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Home My WebLink About202-074Originated: Delivered to:31-Jan-26Alaska Oil & Gas Conservation Commiss31Jan26-NR !"#$$%$ !&$$'($)*%+ ($)*%,-.WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED3S-08C 50-103-20450-03-00 207163 Kuparuk River WL Cutter FINAL FIELD 5-Jan-263S-08C 50-103-20450-03-00 207163 Kuparuk River WL SCMT FINAL FIELD 6-Jan-263S-08C 50-103-20450-03-00 207163 Kuparuk River WL IBC-ASLT FINAL FIELD 12-Jan-26CD4-210B 50-103-20533-02-00 217182 Colville River WL LDL FINAL FIELD 19-Jan-26CD2-25 50-103-20418-00-00 202074 Colville River WL RBP-MechCutter FINAL FIELD 21-Jan-26CD1-40 50-103-20298-00-00 199044 Colville River WL RBP-MechCutter FINAL FIELD 24-Jan-263S-624 50-103-20868-00-00 223104 Kuparuk River WL MechCutter FINAL FIELD 26-Jan-26Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1Please return via courier or sign/scan and email a copy to Schlumberger."2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8" ! - +"8#!(3 . 8)"3 8#!9 3 : 8" +868 8 "8#!;" " 3 - 3" 3""+ 3 + <+3!% T41299T41299T41299T41300T41301T41302T41303CD2-2550-103-20418-00-00202074Colville RiverWLRBP-MechCutterFINAL FIELD21-Jan-26Gavin GluyasDigitally signed by Gavin Gluyas Date: 2026.02.02 09:10:17 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2024-02-03_23014_CRU_CD2-25_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23014 CRU CD2-25 50-103-20418-00 Caliper Survey w/ Log Data 03-Feb-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 202-074 T38486 2/7/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.07 16:16:31 -09'00' ry 0 p r _ r WSW 3 c 0---LU - cu CO Q vv O I¢-,\�Qp Y -JZ_: 4- 4- 4- 01) _- H > DVS �A O v @ O Q = 0 o a o RC aCC❑ ` o E i m ', H' WI 1, YN N O a-+a HO o lC o. teC C (p ~ Wa2Q W a-+ -Ofl. a) c Zi" t0 - O @vNNM Q it)i C d Ou v O Ou . ❑ ❑ ❑ N a V W: 6 W J J J C +., >, W W_ W_ pp C co O 4444 '. 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Q 0 N U U N Z al 03 v .-, Cu p m s7 ami cra STATE OF ALASKA • ALOA OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E 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 (] Exploratory ❑ 202-074 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage, AK 99510 50-103-20418-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075, 387212 CRU CD2-25 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 11994 feet Plugs measured None feet true vertical 7161 feet Junk measured None feet Effective Depth measured 11994 feet Packer measured 7761 feet true vertical 7161 feet true vertical 6940 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2344' 9.625" 2381' 2375' Intermediate Production 8687' 7" 8722' 7211'SCANNED SEP 2 12016 Liner Perforation depth Measured Depth: Perfs from 8084'- 8097', Open Hole Completion 8722'- 11994' True Vertical Depth: Perfs from 7082'-7086', Open Hole Completion 7211'-7161'RECEIVED Tubing(size,grade,measured and true vertical depth) 4.5", L-80, 7882' MD, 6999'TVD MAY 2 7 2016 Packers and SSSV(type,measured and true vertical depth) Packer: Baker S-3, 7761' MD, 6940'TVD AOGCC SSSV: WRDP, 2013' MD, 2007'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8722'- 11994' MD 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: 612 90 448 1498 222 - Subsequent to operation: 587 81 456 1303 225 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory❑ Developments Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El 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: N/A Contact Kerry Freedman Email Kerry.C.Freedman@a,cop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature , . car- 4./'r7- f,« ,Y� Phone 265-6579 Date 06 44% RBDMS Lv MAY 3 1 2016 Form 10-404 Revised 5/2015 Submit Original Only • • CD2-25 Scale Inhibition Treatment 4/28/16 Hybrid Scale Inhibitor Squeeze Job pumped 4/28/16 from 08:00 to 19:30 hrs. LRS= Little Red Services - Initial pressure TBG/IA/OA—261/1137/760 - LRS pumped 119 bbls Diesel/WAW5206/M209 preflush at 2 bpm,TBG/IA/OA-0/725/740 - LRS pumped 119 bbls Seawater/SCW3001 scale inhibitor main treatment at 2 bpm, TBG/IA/OA— 0/681/730 - LRS pumped 1320 bbls Dead Crude/M209 overflush at 2—2.5 bpm,TBG/IA/OA—8/723/710 Interval treated: 8722'—11994' MD WNS PROD • CD2-25 Y' ConacoPhillips Well AttributesMax Angle&MD TD AIiSF i,If lt;, Wellbore API/t1WI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) conomat-det, 501032041800 ALPINE PROD 96.26 11,935.24 11,995.0 --. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date CD2-25,4/28/20164.14:19 PM SSSV:WRDP Last WO: 44.14 4/23/2002 - Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WRDP C/O ppmven 4/28/2016 .= Casing Strings HANGER;33.1 s li ® Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread I ECONDUCTOR 16 15.062 37.0 1140 114.0 109.00 H-40 WELD ° Caning Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread �^ SURFACE 9 5/8 8.921 36.6 2,380.9 2,374.9 36.00 J-55 BTC • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TM)...Wt/Len(I...Grade Top Thread ) � ifff' PRODUCTION 7 6.276 35.2 8,721.7 7,2107 26.00 L-80 MBTC '1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I.. Grade Top Thread '`{{° OPEN HOLE 61/8 8,721.7 11,994.0 7,160.7 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection iR TUBING 41/2 3.958 33.1 7,882.2 6,999.1 12.60 L-80 IBTM Completion Details CONDUCTOR 3].0-114.0 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°I Item Des Com (in) • 33.1 33.1 0.00 HANGER FMC TUBING HANGER 4.500 • • • 2,012.6 2,007.1 5.21 NIPPLE CAMCO BAL-O SSSV 3.812 NIPPLE,2,012.6 - 7,654.2 6,884.8 57.48 SLEEVE-C BAKER CMD X-PROFILE SLEEVE-CLOSED 2/25/2007 3.813 W RDP;2,0126, _4...,1, 7,761.2 6,940.4 59.91 PACKER BAKER S-3 PACKER 3.875 7,765.0 6,942.3 59.96 MILLOUT BAKER MILLOUT EXTENSION 4.500 7,869.5 6,993.2 62.18 NIPPLE HES XN NIPPLE 3.725 7,880.9 6,998.5 62.66 WLEG BAKER WIRELINE GUIDE 3.958 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) _ (ftKB) ("t Des Com Run Date ID(in) 2,012.6 2,007.2 5.21•WRDP 3.81"DB LOCK ON WRDP(HVS-243) 4/17/2016 2.110 SURFACE,36.6-2,380 9-21 IL Perforations&Slots Shot Dens Top(ND) Ben(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT,3,432.78,084.0 8,097,0 7,081.5 7,086.1 10/19/2013 6,0 IPERF 3-3/8"HSC,phased 60 I deg,Millenium II DP Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Bee(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 8,722.0 11,994,0 7,210.7 7,160.7 FRAC -3/2/2007 C-SAND OPEN HOLE FRAC w/GELLED WATER& 16/30 WHITE SAND,TOTAL SLURRY 2784 BBLS- GAS LIFT:5,751 6 - 316581#TOTAL SANDS w/315910#IN FORMATION Mandrel Inserts II St i on Top(ND) Valve Latch Port Sine TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1� 3,432.7 3,426.6 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000- 0.0 12/18/2006 GAS LIFT;7 546.6 2 5,751.6 5,694.4 CAMCO KBG-2 1 GAS LIFT GLV BTM 0.188 1,950.0 7/24/2012 3 7,546.6 6,826.5 CAMCO KBG-2 ' 1 GAS LIFT OV BK 0.250 0.0 7/24/2012 << Notes:General&Safety ('. End Date Annotation f t 8/31/2010 NOTE:View Schematic w/Alaska Schematic9.0 SLEEVE-0,7,654.2 { j E' PACKER,7,761.2 ® - MILLOUT;7,765.0 rg I NIPPLE;7,869.5 A E. al W LEG;7,880.9 I PERF;8,084.0-8,0970--- tie,- -es PRODUCTION', ---11114. AZ FRAC,8 722 0 L.... OPEN HOLE 8,721 7-11 994 0 s , STATE OF ALASKA ALA. ■OIL AND GAS CONSERVATION COMh. JION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other r Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development f Exploratory r 202-074 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20418-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075,387212 , _ CD2-25 - 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 11995 feet Plugs(measured) none true vertical 7161 feet Junk(measured) none Effective Depth measured 11995 feet Packer(measured) 7761 true vertical 7161 feet (true vertical) 6940 Casing Length Size MD ND Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2344 9.625 2381 2375 PRODUCTION 8687 7 8722 7211 RECEIVED NOV 12 2013 SCANNED ,' ', ,. : ''t ;-' Perforation depth: Measured depth: 8084'-8097' O(,CC A True Vertical Depth: 7082'-7086' A'6V MM vv Tubing(size,grade,MD,and ND) 4.5, L-80, 7882 MD,6999 ND Packers&SSSV(type,MD,and ND) PACKER-BAKER S-3 PACKER @ 7761 MD and 6940 ND NIPPLE-CAMCO BAL-O SSSV @ 2013 MD and 2007 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze for this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 691 3095 161 -- 240 Subsequent to operation 709 3021 187 -- 233 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r - Service r Stratigraphic r 16.Well Status after work: Oil p- Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Dan Kolesar I,p7,263-4039 Email Daniel.Kolesar@conocophillips.com Printed Name Dan Kol r Title WNS Production Optimization n neer Signature I Phone:263-4039 Date (3�(l�2.u l'Ll" RBDMS NOV 1 9 0� / // 7- i , 13 Form 10-404 Revised 10/2012 F, Submit Original Only 100 e WNS PROD CD2-25 ConocOPhillip5 �'? Well Attributes Max Angle&MD TD Alaska,Inc. Weubore API/UWI Field Name Wellborn Status Intl(°) MD OMB) Act Bun(ftKB) conocvtul3ps 501032041800 ALPINE PROD 9626 11,935.24 11,995.0 _ --- Comment 1125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD2.25.111620138:0/18 AM $SSV:WRDP Last WO: 44.14 4,232002 Vernon iClema'ic(aPUaf Annotation Depth(RI(B) End Data Annotation Last Mod By End Date Last Tag: I I Rev Reason:UPDATE PERF DEPTHS lehallf I 11/62013 l Casing Strings / r Casing Description OD(in) 10(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread l '»- CONDUCTOR 16 15.062 37.0 114.0 114.0 109.00 H-40 WELD HANGER;33,1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread SURFACE 9518 8.921 36.6 2,380.9 2.374.9 36.00 J-55 BTC Casing Description OD(in) ID(In) Top MKS) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 352 8,721.7 72107 26.00 L-80 MBTC +� Gsing Description OD(in) ID(in) Top MKS) Set Depth(ftKB) Set Depth(TVD)...Wt/Len II..-Grade Top Thread I OPEN HOLE 61/8 8,721.7 11,994.0 7,150.7 Tubing Strings Tubing Description Strang Ma...ID(in) Top(ftKB) Set Depth(ft..1 Set Depth(TVD)(...VA(/SW) Grade Top Connection TUBING 412 3.958 331 7,882211) 6,999.1 12.60 L-80 IBTM Completion Details CONDUCTOR;37.0.114.0 Top)SCSI Top(ND)(ftKB) Tap Inc,(•1 Item Dos Com No(in)I ID 33.1 33.1 0.00 HANGER FMC TUBING HANGER 4.500 2,012.6 2,007.1 521 NIPPLE CAMCO BAL-O SSSV 3.812 7,654.2 6,884.8 5748 SLEEVE-C BAKER CMD X—PROFILE SLEEVE-CLOSED 22512007 3.813 NIPPLE:a 012.6 t4RDF;2.012.6 7,761.2 6,9404 59.91 PACKER BAKER S-3 PACKER 1875 7.765.0 6,942.3 59.96 MILLOUT BAKER MILLOUT EXTENSION 4.500 7,869.5 6,993.2 62.18 NIPPLE HES XN NIPPLE 3.725 7,880.9 6,998.5 62.66 WLEG BAKER WIRELINE GUIDE 3.958 Other In Hole reline retrievable plugs,valves,pumps,fish,etc.) Top(1VD) Top Incl Ai Top Itt/6) (tIKS) (°) Des Com Run Date ID(in) 2,012.6 2.007.2 5.27 WRDP 3.81'DB LOCK ON WRDP(HVS-270) 10/232013 2.110 sURFAC e,3652,3609— ' Perforations&Slots Shot ...--� Dena Top(TVD) Otm(TVD) (sr ts/I Top(ftKB) Btm(ftKB) OMB) (MB) Zone Date t) Type Corn GAS LIFT,3,632.7 8,084.0 8,0970 7,081.5- 7,086.1 ALB96,CD2- 10/192013 6.0 [PERF 3-3/8"HSC,phased 60 25 deg,Millenium II DP j Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVO) BIM(TVO) MKS) (ftKB) (ftKB) PIKER Type Cute Corn 8,722-0 11,994.0 7.210.7 7,1507 FRAC 3/22007 C-SAND OPEN HOLE FRAC w/GELLED WATER 8 16/30 WHITE SAND,TOTAL SLURRY 2784 BBLS- DOS UFT,5,751.6 316581#TOTAL SANDS w/315910#IN FORMATION 1 Mandrel Inserts St as c on I No Top(TVD) Valve Latch Port Site TRO Run Top(Itl(B) ((MB) Make Model OD(in) Sory Type Type (In) (psi) Run Date m 1 1 34327 3,426.6 CAMCO -KB0-2 1 GAS LIFT DMY BK-5 0.000 00 12/182006 GAS LIFT:7.5,6.9 2 5,751.6 5,694.4 CAMCO KBG-2 1 GAS LIFT GLV BIM 0.188 1,950.0 7/2412012 3 7,5466.6 6,826.5 CAMCO KBG-2 1 GAS LIFT OV 6K 0.250 0.0 7/2420/2 Notes:General&Safety End Date Annotation 8/312010 NOTE:View Schematic w/Alaska Schematic9.0 SLEEVE-C,7.654.2 t`( ir PACKER;7,761.2 MILLOUT:7.705U NIPPLE:7469.5 WLEG;7.680.9 Peep a 060.0.5.0970 - . �— I I PRODUCTION,351-8.721.7-4 e e a a FRAC:8.7220�aa^eral I OPEN HOLE:8,721.7-11,990.5 CD2-25 Well Work Summary DATE SUMMARY 10/18/2013 PULLED WRDP @ 2012' RKB, DRIFT OUT TBG TO 8150' SLM w 3.64"CENT,(BARBELL SETUP TO IMMITATE PERF GUNS, OAL 14'), COMPLETE 10/19/2013 PERFORATE INTERVAL 8084'-8097' USING 3-3/8" HSC LOADED 6 SPF, PHASED 60 DEG, MILLENIUM II DP CHARGES. LOG CORRELATED TO SPERRY DGR DUAL GAMMA RAY LOG DATED 17 OCT 2002. TOOLSTRING STUCK IN XN NIPPLE AT 7870', TOP OF TOOL AT 7839'. 10/21/2013 LATCHED FISH w/BAITSUB @ 7813'SLM. ATTEMPTED TO POOH. FISH APPEARS TO HAVE FALLEN BELOW XN @ 7870' RKB. IN PROGRESS. 10/22/2013 PULLED ELINE TOOLSTRING AND SPENT GUN f/8436' SLM. SET WRDP @ 2013' RKB AND PULLED SAME. IN PROGRESS. 10/23/2013 B& F BAL-O AND SET WRDP(HVS-270)@ 2013' RKB. CLOSURE TEST PASSED. REOPENED SSSV. COMPLETE. • • ConocoPhillips Alaska P.O. BOX 100360 ECEJ\ D ANCHORAGE, ALASKA 99510 -0360 April 01, 2011 Atka 3 & 6a Cons. CO P iSSijj ' rcoorbg@ Commissioner Dan Seamount Alaska Oil & Gas Commission t APR 1 333 West 7 Avenue, Suite 100 •� b 40 L Anchorage, AK 99501 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 CD2 -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 5'10" 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 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate [] . Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D 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 []~ Exploratory D 202-0741 .' 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20418-00 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 53' CD2-25 . 8. Property Designatio~: 10. Field/Pool(s): ADL 380075,387212 Colville River Field 1 Alpine Oil Pool . 11. Present Well Condition Summary: Total Depth measured 11995' feet true vertical ~~ feet Plugs (measured) Effective Depth measured ..¡.4.P feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2338' 9-5/8" 2391' PRODUCTION 8669' 7" 8722' OPEN HOLE 3272' 6-1/8" 11994' Perforation depth: Measured depth: 5CANNED APR 1 1 2007 true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7882' MD. Packers & SSSV (type & measured depth) Baker 'S-3' Packer set at 7761' SSSV= NIPPLE SSSV= 2013' 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-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation 1,622 . 1,711 o Bbls 616 270 Subsequent to operation 5,281 5,500 o Bbls 1081 323 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ D [] - D Exploratory Development Service Daily Report of Well Operations _X 16. Well Status after work: Oil[] - GasD WAGD GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/~if C.O. Exempt: ;; /.'/ , .-::..; () 7 -C'c-~$ ,-/ii./?;?, ~/ £'é'}' (? / Contact Tim Schneider Printed Name -7a1er Title Production Engineer 'i-t-tO-- Signature " I/'. ;....ÞL.. Phone 265-6859 Date .. Prepared bv Jeanne L. Haas 263-4470 .~ -- RBDfIllS BFt APR J 0 Z007 ~\{ .~ "¡''l-ó7 su~~~~, Form 10-404 Revised 04/2006 '" . . " CD2-25 Stimulation results: Summary of stimulation job: 3-02-07: Pump frac stages in stair steps; 2,4, & 7 PPA, 2784 bbls total slurry, 751 bbls diesel for freeze protect.. AIR-38 BPM, AIP-2750 psi, ISIP-1602 psi. 315,000Ibs. 16/30 White Sand in perfs. Well test 3/13/07: 5281 bopd, 0. bwpd, 5.5 mmcfpd, 323 psi WHP . . RECEIVED APR. 0 2 Z007 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONs1aska Oil & Gas Cons. Commission Plug Perforations D Perforate New Pool D Perforate D 4, Current Well Status: [] Stratigraphic D STATE OF ALASKA Repair Well D Pull Tubing D Operat. ShutdownD 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2, Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 53' 8. Property Designation: ADL 380075& 387212 ' 11. Presént Well Condition Summary: Total Depth 11995' . feet r ~'1 f~ 'hI) feet I: 01 ".J' feet feet measured true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SURFACE PRODUCTION OPEN HOLE Length Size MD 114' 2338' 16" 9-5/8" 7" 6-1/8" Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) SSSV: 12. Stimulation or cement squeeze summary: Intervals treated (measured) Stimulate [] Waiver D Other Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: " Exploratory D Service D 202-074 1 6. API Number: 50-103-20418-00 9. Well Name and Number: CD2-25 10. Field/Pool(s): Colville River Field 1 Alpine Oil Pool Plugs (measured) Collapse Burst . 4' ,/1 q.tí'\ J- 4, r 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1,622 1,711 0 Bbls 616 270 Subsequent to operation 5,281 .I 5.500 0 Bbls 1081 323 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development [] Service D Daily Report of Well Operations _X_ 16. Well Status after proposed work: Oil[] GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C,O. Exempt: 307-055 Contact Tim Schneider Tim Schneider Title Phone Printed Name Signature RIG 1 N .4 L Form 1 Production Engineer 265-6859 Date «2-0 ;Z Pre ared b Jeanne L. Haas 263-4470 DDnuc;, - ~ c/. J. Þ7 ~ 8Ft APR ] 0 20D7 SUbm~ ~ßß/ , ,; . . CD2-25 Stimulation results: Summary of stimulation job: 3-02-07: Pump frac stages in stair steps; 2,4, & 7 PPA, 2784 bbls total slurry, 751 bbls diesel for freeze protect.. AIR-38 BPM, AIP-2750 psi, ISIP-1602 psi. 315,000Ibs. 16/30 White Sand in perfs. Well test 3/13/07: 5281 bopd, 0 bwpd, 5.5 mmcfpd ,323 psi WHP . . ConocJ'Phillips Alaska "I¡ )?, I· ~ !..'1..i;.,! P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ,~ftl !¡;:n~. ¡';Mm~~ß.ÌI»,ij 1;í1î3" ",00;), J;mr!fiIT~í)3!{1J1! ,lwæmill March 24, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AI< 99501 SCANNED MAH 2 8 Z007 ~-D1~ Dear Mr. Maunder: ,. ....."...~:-, ,.... . ...~...d.~~....4;'. ø ^ ..,,~...:.o -.", Enclosed please fmd 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 respectively was coated with a corrosion inhibiter, RG2401 engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on March 21st, 2007. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor sealant was pumped in a similar manner March 21 st_ 22ß , 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, C27# ~ Arend- ConocoPhillips Well Integrity Field Supervisor ~ Attachment . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Initial top of Well Name PTD # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Initial top of Well Name PTD # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al 03/20/07 Scblumberger NO. 4197 Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 AUn: Beth s{:ANNED APR 1 02007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suit4~ 100 Anchorage, AK 99501 dOd -ò7-« Field: Alpine . Well Job# Log Description Date BL Color Prints CD CD2-25 11632667 LDL 02/24/07 1 CD3-302 11649949 SCMT 03/14/07 1 1'1'''''\ r"" I ¡"'!¡,!r:"'n lfL 'm 1 t! '\L,.\ IJ' ~"''',. R .~~ f1,., ", ~..,4' . --~ /') ¡{Ida Oil (\! 1,,&'5 (.\J\i¡';, Clßh¡m¡~¡GR And10rarl!:! Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. ~ (\ V Q,-- - '-.,/ t11\R 2,,4 zorJ1 SIGNED: DATE: Re: CD2-25 PTD # 202-074 T X IA communication . . Thanks Jerry. Sounds like the communication issue has been resolved. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 2/27/2007 9:56 AM: Tom: An update on CD2-25 communication issue. A Leak Detect Log found the CMD sliding sleeve was leaking @ 7654' md. The sleeve was successfully closed and an MITIA passed on the well while being prepped for a frac. Both an MITT and MITIA passed @ 3500 psi. The next step for this well is a frac before it is put into service. We are not planning any further action regarding the suspected communication problem. Call if you have any questions. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7043 i~ FEe 27 2007 From: NSK Problem Well Supv Sent: Sunday, February 18, 20071:16 PM To: 'Thomas Maunder' Cc: ALP DS LeadjSimops Coord; Schneider, Tim S. Subject: CD2-25 PTD # 202-074 T X IA communication Tom, On 2-17-07, while preparing CD2-25 PTD # 202-074, gas lift producer for a fracture stimulation CPAI discovered pressure communication between the tubing and the Inner annulus. Initial indications are that there is a hole in the tubing between gas lift stations 2 and 1. Initial TIIIO = 275/650/550 psi. CD2-25 has been added to the SCP report. Slickline will continue to troubleshoot the problem. Let me know if you have any questions. Sincerely, Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 1 ofl ~t2-4v1 2/27/2007 12:23 PM Q ~1r~1rŒ (ffi~ ~~~~[ßlA\ . AI,ASIiA. OILAlVD GAS COlVSERVATIOlV COMMISSIOlV SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 Maria Kemner Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 (~"r);~"~ 0 11.\ Re: Colville River Field, Alpine Oil Pool, CD2-25 Sundry Number: 307-055 ~ANNED FEB 1 6 2007 Dear Ms. Kemner: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. J . 0 Ch8.1rman DATED thisfiday of February, 2007 Encl. · 0ì:5 2//1-/7 STATE OF ALASKA -..).{\'\ FEB.O 8 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission APPLICATION FOR SUNDRY APPROVAL Anchorage 20 MC 25.280 Operational Shutdown 0 Plug Perforations 0 Perforate New Pool 0 1. Type of Request: o o o o o o Stimulate Re-enter Suspended Well Time Extension P. O. Box 100360, Anchorage, Alaska 99510 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No [] CD2-25 . 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380075 & 387212 RKB 33' . Colville River Field / Alpine Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11995' . 7161' Casing Length Abandon Suspend Perforate 0 [] Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Repair well Pull Tubing 4. Current Well Class: Development [] Stratigraphic 0 Exploratory 0 Service 0 RECEIVED Waiver o o o Other 0 5. Permit to Drill Number: 202-074 . 6. API Number: 50-103-20418-00 8. Well Name and Number: Size MD TVD CONDUCTOR 114' 16" 114' SURFACE 2338' 9-5/8" 2391' PRODUCTION 8669' 7" 8722' OPEN HOLE 3272' 11994' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 4-1/2" Packers and SSSV Type: Baker 'S-3' Packer Cameo BAL-O Nipple 13. Attachments: Description Summary of Proposal [] Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for Commencing Operations: February 2007 17. Verbal Approval: Date: Commission Representative: 18. I hereby certify that toe foregoing is true and correct to the best of my knowledge. Printed Name / ¡Maria Ke er r /1/ / Signature V 1/ / Packers and SSSV MD (ft) Packer = 7761' MD SSSV= 2013' 14. Well Class after proposed work: Exploratory 0 Development [] 16. Well Status after proposed work: Oil [] Gas 0 WAG 0 GINJ 0 Contact: Title: L Phone 265-6945 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Location Clearance 0 Mechanical Integrity Test 0 Other: Subsequent Form Required: ~'-\ ISSIONER APPROVED BY THE COMMISSION L t> Submit .!Jì¡¡t>u~licate /.. /" ]...{{.o"1 ¿e. .;1,//'-1/07 Date: ~-/~ r- RBDMS Bfl 1 " 200í Approved by: Form 10-403 Revised 06/~6R , Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 7882' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Maria Kemner @ 265-6945 Production Engine r Date 02 D~ D 1- ,. . . Overview: / CD2-25: A hydraulic fracture treatment will be performed in the open hole horizontal section to establish communication vertically and longitudinally through the Alpine"C" sand. This will increase the wells production rate and reserves. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU seven clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 2500 bbls are required for the treatment) 2. Rig up Dowell equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 100 bbl Breakdown with Dowell's YF125ST fluid system. Bring pumps up to maximum rate ASAP. r---t ~ "\ 0 ~'''''''-.J\-~ s ~\J'M.~\V'--~ 5. Pump the following schedule at 30 BPM with a maximum pressure of 9000 psi, add breaker as per lab results. Maintain 3000 psi on the IA during the treatment. ~ Ð-.)\0\\c,,~ ~ .\.-.)\-Ì\f'~ 'o~r-s\ · 300 bbls YF125ST Pad ,- ~ t) \ 'Q ~ · 240 bbls YF125STw/2 ppa 16/30 White Sand · 480 bbls YF125ST w/4 ppa 16/30 White Sand · 1000 bbls YF125ST w/7 ppa 16/30 White Sand · Flush with linear YF125ST and freeze protect >15aoo~,>\ h }:7Vv1~/ t ....., Total Sand: -310,000Ibs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. FCC if required with slick diesel. e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc ')J /Vl') 2- a ð ~( DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Permit to Drill 2020740 Well Name/No. COLVILLE RIV UNIT CD2-25 Qperator CONOCOPHILLlPS ALASKA INC S(;14 d. ~ ~ Æ<kJ ^ API No. 50-103-20418-00-00 MD 11995'-- TVD 7161 /' Completion Date 4/23/2002 /" Completion Status 1-01L -~-- ------"---- REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Electr Digital Dataset Med/Frmt Number D Log/ Data Type ¡'eö LRpt ~D !~ cjeD C Log Log Run Scale Media No 1 Name Directional Survey Directional Survey 11157 LIS Verification LIS Verification 11396 See Notes l__- Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION v@) Daily History Received? Well Cored? Chips Received? ~ Formation Tops Analysis Received? _v I N --- Comments: - ~ Compliance Reviewed By: Current Status 1-01L UIC N Directional Survey @ L,...--- (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Received Comments 0 11994 Open 5/24/2002 0 11994 Open 5/24/2002 2360 11950 Open 10/3/2002 2360 11950 Open 10/3/2002 2391 11994 Open 12/13/2002 Digital Well Logging Data / Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity -' Sample Set Number Comments ~N (f)N Date: J '-I ~ ,Z~ '-'\ ) ') ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 DEPTH VOLUME TYPE SACKS ~---_._-" _. BBlS Cement CD1-1 2.25' 0.3 WI 1.8 .--- .----.-- CD1-2 4' 0.6 WI 3.6 CD1-3 10' 1.4 MI 8.5 CD1-4 7.33' 1 P 6.0 C01-5 4' 0.6 MI 3.6 CD1-6 10.42' 1.4 GI 8.5 CD1-16 14.33' 2 WI 12.1 _~_n'___- CD1-17 8.75' 1.2 P 7.2 - -- CD1-21 13' 1.8 MI 10.9 --'.-.- -,--..---.,.-.'---'---- .--------.----.-------.--.-...----.--- CD1-22 1.83' 0.3 P 1.8 -..---.---.--"------ -.-,- ------ CD1-23 15.42' 2.1 MI 12.7 CD1-24 2' 0.3 P 1.8 ------ CD1-25 5.66' 0.8 P 4.8 ----- -------.. ---- dO(y-~~_Çi>1-27 1~:_~~~----_._._-_..___~:6 P 15.7 CD1-28 6.75' 1 P 6.0 ----~-------"-"'-'-'--" ----"---"--"--------""-"'--'---- \ ~~-\ol.{ ._gi'J.-32 ~.:_~.~:' ._-_!.~?_------_.I.:_.._-----_.Z'_?- JaQ'-(J'-\.~ CD1-34__4J.83' 5.7 P 34.4 "" .. ......., ". ~~<;-\\) CD1-36 16.75' 2.3 WI 13.9 -.- .---.-..-.---.,.--.'--'-------"'-"'-"-- -----.---- étc()'-DD~~- CD1-~?_._-----~:§-~---- 0.5 P 3.0 \~ ~- \ \ <; __SD 1-42 ~_~~9':"_____---_._----Q~----~--_._._------~~- dCJ;)-,-\~,:\ i \X>~\~ --§§~~~~~~'----~-~ ~:: :~3 195~ . ;) t)d--\ ~ d d ~~~~:-!Ii3f=~~-=:11=--=--=-=~~===~=:I7- J~- ~~) -ç.~?:'??_-_._J~~§~---__.___1ß___..__._.__!~~------ -_____t9~~_- Jöd~~ '-\ ¡ CD2-?L-___?7.2~.~__._----~-~?_--_._-- P ._---_____?2.3 c- JD \ "':ð~") _CD~-26 .J_9-.:~~___--_._~.4 INJ._- __~.5 JQ ~ d .) _ÇD?~~~__..__._.._~-~~:'_.__._. _...____J_:.2 !~.J _____l:.?_- \ ;}.o\ -\)~_ÇD2:~~-='m~_-.?:~_----~-~~-~---~:~ dO . -\ ~ \ lo CD2-34 -----~~--- ~i> P ----~~ '6;t dÜd':\J-~ . CD2~41 _JJß.~--_!:?_-----.--f_____92...- J-Od~() ðùd-\D1J=~~Ë~ -=-=~lt.l;'_-==:J;C-=-j~t==.-=~J~-== :;0 \ ., d '1£1-- g-q?..~~.~-- ------~-}}~-_._- --. --_.__'!.:~____._I_~-L___.__._-_?:?_--- . d 0 d-\)~ CO2-50 1.66' 0.25 P 1.5 WEllS ~ I ¡ \<\ S..()~(q._J '~\X)- \~ ) I \~~-\'~O I i~O--~\. '( \~c,- \à'6 :." Ot-""'> ,:;j::fJ- ~:> \ <;c;-o~L\ : ! d()O~- \4Ç d 0\- C)Ù(o \<; ')-)-5:), \~c;,-{)(Q.~. ~ JOD... \ \ 0 \ ~c;.-bã (.. d~btP'6 ¡ dO\)- \~" ---."---..-- ~ d-O \ - \ d- '--\ db\-\ð 5 "\ J ConocóP'hillips Alaska ) P.o. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: 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 by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD 1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16t11, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment Alpine Cement Top Fill ). , / Subject: Alpine Cement Top Fill Date: Wed, 23 Apr 2003 17:38:26 -0800 From: "Jerry C Dethlefs" <Jerry.C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips cc: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling > the conductors with cement. I believe 34 wells were treated. Chuck Scheve > and John Crisp were notified but declined to witness when we told them what > we were doing. Some time past we had agreed to submit a 10-404 for this > kind of work. Due to the number of these, is a 10-404 needed on each well? > I don't want to commit the time to doing this if it is not necessary; > 10-404's are time consuming to prepare. Would a list of the jobs suffice, > or something similar? We have the well numbers, depth to cement top, and > sacks used to fill the void. My proposal would not affect future > submissions of 10-404's for this work. What do you think? Thanks! > > Jerry Dethlefs (See attached file: tom_maunder.vcf) 1 of 2 ) 4/24/2003 7:55 AM Alpine Cement Top Fill ,.. . .'N " ". )... ...', ,_.,....",. . ..........". , "...}, , ,', , . Name: AOGCC ALPINE cement top outs 04-16-03.xls ~AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 ............,......~.......,................."..........."".............."............."''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''.................................."...............,............................."""""''''''''''''''''''''''''''''''''''''''''''....u..........'',''','',''''''',;.......................................................................-....'"-'''~'''''-'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''N'''''' " " LL" .. \ L . ,!' ~ , "" A""",,, \ t, II, \ ^'.I . \ I Name: Cement Top Fill AOGCC Letter 04-23-03.doc 0 Cement Top Fill AOGCC Letter 04-23-03.doc Type: WINWORD File (application/msword) Encoding: base64 ,- ^'- H'_, ".,-n , VW^ ,-. v V '-'N-."'.'" '-.''''- \.\tun',.,- -'''--,-1'- r." "v,,,,"'-' VI \1' ^ ....-, , I Tom Maunder <tom maunder~admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2of2 4/24/2003 7:55 AM ) h. )'''''('1''1; ';".",.~ ~1 'Vi "r- r~, f'i""~ ~ i.": ~,~"" ~ ~\ l t~l~ D '" ~l¡;;' '''' ~. '''''''''''' ~ \if ß',,,.... d-'O if--O\ ~ MAR 1. 1 2003 Well: CD2-25 j~~1i;Q; OM f.. ¡;~;;¡:~~ Gmt¡. Gc71im~~5ionDate: 4/7/2002 kX;~;::~¡~ Casing Detail 9 518" Surface Casing flð)PHILLlPS Alaska, Inc. . ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 56 Doyon 19 RKB to LOS FMC Gen V Hanger 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Shoe 54 Jts Jts 1 to 2 2 Jts 9- 5/8" shoe @ TD 12 1/4" Surface Hole RUN TOTAL 32 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #2) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40,42,44,46,48,50,52 64 joints total in shed - 56 joints total to run Last 8 joints stay out # 57 thru # 64. Use Best-Q-Life 2000 pipe dope Remarks: Up Wt - k On Wt - k Block Wt - 75 LENGTH 36.60 2.20 2257.49 1.40 81.53 1.68 2391.00 Supervisor: Don Mickey DEPTH TOPS 36.60 38.80 2296.29 2297.69 2379.22 2380.90 ') ConocoPhillips Alaska Cementing Report Legal Well Name: CD2-25 Common Well Name: CD2-25 Event Name: ROT - DRILLING Hole Size: TM D Set: Date Set: Csg Type: Csg Size: Primary 12.250 (in) 2,381 (ft) 4/7/2002 Surface Casing 8,625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger ) Page 1 of 3 Report #: Start: Spud Date: 4/1/2002 1 Report Date: 4/8/2002 3/31/2002 End: 4/23/2002 Cement Job Type: Primary Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Jim Thompson Pipe Movement Pipe Movement: Reciprocating Rot Time Start:: Time End:: RPM: Rec Time Start:22:00 Time End: 02:00 SPM: Type: Cement Casing Volume Excess %: 56.00 Meas. From: 125 Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 252 (gpm) Mud Circ Press: 260 (psi) Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 160,000 (Ibs) Drag Down: 140,000 (Ibs) -_._.~.._--_._.- Start Mix Cmt: 00:24 Start Slurry Displ: 00:24 Start Displ: 01 :28 End Pumping: 02:00 End Pump Date: 4/8/2002 Top Plug: Y Bottom Plug: Y w'------ --------.- Type: Spud Mud Density: 9.6 (ppg) Visc: 48 (s/qt) Bottom Hole Circulating Temperature: 62 (OF) Displacement Fluid Type: Mud Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) -- --'--.- .--.----.-----,-'-------..-.-.--- -..- ,.-.- - - ----- ,.-.-. ---_u_--,.----",,'----,-.----.--.-.-- Stage No: 1 of 1 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.20 (bbllmin) 6.20 (bbllmin) Y 650 (psi) 1,350 (psi) 5 (min) Y Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Mud Data Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 125.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: PVIYP: 14 (cp)/16 (lb/100ft2) Gels 10 sec: 14 (lb/100ft2) Gels 10 min: 19 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 177.50 (bbl) Stage No: 1 Slurry No: 1 of 4 To: (ft) Description: Biozan water w/ nut plug Class: Cmt Vol: 40.0 (bbl) Density: 8.30 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) -----'---------"'------'- ._-~,_._-_._"'---- Printed: 3/412003 4:25:02 PM ') legal Well Name: CD2-25 Common Well Name: CD2-25 Event Name: ROT - DRilLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: ) ConocoPhillips Alaska Cementing Report Page 2 of 3 Report #: Start: Spud Date: 4/1/2002 1 Report Date: 4/8/2002 3/31/2002 End: 4/23/2002 Stage No: 1 Slurry No: 2 of 4 To: (ft) Description: ARCO Spacer Class: Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Slurry Data Fluid Type: LEAD Slurry Interval: 1,881.00 (ft)To: (ft) Water Source: Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1 Slurry No: 3 of 4 Description: ASLite Class: Cmt Vol: 317.0 (bbl) Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Slurry Vol:415 (sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: CF) Temperature: CF) Temperature: CF) (OF) Stage No: 1 Slurry No: 4 of 4 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 2,381.00 (ft)To: 1,881.00 (ft) Cmt Vol: 48.0 (bbl) Water Source: Slurry Vol:234 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) - --.---.------ ----------_.- Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) ----_..,.,-,-,---_.__.".- -.----------.---- ------ Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: TAIL Mix Water: (gal) Foam Job: N Pressure (psi) (psi) ----.--------.--,.--,.---- Printed: 3/4/2003 4:25:02 PM ) ) ConocoPhillips Alaska Cementing Report Page 3 of 3 Legal Well Name: CD2-25 Common Well Name: CD2-25 Event Name: ROT - DRILLING Report #: Start: Spud Date: 4/1/2002 1 Report Date: 4/8/2002 3/31/2002 End: 4/23/2002 Casing Test Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Log/Survey Evaluation Interpretation Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Printed: 31412003 4:25:02 PM ) ) Page 1 of 2 Phillips Alaska, Ine Daily Drilling Report WELL NAME I JOB NUMBE_R. .1EVENT CODE 124 HRS PROG TMD I TVD I DFS 1 REPT NO. 1 DATE CD2-25 ODR 2,391.0 2,385.0 3.00 4 4/8/2002 SUPERVISOR I RIG NAME-&'N-Õ~--- -.- --- -I FIELD NAME I OCS NO~- AUTH MD I DAILY TANG I CUM. TANGO Don Mickey doyon1~ppco.com 19 Alpine 12,314.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTW/O MUD CUM INTANG WI MUD Drilling out shoe track 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD - Drill 8 1/2" hole - . -. ..._-.- "- - - . - 123,936 639,255 -~~~'DATE 2,~~~; -----~;:H_:O:-;:71~~;;~;;'::~~::~~-rN~~~~~~ ~ 998:~7~ 4.0 (ft) ::~o;'~;:~S:T DENSITY(ppg) I 9.60 I PP I I ECD I I MUD DATA I DAILY COST I 0 I CUMCOST I 0 FV PVNP GELS WL/HTHP FC/T.SOL OILIWAT %Sand/MBT Ph/pM Pf/Mf CI Ca H2S LIME ES 45 11/19 9114 9.01 I I 117.5 8.41 I FROM TO HOURS CODE TROUBLE SUB 00:00 02:00 2.00 CEMENT P PUMP 02:00 03:30 1.50 CEMENT P 03:30 08:00 4.50 WELCTL P PULD NUND 08:00 13:30 5.50 WELCTL P OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC PJSM - Cement 9 5/8" casing - Pump 40 bbls Pre flush Biozan water wi nut plug wi rig pump - Switch to Dowell - pump 5 bbls water - test lines to 2500 psi - drop bottom plug - pump 50 bbls Arco spacer @ 10.5 ppg - Pump lead slurry ASL3 @ 10.7 ppg - 6 BPM @ 700 psi -Observed nut plug marker @ Shakers w/300 bbls lead pumped - pumped down surge can - 317 bbls total lead slurry - pump 48 bbls tail slurry (G) @ 15.8 ppg - drop top plug wi 20 bbls water fl Dowell- switch to rig pumps & displace wi 9.6 ppg mud - 157.6 bbls - @ 6 BPM - 450 psi to 650 psi - bumped plug wi 1350 psi - floats held - CIP @ 0200 hrs. - full returns through job wi 125 bbls cement retunrs to surface SURFAC RD cement head - LD landing joint - PU stack washer & flush 20" Hydril INTRM1 ND 20" diverter system - NU & test FMC Alpine Unihead - NU 135/8 5K BOPE BOPE INTRM1 13:30 14:00 0.50 DRILL P 14:00 23:30 9.50 DRILL P 23:30 00:00 0.50 DRILL P Set test plug - Test Hyrdil to 250 psi low & 3500 psi high - Test pipe rams, blind rams, kill & choke line valves, choke manifold valves - floor & top drive valves to 250 psi low & 5000 psi high - perform accumlator closure test - witnessing of test waived by Jeff Jones AOGCC * Held to pull test plug & replace seal ring during test PU bails & elevators - prep to PU DP PU & std back 210 joints 4" drill pipe - prep for to PU BHA PU 8 1/2" BHA PULD INTRM1 PULD INTRM1 PULD INTRM1 24 HR SUMMARY: Cmt 9 5/8 " casing - NO diverter - NU well head & BOPE - Test BOPE - PU 4" DP - Begin PU 8 1/2" BHA COMPANY Phillips Doyon ACI BHI SERVICE ITEM Fuel Water, Drilling UNITS gals bbls USAGE PERSONNEL DATA NO. HOURS COMPANY 1 MI 25 Sperry Sun 5 Dowell 1 I DSR SERVICE NO. 2 2 2 4[ HOURS MATERIALS I CONSUMPTION ON HAND ITEM -6,195 Water, Potable -2,790 UNITS bbls USAGE ON HAND -270 Printed: 3/412003 4:28:04 PM WELL NAME TYPE CD2-15 RESERVOIR NAME CD2-15 CD2-25 NO. 1,713 CD2-25 CD2-25 ) Phillips Alaska, Inc Daily Drilling Report ___r~NU::~J~VE~TDC~DE 124 HRS PROG I T~~391.0 REMARKS SUPPORT CRAFT TYPE RESERVOIR AND INTERVAL DATA ZONE TOP BASE 1713 4 1180 ') Page 2 of2 I ~~385.0 I DFS3.00 I REPT ~o. I D~~~2002 NO. REMARKS COMMENTS Printed: 3/412003 4:28:04 PM CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2-25 Date: 4/9/2002 Supervisor: Don Mickey Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8",36#, J-55, BTC CSG Casing Setting Depth: 2,381' TMD Hole Depth: 2,411' TMD 2,375' TVD 2,405' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 30' EMW =: Leak-off Press. + Mud Weight = 800 psi + 9.6 ppg 0.052 x rvD 0.052 x 2,375' EMW for open hole section = 16.1 ppg Used cement unit RiQ pump used NO #2 Pump output = 0.0997 bps After review Fluid Pumped = 1.0 bbls Fluid Bled Back = 0.7 bbls 111111111 -- ----- -- -- ~-- Illlll.llllI111Ì)1~~lllllllll ITIME LINE I ONE MINUTE TICKS ..... LEAK-OFF TEST ~CASING TEST -- LOT SHUT IN TIME --.- CASING TEST SHUT IN TIME - -+- TIME LINE I 30 STROKES 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r------------r------õ-----r--.r;.ps¡--l' í---------------T-----1~Õ------r---3Õ-psf--l t~~~=~=~~~=!~~~=~~~~~=1~~=~~-psi=1 ! ! 3.0 ! 110 psi! r-------------T---4])------r---19-Õpsf-1 r------------T----5~Õ---1---2ifõ-psr-l }--------------+------------t-----------:-; L______---_1-_--~'O _--1_--~~-~J3s~-J i ! 7.0 i 520 psi! r------------r----8~Õ-----r--6Topsi --1 ¡-----------T----9~Õ------r--73-Õ-psr-l }--------------+---------------t------------:--; : : 10.0 : 810 pSI: [=~~=~=-~~~~~I~~~~~=~--==~r=~=~=~~~=J i ¡ ! ! ..--------------..,.-------------r---------------.. I I I I ~--------------+-----------t---------..;---i 1.__------------J._-----------L______-------..1 i-------------1-------------i-------------1 I I I I : : I : r--------------..,.------------r--------------.. I I I I t------------i-------------r------------i ¡~=-~~~~~=~~~+=~~~~=~~~~=~~~=~~~~~==~~1 I I I I r------------r-------------r--------------, I I I I t~~~~~~~=~~~~j~=~~~~~~=~=~t~~~~~~=~~~~~=j I I I I I I : I 60 i SHUT IN TIME! SHUT IN PRESSURE r-----------.-------------r-----------.. : O.Omin : : 810 psi : ~-------.---+------------t-----------.---; LJJL~'n -L_---______L~~_~_P'~I_-.l i--1J!..!!!!!:!--l---------j_-2~-~-p~-~-.1 ! 3.0 min ! ! 780 psi! r-;COmin --r--------------r--¡ã-opsr-l ~-------;----+----------t------:--; L 5.0 ~In _--L_------______L-2?_~Æ~~J L~:9..!!!!!:!-j-------------L-r70 psi-1 ! 7.0 min i ! 760 psi! ~------..,..------------~------------. : 8.0 min : : 760 psi: ~-------.--+--------t----------:--; : 9.0 mln : : 750 pSI: [1 O.<L~J~I==~=:=~[:!~~~p~CJ {lPHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEl.Xv\ COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r-------------T---Õ-stks---T-----opsT---1 r------------ì---2-siï<s---T---fjõ-psr--l ~--------------+--------------+------------i ! : 4 stks : 320 psi: ¡---------------T---ifsiï<š---T---Ö9Õ,)sr--î r------------T---ã-siks--T---ã9Õ-psr--1 r-----------T-l-Õ-stks--T--'¡:-Õ6-fpsT-l t---------------+--------------+--------------:-i : : 12 stks : 1,250 pSI: ¡--------------T--:¡-¡-stks-l-'¡:4š-fpsf-î r---------¡--:¡-6-stks-I--'¡:6~'-fpsr-1 r-------------'---1-ã-stks--T--'¡:92Õ-psrl t------------+--------------+------------:-i : : 20 stks : 2,180 pSI: ¡-------------T--2"fstks--T-2:43-Õ-psrî r--------------T--2-3-stks-I-2:sõõ-psT1 r--------------¡-------------T---------------1 ~=::::~*===:~===:==1 r---------------T------------T---------------1 ~=:::::~+::=::::::+==-=::j i SHUT IN TIME! SHUT IN PRESSURE ¡-õ. 0 -mlñ-T--------------r2~5õõ-¡;s¡-1 t---------:--+-------------+-----------.--i : 1.0 mln : : 2,500 pSI: ¡~m-in - i ---------T-ï:sõ-õ-psrl r-3-:-Õ-mln¡------------T-2:sõopsC1 r--¡orñin-T-----------T-2:sõõ-psrl :-------:----+-------------+--------------~i : 5.0 mln : : 2,500 pSI: ¡--6.omlnl-------------T-2:sõ-õ-psrl r--7-:-õ-miñ--T------------T-2:S0Õ-psC1 r-8.Õ-niin--'------------T-2:SÕÕ-psf-l --------:----+------------+-------------.--i : 9.0 mln : : 2,500 pSI: ¡-1 0 -:-Õñìin l-----------T-2:soõ-psTl r-15-:-õñì1ñ-T--------1-2:sõõ- psTl f2Õ-:-Õmlñ--'-------------T-2:SÕÖ-psi-l t- --~---+-----------+-------------.--i : 25.0 mln : : 2,500 pSI: L~Q~~~}~-r~==-~==:-T~~~~~õÕ~ps£l .-.-' ---. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Phillips Alaska, Inc. ) ) Casing Detail 7" Intermediate Casinq Jt Number Num of Jts Jts 3 to 208 Jts 1 to 2 Remarks: 206 Jts 2 Jts Up Wt = 275 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 Collar 7" 26# L-80 BTCM Csg 7" Davis Lynch Float Shoe 8-1/2" TD 1 straight blade centralizer per jt # 1 thru # 20 # 153, 154, 155 every other joint # 157 - 205. Total Centralizers (48) 220 joints in pipe shed - last 12 joints stay out Use Best-a-Life 2000 pipe dape On Wt = 195 Block Wt= 75K Supervisor: David Burley Well: CD2-25 Date: 4/13/2002 LENGTH 35.20 2.35 8602.08 1.36 78.98 1.71 DEPTH TOPS 35.20 37.55 8639.63 8640.99 8719.97 8721.68 8732.00 ) ConocoPhillips Alaska Cementing Report Legal Well Name: CD2-25 Common Well Name: CD2-25 Event Name: ROT - DRILLING Hole Size: TM D Set: Date Set: Csg Type: Csg Size: Primary 8.500 (in) 8,722 (ft) 4/14/2002 Intermediate Casing/Li (in.) cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger ,) Page 1 of 3 Report #: Start: Spud Date: 4/1/2002 2 Report Date: 4/15/2002 3/31/2002 End: 4/23/2002 Cement Job Type: Primary Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Squeeze Casing Hole Size: TM D Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Jim Thompson Pipe Movement Pipe Movement: Reciprocating Rot Time Start:: Time End:: RPM: Rec Time Start: 02:30 Time End: 04:25 SPM: 1 --.------.-.-. Type: Cement Casing Volume Excess %: 40.00 Meas. From: 0 Time Circ Prior To Cementing: 4.50 Mud Circ Rate: 252 (gpm) Mud Circ Press: 540 (psi) Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 275 (Ibs) Start Mix Cmt: 04:16 Start Slurry Displ: 04:18 Start Displ: 04:26 End Pumping: 05:32 End Pump Date: 4/14/2002 Top Plug: N Bottom Plug: N Stage No: 1 of 1 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.50 (bbl/min) 7.50 (bbl/min) N (psi) (psi) (min) N Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Mud Data Max Torque: (ft-Ibf) Drag Down: 195 (Ibs) Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: Densometer Type: Density: (ppg) Visc: (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: PVIYP: (cp)/ (lb/100ft2) Gels 10 sec: (lb/100ft2) Gels 10 min: (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) Slurry Data Fluid Type: Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Stage No: 1 Slurry No: 1 of 4 To: (ft) Description: Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: CF) Density: (ppg) Water Vol: (bbl) Class: Yield: (ft'/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) - -. - -'--- -"~ Printed: 31412003 4:25:35 PM ') Legal Well Name: CD2-25 Common Well Name: CD2-25 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: ) ConocoPhillips Alaska Cementing Report Page 2 of 3 Report #: Start: Spud Date: 4/1/2002 2 Report Date: 4/15/2002 3/31/2002 End: 4/23/2002 Stage No: 1 Slurry No: 2 of 4 To: (ft) Description: ARea wash Class: Cmt Vol: 20.0 (bbl) Density: 8.30 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) W_""_"~'M'__"'--- Slurry Data Fluid Type: ARC 0 Spacer Slurry Interval: (ft) To: (ft) Water Source: Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) -..-.-.----...- Stage No: 1 Slurry No: 3 of 4 --'''------'--_M'-____---.--'--''--- Description: spacer Cmt Vol: 50.0 (bbl) Slurry Vol: (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: CF) (OF) Class: Density: 12.50 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1 Slurry No: 40f 4 Slurry Data Fluid Type: TAIL Description: G Slurry Interval: 8,722.00 (ft)To: 7,905.00 (ft) Cmt Vol: 30.0 (bbl) Water Source: Slurry Vol:148 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) ---- -.- --.- ,-.,---_.,. --.--- ---'"~-,-~-,~-------_._,-_. '--------'------"--'-'-----'-' - .--- Printed: 3/412003 4:25:35 PM ') ) ConocoPhillips Alaska Cementing Report Page 3 of 3 Legal Well Name: CD2-25 Common Well Name: CD2-25 Event Name: ROT - DRILLING Report #: Start: Spud Date: 4/1/2002 2 Report Date: 4/15/2002 3/31/2002 End: 4/23/2002 Casing Test Shoe Test Liner Top Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 12,50 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation Interpretation Summary CBl Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N Printed: 3/412003 4:25:35 PM ) ) PhiHipsAlaska, Inc Daily Drilling Report WELL NAME .. . . . JJOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS CD2-25 ODR 8,732.0 7,211.0 8.00 SUP.ERVISOR----_n_-- I RI.G .NAME & NO.-- .. . .-. ..1 F. IELD.NAME IOCS NO. AUTH MD I DAILY TANG --- David Burley _1__- doyon1@ppco.com J§LH.__.___.H. ---__.___n_- Alpine 12,314.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTW/O MUD RD casing equipment. 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Test BOPE. MU BHA #3, test csg, FIT, chang~ over MOBM, drW_- --.-.----. ~l13/20Q~._---------------- 223,637 LITHOLOGY ___JJAR -~S ::SERVICE l~.H_~__:~~-~~.~~-'N_s~t:~.~~F~ 6.00 ____~FE 998E06 LAST SURVEY: DATE TMD INC AZIM 1 LAST CASING I NEXT CASING 4/12/2002 8,669.24 85.390 328,710 9,625 (in) @ 2,381.0 (ft) 7.000 (in) @ 8,714.0 (ft) DENSITY(ppg) I 9.70 I PP I I ECD I I MUD DATA I DAILY COST I 0 I CUM COST I FV PVIYP GELS WL/HTHP FC/T.SOL OILIWAT %Sand/MBT Ph/pM Pf/Mf CI Ca H2S 38 7/14 5/8 5.2/13.6 / / /17.5 8.4/ / Paget of2 I REPT NO. IDA TE 9 4/13/2002 I CUM. TANGo CUM INTANG WI MUD 0 CUM COST WI MUD 1,372,577 AUTH. 3,824,890 LAST BOP PRES TEST 4/8/2002 0 LIME ES BHA NO. I 2 I BHA I HOLE CONDITIONS I BIT NO. I 2 BHA WT. BELOW JARS STRING WT. UP STRING WT. DN STRING WT. ROT TORQUE I UNITS BHA LENGTH 1,075.29 ITEM DESCRIPTION NO JTS LENGTH O.D. I.D. CONN SIZE CONN TYPE Bit DP0912 PDC 1 1.00 8.500 MOTOR 1 23.17 8.375 NMSTAB 1 4.78 8.125 2.875 GAMMA SUB 1 27.54 6.750 1.920 MWD 1 20.22 6.750 1.920 FLOAT SUB 1 2.69 6.750 2.813 CSNMDP 3 88.87 4.500 2.875 XO 1 1.67 6.250 2.875 HWDP 3 90.47 5.000 3.000 JARS 1 32.37 6.187 2.250 HWDP 23 689.09 5.000 3.000 XO 1 1.37 6.500 2.500 HWDP 3 92.05 4.000 2.562 BIT I RUN 2/ SIZE MANUF. 8.500 HUGHES BITS TYPE SERIAL NO. JETS OR TFA DP0912 7000565 12/12/12/12/12/ DEPTH IN DATE IN I-O-D-L-B-G-O-R 2,391.0 4/9/20020-0-NO-A-D-I-NO-TD BIT I RUN WOB BIT OPERATIONS RPM I GPM I PRESS I P BIT I HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 01 :45 1.75 DRILL P WIPR INTRM1 Wipe hole to 7020', RIH to 8732', no problems 01 :45 03:30 1.75 DRILL P CIRC INTRM1 Circulate and condition mud 600 gpm - 120 rpm, 03:30 05:45 2.25 DRILL P TRIP INTRM1 Pump out to 8064', POH to 6797'. Monitor well, pump dry job and blow down top drive. 05:45 08:30 2.75 DRILL P TRIP INTRM1 POH to 1075', no problems - flow checks at shoe and BHA, static. 08:30 10:00 1.50 DRILL P PULD INTRM1 Stand back hwdp, lay down remainder of BHA, clear tools from and clean rig floor. 10:00 13:00 3.00 CASE P NUND INTRM1 PU wash sub and flush stack, pull wear bushing and install test plug. Change top rams to 7" and test 250/5000 psi. Pull test plug and set thin wall wear bushing. 13:00 14:15 1.25 CASE P RURD I NTRM 1 RU fill up tool, long bails, slips, elevators and casing tongs. Printed: 3/412003 4:29:25 PM ') ) Page 2 of 2 CD2-25 Phillips Alaska, Inc Daily Drilling Report __.J~OB NUMBER 1 EVE~TDc~DE 124 HRS PROG 1 T~~732.0 1 TVD I DFS 1 REPT NO. IDA TE 7,211.0 8.00 9 4/13/2002 WELL NAME FROM TO HOURS 14:15 14:30 0.25 14:30 16:30 2.00 ----..--------.w..- 16:30 17:00 0.50 17:00 19:00 2.00 19:00 19:45 0.75 ._----_.,--~-_.- 19:45 21:45 2.00 21 :45 23:45 2.00 OPERATIONS SUMMARY TROUBLE SUB PHASE DESCRIPTION -..-- SFTY INTRM1 Held prejob safety and operations meeting with rig crew. RUN~____J_~!~_~_1__~~_~_!.'~_?§!!-!._L-80 casing to 2375', PUW 125k SOW 125k. CIRC INTRM1 Stage pumps up to 6.0 bpm - 340 psi, circ one pipe volume. .~--,-~----_.- --------.,-..- RUNC INTRM1 Run casing to 5022' PUW-180k SOW-170k CIRC INTRM1 Staged pumps up to 6.0 bpm - 570 psi, CBU. .-.----...-..-.--.------"- RUNe INTRM1__~~.~__casing to 7150', encounterd partial returns from well. CIRC INTRM1 Circulate and attempt to regain full returns. Initial rate 2.5 bpm - 520 psi with 25% returns, with 120 bbls pumped returns at 50%. Regained full returns at 2.5 bpm - 720 psi. Added water to cut return mud weight of 10,2 - 10.6 ppg. Staged pumps up to 4.5 bpm - 460 psi final rate/pressure with full returns. CBU .-------------.--------------..------------------ -------------_u_-______mu.~__~!:- in 9.7 ppg, mud wt. out9.8 ppg, estimated total losses @ 140 bbls. 23:45 00:00 0.25 CASE P RUNC INTRM1 Continue to run casing, CODE CASE P CASE P CASE P CASE P CASE P CASE P CASE NP "--------"._'_.'-----"'--'----'-'-'--'----~----'."-,_._._----------_.._-----~-..._._--,_._---- -"---'_._..-"-'-"'''-",~ "._...'h--__--'---'--"---'-----____'.m._____--------....-.-....--,,-------- 24 HR SUMMARY: Wipe hole to 7020', cond mud, POH. RU and run 7" casing, stage circ @ 2375',5022' and 7150'. PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NQ. HOURS Phillips ----------- ---------------------------------------------1...--------- Sperry Sun 2 Doyon 26 Dowell 2 ----_._..._.._--_._,----_._..~_._._. '.-----..-,.-....,.,-..-----.----"-..'-'------,----.-,, .-- --'_._._-,_..._----_._.~-_...~._- ..-.-- --- ---..----------...--.-.-.------__..__n -.--,-,.-.---.- _..-._~._---.-_._--_.- ACI 5 DSR 4 ------,.._.~_.--....._._--"..._-------_.._.._--_.----."- --_""_-_._"'_"_-_U'-"-"---'---~"-""--'--" -"-"--'-"---'- -~-'--'--'-----'- -...- --- . - - _.-- -'--"-----'-'-'-'-'_."._~-""-'- --,._- .-._---_.---_.-.,----_..._-----~--------._.- --.--- "------_u_.-- BHI 1 Weatherford 1 ~_.._.__._.,,----_._. - ---......-'"....- .--.-..--.-..--...-..-- --. _.-,,-- . ,. -- -- -- _.." -- -,---_. -...--.-.. --. .....-- n- - - -... .- .--...--.-.-.-- ---- -- -- ." --~-- - --- """. -_.___.._n."~ . -. ----"-",-------._.___n.___._.-"--- --~._,---.__..__.- -----..-.--..----. ----.----". .---...- MI 3 FMC 1 ---'--" --. - . ____n__--"__- ..--......--." ..--..-... .-- - --~ -.------.--.-... _,__'-n- - "----_.__..~---,--_~__~.n_._- "'-"--'~-- ---- ----- ITEM UNITS £.u_~!_------ .. -------------_____jl~!~___---- -- Water, Drilling bbls USAGE 1,730 - - --,-- ---.---..-.----- 304 MATERIALS I CONSUMPTION ON HAND ITEM UNITS - - :1_~!Q~g--- _YY~~!2E.~!~_~!!_-----_._------- bbls -5,193 USAGE 120 ON HAND -855 - --._----------- TYPE CD2-15 NO. 20 CD2-25 REMARKS SUPPORT CRAFT TYPE NO. REMARKS .--.---,.'''-..-.-,-------.-- .._-----------_..._~_._--_.__._-- ---,._--..- ---.--------...--- RESERVOIR NAME CD2-15 RESERVOIR AND INTERVAL DATA ZONE TOP BASE 20 2 1180 COMMENTS CD2-25 --"-----_._-"-------"---'~-'-'_____'n_n__.- . .. --,-------,-,,--,"___-'n.___...-.- --..-.-.----,,-----.-.--.----.---- Printed: 3/412003 4:29:25 PM ) ) Page 1 of 2 Phillips Alaska, Inc Daily Drilling Report WELL NAME I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS CD2-25 ODR 8,732.0 7,211.0 9.00 SUPERVISOR . JRIG NAME & NO. .---- I FIELD NAME I OCS NO. AUTH MD I DAILY TANG - David Burley____- -- doyon1Cã2PP2o.com 19 -- Alpine 12,314.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTWIO MUD Preparing for MOBM change over 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Change well over to MOBM and drill 6 1/8" horizontal hole. 4/13/2002 178,077 LITHOLOGY -------- I JAR HRS OF SERVIC~J~~~:_:_~~:_I~_~~J~:AKOF~ 6.00---- AFE 998E06 LAST SURVEY: DATE TMD INC AZIM ¡LAST CASING I NEXT CASING 4/12/2002 8,669.24 85.390 328.710 7.000 (in) Cã2 8,722.0 (ft) (in) Cã2 I REPT NO. IDA TE 10 4/14/2002 I CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 1,550,654 AUTH. DENSITY(ppg) I 9.70 I PP I IECDI ¡MUD DATAl DAILY COST I FV PVNP GELS WLlHTHP FCIT.SOL OILIWAT %Sand/MBT Ph/pM 40 8/18 7/8 5.0/ / / /17.5 8.3/ 0 PflMf / (ft) 1 CUM COST .1 CI Ca 3,824,890 LAST BOP PRES TEST 4/14/2002 0 H2S LIME ES BHA No.1 3 I BHA I HOLE CONDITIONS 1 BIT NO. I 3 BHA WT. BELOW JARS STRING WT. UP STRINGWT.DN STRING WT. ROT TORQUE / UNITS BHALENGTH 381.97 ITEM DESCRIPTION NO JTS LENGTH O.D. I;D. CONN SIZE CONN TYPE Bit STR386 PDC 1 0.85 6.125 Turbo-back Stab 1 0.83 6.092 1.500 Mach 1X Navi-drill 1 20.76 6.000 NM Stab 1 4.53 6.125 2.375 Gamma Sub 1 25.58 4.750 1.250 MWD 1 30.22 4.750 1.250 Hang-off Sub 1 11,27 4.750 2.815 NMCSDP 3 92.23 3.500 2.375 XO 1 1.20 5.250 2.500 PBL SUB 1 8.70 4.750 1.500 HWDP 3 92.05 4.000 2.562 Jars 1 32.43 4.750 2.250 HWDP 2 61.32 4.000 2.562 PUMP I HYDRAULIC DATA NO. MAKE OF PUMP STROKE (In) LINER (In) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM / PRESSURE 1 Continental Emsco 12.000 6.000 43 180.00 1,150 180.00 30 780 2 Continetal Emsco 12.000 180.00 30 820 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 01 :45 1.75 CASE P RUNC INTRM1 Run casing, MU hanger and LJ and land casing with shoe @ 8722', FC @ 8640'. 01 :45 02:30 0.75 CEMENT P PULD INTRM1 LD fill up tool and MU cement head. 02:30 04:00 1.50 CEMENT P CIRC I NTRM 1 Staged pumps up to 6 bpm and condition mud for cementing. Reciprocated pipe with full returns throughout, final circ pressure 540 psi. PJSM 04:00 04:45 0.75 CEMENT P PUMP INTRM1 Test cement lines to 3500 psi, pump 20 bbls of wash, 50 bbls of 12.5 ppg spacer and 30 bbls of 15.8 ppg cement. Begin displacement with 20 bbls of FW from cementers. 04:45 05:45 1.00 CEMENT P DISP INTRM1 Displace cement with 311 bbls of 9.7 ppg mud @ 6.5 bpm, plugs bumped - floats held. Reciprocated casing untilllast 15 bbls of displacement, full returns during job, CIP @ 0532 hrs. 05:45 06:15 0.50 CEMENT P PULD INTRM1 RD cement head, LD LJ, elevators and long bails. 06: 15 07:00 0.75 CASE P OTHR INTRM1 Pull thin wear bushing, install and test packott to 5000 psi. Printed: 3/412003 4:30:06 PM ') ) Page 2 of2 CD2-25 Phillips Alaska, Inc Daily Drilling Report ¡JOB NUMBER IEVE~TDC~DE 124 HRS PROG IT~~732.0 1 TVD I DFS 1 REPT NO. IDA TE 7,211.0 9.00 10 4/14/2002 WELL NAME OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE 07:00 08:00 1.00 CASE P NUND INTRM1 - -_.._------.- ------.-.------ 08:00 10:00 2.00 WELCTL P BOPE INTRM1 DESCRIPTION Change top rams to 3-1/2" X 6". Test pipe and blind rams, choke and kill line, manifold, surface safety and Top Drive valves to 250/5000 psi. John Crisp (AOGCC) waived witnessing test. ------------------------------------- ----------------~* Choke manifold and surface safety valves were tested while MU BHA. 10:00 10:30 0.50 CASE P ----------~UR.Q______lNTRM1 Install we:~!_bushing, PU short bails and DP elevators. 10:30 13:30 -~:~~----- DRILL P ------___f_ULD - INTR~~___fy1_~_?HA #3, initialize LWD, PU 3 jts NMCSDP. 13:30 __1~_~___.l9~--- DRILL P --____P'§'9I____LtiTRM1 Shallow test tools, PU and cycle PBL sub, pull up and recover actuating balls. 14:30 20:00 ----_?ßO_- DRILL P _T_~!f._____.!!'J_I~~~_- PU__!_~_5 joints of 4" drill pipe and RIH to 8011'. --~~~Q___~1 :OO_---~.:Q.~-- RIGMNT P ----------- RSRV -- INT~~.!.. Slip and cut drilling line, serviced Top Drive and Drawworks. 21 :00 2~~.Q..____2:~Q___-- QRILL P ----______IF.3!~______l_~_I_~~!_- ~!H, tagged cement @ 8580'. 21:30 22:15 0.75 CEMENT P COUT INTRM1 Clean out cement to 8610' and circulate. -.-...--.-...--.----- --------'.--."-""'--"---- -------.-.------.-,----,.-...-.---------- 22:15 23:15 1.00 CASE P DEQT INTRM1 RU and test casing to 3500 psi for 30 minutes. RD and blow down surface ---- ------------ ------------~g~!p-,!!~~l.._--- -~~J..~- 00:.9.9_-____Q.75____CEfy1ÉNT f._---------___.f9UT INT~M1 Clean out cement to 8637', drill on wiper plugs. -------------".'."-'--'''--'----'----'-'--''--' -_.._--,,~...__.__._--- -------..----- ------_.-.--_._-___."h______-'-- --~ 24 HR SUMMARY: Ran and cemented 7" casing with shoe @ 8722'. Install and test packoff. Test BOPE. MU BHA # 3 and RIH. Clean out cement, test casing to 3500 psi. COMPANY Phillips _.~----- .,,--_.__._------~ ---- ---'.'-----'-------"-____h___.__..__n .--.- - __n_- - Q~E.!!_____-------_.__._----------- -- -- -- - --------.--------- -----.- ACI BHI -.-----. . - .----.-.- - -_..-._-- MI SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 --------------- _~l?erry Sun______------------------------ 25 Dowell -_._,-,._----- ---- 5 DSR --.-.--.-.-".----.- '-~-"-'-'---'-------,--,--, ----- ---_._~_...._----_._----_._._------_. --.---- ._------,------- 1 Weatherford - --"--.- --,,_,__,_,~,-.-.-,,_--,,-,_,,__,,".'- ~- ---- ---. 3 SE~VICE NO. HOURS 2 2 4 -----.------- 1 ----'----- -------.------ -- --- _.~ --" -..-- -- ------- ~_._-_._--- ----~---- _.~-_..~.~.__. . -- -,_.- -.-. --._u_---. --- -.-. -- --- - .-.- ,- ,.." ---- .-.- -. ,---,~ . - ,~..- -".,~.._-_._~-._-_. --,-----, ---'----'.""'--"-'----,---.-"..-.,_u_---- -,_._-----~-_.-.- ITEM MATERIALS I CONSUMPTION UNITS USAGE ON HAND ITEM UNITS gals ----- -- ---- 1 ,6~Q____- ____--=-~L?~.Q.___- ,!!~ter ~~~~~------------------~~------------ bbls 136 -5,329 USAGE 120 ON HAND -975 Fuel ---..----.------- --- Water, Drilling TYPE NO. CD2-15 1,513 CD2-25 -~----,-----_._- .--.- ..- ._-,- ._---",,_._,- -~._--- -,,--,,-~---,,~-_._---- REMARKS SUPPORT CRAFT TYPE NO. REMARKS _...~_.-_._-_..._--- ---_. ----.---.... ____n___-_- -. ~, ---- ---_._--------_.._-,---------""_._._-~----,---_._'''--,------_.__."._,-,-,,-_.._- -_.,-------~----,--------_._-_.._,_._-_.- RESERVOIR NAME CD2-15 RESERVOIR AND INTERVAL DATA ZONE TOP BASE 1513 3.5 890 COMMENTS CD2-25 ---_..~ --,,-- - ----_._----~_._----- - _'_-_n'--_._-,--'"-'--~----- Printed: 31412003 4:30:06 PM Well Name: CD2-25 CASING TEST and FORMATION INTEGRITY TEST 4/14/2002 Supervisor: David Burley Reason(s) for test: Date: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Setting Depth: Casing Size and Description: 95/8" 36# J-55 BTC X 7" 26# L-80 BTMC Mud Weight: 2,381' TMD 2,375' TVD TOC Hole Depth: 7,904' TMD 7,009' TVD 9.6 ppg Length of Open Hole Section: 5,523' EMW = Leak-off Press. + Mud Weight 0.052 x TVD Used cement unit RiQ pump used 800 psi --- 700 psi - = 570 psi 0.052 x 2,375' + 9.6 ppg EMW for open hole section = 14.2 ppg yes #2 Pump output = bbls pumped Fluid Pumped = 6.5 bbls Fluid Bled Back = 0.0 bbls 600 psi - ""'''''--- \. U\ I' 400 psi -'---.. -'>'-- ------. 1\1 TIME LINE I ONE MINUTE TICKS I ~LEAK-oFFTEST w 0:: :J t/J VJ w 0:: 111. II 300 psi 4 , 200 psi -- II 100psi- Opsi¿' 0 """"CASING TEST ~ LOT SHUT IN TIME ~ CASING TEST SHUT IN TI~.4¡::: 10 15 BARRELS 20 25 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT BBLS PRESSURE r-------------r-----õ-------r-----õ--ps¡----l ~---~=~~~~~~~~~~~~Q~~~~=~~~~~~~~Ë!C~~ : : 1.0 I 121 pSI: i=~~~===~~~~l=~I~~~==r=~~~~fE~l=] ! ! 2.0 ! 343 psi! I::=:=:::::::j===~~;==j:::~;:;:~~f::j ! ! 3.5 ! 535 psi! r------------l-----:rõ-----¡---49-s-psf--l r---------T-----~r5--:---4!ffpsf: L~~~~=~~~~~~~!~~~~-~~~==~~t~~~~~~~~ë![~~1 i------------J-----~~------L-~-~_e~~--1 ! ! 6.0 ! 485 psi! ~:::=::=~~~~~¡~~~::~~~---~=í~~~~~~~~ë![~~~ I I I I L_--___-------..l.--------------L__---_--------J. I I I I I , I I ~--------------:..-------------:.----------------~ I I I I ~-------------+--------------¡..----------------~ I I I I t-------------+---------------t---------------i i-_____------_J_------------l______----------l I I I I ¡-------------.!.-------!.----------------J I I I I I I I I I I I I r---------------T----------r---------------l t------------+------------t-------------i I I I I I I I I 1.--------------1...............................".................................. I I I I I I I I I I I I 30 ! SHUT IN TIME ¡ SHUT IN PRESSURE r-- O. õ-iïiTñ-T-----------T--485 jjšT--ì ----------.---+--------------t----------.---i L-1:.Q_!!1_'.!2..-L_________L__~~~_E~'__-1 i-?":.Q_!!1_i~_-l--_---------L-~~_e~~--1 ! 3.0 min ! ! 379 psi! ,--------.---..,.------------r--------------, : 4.0 mln I : 369 psi: r--------.---+------------t----------:--i L2J2.!!1_~~_L______-----L__~~_e~~--1 L~:.Q-!!1-~~-l-----------L-_~~~_e~~-J ! 7.0 min ! ! 353 psi! ,------~--..,.----------r--------------' : 8.0 mln : I 348 psi: r----.---+-------------t----------~-i : 9.0 mln : I 343 pSI: [I9.:~-fñ1~~I==~=~~[=~~~~~e~il ~PHILLIPS Alaska, Inc. ~ A Slbsidiary of PHILLIPS PETROLE\J'.1 COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r-------------r--Õ-štks--T----õ-psi---1 r-------------r-----------r---------------, I I I I :-----------+-----------+---------------i I I I I I I I I Io-----------"'-----------~----------------I I I I I I I I I I J , I "-------------1------------""'---------------" I I I I I I I I ~------------+------------+---------------4 I I I I ~-----------+------------+-------------.f I I I I I I I , Io---------------~------------""'---------------. I I I I I I I I I I I I ,.--------------~-----------.....----------------.. I I I I I I I I ~-----------+------------+-------------~ I I I I t-------------i-----------+----------------i I I I I I I I I 10-----------1----------""'----------------. I I I I I I I I I I I I "-------------""""----------""'--------------1 I I I I I I I I ~-----------+-----------+----------------~ I I I I t------------+------------+---------------i I I I I ~-----_____L______--_..L_--------------_J I I I I I I I I ~------------~----------..:.----------------~ I I I I I I I I ~---------+----------+---------------4 I I I I ~---------+-------------+----------------i : : : r Io----------~-------.....---------------. I I I I : : : I ,~ ! SHUT IN TIME! SHUT IN PRESSURE r------------.-------------.----------------, I 0.0 min : : 0 psi: rl=~mi~-~r -~~--==~!~=~~=~=~:~~J ! 2.0 min ! ! ! "--------1----------""'----------------1 ! 3.0min ! ! ! '----'------------r----------------.. : 4.0min : I : ~---~--+--------+---------------i I 5.0mln I : : 10-----_--"""--------""'--------------1 ! 6.0 min ! ! ! 1"--------...------------.....--------------...... ! 7.0min ! ! ! r------- --- - . - -------,..----------------, : 8.0min : I : ~--- - -- . -+------+-------------i : 9.0 mln I : : ""--------~--------""'--------------..a ! 10.0 min ! ! ! "------~----------""'-------------1 ! 15.0 min ! ! ! r-- - - --.----------.-----------------.. : 20.0 min : I : :----~ I -- ---+------------i : 25.0 mln I : : "-----~-----""'---------------. i-~9.:P min i --------l--------------J .---- NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ) ) ¿;jrJ3- 67 L/ / 139 (0 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 October 2, 2002 RE: MWD Formation Evaluation Logs - CD2-25, AK-MW-22059 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transl11Ìttalletter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom. API#: 50-103-20418-00. ~~J RECEIVED DEC 1 3 2002 Alaska 0í1 & Gas Cons {"'''''mm' . . \All I 158lon Anchorage )! ) a oa- 0/,-/ 11/51 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 October 2, 2002 RE: MWD Formation Evaluation Logs - CD2-25, AK-MW-22059 The technical data listed below' is being submitted here,vith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20418-00. REceIVED OCT 0 9 2002 AI-a Oii & Gas Con Co ~ IJJIJJIa8Jn ') ) ~ S ~...... ......~.. PHilliP 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 July 10, 2002 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-25 (202-074) . Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-25. If you have any questions regarding this matter, please contact me at 265-6120 or Vem Johnson at 265-6081. Sincerely, ~{aL G. C. Alvord Alpine Drilling Team Leader P AI Drilling GCA/skad RECEIVED JUL 11 2002 Alaska Oil & Gas Cons. COrmYilBBIOI AnchoragE! OR\G\NAL ') STATE OF ALASKA) ALA~"Á OIL AND GAS CONSERVATION COMfv.,...¡SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas 0 2, Name of Operator Phillips Alaska, Inc. 3. Address P. O. Sox 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended 0 Abandoned 0 Service 0 7. Permit Number 202-074 1 8. API Number 50-103-20418-00 (ASP: 369472, 5973977) r"ëë¡M¡;i~f'f:': ¡:~~,.. ¡ ~.,: ~"\ '"~E: .... .~,'. .' T"'1~" ;~ ~ ~ j: ~ ~~ ~~.- "..¡:l¡ ~ ~ ,/ ,~ * J -. " ;""', ':~\~~1þ11\'11r7n~mtJTI~ . ,,". 9. Unit or Lease Name Colville River Unit 10. Well Number 1815' FNL, 1533' FEL, Sec. 2, T11N, R4E, UM At Top Producing Interval 2419' FNL, 1521' FWL, Sec. 2, T11 N, R4E, UM At Total Depth 719' FSL, 213' FEL, Sec. 34, T12N, R4E, UM (ASP: 367789, 5977145) 5. Elevation in feet (indicate KB, DF, etc,) 6. Lease Designation and Serial No. RKS 33' feet ADL 380075 & 387212 12. Date Spudded 13. Date T.D. Reached 14, Date Comp., Susp. Or Aband. April 6,2002 April 18, 2002 April 23, 2002 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 11995' MD 17161' TVD 11995' MD 1 7161' TVD YES 0 No D 22. Type Electric or Other Logs Run GR/Res/Neut/Dens 23. (ASP: 371707,5974542) CD2-25 11, Field and Pool Colville River Field Alpine Oil Pool 15. Water Depth, if offshore 16. No. of Completions NI A feet MSL 1 20. Depth where SSSV set 21. Thickness of Permafrost 2013' MD 1656' MD 16" WT. PER FT. 62.5# 36# 26# GRADE H-40 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 2381' Surface 8722' HOLE SIZE 42" CEMENTING RECORD 307 sx AS 1 415 sx AS III Lite, 234 sx Class G 148 sx Class G AMOUNT PULLED CASING SIZE 9.625" 12.25" 7" 8.5" 24, Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 4.5" TUBING RECORD DEPTH SET (MD) 7882' PACKER SET (MD) 7761' 25. SIZE open hole completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED NIA 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 21,2002 Gas Lift Oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL 5/23/2002 10 hours Test Period> 1329 665 0 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL press. 235 psi 983 24-Hour Rate> 2819 1865 0 28. CORE DATA CHOKE SIZE 100% OIL GRAVITY - API (corr) not available GAS-OIL RATIO 662 Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A . 1'1 é)OO2 JUt.. L.. Alaska Oil & Gas Cons. LOII¡¡\lì::iSHb Anchoraoe Form 10-407 Rev, 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate " I {\ L '-,~ ~ ('\ ~, f.\'.~, ! \ 0 \"{ t () \ \ \J j-\ RBDMS 8Fl JUL '2 2002 ,., (,\'"" GEOLOGIC MARKERL ) 30. ') FORMATION TESTS 29. NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. CD2-25 Top Alpine 0 Top Alpine C 8324' 8399' 7156' 7172' r~E(:EIVED JUL '1 "I 2002 ,I.\lask~ Oil ~;: ì"tIH¡¡iiii:;b¡¿~' J~I'i(:hnr!81J(' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Vern Johnson 265-6081 Signed ,41. { 0<--( Chip Alvord Title Alpine Drilling Team Leader Date 7/1(('1-- Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~ i'~' \ 1 ',\ ,\, . ~. @ ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-25 CD2-25 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub . Hoürs.. CodeCôdê Phase 4/5/2002 06:00 - 08:00 2.00 MOVE DMOB MOVE 08:00 - 19:30 11.50 MOVE MOVE MOVE 19:30 - 00:00 4.50 MOVE POSN MOVE 4/6/2002 4/7/2002 4/8/2002 00:00 - 03:30 3.50 DRILL RIRD SURFAC 03:30 - 08:30 5.00 DRILL PULD SURFAC 08:30 - 09:00 0.50 DRILL OTHR SURFAC 09:00 - 10:30 1.50 DRILL PULD SURFAC lO:30 - 11 :00 0.50 DRILL SFTY SURFAC 11 :00 - 11 :30 0.50 DRILL OTHR SURFAC 11 :30 - 12:00 0.50 DRILL DRLG SURFAC 12:00 - 13:00 1.00 DRILL PULD SURFAC 13:00 - 00:00 11.00 DRILL DRLG SURFAC 00:00 - 09:00 9.00 DRILL DRLG SURFAC 09:00 - 10:00 1.00 DRILL CIRC SURFAC 10:00 - 12:00 2.00 DRILL WIPR SURFAC 12:00 - 13:00 1.00 DRILL CIRC SURFAC 13:00 - 16:00 3.00 DRILL TRIP SURFAC 16:00 - 17:30 1.50 CASE RURD SURFAC 17:30 - 21 :30 4.00 CASE RUNC SURFAC 21 :30 - 22:00 22:00 - 00:00 0.50 CASE RURD SURFAC 2.00 CEMENTCIRC SURFAC 00:00 - 02:00 2.00 CEMENT PUMP SURFAC . Page 1 Of8 Spud Date: 4/1/2002 End: 4/23/2002 Group: Start: 3/31/2002 Rig Release: 4/23/2002 Rig Number: 19 Description. of Operations Split motor & pit modules - disconnect f/ su b - turn motor & pit modules around - Skid floor back to move position Move modules & rig fl Nanuq 5 to CD2 Spot rig over well CD2-25 - level & shim - s et feet - pull anchor pins - skid rig floor int 0 drilling position - spot pit & motor module s NU 20" diverter system - Accept Rig @ 000 1 hrs. 4/6/2002 PU & std back in derrick, HWDP, Jars, 5" D P, 8" DC Perform diverter closure test - witnessing of test waived by Jeff Jones AOGCC MU BHA, bit, motor, XO, LC, stab, LC, XO, 1 std. HWDP Held pre spud meeting wi rig crew C/O conductor f/ 54' to 114' Spud in - Drill 12 1/4" hole f/ 114' to 150' ADT- .25 PU MWD & orient MU 8" DC Drill 12 1/4" hole f/ 150' to 1568' - TVD 15 66' ADT 6.45 ART 6.15 AST .30 Drill 12 1/4" hole f/ 1568' to 2391' TVD 238 5' ADT 6.2 ART 4.8 AST 1.4 Circulate hole clean 14 BPM @ 1750' R&R pi pe - monitor well (static) blow down TD Wiper trip f/ 2391' to 1002' - Monitor well (s tatic) RIH Establish circulation - Circ hole clean - Mon itor well (static) POOH to run 9 5/8" casing - flow check @ H WDP - Std back HWDP - 8" DCs - LD Stab, L Cs, XOs, MWD, Motor, & bit RU to run casing PJSM - Ran 56 jts. 9 5/8" 36# J-55 BTC casi ng - work through tight spot @ 680' - PU Ian ding jt & hanger - land casing wi shoe @ 23 81' FC @ 2297' RD fill up tool 7 RU cement head & lines Establish circulation - circ & conditoin mud for cement job 6 BPM @ 260 psi - receiprac ate pipe PJSM - Cement 9 5/8" casing - Pump 40 bbls Pre flush Biozan water wi nut plug wi rig p ump - Switch to Dowell - pump 5 bbls water - test lines to 2500 psi - drop bottom plug - pump 50 bbls Arco spacer @ 10.5 ppg - Pum p lead slurry ASL3 @ 10.7 ppg - 6 BPM @ 70 0 psi -Observed nut plug marker @ Shakers w/300 bbls lead pumped - pumped down sur ge can - 317 bbls total lead slurry - pump 4 8 bbls tail slurry (G) @ 15.8 ppg - drop top Printed: 5/10/2002 2:44:18 PM ) ~ ~ ) Pélge20f 8 PHILLIPS ALASKA INC.. Operations Sum maryRep(jrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-25 CD2-25 ROT - DRILLING doyon1 @ ppco.com Doyon 19 Sub HoursCödeCode Phase 2.00 CEMENT PUMP SURFAC 4/8/2002 00:00 - 02:00 02:00 - 03:30 1.50 CEMENT PULD SURFAC 03:30 - 08:00 4.50 WELCTL NUND INTRM1 08:00 - 13:30 5.50 WELCTL BOPE INTRM1 13:30 - 14:00 0.50 DRILL PULD INTRM1 14:00 - 23:30 9.50 DRILL PULD INTRM1 23:30 - 00:00 0.50 DRILL PULD INTRM1 4/9/2002 00:00 - 02:30 2.50 DRILL PULD INTRM1 02:30 - 04:00 1.50 DRILL TRIP INTRM1 04:00 - 04:30 0.50 CASE CIRC SURFAC 04:30 - 05:30 1.00 CASE DEQT SURFAC 05:30 - 07:00 1.50 CEMENT DSHO SURFAC 07:00 - 07:30 0.50 CEMENT FIT SURFAC 07:30 - 08:30 1.00 CEMENT FIT SURFAC 08:30 - 00:00 15.50 DRILL DRLG INTRM1 4/1 0/2002 00:00 - 04:00 4.00 DRILL DRLG INTRM1 04:00 - 04:30 0.50 DRILL CIRC INTRM1 04:30 - 06:30 2.00 DRILL WIPR INTRM1 06:30 - 08:00 1.50 DRILL WIPR INTRM1 08:00 - 08:30 0.50 DRILL CIRC INTRM1 08:30 - 12:00 3.50 DRILL DRLG INTRM1 12:00 - 22:00 10.00 DRILL DRLG INTRM1 22:00 - 23:00 1.00 RIGMNT RSRV INTRM1 23:00 - 00:00 1.00 DRILL DRLG I NTRM 1 00:00 - 15:30 15.50 DRILL DRLG INTRM1 15:30 - 16:30 1.00 DRILL CIRC INTRM1 4/11/2002 Spud Date: 4/1/2002 End: 4/23/2002 Group: Start: 3/31/2002 Rig Release: 4/23/2002 Rig Number: 19 . Description of Opera.tions . plug w/ 20 bbls water f/ Dowell - switch to r ig pumps & displace wi 9.6 ppg mud - 157.6 bbls - @ 6 BPM - 450 psi to 650 psi - bump ed plug w/ 1350 psi - floats held - CIP @ 02 00 hrs. - full returns through job w/ 125 bbl s cement retunrs to surface RD cement head - LD landing joint - PU stac k washer & flush 20" Hydril ND 20" diverter system - NU & test FMC Alpi ne Unihead - NU 13 5/8 5K BOPE Set test plug - Test Hyrdil to 250 psi low & 3500 psi high - Test pipe rams, blind rams, kill & choke line valves, choke manifold val ves - floor & top drive valves to 250 psi low & 5000 psi high - perform accumlator closu re test - witnessing of test waived by Jeff J ones AOGCC * Held to pull test plug & repl ace seal ring during test PU bails & elevators - prep to PU DP PU & std back 210 joints 4" drill pipe - prep for to PU BHA PU 8 1/2" BHA MU BHA #2. RIH, picking up 4" drill pipe, tagged cement @ 2260'. Circ and cond mud prior to casing test. RU and test casing to 2500 psi for 30 minut es, blow down surface equipment. Drill out cement, float equipment and 20' of new hole to 2411', Circ hole clean prior to FIT. RU and perform FIT to 16.0 ppg EMW. RD Ii nes and blow down surface equipment. Drill from 2411' to 4187' ART=10.7 AST=O. 2 Changed well over to 9.4 ppg LSND mud while drilling ahead from 2411', Drill FI 4187' to 4698', ART 3.1, AST 0.0 AD T 3.1 Pump hi vis sweep, circulate BU, 14 bpm Monitor well, wiper trip f/4698' to 2315',5-1 5 klb over TIH f/ 2315' to 4968' - no problems Wash f/4602' to 4698', pump hi vis sweep Drill f/4698' to 5005' ART 1.3, AST 0.8, ADT 2. 1 Drill f/5005' to 6033' Change out TD saver sub Drill f/6033' to 6060' ART 6.0, AST 1.2, ADT 7.2 (from 5005' MD) Drill from 6060' to 7369' ART=6.1 AST=4.6 Pumped 40 bbl 300 FV sweep and circ hole c lean, slight increase in cuttings with sweep back - 600 gpm, 120 rpm - monitor well, stat Printed: 5/10/2002 2:44: 18 PM (~þ ~ 4/14/2002 ) ') PHILLIPS ALASKA INC~ Operations Summary Report Page 3 ot8 13:00 - 14:15 1.25 CASE RURD INTRM1 14:15 - 14:30 0.25 CASE SFTY INTRM1 14:30 - 16:30 2.00 CASE RUNC INTRM1 16:30 - 17:00 0.50 CASE CIRC I NTRM 1 17:00 - 19:00 2.00 CASE RUNC I NTRM 1 19:00 - 19:45 0.75 CASE CIRC INTRM1 19:45 - 21 :45 2.00 CASE RUNC INTRM1 21 :45 - 23:45 2.00 CASE CIRC INTRM1 23:45 - 00:00 00:00 - 01 :45 0.25 CASE RUNC INTRM1 1.75 CASE RUNC INTRM1 Legal Well Name: CD2-25 Common Well Name: CD2-25 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From- To Hours. Code Sub Phase. Code 4/11/2002 15:30 - 16:30 1.00 DRILL CIRC INTRM1 16:30 - 19:30 3.00 DRILL WIPR INTRM1 19:30 - 20:30 1.00 DRILL CIRC INTRM1 20:30 - 00:00 3.50 DRILL DRLG INTRM1 4/12/2002 00:00 - 21 :30 21.50 DRILL DRLG INTRM1 21 :30 - 22:30 1.00 DRILL CIRC INTRM1 22:30 - 00:00 1.50 DRILL WIPR INTRM1 4/13/2002 00:00 - 01 :45 1.75 DRILL WIPR INTRM1 01 :45 - 03:30 1.75 DRILL CIRC INTRM1 03:30 - 05:45 2.25 DRILL TRIP INTRM1 05:45 - 08:30 2.75 DRILL TRIP INTRM1 08:30 - 10:00 1.50 DRILL PULD INTRM1 10:00 - 13:00 3.00 CASE NUND INTRM1 Spud Date: 4/1/2002 End: 4/23/2002 G rou p: Start: 3/31/2002 Rig Release: 4/23/2002 Rig Number: 19 . Description of Opera.tions ¡c. Wiped hole to 4500' 10-20k over, one tight s pot 5621-5612' - 30-50k over. Flow check we II, static. RIH to 7279', no problems. Precautionary ream last stand and CBU - 60 0 gpm - 120 rpm. Drill from 7369' to 7534'. ART=0.6 AST=2.1 Drill from 7534' to 8732'. ART=3.9 AST=9.3 Pumped 40 bbls 300 FV sweep and circ hole clean, 600 gpm - 120 rpm., Minimal increase in cuttings with sweep back. Flow check well, static. Pump out to 8260', blow down Top drive. Continue to POH 10-20 Kover, 8075' at Midnight. Wipe hole to 7020', RIH to 8732', no proble ms Circulate and condition mud 600 gpm - 120 r pm. Pump out to 8064', POH to 6797'. Monitor w ell, pump dry job and blow down top drive. POH to 1075', no problems - flow checks at shoe and BHA, static. Stand back hwdp, lay down remainder of BH A, clear tools from and clean rig floor. PU wash sub and flush stack, pull wear bush ing and install test plug. Change top rams t 0 7" and test 250/5000 psi. Pull test plug an d set thin wall wear bushing. RU fill up tool, long bails, slips, elevators a nd casing tongs. Held prejob safety and operations meeting w ith rig crew. Run 7",26#, L-80 casing to 2375', PUW 125 k SOW 125k. Stage pumps up to 6.0 bpm - 340 psi, circ 0 ne pipe volume. Run casing to 5022' PUW-180k SOW-170k Staged pumps up to 6.0 bpm - 570 psi, CBU. Run casing to 7150', encounterd partial retu rns from well. Circulate and attempt to regain full returns. Initial rate 2.5 bpm - 520 psi with 25% retu rns, with 120 bbls pumped returns at 50%. R egained full returns at 2.5 bpm - 720 psi. A dded water to cut return mud weight of 10.2 - 10.6 ppg. Staged pumps up to 4.5 bpm - 4 60 psi final rate/pressure with full returns. CBU mud wt. in 9.7 ppg, mud wt. out9.8 ppg, estimated total losses @ 140 bbls. Continue to run casing. Run casing, MU hanger and LJ and land casi ng with shoe @ 8722', FC @ 8640'. Printed: 5/10/2002 2:44:18 PM ) ~~ ~ ') PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-25 CD2-25 ROT - DRILLING doyon1 @ppco.com Doyon 19 Date Sub From - To Hours Code Codè Phase 4/14/2002 01 :45 - 02:30 02:30 - 04:00 0.75 CEMENT PULD INTRM1 1.50 CEMENTCIRC INTRM1 04:00 - 04:45 0.75 CEMENT PUMP INTRM1 04:45 - 05:45 1.00 CEMENT DISP INTRM1 05:45 - 06:15 0.50 CEMENT PULD INTRM1 06:15 - 07:00 0.75 CASE OTHR INTRM1 07:00 - 08:00 08:00 - 10:00 1.00 CASE NUND INTRM1 2.00 WELCTL BOPE INTRM1 10:00 - 10:30 0.50 CASE RURD INTRM1 10:30 - 13:30 3.00 DRILL PULD INTRM1 13:30 - 14:30 1.00 DRILL DEOT INTRM1 14:30 - 20:00 5.50 DRILL TRIP INTRM1 20:00 - 21 :00 1.00 RIGMNT RSRV INTRM1 21 :00 - 21 :30 0.50 DRILL TRIP INTRM1 21 :30 - 22:15 0.75 CEMENTCOUT INTRM1 22:15 - 23:15 1.00 CASE DEOT INTRM1 23:15 - 00:00 0.75 CEMENT COUT INTRM1 4/15/2002 00:00 - 03:00 3.00 CEMENT DSHO INTRM1 03:00 - 04:00 1.00 CEMENT FIT INTRM1 04:00 - 04:30 0.50 CEMENT FIT INTRM1 04:30 - 05:00 0.50 DRILL SFTY PROD 05:00 - 08:00 3.00 DRILL OTHR PROD 08:00 - 09:30 1.50 DRILL OTHR PROD Page 4 of 8 Spud Date: 4/1/2002 End: 4/23/2002 Group: Start: 3/31/2002 Rig Release: 4/23/2002 Rig Number: 19 Description of Operations . LD fill up tool and MU cement head. Staged pumps up to 6 bpm and condition mu d for cementing. Reciprocated pipe with full returns throughout, final circ pressure 540 psi. PJSM Test cement lines to 3500 psi, pump 20 bbls of wash, 50 bbls of 12.5 ppg spacer and 30 bbls of 15.8 ppg cement. Begin displaceme nt with 20 bbls of FW from cementers. Displace cement with 311 bbls of 9.7 ppg m ud @ 6.5 bpm, plugs bumped - floats held. R eciprocated casing until I last 15 bbls of dis placement, full returns during job, CIP @ 05 32 hrs. RD cement head, LD LJ, elevators and long b a i Is. Pull thin wear bushing, install and test pack off to 5000 psi. Change top rams to 3-1/2" X 6". Test pipe and blind rams, choke and kill lin e, manifold, surface safety and Top Drive va Ives to 250/5000 psi. John Crisp (AOGCC) w aived witnessing test. U Choke manifold an d surface safety valves were tested while M U BHA. Install wear bushing, PU short bails and DP elevators. MU BHA #3, initialize LWD, PU 3 jts NMCSD P. Shallow test tools, PU and cycle PBL sub, p ull up and recover actuating balls. PU 135 joints of 4" drill pipe and RIH to 801 1 ' . Slip and cut drilling line, serviced Top Driv e and Drawworks. RIH, tagged cement @ 8580'. Clean out cement to 8610' and circulate. RU and test casing to 3500 psi for 30 minut es. RD and blow down surface equipment. Clean out cement to 8637', drill on wiper pi u g s. Drill on wiper plugs (1.5 hrs), drill out ceme nt, float equipment and 20' of new hole to 8 752' . Circ and cond mud for FIT. RU and perform FIT to 12.5 ppg. Held safety and operation meeting with rig c rew and support personell. Transfer 550 bbls of MOBM into pits - prepa re push pill and caustic wash for change ov e r. Pumped 50 bbls of 250 fv LSND mud, 40 bbl s caustic/Safe Surf-O wash, 70 bbls of visco Printed: 5/10/2002 2:44: 1 B PM ) (~~ ~ ) PHILLIPS ALASKA INC. Operation!; Summary Report Legal Well Name: CD2-25 Common Well Name: CD2-25 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From-To Hours Code Sub Phase Code. 4/15/2002 08:00 - 09:30 1.50 DRill OTHR PROD 09:30 - 10:00 0.50 DRill OTHR PROD 10:00 - 17:00 7.00 DRill DRlH PROD 17:00 - 18:30 1.50 DRill CIRC PROD 18:30 - 00:00 5.50 DRill DRlH PROD 4/16/2002 00:00 - 00:00 24.00 DRill DRlH PROD 4/17/2002 00:00 - 04:30 4.50 DRill DRlH PROD 04:30 - 05:00 0.50 RIGMNT RGRP PROD 05:00 - 07:30 2.50 DRill DRlH PROD 07:30 - 09:00 1.50 DRill CIRC PROD 09:00 - 14:00 5.00 DRill TRIP PROD 14:00 - 15:00 1.00 DRill TRIP PROD 15:00 - 18:00 3.00 DRill TRIP PROD 18:00 - 19:00 1.00 DRill TRIP PROD 19:00 - 20:30 1.50 DRill PUlD PROD 20:30 - 22:30 2.00 DRill PUlD PROD 22:30 - 00:00 1.50 DRill TRIP PROD 4/18/2002 00:00 - 04:30 4.50 DRill TRIP PROD 04:30 - 08:00 3.50 DRill REAM PROD 08:00 - 09:30 1.50 DRill DRlH PROD 09:30 - 10:30 1.00 DRill CIRC PROD 10:30 - 20:00 9.50 DRill DRlH PROD 20:00 - 22:30 2.50 DRill CIRC PROD Page 5 of8 Spud Date: 4/1/2002 End: 4/23/2002 Group: Start: 3/31/2002 Rig Release: 4/23/2002 Rig Number: 19 Description of Operations sified MOBM and change well over with 8.5 ppg MOBM. Wash shaker pans, rinse out pits #1 and #6. Drill from 8752' to 9252'. ART=4.4 AST=0.3 Double reaming prior to connections due to high drag 50-75k. CBU x 1.5 - 5.2 bpm - 2040 psi - 110 rpm, in itial ECD= 10.1 ppg, final ECD=9.8 ppg. Drill from 9252' to 9560' ART!:::2.4 AST=O M ade several attempts to slide for build, una ble due to weight stacking above bit. Drill from 9560' to 10990' (7200' tvd) ART=1 2.5 AST=2.4 ECD @ 5.2 bpm 10.0 ppg - 10 .2 P P g Drill from 10990' to 11255'. ART=3.2 AST=1 . 1 lost power to shakers, electrician located s hort, back on with 2 shakers. Drill from 11255' to 11351'. Resistivity tool fa i led. Circulate hole clean 5.2 bpm - 2220 psi - 11 0 rpm. Monitor well- static. Pump out to 8298', 4.0 bpm - 1550 psi, no p roblems. Flow check well, static. Pump down activati ng ball and open PBl sub, pump dry job, blo w down Top Drive. POH to BHA, no problems, monitor well, stat i c. Recovered Mud Dog wiper assembly, stopped in jars. Dropped deactivation ball and clos ed PBl sub. Break down PBl sub and empty ball catcher. lD PBl sub. Stand back hwdp and NMCSDP, down load an d lD MWD & lWD. Pull up and inspect bit, 0 K. PU MWD and lWD collars, scribe and initiali ze tools. MU remainder of BHA, shallow test too Is. RIH to 2700', fill pipe. RIH to 8936', fill pipe every 2000'. log with lWD for missed data, 8936'-9606', 10191' to 10346' (memory) and 10946' to 1 1351' (real time). Drill from 11351' to 11447'. ART=1.1 AST=O Circ 20 bbl piggy back low vis sweep around , moderate increase in cuttings at shakers w ith sweeps back. Drill from 11447' to 11994' (7160' tvd), TD. Drilled through top of C sand @ 11945' - 96 degrees incl. Circulate and condition mud - 5.2 bpm - 242 0 psi-100 rpm. Printed: 5/10/2002 2:44:18 PM ~~ ~ ) ) PHILLIPS ALASKA INC. . Operations SUrnmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4/18/2002 4/19/2002 4/20/2002 CD2-25 CD2-25 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub From;.; To HoÜrsCbde Code Phase 22:30 - 00:00 00:00 - 05: 15 05: 15 - 07:30 07:30 - 10:30 10:30 - 12:15 12:15 - 13:15 13:15 - 14:45 14:45 - 17:00 17:00 - 20:00 20:00 - 23:30 23:30 - 00:00 00:00 - 03: 15 03: 15 - 06:00 06:00 - 09:00 09:00 - 12:30 12:30 - 15:30 1.50 DRILL TRIP PROD 5.25 DRILL TRIP PROD 2.25 DRILL CIRC PROD 3.00 DRILL CIRC PROD 1.75 DRILL WIPR PROD 1.00 DRILL OTHR PROD 1.50 DRILL TRIP PROD 2.25 DRILL CIRC PROD 3.00 DRILL CIRC PROD 3.50 DRILL TRIP PROD 0.50 DRILL CIRC PROD 3.25 DRILL TRIP PROD 2.75 DRILL CIRC PROD 3.00 DRILL TRIP PROD 3.50 DRILL TRIP PROD 3.00 DRILL TRIP PROD Page 601 8 Spud Date: 4/1/2002 End: 4/23/2002 Group: Start: 3/31/2002 Rig Release: 4/23/2002 Rig Number: 19 Description of operations. Monitor well, static, begin pumping out of 0 pen hole, 11254' @ midnight. Pump out of hole from 11254' to 8298'. Drop ball and open PBL sub, stage pumps up to 7 bpm, PBL sub shifted closed. Attempte d to cycle tool open, no good. Dropped "erne rgency activation ball", unable to cycle tool op en. Circ to clean up casing, 5.2 bpm (MWD limit ) 1860 psi, 120 rpm. Pumped 10 bbls of min eral oil - 20 bbls of MOBM - 20 bbls of 10.0 ppg MOBM. large increase in sand across sh akes with sweeps back, circ untill shakers c lea n. POH to 6772', hole not taking proper fill, m onitor well - static. RU slickline(Doyon) and recover ID pipe wip er assembly. RIH to 8680'. Circ and increase mud wt. to 8.6 ppg. - 5.2 bpm - 1850 psi - 120 rpm. Large push of san d back with 70 % of first BU. Increase rate to 8.0 bpm - 3790 psi - 120 rp m Circulate and balance wt to 8.6 ppg, mode rate increase in cuttings across shakers. Pu mped 10 bbls of mineral oil - 20 bbls of MO BM - 20 bbls of 10.0 ppg MOBM. Circulated sweep around, moderate increase in nut plu g back with mineral oil, slight push of forma tion sand in wt sweep. Continue to circulate until I clean. Pump out to 7726', attempted to pull 1 stan d, observed slight swabbing, pump out from 7726' to 7248'. RIH to 7342' and CBU 8.0 bpm - 3040 psi - 1 20 rpm, very slight amount of sand across s hakers. Monitor well, static. Attempted to pull 1 sta nd, slight swab. Pump out from 7342' to 639 0 '. Circ to clean hole 8 bpm - 3300 psi - 120 rp m, pumped 3 BU with slight amount of sand across shakers throughout. Monitor well, sta tic, attempted to pull 1 stand, had slight sw abbing. Circ and increase mud wt. from 8.6 ppg to 8.8 ppg. Attempt to pull pipe - slight swabbing. Pump out to 5053', monitor well, static. Atte mpted to pull pipe, slight swabbing. Pump out to 4098', monitor well, static. Pull ed 3 stands on trip tank, short 0.5 bbl. Pump out to 1904', monitor well, static. Wor ked 1 stand no swabbing - fluid dropped in Printed: 5/10/2002 2:44: 18 PM ) <,~þ ~~l ~ ) Page 7 018 PHILLIPS ALASKA INC. . . Op.erations SummélryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-25 CD2-25 ROT - DRILLING doyon1 @ ppco.com Doyon 19 Date From-To Hours Code Sub Phase Code 4/20/2002 12:30 - 15:30 3.00 DRILL TRIP PROD 15:30 - 17:30 2.00 DRILL TRIP PROD 17:30 - 19:30 2.00 DRILL PULD PROD 19:30 - 22:30 3.00 DRILL TRIP CMPL TN 22:30 - 00:00 1.50 RIGMNT RSRV CMPL TN 4/21/2002 00:00 - 01 :00 1.00 CMPL TN OTHR CMPL TN 01 :00 - 04:00 3.00 CMPLTN CIRC CMPL TN 04:00 - 07:30 3.50 CMPL TN TRIP CMPL TN 07:30 - 10:30 3.00 CMPL TN TRIP CMPL TN 10:30 - 14:15 3.75 CMPLTN TRIP CMPL TN 14:15 - 16:30 2.25 CMPL TN TRIP CMPL TN 16:30 - 17:30 1.00 CMPL TN RURD CMPL TN 17:30 - 18:00 0.50 CMPL TN SFTY CMPL TN 18:00 - 00:00 6.00 CMPL TN PULD CMPL TN 4/22/2002 00:00 - 02:45 2.75 CMPLTN RUNT CMPL TN 02:45 - 04: 15 1.50 CMPL TN RUNT CMPL TN 04:15 - 08:00 3.75 CMPLTN RUNT CMPL TN 08:00 - 09:00 1.00 CMPL TN RUNT CMPL TN 09:00 - 12:00 3.00 CMPL TN SEaT CMPL TN 12:00 - 17:00 5.00 CMPL TN NUND CMPL TN Start: 3/31/2002 Rig Release: 4/23/2002 Rig Number: 19 Spud Date: 4/1/2002 End: 4/23/2002 Group: annulus. POH, stood back hwdp, hole taking proper di splacement. Flow check @ 473', static. Service break and lay down PBL sub. Found tool in open position with activating ball inb edded in circulating port. Down load LWD, I aid down BHA. MU bit and scraper and RIH to 5914', fill pip e every 2000'. Slip and cut drilling line, service Top Drive. RIH with bit and scraper from 5914' to 7918' , no problems. Staged pumps up to 8.0 bpm - 2440 psi - 11 0 rpm, circ to clean up casing. Pumped 20 b bls of 10.0 ppg MOBM sweep and circ hole c lean. Very slight amount of formation sand a nd nut plug in returns, balanced mud wt. 8.8 ppg in and out. Monitor well 10 minutes, static, attempted t 0 pull 1st stand- observed slight swabbing. Pump out 20 stands to 6009'. Monitor well, static, attempt to pull 1 stand - observed sli ght swabbing. Pump out 20 stands to 4099', monitor well, static. Attempt to pull 1 stand - observed sl ight swabbing. Pump out 20 stands to 2095', monitor well, static. Pulled 1 stand - observed fluid drop in annulus. POH, clean up trip mess. Pull wear bushing and rig up to run 4 1/2" t ubi n g. Held safety and operations meeting with rig and support crews. MU Completion equipment and RIH picking u p 4 1/2",12.6#, L-80 tubing. Run completion tubing to 5879. MU SSSV, RU Camco - connect and test cont rol lines. Continue running tubing - banding control Ii nes 177 joints total. MOBM ran over couplin gs from Jnt #8 on. MU tubing hanger, install and pressure test control line fittings - land tubing with WLEG @ 7882'. RILDS, LD LJa and install TWC. MU LJb - t est hanger M/M seals to 5000 psi, LD LJb. C lean up rig floor. ND BOP Stack, removed ram blocks, bell nip pie and accumulator lines in preparation for stack change out during rig move. Removed choke and kill lines from stack. Printed: 5/10/2002 2:44:18 PM ) ~. ~ ) Page 80t 8 PHILLIPS ALASKA INC. Operations Summary.Repott Legal Well Name: CD2-25 Common Well Name: CD2-25 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 .Date From.. To Hours. Code .Sub,. Phase Code 4/22/2002 17:00 - 18:30 1.50 CMPL TN NUND CMPL TN 18:30 - 20:15 1.75 CMPLTN RURD CMPL TN 20:15 - 20:30 0.25 CMPL TN SFTY CMPL TN 20:30 - 23:30 3.00 CMPL TN FRZP CMPL TN 4/23/2002 23:30 - 00:00 00:00 - 03:00 0.50 CMPL TN SUN CMPL TN 3.00 CMPL TN SUN CMPL TN 03:00 - 04:30 1.50 CMPL TN PCKR CMPL TN 04:30 - 05:30 1.00 CMPL TN NUND CMPL TN 05:30 - 06:30 06:30 - 11 :30 11 :30 - 12:00 1.00 CMPL TN OTHR CMPL TN 5.00 CMPL TN OTHR CMPL TN 0.50 CMPL TN OTHR CMPL TN Spud Date: 4/1/2002 End: 4/23/2002 Group: Start: 3/31/2002 Rig Release: 4/23/2002 Rig Number: 19 Descriptionot Operations. Terminate SSSV control lines, NU adaptor fl ange and tree - test to 5000 psi. RU FMC lubricator and pull TWC, install Ho wco pump in spool and BOP's on tree. RU ci rculating manifold and lines. Held safety meeting to prepare for displacin g well to diesel. Test lines to 4000 psi, pumped 50 bbls of mi neral oil and 248 bbls of diesel to recover M OBM and freeze protect tubing and casing. Average displacement rate of 4 bpm, followe d back pressure schedule on choke. RU slickline lubricator. Test Howco lubicator - RIH & pull dummy in SSSV - Change tools - RIH & close sliding s I eeve Drop rod/ball to set packer - Pressure up on tbg to 3500 psi to set packer & test tbg for 30 mins. - Test 7" x 4.5 annulus for 30 min s to 3500 psi Bleed pressure from annulus to 0 psi - bleed tbg to 1000 psi - blow down lines & manifol d - RD Howco lubicator Set BPV -Secure well LD 111 jts. 4" drill pipe for rig move Clear floor - Release rig @ 1200 hrs. 4/23/2 002 Printed: 5/10/2002 2:44: 18 PM .~ ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00135 Sidetrack No. Page 1 af 7 - ~. Company ~~!--'.PS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co, - Rig: #19 Field ALPINE FIELD ----~ ~'--~--~-~ ----_..-- Well Name & No. PAD CD#2/25 Survey Section Name CD2-25 MWD BHI Rep. D NEWLON I D BALLOU INTEQ. -- -----'-------, WELL DATA Target rvD (FT) Target Coord. N/S Slot Coord. N/S -1814.78 Grid Correction 0,000 Depths Measured From: RKB ~ MSL 0 SSD Target Description Target Coord. E/W Slot Coord, E/W -1532.01 Magn. Declination 0,000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Wálk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 260.80 Magn. to Map Corr. 0,000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length rvD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (per 100 FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 06-APR-02 MWD 114.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 0.00 --- 06-APR-02 MWD 173.00 0.35 274.00 59.00 173.00 0.18 0.01 -0.18 0.59 0.59 06-APR-02 MWD 299.86 0.26 279.72 126.86 299.86 0.82 0.09 -0.85 0.07 -0.07 06-APR-02 MWD 395.67 0.46 241 .18 95.81 395.67 1.39 -0.06 -1.40 0.32 0.21 06-APR-02 MWD 482.56 0.61 239.33 86.89 482.55 2.15 -0.46 -2.10 0.17 0.17 06-APR-02 MWD 568.11 0.73 219.19 85.55 568.10 2.98 -1.12 -2.84 0.31 0.14 06-APR-02 MWD 660.28 1.01 226.29 92.17 660.26 4.09 -2.14 -3.80 0.32 0.30 06-APR-02 MWD 752.85 1.07 231.00 92.57 752.81 5.51 -3.24 -5.06 0.11 0.06 06-APR-02 MWD 843.81 1.49 228.29 90.96 843.75 7.25 -4.56 -6.60 0.47 0.46 06-APR-02 MWD 932,62 1.62 228.12 88.81 932.52 9.28 -6.17 -8.40 0.15 0.15 06-APR-02 MWD 1029.84 3.64 232.49 97.22 1029.64 13.15 -8.97 -11 .87 2.09 2.08 06-APR-02 MWD 1127.47 5.57 237.92 97.63 1126.95 20.25 -13.37 -18.34 2.02 1.98 5.56 06-APR-02 MWD 1 220, 1 2 5.87 236,20 92.65 1219.14 28,70 -18.40 -26.09 0.37 0.32 -1.86 -' 06-APR-02 MWD 1316.37 5.93 237.73 96.25 1314.88 37.75 -23.79 -34.39 0.17 0.06 1.59 06-APR-02 MWD 1409.12 5.92 238.17 92.75 1407.13 46.57 -28,87 -42.50 0.05 -0.01 0.47 06-APR-02 MWD 1505.59 5,99 236.71 96.47 1503.08 55.76 -34.26 -50.94 0.17 0.07 -1.51 07-APR-02 MWD 1601 ,58 6.13 240.12 95.99 1598.53 65.12 -39.56 -59.57 0.40 0,15 3.55 07-APR-02 MWD 1697,31 6,21 242.10 95.73 1693.71 74,81 -44.53 -68.57 0.24 0.08 2.07 07-APR-02 MWD 1792.25 6.42 243.71 94.94 1788.07 84.75 -49.28 -77.87 0.29 0.22 1,70 07-APR-02 MWD 1886.69 6,60 240.98 94.44 1881.91 94.90 -54.25 -87.35 0.38 0.19 -2.89 ------ 07-APR-02 MWD 1981.29 5,36 241 .15 94,60 1975.99 104.18 -59.02 -95.97 1.31 -1,31 0.18 ---- 07 -APR-02 MWD 2076.50 4.89 242.94 95.21 2070.82 112.23 -63.01 -103.48 0.52 -0.49 07-APR-02 ~D-t21-7u6 3,18 242.32 95.26 2165.84 118.60 -66,09 -109.44 1.80 -1.80 I = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00135 Sidetrack No. Page 2 of 7 - Company ~~~~LlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No, PAD CD#2/25 ----- Survey Section Name CD2-25 MWD BHI Rep. D NEWLON I D BALLOU '''''.~ WELL DATA Target rvD (FI) Target Coord. N/S Slot Coord, N/S -1814.78 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSD Target Description Target Coord. E/W Slot Coord, E/W -1532.01 Magn. Declination 0,000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert Sec. Azim. 260.80 Magn. to Map Corr. 0,000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length rvD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FI) (DO) (DO) (FT) (FT) (FI) (FT) (Per 100 FI) Drop (-) Left (-) 07-APR-02 MWD 2267.27 0.60 283.49 95.51 2261.29 121.57 -67.20 -112.27 2.89 -2.70 07 -APR-02 MWD 2325.61 0.72 32.36 58.34 2319.63 121.61 -66.82 -112.37 1.84 0.21 .~ 09-APR-02 MWD 2442.22 1.91 32.12 116.61 2436.21 119.84 -64.56 -110.95 1.02 1.02 09-APR-02 MWD 2537.58 0.87 19.77 95.36 2531.54 118.44 -62.53 -109.86 1.13 -1.09 09-APR-02 MWD 2631 .36 0.30 328.00 93.78 2625.31 118.19 -61 .65 -109.75 0.77 -0.61 09-APR-02 MWD 2727.30 0.45 305.20 95.94 2721 .25 118.56 -61.22 -110.19 0.22 0.16 09-APR-D2 MWD 2823.53 0.53 329.61 96.23 2817.48 118.99 -60.62 -110.72 0.23 0.08 09-APR-02 MWD 2918.80 0.52 318.21 95.27 2912.74 119.38 -59.92 -111 .23 0.11 -0.01 09-APR-02 MWD 3014.28 0.44 330.85 95.48 3008.22 119.74 -59.27 -111 .70 0.14 -0.08 09-APR-02 MWD 3109.82 0.49 321.48 95.54 3103.76 120.07 -58.63 -112.13 0.10 0.05 09-APR-02 MWD 3205.19 0.51 311.52 95.37 3199.12 120.53 -58.03 -112.70 0.09 0.02 09-APR-02 MWD 3300,60 0.50 247.69 95.41 3294.53 121.21 -57.91 -113.41 0.56 -0.01 09-APR-02 MWD 3393.87 0.54 226.06 93.27 3387.79 121 .97 -58.37 -114.10 0.21 0.04 09-APR-02 MWD 3491 .53 0.66 217.98 97.66 3485.45 122.76 -59.13 -114.78 0.15 0.12 ~ 09-APR-02 MWD 3586.91 0.66 216.92 95.38 3580.82 123.56 -60.00 -115.45 0.01 0.00 09-APR-02 MWD 3682.41 0.66 204.84 95.50 3676.32 124.26 -60.94 -116.01 0.15 0.00 09-APR-02 MWD 3778.08 0.64 221 .16 95.67 3771.98 124.98 -61.85 -116.59 0.19 -0.02 09-APR-02 MWD 3873.72 0.62 214.76 95.64 3867.61 125.75 -62.67 -117.24 0.08 -0.02 09-APR-02 MWD 3969.29 0.64 224.27 95.57 3963.18 126.54 -63.48 -117.91 0.11 0.02 09-APR-02 MWD 4062.76 0.64 214.75 93.47 4056.64 127.32 -64.28 -118.57 0.11 0.00 09-APR-02 MWD 4159.54 0,71 239.34 96.78 4153.42 128.25 -65.03 -119.39 0.31 0.07 _._~---- 1 O-APR-02 MWD 4255.07 0,65 218.89 95.53 4248.94 129.21 -65.76 -120.24 0.26 -0,06 1 O-APR-02 MWD 4350.14 0.68 223.93 95,07 4344.00 130.06 -66.58 -120.97 0.07 0.03 .__.~ ---- 1 0-APR-02 MWD 4445.77 0.79 217.44 95.63 4439,63 130.99 -67.51 -121.76 0.14 0.12 = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00135 Sidetrack No. Page 3 of 7 - Company ~~LLlPS ALASKA, INC. Rig Contractor & No. Doyon _Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/25 -- Survey Section Name CD2-25 MWD BHI Rep. D NEWLON I D BALLOU IIVI~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord, N/S -1814.78 Grid Correction 0.000 Depths Measured From: RKB ~ MSL D SSD Target Description Target Coord. E¡W Slot Coord. ENV -1532.01 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 260.80 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100FT) Drop (-) Left (-) 1 0-APR-02 MWD 4541.44 0.80 236.77 95.67 4535.29 132.08 -68.40 -122.72 0.28 0.01 1 0-APR-02 MWD 4634.02 0.77 234.96 92.58 4627.86 133.23 -69.11 -123.77 0.04 -0,03 - 10-APR-02 MWD 4732.75 3.02 233.27 98.73 4726.53 136.14 -71.05 -126.40 2.28 2.28 1 0-APR-02 MWD 4828.19 6.57 231.92 95.44 4821 .62 143.15 -75.92 -132.72 3.72 3,72 -1.41 1 0-APR-02 MWD 4922.86 8.59 232.18 94.67 4915.46 154.10 -83.60 -142.57 2.13 2,13 0.27 1 0-APR-02 MWD 5018.49 10.51 233.60 95.63 5009.76 168.13 -93.16 -155.23 2.02 2.01 1.48 10-APR-02 MWD 5113.37 13.37 237.14 94.88 5102.58 185.87 -104.25 -171.41 3.11 3,01 3.73 1 0-APR-02 MWD 5208.55 15.48 240.04 95.18 5194.75 207.83 -116.56 -191.66 2.34 2.22 3.05 1 0-APR-02 MWD 5304.57 18.01 240.92 96.02 5286.69 233.78 -130.18 -215.74 2.65 2,63 0.92 1 0-APR-02 MWD 5400.16 20,54 242.61 95.59 5376.92 263.61 -145.08 -243.55 2.71 2.65 1.77 1 0-APR-02 MWD 5494.79 22.79 242.79 94.63 5464.86 296.82 -161 .10 -274.59 2.38 2,38 0.19 1 0-APR-02 MWD 5590.03 25.80 239.71 95.24 5551.66 333.71 -179.99 -308.90 3.43 3,16 -3.23 1 0-APR-02 MWD 5684.52 28.05 237.39 94.49 5635.90 373.29 -202.34 -345.38 2.63 2,38 -2.46 1 0-APR-02 MWD 5781.67 31.54 237.61 97.15 5720.19 417.62 -228.27 -386.09 3.59 3.59 0.23 -~..... 10-APR-02 MWD 5876,74 34.71 237.64 95.07 5799.80 465.37 -256.08 -429.96 3.33 3.33 0.03 1 0-APR-02 MWD 5973.25 37,58 237.30 96.51 5877.73 517.64 -286.69 -477.95 2.98 2,97 -0.35 11-APR-02 MWD 6069.41 40.36 236.96 96.16 5952.48 573.02 -319.52 -528.73 2.90 2.89 -0.35 11-APR-02 MWD 6162.77 42.92 236.48 93.36 6022.25 629.64 -353.56 -580.58 2.76 2.74 -0.51 11-APR-02 MWD 6258.58 46,15 234.91 95.81 6090.54 690.47 -391.45 -636.07 3.56 3.37 -1.64 11 -APR-02 MWD 6354.58 48.55 234.57 96.00 6155.58 753.89 -432.21 -693.71 2.51 2.50 -0.35 11-APR-02 MWD 6450.60 51.87 235,63 96.02 6217.02 820.37 -474.40 -754.22 3.56 3.46 1.10 ------ 11-APR-02 MWD 6546.26 55,06 235,70 95.66 6273,96 889.95 -517,75 -817.69 3.34 3.33 0.07 11-APR-02 MWD 6641,87 57.55 237.06 95.61 6327,00 962.37 -561,77 -883.93 2.86 2.60 1.42 ~---------- 11-APR-02 MWD 6737.86 57.45 235.91 95.99 6378.58 I 1036.15 -606.47 -951.42 1,02 -0.10 ~1.20 I = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00135 Sidetrack No, Page 4 of 7 ~~---- - Company Pf::i!~~I~~__~SKA, INC, Rig Contractor & No. Doy~n Drilling Co. - Rig: #19 Field ALPINE FIELD -~~ Well Name & No, PAD CD#2I25 ---- Survey Section Name CD2-25 MWD BHI Rep. D NEWLON / D BALLOU IIV.~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1814.78 Grid Correction 0.000 Depths Measured From: RKB g] MSL 0 SSO Target Description Target Coord. E/W Slot Coord. E!W -1532.01 Magn: Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert Sec. Azim. 260.80 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 11-APR-02 MWD 6833.64 57.33 235.97 95.78 6430.19 1109.35 -651.66 -1018.26 0.14 -0.13 0.06 ~ - 11-APR-02 MWD 6926.92 57.15 236.00 93.28 6480.67 1180.55 -695.54 -1083.28 0.19 -0.19 0.03 11-APR-02 MWD 7022.47 57.10 236.22 95.55 6532.53 1253.47 -740.29 -1149.90 0.20 -0.05 0.23 11-APR-02 MWD 7117.99 56.92 235.35 95.52 6584.54 1326.07 -785.34 -1216.15 0.79 -0.19 -0.91 11-APR-02 MWD 7151.25 56.74 235.68 33.26 6602.74 1351.24 -801.10 -1239.10 0.99 -0.54 0.99 11-APR-02 MWD 7182.46 56.22 236.78 31.21 6619.98 1374.90 -815.56 -1260.73 3.38 -1.67 3.52 11-APR-02 MWD 7212.93 55.42 239.44 30.47 6637.10 1398.16 -828.88 -1282.13 7.68 -2.63 8.73 11-APR-02 MWD 7247.20 54.98 242.72 34.27 6656.66 1424.64 -842.49 -1306.75 7.96 -1.28 9.57 11-APR-02 MWD 7280.23 54.67 245.26 33.03 6675.69 1450.48 -854.33 -1331.01 6.36 -0.94 7.69 11-APR-02 MWD 7305.16 54.50 247.15 24.93 6690.14 1470.14 -862.52 -1349.60 6.22 -0.68 7.58 11-APR-02 MWD 7340.29 54.59 249.79 35.13 6710.52 1498.09 -873.02 -1376.21 6.13 0.26 7.51 11-APR-02 MWD 7374.15 55.02 252.57 33.86 6730.03 1525.37 -881 .95 -1402.40 6._83 1.27 8.21 11-APR-02 MWD 7403.24 55,29 254.01 29.09 6746.66 1549,04 -888.81 -1425.27 4.17 0.93 4.95 11-APR-02 MWD 7437.16 55,60 256.77 33.92 6765.90 1576.84 -895.86 -1452.30 6.76 0.91 8.14 .~ 11-APR-02 MWD 7470.18 56,03 259.13 33.02 6784.45 1604.12 -901 .56 -1479.01 6.05 1.30 7.15 11-APR-02 MWD 7500.51 56,66 261 .06 30.33 6801 .26 1629.36 -905,90 -1503.87 5.69 2.08 6.36 12-APR-02 MWD 7536.36 56.94 263.86 35.85 6820.90 1659.35 -909.83 -1533.61 6.58 0.78 7.81 12-APR-02 MWD 7566.30 57.05 266.16 29.94 6837.21 1684.38 -912.01 -1558.62 6.45 0.37 7.68 12-APR-02 MWD 7597.58 57.25 269.23 31.28 6854.18 1710.47 -913.07 -1584.87 8.27 0.64 9.81 1 2-APR-02 MWD 7629.01 57,17 271 .96 31.43 6871.20 1736.50 -912.80 -1611.29 7.31 -0.25 8.69 12-APR-02 MWD 7661,50 57.57 273.03 32.49 6888.72 1763.29 -911 .60 -1638.62 3.03 1.23 3.29 12-APR-02 MWD 7691.76 58.47 276.22 30.26 6904.75 1788.21 -909,53 -1664.20 9.42 2.97 10,54 12-APR-02 MWD 7725.42 59,09 278.48 33.66 6922.20 1815.80 -905.85 -1692.75 6.03 1,84 6.71 --------- ---- 12-APR-02 MWD I 7756.35 59,85 281 .20 30.93 6937.91 1840.98 -901 .29 -1718.99 7.96 2.46 8.79 . :- - - - - - :- = SURVEY CALCULATION AND FIELD WORKSHEET Job No, 0450-00135 Sidetrack No. Page 5 of 7 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co, - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/25 Survey Section Name CD2-25 MWD BHI Rep. D NEWLON / D BALLOU 11w.~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1814.78 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSD Target Description Target Coord. E/W Slot Coord. E/W -1532,01 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 260.80 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 12-APR-02 MWD 7787.78 60.23 282.67 31.43 6953.61 1866.38 -895.66 -1745.63 4.23 1.21 4.68 ~ '-- 12-APR-02 MWD 7820.29 60.79 285.42 32.51 6969.61 1892.37 -888.79 -1773.08 7.56 1.72 8.46 12-APR-02 MWD 7851.26 61.42 288.15 30.97 6984.58 1916.74 -880.96 -1799.04 7.98 2.03 8.82 12-APR-02 MWD 7882.84 62.74 290.98 31.58 6999.37 1941.20 -871 .62 -1825.32 8.95 4.18 8.96 12-APR-02 MWD 7916.47 63.62 293.26 33.63 7014.54 1966.83 -860.31 -1853.12 6.59 2.62 6.78 12-APR-02 MWD 7947.32 64.35 295.14 30.85 7028.08 1989.98 -848.95 -1878.41 5.97 2.37 6.09 12-APR-02 MWD 7978.64 65.53 297.74 31.32 7041 .34 2013.03 -836.31 -1903,81 8.41 3.77 8.30 12-APR-02 MWD 8009.26 67.26 298.74 30.62 7053.61 2035.30 -823.04 -1928.52 6.39 5.65 3.27 12-APR-02 MWD 8042.17 67.87 299.56 32.91 7066.16 2059.16 -808.22 -1955.09 2.96 1.85 2.49 12-APR-02 MWD 8072.28 68.87 300.41 30.11 7077.26 2080.85 -794.23 -1979.33 4.23 3.32 2.82 12-APR-02 MWD 8106.47 69.44 301 .80 34.19 7089.43 2105.22 -777.72 -2006.69 4.15 1.67 4.07 12-APR-02 MWD 8137.17 69.61 301 .93 30.70 7100.17 2126.90 -762.54 -2031.11 0.68 0.55 0.42 12-APR-02 MWD 8167.66 70.65 302.90 30.49 7110.53 2148.34 -747.17 -2055.32 4.54 3.41 3.18 12-APR-02 MWD 8200.43 71.62 305,39 32,77 7121.13 2170.89 -729.77 -2080,98 7.78 2.96 7.60 ~ 12-APR-02 MWD 8234.15 72.73 306,88 33,72 7131 .45 2193.45 -710.84 -2106.91 5.34 3.29 4.42 12-APR-02 MWD 8263.35 73.80 308.72 29,20 7139.86 2212,52 -693.70 -2129,00 7.06 3.66 6.30 12-APR-02 MWD 8297.16 75.02 311.27 33.81 7148.95 2233.80 -672.77 -2153.94 8.11 3.61 7.54 12-APR-02 MWD 8329.19 76,29 313,17 32.03 7156.89 2253.15 -651.91 -2176,92 6.98 3.96 5.93 12-APR-02 MWD 8359,08 77,32 315,28 29,89 7163.71 2270.48 -631 ,62 -2197,77 7.69 3.45 7.06 12-APR-02 MWD 8393.27 78.13 316.28 34,19 7170,98 2289.66 -607.68 -2221.07 3.71 2.37 2.92 12-APR-02 MWD 8425.27 79.24 317.55 32.00 7177.26 2307,15 -584.76 -2242,50 5.21 3.47 3.97 -- 12-APR-02 MWD 8454.22 80.32 318,50 28,95 7182.39 2322.57 -563.58 -2261 ,56 4.93 3.73 3.28 12-APR-02 MWD 8488.15 81.75 320,12 33,93 7187.68 2340.08 -538.17 -2283.41 6.32 4.21 4.77 12-APR-02 MWD 8520.15 82.75 321 .13 32,00 7192.00 2356.01 -513.66 -2303,52 4.42 3.13 3.16 = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-001 35 Sidetrack No. Page 6 of 7 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD -~.~---~-- Well Name & No. PAD CD#2/25 Survey Section Name CD2-25 MWD BHI Rep. D NEWLON 1 D BALLOU ,,... .I:=Q. WELL DATA Target TVD - (FT) Target Coord. N/S Slot Coord. N/S -1814.78 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSD Target Description Target Coord. E/W Slot Coord. E/W - 1532.01 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 260.80 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) IS(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100FT) Drop (-) Left (-) 12-APR-02 MWD 8549.94 83.69 322.71 29.79 7195.51 2370.30 -490.37 -2321.76 6.14 3.16 5.30 ---, - 12-APR-02 MWD 8583.23 84.12 324.41 33.29 7199.05 2385.45 -463.74 -2341.43 5.24 1.29 5.11 12-APR-02 MWD 8615.14 84.38 326.13 31.91 7202.25 2399.13 -437.65 -2359.51 5.42 0.81 5.39 12-APR-02 MWD 8644.88 84.88 327.28 29.74 7205.03 2411.22 -412.90 -2375.77 4.20 1.68 3.87 12-APR-02 MWD 8669.24 85.39 328.71 24.36 7207.09 2420.63 -392.32 -2388.63 6.21 2.09 5.87 15-APR-02 MWD 8812.12 89.10 332.05 142.88 7213.96 2470.40 -268.29 -2459.14 3.49 2.60 2.34 15-APR-02 MWD 8906.71 90.02 332.39 94.59 7214.69 2500.54 -184.61 -2503.22 1.04 0.97 0.36 15-APR-02 MWD 9003.95 90.04 333.00 97.24 7214.64 2530.76 -98.20 -2547.83 0.63 0.02 0.63 15-APR-02 MWD 9099.88 90.06 333.21 95.93 7214.55 2559.91 -12.65 -2591 .22 0.22 0.02 0.22 15-APR-02 MWD 9194.55 89.78 333.25 94.67 7214.69 2588.49 71.88 -2633.86 0.30 -0.30 0.04 15-APR-02 MWD 9289.97 89.70 333.03 95.42 7215.12 2617.44 157.00 -2676.98 0.25 -0.08 -0.23 15-APR-02 MWD 9385.96 89.76 333.81 95.99 7215.57 2646.11 242.84 -2719.93 0.81 0.06 0.81 15-APR-02 MWD 9480.16 89.16 332.79 94.20 7216.46 2674.44 326.99 -2762.25 1.26 -0.64 -1.08 16-APR-02 MWD 9576.12 90.27 332.14 95,96 7216.94 2704.62 412.08 -2806.61 1.34 1.16 -0.68 ..-/ 16-APR-02 MWD 9671.29 90.68 331.54 95,17 7216.15 2735.54 495.98 -2851.52 0.76 0.43 -0.63 16-APR-02 MWD 9766.55 90.84 331.27 95,26 7214.88 2767.17 579.62 -2897.11 0.33 0,17 -0.28 16-APR-02 MWD 9861.63 90.25 330.70 95.08 7213.98 2799.40 662.76 -2943.22 0.86 -0,62 -0.60 1 6-APR-02 MWD 9957,05 90.99 329.88 95.42 7212,95 2832.83 745.63 -2990.51 1.16 0.78 -0.86 16-APR-02 MWD 10052.31 90.70 328.89 95.26 7211 .54 2867.61 827.60 -3039.02 1.08 -0.30 -1.04 16-APR-02 MWD 10149.00 92.14 328.96 96.69 7209.15 2903.62 910.39 -3088.91 1.49 1,49 0.07 1 6-APR-02 MWD 10244.32 92.61 329.17 95.32 7205.20 2938.89 992.08 -3137.87 0.54 0,49 0.22 16-APR-02 MWD 10339.65 91.55 330.13 95.33 7201.74 2973.26 1074.29 ~3186.00 1.50 -1.11 1.01 16-APR-02 MWD 10435.27 91,44 330.28 95.62 7199.24 3006.89 1157.24 -3233.50 0.19 -0.12 0.16 ---- ---.----- -- 16-APR-02 MWD 10530,71 89.65 332.24 95.44 7198,33 3038.80 1240.91 -3279,39 2.78 -1.88 2.05 ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00135 Sidetrack No. Page 7 of 7 ~ Company PHILLIPS ALASKA. INC. ---'-------------- ~ ~--- --------- Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2!25 Survey Section Name CD2-25 MWD BHI Rep. D NEWLON I D BALLOU INTEQ -------- - -- WELL DATA Target rvD (FT) Target Coord. N/S Slot Coord, N/S -1814.78 Grid Correction 0.000 Depths Measured From: RKB ~ MSL D SSD Target Description Target Coord. E/W Slot Coord, E/W -1532.01 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 260.80 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length rvD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100FT) Drop (-) Left (-) 16-APR-02 MWD 10626.09 89.30 332.18 95.38 7199.21 3069.21 1325.28 -3323.85 0.37 -0.37 -0.06 16-APR-02 MWD 10721 .59 88.94 331.82 95.50 7200.68 3099.98 1409.60 -3368.68 0.53 -0.38 -0.38 .~ 16-APR-02 MWD 10817.70 89.96 331.76 96.11 7201 .60 3131.28 1494.28 -3414.11 1.06 1.06 -0.06 16-APR-02 MWD 10911.29 90.13 332.30 93.59 7201 .52 3161 .40 1576.94 -3458.01 0.60 0.18 0.58 17 -APR-02 MWD 11 006.50 90.79 332.1 0 95.21 7200.76 3191.77 1661.16 -3502.41 0.72 0.69 -0.21 17 -APR-02 MWD 111 01.40 92.66 332.62 94.90 7197.90 3221.77 1745.19 -3546.41 2.05 1.97 0.55 17-APR-02 MWD 11197.68 93.19 332.69 96.28 7192.99 3251 .71 1830.60 -3590.58 0.56 0.55 0.07 17-APR-02 MWD 11290.31 91.33 332.31 92.63 7189.34 3280.77 1912.69 -3633.32 2.05 -2.01 -0.41 18-APR-02 MWD 11390.08 90.64 333.06 99.77 7187.62 3311.79 2001 .32 -3679.09 1.02 -0.69 0.75 18-APR-02 MWD 11485.95 90.61 332.40 95.87 7186.58 3341 .53 2086.53 -3723.02 0.69 -0.03 -0.69 18-APR-02 MWD 11581.07 91.47 331.66 95.12 7184.85 3372.13 2170.53 -3767.62 1.19 0.90 -0.78 18-APR-02 MWD 11676.42 92.86 331 .79 95.35 7181.25 3403.26 2254.44 -3812.75 1.46 1.46 0.14 18-APR-02 MWD 11773.06 92.73 332.21 96.64 7176.54 3434.37 2339.66 -3858.07 0.45 -0.13 0.43 18-APR-02 MWD 11868.38 92.47 331.96 95.32 7172.21 3464.92 2423.81 -3902.65 0.38 -0.27 -0.26 ~ 18-APR-02 MWD 11935.22 96.26 332.03 66.84 7167.12 3486.40 2482.64 -3933.94 5.67 5.67 0.10 18-APR-02 MWD 11994.00 96.26 332.03 58.78 7160.72 3505.20 2534.24 -3961.34 0.00 0.00 0.00 Projected Data - NO SURVEY ------- ---- --- -------~-- ------ ) a Da-o,'-! 17-May-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well CD2-25 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s} RECEIVED NAY 2 :~ 2002 AlaskaOi & Gas Cons. CommÌG8tA Anchorage IWIUn ~ s . . I Ö>. 1) )EF N T VE ."'- Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-25 CD2-25 Job No. AKMW22059, Surveyed: 18 April, 2002 SURVEY REPORT 14 May, 2002 Your Ref: 501032041800 Surface Coordinates: 5974542.33 N, 371706.81 E (70020' 19.2500" N, 151002' 27.7246" W) Kelly Bushing: 52. 83ft above Mean Sea Level /-- 5r---J ...- -"'--. JI1 DRILLING sE!AVlc:es A Halliburton Company Survey Ref: svy9864 ~ -.. '1 ':.. Sperry-Sun Drilling Services . Survey Report for CD2-25 Your Ref: 501032041800 Job No. AKMW22059, Surveyed: 18 April, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -52.83 0.00 O.OON O.OOE 5974542.33 N 371706.81 E 0.00 Tolerable Gyro 114,00 0.000 0.000 61,17 114.00 O.DON a.OOE 5974542.33 N 371706.81 E 0.000 0,00 173.00 0.350 274.000 120.17 173.00 0.01 N 0.18W 5974542.35 N 371706.63 E 0.593 0.10 MWD Magnetic 299,86 0.260 279.720 247.03 299.86 0.09N 0.85W 5974542.43 N 371705.96 E 0.075 0.48 395.67 0.460 241.180 342.84 395.67 0.068 1.40 W 5974542.29 N 371705.41 E 0.317 0.61 482.56 0.610 239.330 429,72 482.55 0.46 8 2.10W 5974541.90 N 371704.70 E 0.174 0.58 568.11 0.730 219.190 515.27 568.10 1.128 2.84W 5974541.26 N 371703.95 E 0.307 0.35 660.28 1,010 226.290 607.43 660.26 2.148 3.80W 5974540.26 N 371702.98 E 0.325 -0.09 752,85 1.070 231.000 699.98 752.81 3.248 5.06W 5974539.17 N 371701.69 E 0.113 -0.47 843.81 1.490 228.290 790,92 843.75 4.568 6.60W 5974537.88 N 371700.13 E 0.466 -0.91 932.62 1.620 228.120 879.69 932.52 6.178 8.40 W 5974536.30 N 371698.31 E 0.146 -1.48 1029.84 3.640 232.490 976.81 1029.64 8.978 11.87 W 5974533.57 N 371694.79 E 2.086 -2.31 1127.47 5.570 237.920 1074,12 1126.95 13.37 8 18.35 W 5974529.27 N 371688.24 E 2.024 -3.14 1220,12 5,870 236.200 1166,31 1219.14 18.40 8 26.09 W 5974524.38 N 371680.41 E 0.373 -3.91 1316.37 5.930 237.730 1262.05 1314.88 23.79 8 34.39 W 5974519.13 N 371672.02 E 0.175 -4.75 1409,12 5.920 238.170 1354.30 1407.13 28.87 8 42.50 W 5974514.19 N 371663.82 E 0.050 -5.40 1505,59 5.990 236.710 1450.25 1503.08 34.26 8 50.94 W 5974508.95 N 371655.30 E 0.173 -6.17 .- 1601.58 6.130 240.120 1545.70 1598.53 39.56 8 59.57 W 5974503.80 N 371646.58 E 0.402 -6.78 1697.31 6.210 242.100 1640.88 1693.71 44.53 8 68.57 W 5974498.98 N 371637.48 E 0,237 -6.91 1792.25 6.420 243,710 1735.24 1788.07 49.28 8 77.87 W 5974494.39 N 371628.11 E 0.289 -6.71 1886.69 6.600 240.980 1829.08 1881.91 54.25 8 87.35 W 5974489.58 N 371618.54 E 0.379 -6.62 1981.29 5.360 241.150 1923.16 1975.99 59.02 8 95.97 W 5974484.96 N 371609.84 E 1,311 -6.76 2076.50 4.890 242.940 2017,99 2070.82 63.01 8 103.48 W 5974481.10 N 371602.26 E 0.521 -6.74 2171.76 3.180 242.320 2113.01 2165.84 66.09 8 109.44 W 5974478.12 N 371596.26 E 1.796 -6.64 2267.27 0.600 283.490 2208.46 2261.29 67.20 8 112.27 W 5974477.06 N 371593.40 E 2.886 -6.29 2325,61 0,720 32.360 2266,80 2319.63 66.82 8 112.37W 5974477.44 N 371593.31 E 1.844 -5.90 2442.22 1.910 32.180 2383,38 2436.21 64.56 8 110.95 W 5974479.68 N 371594.78 E 1.021 -4.58 2537,58 0.870 19.770 2478.71 2531.54 62.53 8 109.85 W 5974481.69 N 371595.90 E 1.129 -3.31 2631.36 0.300 328.000 2572.48 2625.31 61.658 109.74 W 5974482.56 N 371596.03 E 0.772 -2.59 2727.30 0.450 305.200 2668.42 2721.25 61.22 S 110.18W 5974483.00 N 371595.59 E 0.218 -2.00 14 May, 2002 - 15:04 Page 2 of 8 DrillQ/lp. C) t 2.00.08.005 ~..;,.'<Sperry-Sun Drilling Services . Survey Report for CD2-25 Your Ref: 501032041800 Job No. AKMW22059, Surveyed: 18 April, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) - 2823.53 0.530 329.610 2764.65 2817.48 60.62 5 110.72W 5974483.61 N 371595.07 E 0.230 -1.22 2918.80 0.520 318.210 2859,91 2912.74 59.92 5 111.23 W 5974484.32 N 371594.57 E 0.110 -0.35 3014.28 0.440 330.850 2955.39 3008.22 59.28 5 111.70 W 5974484.97 N 371594.12 E 0.139 0.43 3109.82 0.490 321 .480 3050.93 3103.76 58.64 5 112.13 W 5974485.62 N 371593.69 E 0.095 1.20 3205,19 0.510 311.520 3146.29 3199.12 58.03 5 112.70W 5974486.23 N 371593.13 E 0.093 2.00 3300.60 0.500 247.690 3241.70 3294.53 57.91 5 113.40 W 5974486.37 N 371592.43 E 0.560 2.44 3393.87 0,540 226.060 3334.97 3387.80 58.37 5 114.10 W 5974485.92 N 371591.73 E 0.213 2.36 3491.53 0.660 217.980 3432.62 3485.45 59.135 114.78 W 5974485.17 N 371591.04 E 0,150 2.01 3586.91 0.660 216.920 3527,99 3580.82 60.01 5 115.44 W 5974484.31 N 371590.36 E 0.013 1.56 3682.41 0.660 204.840 3623.49 3676.32 60.94 5 116.00 W 5974483.38 N 371589.78 E 0.145 0.99 3778.08 0.640 221.160 3719.15 3771.98 61.855 116.59 W 5974482.49 N 371589.18 E 0,194 0.47 3873.72 0.620 214.760 3814.79 3867.62 62.67 5 117.23 W 5974481.67 N 371588.52 E 0.076 0.05 3969.29 0.640 224.270 3910,35 3963.18 63.48 5 117.90W 5974480.88 N 371587.84 E 0.111 -0.35 4062.76 0.640 214.750 4003.81 4056.64 64.28 5 118.56 W 5974480.08 N 371587.16 E 0.114 -0.74 4159.54 0.710 239.340 4100.59 4153.42 65.03 5 119.39W 5974479.35 N 371586.33 E 0.305 -1.02 4255.07 0.650 218.890 4196.11 4248.94 65.76 S 120.24 W 5974478.64 N 371585.47 E 0.260 -1.25 4350.14 0.680 223.930 4291.17 4344.00 66.58 5 120.97 W 5974477.83 N 371584.72 E 0.069 -1.64 4445,77 0.790 217.440 4386.80 4439.63 67.52 5 121.76 W 5974476.91 N 371583.91 E 0.144 -2.08 ~~ 454 1.44 0.800 4535.29 68.41 5 122.72 W 5974476.03 N 371582.94 E 0.279 -2.42 236.770 4482.46 4634.02 0.770 234,960 4575.03 4627.86 69.12 5 123.77 W 5974475.34 N 371581.87 E 0.042 -2.55 4732.75 3,020 233.270 4673.70 4726.53 71.05 5 126.40 W 5974473.45 N 371579.21 E 2.279 -3.02 4828.19 6.570 231.920 4768.79 4821.62 75.93 5 132.71 W 5974468.69 N 371572.82 E 3.721 -4.33 4922.86 8.590 232,180 4862.63 4915.46 83.60 5 142.56 W 5974461.18 N 371562.84 E 2.134 -6.45 5018.49 10.510 233.600 4956.93 5009.76 93.165 155.23 W 5974451.84 N 371550.01 E 2.023 -8.91 5113.37 13.370 237.140 5049.75 5102.58 104.255 171.41 W 5974441.03 N 371533.64 E 3.110 -11.05 5208.55 15.480 240.040 5141.92 5194.75 116.565 191.66 W 5974429.06 N 371513.18 E 2,343 -12.35 5304.57 18,010 240.920 5233.86 5286.69 130.185 215.74 W 5974415.86 N 371488.88 E 2,648 -13.00 5400.16 20.540 242.610 5324.09 5376.92 145.08 5 243.55 W 5974401.44 N 371460.82 E 2.710 -13.02 5494.79 22.790 242.790 5412.03 5464.86 161.105 274.59 W 5974385.95 N 371429.50 E 2.379 - 1 2.50 5590.03 25-800 239.710 5498.83 5551.66 179.99 S 308.90 W 5974367.65 N 371394.87 E 3.428 -12.97 -------------- --"-_. -------- 14 May, 2002 - 15:04 Page 3 of 8 Dri/lQ/lf?st 2.00.08.005 ~t~:;. . Sperry-Sun Drilling Services.... Survey Report for CD2-25 Your Ref: 501032041800 Job No. AKMW22059, Surveyed: 18 April, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) .~ 5684.52 28.050 237.390 5583.07 5635.90 202.34 S 345.38 W 5974345.93 N 371358.02 E 2.628 -15.46 5781.67 31,540 237.610 5667.37 5720.20 228.27 S 386.09 W 5974320.70 N 371316.87 E 3.594 -19.12 5876.74 34.710 237.640 5746.97 5799.80 256.08 S 429.96 W 5974293.64 N 371272.53 E 3.334 -22.95 5973.25 37.580 237,300 5824.90 5877.73 286.70 S 477.94 W 5974263.85 N 371224.03 E 2.981 -27.30 6069.41 40.360 236,960 5899.66 5952.49 319.52 S 528.73 W 5974231.90 N 371172.69 E 2.900 -32.28 6162.77 42.920 236.480 5969.42 6022.25 353.56 S 580.58 W 5974198.75 N 371120.26 E 2.763 -37.83 6258.58 46.150 234.910 6037.71 6090.54 391.45 S 636.06 W 5974161.82 N 371064.14 E 3.562 -45.06 6354 .58 48.550 234.570 6102.75 6155.58 432.21 S 693.71 W 5974122.05 N 371005.81 E 2.514 -53.80 6450.60 51.870 235.630 6164.19 6217.02 474.40 S 754.22 W 5974080.90 N 370944.58 E 3.560 -62,46 6546.26 55.060 235.700 6221.13 6273.96 517.75 S 817.68 W 5974038.65 N 370880.39 E 3.335 -70.74 6641,87 57.550 237.060 6274.17 6327.00 561.78 S 883.92 W 5973995.76 N 370813.40 E 2.861 -78.31 6737.86 57.450 235.910 6325.75 6378.58 606.47 S 951.42 W 5973952.22 N 370745.15 E 1.016 -85.88 6833.64 57,330 235.970 6377.36 6430.19 651.66 S 1018.26 W 5973908.19 N 370677.55 E 0.136 -94.18 6926.92 57,150 236,000 6427.84 6480.67 695.54 S 1083.28 W 5973865.42 N 370611.79 E 0.195 -102.20 7022.4 7 57.100 236,220 6479.70 6532.53 740.29 S 1149.90 W 5973821.82 N 370544.42 E 0.200 -110.22 7117.99 56.920 235.350 6531.72 6584.55 785.34 S 1216.15 W 5973777.91 N 370477.40 E 0,787 -118.69 7151.25 56.740 235,680 6549.91 6602.74 801.10 S 1239.10 W 5973762.55 N 370454.19 E 0.991 -121.76 7182.46 56.220 236,780 6567.15 6619.98 815.57 S 1260.73 W 5973748.45 N 370432.32 E 3.378 -124.31 7212.93 55.420 239.440 6584.27 6637.10 828.88 S 1282.12 W 5973735.51 N 370410.69 E 7.684 -125.96 7247.20 54.980 242.720 6603.83 6656.66 842.49 S 1306.75 W 5973722.32 N 370385.84 E 7.963 -126.34 7280.23 54.670 245.260 6622.86 6675.69 854.33 S 1331.01 W 5973710.90 N 370361.38 E 6.355 -125.33 7305,16 54.500 247,150 6637.31 6690.14 862.53 S 1349.60 W 5973703.02 N 370342.65 E 6.216 -123,79 7340.29 54.590 249,790 6657.69 6710.52 873.03 S 1376.21 W 5973692.98 N 370315.86 E 6,127 -120.49 7374.15 55.020 252.570 6677.21 6730.04 881.95 S 1402.40 W 5973684.50 N 370289.53 E 6,828 -116.00 7403.24 55.290 254.010 6693.83 6746.66 888.81 S 1425.26 W 5973678.03 N 370266.55 E 4,167 -111.27 7437.16 55.600 256.770 6713.07 6765.90 895.86 S 1452.29 W 5973671.45 N 370239.40 E 6.763 -104.73 7470.18 56.030 259.130 6731.62 6784.45 901.56 S 1479.00 W 5973666.21 N 370212.60 E 6.054 -97.15 7500,51 56.660 261.060 6748.43 6801.26 905.90 S 1503.87 W 5973662.30 N 370187.66 E 5.689 -89.25 7536.36 56.940 263.860 6768.07 6820.90 909.83 S 1533.61 W 5973658.87 N 370157.86 E 6.582 -78.69 7566.30 57,050 266.160 6784.38 6837.21 912.02 S 1558.62 W 5973657.11 N 370132.82 E 6.453 -68.81 .--.------ .~- 14 May, 2002 - 15:04 Page 4 of 8 Dr;¡¡QUf~st 2,00.08.005 ;'::~;5, . ~: Sperry-Sun Drilling Services ,', U] Survey Report for CD2-25 Your Ref: 501032041800 Job No. AKMW22059, Surveyed: 18 April, 2002 North Slope, Alaska Kuparuk River Unit AlpineCD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7597.58 57.250 269.230 6801.35 6854.18 913.07 S 1584.87 W 5973656.51 N 370106.55 E 8.270 -57.36 7629.01 57,170 271.960 6818.37 6871.20 912.80 S 1611.28W 5973657.23 N 370080.14 E 7.306 -44.65 7661.50 57.570 273.030 6835.89 6888.72 911.61 S 1638.62 W 5973658.89 N 370052.83 E 3.034 -30.71 7691.76 58,470 276.220 6851.92 6904.75 909.53 S 1664.20 W 5973661.40 N 370027.29 E 9,423 -16.81 7725,42 59.090 278,480 6869.37 6922.20 905.85 S 1692.74 W 5973665.58 N 369998.81 E 6.030 -0.10 7756.35 59.850 281.200 6885.08 6937.91 901.29 S 1718.99 W 5973670.58 N 369972.65 E 7.963 16.30 7787.78 60.230 282.670 6900.78 6953.61 895.66 S 1745.63 W 5973676.67 N 369946.11 E 4.229 33.84 7820.29 60.790 285,420 6916.78 6969.61 888.79 S 1773.08 W 5973684.00 N 369918.78 E 7.562 52.84 7851.26 61,420 288.150 6931.75 6984.58 880.96 S 1799.03 W 5973692.28 N 369892.97 E 7.981 71.99 7882.84 62.740 290.980 6946.54 6999.37 871.62 S 1825.32 W 5973702.07 N 369866.84 E 8.953 92.63 7916.47 63.620 293.260 6961.71 7014.54 860.31 S 1853.12 W 5973713.85 N 369839.24 E 6.592 115.71 7947.32 64.350 295.140 6975.25 7028.08 848.95 S 1878.41 W 5973725.64 N 369814.15 E 5.966 137.66 7978.64 65.530 297.740 6988.51 7041.34 836.32 S 1903.80 W 5973738.71 N 369788.98 E 8,411 160.79 8009.26 67,260 298.740 7000.78 7053.61' 823.04 S 1928.52 W 5973752.41 N 369764.49 E 6.393 184. 1 5 8042.17 67.870 299.560 7013.34 7066.17 808.22 S 1955.09 W 5973767.68 N 369738.18 E 2,956 209.75 8072.28 68.870 300.410 7024.43 7077.26 794.23 S 1979.33 W 5973782.08 N 369714.18 E 4.233 233.52 8106.47 69.440 301.800 7036.60 7089.43 777.73 S 2006.69 W 5973799.05 N 369687.11 E 4.149 260.98 8137.17 69.610 301.930 7047.34 7100.17 762.54 S 2031.11 W 5973814.65 N 369662.95 E 0.681 285.90 8167.66 70.650 302,900 7057.70 7110.53 747.17 S 2055.32 W 5973830.43 N 369639.01 E 4.537 310.87 8200.43 71.620 305.390 7068.30 7121.13 729.77 S 2080.98 W 5973848.28 N 369613.65 E 7.776 338.32 8234.15 72.730 306.880 7078.62 7131.45 710.84 S 2106.90 W 5973867.65 N 369588.05 E 5,341 367.24 8263.35 73.800 308.720 7087.03 7139.86 693.70 S 2129.00 W 5973885.16 N 369566.26 E 7.060 392.78 8297.16 75.020 311.270 7096.12 7148.95 672.77 S 2153.94 W 5973906.51 N 369541.67 E 8.111 423,00 8329,19 76.290 313,170 7104.05 7156.88 651.92 S 2176.92 W 5973927.76 N 369519.06 E 6.982 452.23 8359.08 77.320 315.280 7110.88 7163.71 631.62 S 2197.77 W 5973948.41 N 369498.56 E 7.688 479,96 8393.27 78.130 316.280 7118.15 7170.98 607.68 S 2221.07 W 5973972.74 N 369475.67 E 3,712 512,06 8425.27 79.240 317,550 7124.43 7177.26 584.76 S 2242.50 W 5973996.02 N 369454.63 E 5.213 542.38 8454.22 80,320 318.500 7129.56 7182.39 563.58 S 2261.55 W 5974017.53 N 369435.94 E 4,934 570.04 8488.15 81.750 320.120 7134.85 7187.68 538.17 S 2283.40 W 5974043.31 N 369414.53 E 6.325 602.76 8520,15 82.750 321,130 7139.17 7192.00 513.66 S 2303.52 W 5974068.16 N 369394.84 E 4.421 633.86 - -------- 14 May, 2002 - 15:04 Page 50f8 Dril/QI/P-st 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-25 Your Ref: 501032041800 Job No. AKMW22059, Surveyed: 18 April, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8549.94 83.690 322.710 7142.68 7195.51 490.37 S 2321.76 W 5974091.75 N 369377.00 E 6.140 662.99 8583.23 84.120 324.410 7146.22 7199.05 463.74 S 2341.42 W 5974118.71 N 369357.80 E 5,239 695.75 8615.14 84.380 326.130 7149.41 7202.24 437.65 S 2359.51 W 5974145.11 N 369340.16 E 5.425 727.29 8644.88 84.880 327.280 7152.20 7205.03 412.90 S 2375.76 W 5974170.14 N 369324.33 E 4,201 756.78 8669.24 85.390 328.710 7154.26 7207.09 392.32 S 2388.63 W 5974190.94 N 369311.82 E 6213 780.99 8812.12 89.100 332.050 7161.13 7213.96 268.29 S 2459.14 W 5974316.15 N 369243.44 E 3.492 923.62 8906.71 90.020 332.390 7161.86 7214.69 184.61 S 2503.22 W 5974400.58 N 369200.80 E 1.037 1018.20 9003.95 90.040 333.000 7161.81 7214.64 98.20 S 2547.83 W 5974487.73 N 369157.68 E 0.628 1115.43 9099.88 90,060 333.210 7161.72 7214.55 12.65 S 2591.22 W 5974574.02 N 369115.75 E 0.220 1211.34 9194.55 89.780 333.250 7161.86 7214.69 71.87 N 2633.86 W 5974659.26 N 369074.56 E 0,299 1305,98 9289.97 89.700 333.030 7162.29 7215.12 157.00 N 2676.97 W 5974745.11 N 369032.92 E 0245 1401.37 9385.26 89.760 333.810 7162.74 7215.57 242.22 N 2719.61 W 5974831.04 N 368991.74 E 0.821 1496,63 9480.16 89.160 332.790 7163.63 7216.46 326.99 N 2762.25 W 5974916.54 N 368950.56 E 1,247 1591.49 9576.12 90.270 332.140 7164.11 7216.94 412.08 N 2806.61 W 5975002.37 N 368907.66 E 1.340 1687.44 9671.29 90.680 331.540 7163.32 7216.15 495.98 N 2851.52 W 5975087.03 N 368864.19 E 0,764 1782.61 9766.55 90.840 331.270 7162.06 7214.89 579.61 N 2897.11 W 5975171.43 N 368820.04 E 0,329 1877.86 9861.63 90.250 330.700 7161.15 7213.98 662.76 N 2943.22 W 5975255.35 N 368775.36 E 0,863 1972.92 9957.05 90,990 329.880 7160.12 7212.95 745.63 N 2990.51 W 5975339.01 N 368729.50 E 1.158 2068.30 10052.31 90.700 328.890 7158.72 7211.55 827.60 N 3039.02 W 5975421.80 N 368682.40 E 1.083 2163.46 10149.00 92.140 328.960 7156.32 7209.15 910.39 N 3088.91 W 5975505.43 N 368633.93 E 1.491 2259.99 10244.32 92.610 329.170 7152.37 7205.20 992.08 N 3137.87 W 5975587.95 N 368586.38 E 0.540 2355.12 10339.65 91.550 330.130 7148.91 7201.74 1074.29 N 3186.00 W 5975670.97 N 368539.66 E 1.500 2450.31 1043527 91.440 330.280 7146.42 7199.25 1157.24 N 3233.50 W 5975754.72 N 368493.58 E 0.194 2545,86 10530.71 89.650 332.240 7145.51 7198.34 1240.91 N 3279.38 W 5975839.17 N 368449.14 E 2.781 2641,28 10626,09 89.300 332.180 7146.38 7199.21 1325.28 N 3323.85 W 5975924.29 N 368406.12 E 0.372 2736,65 10721.59 88.940 331.820 7147.85 7200.68 1409.60 N 3368.68 W 5976009.36 N 368362.74 E 0.533 2832,14 10817.70 89,960 331.760 7148.77 7201.60 1494.28 N 3414.11 W 5976094.81 N 368318.77 E 1,063 2928,25 10911.29 90.130 332.300 7148.70 7201.53 1576.94 N 3458.00 W 5976178.21 N 368276.29 E 0.605 3021.84 11006.50 90.790 332.100 7147.93 7200.76 1661.16N 3502.41 W 5976263.17 N 368233.34 E 0.724 3117.04 11101.40 92.660 332.620 7145.08 7197.91 1745.19 N 3546.41 W 5976347.94 N 368190.78 E 2,045 3211.89 - ~-------- ---- ----------------- 14 May, 2002 - 15:04 Page 6 of 8 DrillQup.st 2.00,08.005 .5:"~::-'~-- . Sperry-Sun Drilling Services. . Survey Report for CD2-25 Your Ref: 501032041800 Job No. AKMW22059, Surveyed: 18 April, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) .- 11197.68 93.190 332.690 7140.16 7192.99 1830.60 N 3590.58 W 5976434.09 N 368148.08 E 0.555 3308.03 11290.31 91.330 332.310 7136.51 7189.34 1912.69 N 3633.31 W 5976516.91 N 368106.75 E 2,049 3400.58 11390.08 90.640 333.060 7134.80 7187.63 2001.32 N 3679.09 W 5976606.31 N 368062.50 E 1,021 3500.33 11485.95 90.610 332.400 7133.75 7186.58 2086.53 N 3723.01 W 5976692.26 N 368020.04 E 0.689 3596,18 11581.07 91.470 331.660 7132.02 7184.85 2170.53 N 3767.62 W 5976777.00 N 367976.88 E 1,193 3691.28 11676.42 92.860 331.790 7128.42 7181.25 2254.44 N 3812.75 W 5976861.67 N 367933.19 E 1.464 3786,56 11773.06 92,730 332.210 7123.71 7176.54 2339.67 N 3858.07 W 597694 7 .66 N 367889.34 E 0.454 3883.08 11868.38 92.470 331.960 7119.38 7172.21 2423.81 N 3902.65 W 5977032.55 N 367846.21 E 0.378 3978.30 11935.22 96.260 332.030 7114.30 7167.13 2482.64 N 3933.93 W 5977091.91 N 367815.93 E 5.671 4044,94 11994.00 96.260 332.030 7107.89 7160.72 2534.24 N 3961.34 W 5977143.98 N 367789.41 E 0.000 4103.37 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.085° (03-Apr-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 331.850° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11994.000., The Bottom Hole Displacement is 4702.61ft., in the Direction of 302.609° (True). ------------ 14 May, 2002 - 15:04 Page 7 of 8 DrillQuest 2,00.08.005 ~t~:t,~ . Sperry-Sun Drilling Services Survey Report for CD2-25 Your Ref: 501032041800 Job No. AKMW22059, Surveyed: 18 April, 2002 Kuparuk River Unit North Slope, Alaska Alpine CD-2 Comments .~ Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11994.00 7160.72 2534.24 N 3961.34 W Projected Survey Survey tool program for CD2-25 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 173.00 0.00 173.00 173.00 11994.00 173.00 Tolerable Gyro 7160.72 MWD Magnetic .._",~ - ---- -- - .---- - 14 May, 2002 - 15:04 Page 8 of 8 DrillQuest 2.00.08.005 Diverterless drilling on CD2-25 Ii Subject: Diverterless drilling on CD2-25 Date: Wed, 27 Mar 2002 13:55:58 -0900 From: ''Vernon T Johnson" <vjohns01 @ppco.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "Chip Alvord" <calvord@ppco.com> Tom, As discussed, Phillips Alaska is withdrawing its request to drill without a diverter on CD2-25. There are several internal requirements which must be fulfilled prior to drilling without a diverter and there is not enough time to complete the work prior to spudding CD2-25. If you have any questions, please contact me at the number below. Vern Johnson 907-265-6081 (w) 907 -265-64 72 (fax) 907 -7 48-3906 (Cell) 907 -267 -0566 (pgr) vjohnso1 @ppco.com 1 of 1 3/27/021:55 PM ~~!Æ~E ,¡,ì' ~, : f !Æ~!Æ~~~!Æ (' ALASKA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Graham Alvord Drilling Team Leader Phillips Alaska, Inc P. O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Unit CD2-25 Phillips Alaska, Inc Permit No: 202-074 Sur Loc: 1815' FNL, 1533' FEL, SEC. 2, TIIN, R4E, UM Btmhole Loc: 4312' FNL, 351' FEL, SEC. 34, TI2N, R4E, UM Dear Mr. Alvord: 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 pad 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. 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, ~~[kU~ Cammy OJehsli Taylor Chair ' BY ORDER OF THE COMMISSION , DA TED thisL7~ay of March, 2002 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. {' ¥J6/t S{2&7(OL Þ-- "'Sf;)) --0) 1 a. Type of Work Drill X Re-Entry STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b Type of Well Exploratory Service Development Gas 5. Datum Elevation (OF or KB) DF 52' 6. Property Designation Redrill Deepen Stratigraphic Test Development Oil X Single Zone X Multiple Zone 10. Field and Pool Colville River Field Alpine Oil Pool feet 2. Name of Operator Phillips Alaska, Inc. Address P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface ADL 380075,387212 7. Unit or property Name 11. Type Bond (see 20 MC 25.025) Colville River Unit Statewide 8. Well number Number CD2-25 #59-52-180 9, Approximate spud date Amount 04/04/2002 $200,000 14, Number of acres in property 15. Proposed depth (MD and TVD) 12314' 2560 7177' TVD feet 3. 4, 1815' FNL, 1533' FEL, Sec. 2, T11 N, R4E, UM At target (=7" casing point) S::.c- .2.. 2205' FNL, 3935' FEL...~?€I. 11, T11 N, R4E, UM ;fIt: At total depth 4312' FNL, 351' FEL, Sec. 34, T12N, R4E, UM 12. Distance to nearest 13, Distance to nearest well Property line CD2-42 Crosses 380075 to feet 6.6' at 400' 387212 16. To be completed for deviated wells Feet 17. Anticipated pressure (see 20 AAC 25,035(e)(2)) Kickoff depth 800' feet Maximum hole angle 90.840 Maximum surface 2544 psig At total depth (TVD) 3224 at psig 7125' 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' 306 Sx Arctic set 1 12.25" 9.625" 36# J-55 BTC 2359' 37' 37' 2396' 2389' 494 Sx Arcticset III L & 230 Sx Class G 8.5' 7' 26# L-80 BTC-M 8677' 37' 37' 8714' 7217' 136 Sx Class G N/A 4.5' 12.6# L-80 IBT-mod 7831' 32' 32' 7863' 6980' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Size Cemented True Vertical depth Structural Conductor Surface Intermediate Production liner Perforation depth: measured true vertical 20, Attachments Filing fee X Property plat Drilling fluid program X Time vs depth plot BOP Sketch Refraction analysis Diverter Sketch Seabed report Drilling program X 20 AAC 25,050 requirements X 21, I hereby certify that the foregoing is true and correct to the best of my knowledge Signed {1 1--- £ 0..( Title /~ Commission Use Only Permit Number I API number , / <"7 I Approval date '2..1 ~ I See cover letter for ..2nZ-ð 7 y 50- /rl.3 - Z o~.... 7) ".1dÎ ()~ Otherrequirements Conditions of approval Samples required Yes ~ Mud log re uired Yes (f§) Hydrogen sulfide measures Yes @ Directional survey required 6J No Required working pressure for BOPE 2M 3M 5M 10M 15M Other: ~50U~~\ ~\r\.\f'I\.~~~~ ~-\- lR.-~ Drilling Team Leader Date S IL/{ () l- Approved by Form 10-401 Rev, 7-24-89 Origidsl Signed Bv Cammy' Oechsli Commissioner by order of the commission Date'N;J1 JD~ Submit in triplicate Or'~':' ..:: L ' i III i ru'j~ ' ( ( CD2-25 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) .12-1/411 Hole /9-5/8' Casina Interval Event Risk Level ,---- - Conductor Broach Low Well Collision Low Gas Hydrates Low Running Sands and Gravel Abnormal Pressure in Surface Formations >2000' TVO Lost Circulation ,8-1/2' Hole /7' Event Abnormal Pressure in Surface Formations >2000' TVO Lost circulation Hole swabbing on trips Abnormal Reservoir Pressure Hydrogen Sulfide gas Low Low Low Casina Interval Risk Level low Low Moderate low Low - M itiq~~i~~ Strat~9Y - Monitor cellar continuously during interval. Gyro single shots as required Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries M iti~ation Strate~y BOPE drills, Keep mud weight above 10.4 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 7001 of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers ,6-1/8' Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Abnormal Reservoir Pressure Hydrogen Sulfide gas Moderate Medium .; Low Mitiqation Strateqy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to T shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 9.3 ppg. / Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers C i"G¡'iVAi. Alpine: CD2-25 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Procedure , /' Move on Doyon 19. Drill 12 %' hole to the surface casing point as per the directional plan. Run and cement 9 5/8' surface casing. / Install and test BOPE to minimum 5000 psi.'" Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 %" hole to the intermediate casing point in the Alpine Sand. (LWD tools, GR/RES/PWD) ~ / Run and cement T 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 r casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus. Pressure test casing to 3500 psi. / Run +1- 2000' 4-1/2' tbg. circulation string with tubing hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Circulate diesel freeze protect. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Set back-pressure valve and secure well. Temporarily suspend CD2-25. Rig down and move off Doyon 19. /' Move on with Doyon 19. Install BOPE and test to 5000 psi. /' Pull circulation string / Run drilling assembly. Swap fluid to oil based mud. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. / Drill 6-1/8' horizontal section to well TD. (LWD: GR/RES/PWD) Contingency' set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). I Run 4-%', 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels, sliding sleeve and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi 130 mins. Rig up slickline and shift sliding sleeve. Reverse circulate diesel freeze protect to annulus and diesel to tubing Set BPV and secure well. Move rig off. ()i1I~HlytïL (, Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-26 will be the closest well to CD2-25, 6.6' at 400' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 4.4' at 400' MD. Drillina 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 Pumpina Operations: Incidental fluids developed from drilling operations on well CD2-25 will be injected into a permitted annulus on CO2 pad or the class 2 disposal well on CD1 pad. Incidental fluids to include oil based mud using mineral oil as the base fluid. / The CD2-25 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 200O' 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 CD2-25 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 near the base of the Schrader Bluff Formation (C-40). 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 = 1 ,086 psi / Pore Pressure 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' 36 J-55 3 BTC 2,020 psi 1,717psi 3,520 psi 2.992 psi / T 26 L-80 3 BTC-Mod 5,410 psi 4.599 psi¡ 7,240 psi 6,154 ps i 0: G Nt- '\ CD2-25 DRILLING FLUID PROGRAM SPUD to Intermediate hole to T Production Hole 9-5/8' surface casing casing point' 8 Y2' Section' 6 1/8' point' 12 ~' Density 8.8' 9.6 ppg 9.6' 9.8 ppg ,/ 9.2 ppg 0/ PV 10' 25 15 -20 YP 20' 60 15' 25 18 -25 Funnel Viscosity 100' 200 Initial Gels 4' 8 NA 10 minute gels <18 9-12 API Filtrate NC' 10 cc 1 30 min 4' 12 cc/30 min (drilling) NA H PHT Fluid Loss at 160 4.0-5.5 PH 8.5' 9.0 9.0' 10.0 NA Electrical Stability +800Vts Oil Iwater ratio 80/20 Surface Hole: A standard high viscosity fresh water 1 gel spud mud is recommended for the surface interval. Keep flowline viscosity at í 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 1 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 low 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 80/20 oil/water ratio M-I Versa-Pro mineral oil based drill-in fluid. The base fluid will consist of high flash point (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. Ci/G/Nt ~ I I I i i : I ! L....i ::.:!':,:' I: H~ì.:: . ~j JI >GL>J >(3LJ l Colville River Field CD2-25 Production Well Completion Plan . 16" Conductor to 114' Updated 03/18/02 4-1/2" Camco BAL-O SSSV Nipple (3.813" ID) at 2000' TVD=200T MD Isolation Sleeve with OB-6 No-Go Lock (3.812" 00) run in profile Dual 1/4" x 0.049" sls control lines "i,'i,'!i:! 9-5/8" 36 ppf J-55 BTC .. Surface Casing @ 2396' MD I 2389' TVD cemented to surface WROP-2 SSSV (2.125"10) wi DB-6 No-Go Lock (3.812" 00) - to be installed later Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Tubing Supended with diesel to lowest GLM Completion Start thermal centralizers. 1 per joint from 4500' TVO to 2400' TVD Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple End thermal centralizers 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing Start thermal centralizers. (1 per joint) Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2" tubing joints (2) Baker CMD sliding sleeve cw 3.813" X profile 4-1/2" tubing joint (2) Baker S3 Packer 4-1/2" tubing joints (2) HES "XN" (3.725" ID)-61.9Q inc 4-1/2" 1 0' pup joint WEG Camco KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) E Dummy with 1" BK-2 Latch set 2 joints above the CMD sliding sleeve Baker 4-1/2" CMD sliding sleeve with 3.813 'X' Profile set 2 joints above 83 packer .::.~ ¡H;i!Hn~>.,~ Baker S3 Packer at +/- 7750' I:", , 'I, .....~.-:-"._._._._._._~ -/ TOC @ +/- 7935' MD (500' MD above top Alpine C) '-,~.~: Top Alpine C at 8435' MD I 7180' TVD ~'~'~"""''''~-~--'---~'-~'--~~-~~ 7" 26 ppf L-80 BTC Mod Production Casing @ 8714' MD I 7217' TVD @ 87Q MD TVD 32' 32' 2007' 2000" 2407' 2400' 3407' 3400' 4507' 4500' 5760' 5700' 7540' 6816' 7650' 6875' 7750' 6926' 7850' 6974' 7863' 6980' Well TD at 12314' MD I 7177' TVD 0 =, G¡NÞ~ . I- i i ¡ I I i i I L. liil Iii GL J ~L>J TOC @ +/- 7935' MD (500' MD above top Alpine C) { Colville River Field CD2-25 Production Well Completion Plan Formation Isolation Contingency Options - . Updated 03/18/02 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" 10), WROP-2 SSSV (2.25" 10) and DB-6 No-Go Lock (3.812" OD) with dual 1/4" x 0.049" s/s control line @ 2000' TVD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2396' MD /2389' TVD cemented to surface (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" 10) - 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 Cameo 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 (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-1 0 ECP (anchor) - Muleshoe / Entry Guide Cameo KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK-2 Latch (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Cameo KBG-2 GLM (3.909" ID) & 1" Cameo RP Shear Valve Pinned for casing side shear @ 2000 psi set 2 joints above the X landing nipple Baker 4-1/2" CMD sliding sleeve with 3.813 'X' Profile set 2 joints S3 packer i;~:>~ Baker S3 Packer set at +/- 7750' MD , . ,"""¡".............. --. Well TD at 12314' MD I 7177' TVD -...., ""'-.......... r '-......."'-.,~ :::::::::::~:::::-..~ ~:)'. 7" 26 ppf L-80 BTC Mod Production Casing @ 8714' MD / 7217' TVD @ 87Q ORf llfVAL { CD2-25 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 F ractu re Pore pressure ASP Drilling (in) Depth Gradient (Ibs. 1 (psi) (psi) MDfTVD(ft) gal) 16 114/114 10.9 52 53 95/8 2396 1 2389 14.2 1081 1525 l' 8714 17217 16.0 3266 2544 N/A 12314/7177 16.0 3248 N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 3500 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]0 Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./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 1. ASP CALCULATIONS 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) = 1081 ' (0.1 x 2389') = 842 psi 2. Drilling below surface casing (9 5/8') ASP = [(FG x 0.052)' 0.1] 0 = [(14.2 x 0.052)' 0.1] x 2389 = 1525 psi OR ASP = FPP' (0.1 x D) = 3266' (0.1 x 7211') = 2544 psi 3. Drilling below intermediate casing (1') ASP = FPP' (0.1 x D) J/ = 3266' (0.1 x 7211') = 2544 psi 0 I~J G II~\'" .~ " ~' .J:r .i~;ì i ¡ . ..~ ;, . :,~ r¡~ &. ( Alpine, CD2-25 Well Cementinq Requirements 9 5/8' Surface Casing run to 2407' MD /2400' TVD. Cement from 2407' MD to 190T (500' of fill) with Class G + Adds @ 15.8 PPG, and from 190T to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: System: Tail slurry: System: (1907'-1656') X 0.3132 fe/ft X 1.5 (50% excess) = 117.9 fe below permafrost 1656' X 0.3132 ft3/ft X 4 (300% excess) = 2074.6 fe above permafrost Total volume = 117.9 + 2074.5 = 2192.4 fe => 494 Sx @ 4.44 fe/sk ,../' 494 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 fe/sk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% S001 accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 fe/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 ft3/ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 fe/sk / 230 Sx Class G + 0.2% 0046 antifoamer, 0.3% 0065 dispersant and 1 % S001 accelerator @ 15.8 PPG yielding 1.17 fe/sk 7' Intermediate Casing run to 8714' MD /7217' TVD Cement from 8714' MO to +/- 7935' MO (minimum 500' MO above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (8714" 7935') X 0.1268 ft3/ft X 1.4 (40% excess) = 138.3 fe annular volume 80' X 0.2148 ft3/ft = 17.2 fe shoe joint volume Total volume = 138.3 + 17.2 = 155.5 fe => 136 Sx @ 1.15 fe/sk / 136 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk 1 By Weight Of mix Water, all other additives are BWOCement " ~ fG (NA ,.' ~ ¡A ,I "'1 ¡ !l- <:) ::t::J --- ~ ---- <:: ~ r-- ~'-'PHILLlPS' Phi ll_~_p_~--~!_~--~_!s a , I~~_~m_____- -i For: Vern Johnson Date plotted: 5-Mar-2002 Structure: CD#2 Well: 25 Fie I d : A I pin e Fi e I dm_~()~? t ion m_-=-nn~_()~~_?n~<:>l?m~,__~1 ask ~J Plot Reference is CD2-25 Versionl4. Coordinates are in feet reference slot #25. Vertical Dep~:~reference RKB:52'(Doyon a~~= Created by bmichael ~ fHe: CD225COM -~------------~---------- -======- -=====- ~ -- PROFILE COMMENT DATA ---- ----- Point ----- MD Inc Dir ND North East V. Sect Deg/1 00, BEGIN NUDGE 800.00 0.00 238.00 800,00 0.00 0.00 0.00 0.00: West Sak 1068.22 4.02 238.00 1068.00 -4.99 -7.98 8.68 1.50 TOC NUDGE 1266,67 7.00 238,00 1265,51 -15,09 -24.15 26,25 1.50 Permafrost 1656.06 7.00 238,00 1652,00 -40.24 -64.39 69,99 0,00, EOH/SOD NUDGE 1900.00 7,00 238.00 1894.12 -55.99 -89.60 97.40 0.00 -C-40 2229.01 2.06 238.00 2222,00 -69.76 - 11 1 .64 121.36 1.50 END NUDGE 2366.67 0.00 238.00 2359.63 -71.08 -113.75 123.65 1.50 9 5/8 Casing pt 2396.04 0.00 238.00 2389.00 -71.08 -113.75 123.65 0,00 C-30 2406.04 0.00 238.00 2399,00 -71.08 -113.75 123.65 0,00 C-20 2543.04 0.00 238.00 2536,00 -71.08 -113.75 123.65 0.00 K-3 3855.04 0.00 238.00 3848.00 -71.08 -113.75 123.65 0.00 K-2 4075.04 0.00 238.00 4068.00 - 71 .08 -113.75 123.65 0_00 K.O.P. 4700.00 0.00 238.00 4692,96 -71.08 -113.75 123,65 0.00 Albian-97 5153.28 13.60 236.54 5142,00 -100.60 -158.41 172.46 3.00 :Albian-96 6011,77 39.35 236.54 5904,00 -309.84 -475.04 518.4 7 3.00 EOB/EOT 6578.76 56.36 236.54 6283.03 -540.79 -824.48 900.35 3.00 TOH/SOT/SOB 7168.23 56.36 236,54 6609,56 -811,37 -1233.93 1347.79 0,00 -~"-. HRZ 7536.35 57.11 263.01 6814.00 -915.97 -1518.72 1645.64 6.00 K-1 7925.63 63.58 288.92 7009,00 -878,82 -1850.45 1967,16 6.00 LCU 8152.78 69.36 302.40 7100,00 -788.46 -2037.30 2137.16 6.00 Alpine D 8353.13 75.27 313.39 7161.00 -671.25 -2187.41 2266.59 6.00 Miluveach A 8369.13 75.77 314.24 7165,00 -660.53 -2198.58 2275.91 6.00 -Alpine 8434.80 77.83 317.68 7180.00 -614.57 -2243_02 2312.42 6_00 ,Target - Csg pt 87l4"07 87.00 331.85 7217,00 -389.07 -2401,82 2433.13 6.00 TOC 9098.25 90.84 331.85 7224.23 -50.45 -2582.98 2557.81 1.00 Œ¡::L=n_Ç_:;;g__EL________m_n__m____mm__m_m__Jm2~ml1"-2~__-nm__nnm___n9_Q_:8.4__mn__mnm__;2~_LßJ2n___n___nmZ1ZL_QQ_-_n____2]a1._9_~____m~4 _09 9 ,_85 -- 3E301,80 0_00 ,0 \, P hilli Alaska, Inc~ s HEEL TARGET LOCATION: FNL: 2205' FEL: 3935' SECTION 2, T11 N-R4E, UMIAT MERIDIAN ::'or': Vern Johnson Dole ploUed: 5-Mor-2002 Plol RefluClncCI i, CD2-25 Vtmlion/4. Coordinote~ orCl in tut rcfcrence ~Iot InS. Vertical Deplh~ ore refercnco RKB:S2'(Doyon 1Ii.. Crccted by bmichctll ~s file; ccl225p 5600 4800 5200 TOE/TO LOCATION: FNL: 4312' FEL: 351' SECTION 34, T12N-R4E, UMIAT MERIDIAN Well: 25 Structure: CD#2 Field: Alpine Field Location: North Slope, Alaska <- West (feet) 4400 3600 3200 2400 400 2000 1600 1200 800 4000 2800 TD -- Csg pt SURFACE LOCATION: FNL: 1815' FEL: 1533' SECTION 2, T11 N-R4E UMIAT MERIDIAN K.O.P, 9 5/8 Casing"..-::: é-3ÓO ~¡'J- 1C-20 ,(~ þ." K-~2 <)<;,; Albian-97 (§) Albian-96 r¡;1fÒ' HRZ 260.80 AZIMUTH 2433' (TO TARGET) *** PLANE OF PROPOSAL *** ~ ~ TRUE ~HI~LlP~ . 400 800 3600 - 3200 - 2800 - 2400 - 2000 - 1600 - 1200 ^ I - 800 Z 0 :¡. :J"' - 400 ,...-., -+-. () ~ - 0 '-'" - 400 - 800 - 1200 - 1600 - 2000 - 2400 JI1/GINAL 400 - 800 - 1200 - 1600 - 2000 - 2400 - ~ Q; Q) 2800 - '<- ~ ..c ~ 3200 - Q) 0 0 3600 - U +- I... Q) 4000 - > Q) :J 4400 - I... I- I V 4800 - 5200 - 5600 - 6000 - 6400 - 6800 - 7200 - 7600 Philli s Alaska, Structure: CO#2 Field: Alpine Field Well: 25 Location' North Slope, Alaska ~ - ~ 0 - ~ " BEGIN NUDGE " 1.50 ;\t~gwest Sak DLS: 1.50 deg per 100 ft EOC NUDGE TANGENT ANGLE: 7.00 DEG. Permafrost ~~OH¿SOD NUDGE " 4.50 DLS: 1.50 deg per 10° ft ; ~:~gC-40 j 1 END NUDGE I¡ 9 5/8 Cosing C-30 .. C-20 TANGENT ANGLE: 0.00 DEG.(VERTICAL) 260.80 AZIMUTH 2433' (TO TARGET) *** PLANE OF PROPOSAL *** .. K-3 .. K-2 .. K.O.P. .. 3.00 .. 6.00 9.00 DLS: 3.00 deg per 100 It ?i5?goAlbian-97 18.00 21.00 24.00 27.00 30,00 33.00 39.00Albian-96 45.00 51.00 EOB/EOT TANGENT ANGLE: 56,36 DEGREES Eg~~ðOT/SOB 56.17 HRZ 57.81 DLS: 6.00 deg per 100 It 60.95 K 1 65'14 A-I LÇU D \. 73.62asing pine '1' Miluve°'ì>,7ptne Target - Csg pt * TD - Csg pt 400 1200 1600 2000 2400 2800 3200 3600 4000 800 Vert i c a I See t ion (f e e t ) - > Azimuth 260.80 with reference 0.00 N, 0.00 E from slot #25 Inc. TANGENT ANGLE: 90.84 DEGREES ~HI~LlPS\ ¡:-or: VerT1 Johnson Dale ploH8d: 5-Mar-2002 PIal RehHMco is CD2-25 Vc:r'lion'04. Coord!notGII ere In f.at rGflllr.nce slot H25. Depth. ore roference RK8:52'(Oo)lon 19). BAl"i1-8 Created by bmic:hoe1 HUGHES fiie: cd225v C I:) J, G1~ ~ .'.\.,~. '.'" ).I;:~.:... ! 1 I ¡IV 11'~i L ( ATTACMENT 5 Pllilli P s Alaska, Inc tPHILLlP~ ~ For: Yen: J0h nso~) Dot. ploUed: ~-lkJr-20D2 Plot Q",18r8nc. i. CD2-2S V.r.ìol'll4 Structure: CD#2 Field: Alpine Field Well: 25 Location' North Slope, Alaska Coon:Moln on in lut relet1llnc:. 1101 '2~ TrIA V/lrticol Dllplhl or. rllf.rllncð RKB:~2'(Doyon Bíi. UKø: HUGIES IN'I'1i1) 460 <- West (feet) 440 360 320 260 240 200 '60 120 60 40 40 60 , 20 160 Q:; ~Q) 1300 ~ 3400 I $320~ ~OO I . 1500 . 185Q 1250 . .1450 120()- 3350 .31501150 r;-g-, .. 1400 '.. . & " " 1350 1800 .. 11:>J)3" 300 3100. . 1100@-260 """" III. 1100 <:::7 9 ;"".,~ ~OO .. 13001 . ",.1 ègéo 3050. . 1050 1350 .. - 1700 ".""..,18501600 ".i¡~oo '..1.:9.R5b 3000~,,1000 ,,1300 1650 ""'~,,"", ,,1550 1100 .. ::¡1~ \ 295q",950 - 240 1800 """"..." 1"500,, "1" 450 " . 1700 . .31 ó)(j300 90,,0" 2900 ,"'" 14",08)09- 1750 """""" .. 1350 1000"" 3050 8086'0;. .2850 " 1200",,1350 1 700 "",:~, " 1>e5¡§\50 90å' ~3000 " .. 2750 1150,. ../1300 - 200 165u """.,,1,~00 ¡Ji 1150 ,800" 2950 is .. 2650 1100.. )i',f 250 '.,,!,?,~? .. 1 00. 1 05~';850 e go~50 105q. ,..1 200 "".."1450,, , " ",,1550 950 ;t ,f750e .. "1, 000",,", ,f150 ~ "'''',,~~Oo. 800 e 950.. "1';00 \1 - 160 ""'.,,,, 1 500 135ð' .. e 80~00,*1o"50 \" 130Ù'"" 1200 1200 8 , ,/ "..,~- .. """ 1 050@800'#950305Q...:><i'5"00Y 1450 "'ö" 1100 ' / 2950 JI<.).libUJ , 20 .. 140 """..,,!OOO e.,/"'800 2750".. ~;¡,,¡)z:::¡00 - . 1350 """,..,ß.9.~..:~ 1150..80\i4Ó~00 .. 1300 e..-- 1150 " 1250 e.¡¡,og""''',',ÖO - 80 '* 11<.". 950 ~OO e 001250 1400 1550 ..1650@ 1 550 1 u50 1 15ð 1000 ~ROO " " ..* £ì - """"" 1 450 .. ,"' 8 510d 1 50,& ""''''I'"",,,,,,,,,, 1350 4950 ""."..~- 40 '..,,,,,,,,., 1250 , , 5" 350 1 ,,' . 800 3150 ".."";. 110 ').Iò "''''''''''''''''.,.1.~',?? ~ 8 1150~"" .. 1050 ,~'!I- "5650 8Ôö""""""8 ,.......,...800..,.......j'1 000 . 135 ~5800 B50@"S'000"i'Pcw'OOE-O t900 115Œ> S' urface, .' 1 Z50 ~OOO 130C).-;;;' ';'8 "BOO. 11 50 t 1 00 1450.." ¡;O;,1 '8 II, 1000 '6200 175~~q, " Be' . 800 - 40 .' 6300 1909." " '*C 1150 8800 - 205~ 000,," e .6400 4800 "~50"950" '"'' ,f1 6500 r;~5 1350 ." e ,,,.............,..,,... 800 5050 E0 - 80 . 18001150 :'50Jo 0 ' 550.t)Jé~'::::':"/8'., 'J ¡ gg~050 @ r?5' * 6600 , '200"0,, 1900... ,. "-5150 " " ,.....l;3t3tJ t 800 15~D"""#"""", ~ 150 - ~ 2100 13'bQ, 12:>0 "-JI<,..1450::.rÍ'00 00 5350 "'";""" 2200 2150 ,*,' .. 135Q,' --s'S6ð5O ",.,'1'5:5U!!!..>8cJ'b 120,,0 5500 fJJ)- '20 2250 " . ". ' A ...."650»'1800 170'1 800 pOO. ".. 1400 ,,1I"':>3~9."" t 1é¥c9° e ''¡01¡ß&01 300 - (ill 1459. 540,,1} ,".8'66 750m~~ ~ e '~,,'9Q01¡1:3~@5Q 150q, 545)¥»"H!~0 "Qlt1~8æ e .. 8(:)~.e.(,,05Ü 1200 - 160 155n 5500 "'1'~00.?tI50 80~ , ð>'~"5OD II' 11< 1950 ',5'i, J.I<i" .:2i1fz%l 00 9" 00 " ,<I 00.. 11 ~"'~~~;., 80,,0, .. ,130,,0 " 160q" 2000..,,";:" ,;,~~~ 50 1000 .. ".rfšbD ..1 {2g0'~~,;qfuo 2050",,560ij. ~,,"j(:?200 1 050 , .. ,.f250 e.."". l.e~g50 '<~" ¡,ç.. - 200 .1650 2109'5,,65, 0 ",:::::,..,... 2LOCT 110n .. , ,.....i/f "So" 0,!980Ü"',< , l' ~OO ". 9S{)" "U, 215Q....,"'. ";,'#2"2~02250 1150 i\ ,..-1350. ..115ÇE¡ '.''',," J~OO ",- . 170022.9.0."''''' 23QOir"'1. 2300 1200 . ".1'!~0¡¡'00. 900,,12,50 8 .. 1~~ 390 1100'\" c§J~,~9, "",""'" 2' 3' ?~)5~~" '"5700 "1250. , ,.,,*'(~OO '" 1.0660 l;~~,~ö,oo /~ .., 8,,0905ij) 1~" , cr.¡~900 , , J"$ , - 240 ij5;;,'"'' 24,,_~~""'t4?g. ... 5750 130~ , .' ,.,1550 .. 1 05Sg6c, ;r'$S59s,ô(l.~ ,,~2200. 145tf30o-""", "t9 - ~24~,~,"'}450.-*;" 135g. ,...1600.. 11 0~~50,,"1"3()ð' ~8{ß . 2300 "" 1850 ''li'f.. ~~""'2500 ,," 5800 140n , ,..;;<"'1650 'it 115,,0, /1,,00014"50 ~OOoe of' ~OO" . 8,OiJ'l' , ~- 260 '~.. ,,1I§850 11< ;1>'1700 . 1200 1.~6šo . 575Q ~ 100 e," :1~0 III gog900 õ " 145Q" "A~, 5801>1 ~200 e. 2450.. 1050" 1000 - .,;;" ,..'1750 .1250"</1100 ~ ",l350e.2500 ' "" 050 é§5 5900 150Q " ,,,,{¿OO ..,13~QB"Ó6'l:91150 , III. ~8950UO" 800 e255€J800,,"8bb5~1Wx9111 ~ - 320 1550' "n350 '.3000" ~.. 850 .. ,.9~250 "fu " /"",1850 ~1Jif~& '/1200" !II 5950 .. 900 iii 800' 600 )t 900, "III 1000 - 1600 , ,';" ! ,.31tHJ.. 950 , 850' ~ 80u , 950 '" ," /""""19",00 "",......r~ /,125g.2g6~P600@ 1000 .'900' 6 0.9, 0;" 1,'b¿OOO~6' - 360 1 650.. ....,Ú50"..",.;q~go / 32s0 . 1050 .. 950 . 270~ 00&50.. 105.Q .5'",- ,/ . .,...-2Ó50 / 3300 605(1 .. 1100 1000 . 8i01000 "l750 170~ ..<:1'OOO.zfóo .. 1500 /. 1150".. 2750 9@01050" 11 00 ~ 2100 - 400 // ,/'" . ~/3350 " .. . 1050", "" :tJtJjO 175t¡ , ' ..,1:.'050..,.-2150...1550 ",Dlmoo "","115001100.2800 .9~1100..,,8 /,/ ,..2'200 .345 ' . 6 O~. 1 Q¡JCll 50 2J =\(Q~O &> ~'2~/' c§> ø" @ ê!j;250 @ @ ~B W ~% -440 - 320 /<õ1 1 650 1 600 -..J.êJ . .. .1550 .1500 1450 1400 1,150 ~' ..".1,~S.°..,.1,~,~0 '.. .1,?~0 .. '*~!.?O " ,;~:o 1250 . l/1 0 c: :r "....., "'"'" CD CD ....,. '--" I V C::¡GINt - (' Phillips Alaska, Inc8 IPHILLlPS\ Structu re : CD#2 Field: Alpine Field Well: 25 Location' North Slope, Alaska: ;"0 r: V 0 m J 0 h Il SOil Dolfi ploHed: S-t.\ot-2002 PitH R""Hent:II i~ r.O;i'l-:I'5 Vltt"ionl4. I Coo'd¡nQt~!J ore in Icel rl!Ierence slot '2~. 1'nJtI Verticat Deplns o~ fl!'htH!nc.fI R(B:~2'(:>oyon 19).1 ~.. Created by ~mìcnoe I . .1~?:~;=...1.'If.':.~~~~~S.~..1 2100 2000 1900 1800 <- West (feet) 1700 1600 1500 HOO 1300 1200 1100 QJ ~ ,pOO 1000 900 800 700 600 500 ~OO 500 &j.. 3100 3000 2900 2800 2700 2600 ŒJ 28ÒO ...~.... 2500 27ÔO ~ ""<;<""." 2400 2600 25ÔO '" .......~.... 2400 '" 2300 22ÓO I c[j;;z."'.24~0 QJ "'''''',,-....2300 " 1800 - 400 """'"....2200 " 1700 200ð """""',pOO CZ¡- 19ÒO "...~.",;Z.?~O Q}; - 300 1800 1 70ð"~ - 200 210Ô 2300 ...~...."...7.2Q9....i2oO 1900 1800 2100 20ÖÜ" "';>r'õÓ' " ¡ 700 @- 100 "2'öÖ'ö"" """"""(E 19000EJ- " 7100 - 0 ,,7000 6800 6500~. @- 100 ".,~ " 2400 230r- 2500 ~ dk- 200 2509'~'~~~~;~~ 190.Ck.Z5Ó~6,:?\3.026.-00 J§>- 300 2000'266'~""2"'8':O'¡'0' 27?q,ÓOO ..,¡¡o ,.,'''' .- ,*,.¡J.1~,~'ó6'¡(2900.-...6100 ~- 400 .../"":~ijJroPOOO .-'- 1800 , ~a- """","2~~çf~~0 .- .-'" $'200 2~W?r* ,.,."., . ;¡...0t3MOO.- ""'&'i§00 - 500 ,,,,'29'~ð<t:~ðOO $'300 ~;r~o 7§> ",'/"""""/ ,.i6~00 .-.-.-'" , ,,/:J¿7ö8 - 600 .".-*.,,3°, 'ÓÔ', ,~i6!óø:ot -64¿0 , , ","'}gc)Ø~OOO " 4~C(¡C(¡, ø- ,/..,., 3800 ""."800 .- .Ji' ,'If{, 0900 "- ",.,.,'''' 3900,,"""*§B~ð" .-'-" 2.~~:ð3ÖO , " 4200 .,....- 4000 ,,!!";nOð .- øtmJ <;I 2000 ,,4300 - 700 //~(j00 ... 6500 ß 3' .1 °9...,-:r1'OO 42,004~,Q.Q;1¡"1 00 .-'- ',", '~,;¡'.?~âOO. " 4400 ~ ,...;:';-";::" 4300..':(L800 .- '-,'fti';M'~ Ji" 2100 " 4500 " . ,.<:::;>. , 440n439P""*'4200 ",,'-6600 '" j4,m88 Ji' 4600 " " ><":::::::.,/ 4500 '''''44~J2900 .- .- .- ,,)Ir;:;&d'ó ~.' 2200 " 4700 ~" ,.,,..":,."", 70g~øê£8 .- ~ 36°9w2S,p{!000 " 4800 &>::'-,/" 32004 7Ôcr,.-41;¡°SJ - 00 6900 - - ~ ~ ~ '1'6700",...,37.00' Ji' 2300 - . 4900 ~ 480Ç,,,,,,.47,p0 - - - II<- - - - - - -t800 380~'2ßO'6 3100 " bOOO 48.?,?".,II<-, 3100 3909Y'/ " ,,5100 ~~ /..,..t¡900'" 3200 40, 00",¡¡:'279P"" 3200 , 'i'5200 ~'?'tI' ,...,... ' ,," . ~ 3300 '4,1.0,.,0,,/, '", ..01<'3300 '" 5300 lj9-- 420g,/'. 280,0-' " 2500 '" 5400 4300. /' ,.....-3400 . 5500 "..; 2900,/ '" 2600 5600 4409.,./' ,1(::3500 , " 4500*,;'3000//" - '" 5700 4600/'/ ",,<3600 'i' 2700 'i' 5800 4700 /'~"'3100 ./' '" 5900 4800 /..11( ,..>I',J700 ..2800 ,,6000 490~".''''~ 320°-38~0 ,,5100 5000// ,,,,If 'i' 2900 .,., 6200 5100,/".' " 3300,,,,.-:5900 'i> 6300 5200/'" ,/' 'i> 3000 .. 6400 ~...,,/ '" 3400 .,..",,4000 .. 6500 l.Y,' 'i' 6600 ~100 ~ 3100 hÄ ~ & ~ .3300 3200 3100 3000 2900 .. 2800 Jt- 2700 2600 iii (ill Uì 0 C -I- :r ~ ....... CD CD -I- '--" I V - 800 @ - 900 '" 2000 - - 1000 .2100 - 1100 .. 2200 @ - 1200 ,(ì::¡ 2400 ¡\J - 2200'" ! - 1300 .I " 2300 J 2500 2300" / - 1400 @@ - 1500 c§> @ IIr, j ~GIN'A [11," ,~; ~ ~l ¡~'()r: Ven"": .1oh!iSCn Cole plotlea !>-lroIor-20D2 Phillips Alaska, Inc - - - (""PHILLlP~ Pled RlllhHlnc:. \. C02-25 V18t11ionl4 Structure: CD#2 Field: Alpine Field Well: 25 Location: North Slope, Alaska ~~~;:~~~~ Coordlnot81i are in filet ",llrllnte I1lot 12~. TnJI VDrtical Depth. ore nfllr8nC8 RIŒ:52'(Doyon .9- Crectad by bmichoel HUGHES ti'c: r,,12::55~j IN'!'!!:\) . ....... ,,,...,,.. 4200 <- West (feet) 4000 3BOO 3600 3400 3200 3000 2BOO 2600 2400 2200 2000 lBOO '600 1400 1200 1000 ~ T.D. & Target - 7177.00 Tvd, 2784.95 N, 4099.87 W CD \ 440Ô \ '14300 \ .. 4200 \ .. 4100 \ .. 4000 \ .. 3900 \ .. 3800 \ .. 3700 \ .. 3600 C!:; I .. 3500 III 3900 I .. 3800 II .. 3400 ..3700 \ .. 3300 Çf§-¡ .. I ... 3200 C:Sí.....5900 3600 \.. 3500 .. 3100 """""'~.,2.?00 \" 3400 .. 3000 '''''''or-..?.~.o° I I .. 3300 ~;O'Ô...".." I " 3200 2900" ,...., I .. 5100 """":" ",3100 2800 \ ,..,~~OO 3000 \ ""'''",...1700 .. I """"'".....4500 " 2900 I I """"..,...,.~300 " 2800 \ "'''''''1i',,~!00.. 2700 .. I '"'' "''Ii'.,3900 .. 2600 3300 I ''I' 3200 .,.,',.,,'.. 3700 .. 2500 \ * 3100" 3000"""'.,..",3500 " 2400 I '2900 """" ~ I" '2800 "'1i'.}.300 >1\ 2300 - ~ 5000 I ", "" """",*,,,~,~.o° '" 2200 em..,.... "";¡''''' 4800 \ 2700 '" "'..,,,,,~.900, - 600 "..,.""..... ,....,....,4600 4400 I 2600.. """"'110.,2,700 ~ ""'''' ,,,,;¡,,,,,......,.....:"~OO 40~0 2500 2406 " 2'5'08.. ,:S- 4400 "'''''''''<1<..........,,, 3800 230ð " ',> <JI1* <1<4200 4000 I""""""", ........,..,...:,~.~,? 3400 2200CjJ- 400 .. " " \ . ,,,,,,......,,,...., ....,}200 3000 3800 3600 3400"" " ,,"'''' """""" ......2,~~0 '''' 2600 Œ I 3200 3000 * " 2'400,.."",..", ~40 - 200 I 2800 2600 " "'~'i<'" ....:;: '" I 2200 , a "'- \ 24~ I I I I I \ 3200 3100 3000" "Œ- 200 I 3500 3400 "3300,, ,If, ~ 29ÔO 2800 I, '" .. ~~- 4200 4100 *, " ," 360>10 \ ~ôO ~ 4400 4300 '" II' 3900 3800 3700 'OJ'?; I....3;k - 400 II' ," 4000 I ,,7- .. \ "" 7- \ ~200 3;,9.9~~ ,~.\ , 3~9g,3'r°,ß§ÕO 2500 ~- 600 " .' ",.., 9§o.. 2600 --.c..:.p; " 3,1,00 ,3'''ÓO'' , ~~4' 00 '"",,,50~O " ...,oM' ,~":o8 2700 -- --~\,) " ",,,,,;:'''';','' 4~~R:i9ëfu3 006609.-- 240% 7- - BOO 3200",,";';><',700,Q¡," cfuOO ~ -- 3509:;.~' ,.<..~:-,3'200,.,¡¡'1iÕÓ _4~';.. - -... ~ -t700 /'<11 OO~- ~""""':':,,,':)3o.. ,~'ff0031 00 6900 6800,,,,'~0 L7 ì:}liS @ "J7- '~o :3200 & ~ r§> - 1000 j7-1Ø I , ~ C0 6300 .. 6200 .. 6100 I 52~~' 5100 b 'B - 2BOO - 2600 .. 6000 .. 5900 - 2400 .. 5800 .. 5700 " 5600 . 5500 " 5400 " 5300 " 5200 - 2200 - 2000 - lBOO " 5100 " 5000 - 1600 " 4900 * 4800 - 1400 " 3400 .. 2700 .. 2600 .. 2500 .. 2~00 " 2300 Qì - BOO ~- - 1200 QJ " 3800. 3700 ,,3600 3500 * - 1000 ^ I z 0 , ~ ~ - ro ~ '-" ~ ~, \ \ @\ \\ ~ :RIGINA~ C) ::x:J ........,.. "-"'> t7:J ~Cõ} ~.;<¿---~ ~ £...;;-""'. );::-- ~ r-- -------------.--------------..--... ..!?_Þ~!.~..!I~_~_~~!~._?_~-~}.!?:_C . .... ....... ..... .('PHlUìPs\ F G-i~.ii.~~' ¿~~¡~i;- f'ki Rt-'=<,...-..;e is tD2-25 YeBc..-4. ; ~21f...~fttnf_.-drð. ~no= ~ Deptb l7e rdererce P.Ka:.52"(~ 19).: ~ ulf#8 ~eC by bnaœI ~ --=~~---~~~~~.~~::~~._-~ Structure: CD#2 _Xi~L<:!n_:n~lE-i~~Y~)~___n Well: 25 Location : Nc:>!::!~__?_I_c:>P~-'n_~I~~~~ TRU E NORTH ~ 350 0 10 240 20 ~.~ ~ ffiJ----- ~"'-. Q) @ <§i <§> ~QJ ~~~ cW ';;:,"-~~.~, ~~.3Z0 ",'200 3'r:¡'''''' 330 ..""" 40 310 300 290 70 <:§) 280 80 .'2OÓ ø 270 260 @~~ 100 ~ 250 110 i~;:::':'~,: .. c§> ;1"30 220 ~ :;:;~~ 14Quœ . 1~ '~:.~"C- 150 "''-......., ~ @ '~~ fE)<?ð ~1SC:O 210 &> i90 i70 180 Aft depths shown ore Measured depths on Reference Well Normal Plane Travelling Cylinder - Feet (' Phillips Alaska, Inc. CD#2 25 slot #25 Alpine Field North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: CD2-25 Version#4 Our ref: prop5155 License: Date printed: 5-Mar-2002 Date created: 25-Feb-2002 Last revised: 5-Mar-2002 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 19.250,w151 2 27,723 Slot Grid coordinates are N 5974542.366, E 371706.867 Slot local coordinates are 1814.78 S 1532.01 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North 0,7'\', ~1;1i~L I \; ,¡:~ " ~ , \1' ';'," .,'Ij;~ , Wi I \;1 ~rV~~' Phillips Alaska, Inc, ( PROP05AL LI5TING pag{ CD#2,25 Your ref : CD2-25 Version#4 Alpine Field,North 5lope, .Z\laska Last revised : 5-Mar-2002 }'leasL:red I;)clin .Z\zimuth True Vert R E C TAN G U L A R G R I D COO R D 5 G E 0 G R A P H I C =>epth Degrees Degrees Depth COO R D I N ATE 5 Easting Northing COORDI N ATE 5 0.00 0.00 238.00 0.00 O.OON O,OOE 371706.87 5974542.37 n70 20 19.25 w151 2 27.72 :,00.00 0.00 238.00 500.00 O.OON O.OOE 371706.87 5974542.37 n70 20 19.25 w151 2 27.72 8Ce.00 0.00 238.00 800.00 O.OON O,OOE 371706.87 5974542.37 n70 20 19.25 w151 2 27.72 <:)JO.OO 1. 50 238,00 899.99 0.695 1.11W 371705.75 5974541.69 n70 20 19.24 w151 2 27.76 1000.00 3.00 238.00 999.91 2.775 4.44W 371702.38 5974539.67 n70 20 19.22 w151 2 27.85 1068.22 4.02 238.00 1068.00 4.995 7.98W 371698.80 5974537.51 n70 20 19.20 w151 2 27.96 noo.oo 4.50 238.00 1099.69 6,245 9.99W 371696.78 5974536.30 n70 20 19.19 w151 2 28.01 ~~OO.OO 6.00 238.00 1199.27 11 .095 17 . 75W 371688.94 5974531.58 n70 20 19.14 w151 2 28.24 .~~66.67 7.00 238.00 1265.51 15.095 24.15W 371682.47 5974527.69 n70 20 19.10 w151 2 28.43 1',00,00 7.00 238.00 1497.10 30.165 48.26W 371658.11 5974513.03 n70 20 18.95 w151 2 29.13 1656.06 7.00 238,00 1652.00 40,245 64.39W 371641.81 5974503.23 n70 20 18.85 w151 2 29.60 1900.00 7,00 238,00 1894.12 55.995 89.60W 371616.34 5974487.90 n70 20 18.70 w151 2 30.34 1966.67 6,00 238.00 1960.36 59.995 96, OOW 371609,87 5974484.01 n70 20 18.66 w151 2 30.53 2066.67 4,50 238.00 2059.93 64.845 103.76W 371602.03 5974479.30 n70 20 18.61 w151 2 30.75 2166.67 3.00 238.00 2159.72 68.305 109.31W 371596,43 5974475.93 n70 20 18.58 w151 2 30.92 2229.01 2.06 238.00 2222.00 69.765 111. 64W 371594.07 5974474.51 n70 20 18.56 w151 2 30.98 :2266,67 1. 50 238.00 2259.64 70.385 112.64W 371593,07 5974473.90 n70 20 18.56 w151 2 31. 01 2366,67 0.00 238.00 2359.63 71.085 113.75W 371591.94 5974473.23 n70 20 18.55 w151 2 31. 04 :¿396.04 0.00 238.00 2389.00 71.085 113.75W 371591.94 5974473.23 n70 20 18.55 w151 2 31.04 2406.04 0.00 238.00 2399.00 71.085 113. 75W 371591.94 5974473.23 n70 20 18.55 w151 2 31.04 2500.00 0.00 238.00 2492.96 71. 085 113. 75W 371591.94 5974473.23 n70 20 18.55 w151 2 31.04 2543.04 0.00 238.00 2536.00 71. 085 113. 75W 371591.94 5974473.23 n70 20 18.55 w151 2 31.04 :1000,00 0,00 238.00 2992.96 71,085 113. 75W 371591.94 5974473.23 n70 20 18.55 w151 2 31.04 3500,00 0.00 238.00 3492.96 71. 085 113. 75W 371591.94 5974473.23 n70 20 18.55 w151 2 31.04 3855.04 0,00 238,00 3848.00 71.085 113. 75W 371591.94 5974473.23 n70 20 18.55 w151 2 31.04 4000,00 0.00 238,00 3992.96 71.085 113. 75W 371591.94 5974473.23 n70 20 18.55 w151 2 31.04 4075.04 0,00 238,00 4068.00 71.085 113. 75W 371591.94 5974473.23 n70 20 18.55 w151 2 31.04 4'500.00 0,00 238.00 4492.96 71.085 113. 75W 371591.94 5974473.23 n70 20 18.55 w151 2 31.04 4700,00 0,00 238,00 4692.96 71.085 113. 75W 371591. 94 5974473.23 n70 20 18.55 w151 2 31.04 4800,00 3.00 236.54 4792.91 72 . 525 115.93W 371589,74 5974471.82 n70 20 18.54 w151 2 31.11 4900.00 6,00 236.54 4892.59 76.855 122.47W 371583.12 5974467.61 n70 20 18.49 w151 2 31.30 5000.00 9,00 236.54 4991.73 84.045 133.36W 371572.11 5974460.60 n70 20 18.42 w151 2 31. 62 5100,00 12,00 236.54 5090,04 94.095 148,57W 371556.74 5974450.81 n70 20 18.32 w151 2 32.06 5153,28 13.60 236.54 5142,00 100.605 158.41W 371546,79 5974444.47 n70 20 18.26 w151 2 32.35 5200.00 15.00 236.54 5187,27 106.965 168.04W 371537.06 5974438.27 n70 20 18.20 w151 2 32.63 ~)300.00 18.00 236.54 5283.14 122.615 191.73W 371513.11 5974423.02 n70 20 18.04 w151 2 33.32 ~')400.00 21.00 236.54 5377.39 141.025 219.58W 371484.96 5974405.09 n70 20 17.86 w151 2 34.14 ~:'500. 00 24.00 236.54 5469.77 162.115 251.50W 371452.68 5974384.54 n70 20 17.66 w151 2 35.07 5600.00 27,00 236.54 5560.02 185,855 287.41W 371416.38 5974361.42 n70 20 17.42 w151 2 36,12 5700.00 30.00 236.54 5647.89 212.155 327.21W 371376.14 5974335.79 n70 20 17.16 w151 2 37.28 5800.00 33.00 236.54 5733.14 240.965 370.80W 371332.08 5974307.73 n70 20 16.88 w151 2 38.55 5900,00 36.00 236.54 5815.55 272.185 418.05W 371284.31 5974277.31 n70 20 16.57 w151 2 39.93 6000,00 39,00 236.54 5894.87 305.745 468.83W 371232.97 5974244.62 n70 20 16.24 w151 2 41.41 6011,77 39.35 236.54 5904.00 309.845 475.04W 371226.70 5974240.62 n70 20 16.20 w151 2 41.60 6100,00 42.00 236.54 5970.90 341.555 523.01W 371178.20 5974209.74 n70 20 15.89 w151 2 43.00 6200,00 45,00 236.54 6043.43 379.495 580.43W 371120.15 5974172.77 n70 20 15.52 w151 2 44.67 6300,00 48.00 236.54 6112.26 419.485 640.94W 371058.98 5974133.81 n70 20 15.12 w151 2 46.44 6400,00 51.00 236.54 6177.20 461.405 704.37W 370994.86 5974092.97 n70 20 14.71 w151 2 48.29 6500,00 54.00 236.54 6238.07 505.145 770.55W 370927.95 5974050.37 n70 20 14.28 w151 2 50.22 6578,76 56.36 236.54 6283.03 540.795 824.48W 370873.43 5974015.64 n70 20 13.93 w151 2 51. 80 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #25 and TVD from RKB:52' (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 4956,30 on azimuth 304.19 degrees from wellhead. Total Dogleg for wellpath is 166.96 degrees. Vertical section is from wellhead on azimuth 260,80 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ J ~/GI^Ái.. Phillips Alaska, PROPOSAL LISTING ( Inc. Page CD#2,25 Your ref : CD2-25 Version#4 Alpine Field,North Slope, Alaska Last revised : 5-Mar-2002 :'<'2élSL::-ed Inclin Azimuth True Vert R E C TAN G U L .ì1. R G R I D COO R D S G E 0 G RAP H I C 0epth Degrees Degrees Depth COO R D I N A T E S Easting Northing COO R D I N ATE S /JOO. 00 56.36 236.54 6516.37 734.15S 1117. 07W 370577.63 5973827,26 n70 20 12.03 w151 3 00.34 ~!~68.:::3 56.36 236.54 6609.56 811.37S 1233.93W 370459.50 5973752,03 n70 20 11. 27 w151 3 03.75 ':~O().OO 56.20 238.82 6627.20 825.50S 1256.25W 370436.94 5973738.29 n70 20 11,13 w151 3 04.41 ':300.00 55.98 246.05 6683.04 863.87S 1329.74W 370362.82 5973701.17 n70 20 10,75 w151 3 06.55 71,00.00 56.17 253.28 6738.90 892.67S 1407.47W 370284.63 5973673.69 n70 20 10.47 w151 3 08.82 7~!OO.00 56.79 260,44 6794.17 911 .58S 1488.57W 370203.22 5973656.15 n70 20 10.28 w151 3 11.19 ¡~!36.35 57.11 263.01 6814.00 915.978 1518.72W 370173.01 5973652.28 n70 20 10.24 w151 3 12.07 7600.00 57.81 267.47 6848.25 920.418 1572.17W 370119.49 5973648.74 n70 20 10.19 w151 3 13.63 7700.00 59.20 274.31 6900.54 919.058 1657.35W 370034.36 5973651.54 n70 20 10.21 w151 3 16.12 7fWO.00 60,95 280.94 6950,46 907,528 1743 ,17W 369948.75 5973664.52 n70 20 10,32 w151 3 18.63 ¡CiOO.OO 63.01 287.32 6997,48 885,948 1828,69W 369863.61 5973687.54 n70 20 10.53 w151 3 21. 12 7925,63 63.58 288,92 7009.00 878,828 1850.45W 369841.98 5973695.03 n70 20 10.60 w151 3 21. 76 8000.00 65.34 293,46 7041.08 854.55S 1912.98W 369779.87 5973720,35 n70 20 10,84 w151 3 23,59 [noo.oo 67.92 299,37 7080.77 813,70S 1995,12W 369698.44 5973762.58 n70 20 11. 24 w151 3 25.99 8152.78 69.36 302,40 7100.00 788.468 2037.30W 369656.70 5973788.52 n70 20 11.49 w151 3 27,22 8200.00 70.70 305,05 7116.13 763.828 2074.20W 369620.22 5973813.78 n70 20 11.73 w151 3 28,30 8300.00 73,65 310.54 7146.76 705.488 214 9 . 36W 369546.07 5973873.38 n70 20 12.30 w151 3 30.49 8353.13 75.27 313,39 7161.00 671. 258 2187.41W 369508.61 5973908.24 n70 20 12.64 w151 3 31.60 8369,13 75.77 314.24 7165.00 660.538 2198.58W 369497.61 5973919.15 n70 20 12.75 w151 3 31.93 8400,00 76.73 315,87 7172.34 639,318 2219.77W 369476.79 5973940.73 n70 20 12.96 w151 3 32.55 8434,80 77.83 317 .68 7180.00 614.578 2243.02W 369453.97 5973965.85 n70 20 13.20 w151 3 33.23 8500,00 79.93 321.05 7192.58 566.028 2284.66W 369413.15 5974015.09 n70 20 13.68 w151 3 34.44 8600,00 83,20 326.14 7207.25 486.448 2343.32W 369355.85 5974095.65 n70 20 14.46 w151 3 36.16 8700.00 86,53 331.15 7216,20 401.428 2395.12W 369305.50 5974181.52 n70 20 15.29 w151 3 37.67 [1714.07 87,00 331. 85 7217,00 389.078 2401.82W 369299.01 5974193.98 n70 20 15,42 w151 3 37.87 f1714.09 87,00 331. 85 7217.00 389.058 2401.83W 369299.00 5974194.00 n70 20 15,42 w151 3 37.87 8814.09 88,00 331. 85 7221.36 300.978 2448.96W 369253.37 5974282.87 n70 20 16.28 w151 3 39.25 fJ914.09 89.00 331. 85 7223.98 212.828 2496.11W 369207.72 5974371.79 n70 20 17.15 w151 3 40. 63 9014.09 90.00 331. 85 7224.85 124.658 2543.28W 369162.05 5974460.74 n70 20 18.02 w151 3 42.01 9098,25 90.84 331. 85 7224.23 50.458 2582.98W 369123.62 5974535.59 n70 20 18.74 w151 3 43.17 9~)00.00 90.84 331.85 7218.33 303.76N 2772.47W 368940.15 5974892.92 n70 20 22.23 w151 3 48.71 10000.00 90.84 331. 85 7210.99 744.58N 3008.31W 368711.82 5975337,64 n70 20 26.56 w151 3 55.60 .10500.00 90.84 331. 85 7203.65 1185.41N 3244.14W 368483.49 5975782.35 n70 20 30.90 w151 4 02.50 UOOO,OO 90.84 331. 85 7196.30 1626.24N 3479.97W 368255.17 5976227.06 n70 20 35.23 w151 4 09.40 11500.00 90.84 331,85 7188.96 2067.06N 3715.81W 368026.84 5976671.78 n70 20 39.56 w151 4 16.30 12000.00 90.84 331,85 7181.62 2507.89N 3951. 64W 367798.51 5977116.49 n70 20 43.90 w151 4 23.20 12314.23 90.84 331,85 7177.00 2784.93N 4099.85W 367655.01 5977395.98 n70 20 46.62 w151 4 27.53 12314.25 90.84 331.85 7177.00 2784.95N 4099.87W 367655.00 5977396.00 n70 20 46.62 w151 4 27.53 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #25 and TVD from RKB:52' (Doyon 19) (52.00 Ft above mean sea level), Bottom hole distance is 4956.30 on azimuth 304.19 degrees from wellhead. Total Dogleg for wellpath is 166.96 degrees. Vertical section is from wellhead on azimuth 260.80 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0h ~~ ~.~j '?iJ' ~L~ Phillips Alaska, Inc. CO#2,25 Alpine Field,North 81ope, Alaska PROP08AL LI8TING pag! Your ref: C02-25 Version#4 Last revised: 5-Mar-2002 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 800.00 800.00 O.OON O.OOE BEGIN NUDGE :068.22 1068,00 4.998 7.98W West 8ak 1266.67 1265.51 15.098 24.15W EOC NUDGE 1656.06 1652.00 40.248 64.39W Permafrost 1900.00 1894.12 55.998 89.60W EOH/80D NUDGE 2229,01 2222.00 69.768 111. 64W C-40 2366.67 2359,63 71.088 113. 75W END NUDGE 2396,04 2389.00 71.088 113. 75W 9 5/8" Casing Pt 2406,04 2399.00 71.088 113.75W C-30 2543.04 2536.00 71.088 113.75W C-20 3855.04 3848.00 71.088 113.75W K-3 4075.04 4068.00 71.088 113. 75W K-2 4700.00 4692.96 71. 088 113.75W K.O.P, 5153.28 5142.00 100.608 158.41W Albian-97 6011.77 5904,00 309.848 475.04W Albian-96 6578,76 6283.03 540.798 824.48W EOB/EOT 7168.23 6609.56 811.378 1233.93W EOH/80T/80B 7536.35 6814.00 915.978 1518.72W HRZ 7925.63 7009.00 878.828 1850.45W K-1 8152.78 7100.00 788.468 2037.30W LCU 8353.13 7161.00 671,258 2187.41W Alpine D 8369,13 7165.00 660.538 2198.58W Miluveach A 8434,80 7180.00 614.578 2243.02W Alpine 8714.07 7217.00 389.078 2401.82W Target - Csg pt 8714.09 7217.00 389.058 2401.83W HEEL TGT. (2/25/2) 9098.25 7224.23 50.458 2582.98W EOC 12314,23 7177.00 2784.93N 4099.85W 'I'D - Csg pt 12314.25 7177.00 2784.95N 4099.87W TOE TGT. (2/25/2) Casing positions in string '0' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords, Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE 2396.04 2389.00 O.OOE 8714.09 7217,00 71. 088 389,068 113.75W 9 5/8" Casing 2401.83W 7" casing Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D, Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- HEEL TGT, (2/25/2) TOE TGT, (2/25/2) 369299.000,5974194.000,0.0000 7217.00 367655.000,5977396.000,0.0000 7177.00 389.058 2784.95N 2401.83W 25-Feb-2002 4099.87W 25-Feb-2002 ( i'GINA.. ~_.__.._._._---_.__..- DATE f \ ----..-.--.-- - - -"" ---.-.-.-,,'-'-'-'--- ----,,---,,_. -------- t ). 12" FLOWLINE NIPPLE I "'-.. + 0 I 0 I- 18" 150#, SLOTTED FLANGE FOR NIPPLE ALIGNMENT 1 8" I "'-.. + ~ 0 I 0 N ~ / 20"x 18" CONCENTRIC ~ REDUCER I, 21 )4" , 2M, RT J ~rJ<J1 . FMC ADAPTER -cj þ- 16" CONDUCTOR /~~~Y M«/.(V ~~ ~~~~~~~~~~» /, / /" / /" / /,,/ Â'VÂ'VÂ'V/.".//" / /, / // THIS IS A PROPRIETORY DESIGN OF DOYON DRilLING, REPRODUCTION OR USE OF DESIGN IS PERMISSIBLE ONLY IF AUTHORIZED IN WRITING BY DOYON DRllLlNC. .:JuJun PROJECT RIG 19 PROPOSED DIVERTERLESS RISER CONFIGURATION ------------.----- TITLE -.---.--- -- ._~.__.._---_._- ..-.,--- DATE 03-21-02 SCAI.E NTS CHECKED BY APPROVED BY LEA DRAWN BY DWG. NO. DWB ""-.---'---'-- REV-- 0 LEA PDRC -.----.-.- SHI. REV. DWN. APPR. NO. BY BY DESCRIPTION ----------~---_..__.._-._._---------- 0 .., '¡:G' J' ß f. ,I,~ " J æil I..! I I J, . I;¡ r"¡ I. ~ Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 22, 2002 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 I::"~ ..~. ..... .'--' ~ r - Re: Application for Permit to Drill CD2-25 .... ,-, ',' ';,f"". -,'\' " ":,\,, Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore PíððIT~., well from the Alpine CD2 drilling pad. The intended spud date for this well is~AP91 4, 2002. It is intended that Doyon Rig 19 be used to drill the well. \',,~,_.._-_.///' ("ì The well CD2-25 will be drilled to penetrate the Alpine sand horizontally. 7C.basing will then be run and cemented in place. T~oE}fig will be moved to anot~er well on the pad, and will return to CD2-25 to drill out the "tAloat equipment and 6-1/St)horizontal section. The horizontal section will be drilled with oil based mud using mineral oil as the base fluid. CD2-25 will be completed as an open hole producer. ~At the end of the work program the well will be shut in awaiting surface connection/ Note that it is planned to drill the surface hole without a diverter~ There have been 38 /. wells drilled on CD1 pad and 14 surface holes drilled on CD2 pad with no significant indication of gas or shallow gas hydrates. All of the wells on CD2 have surface casing shoes within a 1600' radius of the planned surface casing shoe of CD2-25. / 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 ACC25.035 (d)(2). 8. Directional drilling I collision avoidance information as required by 20 ACC 25.050 (b). 9. Diagram of riser setup which replaces diverter. Information pertinent to this application that is presently on file at the AOGCC is: ,......:::::"O'.~.) 1. Diagrams of the BOP equipmen(divertel/équipment and choke manifold layout as required by 20 ACC 25.035 (a) a~-~Ð-}'~ 2. A description of the drilling fluids handling system. ( If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~rel~~ ~¿~~ Vern Johnson Drilling Engineer Attachments cc: CD2-25 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin e-mail : ATO 1530 ATO 868 ATO 848 ATO 844 Anadarko - Houston Kuukpik Corporation Tommy_Thompson@anadarko.com CHECK 1 STANDARD LEITER DEVELOPMENT v DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ( ( TRANSMIT AL LEITER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITIAL LETTER WELL NAME C! C/t 2, - 2 S CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) PD..,OT HOLE (PH) . ANNULAR DISPOSAL , L--> NO ANNULAR DISPOSAL ~. ANNULAR DISPOSAL THIS WELL' "CLUE" Tbe permit is for a new wellbore segment of exisüng weD ~ Permit No, ,API No. . " Production should continue to be reported as a function of tbe original API number stated above. . In accordance with 2,0 MC 25.005(1), all r~ords, data and logs acquired for tbe pilot bole mUlt be clearly , differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for wel. (n8:me on permit). Annular disposal has ~ot been requested. . . Annular Disposal, of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated. '. . ANNULU~ /. ' ~YES+ SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed Is tbe approved application for permit to drill the above referenced well. Tbe permit is approved .sùbJect to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuan'ce of a conservation order approving a spacing exception. {Company Name) will assume tbe liability of any protest to tbe spacing exception tbat may occur. ( { DC)- 1\~3~,~~2 ,?;,~3~~~ '1~:;O:1S. ~~c~~r~f~~::'=:l '"9 ....... ... ~., '"-'''.'''''''''~-''''.'-''''''''' ~""~"""'.'.M...,.... """"'-'-.' :::l?:!frllœbJ~:S:::\/ ,«t.ÄS:KA:INC .... :ÄLp:If\IE :ÒI~BdÁSEMeNi. ÄCCOÚNT ... ..:.. ". ~h~~~~~~~4~$~!.9~~.~O;ß ..... ..:ÞAv.:. .:::::~+A~.~.dÞ<ÂL~~KA .: :9~D~~~:qF~>: ,.,::~:~~'~<7TH.¥V~N1J~rsÙ't~10 0 :.,'",' 1 :~28:8 08;<2.002 :~~~:::::.::~Òì~::Apif:ER9Q ö~:Y$\ .~*~ . . " ... . " , . :: e(x ACr4Y :*~w** ** *#~ 100.. .. ÞOl:þJfs$::~tfiDOQ> c~iJ/rs~* * * * * * **1 PO.OO .. . .:".:i'~::. ...... 'BANK =:ONE. :.. -- BANK ONE,NA - 0710 .PHipØ9!:', IL /. ..:...:.:~:~.:.1~.:~;:~~g~¡':.:Íru~.~..::.:!:o~~~ny::. . ~~~RÁ$¡~¡~:tM:~;~ :~~~;It .ti....:........ . Q-. ............'..... è~4~ 'IX Ú .. C~b.. WELL PERMIT CHECKLIST COMPANY I1JÏ/I;o.~ WELL NAMEC/) - ..2. - ¿_< FIELD & POOL /20 /' O~ INIT CLASS ,/} ,..~.... / - ð! J ADMINISTRATION 1. Permittee 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. . . . . . . . AUR _Df, .~'Z 12. Permit can be issued without administrative approval.. . . . . £ <117~ 6 i... 13. Can permit be approved before 15-day wait.. . . . . . . . . . ENGINEERING 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. . . . . . . . . . . . . . . . ~APP.B 1 D:tT~/ 26. BOPE press rating appropriate; testto 5000 psig. Gf'\ ;t2iÞ,Ol. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . YiJ 9IJ/J ~/ 28. Work will occur without operation shutdown. . . . . . . . . . . ~-fV( (~-o').-.29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . AJER - gAT9 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . ¡(ß/- ~~ ~ 34. Contact name/phone for weekly progress reports [exploratory 0 ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . APPR DATE (B) will not contaminate freshwater; or cause drilling waste. .. //J / ;¡!. to surface; IV L. r ~ 2-; (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 MC 25.252 or 20 MC 25.412. , Y) N GEOLOGY: ENGIW=~~~GA: UIC/Annular: COMMISSIONV RP~ TE~l COT SFD- WGA t¡J6/r DTS{)o/-¿10~ JMH. G: \geology\templates \checklist. doc PROGRAM: Exp - Dev.xRedrll - Serv - Wellbore seg - Ann. disposal para req - GEOLAREA %7C> UNIT# 0 JD.3~~ ON/OFF SHORE ~ ~~ Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N '\!)N (j) N ("If @ illf' f\f P . $ ~ Akt,.~ Þ -U(6<' ~f 2t7N 10 N ~oy~ Iq . ~ ~t 1<-" tc"'¡pf h<' "'"" L t" (p' €J </00' tit () r"--. . ~Y N D~~ev& we!{ \La,.,- r-uj lA.R~t:t4. ~ ~~~~ ~"<t,,,",-~~ ~/;;) ~ i ~ 'Ff "ffúCJC t; ~, /11 c. P = 1./N<I f (A'. ÝÞlwf C s'j td ~ '<;,1> CD I' ÍA. " y&J Y N ",. Y N //,¡:I\ N y] Y N ~N Y N ' ( ( Commentsllnstructions: ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simp\rty finding information, infonnation of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. ) ) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Oct 01 07:25:27 2002 Reel Header Service name......... ... .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02/10/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ........... . UNKNOWN Continuation Number.... ..01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments....... ......... .STS LIS Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22059 M. HANIK D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services CD2-25 501032041800 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 01-0CT-02 MWD RUN 3 AK-MW-22059 M. HANIK D. BURLEY MWD RUN 4 AK-MW-22059 M. HANIK D. BURLEY 2 llN 4E 1815 1533 52.83 15.90 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 2381.0 6.125 7.000 8723.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. aoa-Ole¡ 1115 -, ) ) 4. MWD RUNS 2, 3, AND 4 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). RUNS 3 & 4 ALSO INCLUDED DRILL STRING DYNAMICS SENSOR (DDS) . 5. DATA FOR THE FOLLOWING MWD RUN 3 INTERVALS WERE ACQUIRED WHILST RIH FOR MWD RUN 4: 8930'MD-9533'MD; 10186'MD-10275'MD; AND 10940'MD-11314'MD. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER MEG KREMER (PPCO) DISCUSSION OF REQUIREMENTS 9/26/01. MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 2, 3, AND 4 REPRESENT WELL CD2-25 WITH API#: 50-103-220418-00. THIS WELL REACHED A TOTAL DEPTH (TO) OF 11994'MD/7161'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/01 Maximum Physical Record. .65535 File Type... ........... ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2360.0 2360.0 2360.0 2360.0 2360.0 2360.0 2391.5 STOP DEPTH 11957.5 11957.5 11957.5 11957.5 11957.5 11950.5 11994.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD BIT RUN NO MERGE TOP 2 2360.0 MERGE BASE 8732.0 ) ) MWD MWD $ 3 4 8732.0 11351. 0 11351. 0 11994.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..... .............0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units..... ..... .Feet Data Reference Point............. .Undefined Frame Spacing... ................. .60 .1IN Max frames per record............ .Undefined Absent value...................... -999 Depth units.. . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2360 11994.5 7177.25 19270 2360 11994.5 ROP MWD FT/H 0.28 1442.73 137.652 19207 2391.5 11994.5 GR MWