32 4253.35 277.96 0.90 MWD_M 2549.34 600.77 -4282.15 4324.09 277.99 0.44 MWD_M 2592.41 612.35 -4351.83 4394.70 278.01 0.54 MWD_M 76 7287.00 48.04 279.81 95.00 5337.54 77 7382.00 48.03 279.72 95.00 5401.06 78 7478.00 48.05 279.74 96.00 5465.25 79 7573.00 48.07 279.28 95.00 5528.74 80 7668.00 48.02 277.06 95.00 5592.26 2635.85 624.37 -4421.45 4465.32 2679.24 636.35 -4491.07 4535.92 2723.07 648.41 -4-561.43 4607.28 2766.23 660.09 -4631.12 4677.92 2808.06 670.13 -4701.04 4748.56 278.04 0.03 MWD_M 278.06 0.07 MW _M 278.09 0.03 MWD_M 278.11 0.36 MWD_M 278.11 1.74 MWD~ 81 7763.00 47.97 276.25 95.00 5655.83 82 7858.00 48.06 276.14 95.00 5719.38 83 7953.00 48.01 277.11 95.00 5782.91 84 8048.00 48.14 277.93 95.00 5846.38 85 8144.00 47.97 278.31 96.00 5910.55 2848.35 678.31 -4771.16 4819.13 2888.18 685.93 -4841.36 4889.71 2928.45 694.08 -4911.53 4960.33 2969.66 703.33 -4981.60 5031.00 3011.89 713.41 -5052.29 5102.41 278.09 0.64 MWD_M 278.06 0.13 MWD_M 278.04 0.76 MWD_M 278.04 0.66 MWD_M 278.04 0.34 MWD_M 86 8239.00 48.01 278.37 87 8335.00 48.07 279.21 88 8430.00 48.07 279.61 89 8525.00 48.09 279.80 90 8620.00 48.09 279.03 95.00 96.00 95.00 95.00 95.00 5974.13 6038.32 6101.80 6165.27 6228.73 3053.86 723.65 -5122.13 5172.99 3096.75 734.56 -5192.67 5244.37 3139.82 746.12 -5262.40 5315.03 3183.19 758.03 -5332.08 5385.69 3226.28 769.60 -5401.82 5456.37 278.04 0.06 MWD_M 278.05 0.65 MWD_M 278.07 0.31 MWD_M 278.09 0.15 MWD_M 278.11 0.60 MWD_M ~ ANADRILL SCHLUMBERGER Survey Report 27-Jun-2001 16:02:38 Page 5 of 7 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 8715.00 48.09 278.29 92 8809.00 49.36 278.57 93 8904.00 49.53 279.02 94 8999.00 49.54 282.49 95 9031.00 49.76 283.42 96 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 9095.00 50.69 284.55 9190.00 53.44 288.68 9285.00 55.06 289.83 9380.00 55.66 290.82 9474.00 57.07 293.66 9569.00 57.58 293.98 9664.00 57.56 295.59 9759.00 57.50 296.15 9855.00 58.76 298.44 9950.00 61.25 300.66 10045.00 65.24 305.21 10141.00 67.85 308.43 10236.00 70.74 312.15 10331.00 73.92 314.73 10426.00 76.72 317.38 10521.00 79.35 320.39 10616.00 82.46 325.40 10711.00 84.13 327.57 10773.00 85.91 329.13 10900.00 87.91 328.54 10996.00 90.10 327.64 11093.00 91.99 328.75 11187.00 90.48 331.76 11284.00 90.55 331.71 11379.00 90.75 331.48 95.00 94.00 95.00 95.00 32.00 64.00 95.00 95.00 95.00 94.00 95.00 95.00 95.00 96.00 95.00 95.00 96.00 95.00 95.00 95.00 95.00 95.00 95.00 62.00 127.00 96.00 97.00 94.00 97.00 95.00 TVD depth (ft) Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 6292.18 3268.63 780.24 6354.19 3310.72 790.60 6415.96 3354.10 801.64 6477.62 3399.46 815.12 6498.34 3415.50 820.59 6539.29 3448.49 832.48 6597.70 3501.26 853.94 6653.20 3558.00 879.37 6707.20 3616.51 906.52 6759.28 3676.80 936.15 6810.57 6861.51 6912.52 6963.21 7010.70 7053.48 7091.69 7125.29 7154.12 7178.20 -5471.71 -5541.59 -5612.92 -5683.91 -5707.68 -5755.40 -5827.15 -5899.93 -5973.22 -6045.65 5527.06 278.12 0.58 5597.71 278.12 1.37 5669.88 278.13 0.40 5742.06 278.16 2.78 5766.36 278.18 2.32 5815.30 278.23 1.99 5889.39 278.34 4.49 5965.11 278.48 1.97 6041.62 278.63 1.06 6117.70 278.80 2.93 3739.78 968.45 -6118.80 6194.97 3803.75 1002.06 -6191.59 6272.16 3868.60 1037.03 -6263.71 6348.98 3935.73 1074.42 -6336.15 6426.60 4005.27 1115.01 -6407.70 6503.99 4079.50 1161.16 -6478.82 6582.05 4159.28 1213.94 -6549.29 6660.84 4241.91 1271.41 -6617.03 6738.07 4327.77 1333.65 -6682.73 6814.51 4416.18 1399.81 -6746.48 6890.17 7197.90 4506.73 1469.82 -6807.57 6964.44 7212.92 4599.35 1544.61 -6864.13 7035.77 7224.01 4693.28 1623.27 -6916.21 7104.15 7229.40 4754.92 1675.84 -6948.62 7147.85 7236.24 4881.55 1784.35 -7014.25 7237.65 7237.91 7236.14 7234.11 7233.24 7232.16 4977.32 1865.82 -7064.98 7307.20 5074.11 1948.24 -7116.09 7377.96 5168.03 2029.83 -7162.71 7444.77 5265.03 2115.26 -7208.64 7512.58 5360.02 2198.81 -7253.83 7579.76 278.99 0.61 279.19 1.43 279.40 0.50 279.62 2.41 279.87 3.31 280.16 5.99 280.50 4.11 280.88 4.76 281.29 4.23 281.72 4.00 282.18 4.16 282.68 6.15 283.21 2.87 283.56 3.81 284.27 1.64 IMP 284.79 2.47 IMP 285.31 2.26 IMP 285.82 3.58 IMP 286.35 0.09 IMP 286.86 0.32 IMP 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis · ANADRILL SCHLUMBERGER Survey Report 27-Jun-2001 16:02:38 Page 6 of 7 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 11474.00 90.07 331.93 122 11570.00 90.55 331.98 123 11666.00 91.03 332.48 124 11761.00 90.21 332.47 125 11855.00 90.58 332.34 95.00 96.00 96.00 95.00 94.00 TVD depth (ft) 7231.48 7230.96 7229.64 7228.61 7227.97 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 5455.02 5551.02 5647.00 5741.99 5835.99 2282.46 -7298.86 2367.19 -7343.99 2452.12 -7388.72 2536.36 -7432.62 2619.67 -7476.16 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) i00f) type type 7647.42 7716.07 7784.99 7853.47 7921.84 287.37 0.86 IMP 287.87 0.50 IMP 288.36 0.72 IMP 288.84 0.86 IMP 289.31 0.42 IMP 6-axis 6-axis 6-axis 6-axis 6-axis 126 127 128 129 130 11952.00 90.86 332.73 12045.00 88.87 332.46 12142.00 89.31 331.81 12236.00 90.72 332.12 12332.00 90.41 332.29 97.00 93.00 97.00 94.00 96.00 7226.75 7226.97 7228.51 7228.48 7227.54 5932.97 6025.96 6122.94 6216.94 6312.93 2705.73 -7520.89 2788.29 -7563.70 2874.03 -7609.03 2956.99 -7653.21 3041.91 -7697.97 7992.80 8061.27 8133.71 8204.59 8277.20 289.79 0.49 IMP 290.24 2.16 IMP 290.69 0.81 IMP 291.13 1.54 IMP 291.56 0.37 IMP 6-axis 6-axis 6-axis 6-axis 6-axis 131 132 133 134 135 12427.00 91.99 331.81 12523.00 91.81 331.85 12618.00 92.16 333.33 12714.00 90.14 333.98 12809.00 90.68 333.80 95.00 96.00 95.00 96.00 95.00 7225.55 7222.36 7219.07 7217.15 7216.47 6407.91 6503.86 6598.79 6694.72 6789.66 3125.81 -7742.48 3210.39 -7787.78 3294.68 -7831.49 3380.68 -7874.08 3465.99 -7915.89 8349.66 8423.55 8496.30 8569.14 8641.43 291.99 1.74 IMP 292.40 0.19 IMP 292.82 1.60 IMP 293.24 2.21 MWD 293.65 0.60 IMP 6-axis 6-axis 6-axis 5-axis 6-axis 136 137 138 139 140 12905.00 89.73 333.46 12999.00 90.41 333.59 13096.00 90.75 332.62 13191.00 90.10 332.97 13287.00 90.17 332.67 96.00 94.00 97.00 95.00 96.00 7216.12 7216.01 7215.03 7214.32 7214.09 6885.61 6979.57 7076.54 7171.52 7267.51 3551.99 -7958.52 3636.14 -8000.43 3722.64 -8044.31 3807.13 -8087.74 3892.53 -8131.59 8715.20 8787.97 8863.91 8939.00 9015.24 294.05 1.05 IMP 294.44 0.74 IMP 294.83 1.06 IMP 295.21 0.78 IMP 295.58 0.32 IMP 6-axis 6-axis 6-axis 6-axis 6-axis 141 142 143 144 145 13382.00 89.62 333.83 13477.00 88.83 333.99 13573.00 89.11 333.62 13668.00 89.38 332.56 13763.00 88.32 332.99 95.00 95.00 96.00 95.00 95.00- 7214.27 7215.55 7217.28 7218.53 7220.44 7362.48 7457.41 7553.34 7648.31 7743.27 3977.36 -8174.35 4062.67 -8216.12 4148.79 -8258.49 4233.50 -8301.48 4317.96 -8344.94 9090.62 9165.69 9242.03 9318.65 9395.89 295.95 1.35 IMP 296.31 0.85 IMP 296.67 0.48 IMP 297.02 1.15 IMP 297.36 1.20 IMP 6-axis 6-axis 6-axis 6-axis 6-axis 146 147 148 149 150 13860.00 88.87 333.79 13954.00 92.06 334.62 14050.00 93.09 334.62 14145.00 93.36 334.62 14240.00 93.84 334.95 97.00 94.00 96.00 95.00 95.00 7222.82 7222.05 7217.74 7212.40 7206.43 7840.21 7934.11 8029.90 8124.64 8219.33 4404.65 -8388.37 4489.27 -8429.27 4575.92 -8470.37 4661.61 -8511.03 4747.39 -8551.42 9474.48 9550.19 9627.37 9704.03 9780.82 297.70 1.00 IMP 298.04 3.51 IMP 298.38 1.07 IMP 298.71 0.28 IMP 299.04 0.61 IMP 6-axis 6-axis 6-axis 6-axis 6-axis ' ANADRILL SCHLUMBERGER Survey Report 27-Jun-2001 16:02:38 Page 7 of 7 Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) Vertical Displ section +N/S- (ft) (ft) Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type 151 14301.00 93.84 334.95 61.00 7202.35 8280.11 4802.53 -8577.19 9830.18 299.25 0.00 MWD PROJECTED [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc. Field .................... : Coville River Well ..................... : CD2-24PH API number ............... : 50-103-20377-70 Engineer ................. : St. Amour COUNTY: .................. : USA STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 15.90 ft KB above permanent ....... : na DF above permanent ....... : 52.85 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point .... Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 278.07 degrees 12-Jun-2001 12:38:54 Page 1 of 5 Spud date ................ : 2-Jun-01 Last survey date ......... : 12-Jun-01 Total accepted surveys...: 106 MD of first survey ....... : 0.00 ft MD of last survey ........ : 10054.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 02-Jun-2001 Magnetic field strength..: 1147.15 HCNT Magnetic dec (+E/W-) ..... : 25.36 degrees Magnetic dip ............. : 80.54 degrees MWD survey Reference Criteria Reference G .............. : 1002 68 mGal Reference H .............. : 1147 15 HCNT Reference Dip ............ : 80 54 degrees Tolerance of G ........... : (+/-) 2 50 mGal Tolerance of H ........... : (+/-) 6 00 HCNT Tolerance of Dip ......... : (+/-) 0 45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.36 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.36 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [ (c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 12-Jun-2001 12:38:54 Page 2 of 5 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 114.00 0.00 0.00 3 290.00 0.26 233.58 4 383.00 0.60 259.77 5 474.00 1.62 277.25 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 564.00 2.78 273.90 655.00 4.03 277.14 744.00 4.77 279.73 833.00 5.20 282.56 922.00 5.95 284.58 1013.00 8.21 283.48 1109.00 11.66 283.19 1204.00 14.89 283.62 1300.00 16.72 283.82 1397.00 19.56 282.10 1491.00 23.33 278.93 1587.00 28.21 277.04 1682.00 32.45 276.17 1778.00 36.68 275.48 1872.00 41.49 274.52 21 1968.00 46.40 275.15 22 2063.00 50.33 276.11 23 2159.00 52.15 278.06 24 2254.00 52.44 277.65 25 2349.00 52.83 277.58 26 2444.00 52.61 277.74 27 2539.00 52.64 278.98 28 2634.00 51.38 279.26 29 2735.61 50.71 278.35 30 2907.00 50.66 279.83 TVD Vertical Displ depth section +N/S- (ft) (ft) (ft) 0.00 0.00 0.00 0.00 114.00 114.00 0.00 0.00 176.00 290.00 0.28 -0.24 93.00 383.00 0.90 -0.45 91.00 473.98 2.64 -0.37 90.00 563.91 6.09 -0.06 91.00 654.75 11.48 0.49 89.00 743.49 18.31 1.50 89.00 832.15 26.03 3.00 89.00 920.73 34.63 5.04 91.00 96.00 95.00 96.00 97.00 1011.03 45.79 7.74 1105.57 62.28 11.56 1198.02 84.00 16.62 1290.39 110.02 22.82 1382.56 140.10 29.56 94.00 1470.04 174.42 35.75 96.00 1556.47 216.14 41.49 95.00 1638.45 264.09 46.98 96.00 1717.48 318.50 52.49 94.00 1790.43 377.66 57.63 96.00 1859.53 444.15 63.26 95.00 1922.63 515.07 70.24 96.00 1982.73 589.91 79.49 95.00 2040.84 665.07 89.76 95.00 2098.49 740.57 99.77 95.00 95.00 95.00 101.61 171.39 2156.03 2213.70 2272.18 2336.06 2444.65 816.16 891.65 966.51 1045.52 1178.09 Displ Total At DLS +E/W- displ Azim (deg (ft) (ft) (deg) 100f 0.00 0.00 0.00 0.00 -0.32 0.40 -0.97 1.07 -2.72 2.74 -6.15 6.16 -11.53 11.54 -18.28 18.34 -25.86 26.04 -34.27 34.63 -45.15 45.81 -61.27 62.35 -82.48 84.14 -107.88 110.27 -137.31 140.46 -171.10 174.79 -212.42 216.44 -260.07 264.28 -314.24 318.59 -373.26 377.68 -439.62 444.15 -510.27 515.08 -584.54 589.92 -659.00 665.08 -733.83 740.59 109.84 -808.75 816.18 120.82 -883.44 891.66 132.68 -957.36 966.51 144.78 -1035.45 1045.52 165.73 -1166.37 1178.09 Srvy Tool / tool qual ) type type 0.00 0.00 TIP 0.00 0.00 MWD 233.58 0.15 MWD 245.18 0.41 MWD 262.22 1.17 MWD 269.42 1.30 MWD 272.41 1.39 MWD 274.69 0.86 MWD 276.62 0.56 MWD 278.37 0.87 MWD 279.73 2.49 MWD 280.68 3.59 MWD 281.39 3.40 MWD 281.95 1.91 MWD 282.15 2.98 MWD 281.80 4.19 MWD 281.05 5.15 MWD 280.24 4.49 MWD 279.48 4.43 MWD 278.78 5.16 MWD 278.19 5.13 MWD 277.84 4.21 MWD 277.74 2.47 MWD 277.76 0.46 MWD 277.74 0.41 MWD 277.73 0.27 MWD 277.79 1.04 MWD 277.89 1.35 MWD 277.96 0.96 MWD 278.09 0.67 MWD_M 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- ANADRILL SCHLUMBERGER Survey Report 12-Jun-2001 12:38:54 Page 3 of 5 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 31 3002.00 50.66 279.13 95.00 2504.88 32 3098.00 50.70 279.04 96.00 2565.71 33 3194.00 50.63 277.23 96.00 2626.56 34 3289.00 50.82 278.07 95.00 2686.70 35 3385.00 51.06 277.48 96.00 2747.19 1251.54 1325.79 1400.04 1473.58 1548.12 177.83 -1238.84 189.56 -1312.18 200.06 -1385.68 209.85 -1458.56 219.94 -1532.42 1251.54 1325.80 1400.05 1473.58 1548.12 278.17 0.57 278.22 0.08 278.22 1.46 278.19 0.71 278.17 0.54 MWD_M MWD_M MWD_M MWD_M MWD_M 36 3480.00 50.82 276.96 95.00 2807.05 37 3575.00 50.77 277.40 95.00 2867.10 38 3670.00 49.60 276.72 95.00 2927.93 39 3765.00 49.65 277.22 95.00 2989.47 40 3860.00 48.24 276.28 95.00 3051.87 1621.88 1695.48 1768.44 1840.80 1912.42 229.21 -1605.60 238.41 -1678.64 247.38 -1751.05 256.16 -1822.89 264.59 -1894.03 1621.88 1695.48 1768.44 1840.80 1912.42 278.12 0.49 278.08 0.36 278.04 1.35 278.00 0.40 277.95 1.66 MWD_M MWD_M MWD_M MWD_M MWD_M 41 3956.00 48.26 276.37 96.00 3115.79 1984 42 4051.00 48.28 276.61 95.00 3179.03 2054 43 4146.00 48.38 276.56 95.00 3242.18 2125 44 4241.00 48.40 276.94 95.00 3305.27 2196 45 4336.00 48.39 276.19 95.00 3368.35 2267 .O0 .87 .81 .82 .83 272.48 -1965.21 280.49 -2035.66 288.63 -2106.15 296.98 -2176.69 305.10 -2247.26 1984.01 2054.89 2125.84 2196.85 2267.87 277.89 0.07 277.85 0.19 277.80 0.11 277.77 0.30 277.73 0.59 46 4432.00 48.04 277.73 47 4527.00 48.10 278.52 48 4622.00 48.11 279.00 49 4717.00 48.14 278.99 50 4813.00 47.98 278.68 51 4908.00 48.00 280.11 52 5003.00 47.98 279.34 53 5098.00 48.04 279.01 54 5193.00 48.02 278.44 55 5288.00 47.98 277.85 96.00 95.00 95.00 95.00 96.00 95.00 95.00 95.00 95.00 95.00 3432.32 3495.80 3559.24 3622.65 3686.82 3750.40 3813.98 3877.53 3941.06 4004.63 2339.40 2410.07 2480.78 2551.51 2622.91 2693.48 2764.04 2834.63 2905.26 2975.86 313.77 -2318.31 323.76 -2388.27 334.53 -2458.16 345.59 -2528.03 356.56 -2598.59 368.08 -2668.23 380.00 -2737.80 391.26 -2807.51 401.98 -2877.32 411.98 -2947.21 2339.45 2410.12 2480.82 2551.54 2622.94 2693.50 2764.05 2834.64 2905.27 2975.86 277.71 1.25 277.72 0.62 277.75 0.38 277.78 0.03 277.81 0.29 277.85 1.12 277.90 0.60 277.93 0.27 277.95 0.45 277.96 0.46 MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M 56 5384.00 48.03 276.81 57 5479.00 48.05 276.95 58 5574.00 48.07 277.64 59 5670.00 48.07 277.63 60 5765.00 48.10 278.14 96.00 95.00 95.00 96.00 95.00 4068.86 4132.38 4195.87 4260.02 4323.49 3047.20 3117.83 3188.48 3259.90 3330.59 421.08 -3017.97 429.54 -3088.11 438.52 -3158.20 448.01 -3228.99 457.70 -3299.01 3047.21 3117.84 3188.50 3259.92 3330.61 277.94 0.81 277.92 0.11 277.91 0.54 277.90 0.01 277.90 0.40 MWD_M MWD_M MWD_M ANADRILL SCHLUMBERGER Survey Report 12-Jun-2001 12:38:54 Page 4 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 5860.00 48.00 277.27 62 5956.00 48.09 277.84 63 6051.00 48.00 276.48 64 6146.00 48.22 276.59 65 6242.00 48.41 278.53 66 6337.00 48.36 278.96 67 6432.00 48.35 277.30 68 6526.00 48.37 277.86 69 6621.00 48.33 277.41 70 6717.00 48.38 278.99 71 6812.00 48.30 279.93 72 6907.00 48.31 280.64 73 7002.00 48.29 279.49 74 7097.00 48.00 279.09 75 7192.00 48.06 279.78 76 7287.00 48.04 279.81 77 7382.00 48.03 279.72 78 7478.00 48.05 279.74 79 7573.00 48.07 279.28 80 7668.00 48.02 277.06 95.00 96.00 95.00 95.00 96.00 95.00 95.00 94.00 95.00 96.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 96.00 95.00 95.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) i00f) 4386.99 4451.17 4514.69 4578.12 4641.97 4705.06 4768.19 4830.65 4893.78 4957.58 5020.73 5083.92 5147.11 5210.50 5274.03 5337.54 5401.06 5465.25 5528.74 5592.26 3401.25 3472.63 3543.27 3613.97 3685.65 3756.67 3827.66 3897.90 3968.89 4040.62 4111.57 4182.46 4253.34 4324.08 4394.70 4465.32 4535.92 4607.28 4677.92 4748.56 81 7763.00 47.97 276.25 95.00 5655.83 4819.13 82 7858.00 48.06 276.14 95.00 5719.38 4889.71 83 7953.00 48.01 277.11 95.00 5782.91 4960.33 84 8048.00 48.14 277.93 95.00 5846.38 5031.00 85 8144.00 47.97 278.31 96.00 5910.55 5102.41 86 8239.00 48.01 278.37 95.00 5974.13 5172.99 87 8335.00 48.07 279.21 96.00 6038.32 5244.37 88 8430.00 48.07 279.61 95.00 6101.80 5315.03 89 8525.00 48.09 279.80 95.00 6165.27 5385.69 90 8620.00 48.09 279.03 95.00 6228.73 5456.37 467.18 -3369.02 476.56 -3439.80 485.37 -3509.89 493.42 -3580.15 502.85 -3651.22 513.65 -3721.41 523.69 -3791.69 532.96 -3861.32 542.39 -3931.68 552.62 -4002.68 564.28 -4072.69 576.95 -4142.48 589.34 -4212.32 600.77 -4282.15 612.35 -4351.83 624.37 -4421.45 636.35 -4491.07 648.41 -4561.43 660.09 -4631.12 670.13 -4701.04 678.31 -4771.16 685.93 -4841.36 694.08 -4911.53 703.33 -4981.60 713.41 -5052.29 723.65 -5122.13 734.56 -5192.67 746.12 -5262.40 758.03 -5332.08 769.60 -5401.82 3401.26 3472.65 3543.29 3613.99 3685.68 277.89 0.69 277.89 0.45 277.87 1.07 277.85 0.25 277.84 1.52 3756.70 3827.68 3897.93 3968.91 4040.65 277.86 0.34 277.86 1.31 277.86 0.45 277.85 0.36 277.86 1.23 4111.59 4182.47 4253.35 4324.09 4394.70 277.89 0.74 277.93 0.56 277.96 0.90 277.99 0.44 278.01 0.54 4465.32 4535.92 4607.28 4677.92 4748.56 278.04 0.03 278.06 0.07 278.09 0.03 278.11 0.36 278.11 1.74 4819.13 4889.71 4960.33 5031.00 5102.41 278.09 0.64 278.06 0.13 278.04 0.76 278.04 0.66 278.04 0.34 5172.99 5244.37 5315.03 5385.69 5456.37 278.04 0.06 278.05 0.65 278.07 0.31 278.09 0.15 278.11 0.60 Srvy tool type MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M Tool qual type ANADRILL SCHLUMBERGER Survey Report 12-Jun-2001 12:38:54 Page 5 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) i00f) type type 91 8715.00 48.09 278.29 95.00 6292.18 92 8811.00 48.09 277.27 96.00 6356.31 93 8906.00 47.17 276.68 95.00 6420.33 94 9001.00 44.14 276.61 95.00 6486.73 95 9095.00 40.79 276.69 94.00 6556.06 96 9191.00 37.39 275.67 96.00 6630.56 97 9286.00 32.92 275.45 95.00 6708.21 98 9381.00 30.67 276.44 95.00 6788.95 99 9475.00 28.50 278.13 94.00 6870.69 100 9570.00 28.11 281.87 95.00 6954.34 101 9666.00 27.69 283.53 96.00 7039.18 102 9761.00 24.93 285.95 95.00 7124.34 103 9811.00 24.48 288.01 50.00 7169.76 104 9883.00 24.85 288.53 72.00 7235.19 105 9979.00 24.50 287.98 96.00 7322.43 5527.06 5598.50 5668.67 5736.58 5800.02 Projected to TD: 106 10054.00 5860.51 5915.14 5965.15 6011.55 6056.55 6101.32 6143.14 6163.78 6193.35 6232.80 24.50 287.98 75.00 7390.67 6263.43 [(c)2001 Anadrill IDEAL ID6_iC_08] 780.24 -5471.71 789.91 -5542.50 798.44 -5612.16 806.30 -5679.64 813.65 -5742.66 820.18 -5802.83 825.49 -5857.26 830.66 -5907.04 836.52 -5953.07 844.33 -5997.41 854.20 -6041.23 864.87 -6081.95 870.96 -6101.94 880.39 -6130.47 892.94 -6168.53 902.54 -6198.11 5527.06 5598.50 5668.67 5736.58 5800.02 5860.51 5915.14 5965.16 6011.56 6056.55 6101.32 6143.14 6163.78 6193.36 6232.82 278.12 0.58 278.11 0.79 278.10 1.07 278.08 3.19 278.06 3.56 278.05 3.60 278.02 4.71 278.00 2.43 278.00 2.47 278.01 1.91 278.05 0.92 278.09 3.12 278.12 1.94 278.17 0.60 278.24 0.44 6263.48 278.28 0,00 MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M 6-axis 6-axis 8/15/2001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1372 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD2-42 PB1 21291 CDR,ADN,ARC,M10 (PDC) 05/2tl01 CD2-42 PBI 21291 MD VISION RESISTIVITY 05/21/0t CD2-42 PBI 2t 29t TVD RESISTIVITY 0512tl01 CD2-42 PBI 21291 MD VISION DENSITY NEUTRON 0512tl01 CD2-42 PBI 21291 TVD VISION DENSITY NEUTRON 05121101 CD2-24 PBI 21324 IMPULSE & ADN 06113101 CD2-24 PB1 21324 MD VISION RESISTIVITY 06/13101 CD2-24 PB1 21324 'I'VD RESISTIVITY 06/13/01 CD2-24 PBI 21324 MD VISION DENSITY NEUTRON 06/13/01 CD2-24 PBI 21324 TVD VISION DENSITY NEUTRON 06113101 RECEIVED AUG ,- 1 £UU! DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-831 .~.la~!~;~f~as Coils. Anchorage 7/18/2001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1297 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alpine Well Job # Log Description Date BL Sepia Color Prints CD CD2-24 21322 PROCESSED DSI 06115101 1 DATE: RECEIVED JUL 50 2001 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ,Nadm Oil & ~as Cons. ConmlJldtm ~lchofage MWD/LWD Log Product Delivery JUL 18 2( 41aska Oil 8, Gas Cons. Anchorage Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD2-24 Date Dispatche 15-Jul-01 Installation/Rig Doyon 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 Received By: ~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite $00 Anchorage, Alaska 9950;3 nrosel @slb.oom Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ED 'on]mission PETRO£~ SER¥ICE~ Core Laboratories - Alaska From: Core Laboratories 600 W. 58th Ave., Unit D Anchorage, Alaska 99518 907-349-3541 Da~: Well Name: Number of Samples: Contact: Description of Material: Depths: 7/17/01 Phillips Alaska Inc. Alpine CD2-24 Meg Kremer Phillips Alaska Core Chip Samples 9856 - 9952.8 To: Alaska Oil & Gas Conservation Commission 333 W. 7th #100 Anchorage, Alaska 99501 907-279-1433 Sent By: Tim Lawlor Core Laboratories Received By: Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 5, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drillinq Waste on well CD2-24 Dear Sir or Madam: Phillips Alaska, Inc. hereby requests that CD2-24 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular injection on CD2-24 approximately July 25, 2001. Please find attached form 10-403 and other pertinent information as follows: 1. Form 10-403 2. Annular Disposal Transmittal Form 3. Pressure Calculations for Annular Disposal 4. Surface Casing Description 5. Surface Casing Cementing Report 6. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 7. Intermediate Casing Description 8. Intermediate Casing Cementing Report 9. Formation LOT on 9-5/8" x 7" casing annulus 10. Plan View of Adjacent Wells If you have any questions or require further information, please contact Vern Johnson at 265- 6081, or Chip Alvord at 265-6120. Vern Johnson Drilling Engineer cc: CD2-24 Well File Chip Alvord Scott Reynolds Nancy Lambert Sharon AIIsup-Drake ATO-868 ATO-838 Anadarko ATO-1530 RECEIVED JUL 0 b'2001 Alaska Oil & Gas Cons. Commission Anchorage 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 _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Annular Disposal 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development _X Exploratory __ Stratigraphic __ Service __ 4. Location of well at surface 1806' FNL, 1535' FEL, Sec. 2, T11N, R4E, UM At top of productive interval 96' FNL, 2094' FWL, Sec. 3, T11 N, R4E, UM At effective depth ..... Per APD At total depth 1410' FNL, 24' FEL, Sec. 33, T12N, R4E, UM ..... Per APD 12. Present well condition summary Total depth: measured true vertical Effective depth: measu red true vertical Casing Length Conductor 77' Surface 2755' Production 10774' 14301' 7202' 14301' 7202' Size 16" 9-5/8" 11 feet Plugs (measured) feet feet Junk (measured) feet Cemented lO yds portland 3 ready mix cmt 379 Sx AS III L & 235 Sx 15.8 class G 160' S'x 15.8 class G 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Collevile River Unit 8. Well number CD2-24 9. Permit number/approval number 201-095 10. APl number 50-103-20377 11. Field / Pool Coleville River Field / Alpine Oil Pool Measured Depth Truevertical Depth 114' 114' 2792' 2372' 10811' 7232' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth Packers & SSSV (type &measured depth) 4.5" 12.6#, L-80 @ 10,030' MD RECEIVED JUL 0 6 '7.001 ,Naska Oil & Gas Cons. commissio~ Anchorage 7" Baker S-3 Permanent Packer @ 9954 MD, Camco BAL-O SSSV @ 2137' MD 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __X 15. Status of well classification as: 14. Estimated date for commencing operation July 25, 2001 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas __ Suspended __ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Vern Johnson 265-6081 SignedChip A,vord ~//~l~L~'~&.- Title: Alpine Drilling Team Leader Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity__ BOP Test_ Location clearance_ Subsequent form required 10- ~ ~ Approved by order of the Commission Form 10-403 Rev 06/15/88 · Mechanical Integrity Test _ ¢~G,NAL ~(~E~ BY Commissioner Date 0RIG1HAL SUBMIT IN TRIPLICATE ' ~: t' Alpine: CD2-24A Procedure (continued from Proqram CD2-24) 1. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak offfor drilling ahead is 11.5 ppg EMW. 2. Drill 6 1/8" horizontal section to well TD. 3. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). 16. Displace well to brine and pull out of hole. 17. Run 4 %, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 rains. 21. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus. 22. Set BPV and secure well. Move rig off. Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-42 will be the closest well to CD2-24A. The ellipse separation between these wells will be 5423' at 10822' MD. Drillinq Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular PumpinR Operations: Incidental fluids developed from drilling operations on well CD2-24A will be disposed of into the annulus of another permitted well on the CD2 pad. The CD2-24A surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TYD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD2-24A be permitted for annular pumping of fluids occurring as a result of drilling 'operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set below the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998- 1086 = 1912 psi. The internal casing, pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst , 9-5/8" 40 L-80 3 BTC 3,090 psi 2,472 psi 5,750 psi 4,600 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi CD2-24A DRILLING FLUID PROGRAM Production Hole Section - 6 1/8" Density 9.2 ppg PV 10 -15 YP 25 - 30 Funnel Viscosity Initial Gels 10 - 15 10 minute gels 12 - 20 APl Filtrate HPHT Fluid Loss at 12 - 14 cc/30 min 160 9.0 - 9.5 PH 6 % KCL Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and DuaI-FIo starch will be used for viscosity and fluid loss control respectively. 12 Colville River Field CD2-24A Production Well Completion Plan 16" Conductor to 114' Updated 06/20101 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 2000' TVD=2254' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" s/s control lines 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2824' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 pp.q KCI Brine with 2000' TVD diesel cap Tubinq Supended with diesel to lowest GLM Completion MD Tubing Hanger 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 2254' End thermal centralizers 2824' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4251' 4-1/2", 12.6#/ft, IBT-Mod Tubing Start thermal centralizers. 5958' (1 per joint) Camco KBG-2 GLM (3.909" ID) 7026' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 9853' TVD 32' 2000" 2400' 3400' 4500' 5200' % % % 4-1/2" tubing joints (2)(R3) i HES "X" (3.813" ID) 9952' \ \ \ \ 4-1/2" tubing joint (1) (R3) Camco KBG-2 GLM (3 909" ID) B ' ' \\ \\ · aker S3 Packer 9993 7081 ~\ \ \ & 1" Camco DCK-2 ShearValve 4 1 ................. Pinn . . + . - /z ~umng joln~ []) t~,~) \ \ \ \F ed for cas,ng s,de shear @ /- 2000 ps, ................................ rl~-~ ,'tr~ ~,~ tz~ ~u) b;~ b aeg '~uu~b \ \ ~. % set 2 joints above the X landing nipple . ,. , ~- . , 7099' \ ~, ~ ' (with RHC plug ana ~auges) ~ ~ %. 4-1/2" 10' pup joint ~~ \~/, WEG(+l-65.1deg) 10046' 7104' ~ ~;~ +/-9993' TOC+/- 10010' MD\ ...................................................................... . ~ ~ Well TD at (500' MD above top 15300' MD / Alpine) '":~'",~.i~ ' , 7227' TVD Top Alpine at 10510' MD / 7245' TVD<':;'i'i'':<'':~-;---'---'---:--:-":i''<':''~~'''' ..... ' 7" 26 ppf L-80 BTC Mod Production Casing @ 10751' MD / 7272' TVD @ 87.5 deg 12 Colville River Field CD2-24A Production Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID), WRDP-2 SSSV (2.25" ID) and DB-6 No-Go Lock (3.812" OD) with dual 1/4" x 0.049" sis control line @ 2000' TVD 9-5/8" 40 ppf L-80 BTC Surface Casing @ 2824' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Updated 06~20~01 (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide (C) OI3en Hole Bridge Plucl Assembly - Baker Payzone ECP (cement inflated) \ \ \ \ & 1" Camco DCK-2 ShearValve \ \ \ ~, Pinned for casing side shear @ 2000 psi ~XX.X~~ iints ab°ye the X landing nipple,. TOC @ +/- 10010'M (500' MD above top Alpine) -XO -Float Collar - 4-1/2" Float Shoe Well TD at 15300' MD / 7227' TVD .............. ........ 7" 26 ppf L-80 BTC Mod Production Casing @ 10751' MD / 7272' TVD @ 87.5 deg CD2-24 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114/114 10.9 52 53 9 5/8 2824 / 2400 14.5 1086 (0.4525 psi/fi) 1570 7" 10751 / 7272 16.0 3290 (0.4525 psi/fi) 2565 N/A 15300 / 7227 16.0 3293 (0.4525 psi/fi) N/A · NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP - Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 - Gas gradient in psi/ft D - true Vertical depth of casing seat in ft RKB OR 2) ASP= FPP- (0.1x D) Where; FPP - Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052)- 0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052)- 0.1} D = [(14.5 x 0.052) - 0.1] x 2400 = 1570 psi OR ASP = FPP - (0.1 x D) = 3290 - (0.1 x 7272') - 2564 psi 3. Drilling below intermediate casing (7") ASP - FPP - (0.1 x D) - 3293 - (0.1 x 7277') = 2565 psi ATTACHMENT 8 Creoted by brnlchael FOI'; ¥ Johnson D~2te plotted: 20--Jun--2Q01 Plot Reference is 2~r Ver~nl~l 1. Cooraln~e~ are is feet reference slot ~24. ~T~e Ve~ol Depths ore refer~ce Estimated RKB4 Phillips Alaska, Inc. Strucfure : CD#Z Well: 24A Field : Alpine Field Loc(~fion : North Slope, AIc~sko Point KOP - 7 EOC Casing PROFILE MD Inc 10822.00 88.00 11114.84 90.13 COMMENT DATA Dir TVD North East 530.57 7231.99 1718.11 -6973.28 332.38 7256.76 1975.09 -7115.54 V. Secl~ Deg/1 O0 4803.81 0.00 5096.57 1.00 Revised TD 15299.68 90.13 332.58 7227.00 5682.89 -9055.90 9281.25 0.00 ATTACHMENT 8 REVISED TD LOCATION 1410' FNL, 24' FEL SEC, 3.3, T12N, R4E Phillips Alaska, Inc. [c .... ~'~"'~':., For: V .,o~,~,-o~ I S,,',,~,,,r,, : CO~ W~,: [ Dote ~tted: 2D-Jun-2001 J P~t Reference ~ 24 Vemion~ll. J Field : Alpine Field Location : North Slope, Alaska [ ~,.~ .....,.,.~ ............ ~ ~2,. j ............................................................................................................................................................................................................... L ~ I <- Wesf (feel) 9900 9600 9300 9000 8700 8400 B 1 O0 7800 7500 7200 6900 6600 6300 6000 5700 5400 I I I I I I I I I I I I I I I [ I I t I I I I J I I I I I J I I ~ 6300 r 6ooo 331.86 AZIMUTH ~v~ 9~81' (TO RgVIS~D TD) ~oo ~Pl~ne of ProposoN~* TRUE 5400 5100 4800 4500 4200 3900 3600 3300 3000 27OO 2400 KOP LOCATION: 92' FNL, 2054' FWL SEC. 3, Tl lN, R4E EOC KOP - 7 Cosing 2100 1800 1500 1200 9OO 600 ATTACHMENT 8 Created by brnichael ]~or: V ,]'ohnBol'l. ] Date plo[ted: 20-Jun--2001 ] Plot Reference is 24 Versionj[11. ] I Coord~tes ere ;n feet reference slot i~24. ] True VerUcel Depths are reference Estimated RKB.i Phillips Alaska, Inc.i Structure: CD#2 Well : 24A Field: Alpine Field Locafion : Nodh Slope, Alaskai 331.86 AZIMUTH 9281' (T0 REVISED TD) ·**Plane of Proposol*~ ~ 6000 .-I-- 6300 ..i.- ~ 6600 "~ 6900 .__ ~ 7200 I--- 7500 I 7800 270O I I I I I I [ 3000 3300 3600 3900 FINAL ANGLE 90.13 DEG [ i i t i 4200 4500 i i i i i i i i i i i i i i i i i i i i 4800 5100 5400 5700 6000 6300 6600 6900 7200 7500 Veri'ical Sec'[ion (feel) -> Azimufh 331.86 with reference 0.00 N, 0.00 E from slot #24 i i i i i i 7800 8100 8400 8700 9000 1~4AI i i ii 9300 9600 MWD/LWD Log Product Delivery Customer Well No Installation/Rig Phillips Alaska Inc. CD2-24PH Doyon 19 LOG Surveys (Paper) Received By: Run No. Scale LWD Log Deliver V1.1, Dec '97 linal Film Dispatched To: Date Dispatche Dispatched By: No Of Prints Ala~ AOGCC 25-Jun-01 Nate Rose No of Floppies RECE JUN Z ] Oil & Gas Co~ "E EI/V · No of Ta VED 2001 e Please sign and return to: Anadrill LWD Division 3940 Arctic BIvd, Suite 300 Anchorage, Alaska 99503 nrosel @slb.com Fax: 907-561-8417 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 June 20,2001 Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Permit to Drill, CD2-24~ Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a permit to drill the horizontal portion of the well CD2-24 past its originally permitted depth. The original permit depth was 13752' MD, and the new planned depth is 15300' MD. Drilling of the horizontal hole extension will begin approximately June 25, 2001. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Application for Permit to Drill CD2-24, dated 16-May-01, Permit No. 50-103-20377 If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. Vern Johnson Drilling Engineer RECEIVED JUN Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL RECEIVED JUN 2, 1 2001 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIOJ~aska Oil & Gas C,(ms. Commission PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill I lb. Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 52' feet Colville River Field 3. Address 6. Properly Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 387212 & ADL 387207 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1806' FNL, 1535' FEL SEC. 2, T11 N, R4E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 96' FNL, 2094' FWL SEC. 3, T11N, R4E, UM CD2-24~ ~)~.. #U-630610 At total depth 9. Approximate spud date Amount 1410' FNL, 24' FEL SEC. 33, T12N, R4E, UM 06/25/2001 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD2- 42 15300' MD 24' W. of Sec 34 feet 177' ~ 500' MD Feet 2560 7227' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 325' feet Maximum hole angle 90.37 Maximum surface 2565 pslg At total depth (TVD) 3293 at psig 7225' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 40# L-80 BTC 2787' 37' 37' 2824' 2400' 480 Sx Arcticset III L & 231 Sx Class G 8.5" 7" 26# L-80 BTC-M 10714' 37' 37' 10751' 7272' 128 sx Class G N/A 4.5" 12.6# L-80 IBT-M 10014' 32' . 32' 10046' 7104' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'-"~ <~- ,~'4 Title Drillin~l Team Leader Date ' Commission Use Only I ') ] See cover letter for Permit Number APl nurrjber _ I Approval date ~' ~"1 ,~ ,-x ] O z- .3 7 ? -I~ I Other requirements · I ' Conditions of appr6var Samples required Yes (""~o ~) Mud Icg r~quired Yes t,"'"'-No ~ Hydrogen sulfide measures Yes ~ Dir''''-''~'- ' ectional survey required ~ No Required working pressure for BOPE 2M 3M 5M 10M 15M 1501t Approved by D Taylor -~-~mo.,-.-.t Commissioner the commission Date Form 10-401 Rev. 7-24-89 S~ bmit in triplicate CD2-24A Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 6-1/8" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips High Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 9.3 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. Alpine formation may be abnormally pressured due to gas injection from CD1-06. Horizontal section may be depleted causing lost circulation Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. b. The depth to the base of freshwater aquifers and permafrost, if present. c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. d. e. g, h, 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. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operation and calculations showing how this value was determined. 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. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. Any additional data required by the Commission to confirm containment of drilling wastes. CD2-24 There are no USDW aquifers in the Coleville !River Unit. Base of Permafrost = 732' TVD (RKB) The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. Types of fluids can be mud, diesel, cement, and water. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated pressure at casing shoe during disposal operations is 1906 psi. See attached calculation page. See attached cementing reports, LOT/FIT reports, and casing reports. NA See attached casing summary sheet and calculation page. DETAILS: CD2-24: Pressure Calculations for Annular Disposal TOC ~9-5/8" 40 lb/fi, L-80 BTC casing @ 2792 fi MD (2372 ft TVD) Pburst = 5750 psi, @ 85%' P~,u~85% = 4888 psi Estimated Top of Cement @ 10 080 ft MD (7068 ft TVD) ¢7" 26 lb/fi, L-80, BTC casing @ 10811 fi MD (7232 fi TVD) Pcollapse = 5410 psi, @ 85%: Pcollapses5% = 4598 psi ~4-1/2" 12.6 Ib/ft L-80 tubing to 10 030 fi MD ASSUMPTIONS,,,; Maximum injection pressure, PApp,e~ = 1500 psi · Maximum density of injection fluid is 12.0 ppg. ° Pore pressure at 9-5/8" casing shoe is 0.4525 psi/fi · Injection gas pressure is 0.1 psi/ft + 2000 psi header pressure CALCULATIONS: Maximum pressure at 9-5/8" shoe: Pmax = PHydrostatlc + PApplied ' PFormatlon Pmax = 12.0 (0.052)(2372)+1500-0.4525 (2372) Pmax = 1906psi Maximum fluid density to burst 9-5/8" casing.: Pburst85% = PHydrostatic + PApplled ' PFormation 4888 = MWr,~ (0.052) (2372) + 1500- 0.4525 (2372) MW,~ax = 36.2 ppg Maximum Fluid Den.s.it¥..to Collapse 7" Casin. g: Pcollapse85% = PHydrostatic + PApplled- PGasGradlent - PHeader 4598 = MWmax (0.052)(7068) + 1500- (0.1)(7068) - 2000 MW,~,,x = 15.8 ppg Casing Detail Well: CD2- 24 9 518" Surface Casing Date: 6/3/0t PHILLIPS aska Inc. ~ A Subsidiary o¢ PHILLIPS PETROLEUM~COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS I Doyon 19 RKB to LDS 36.95 FMC Gen V Hanger 2.40 36.95 Jts 3 to 67 65 Jts 9-5/8" 40# L-80 BTC Csg 2668.49 39.35 Davis Lynch Float Collar 1.50 '2707.84 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 81.29 2709.34 Davis Lynch Float Shoe 1.79 2790.63 ....... 2792.42 ...... ..... ~'D 12 i/4" Surfa~'e H0ie ....... 28'07.0d ............. , , ......... ..... , .............. Run 1 bow spring centralizer on first '12 jts. then one on ,, ,,, jt # 14,16,18,20,22,24,26,28,30,32,34,36,38,40.42,44 , , 46,48,50,52,54,56,58,60,62, & 64 ..... 38 total .... , ......... , .... ............... , LaSt 8 jts. out # 68 to #"75 .... , ,, ,, , ,, , ,, ,,, ,,, ...... ...... , ............... , .......... ,,,,,,,, ......................... ......... .... , , ,,, .... Use'BeSt-o-Life 2000 pipe dope ................. .................................................. Remarks: Up Wt-180 k " ,,,,, Dn Wt-140 k Block Wt - 70 ....... ................. , .................. ........................ ~.upervisor: MickeY/Dale ............................. Phillips Alaska Drilling Cementing Details Well Name: CD2-24 Report Date: 06104/2001 Report Number. 4 Rig Name: Doyen 19 AFC No.: g98D05 Field: Alpine Centrallzem State type used, inten/els covered and spacing Comments: Bow Spring centrallzem - one each on flint 12 Jt~. then one on every other Jt to 120' - total 38 Mud Weight: PV(prlor cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.7 32 16 53 16 Gels before: Gels after. Total Volume Circulated: 42,74,92 9,18,26 Wash 0 Type: Volume: Weight: Comments: Water 40 bbls 8.3 ppg Vlacoelfied wi nut plug Spacer 0 Type: Volume: Weight: Comments: ARCO B45 50 bble 10.5 ppg Lead Cement 0 Type: Mix wtr tamp: No. of Sacks: Weight: Yield: Comments: AS111 70 379 10.7 ppg 4.44 Additives: 30 % DO53, .?0% DO46, 1.5% DO79, 1.5% SOO1,50% D124, 9% DO44(BWOW) rail Cement 0 No. of Sacks: Weight: Yield: Comments: ' Type: Mix wtr tamp: . G 70 235 15.8 ppg 1.1 5 .Displacement 0 i . . '. Rate(before tall at shoe): Rata(tall around shoe): Sir. Wt. Up: 6.5 him 6.5 b/m 180 · ' ~ ': ii 12'RecIprocatIon Reciprocation speed: 140 .! i, ' '" '" '"'' '. 205.3Theoretical Displacement: Actual205.3 Displacement: Str. Wt. In mud: Calculated top of cement: I CP: Bumped plug: I Floats held: SurfaceI Date:614101 YesI Yes Time:04:48 hm F~emarks:Full clrc through out Job - 100 bbls cmt retunm to surface Cement Company: Dowell Rig Contractor: DOYON Approved By: Don Mickey / John Dale Phillips Alaska Drilling Daily Drilling Report AFC No. Date Rpt No Rig Accept - hfs Days Since AcceptJEst: 3 / 3.5 Rig Relase - hrs: 9981305 06/04/2001 4 ~06u/02/2001 12:01:00 Well: CD2-24 Depth (MD/TVD) 2802/2378 Prev Depth MD: 2802 Progress: 0 Contractor:. DOYON Daily Cost $ 88~85 Cum Cost $ 820264 Est Cost To Date $ 850000 Rig Name: Doyon 19 Last Csg: 9 5/8" ~ 2792' I Next Csg: 7" {~ 10,510' Shoe Test: Dperetlon At 0600: Surface check AutoTrak Jpcoming OperaUons: RIH wlAutoTmk. Test Csg - Perform LOT. Drill 8 1/2" hole i~ :: ':. ? ::: t~ul~ .. OATA :: ": :::.'. '0 m~ Lm,~.' ~TA: :..~:i i;:.:.:' :' ': :~;. i: !' :i :':~ :,: ~::.:.:. :' ?.; .i :: ,!! :: ;'. :;;,:ant! t~ITA' .?i, ::; i: i:: '!: ;i:; ~: ;!'~i :. :.:, ;: ;: :'i: :':: ". ,~ ii.'~i :.: :,: i' :;: i ~:::- :.i:" ~ MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL SPUD 2802 N TST 06/04/2001 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL g.6ppg VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 55sqc N SPACE PV/YP SO wm TYPE TYPE TYPE GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 1140 ?/16126 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER 93~ 8.4 06/04/2001 USED - BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN ,.,,;.:;,,.,:.v,., ;:, ...,'.... ;.'..:,.,..,.,.,,;:, ,.., POTABLE WATER mi/30 Tin INJECTION' USED - BBLS ' SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & /'% CD2-42 PER ,.~.~.~.~.~.~.~.~.~ N N E L DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL I'EI~P °F 33 212~ III / / CD2-24 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) iWIND SPEED 3 22.5 1t211 ' 4 Dh LINER SZ RPM 1 RPM I PRESSURE (psi) :WIND DIRECTION 220' " 5'stel I - 1o5o LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F 33.00 4.6% III Water Base Muds 1000 PIT VOL iGPM 2 JETS JETS Fresh Water PHILLIPS 2 280 III IIIII IIIII lOO PERSONNEL Diesel 45 DALLY MUD SPS 1 BIT COST BIT COST Other CONTRACTOR 27 i$17395 III 600 PERSONNEL 0 ITOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $40109 III III III 17~ COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 13 M, III III l II 41s2 PERSONNEL TOTAL 47. , BHA DF.~CRIPTION J i DRILLPIPE DATA I ,~BHA NO ~D ID WEIGHT GRADE Co~INEcTION CLASS 2 LENGTH · BHA LENGTH 5 4.281 19.5 G105 4-112" I.F. DATE LAST INSPECTED: HOURS ON JARS: .TIME" t .'END. [ . ~HOURS "OP$CODE . I. HOLE SECT I PHASE CPS .I . OPERATIONS FR. OM 0000-0000 12:00 AM 03:00 AM 3.00 ClRC SURF Making Hole Clrc and condition for cmt Job 03:00 AM 05:00 AM 2.00 CMT_CSG SURF Making Hole PJSM - cement 9 5/8" csg - Pumped 40 bble vlscoslfled water w/nut plug marker - 5 bbls water - test lines to 2500 pal - drop btm plug - pumped 50 bbls 10.5 ppg Arco Spacer - Mixed & pumped 300 bbls t0.7 ppg lead slurry, observerd nut plug mark ~ shakers - switch over to tall slurry - Mixed & pumped 48 bbls 15.8 ppg tall slurry - drop top plug wi 20 bbls water f/Dowell - switched over to rig pumps & displaced wi 185 bbls 9.6 ppg mud - bumped plug -floats held. ClP ~ 04:40 hrs. 05:00 AM 06:00 AM 1.00 CASG SURF Making Hole L/D cmt head - landing Jt - elevators & long balls 06:00 AM 07:00 AM 1.00 OTHER P1 Making Hole Flush flow line & dlvertar 07:00 AM 11 :iX) AM 4.00 NU_ND PI Making Hole RID dlverter system - Install & test wellhead to 1000 psi - NlU BOP 11:00 AM t2:00 PM 1.00 BOPE Pt Making Hole Install test equipment - held PJSM on tostlng BOPE 12:00 PM 05:00 PM 5.00 BOPE P1 Making Hole Test BOPE - Pipe rams, blind rams, choke manifold valves, kill and choke line valves, floor valves kelly valves on top drive to 250 psi Iow & 5000 psi high - Hydrll to 250 pal Iow - 3500 psi high - accumulator closure test - test gas detectors - wlttnesslng of test waned by Chuck Scheve AOGCC 05:00 PM 05:30 PM 0.50 BOPE P1 Making Hole Pull Test plug & run wear bushing 05:30 PM 06:00 PM 0.50 OTHER Pt Other Pick up elevator balls and 5" dp elevators 06:00 PM 12:00 AM 6.00 OTHER PI Other Pick up 5" drill pipe & rack In derrick162 its picked up2? stds racked27 stds In hole48 its more to pick up. 24.00 Daily Ddlling Report: CD2-24 06/04/2001 Page 1 Supervisor. DON MICKEY / JOHN DALE CASING TEST and FORI~cIAT]ON ~NTEGR~TY TEST Well Name: CD2-24 Date: 6/5/01 Supervisor: D. I~ickey __ [] Initial Casing Shoe Test Reason(s) for test: [] Formation Adequacy for Annular injection F~ Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8", 40#, L-S0, BTC CSG 'l~ * ~o__.~2 ~ ~ Casing Setting Depth: 2,792' TIVID Hole Depth: 2,822'TIVID 2,378' TVD 2,397' TVD Mud Weight: 9.8 pp~ ~ Length of Open Hole Section: 30 EMW = Leak~off Press. + Mud Weight = 800 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,378' E~¢W for open ho~e section = 16,I ppg Used cement unit NO Pump outpul = 0.0997 bps Fluid Pumped = %1 bbs Rig pum~o u~ #2 .F u d Bed Baqk ~ ! ¢bb s NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA ~INUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE i 1.0 ~ 30psi ~ i = 2stks ~ 1O0p. si , 2.0 - 40~s~ , , , 4stks , 230~s~ [ 3.0 ~ 7Opsi, ~~ [ 6stks i 420ps~ I 4,0 t 110psis,__ I 8stks ~ 650psi I 7.0 I 430psi~O ~14stksI1140psi I 110 i 800psi ~G~ I22stks ~1840psi j i i ~ !26stks ]2,27~si i 0~0rnn i ~ ~}00e:~ i i 4,0m~n j ~ 2500 F-cT:aa-:--] ............. ?-~-~;---x F-'a%';;'F;-] .............. 4.0m~ i i 660psi ii ~0mh i ! 2,50O~si i 70mn ~ ~ ~Ops~ ~ ~ 150rain ' ' 2490psi 8.0rn~n~ : ~0~s~ : ~ 20.0mn ~ ~ 2,490ps~ NOTE~ TQ CLEAR DATA~ HiGHLiGHT AND PRESS THE DBLET~ K~Y Mr~diaed by Scz~tt Reynolds CASING TEaT and FORMATION MTBGR~TY TEST Well Name: CD2.~4 Date', 8/~8181 Supervisor: ~ initial Casing Shoe Test Reeson(s) for test: ~ Formation Adequ¢cy fo~ Annula¢ ~njection ~] Deep %est: Open Hole Adequacy for H~her Mud Weight Casing S~ze and Descapt~on: ~818" 4¢¢ b88 8TO 08~ X 7" 28¢ L-88 BTC.~OD Cestng Setting Depth; Hole Depth; EMW = + Mad Weight s 525 ~si ~ + 9,8 0052 x TVD o,o52 × 2,3?8' ~CASINGT LOT SHuTTSSTIN TfleE ~; : LEAK~OFF DATA ~PHILLIP8 Alaska, Ir~c. TEST DATA { 10.0 sr ' Modified by Scott Reynolds Casing Detail Well: CD2,,24 ~ntermedC, ate Caein~ Date: 6/19/01 ARCO Alaska, Inc, Subsidiary of Atlal Subsidiary of Atlantic Richfietd Company COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKB to LDS FMC 11" X 7" Hanger 7" 26# L-80 BTCM Csg 7" Davis Lynch Float Coltar 7" 26# L-80 BTCM Csg T' Davis Lynch Float Shoe 8-1/2" OPEN HOLE stlaight blade centralize pel}t spiral b;~de centralize!' evew othe'jt #i95,-#261 Total 52 positive centralizers Use Besbo-Life 2~e dope LENGTH 35,20 2,24 10686.95 1.38 83.90 1.73 F~¢~tn¢:,¢'k:¢: Up Wt = 4©Ok Dn b$4~ = 110,~ B/ock Wi= 75k Supervisor: David Burley Phillips Alaska Drilling Cementing Details Well Name: CD2-24 Report Date: 06120/2001 Report Number. 20 Rig Name: Dc ton 19 AFC No.: ggSD05 F~eld: Alpine Casing Size Hole Diameter:, Anglo thru KP, U: Shoe Depth: I LC Depth: I % washout: I Centrallzem State type used, Intervals covered and spacing Comments: 52 Total 18 8-3/8" straight blade RoSco centrallzem 1 per Joint fH-18.1 eplral blade Centralizer every other Joint #195-261. Mud Weight: PV(pdor cond): PV(after cond): I YP(pdor cond): YP(after cond): Comments: 10.1 10 0I 16 15 Gels before: Gels after. Total Volume Circulated: 5/7/9 5/7/9 1280 bbls Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 bbls 8.5 Spacer 0 Type: Volume: Weight: Comments: ARCO B45 50 12.5 Load Cement 0 Type: I Mix wtr tamp: No. of Sacks: I Weight: Yield: Comments: I Additives: i . . . Additives: r0.2 ~D046, 0.25%D065, 0.25~D800, 0.18%D167 )laplacement 0 Rata(before tail at shoe): Rata(tall around shoe): Str. Wt. Up: · ': i .6bpm 8bpm .~0mments: 'r ' . '0Reciprocati°n length: 0Recipr°cati°n speed: Str. Wt.110Down: Theoretical Displacement: Actual Displacement: Str. Wt. in mud: Calculated top of cement: I CP: Bumped plug; Floats held: I0080' with 60% excessI Date:6120101 yes yes Time:0600 o {emarks:Staged pumps up to 6 bpm and conditioned mud with 95% retume for first 600 bbls. Incresed rate to 7.5 bpm last 680 bbls pumped with 90 '~ returns. )lsplaced cement at 6 bpm for first 327 bbls with full returns, Increased rate to 8 bpm for last 83 bbls with 90 % returns. Cement Company: Rig Contractor: Approved By: Dowell DOYEN DAVID P. BURLEY CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2,24 Date: 6120R1 Supervlaor: Reynolda/Wlttry Reason(e) for teat: [] Initial Casing $hoe Teat [] Formation Adequacy for Annular Injection r'l Deep Teat: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9,618" 40~ ,L.-60 BTC CeO X 7" 26# L-60 BTC.MOD C$G Cueing Setting Depth: 2,r792' TMD Hole Depth: 10F08.0' TMD 7r068' 'rVD EMW = Mud Weight: 9,6 ppg Leak~ff Press, + Ml~d Weight 0.052 x TVD Length of Open Hole 8eotlon: 7~288' · 52~'p~1 + 9.6 0.052 x 2,378' EMW for open hole section = 13.8 ppg Uud cement unit Rio Dump used Pump output - bbll pumped Fluid Pumped n 10.0 bbls Fluid Bled Ber.,k · %:~2-~;~3~;i!3~'.'~;~ ?GO psi LEAK-OFF TEST ""dP"'CAalNG TEST --'~ LOT SHUT IN TiME '-*--CASING TEaT SHUT IN TiME ~TIME LINE 600 400 psi 300 p~l ~'00 p~ 0 Blrrele PHILLIP8 Alaoka, Ino. A S~bi~i/y o~ PHILLIPS PrrRoL~UM CO~PANY LEAK-OFF DATA MINUTII FOR ~.oT- BaLe ::::!:..E:::', 2.0 4,0 ................ ,~';d ..... , ............... -~ ..... ..--.....----...--.--.....---.., ..,..6_..o...mj.n..., ..Z_..o...rnj.r'.... _8:.o..?i_n..., __9:.o...m. Ln..., _ j_o.:.o...mj..n.., CASING TEST DATA M~UTII FOR glo TIlT ITROKli PRIIIURI ............... .o...~ ...... .o.g~.! ..... --.,,,.e.,.4. i,,,...~ --i....--.Ill1--1 ~llll.--IIl--! lliell~J~nllilll, --.lUl. H.Illal I--IIIII--IIIIIB'I ~l. IlUlllllli, Iillllil~'B .lWil. ~........ ....... --...............--.............. --....,.N,,.l.,,m.~ .,.........,..... . ,, ....... ,,,,, ~ ,,,.~ NII.IIH.."..'' ......'.....'..e~.'' .... ''.''e'~'''''-- .... '" . .,...."~.. "'"' a"' --....lN..'... ......--.....--~.. .... ....................... m.,,,l.l.m.e..,lM, .,e,,...,,.,,,,...,,....,,..---.--".--'------. ,.............--.--.....--...... I. llle.~.,,a.,,.,~· .,I ,,,..,~.... ,,,.... --,,,....--I...'N, '--...'"--.''"'.~ --.....--.....--.--.....--...... --...~,,--..,....., ,~.....--......, I I II IHUT IN Till IHUT IN PRISlUll Hi ummllmlllllfllmill Ill~lllllUl ,llmil l llilMll mi lmm _..o.:9_m. Ln' ................ : .... .o..~.s.[ ..... 1.0 rain _..3.:.0_.m.i..n. .................................. ....4.:.o...m.J..n._; ............................... 5.0 min · ..~..~%f,~- ............................... _..9.:.o_.m.i..n. .................................... 10.0 man _j.5.._o_..mj..n_ ............................... _.2..o...o..mL,. ................................. . . .2. .5. ._ O_ .mj. .n_ ................................ ..3..o.._o_...m.i..n_ ~ .............................. Modified by scott Reynolds Phillips Alaska, Inc. CD#2 24A slot #24 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 24A Version#ii Our ref : prop4407 License : Date printed : 19-Jun-2001 Date created : 16-Jan-2001 Last revised : 19-Jun-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 I 42.976 Slot location is n70 20 19.348,w151 2 27.759 Slot Grid coordinates are N 5974552.311, E 371705.811 Slot local coordinates are 1804.85 S 1533.23 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. CD~2,24A Alpine Field,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 10822.00 88.00 330.37 7231.99 10900.00 88.57 330.90 7234.32 11000.00 89.30 331.59 7236.19 11100.00 90.03 332.27 7236.78 11114.84 90.13 332.38 7236.76 11500.00 90.13 332.38 7235.86 12000.00 90.13 332.38 7234.69 12500.00 90.13 332.38 7233.53 13000.00 90.13 332.38 7232.36 13500.00 90.13 332.38 7231.20 14000.00 90.13 332.38 7230.03 14500.00 90.13 332.38 7228.86 15000.00 90113 332.38 7227.70 15299.68 90.13 332.38 7227.00 15299.70 90.13 332.38 7227.00 PROPOSAL LISTING Page Your ref : 24A Version#ii Last revised : 19-Jun-2001 R E C T A N G U L A R Dogleg Vert C 00 R D I N A T E $ Deg/100ft Sect 1718.11 N 6973.28 W 0.00 4803.81 KOP - 7" Casing 1786 06 N 7011 51 W 1.00 4881.76 1873.71N 7059.60W 1.00 4981.74 1961.95N 7106.65W 1.00 5081.73 1975.09N 7113.54W 1.00 5096.57 EOC 2316.35N 7292.13W 0.00 5481.72 2759.35N 7523.96W 0.00 5981.70 3202.36N 7755.79W 0.00 6481.67 3645.36N 7987.62W 0.00 6981.65 4088.36N 8219.45W 0.00 7481.63 4531.37 N 8451.29 W 0100 7981.61 4974.37N 8683.12W 0.00 8481.59 5417.38N 8914.95W 0.00 8981.57 5682.89N 9053.90W 0.00 9281.23 Revised TD 5682.92N 9053.91W 0.00 9281.26 CD2-24 TD Pt Rvsd 13-J%u%-01 All data is in feet unless otherwise stated. Coordinates from slot #24 and TVD from Estimated RKB (52.00 Ft above mean sea level). Bottom hole distance is 10689.66 on azimuth 302.12 degrees from wellhead. Total Dogleg for wellpath is 2.93 degrees. Vertical section is from S 0.00 W 0.00 on azimuth 331.86 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD~2,24A Alpine Field,North Slope, Alaska PROPOSA~L LISTING Page 2 Your ref : 24A Version#il Last revised : 19-Jun-2001 Comments in wellpath ==================== MD TVD Rectangular Coords. Comment 10822.00 7231.99 1718.11N 6973.28W KOP- 7" Casing 11114.84 7236.76 1975.09N 7113.54W EOC 15299.68 7227.00 5682.89N 9053.90W Revised TD 15299.70 7227.00 5682.92N 9053.91W CD2-24 TD Pt Rvsd 13-Jun-01 Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a V231.99 1718.11N 6973.28W n/a 7231.99 1718.11N 6973.28W 9 5/8" Casing n/a 7231.99 1718.11N 6973.28W 10822.00 7231.99 1718.11N 6973.28W 7" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised CD2-24 TD Pt Rvsd 13 362750.000,5980387.000,0.0000 7227.00 5682.92N 9053.91W 18-Jun-2001 Phillips Alaska, Inc. CD#2 24A slot #24 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 24A Version#Il Our ref : prop4407 License : Date printed : 19-Jun-2001 Date created : 16-Jan-2001 Last revised : 19-Jun-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on nT0 20 37.100,w151 i 42.976 Slot location is n70 20 19.348,w151 2 27.759 Slot Grid coordinates are N 5974552.311, E 371705.811 S10t local coordinates are 1804.85 S 1533.23 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. CD~2,24A Alpine Field,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S 10822.00 88.00 330.37 7231.99 1718.11N 6973.28w 10900.00 88.57 330.90 7234.32 1786.06N 7011.51W 11000.00 89.30 331.59 7236.19 1873.71N 7059.60w 11100.00 90.03 332.27 7236.78 1961 95N 7106.65W 11114.84 90.13 332.38 7236.76 1975.09N 7113.54W 11500.00 90.13 332.38 7235.86 2316.35N 7292.13W 12000.00 90.13 332.38 7234.69 2759.35N 7523.96W 12500.00 90.13 332.38 7233.53 3202.36N 7755.79W 13000.00 90.13 332.38 7232.36 3645.36N 7987.62W 13500.00 90.13 332.38 7231.20 4088.36N 8219.45W 14000.00 90.13 332.38 7230.03 4531.37N 8451.29W 14500.00 90.13 332.38 7228.86 4974,37N 8683.12W 15000.00 90.13 332.38 7227.70 5417.38N 8914.95W 15299.68 90.13 332.38 7227.00 5682.89N 9053.90W 15299.70 90.13 332.38 7227.00 5682.92N 9053.91W PROPOSAL LISTING Page Your ref : 24A Version~ll Last revised : 19-Jun-2001 GRID C 0 0 R D $ G E 0 Easting Northing C 0 0 364763.14 5976387.91 n70 364726.07 5976456.49 n70 364679.47 5976544.94 n70 364633.92 5976633.95 n70 364627.26 5976647.21 nT0 364454.48 5976991.41 n70 364230.19 5977438.23 n70 364005.90 5977885.05 n70 363781.61 5978331.88 n70 363557.31 5978778.70 n70 363333.02 5979225.52 nT0 363108.73 5979672,35 n70 362884.44 5980119.17 nT0 362750.01 5980386.98 nT0 362750.00 5980387.00 n70 GRAPHIC RDINATES 20 36.20 w151 5 51.49 20 36.87 w151 5 52.61 20 37.73 w151 5 54.02 20 38.60 wlS1 5 55.40 20 38.73 w151 5 55.60 20 42.08 w151 6 00.83 2046.43 w151 6 07.62 2050.79 wlS1 6 14.41 2055.14 w151 6 21.20 2059.50 w151 6 27.99 21 03.85 w151 6 34.78 21 08.20 w151 6 41.57 21 12.56 w151 6 48.37 21 15.17 w151 6 52.44 21 15.17 w151 6 52.44 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot %24 and TVD from Estimated RKB (52,00 Ft above mean sea level). Bottom hole distance is 10689.66 on azimuth 302.12 degrees from wellhead, Total Dogleg for wellpath is 2.93 degrees. Vertical section is from S 0.00 W 0.00 on azimuth 331.86 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD~2,24A Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 24A Version#il Last revised : 19-Jun-2001 Comments in wellpath MD TVD Rectangular Coords. Comment 10822.00 7231.99 1718.11N 6973.28W KOP - 7" Casing 11114.84 7236.76 1975.09N 7113.54w EOC 15299.68 7227.00 5682.89N 9053 90W Revised TD 15299.70 7227.00 5682.92N 9053.91W CD2-24 TD Pt Rvsd 13-Jun-01 Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 7231.99 1718.11N 6973.28W n/a 7231.99 1718.11N 6973.28W9 5/8" Casing n/a 7231.99 1718.11N 6973.28W 10822.00 7231.99 1718.11N 6973.28W 7" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised CD2-24 TD Pt Rvsd 13 362750.000,5980387.000,0.0000 7227.00 5682.92N 9053.91W 18-Jun-2001 Phillips Alaska, Inc. CD#2 24A slot ~24 Alpine Field North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 24A Version#Ii Our ref : prop4407 License : Date printed : 19-Jun-2001 Date created : 16-Jan-2001 Last revised : 19-Jun-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 19.348,w151 2 27.759 Slot Grid coordinates are N 5974552.311, E 371705.811 S10t local coordinates are 1804.85 S 1533.23 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. CD#2,24A Alpine Field,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 10822.00 88.00 330.37 7231.99 1718.11N 6973. 10900.00 88 57 330.90 7234.32 1786.06N 7011. 11000.00 89.30 331.59 7236.19 1873.71N 7059. 11100.00 90.03 332.27 7236.78 1961.95N 7106. 11114.84 90.13 332.38 7236.76 1975.09N 7113. 11500.00 90.13 332.38 7235.86 2316.35N 7292. 12000.00 90.13 332.38 7234.69 2759.35N 7523 12500.00 90.13 332.38 7233.53 3202.36N 7755. 13000.00 90.13 332.38 7232.36 3645.36N 7987. 13500.00 90.13 332.38 7231.20 4088.36N 8219. 14000.00 90.13 332.38 7230.03 4531.37N 8451. 14500.00 90.13 332.38 7228.86 4974.37N 8683. 15000.00 90.13 332.38 7227.70 5417.38N 8914. 15299.68 90.13 332.38 7227.00 5682.89N 9053. 15299.70 90.13 332.38 7227.00 5682.92N 9053. PROPOSAL LISTING Page 1 Your ref : 24A Version~ll Last revised : 19-Jun-2001 R E C T A N G U L A R Vert Ellipse Semi Axes Minor C O 0 R D I N A T E S Sect Major Minor Vert. Azi. 28W 4803.81 513.76 52.42 64.12 283.71 51W 4881.76 521.64 52 53 64 96 284 06 60W 4981.74 525.26 52.66 66.05 284.49 65W 5081.73 528.80 52.80 67.14 284.91 54W 5096.57 529.33 52.82 67.30 284.98 13W 5481.72 543.23 53.43 71.49 286.56 96W 5981.70 561.87 54.38 76.92 288.50 79W 6481.67 581.13 55.46 82.34 290.32 62W 6981.65 600.95 56.63 87.76 292.02 45W 7481.63 621.29 57.87 93.18 293.61 29 W 7981.61 642.09 12 W 8481.59 663.32 95W 8981.57 684.92 90W 9281.23 698.05 91W 9281.26 698.05 59.14 98.60 295.10 60.43 104.01 296.50 61.73 109.43 297.82 62.50 112.67 298.57 62.50 112.67 298.57 POSITION UNCERTAINTY SUMMARY ============================== Depth Position Uncertainty From TO Survey Tool Error Model Major Minor Vert. 0 8715 ARCO (H.A. Mag) User specified 401.15 43.77 46.27 8715 10822 ARCO (H.A. Mag) User specified 818.76 52.42 64.12 10822 15300 ARCO (H.A. Mag) User specified 698.05 62.50 112.67 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. Ail data is in feet unless otherwise stated. Coordinates from slot ~24 and TVD from Estimated RKB (52.00 Ft above mean sea level). Bottom hole distance is 10689.66 on azimuth 302.12 degrees from wellhead. Vertical section is from S 0.00 W 0.00 on azimuth 331.86 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD#2,24A Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 24A Version#Il Last revised : 19-Jun-2001 Comments in wellpath ==================== MD TVD Rectangular Coords. Comment 10822.00 7231.99 1718.11 N 6973.28 W KOP - 7" Casing 11114.84 7236.76 1975.09 N 7113.54 W EOC 15299.68 7227.00 5682.89 N 9053.90 W Revised TD 15299.70 7227.00 5682.92 N 9053.91 W CD2-24 TD Pt Rvsd 13-Jun-01 Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 7231.99 1718.11N 6973.28W n/a 7231.99 1718.11N 6973.28W 9 5/8" Casing n/a 7231.99 1718.11N 6973.28W 10822.00 7231.99 1718.11N 6973.28W 7" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised CD2-24 TD Pt Rvsd 13 362750.000,5980387.000,0.0000 7227.00 5682.92N 9053.91W 18-Jun-2001 Phillips Alaska, Inc. CD#2 24A slot #24 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 24A Version#il Our ref : prop4407 License : Date printed : 19-Jun-2001 Date created : 16-Jan-2001 Last revised : 19-Jun-2001 Field is centred on nT0 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is nT0 20 19.348,w151 2 27.759 Slot Grid coordinates are N 5974552.311, E 371705.811 Slot local coordinates are 1804.85 $ 1533.23 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-11984'>,,35,CD#2 MWD <0-9507'>,,42PH,CD~2 MWD <8480 - 13138'>,,42,CD#2 MWD <8715 - ???'>,,24,CD#2 MWD <0-10054'>,,24PH,CD~2 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 17-May-2001 8817.4 10822.0 10822.0 27-May-2001 5423.4 10822.0 10822.0 31-May-2001 5444.6 10822.0 10822.0 18-Jun-2001 0.0 10822.0 10822.0 18-Jun-2001 1136.3 10822.0 10822.0 Attachments CC: CD2-24 Well File / Sharon AIIsup Drake Chip AIvord Cliff Crabtree Nancy Lambert Lanston Chin ATO 1530 ATO 868 ATO 848 Anadarko - Houston Kuukpik Corporation e-mail: Tommy Thompson~anadarko.com ORiGIr'XAL SENT BY: 9- 4- 1 ; l:52PM : PHILLIPS AK INC-, 907 276 7542:# 2/ 4 RECEIVED BAKER HUGHES INTEQ SEP 4 2001 ALPINE CD2-24 Measured Angle Azimuth TVD-FIKB TVD SvY# Depth Tie-In 0.00 1 114,00 2 290.00 3 383,00 4 474.00 5 564.00 6 655.00 deg deg fl Subsea fl ft 0.00 0.00 0,00 -52.00 371705.81 5974552,31 0.130 0.00 114,00 62.00 371705.81 5974552.31 0.26 233.58 290.00 238.00 371705.49 5974,552,08 0.60 259,77 383,00 331,00 371704.83 5974551.88 1,62 277.25 473.98 421,98 371703.09 5974551.99 2,78 273.90 563.91 511,91 371699,66 5974552.35 4.03 277.14 654.75 602,75 371694,29 Al~ka State Plane X di',~,;!,:~.~ N/-S E/-W 0.00 0.00 0,00 0.00 -0.24 -0.32 -0,45 -0,97 -0,37 -2,72 -0.06 -6.15 0.49 -11.53 7 744,00 8 833,00 9 922,00 10 1013,00 11 1109,00 12 1204.00 13 1300.00 14 1397.00 15 1491.00 16 1587.00 17 1682.00 18 1778.00 19 1872,00 20 1968, 00 21 2063.00 22 2159,00 23 2254,00 24 2349.00 25 2444,00 26 2539,00 27 2634,00 28 2735.61 29 2907,00 3O 3002.00 31 3098.00 32 3194.00 33 3289.00 34 3385,00 35 3480.00 36 3575,00 37 3670.00 38 3765.00 39 3860.00 40 3956.00 41 4051.00 42 4146,00 43 4241,00 44 4336,00 45 4432.00 46 4527.00 47 4622.00 48 4717.00 49 4813.00 50 4908.00 51 5003.00 52 5098.00 4.77 279.73 743.49 691,49 371687,56 5974554.12 5,20 282,56 832.15 780.15 371680.00 5974555.75 5.95 284,58 920,73 868.73 371671.64 5974557,93 8.21 283.48 1011.03 959,03 371660.80 5974560,81 11.66 283-19 1105.57 1053.57 371644.75 5974564.90 14,89 283.62 1198.02 1146,02 371623.63 5974570.32 16.72 283.82 1290,39 1238.39 371598,34 5974576.95 19.56 282.10 1382,56 1330.56 371569.03 5974584.19 23.33 278,93 1470.04 1418.04 371535.36 5974590.95 1.50 -18,28 3.00 -25.86 5.04 -34.27 7,74 -45,15 11,56 -61,27 16.62 -82,48 22.82 -107.88 29.56 -137,31 35.75 -171,10 28,21 277,04 1556.47 1504.47 371494.14 5974597.38 41.49 -212.42 32,45 276.17 1638.45 1586,45 371446,60 5974603,68 46,98 -260.07 36.68 275.48 1717.48 1665,48 371392.53 5974610,10 52,49 -314.24 41,49 274.52 1790,43 1738,43 371333.61 5974616,24 57.63 -373.26 46.40 275.15 1859,53 1807,53 371267.36 5974622.99 63.26 -439.62 50.33 276,11 1922.63. 1870.63 371196.85 5974631,16 70.24 -510,27 52,t5 278.06 i982,73 1930.73 371122.75 5974641.66 79,49 -584.54 52.44 277,65 2040.84 1988,84 371048,48 5974653.19 89.76 -659.00 52,83 277.58 2098.49 2046,49 370973,83 5974664,46 99,77 -733.83 52.61 277.74 2156.03 2104.03 370899.10 5974675.80 109,84 -808.75 5,?,,64 278,98 2213.70 2161,70 370824.61 5974688.04 120.82 -883.44 51.38 279.26 2272.18 2220,18 370750.91 5974701.15 132.68 ,957.36 50,71 278,35 2336.06 2284,06 370673.05 5974714.56 144,78 -1035.45 50.86 279.83 2444,65 2392.65 370542.,,50 5974737.72 165.73 -1166.37 50,66 279.13 2504,88 2452.88 370470.25 5974751,04 177,83 -1238,84 50.70 279.04 2565,71 2513,71 370397.13 5974764.01 189.56 -1312.18 50,63 277.23 2626,56 2574.56 370323.83 5974775,75 200,06 -1385,68 50,82 278,07 2686-70 2634.70 370251:12 5974786,77 209.85 -1458,56 51.06 277.48 2747,19 2695.19 370177.45 5974798,10 219,94 -1532,42 50.82 276.96 2807.05 2755.05 370104.45 5974808,61 229,21 -1605.60 50,77 277.40 2867.10 2815.10 370031.58 5974819,04 238.41 -1678,64 49,60 276.72 2927.93 2875,93 369959,33 5974829,24 247,38 -1751,05 49.65 277,22 2989,47 2937.47 369887.66 5974839.23 256.16 -1822.89 48,~,4 276.28 3051.87 2999,87 369816.68 5974848.66 264.59 -1894.03 48,26 276.37 3115,79 3063.79 369745,65 5974857,95 272,48 -1965,21 48,28 276.61 3179.03 3127.03 3696'7'5.35 59'74867.15 280.49 -2035,66 48,38 276.56 3242.18 3190.18 369605.01 5974876.48 288.63 -2106.15 48.40 276,94 3305.27 3253.27 369534.63 5974886.02 296.98 -2176,69 48.39 276.19 3368.35 3316,35 369464,22 5974895.33 305.10 -2247.26 48.04 277,73 3432,32 3380.32 369393.33 5974905.20 313,77 -2318.31 48.10 278,52 3495.80 3443.80 369323,$5 5974916.37 323.76 -2388.27 48,11 279.00 3559.24 3507.24 369253,85 5974928.32 334.53 -2458,16 48.14 278.99 3622,65 3570.65 369184.19 5974940.56 345,59 -2528,03 47.98 278.68 3686.82 3634.82 369113.83 5974952.72 356,56 -2598.59 48,00 280.11 3750,40 3698.40 369044.40 5974965.41 368.08 -2668.23 47.98 279.34 3813.98 3761.98 368975.05 5974978.51 380,00 -Z737,80 48,04 279,01 3877.53 3825.53 368905.55 5974990.95 391.26 -2807.51 VSeot. Plane = 331,86 DLS Vel. Sec dog/100 ft fl 0.00 0.00 0,00 0.00 0,15 0.28 0.41 o,g0 1~17 2.64 1,30 6.09 1.39 11.48 0.86 18.31 0.56 26.03 0.87 34,63 2.49 45,79 3,59 62.28 3,40 84,00 1.91 110,02 2,98 140,10 4.19 174.4Z 5,15 216.14 4.4.9 264.09 4.43 318,50 5.16 377.66 5,13 ,444.15 4.21 515,07 2.47 589,91 0.46 865,07 0.41 740.57 0.27 8t6.16 1,04 891,65 1,35 966~51 0.96 1045.52 0.67 117R.09 0.57 1251,54 0.08 1325,79 1,46 14,00,04 0.71 1473,58 0.54 1548.12 0.49 1621,88 0.36 1695,48 1,35 1768.44 0,40 1840.80 1,66 1912,41 0,07 1984,00 0,19 2054,87 0.11 2125.81 0.30 2'196,82 0.59 2267.83 1.25 2339,40 0,62 2410.07 0,38 2480,78 0,03 2551,51 0,29 2622,91 1,12 2693,48 0,60 2764,O4 0.27 2834.63 ~- g- I ' l'OLJl~ ' I~MILLII~ Ail 1l~3~' DU! Z/~3 /Dc~Z,~ O! ~ 53 5193.00 54 5288.00 55 5384.00 56 5479.00 57 5574,00 58 5670,00 59 5765.00 60 5860.00 61 5956.00 62 6051.00 63 6146.00 64 6242.00 65 6337.00 66 6432.00 67 6526,00 68 6621.00 69 6717.00 7O 6812.00 71 6907.00 72 7002.00 73 7097.00 74 7192.00 75 7287.OO 76 7382.00 77 7478.00 78 7573,00 79 7888.00 8O 7763.00 81 7858.00 82 795~.00 83 8048.00 84 8144.00 85 8239.00 86 8335.00 87 6430,00 88 8525.00 89 8620,00 90 8715.00 91 8809.00 92 8904.00 93 8999.00 94 9031.00 95 9095,00 96 9190.00 97 9285.00 98 9380,00 99 9474,00 100 9569,00 101 9664.00 102 9759.00 103 9855,00 104 9950.00 105 10045.0O 106 10141.00 107 10236.00 108 10331.00 109 10426,00 110 10521.00 1tl 10816.00 112 10711,OO 48,02 278.44 3941,06 3889.06 368835.93 5975002.84 401.98 -2877,32 47.98 277.85 4004,63 3952~3 368766.23 5975014,02 411.98 -2947.21 48.03 276.81 4068.86 4016.86 368695.64 5975024.32 421.08 -3017.97 48.05 276.95 4132.38 4080.38 368625.66 5975033.96 429.54 -3088.11 48.07 277.64 4195,87 4143.87 368555.73 5975044.12 438.52 -3158.20 48.07 277.63 4280.02 4208.02 368485,12 5975054.80 448.01 -3228.99 48.10 278.14 4323.49 4271.49 368415.28 5975065.68 457.70 -3299.01 48.00 277.27 4386,99 4334~9 368345.44 5975076.33 467.18 -3369.02 48,09 277.84 4451.17 4399.17 368274.84 5975086,92 476.56 -3439.80 48.00 276.48 4514.69 4462.69 368204.91 5975096.90 485.37 -3509.89 48.22 276.59 4578.12 4526.12 368134.80 5975106.14 493,42 -3580.15 48.41 278.53 4641.97 4589.97 368063.92 5975116.77 502.85 -3651.22 4~!.36 278.96 4705,06 4653.06 367993.92 5975128.75 513.65 -3721.41 48.35 277.30 4768.19 4716.19 367923,83 5975139.98 523.69 -3791.69 48.37 277.86 4830.65 4778.65 367854.36 5975150.42 532.96 -3861.32 48.33 277.41 4893.78 4841.78 387784.18 5975161.04 542.39 -3931.68 48,38 278.99 4957.58 4905.58 367713,37 5975172,47 552.62 -4002.68 48.30 279.93 5020.73 4968.73 367643.58 5975185.31 564.28 -4072.69 48.31 280.64 5083.92 5031.92 367574.01 5975199.16 576.95 -4142.48 48.29 279.49 5147.11 5095.11 367504.40 5975212.73 589.34 -4212.32 48.00 279.09 5210.50 5158.50 367434.78 5975225,33 600.77 -4282.15 48,06 279.78 5274.03 5222.03 367365,31 5975238.08 612.35 -4351.83 48,04 279.81 5337.54 5285.54 367295,91 5975251,28 624,37 -4421.45 48.03 279.72 5401.06 5349.06 367226.51 597S264.43 636.35 -4491.07 48.05 279.74 5465,25 5413,25 367156.37 5975277.69 648.41 -4561.43 48,07 279,28 5528.74 547G.74 367066,89 5975290.54 660,09 -4631.12 48,02 277,06 5592.26 5540.26 367017,15 5975301.76 870.13 -4701.04 47,97 276.25 5655,84 5603.84 366947A9 5975311.12 678.31 -4771.16 48,06 276.14 57t9.38 5667.38 366877,13 59753~9,92 685.93 -4841.3~ 48.01 277.11 5782.91 5730.91 366807.12 5975329.26 694.08 -491t.5~ 48,14 277.93 5848.38 5794.38 366737,22 5975339.69 703,33 -4981.60 47.97 278.31 5910,55 5858.55 366666.72 5975350.97 713.41 -5052,29 48.01 278.37 5974.13 5922.13 366597.07 5975362.39 723.65 -5122.13 48,07 279,21 6038.32 5986.32 366526172 5975374.49 734.56 -5192.67 48.07 279,61 6101.80 6049.80 366457.21 5975387.22 746.12 -5262,40 48.09 279,80 6165.27 6113.27 366387,75 5975400.31 758.03 -5332,08 48.09 279.03 6228.73 6176,73 366316.21 5975413.05 769.60 -5401.82 48.09 278.29 6292.18 6240.18 366248.52 5975424.87 780.24 -5471.71 49.36 278.57 6354.19 6302.19 366178.83 5975436.41 790.60 -5541.59 49.53 279,02 6415,96 6363.96 366107.70 5975448.65 801,64 -5612.92 49.54 282.49 6477,62 6425.62 366036.96 5975463.33 815.12 -5683,9t 49.76 283.42 6498.34 6446.34 366013.29 5975469.20 820.59 -5707.68 50,69 284,55 6539,29 6487,29 365965,77 5975481.89 832.48 -5755.40 53.44 288.68 6597.70 6545.70 365894.40 5975504.56 853.94 -5827.15 55.06 289.83 6653,20 6601.20 365822.07 5975531.22 879,37 -5899.93 55.66 290.82 6707,20 6655.20 365749,25 5976559.60 906,52 -5973.22 57.07 293,66 8759,28 8707.28 385677.35 5975590,45 936,15 -6045.64 57.58 293,98 6810,57 6758.57 365604,76 5975623.98 968.45 -6118.80 57.56 295.59 686t.51 6809.51 365532.55 $975658,81 1002.06 -6191.59 57.50 296,15 6912.51 6860.51 365461.04 5975694.99 1037.03 -6263.71 58.76 298.44 6963.21 6911.21 365389.25 5975733.60 1074.42 -6336.15 61.25 300.66 7010,70 6958.70 365318.40 5975775.39 1115.01 -6407,70 65,24 305,21 7053,48 7001,48 365248,07 5975822,73 1161.16 ,647B.82 67.85 308.43 7091.69 7039.69 365178.51 5975876.69 1213,94 -6549.29 70.74 312.15 7125.29 7073.29 365111,76 5975935.29 1271.41 -6617.03 73.92 314.73 7154.12 7102.12 365047.13 5975998.62 1333,65 -668~73 76,72 317.38 7178.20 7126.20 364984,51 5976065,85 1399.81 -6746,48 79.35 320.39 7197.90 7145.90 364924.61 5976136.88 1469.82 -6807.57 82.46 32S.40 7212.02 7180.92 364860.34 5976212.61 1544,61 -6864.12 84.13 327.57 7224.01 7172,01 364818.59 5976292.13 1623.27 -6916,21 0.45 2905.26 0.46 2975.86 0.81 3047.20 0.11 3117.83 0.54 3188.46 0.01 3259.9O 0.40 3330.59 0.69 3401,25 0.45 3472.63 1.07 9643.27 0.25 3613.97 1,52 368~,65 0.34 3756.67 1.31 3827.66 0,45 3897,90 0.36 3968.89 1.23 4040.62 0.74 4111,57 0.56 4182,46 0,90 4253,34 0.44 4324.08 0,54 4394.69 0.03 4465.32 0.07 4535.92 0.03 4607.28 0.36 4677.92 1.74 4748.56 0.64 4819.13 0,13 4889.71 0.76 4960,3~ 0.66 5031.00 0,34 5102.41 0.06 5172.99 0,65 5244,37 0,31 5315,03 0.15 53~5.69 0.60 5456.37 0,58 5527,06 1.37 3310,72 0.40 3354.09 2.78 3399.46 2,32 3415.49 1.99 3448,48 4.49 3501,25 1.97 3558.00 1.06 3516,50 2.93 3676.79 0,61 3739.77 1,43 3803.74 0.50 3868.59 2.41 3935.72 3,31 40O5,25 6.99 a079.4~ 4,11 4159.27 4.76 4241,90 4.23 4327.76 4,00 4416.17 4,16 4506,72 6.15 4599.34 2.87 4693,27 SENT BY: 9- 4- 1 ' l'53PM ' PHILLIPS AK INC-+- ' , 907 276 7542:# 4/ 4 113 10773,00 85.91 114 10900,00 87.91 115 10996,00 90,10 116 11093.00 91.99 117 11187.00 90,48 118 11284.00 90.55 119 11379.00 90~5 120 11474.00 90.07 121 11570.00 90,55 122 11666.00 91,03 123 11761.00 90.21 124 11855,00 90,58 125 11952,00 90,86 126 12045,00 88,87 127 12142.00 89,31 128 12236.00 90.72 129 12332.00 90.41 130 12427.00 91.99 131 12523.00 91,81 132 12618,00 92,16 133 12714,00 90,14 134 12809,00 90.68 135 12905,00 89.73 136 12999,00 90.41 137 1309&00 90,75 138 13191.00 gO. lO 139 13287,00 90,17 140 13382.00 89,62 141 13477.00 88,83 142 13573,00 89.11 143 13668.00 89.38 144 13763,00 88,32 145 13860,00 88.87 146 13954.00 92.06 147 14050,00 93,09 148 14145.00 93.36 149 14240,00 93,84 150 14301.00 93.84 329.13 7229,40 7177,40 364787,08 8976345,24 1675.84 -6948.62 328.54 7236,24 7184.24 364723.31 5976454,83 1784,35 -7014.24 327.64 7237.91 7185,91 364673.96 5976537. t5 1885.83 -7064.98 328.75 7236.14 7184.14 364624.26 5976620.41 1948,24 -7116.09 331.76 7234.11 7182,11 364579.03 5976702,76 2029.83 -7162.71 331,71 7233.24 7181.24 364534.55 5976788.95 2115.26 -7208,64 331,48 7232.16 7180,16 384490,78 5976873.25 2198.81 -7253.83 331,93 7231,48 7179.48 364447.18 5976957.64 2282.46 -7298.86 331.98 72~0.96 7178.96 364403,49 5977043,11 2367.19 -7343.99 332.48 7229.64 7177.64 364360.21 5977126.76 2452,12 -7388,72 332.47 7228.61 7176.61 364317.74 5977213.75 2536.36 -7432,62 332.34 7227,9G 7175.96 364276.62 5977297.77 2619.67 -7476.16 332.73 7226.75 7174.75 364232,35 5977384,57 2705,73 -7520.89 332.46 7226,97 7174.97 364190.95 5977467.83 2788.29 -7563.69 331.81 7228.51 7176,51 364147.08 5977554.32 2874.03 -7609.02 332.12 7228,48 7176,48 364104,31 5977638.01 2957.00 -7653.20 332,29 7227,53 7175.53 364060.99 5977723,67 3041,91 -7697,97 331.81 7225.54 7173.54 ~64017.91 5977808.3 3125.81 ~742,48 331,85 7222.36 7170,36 363974.05 5977893,63 3210.39 -7787,78 333.33 7219,07 7167.07 363931,78 5977978.63 3294.68 -7831.49 333.98 7217,14 7165.14 363890,65 5978065.34 3380,68 -7874,08 333.80 7216,46 7164,46 383850,3 5978451.33 3465.99 -7915.88 333,46 7216.12 7164,12 363809.12 5978238.04 3552.00 -7958.52 333,59 7216.01 7164.01 363768.65 597832~87 3636.14 -8000.43 332.62 7215.02 7163.02 363726,24 5978410,1 3722.64 -8044,30 332.97 7214.32 7162.32 363684,25 5978495.3 3807.13 -8087.73 332.67 7214.09 7162.09 363641,85 5978581.42 3892,53 -8131.59 333.63 721!~,27 7162.27 368600.54 5978666.96 3977,36 -8174.34 333.99 721"5,55 7163.55 363560.2'1 5978752,96 4062.67 -8216,12 333.62 721728 7165,28 363519.31 5978839.78 4146,80 -8256,49 332.56 7218.53 7166.53 363477.76 5978925,19 4233,50 -8301.48 332.99 7220.44 7168,44 363435.74 5979010.36 4317,96 -8344.93 333.79 7222.82 7170.82 363393,79 5979097.78 4404.66 -8388.37 334.62 7222,05 7170.05 363354,33 5979183.07 4489.27 -8429.27 334,62 7217.74 7165,74 363314,70 5979270.39 4575,92 -8470,37 334.62 7212.40 7160.40 363275.50 5979356.75 4661.62 -8S11,02 334.95 7206.43 7154,43 363236.57 5979443,~9 4747,39 -8551.42 334,95 7202.34 7150.34 363211,74 5979498.76 4802.53 -8577.19 3.81 4754.91 1,64 4881,55 2,47 4977,32 2,26 ,5074.10 3,58 5168,02 0.09 5265.02 0,32 5360.01 0,86 5455.01 0.50 5551.01 0.72 5647.00 0.86 5741,98 O.42 5835,98 0,49 5932,96 2,16 6025,95 0.81 6122.94 1,54 6216,93 0.37 6312,93 1,74 6407,90 0,19 6503.85 1,60 6598,78 2.2! 6694,71 0.6O 6789,65 1.05 6885.60 0.74 6979,56 1.06 7076.53 0,78 7171,51 0.3~ 7267.50 1.35 7362,47 0,85 74~7,40 0,48 7553,33 1.15 7648,30 1.20 7743,26 1.00 7840.20 3.51 7934.10 1,07 8029,90 0.28 8124,63 0.61 8219.32 0,00 ~280.10 RECEIVED SEP 4 American Express' Cash Advance Draft 146 PAY TO ',THE . : , ~kw~, ~k~o NOT V~LID FO~ AMOUNT, OVE~ $ I~ PERIOD:ENDING ~ '~ ~'--D~ ' ~~ ~.-, ALASKA OIL AND GAS CONSERVATION COMMISSIO~ TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Scott D. Reynolds Drilling Engineer Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 Re: Colville River Unit CD2-24 Phillips Alaska Inc. Permit No: 201-095 Sur Loc: 1806' FNL, 1535' FEL Sec. 2, TllN, R4E, UM Btmhole Loc. 2548' FSL, 681' FWL, Sec. 34, T12N, R4E, UM Dear Mr. Reynolds: 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 for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of'fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on. CD2 must comPly with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Permit No: 201-095 May 23, 2001 Page 2 of 2 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, Seamount, Jr. Commissioner BY ORDER OF_~FHE COMMISSION DATED this~__~, "d~y of May 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( C" RECEtVED fL STATE OF ALASKA ~/~¥ ~. 7 2001 ALASKA OIL AND GAS CONSERVATION COMMISSION ,~~/01 PERMIT TO DRILL Alaska Oil & Gas Cons. CommissiorT 20 AAC 25.005 Anchorage la. Type of Work Drill X Redrill lb. Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 52' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 387212 & ADL 387207 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1806' FNL, 1535' FEL SEC. 2, T11N, R4E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 96' FNL, 2094' FWL SEC. 3, T11N, R4E, UM CD2-24 #U-630610 At total depth 9. Approximate spud date Amount 2548' FSL, 681' FWL SEC. 34, T12N, R4E, UM 05/31/2001 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD2- 42 13752' MD 681' W. of Sec 35 feet 177' @ 500' MD Feet 2560 7260' TVD feet ...... 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 325' feet Maximum hole angle 90.37 Maximum surface 2565 pslg At total depth (TVD) 3293 at p$1g 7225' TVD. SS ......... 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement .............. Hole Casing Weight Grade Coupling Len~lth MD TVD MD TVD (include stage data) .............. 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed ............. 12.25" 9.625" 40# L-80 BTC 2787' 37' 37' 2824' 2400' 480 Sx Arcticset III L & 231 Sx Class G 8.5" 7" 26# L-80 BTC-M 10714' 37' 37' 10751' 7272' 128 sx Class G N/A 4.5" 12.6# L-80 I BT-M 10014' 32' 32' 10046' 7104' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true,vertical 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X ......................... 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ I~*--- Title Drilling Team Leader Date ¢[/(~[OI ......... ,// - - Commission Use Only Permit Number I APl number I Approvaldate ,~ j See cover letter for .2~_O//- O ~' ~ 50- /43' ~, "" ~-- O ,~ 7 2 '¢~ '~' d Other requirements Conditions of approval Samples required Yes (~ Mud Icg required Yes ~ Hydrogen sulfide measures Yes ~ Directional survey required ~ No Required working pressure for BOPE 2M 3M SM 10M 15M Other: ORIGINAL SIGNED BY by order of Approved by 0 Taylor Seamount commissioner the commission Date 5' 4:~ ~-~) / ......... Form 10-401 Rev. 7-24-89 Submit in triplicate ORIGINAL CD2-24 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole ! 9-5!8" Casinq Interval Event Risk Level Miticdation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low N/A Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, Iow mud temperatures Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps, run gravel isolation string. Abnormal Pressure in Low Diverter drills, increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of Iow density cement slurries 8-1/2" Hole ! 7" Casinfl,,,Interval Event ., Risk Level Mitigation Strategy Abnormal Pressure in Moderate BOPE drills, Keep mud weight above 10.4 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud weight Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Low Well control drills, increased mud weight. Pressure Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-1/8" Hole ! Horizontal Production Hole Event .... Risk LevelMitigation Strategy Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips High Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 9.3 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. Alpine formation may be abnormally pressured due to gas injection from CD1-06. Horizontal section may be depleted causing lost circulation Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers ORIGI AL Alpine: CD2-24PH (Pilot Hole) & CD2-24 Procedure 1. Install diverter. Move on Doyon 19. Function test diverter. 2. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. 3. Run and cement 9 5/8 surface casing. 4. Install and test BOPE to 5000 psi. 5. Pressure test casing to 2500 psi. 6. Drill out 20' of new hole. Perform leak off test. Maximum 16 ppg EMW. 7. Drill 8 ~" hole to core point at +/- 9834' MD. POOH and PU coring BHA. 8. RIH and cut approximately 82' of core to 9916' MD. POOH with core. 9. PU directional drilling BHA and RIH to 9916' MD. Continue to drill pilot hole to TD @ approximately 10054' MD. This will allow enough rat hole for complete coverage of the Alpine when running e-line logs. POOH. 10. RU Schlumberger e-line (SWS) and run di-pole sonic from TD to surface casing shoe. POOH & RD SWS. 11. PU mule shoe and RIH with tapered 3-1/2" x 5" DP. Set 700 ft cement plug #1 from TD to +/- 9354' MD. 12. Set 620 ft cement plug #2 from +/- 9354' to +/- 8734' MD. POOH. 13. RIH with drilling assembly. Dress-off plug #2. Kick off at +/- 8930' and drill sidetrack to intermediate casing point in the Alpine Reservoir. 14. Run and cement 7 inch casing as per program. Top of cement + 500 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 15. BOPE test to 5000 psi. 16. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. 17. Drill 6 1/8" horizontal section to well TD. 18. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). 16. Displace well to brine and pull out of hole. 17. Run 4 1~, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 21. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus. 22. Set BPV and secure well. Move rig off. ORIGINAL Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-42 will be the closest well to CD2-24. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 177' at 500' MD. Drillinq Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpin,q Operations: Incidental fluids developed from drilling operations on well CD2-24 will be disposed of into the annulus of another permitted well on the CD2 pad.. The CD2-24 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD2-24 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set below the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi 2,472 psi 5,750 psi 4,600 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ,, CD2-24 & CD2-24 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 Y2" Section - 6 1/8" point - 12 1~,, Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 12 - 14 cc/30 min 160 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 PH 6 % KCL ,,, Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: · The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with __ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and DuaI-FIo starch will be used for viscosity and fluid loss control respectively. RKB- GL = 37' Colville River Field CD2-24PH Pilot Hole - Prior to Sidetracking Updated 05/03/2001 Wellhead 16" Conductor to 114' 9.8 ppg drilling mud in hole Cement Plug 9-5/8" 40 ppf L-80 BTC Surface Casing @ 2823' MD / 2400' TVD cemented to surface Plug #2: 620'~ 17 pp.q to c_oygr ~h~ HRZ when in place (top at +/-8734') Top of cement plug dressed off to 8930' MD / 6476' TVD (+/- 48.13° inc.) Top Alpine Reservoir at 9846' MD / 7240' TVD Pilot Hole TD at 10054' MD / 7436' TVD (+/- 20° inc.) Top of Cement Plug ¢1 at +/- 9354' 700 ~ Colville River Field CD2-24 Production Well Completion Plan 16" Conductor to 114' Updated 05/7/01 4~1/2" Camco BAL-O SSSV Nipple (3,812" ID) at 2000' TVD=2254' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" s/s control lines 9~5/8" 40 ppf L-80 BTC Surface Casing @ 2824' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4~1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ +/- 2000 psi set 2 joints above the X landin9 nipple WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3.812" OD) ~ to be installed later Packer Fluid mix: 9.6 ppq KCI Brine with 2000' TVD diesel cap Tubin~ Supended with diesel to lowest GLM Completion M~D TV~D Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 2254' 2000" End thermal centralizers 2824' 2400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3,909" ID) 4251' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Start thermal centralizers. 5958' 4600' (1 per joint) Camco KBG-2 GLM (3.909" ID) 7026' 5200' 4~1/2", 12.6#/ft, lB%Mod Tubing Camco KBG-2 GLM (3.909" ID) 9853' 4d/2" tubing joints (2) iR3) I-lES "X" (3.813" iD) 9952' 4-1/2" tubing joint (1) iR3) Baker S3 Packer 9993' 7081' 4-1/2" tubing joint (1) (R3} HES "XN" (3.725" ID)-63.6 deg 10036' 7099' 4-1/2" 10' pup joint WEG (+/- 65.1 deg) 10046' 7104' Baker S3 Packer at +/- 9993' TOO @ +/- (500' MD above top Alpine) Top Alpine at 10510' MD /7245' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 10751' MD / 7272' TVD @ 87.5 deg Well TD at 13752' MD / 7260' TVD Colville River Field CD2-24 Production Well Completion Plan Formation Isolation Contingency Options Updated 05/] 4/0~ 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID), WRDP-2 SSSV (2.25" ID) and DB-6 No-Go Lock (3.812" OD) with dual 1/4" x 0.049" s/s control line @ 2000' TVD 9-5/¢ 40 ppf L-80 BTC Surface Casing @ 2824' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12,6 ppf b80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Star; thermal centralizers, 1 per joint from 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger ~ XO to lB%Mod - blank 4-1/2" joints (TBD) ~ Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank ~ Guide Shoe (B) Open Hole Scab Liner ~ Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) ~ Muleshoe / Entry Guide .(C) Ope_n Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Ftoat Collar ~ 4-1/2" Float Shoe TOC (500' MD above top Alpine) Camco KBG-2 GLM (3.909" ID) & 1~ Camco DCK-2 Shear Valve Pinned for casing side shear @ 2000 psi set 2 joints above the X landing nipple Baker S3 Packer set at +/- 9993' Well TD at 13752' MD / 7260' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 10751' MD / 7272' TVD @ 87.5 deg CD2-24 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well · Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114/114 10.9 52 53 9 5/8 2824 / 2400 14.5 1086 (0.4525 psi/ft)1570 7" 10751 / 7272 16.0 3290 (0.4525 psi/ft)2565 N/A 11037 / 7277 16.0 3293 (0.4525 psi/ft)N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP- (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1} D = [(14.5 x 0.052) - 0.1] x 2400 = 1570 psi OR ASP = FPP - (0.1 x D) = 3290 - (0.1 x 7272') = 2564 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0,1 x D) = 3293 - (0.1 x 7277') = 2565 psi ORIGINAL Alpine, CD2-24PH Cementinc~ Requirements CD2-24PH Cement Plug #1: 10054' MD to 9354' MD = 700'. Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 700' X 0.3941 ft3/ft X 1.15 (15% excess) = 317.3 ft3 => 274 Sx @ 1.16 ft~/sk CD2-24PH Cement Plug #2 · 9354' MD to 8734' MD = 620'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 620' X 0.3941 ft~/ft X 1.15 (15% excess) = 281 ft~ => 281 sx @ 1.00 ft~/sk L Field : Alpine Field Looofion : Nodh Slope, klosko 5000 4500 4000 3500 3ooo 2500 2000 1500 1000 500 <- West (fee~r) 9500~ ~ 9000 85O0 8000 75O0 7O0O 8500 ~ 6000~ ~ 5500~ ~ 5000~ ~ 4500 4000 .5500 5000 ~ 2500~ ~ 20~00 1500 ~000 5OO 0 500 TD LOCATION: 2548* FSL. 681' FWL SEC, 54, T12N, R4E 978.07 AZIMUTH 6979' (TO PILOT HOLE TD) TARGET LOCATION: 96' FNL, 2094' FWL SEC. 3. T11N, R4E LOCATION: 927' FNL, 2470' FEL SEC. 5, TllN, R4E 4500 9500 9000 8800 8000 7500 7000 5500 6000 5500 8000 4-800 4000 .5500 8000 2500 2000 1500 1000 500 0 000 <- WeD (feet) 0 2400 2800 5600 8000 $400 8800 7200 7600 Phillips Alaska, Inc.i S~rue+ure CD#2 KOP 6.00 DLS~ 2.OO de9 per 100 ft 8.OO 12,21Beg~n Bid/Tm 1~~1186BQse2~.1524,14___ PermQfrost 2~2 DLS: 3,00 deg per 100 ft 39,10 45'10E0C %% C-20 TANGENT ANGLE 48.13 DEG 278.07 AZIMUTH 62?9' (TO PH 1600 20002400 2800 3200 36OO 4000 4400 4800 52005600eooO Vertical Section (feet) -> Azimuth 281.51 wi~h referenee 0.00 N, 0.00 E from slot //24 Phillips Alaska, Inc. w2i~: 24~ 331.86 AZIMUTH 7781' (TO TD) TARGET ANGLE 87.5 DEG FINAL ANGLE 90.37 DEG & 3200 ,t~o0 3600 5800 4000 4200 4400 4600 4800 5000 5200 5400 560O 5800 6000 6200 6400 5600 6800 7000 7200 7400 7600 7800 Vertical Section (feet) -> Azimuth $$1.86 wHh reference 0.00 N, 0.00 E from slot //24 fc~ ~ o~c~ For: ¥ Johnson Oats plotted: 25-~r-~1 P~ R~ ~ CD2-24~ V~9. ~l~ ~a ~ f~ r~ s~ ~24. ~ V~l ~t~ a~ E~ ~ Phillips Alaska, Inc. Structure: CD~2 Field: Alpine Field Well: 24PH Location: Noflh Slope, Alaska Point KOP Begin BId/Trn Base Permofrost EOC C-40 9 5/8 Casing Pt C-50 C-20 K-5 K-2 Albian-97 Albian-96 Bgn Angle Drop HRZ K-I LCU EOD Miluveach A Alpine D Alpine Base Alpine TD PROFIL MD 525.00 825.00 1040.32 2101.28 2541.92 2823.60 2856.56 341 8.42 5029.07 5298.76 7084.70 8145.99 8950.56 9447.94 9600.00 9698.84 9754.10 9824.55 9826.68 9845.84 9904.37 10018.23 E COMMENT Inc Dir TVD 0.00 269.00 325.00 10.00 269.00 822.47 16.58 275.45 1052.00 48.15 278.51 1917.90 48.15 278.51 2212.00 48.15 278.31 2400.00 48.15 278.51 2422.00 48.15 278.51 2797.00 48.15 278.51 5872.00 48.15 278.51 4052.00 48.15 278.51 5244.00 48.15 278.51 5951.00 48.15 278.51 6475.85 50.02 278.31 6876.00 24.69 278.31 7011.01 21.25 278.51 7102.00 20.00 278.51 7155.00 20.00 278.51 7220.00 20.00 278.51 7222.00 20.00 278.51 7240.00 20.00 278.51 7295.00 20.00 278..31 7402.00 DAT North 0.00 -0.76 0.74 68.58 11 5.99 146.51 149.85 210.51 385.64 412.66 604.84 718.85 805.46 850.40 860.50 866.O7 867.86 872.55 872.44 873.38 876.27 881.90 A East 0.00 -45.52 -92.57 -647.16 -971.85 - 1179.40 -1205.69 -1617.70 -2804.51 -5005.25 -4519.21 -5099.75 -5679.19 -6000.66 -6O69.77 -6107.95 -6120.21 -6150.82 -6151.54 -6158.05 -61 77.85 -6216.57 V. Sect 0.00 42.98 91.76 650.58 978.51 1188.26 1212.81 1651.20 2850.59 5051.42 4561.55 5150.16 5755.74 6060.62 6150.47 6169.02 6181.44 6212.57 6215.10 6219.65 6239.67 6278.62 Deg/1 O0 0.00 2 O0 5 O0 5 O0 0 O0 0 O0 0 O0 0 O0 0.00 0.00 0.00 0.00 0.00 3.50 3.50 3.50 3.50 0.00; 0.00 0.00 0.00 0.00 Phillips Alaska, Inc. Structure: CD~2 Field: Alpine Field Well: 24 Location: North Slope, Alaska Point KOP - Sidetrack Pt End BId/Trn HRZ Begin Fnl BId/Trn K-1 LCU Miluveach A Alpine D Alpine T(~rget - Csg Pt. EOC TD - Csg Pt. PROFILE COMMENT DATA MD 8950.00 9291.94 9599.48 9719.51 9852.51 10046.22 10592.69 10417.92 1051 O. 34 10751.06 11057.58 13751.51 Inc Dir TVD North Ec~st V. Sect 48.13 278.51 6475.61 805.45 -5678.92 3586.90 Deg/1 O0 0.00 56.02 295.25 6704.12 888.68 -5944.80 5587.46 4.50 56.02 295.23 6876.00 997.40 - 6175.49 5792.12 0.00 56.02 295.25 6942.97 1059.76 -6265.38 5871.87 0.00 59.56 500.95 7014.00 1092.88 -6564.68 5965.55 4.50 65.11 508.55 7104.00 1190.77 -6505.28 4118.18 4.50 75.84 520.58 7220.00 1419.86 -6756.27 4429.14 4.50 76.65 521.40 7226.00 1458.90 -6751.70 4453.20 4.50 79.63 324.36 7245.00 1511.02 -6806.26 4542.53 4.50 87.50 551.86 7272.00 1715.87 -6952.55 4780.86 4.50 90.37 551.86 7277.54 1966.45 -7067.45 5067.50 1.00 90.57 551.86 7260.00 4559.54 -8547.57 7781.18 0.00 % <- West (feet) 400 380 360 NO 320 300 28O 26O 240 220 200 I80 160 140 ~20 ~00 80 60 400 580 350 340 320 30O 28O 26O 24O 22O 2OO 180 160 140 120 100 60 60 40 2O 0 20 <- West (fee~) S ure: CD#2 ell : 2,4PH F~eld : Alpine i-qeld Locofion :Norfh Slope, Alosko <- West (feet) 1240 ~200 1160 1120 1080 1040 1000 960 920 680 840 8O0 760 720 680 640 500 560 520 480 44O 40O 560 1240 1200 ~160 1120 ~080 1040 ~000 960 920 880 840 800 760 720 680 640 600 560 520 480 440 400 560 <- West (feet) SSrucfure: CD#2 Well : 24PH <- Wesf (feel) 800 1600 3700 ~' 3500 ~gO0 ..... 3,~ oc¢ ~ ~ 4300 <- Wesf (feet) Phillips Alaska, Inc. <- West (feet) ~1580 11200 ~0850 10500 10150 9800 9480 9100 8750 8400 8050 7700 7550 7000 6850 6500 5950 5600 5280 4900 4550 4200 4550 ~-.~-/1~0 ~900 6700 6500 6500 6~00 .... 5700 5500 <- West (feet) ,52O 510 5OO 290~. 28O Phillips Alaska, Inc. I ~?d: Alpln~ Field Location; North SIop~.~!~j 330 54O TRUE N O.~R~H 550 ~ ~CelU- 2O 40~~ 5O 7O 8O 270 9O 26O 250 240 25O 110 220 140 210 150 2OO 190/ 180 ~-70- '1-6%~°~ Normal Plane Travelling Cyllnder - Fee[ Ali depths shown are Measured depths on Reference Wel! 520 310 300 290 280 330 8O 27O 2 9O 26O 25O 24O 100 '~1!0 ', 130 220 ' f40- 2O0 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on ReFerence Well Phillips Alaska, Inc. CD#2 24PH slot #24 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : CD2-24PH Vers#9 Our ref : prop3655 License : Date printed : 25-Apr-2001 Date created : 12-Oct-1999 Last revised : 25-Apr-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 19.348,w151 2 27.759 Slot Grid coordinates are N 5974552.311, E 371705.811 Slot local coordinates are 1804.85 S 1533.23 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL Phillips Alaska, Inc. CD~2,24PH Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : CD2-24PH Vers#9 Last revised : 25-Apr-2001 Measured Inclin Azimuth True Vert R E C T A N G U L A R G R I D C 0 0 R D S G E 0 G R A P H I C Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 100.00 0.00 269.00 100.00 200.00 0.00 269.00 200.00 300.00 0.00 269.00 300.00 325.00 0.00 269.00 325.00 425.00 2.00 269.00 424.98 525.00 4.00 269.00 524.84 625.00 6.00 269.00 624.45 725.00 8.00 269.00 723.70 825.00 10.00 269.00 822.47 900.00 12.21 271.07 896.06 1000.00 15.18 272.89 993.20 1040.32 16.38 273.45 1032.00 1100,00 18.16 274.13 1088.99 1200.00 21.15 275.03 1183.15 1300.00 24.14 275.72 1275.43 1400.00 27,13 276.26 1365.58 1500,00 30.12 276.71 1453.35 1600,00 33.11 277.08 1538.50 1700.00 36.11 277.39 1620.79 1800.00 39.10 277.66 1700.01 1900.00 42.10 277.90 1775.92 2000.00 45.10 278.11 1848.34 2100.00 48.09 278.31 1917.04 2101.28 48.13 278.31 1917.90 2500.00 48.13 278.31 2184.02 2541.92 48.13 278.31 2212.00 2823.60 48.13 278.31 2400.00 2856.56 48.13 278.31 2422.00 3000.00 48.13 278.31 2517.73 3418.42 48.13 278.31 2797.00 3500,00 48.13 278.31 2851,45 4000,00 48.13 278.31 3185.17 4500.00 48.13 278.31 3518.88 5000.00 48.13 278,31 3852.60 5029.07 48,13 278.31 3872.00 5298.76 48,13 278,31 4052.00 5500,00 48,13 278,31 4186.32 6000.00 48.13 278.31 4520.03 6500.00 48.13 278.31 4853.75 7000.00 48.13 278.31 5187.47 7084,70 48.13 278,31 5244,00 7500,00 48.13 278.31 5521,18 8000,00 48.13 278.31 5854.90 8143.99 48,13 278.31 5951.00 8500,00 48,13 278.31 6188.62 8930,36 48.13 278.31 6475.85 9000,00 45.69 278,31 6523.42 9100.00 42.19 278.31 6595.41 9200.00 38,69 278.31 6671.51 C O 0 R D I N A T E S Easting Northing C 0 0 R D I N A T E S 0.00N 0.00N 0.00N 0.00N 0.00N 0.00E 371705.81 5974552.31 n70 20 19.35 w151 2 27.76 0.00E 371705.81 5974552.31 n70 20 19.35 w151 2 27.76 0.00E 371705.81 5974552.31 n70 20 19.35 w151 2 27.76 0.00E 371705.81 5974552.31 n70 20 19.35 w151 2 27.76 0.00E 371705.81 5974552.31 n70 20 19.35 w151 2 27.76 0.03S 0.12S 0.27S 0.49S 0.76S 1.74W 371704.07 5974552.31 n70 20 19.35 w151 2 27.81 6.98W 371698.83 5974552.31 n70 20 19.35 w151 2 27.96 15.69W 371690.12 5974552.30 n70 20 19.35 w151 2 28.22 27.88W 371677.93 5974552.30 n70 20 19.34 w151 2 28.57 43.52W 371662.29 5974552.29 n70 20 19.34 w151 2 29.03 0.73S 0.13N 0.74N 1.92N 4.63N 57.96W 371647.85 5974552.57 n70 20 19.34 w151 2 29.45 81.62W 371624.21 5974553.82 n70 20 19.35 w151 2 30.14 92.57W 371613.27 5974554.62 n70 20 19.36 w151 2 30.46 110.25W 371595.61 5974556.09 n70 20 19.37 w151 2 30.98 143.78W 371562.15 5974559.37 n70 20 19.39 w151 2 31.96 8.25N 12.77N 18.19N 24.49N 31.64N 182.10W 371523.89 5974563.63 n70 20 19.43 wlS1 2 33.08 225.11W 371480.97 5974568.89 n70 20 19.47 w151 2 34.33 272.70W 371433.48 5974575.11 n70 20 19.53 w151 2 35.72 324.74W 371381.56 5974582.28 n70 20 19.59 w151 2 37.24 381.08W 371325.35 5974590.39 n70 20 19.66 w151 2 38.89 39.64N 48.45N 58.06N 68.44N 68.58N 441.57W 371265.01 5974599.40 n70 20 19.74 w151 2 40.66 506.04W 371200.70 5974609.31 n70 20 19.82 w151 2 42.54 574.32W 371132.60 5974620.07 n70 20 19.92 w151 2 44.53 646.22W 371060,90 5974631.66 nT0 20 20.02 w151 2 46,63 647.16W 371059.95 5974631.81 n70 20 20.02 w151 2 46.66 111.48N 115.99N 146.31N 149.85N 165.29N 940.96W 370766.95 5974679.67 n70 20 20.44 wlS1 2 55.24 971.85W 370736.14 5974684.71 n70 20 20.49 w151 2 56.15 1179.40W 370529.15 5974718.52 n70 20 20.78 w151 3 02.21 1203.69W 370504.92 5974722.48 n70 20 20.82 w151 3 02.92 1309.38W 370399.52 5974739.70 n70 20 20.97 w151 3 06.01 210.31N 219.09N 272.90N 326.70N 380.51N 1617.70W 370092.03 5974789.92 n70 20 21.41 w151 3 15.01 1677.81W 370032.08 5974799.72 n70 20 21.50 w151 3 16.77 2046.24W 369664.65 5974859.74 n70 20 22.02 w151 3 27.53 2414.66W 369297.21 5974919.76 n70 20 22.55 w151 3 38.29 2783.09W 368929.78 5974979.78 n70 20 23.08 w151 3 49.05 383.64N 412.66N 434.31N 488.12N 541.92N 2804.51W 368908.42 5974983.27 n70 20 23.11 w151 3 49.68 3003.23W 368710.23 5975015.64 nTO 20 23.39 w151 3 55.48 3151.52W 368562.34 5975039.80 nTO 20 23.61 w151 3 59.82 3519.95W 368194.91 5975099.82 n70 20 24.13 w151 4 10.58 3888.37W 367827.47 5975159.84 n70 20 24.66 w151 4 21.34 595.73N 604.84N 649.53N 703.34N 718.83N 4256.80W 367460.04 5975219.86 n70 20 25.19 w151 4 32.10 4319.21W 367397.79 5975230.03 n70 20 25.28 w151 4 33.93 4625.23W 367092.60 5975279.89 n70 20 25.71 w151 4 42.87 4993.65W 366725.17 5975339.91 n70 20 26.24 w151 4 53.63 5099.75W 366619.36 5975357.19 n70 20 26.39 w151 4 56.73 757.14N 803.46N 810.80N 820.83N 830.20N 5362.08W 366357.74 5975399.93 n70 20 26.76 w151 5 04.39 5679.19W 366041.48 5975451.59 n70 20 27.22 w151 5 13.66 5729.51W 365991.29 5975459.79 n70 20 27.29 w151 5 15.13 5798.17W 365922.82 5975470.97 n70 20 27.39 w151 5 17.14 5862.35W 365858.82 5975481.43 n70 20 27.48 w151 5 19.01 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot %24 and TVD from Estimated RKB (52.00 Ft above mean sea level). Bottom hole distance is 6278.62 on azimuth 278.07 degrees from wellhead. Total Dogleg for wellpath is 76.42 degrees. Vertical section is from wellhead on azimuth 278.07 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORI IIVAL Phillips Alaska, Inc. CD#2,24PH Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : CD2-24PH Vers~9 Last revised : 25-Apr-2001 Measured Inclin Azimuth True Vert R E C T A N G U L A R G R I D C 0 0 R D S G E 0 Depth Degrees Degrees Depth C 0 0 R D I N A T E S Easting Northing C O O 9300.00 35.19 278.31 6751.42 838.89N 5921.81W 365799.51 5975491.11 n70 20 9400.00 31.69 278.31 6834.85 846.85N 5976.33W 365745.14 5975500.00 n70 20 9447.94 30.02 278.31 6876.00 850.40N 6000.66W 365720.87 5975503.96 n70 20 9500.00 28.19 278.31 6921.48 854.06N 6025.72W 365695.89 5975508.04 n70 20 9599.99 24.69 278.31 7011.00 860.49N 6069.77W 365651.95 5975515.22 n70 20 9698.84 21.23 278.31 7102.00 866.07N 6107.93W 365613.90 5975521.43 n70 20 9700.00 21.19 278.31 7103.08 866.13N 6108.34W 365613.48 5975521.50 n70 20 9734.10 20.00 278.31 7135.00 867.86N 6120.21W 365601.65 5975523.43 n70 20 9824.55 20.00 278.31 7220.00 872.33N 6150.82W 365571.12 5975528.42 n70 20 9826.68 20.00 278.31 7222.00 872.44N 6151.54W 365570.40 5975528.54 n70 20 9845.84 20.00 278.31 7240.00 873.38N 6158.03W 365563.93 5975529.59 n70 20 9904.37 20.00 278.31 7295.00 876.27N 6177.83W 365544.18 5975532.82 n70 20 10000.00 20.00 278.31 7384.87 881.00N 6210.20W 365511.90 5975538.09 n70 20 10018.23 20.00 278.31 7402.00 881.90N 6216.37W 365505.75 5975539.10 n70 20 GRAPHIC RDINATES 27.56 w151 5 20.75 27.64 w151 5 22.34 27.68 w151 5 23.05 27.71 w151 5 23.78 27.77 w151 5 25.07 27.83 w151 5 26.18 27.83 w151 5 26.20 27.85 wl51 5 26.54 27.89 w151 5 27.44 27.89 w151 5 27.46 27.90 w151 5 27.65 27.93 w151 5 28.23 27.97 w151 5 29.17 27.98 w151 5 29.35 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #24 and TVD from Estimated RKB (52.00 Ft above mean sea level). Bottom hole distance is 6278.62 on azimuth 278.07 degrees from wellhead. Total Dogleg for wellpath is 76.42 degrees. Vertical section is from wellhead on azimuth 278.07 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL Phillips Alaska, Inc. CD#2,24PH Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : CD2-24PH Vers~9 Last revised : 25-Apr-2001 Con~ents in wellpath ==================== MD TVD Rectangular Coords. Comment 325 00 325.00 0.00N 0.00E KOP 825 1040 2101 2541 2823 2856 3418 5029 5298 7084 8143 8930 9447 9599 9698 9734 9824 9826 9845 9904 10018 00 822.47 0.76S 43.52W Begin Bld/Trn 32 1032.00 0.74N 92.57W Base Permafrost 28 1917.90 68.58N 647.16W EOC 92 2212.00 115.99N 971.85W C-40 60 2400.00 146.31N 1179.40W 9 5/8" Casing Pt 56 2422.00 149.85N 1203.69W C-30 42 2797.00 210.31N 1617.70W C-20 07 3872.00 383.64N 2804.51W K-3 76 4052.00 412.66N 3003.23W K-2 70 5244.00 604.84N 4319.21W Albian-97 99 5951.00 718.83N 5099.75W Albian-96 36 6475.85 803.46N 5679.19W Bgn Angle Drop 94 6876.00 850.40N 6000.66W HRZ 99 7011.00 860.49N 6069.77W K-1 84 7102.00 866.07N 6107.93W LCU 10 7135.00 867.86N 6120.21W EOD 55 7220.00 872.33N 6150.82W Miluveach A 68 7222.00 872.44N 6151.54W Alpine D 84 7240.00 873.38N 6158.03W Alpine 37 7295.00 876.27N 6177.83W Base Alpine 23 7402.00 881.90N 6216.37W TD Casing positions in string 'A' ============================== Top MD Top ~ Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 2823.60 2400.00 146.31N 1179.40W9 5/8" Casing NO Targets associated with this wellpath ORIGINAL Phillips Alaska, Inc. CD#2 24 slot #24 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : CD2-24 Vers#9 Our ref : prop4601 License : Date printed : 25-Apr-2001 Date created : 4-Apr-2001 Last revised : 25-Apr-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 19.348,w151 2 27.759 Slot Grid coordinates are N 5974552.311, E 371705.811 Slot local coordinates are 180~.85 S 1533.23 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL Phillips Alaska, Inc. CD#2,24 Alpine Field. North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : CD2-24 Vers#9 Last revised : 25-Apr-2001 Measured Inclin Azimuth True Vert R E C T A N G U L A R G R I D C 0 0 R D S G E 0 G R A P H I C Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 100.00 0.00 269.00 100.00 200.00 0.00 269.00 200.00 300.00 0.00 269.00 300.00 325.00 0.00 269.00 325.00 425.00 2.00 269.00 424.98 525.00 4.00 269.00 524.84 625.00 6.00 269.00 624.45 725.00 8.00 269.00 723.70 825.00 10.00 269.00 822.47 900.00 12.21 271.07 896.06 1000.00 15.18 272.89 993.20 1100.00 18.16 274.13 1088.99 1200.00 21.15 275.03 1183.15 1300.00 24.14 275.72 1275.43 1400.00 27.13 276.26 1365.58 1500.00 30.12 276.71 1453.35 1600.00 33.11 277.08 1538.50 1700.00 36.11 277.39 1620.79 1800.00 39.10 277.66 1700.01 1900.00 42.10 277.90 1775.92 2000.00 45.10 278.11 1848.34 2100.00 48.09 278.31 1917.04 2101.28 48.13 278.31 1917.90 2500.00 48.13 278.31 2184.02 3000.00 48.13 278.31 2517.73 3500.00 48.13 278.31 2851.45 4000.00 48.13 278.31 3185.17 4500.00 48.13 278.31 3518.88 5000.00 48.13 278.31 3852.60 5500.00 48.13 278.31 4186.32 6000.00 48.13 278.31 4520.03 6500.00 48.13 278.31 4853.75 7000.00 48.13 278.31 5187.47 7500.00 48.13 278.31 5521.18 8000.00 48.13 278.31 5854.90 8500.00 48.13 278.31 6188.62 8930.00 48.13 278.31 6475.61 9000.00 47.93 282.54 6522.43 9030.00 47.90 284.36 6542.54 9100.00 49.97 287.51 6588.53 9200.00 53.06 291.69 6650.78 9291.94 56.02 295.23 6704.12 9500.00 56.02 295.23 6820.40 9599.48 56.02 295.23 6876.00 9719.31 56.02 295.23 6942.97 9800.00 58.14 298.75 6986.83 9852.51 59.56 300.95 7014.00 9900.00 60.88 302.89 7037.58 10000.00 63.75 306.80 7084.05 C 0 0 R D I N A T E S Easting Northing C 0 0 R D I N A T E S 0.00N 0.00N 0.00N 0.00N 0.00N 0.03S 0.12S 0.27S 0.49S 0.76S 0.73S 0.13N 1.92N 4.63N 8.25N 12.77N 18.19N 24.49N 31.64N 39.64N 48.46N 58.06N 68.44N 68.58N 111.49N 165.30N 219.10N 272.91N 326.72N 380.53N 434.33N 488.14N 541.95N 595.76N 649.56N 703.37N 757.18N 803.45N 812.86N 818.04N 832.54N 858.84N 888.68N 962.23N 997.40N 1039.76N 1070.51N 1092.88N 1114.67N 1165.28N 0.00E 371705.81 5974552.31 n70 20 19.35 w151 2 27.76 0.00E 371705.81 5974552.31 n70 20 19.35 w151 2 27.76 0.00E 371705.81 5974552.31 n70 20 19.35 w151 2 27.76 0.00E 371705.81 5974552.31 n70 20 19.35 w151 2 27.76 0.00E 371705.81 5974552.31 n70 20 19.35 w151 2 27.76 1.74W 371704.07 5974552.31 n70 20 19.35 w151 2 27.81 6.98W 371698.83 5974552.31 n70 20 19.35 wl51 2 27.96 15.69W 371690.12 5974552.30 n70 20 19.35 w151 2 28.22 27.88W 371677.93 5974552.30 n70 20 19.34 w151 2 28.57 43.52W 371662.29 5974552.29 n70 20 19.34 w151 2 29.03 57.96W 371647.85 5974552.57 n70 20 19.34 w151 2 29.45 81.62W 371624.21 5974553.82 n70 20 19.35 w151 2 30.14 110.25W 371595.61 5974556.09 n70 20 19.37 wlS1 2 30.98 143.78W 371562.15 5974559.37 n70 20 19.39 w151 2 31.96 182.10W 371523.89 5974563.63 n70 20 19.43 w151 2 33.08 225.11W 371480.97 5974568.89 n70 20 19.47 w151 2 34.33 272.70W 371433.48 5974575.11 n70 20 19.53 w151 2 35.72 324.74W 371381.56 5974582.28 n70 20 19.59 w151 2 37.24 381.08W 371325.35 5974590.39 n70 20 19.66 w151 2 38.89 441.57W 371265.01 5974599.41 n70 20 19.74 w151 2 40.66 506.04W 371200.70 5974609.31 n70 20 19.82 w151 2 42.54 574.32W 371132.60 5974620.07 n70 20 19.92 w151 2 44.53 646.22W 371060.90 5974631.66 n70 20 20.02 w151 2 46.63 647.16W 371059.96 5974631.82 n70 20 20.02 w151 2 46.66 940.96W 370766.95 5974679.68 n70 20 20.44 w151 2 55.24 1309.38W 370399.52 5974739.70 n70 20 20.97 w151 3 06.01 1677.81W 370032.08 5974799.73 n70 20 21.50 w151 3 16.77 2046.24W 369664.65 5974859.75 n70 20 22.03 w151 3 27.53 2414.66W 369297.21 5974919.77 n70 20 22.55 w151 3 38.29 2783.09W 368929.78 5974979.80 n70 20 23.08 w151 3 49.05 3151.52W 368562.35 5975039.82 n70 20 23.61 w151 3 59.82 3519.94W 368194.91 5975099.85 n70 20 24.13 w151 4 10.58 3888.37W 367827.48 5975159.87 n70 20 24.66 w151 4 21.34 4256.79W 367460.04 5975219.89 n70 20 25.19 w151 4 32.10 4625.22W 367092.61 5975279.92 n70 20 25.71 w151 4 42.87 4993.65W 366725.18 5975339.94 n70 20 26.24 w151 4 53.63 5362.07W 366357.74 5975399.96 n70 20 26.77 w151 5 04.39 5678.92W 366041.75 5975451.58 n70 20 27.22 w151 5 13.65 5730.09W 365990.75 5975461.86 n70 20 27.31 w151 5 15.15 5751.74W 365969.19 5975467.40 n70 20 27.36 wl51 5 15.78 5802.47W 365918.72 5975482.76 n70 20 27.50 w151 5 17.26 5876.15W 365845.50 5975510.29 n70 20 27.76 wl51 5 19.41 5944.80W 365777.37 5975541.29 n70 20 28.05 w151 '5 21.42 6100.87W 365622.58 5975617.46 n70 20 28.77 wl51 5 25.98 6175.49W 365548.57 5975653.88 n70 20 29.12 wl51 5 28.16 6265.38W 365459.41 5975697.75 n70 20 29.54 w151 5 30.79 6325.71W 365399.62 5975729.51 n70 20 29.84 w151 5 32.55 6364.68W 365361.04 5975752.54 n70 20 30.06 w151 5 33.69 6399.66W 365326.43 5975774.92 n70 20 30.27 w151 5 34.71 6472.28W 365254.68 5975826.74 n70 20 30.77 w151 5 36.84 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #24 and TVD from Estimated RKB (52.00 Ft above mean sea level). Bottom hole distance is 9417.25 on azimuth 297.58 degrees from wellhead. Total Dogleg for wellpath is 113.87 degrees. Vertical section is from wellhead on azimuth 331.86 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD#2,24 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : CD2-24 Vers~9 Last revised : 25-Apr-2001 Measured Inclin Azimuth True Vert R E C T A N G U L A R G R I D C 0 0 R D S G E O G R A P H I C Depth Degrees Degrees Depth 10046.22 65.11 308.55 7104.00 10100.00 66.72 310.53 7125.95 10200.00 69.77 314.09 7163.01 10300.00 72.90 317.51 7195.02 10392.69 75.84 320.58 7220.00 10400.00 76.07 320.82 7221.78 10417.92 76.65 321.40 7226.00 10500.00 79.29 324.03 7243.11 10510.34 79.63 324.36 7245.00 10600.00 82.55 327.18 7258.89 10700.00 85.82 330.29 7269.03 10751.06 87.50 331.86 7272.00 10751.08 87.50 331.86 7272.00 10801.08 88.00 331.86 7273.96 10901.08 89.00 331.86 7276.58 11001.08 90.00 331.86 7277.45 11037.58 90.37 331.86 7277.34 11100.00 90.37 331.86 7276.94 11200.00 90.37 331.86 7276.30 11300.00 90.37 331.86 7275.66 11400.00 90.37 331.86 7275.03 11500.00 90.37 331.86 7274.39 11600.00 90.37 331.86 7273.75 11700.00 90.37 331.86 7273.11 11800.00 90.37 331.86 7272.48 11900.00 90.37 331.86 7271.84 12000.00 90.37 331.86 7271.20 12100.00 90.37 331.86 7270.56 12200.00 90.37 331.86 7269.92 12300.00 90.37 331.86 7269.28 12400.00 90.37 331.86 7268.65 12500.00 90.37 331.86 7268.01 12600.00 90.37 331.86 7267.37 12700.00 90.37 331.86 7266.73 12800.00 90.37 331.86 7266.09 12900.00 90.37 331.86 7265.45 13000.00 90.37 331.86 7264.81 13100.00 90.37 331.86 7264.17 13200.00 90.37 331.86 7263.53 13300.00 90.37 331.86 7262.89 13400.00 90.37 331.86 7262.25 13500.00 90.37 331.86 7261.61 13600.00 90.37 331.86 7260.97 13700.00 90.37 331.86 7260.33 13751.51 90.37 331.86 7260.00 13751.53 90.37 331.86 7260.00 C O O R D I N A T E S Easting Northing C 00 R D I N A T E S 1190.77N 1222.02N 1284.54N 1352.46N 1419.86N 1425.35N 1438.90N 1502.77N 1511.02N 1584.24N 1669.26N 1713.87N 1713.89N 1757.94N 1846.09N 1934.26N 1966.45N 2021.49N 2109.67N 2197.85N 2286.03N 2374.20N 2462.38N 2550.56N 2638.74N 2726.91N 2815.09N 2903.27N 2991.45N 3079.62N 3167.80N 3255.98N 3344.16N 3432.34N 3520.51N 3608.69N 3696.87N 3785.05N 3873.23N 3961.41N 4049.58N 4137.76N 4225.94N 4314.12N 4359.54N 4359.56N 6505.28W 365222.12 5975852.78 n70 20 31.02 w151 5 37.80 6543.14W 365184.80 5975884.67 n70 20 31.33 w151 5 38.91 6611.78W 365117.23 5975948.33 nT0 20 31.94 w151 5 40.92 6677.79W 365052.38 5976017.35 n70 20 32.61 w151 5 42.85 6736.27W 364995.05 5976085.73 n70 20 33.27 wlS1 5 44.56 6740.77W 364990.65 5976091.29 n70 20 33.32 w151 5 44.69 6751.70W 364979.95 5976105.02 n70 20 33.46 w151 5 45.01 6800.31W 364932.43 5976169.70 n70 20 34.08 w151 5 46.43 6806.26W 364926.62 5976178.04 n70 20 34.16 w151 5 46.61 6856.07W 364878.07 5976252.10 n70 20 34.88 w151 5 48.06 6907.68W 364827.90 5976337.97 n70 20 35.72 w151 5 49.57 6932.33W 364804.01 5976382.99 n70 20 36.16 w151 5 50.29 6932.34W 364804.00 5976383.00 n70 20 36.16 w151 5 50.30 6955.90W 364781.19 5976427.44 n70 20 36.59 w151 5 50.98 7003.05W 364735.54 5976516.37 n70 20 37.46 w151 5 52.37 7050.21W 364689.88 5976605.32 n70 20 38.32 w151 5 53.75 7067.43W 364673.21 5976637.79 n70 20 38.64 w151 5 54.25 7096.87W 364644.71 5976693.32 n70 20 39.18 w151 5 55.11 7144.03W 364599.05 5976782.27 n70 20 40.05 w151 5 56.49 7191.20W 364553.38 5976871.23 n70 20 40.92 w151 5 57.87 7238.36W 364507.72 5976960.18 n70 20 41.78 wlS1 5 59.25 7285.52W 364462.06 5977049.14 n70 20 42.65 w151 6 00.64 7332.69W 364416.40 5977138.09 n70 20 43.52 w151 6 02.02 7379.85W 364370.74 5977227.05 n70 20 44.38 wl51 6 03.40 7427.01W 364325.08 5977316.00 n70 20 45.25 w151 6 04.78 7474.17W 364279.41 5977404.96 n70 20 46.12 w151 6 06.16 7521.34W 364233.75 5977493.91 n70 20 46.98 w151 6 07.54 7568.50W 364188.09 5977582.87 n70 20 47.85 w151 6 08.92 7615.66W 364142.43 5977671.82 n70 20 48.72 w151 6 10.30 7662.82W 364096.77 5977760.78 n70 20 49.58 w151 6 11.68 7709.98W 364051.11 5977849.73 n70 20 50.45 wlS1 6 13.07 7757.15W 364005.45 5977938.69 n70 20 51.32 w151 6 14.45 7804.31W 363959.79 5978027.64 n70 20 52.18 w151 6 15.83 7851.47W 363914.13 5978116.60 n70 20 53.05 w151 6 17.21 7898.63W 363868.47 5978205.56 n70 20 53.91 w151 6 18.59 7945.79W 363822.81 5978294.51 n70 20 54.78 w151 6 19.97 7992.95W 363777.15 5978383.47 nTO 20 55.65 w151 6 21.35 8040.11W 363731.49 5978472.42 n70 20 56.51 w151 6 22.74 8087.28W 363685.83 5978561.38 n70 20 57.38 w151 6 24.12 8134.44W 363640.17 5978650.33 nTO 20 58.25 w151 6 25.50 8181.60W 363594.51 5978739.29 n70 20 59.11 w151 6 26.88 8228.76W 363548.85 5978828.25 n70 20 59.98 w151 6 28.26 8275.92W 363503.19 5978917.20 n70 21 00.85 w151 6 29.64 8323.08W 363457.53 5979006.16 n70 21 01.71 w151 6 31.02 8347.37W 363434.01 5979051.98 n70 21 02.16 w151 6 31.74 8347.38W 363434.00 5979052.00 n70 21 02.16 w151 6 31.74 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #24 and TVD from Estimated RKB (52.00 Ft above mean sea level). Bottom hole distance is 9417.25 on azimuth 297.58 degrees from wellhead. Total Dogleg for wellpath is 113.87 degrees. Vertical section is from wellhead on azimuth 331.86 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL Phillips Alaska, Inc. CD~2,24 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : CD2-24 Vers~9 Last revised : 25-Apr-2001 Comments in wellpath MI) TVD Rectangular Coords. Comment 8930.00 6475.61 803.45N 5678.92W KOP - Sidetrack Pt 9291.94 6704.12 888.68N 5944.80W End Bld/Trn 9599.48 6876.00 997.40N 6175.49W HRZ 9719.31 6942.97 1039.76N 6265.38W Begin Fnl Bld/Trn 9852.51 7014.00 1092.88N 6364.68W 10046.22 7104.00 1190.77N 6505.28W LCU 10392.69 7220.00 1419.86N 6736.27W Miluveach A 10417.92 7226.00 1438.90N 6751.70W Alpine D 10510.34 7245.00 1511.02N 6806.26W Alpine 10751.06 7272.00 1713.87N 6932.33W Target - Csg Pt. 10751.08 7272.00 1713.89N 6932.34W CD2-24 Tgt Rvsd 15-Mar-2001 11037.58 7277.34 1966.45N 7067.43W EOC 13751.51 7260.00 4359.54N 8347.37W TD - Csg Pt. 13751.53 7260.00 4359.56N 8347.38W CD2 Tgt76 Toe Rvsd 26-0ct-00 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 2823.60 2400.00 146.31N 1179.40W 9 5/8" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised CD2-24 Tgt Rvsd 15-M 364804.000,5976383.000,0.0000 7272.00 1713.89N 6932.34W 26-Mar-2001 CD2 Tgt76 Toe Rvsd 2 363434.000,5979052.000,0.0000 7260.00 4359.56N 8347.38W 18-Jun-1998 O I IiVAL Phillips Alaska, Inc. CD#2 24 slot #24 Alpine Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : CD2-24 Vers#9 Our ref : prop4601 License : Date printed : 25-Apr-2001 Date created : 4-Apr-2001 Last revised : 25-Apr-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 19.348,w151 2 27.759 Slot Grid coordinates are N 5974552.311, E 371705.811 Slot local coordinates are 1804.85 S 1533.23 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 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 by an asterisk, e.g. 487.4* Object wellpath CD2-58 Vers#3 ,58,CD#2 CD2-57 Vers#3 ,57,CD#2 CD2-56 Version#2 ,56,CD#2 CD2-55 Vers#3 ,55,CD#2 CD2-54 Vers#5 ,54,CD#2 CD2-53 Vers#5 ,53,CD#2 CD2-52 Vers#5 ,52,CD#2 CD2-51 Vets#6 ,51,CD#2 CD2-50 Vers#7 ,50,CD#2 CD2-49 Vets#5 ,49,CD#2 CD2-48 Version#3 ,48,CD#2 CD2-47 Version#3 ,47,CD#2 CD2-46 Version#5 ,46,CD#2 CD2-45 Vers#4 ,45,CD#2 CD2-44 Vers#4 ,44,CD#2 CD2-41 Vers#5 ,41,CD#2 CD2-38 Version#3 ,38,CD#2 CD2-37 Version#3 ,37,CD#2 CD2-34 Vers#5 ,34,CD#2 CD2-35A Vers. 82, 35A-61,CD#2 PMSS <0-11984'> ,35,CD#2 CD2-32 Vers#4 ,32,CD#2 CD2-31 Vets#5 ,31,CD#2 CD2-29 Version#3 ,29,CD#2 CD2-28 Vers#6 ,28,CD#2 CD2-27 Vers#6 ,27,CD#2 CD2-26 Version#4 ,26,CD#2 CD2-25 Version#3 ,25,CD#2 CD2-22 Version#3 ,22,CD#2 CD2-19 Vets#4 ,19,CD#2 CD2-18 Vers#4 ,18,CD#2 CD2-17 Verslon#3 ,17,CD#2 CD2-16 Version#5 ,16,CD#2 CD2-15 Vers#4 ,15,CD#2 CD2-14 Version#3 ,14,CD#2 Closest approach with 3-D Last revised Distance 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 14-Mar-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 338.9( 328.2( 318.6( 308.8( 298.7( 288.8( 278.0( 268.7( 258.0( 248.3( 238.0( 228.6( 218.0( 208.6( 198.6( 168.0( 138.4( Minimum Distance method M.D. Diverging from M.D. 300 0 362 5 300 0 300 0 300 0 300 0 462 5 300 0 412 5 337 5 462 5 300 0 462 5 300 0 300 0 462 5 350 0 300.0 362.5 10209.1 300.0 300.0 10717.0 10445.3 300.0 412.5 337.5 462.5 300.0 462.5 300.0 300.0 462.5 350.0 9-Apr-2001 9-Apr-2001 8-Feb-2001 15-Nov-2000 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 )53.0( 10055 )98.5( 325 )7497.9 2240 )109.4 200 )78.0 450 )68.0 437 )48.0 437 )37.0 437 )28.0 425 )18 0 412 )8 6 300 )18 5 325 )46 9 550 )49 1( 1744 )66 6( 587 )78 1( 412 )86 7( 550 )97 6( 450 10055.2 325.0 2860.0 200.0 9273.6 13751.5 437.5 10600.0 13751.5 412.5 8180.0 7100.0 550.0 13751.5 9360.0 11037.6 13751.5 6660.0 ORISINAL CD2-13 Version#3,,13,CD#2 CD2-12 Version~3,,12,CD#2 CD2-11 Vers~5,,ll,CD#2 CD2-10 Version#3,,10,CD#2 CD2-9 Vers~4,,9,CD#2 CD2-8 Vers#4,,8,CD#2 CD2-7 Ver$ion#3,,7,CD#2 CD2-6 Vers~4,,6,CD~2 CD2-5 Vers~4,,5,CD#2 CD2-20 Version#5,,20,CD#2 CD2-23 Vers#8,,23,CD~2 CD2-39 Version#9,,39,CD#2 CD2-21 Version ~? (Old 1-18),,21,CD#2 CD2-30 Vers~5,,30,CD#2 CD2-40 Version~3,,40,CD~2 CD2-43 Leg#l Vers~2,,43,CD#2 CD2-33 Vers#4,,33,CD#2 CD2-42 Version#3,,42,CD~2 CD2-24PH Vers#9,,24PH,CD#2 PMSS <0-7170'>,,Neve #1,Neve #1 PMSS <1868-8850'>,,AlplB,Alpine #1 PMSS <0-3161'>,,Alpl,Alpine #1 PMSS <1876-9940'>,,AlplA,Alpine #1 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 14-Mar-2001 14-Mar-2001 12-Apr-2001 17-ADr-2001 9-ADr-2001 9-Apr-2001 14-Mar-2001 9-Apr-2001 9-Apr-2001 25-Apr-2001 16-Dec-1999 21-Sep-1999 21-Sep-1999 21-Sep-1999 )108.1( )115.9( )128.9( )138.7( )147.6( )158.7( )168.7( )178.8( )99.4( )37.1( )7.6( )148.5( )28.6( )58.0( )157.6( )188.7( )88.6( )176.9( )0.0( ) 9277.3 ( )4282.0( )4282.0( ) 4150.2 ( 425.0 662.5 300.0 300.0 2320.0 300.0 300.0 300.0 13751.5 550.0 450.0 300.0 300.0 462.5 350.0 300.0 300.0 500.0 9400.0 2160.0 337.5 337.5 1833.3 425 13751 12600 13751 13100 300 13751 13751 13751 13751 13751 300 10901. 10663 350 30O 10383 500 9400 2160 337 337 4880 ORIGINAL Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 16, 2001 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-24 (& CD2-24 PH) RECEIVED t gy I 7 AJaska Oil & Gas Cons. Commission Anchorage Dear Sirs: Phillips Alaska, Inc. hereby applies for a permit to drill an onshore production well from the Alpine CD2 drilling pad. The intended spud date for this well is May 31, 2001. It is intended that Doyon Rig 19 be used to drill the well. The CD2-24 PH will be drilled through to the base of the Alpine Sand at an inclination of approximately 20°. A core will be cut through the Alpine sands from approximately 9834' MD to 9916' MD. The CD2-24 PH will then be plugged back and sidetracked to enable a horizontal penetration of the Alpine reservoir. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as an open hole producer. At the end of the work program, the well will be closed in awaiting the start-up of CD2 pad, which is tentatively scheduled for August 2001. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: . . 5. 6. 7. 8. 9. 10. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per20 ACC 25.005 (c) (1). A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Proposed pilot hole schematic. Proposed completion diagram. Proposed completion diagram with open hole isolation options. Pressure information as required by 20 ACC 25.035 (d)(2). CD2-24 Pilot Hole Cementing Requirements. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the ddlling fluids handling system. .. If you have any questions or require further information, please contact Scott Reynolds at 265-6253 or Chip Alvord at 265-6120. Ddlling Engineer Attachments CC' CD2-24 Well File / Sharon AIIsup Drake Chip Alvord Cliff Crabtree Gracie Stefanescu Lanston Chin ATO 1530 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tom my_Thompson @ anadarko.com RECEIVED ~A¥ 1 7 2001 , Alaska Oil & Gas Cons. Commission Anchorage American Express" ,Cash ~c[~ance Draft 133 ORDER OF -- / / ~ ~ ~ ~ DOLLARS Issued by Inte~mtecl P~yment: System, Inc. NO'~ VALID FOR AlflOUNT OVER $1000 c~ Payab~ ~ No~C I~nk of Grand Jun~ion - Downtown, N~ ' T, -- _ Grand JuncrJo. nI Color'ado ,~,,o, ~,,,,~ P_'DD~.~, ,". i,D ;~ i,DDhDD": ~ 5 ,,,D i, ? 5DDEI WELL PERMIT CHECKLIST COMPANY ~,~x~',////J ~ <; WELL NAME ~Z>.2.-.2_ 5 PROGRAM: exp dev ~ redrll serv wellbore sag FIELD & POOL INIT CLASS ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in drilling unit ............ 8. If deviated, is wellbore plat included ............. . . 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons ..... ' ..... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed .... ~ ........ 23. If diverter required, does it meet regulations .......... 24. Drilling .fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation . . ~ ............. 26. BOPE press rating appropriate; test to .. '~ ~- ~ 'O Dsig. 27. Choke manifold complies.W/APl RP-53 (May 84) ......... 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY G/~OL AREA ¥ N ¥ N ¥ N '~ N ann. disposal para req ON/OFF SHORE N 30. Permit can be issued wlo hydrogen sulfide measures ...... Y N 31 Data presented on potential overpressure zones ....... Y N~/ ,n ) /"7 32. Seismic analysis of shallow gas zones ............. Y./4q ~' ~ ~ 33. Seabed condition survey (if off-shore) ............. //'¢ N ' 34. Contact name/phone for weekly progress reports [exploratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... ~ N APPR DATE (B) will not contaminate freshwater; or cause drilling waste.., q.Y-.) N to surface; , "' ~ h,~ ~ !2..Z.~ O) (C) will not impair mechanical integrity of the well used for diSposal; ~. N (D) will not damage producing formation or impair recovery from a (~ N pool; and (E) will n0.t' circumvent 20 AAC 2.5.252 or 20 AAC 25.412. ~,.,<'~ N GEOLOGY: ENGINEERING: ' UlClAnnular COMMISSION: DTS ,,~-, //.2.,Z,,,,-) / JMH- / /- , , , , ,, , Comments/Instructions: O Z O -I c:~msoffice\wordian~iana\checklist (rev. 11101//00) " WELL NAME .~Z~ .2.- 2., ~' PROGRAM: exp~dev ,X redrll ~serv ~wellbore seg ann. disposal para req ~ FIELD & POOL /,2_,o../cJ c, II~IT CLA~S /~ /-' .~ ,'/ GEOL AREA / ADMINISTRATION 1. Permit fee attached ....................... //~R DATE ENGINEERING GEOLOGY APPR DATE 2. Lease number appropriate ................... 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 ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ....... . .... 14. Conductor stdng 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 hodzons ..... .-~'. .... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ........... ~ ...... ~.._~ UNIT//. ' N - 21. If a re-drill, has a 10-403 for abandonment been approved... -Y--N- 22. Adequate wellbore separation Proposed.: ............ ~,~ N · ' ' 23. If diverter required, does it meet regulations .......... 24. Drilling .fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ............. '... (.~_.) N 26. BOPE press rating appropriate; test to ' '~-~O~,..~ 13sig. ~N 't-~3;;~ ~,.~--'~ ~'~,(3'~ ~ ~ -~:,(43c:~ .~ ~ ' 27. Choke manifold complies w/APl RP-53 (May 84) ......... C,~ N 28. Is presence of H2S gas probable ................. Y N~'~ . Work will occur without operation shutdown ........... (,_y..) ~N 29. 30. Permit can be issued Wlo hydrogen sulfide measures ...... Y N...~ ' / 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. /Y" N 33. Seabed condition survey (if off-shore) ............. · 34. Contact name/phone for weekly progress reports [exploratory (~fly] Y N ' ON/OFF SHORE ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; ' ' (C) will not impair mechanical integrity of the well used for diSposal; Y' N (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: 'UICIAnnular COMMISSION: Comments/Instructions: ...mi+ O Z O c:~soffice\wordia n~diana\checklist (rev. 111011/00) 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 APPENDIX. ,, No 'special'effort has been made to chronologically organize this category of information. · ,, · ,o Tape Subfile 2 is type: LIS TAPE HEADER ALPINE UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MWD RUN 1 1 T. DURING D. MICKEY REMARKS: OPEN HOLE CD2-24PB1 501032037770 Phillips Alaska, Inc. BAKER HUGHES INTEQ il-FEB-02 MWD RUN 2 2 B. LACOSTE D. BURLEY 2 lin 4E 52.83 15.88 MWD RUN 3 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT 9.625 2792.0 8.500 9856.0 PER PHILLIPS ALASKA INSTRUCTIONS, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. SURFACE LOCATION: LAT: N70 DEG 20' 19.348" LONG: W151 DEG 2' 27.759" LOG MEASURED FROM D.F. AT 36.95 FT. ABOVE PERM. DATUM (G.L. @ 15.88') . BAKER HUGHES INTEQ RUNS 1 & 2 UTILIZED AUTOTRAC RCLS (ROTARY CLOSED LOOP SYSTEM) WITH DIRECTIONAL, MPR (MULTIPLE PROPAGATION RESISTIVITY), AND MAP (MODULAR ANNULAR PRESSURE) SERVICE TO DRILL OUT THE 9' 5/8" CASING AND DRILL FORMATION FROM 2802 - 9856' MD (2378 - 7211' TVD). DUE TO SENSOR TO BIT OFFSET NO FE DATA WAS RECORDED ON BIT RUN 1. 1) THE INTERVAL FROM 2802 - 2822' MD (2378 - 2391' TVD) WAS LOGGED UP TO 8.9 HOURS AFTER BEING DRILLED DUE TO A TRIP TO CHANGE OUT THE AUTOTRAC DRILLING ASSEMBLY. 2) THE INTERVAL FROM 9825 - 9856' MD I7183 - 7211' TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET AT CASING POINT. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 2802.0 2822.0 MWD 2822.0 9856.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 .0 .0 2 2800.0 9825.0 MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. CN WN FN COUN STAT : PHILLIPS ALASKA, INC. : CD2-24PB1 : ALPINE : NORTH SLOPE : Alaska * FORMAT RECORD (TYPE% 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 2 ROP MWD 68 3 RAD MWD 68 4 RPD MWD 68 5 RAS MWD 68 6 RPS MWD 68 7 FET MWD 68 1 GAPI 1 FPHR 1 OHMM 1 OHMM 1 OHMM 1 OHMM 1 MINS AP1 AP1 AP1 AP1 Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 28 * DATA RECORD (TYPE% 0) 998 BYTES * Total Data Records: 456 Tape File Start Depth = 9860.000000 Tape File End Depth = 2800.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 112969 datums Tape Subfile: 2 559 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 2800.0 $ 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: STOP DEPTH 9825.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DIR DIRECTIONAL RNT PROPAGATION RESIST. GRAM GAMMA RAY $ 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 09-JUN-01 MSL 30399 6.75 ATK MEMORY 9856.0 2800.0 9825.0 0 24.5 51.0 TOOL NUMBER RNT 20016 RNT 20016 8.500 2792.0 FW LIGNO 9.75 .0 .0 2600 .0 .000 .000 .000 .000 .0 .0 .0 .0 .00 .000 .0 0 REMARKS: BIT RUN 2. GR/RNT. BIT RUN 1 WAS RECORDED WHILE DRILLING OUT CASING AND NO FE DATA WAS RECORDED. THERFORE, NO FILE FOR BIT RUN 1 IS PRESENTED. CN WN FN COUN STAT CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP PHASE RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ : PHILLIPS ALASKA, INC. : CD2-24PB1 : ALPINE : NORTH SLOPE : Alaska * FORMAT RECORD (TYPE% 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GRAM MWD 68 1 GAPI 2 ROPS MWD 68 1 FPHR 3 RACL MWD 68 1 OHMM 4 RPCL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 RPCH MWD 68 1 OHMM 7 RPTH MWD 68 1 MINS AP1 AP1 AP1 AP1 Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 456 Tape File Start Depth = 9860.000000 Tape File End Depth = 2800.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 112969 datums Tape Subfile: 3 Minimum record length: Maximum record length: 535 records... 62 bytes 998 bytes Tape Subfile 4 is type: LIS MWD 02/02/11 01 **** REEL TRAILER **** MWD **/ 2/12 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 12 FEB ** 3:36p Elapsed execution time = 0.66 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 2 is type: LIS TAPE HEADER ALPINE UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 1 T. DURING D. MICKEY CD2-24PB1 501032037770 Phillips Alaska, Inc. BAKER HUGHES INTEQ il-FEB-02 MWD RUN 2 2 B. LACOSTE D. BURLEY MWD RUN 3 2 liN 4E 52.83 15.88 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 9.625 2792.0 PRODUCTION STRING 8.500 9856.0 REMARKS: PER PHILLIPS ALASKA INSTRUCTIONS, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. SURFACE LOCATION: LAT: N70 DEG 20' 19.348" LONG: W151 DEG 2' 27.759" LOG MEASURED FROM D.F. AT 36.95 FT. ABOVE PERM. DATUM (G.L. @ 15.88'). BAKER HUGHES INTEQ RUNS 1 & 2 UTILIZED AUTOTRAC RCLS (ROTARY CLOSED LOOP SYSTEM) WITH DIRECTIONAL, MPR (MULTIPLE PROPAGATION RESISTIVITY), AND MAP (MODULAR ANNULAR PRESSURE) SERVICE TO DRILL OUT THE 9 5/8" CASING AND DRILL FORMATION FROM 2802 - 9856' MD (2378 - 7211' TVD). DUE TO SENSOR TO BIT OFFSET NO FE DATA WAS RECORDED ON BIT RUN 1. 1) THE INTERVAL FROM 2802 - 2822' MD (2378 - 2391' TVD) WAS LOGGED UP TO 8.9 HOURS AFTER BEING DRILLED DUE TO A TRIP TO CHANGE OUT THE AUTOTRAC DRILLING ASSEMBLY. 2) THE INTERVAL FROM 9825 - 9856' MD (7183 - 7211' TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET AT CASING POINT. FILE HEADER PILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 2802.0 2822.0 MWD 2822.0 9856.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 .0 .0 2 2800.0 9825.0 MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. CN WN FN COUN STAT : PHILLIPS ALASKA, INC. : CD2-24PB1 : ALPINE : NORTH SLOPE : Alaska * FORMAT RECORD (TYPE% 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: API API API API Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 GR MWD 68 1 GAPI 4 2 ROP MWD 68 1 FPHR 4 3 RAD MWD 68 1 OHMM 4 4 RPD MWD 68 1 OHMM 4 5 RAS MWD 68 1 OHMH 4 6 RPS MWD 68 1 OHMM 4 7 FET MWD 68 1 MINS 4 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE% 0) 998 BYTES * Total Data Records: 456 Tape File Start Depth = 9860.000000 Tape File End Depth = 2800.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 112969 datums Tape Subfile: 2 559 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 2800.0 $ 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: STOP DEPTH 9825.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DIR DIRECTIONAL RNT PROPAGATION RESIST. GRAM GAMMA RAY $ 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 09-JUN-01 MSL 30399 6.75 ATK MEMORY 9856.0 2800.0 9825.0 0 24.5 51.0 TOOL NUMBER RNT 20016 RNT 20016 8.500 2792.0 FW LIGNO 9.75 .0 .0 2600 .0 .000 .000 .000 .000 .0 .0 .0 .0 .00 .000 .0 0 REMARKS: BIT RUN 2. GR/RNT. BIT RUN 1 WAS RECORDED WHILE DRILLING OUT CASING AND NO FE DATA WAS RECORDED. THERFORE, NO FILE FOR BIT RUN 1 IS PRESENTED. CN WN FN COUN STAT CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP PHASE RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ : PHILLIPS ALASKA, INC. : CD2-24PB1 : ALPINE : NORTH SLOPE : Alaska * FORMAT RECORD (TYPE% 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GRAM MWD 68 1 GAPI 2 ROPS MWD 68 1 FPHR 3 RACL MWD 68 1 OHMM 4 RPCL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 RPCH MWD 68 1 OHMM 7 RPTH MWD 68 1 MINS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 4 4 90 995 99 1 28 * DATA RECORD (TYPE% 0) 998 BYTES * Total Data Records: 456 Tape File Start Depth = 9860.000000 Tape File End Depth = 2800.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 112969 datums Tape Subfile: 3 Minimum record length: Maximum record length: 535 records... 62 bytes 998 bytes Tape Subfile 4 is type: LIS MWD 02/02/11 01 **** REEL TRAILER **** MWD **/ 2/12 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 12 FEB ** 3:36p Elapsed execution time = 0.66 seconds. SYSTEM RETURN CODE = 0 **** REEL HEADER **** MWD 02/02/20 AWS 01 **** TAPE HEADER **** MWD 02/01/11 01 *** LIS COPIMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: LISTAPE.HED TAPE HEADER ALPINE UNIT MWD/MAD LOGS WELL NAME: API NI/MBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NI/MBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: CD2-24 501032037700 Phillips Alaska, Inc. BAKER HUGHES INTEQ il-JAN-02 MWD RUN 1 MWD RUN 2 1 2 T. DURING B. LACOSTE D. MICKEY D. BURLEY 2 liN 4E MWD RUN 3 3 B. LACOSTE D. BURLEY ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 52.83 15.88 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 2792.0 10822.0 PER PHILLIPS ALASKA INSTRUCTIONS, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. SURFACE LOCATION: LAT: NT0 DEG 20' 19.348" LONG: W151 DEG 2' 27.759" LOG MEASURED FROM D.F. AT 36.95 FT. ABOVE PERM. DATUM (G.L. @ 15.88') . MWD RUNS 1 & 2 ORIGINATE FROM THE PLUG BACK SECTION OF THIS WELLBORE, CD2-24PB1. THE SECOND RUN WAS COMPLETED 09-JUN-01 TO A DEPTH OF 9856' MD (7211' TVD). THAT WELLBORE WAS PLUGGED BACK AND SIDETRACKED AT 8780' MD (6335' TVD). MWD RUN 3 WAS COMPLETED ON 18-JUN-01 AND COVERS THE SIDETRACK PORTION OF THE WELLBORE. COVERS THE SIDETRACK PORTION OF THE WELLBORE. CD2-24PB1 CONSISTS OF MWD RUNS 1 & 2 TO A DEPTH OF 9856' MD (7211' TVD). CD2-24 CONSISTS OF MWD RUNS 1 & 2 TO THE SIDETRACK DEPTH OF 8780' MD (6335' TVD) FOLLOWED BY MWD RUN 3 TO A TOTAL DEPTH OF 10822' MD (7232' TVD). A TOTAL DEPTH OF 10822' MD (7232' TVD). BAKER HUGHES INTEQ RUNS 1 & 2 UTILIZED AUTOTRAC RCLS (ROTARY CLOSED LOOP SYSTEM) WITH DIRECTIONAL, MPR (MULTIPLE PROPAGATION RESISTIVITY), AND MAP (MODULAR ANNULAR PRESSURE) SERVICE TO DRILL OUT THE 9 5/8" CASING AND DRILL FORMATION FROM 2802 - 8780' MD (2378 - 6335' TVD). DUE TO SENSOR TO BIT OFFSET NO FE DATA WAS RECORDED ON BIT RUN 1. BAKER HUGHES INTEQ RUN 3 UTILIZED AUTOTRAC RCLS (ROTARY CLOSED LOOP SYSTEM) WITH DIRECTIONAL, MPR (MULTIPLE PROPAGATION RESISTIVITY), AND MAP (MODULAR ANNULAR PRESSURE) SERVICE TO SIDETRACK FROM THE PILOT HOLE AND DRILL FORMATION FROM 8780 - 10822' MD (6335 - 7232' TVD). 1) THE INTERVAL FROM 2802 - 2822' MD (2378 - 2391' TVD) WAS LOGGED UP TO 8.9 HOURS AFTER BEING DRILLED DUE TO A TRIP TO CHANGE OUT THE AUTOTRAC DRILLING ASSEMBLY. 2) THE INTERVAL FROM 10790 - 10822' MD (7231 - 7232' TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET AT CASING POINT. Tape Subfile: 1 Minimum record length: Maximum record length: 91 records... 8 bytes 132 bytes **** FILE HEADER MWD .001 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! !! ! ! ! ! ! ! ! ! !!!! LDWG File Version 1.000 ! !!! !! ! ! ! ! !! ! ! ! !! ! ! Extract File: FILE001.HED FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUFIMARY PBU TOOL CODE MWD MWD MWD $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 2802.0 2822.0 2822.0 8780.0 8780.0 10822.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 .0 .0 2 2790.0 8715.0 3 8715.0 10790.0 MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. *** INFORMATION TABLE: CONS MNEM VALU WDFN cd2-24.xtf LCC 150 CN PHILLIPS ALASKA, INC. WN CD2-24 FN ALPINE COUN NORTH SLOPE STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM GR GR GRAM ROP ROP ROPS RAD RAD RACL RPD RPD RPCL RAS RAS RACH RPS RPS RPCH FET FET RPTH * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is up (value= 1) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units ODEP ___ 00 00 00 00 00 00 00 Size Length 1 GR MWD 6 8 1 GAP I 4 4 2 ROP MWD 6 8 1 FPHR 4 4 3 RAD MWD 6 8 1 OHM14 4 4 4 RPD MWD 6 8 1 OHMM 4 4 5 RAS MWD 6 8 1 OHMI~ 4 4 6 RPS MWD 68 1 OHM~ 4 4 7 FET MWD 68 1 HRS 4 4 Total Data Records: 522 28 Tape File Start Depth = 10822.000000 Tape File End Depth = 2735.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER Tape Subfile: 2 Minimum record length: Maximum record length: **** FILE HEADER **** lvIWD .002 569 records... 50 bytes 4124 bytes 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SI/MMARY VENDOR TOOL CODE START DEPTH MWD 2790.0 $ 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): STOP DEPTH 8715.0 09-JUN-01 MSL 30399 6.75 ATK MEMORY 8780.0 2790.0 8715.0 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 24.5 51.0 VENDOR TOOL CODE TOOL TYPE TOOL NI/MBER DIR DIRECTIONAL RNT PROPAGATION RESIST. RNT 20016 GRAM GAMMA RAY RNT 20016 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MIID TYPE: IvIUD DENSITY (LB/G): S): PPM): MUD VISCOSITY MUD PH: MUD CHLORIDES FLUID LOSS (C3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 8.500 2792.0 FW LIGNO 9.75 .0 .0 2600 .0 .000 .000 .000 .000 .00 .000 .0 .0 .0 .0 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): REMARKS: BIT RUN 2. GR/RNT. BIT RUN 1 WAS RECORDED WHILE DRILLING OUT CASING AND NO FE DATA WAS RECORDED. THERFORE, NO FILE FOR BIT RUN 1 IS PRESENTED. FOR BIT RUN 1 IS PRESENTED. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHFIM) RPCL - DEEP PHASE RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMI~) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ *** INFORMATION TABLE: CONS MNEM VALU WDFN cd2-24.xtf LCC 150 CN PHILLIPS ALASKA, INC. WN CD2-24 FN ALPINE COUN NORTH SLOPE STAT Alaska. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM GRAM GRAM GRAM ROPS ROPS ROPS RACL RACL RACLM RPCL RPCL RPCLM RACH RACH RACHM RPCH RPCH RPCHM RPTH RPTH RPTHM * FORMAT RECORD (TYPE# 64) ODEP O0 O0 O0 O0 O0 O0 O0 Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is up (value= 1) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size 1 GRAM MWD 68 1 GAPI 4 2 ROPS MWD 68 1 FPHR 4 3 RACL MWD 68 1 OHPIM 4 4 RPCL MWD 68 1 OHFIM 4 5 RACH MWD 68 1 OHMI~ 4 6 RPCH MWD 68 1 OHMM 4 7 RPTH MWD 68 1 MINS 4 Total Data Records: 386 Length 28 Tape File Start Depth = 8715.000000 Tape File End Depth = 2735.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 475 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** MWD .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 8715.0 $ 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: MAXIMI/M ANGLE: TOOL STRING (TOP TO BOTTOM) STOP DEPTH 10790.0 18-JUN-01 MSL 30399 6.75 ATK MEMORY 10822.0 8715.0 10790.0 0 49.4 88.0 VENDOR TOOL CODE TOOL TYPE TOOL NLTMBER DIE DIRECTIONAL RNT PROPAGATION RESIST. RNT 20016 GRAM GAlV~LA RAY RNT 20016 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 2792.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY MUD PH: MUD CHLORIDES FLUID LOSS (C3 S): PPM): RESISTIVITY (OHPIM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: BIT RUN 3. GR/RNT. FW LIGNO 10.15 .0 .0 1200 .0 .000 .000 .000 .000 .00 .000 .0 0 .0 .0 .0 .0 CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP PHASE RESISTIVITY (OHM~i) RACH - SHALLOW ATTENUATION RESISTIVITY (OHFIM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ *** INFORMATION TABLE: CONS PINEM VALU WDFN cd2-24.xtf LCC 150 CN PHILLIPS ALASKA, INC. WN CD2-24 FN ALPINE COUN NORTH SLOPE STAT Alaska *** INFORMATION TABLE: CIFO MI~EM CHAN DIMT CNAM ODEP GRAM GRAM GRAM ROPS ROPS ROPS RACL RACL RACLM RPCL RPCL RPCLM RACH RACH RACHM RPCH RPCH RPCHM RPTH RPTH RPTHM FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is up (value= 1) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GRAM MWD 68 1 GAPI 2 ROPS MWD 68 1 FPHR 3 RACL MWD 68 1 OHM~i 4 RPCL MWD 68 1 OHMM 5 RACH MWD 68 1 OHM~i 6 RPCH MWD 68 1 OHF~I 7 RPTH MWD 68 1 MINS Total Data Records: 136 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 4 4 28 Tape File Start Depth = 10822.000000 Tape File End Depth = 8715.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 4 Minimum record length: Maximum record length: **** TAPE TRAILER **** MWD 02/01/11 221 records... 50 bytes 4124 bytes 01 **** REEL TRAILER **** MWD 02/02/20 AWS 01 Tape Subfile: 5 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes **** REEL HEADER **** MWD 02/02/20 AWS 01 **** TAPE HEADER **** MWD 02/01/11 01 *** LIS COPIMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: LISTAPE.HED TAPE HEADER ALPINE UNIT FfWD / MAD LOGS WELL NAME: API hKIMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: CD2-24 501032037700 Phillips Alaska, Inc. BAKER HUGHES INTEQ il-JAN-02 MWD RUN 1 MWD RUN 2 1 2 T. DURING B. LACOSTE D. MICKEY D. BURLEY 2 lin 4E MWD RUN 3 3 B. LACOSTE D. BURLEY ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 52.83 15.88 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 2792.0 10822.0 PER PHILLIPS ALASKA INSTRUCTIONS, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. SURFACE LOCATION: LAT: N70 DEG 20' 19.348" LONG: W151 DEG 2' 27.759" LOG MEASURED FROM D.F. AT 36.95 FT. ABOVE PERM. DATUM (G.L. @ 15.88') . MWD RUNS 1 & 2 ORIGINATE FROM THE PLUG BACK SECTION OF THIS WELLBORE, CD2-24PB1. THE SECOND RUN WAS COMPLETED 09-JUN-01 TO A DEPTH OF 9856' MD (7211' TVD). THAT WELLBORE WAS PLUGGED BACK AND SIDETRACKED AT 8780' MD (6335' TVD). MWD RUN 3 WAS COMPLETED ON 18-JUN-01 AND COVERS THE SIDETRACK PORTION OF THE WELLBORE. COVERS THE SIDETRACK PORTION OF THE WELLBORE. CD2-24PB1 CONSISTS OF MWD RUNS 1 & 2 TO A DEPTH OF 9856' MD (7211' TVD). CD2-24 CONSISTS OF MWD RUNS 1 & 2 TO THE SIDETRACK DEPTH OF 8780' MD (6335' TVD) FOLLOWED BY MWD RUN 3 TO A TOTAL DEPTH OF 10822' MD (7232' TVD). A TOTAL DEPTH OF 10822' MD (7232' TVD). BAKER HUGHES INTEQ RUNS 1 & 2 UTILIZED AUTOTRAC RCLS (ROTARY CLOSED LOOP SYSTEM) WITH DIRECTIONAL, MPR (MULTIPLE PROPAGATION RESISTIVITY), AND MAP (MODULAR ANNULAR PRESSURE) SERVICE TO DRILL OUT THE 9 5/8" CASING AND DRILL FORMATION FROM 2802 - 8780' FID (2378 - 6335' TVD). DUE TO SENSOR TO BIT OFFSET NO FE DATA WAS RECORDED ON BIT RUN 1. BAKER HUGHES INTEQ RUN 3 UTILIZED AUTOTRAC RCLS (ROTARY CLOSED LOOP SYSTEM) WITH DIRECTIONAL, MPR (MULTIPLE PROPAGATION RESISTIVITY), AND MAP (MODULAR ANNULAR PRESSURE) SERVICE TO SIDETRACK FROM THE PILOT HOLE AND DRILL FORMATION FROM 8780 - 10822' MD (6335 - 7232' TVD). 1) THE INTERVAL FROM 2802 - 2822' MD (2378 - 2391' TVD) WAS LOGGED UP TO 8.9 HOURS AFTER BEING DRILLED DUE TO A TRIP TO CHANGE OUT THE AUTOTRAC DRILLING ASSEMBLY. 2) THE INTERVAL FROM 10790 - 10822' MD (7231 - 7232' TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET AT CASING POINT. Tape Subfile: 1 Minimum record length: Maximum record length: 91 records... 8 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMlV~ENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE S LrMNLARY PBU TOOL CODE MWD MWD MWD $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 2802.0 2822.0 2822.0 8780.0 8780.0 10822.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 .0 .0 2 2790.0 8715.0 3 8715.0 10790.0 MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. *** INFORMATION TABLE: CONS MNEM VALU WDFN cd2-24.xtf LCC 150 CN PHILLIPS ALASKA, INC. WN CD2-24 FN ALPINE COUN NORTH SLOPE STAT Alaska INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ........ GR GR GRAM ROP ROP ROPS RAD RAD RACL RPD RPD RPCL RAS RAS RACH RPS RPS RPCH FET FET RPTH ODEP 0 0 0 0 0 0 0 0 0 0 0 0 0 0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is up (value= 1) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 GAPI 2 ROP MWD 68 1 FPHR 3 RAD MWD 68 1 OHFIM 4 RPD MWD 68 1 OHMM 5 RAS MWD 68 1 OHMM 6 RPS MWD 68 1 OHM14 7 FET MWD 68 1 }IRS Size Length 4 4 4 4 4 4 4 4 4 4 4 4 4 4 28 Total Data Records: 522 Tape File Start Depth = 10822.000000 Tape File End Depth = 2735.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .002 569 records... 50 bytes 4124 bytes 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUPIMARY VENDOR TOOL CODE START DEPTH MWD 2790.0 $ 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) : STOP DEPTH 8715.0 09-JUN-01 MSL 30399 6.75 ATK MEMORY 8780.0 2790.0 8715.0 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMLrM ANGLE: TOOL STRING (TOP TO BOTTOM) 24.5 51.0 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DIR DIRECTIONAL RNT PROPAGATION RESIST. RNT 20016 GRAM GAMMA RAY RNT 20016 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 2792.0 BOREHOLE CONDITIONS MUD TYPE: FW LIGNO MUD DENSITY (LB/G): 9.75 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 2600 FLUID LOSS (C3): .0 RESISTIVITY (OHFIM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TEMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 .0 .0 .0 .0 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): REMARKS: BIT RUN 2. GR/RNT. BIT RUN 1 WAS RECORDED WHILE DRILLING OUT CASING AND NO FE DATA WAS RECORDED. THERFORE, NO FILE FOR BIT RUN 1 IS PRESENTED. FOR BIT RUN 1 IS PRESENTED. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP PHASE RESISTIVITY (OHMI~) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMI~) RPCH - SHALLOW PHASE RESISTIVITY (OHPIM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ *** INFORMATION TABLE: CONS FINEM VALU WDFN cd2-24.xtf LCC 150 CN PHILLIPS ALASKA, INC. WN CD2-24 FN ALPINE COUN NORTH SLOPE STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAM GRAM GRAM ROPS ROPS ROPS RACL RACL RACLM RPCL RPCL RPCLM RACH RACH RACHM RPCH RPCH RPCHM RPTH RPTH RPTHM * FORMAT RECORD (TYPE# 64) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is up (value= 1) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GRAM MWD 68 1 GAPI 2 ROPS MWD 68 1 FPHR 3 RACL MWD 68 1 OHMM 4 RPCL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 RPCH MWD 68 1 OHMM 7 RPTH MWD 68 1 MINS Total Data Records: 386 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 4 4 28 Tape File Start Depth = 8715.000000 Tape File End Depth = 2735.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 475 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** MWD .003 1024 *** LIS COM~ENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 8715.0 $ 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: STOP DEPTH 10790.0 TOOL STRING (TOP TO BOTTOM) 18-JUN-01 MSL 30399 6.75 ATK MEMORY 10822.0 8715.0 10790.0 0 49.4 88.0 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DIR DIRECTIONAL RNT PROPAGATION RESIST. RNT 20016 GRAM GAMMA RAY RNT 20016 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 2792.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY MUD PH: MUD CHLORIDES FLUID LOSS (C3 S): PPM): RESISTIVITY (OHiVlM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: BIT RUN 3. GR/RNT. FW LIGNO 10.15 .0 .0 1200 .0 .000 .000 .000 .000 .00 .000 .0 0 .0 .0 .0 .0 CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP PHASE RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHPIM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ *** INFORMATION TABLE: CONS MNEM VALU ......... WDFN cd2-24.xtf LCC 150 CN PHILLIPS ALASKA, INC. WN CD2-24 FN ALPINE COUN NORTH SLOPE STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM GRAM GRAM GRAM ROPS ROPS ROPS RACL RACL RACLM RPCL RPCL RPCLM RACH RACH RACHM RPCH RPCH RPCHM RPTH RPTH RPTHM * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is up (value= 1) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GRAM MWD 68 1 GAPI 2 ROPS MWD 68 1 FPHR 3 RACL MWD 68 1 OHM~ 4 RPCL MWD 68 1 OHIO4 5 RACH MWD 68 1 OHMM 6 RPCH MWD 68 1 OHMS4 7 RPTH MWD 68 1 MINS Total Data Records: 136 ODEP 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 4 4 28 Tape File Start Depth = 10822.000000 Tape File End Depth = 8715.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 4 Minimum record length: Maximum record length: **** TAPE TRAILER **** MWD 02/01/11 01 221 records... 50 bytes 4124 bytes **** REEL TRAILER **** MWD 02/02/20 AWS 01 Tape Subfile: 5 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes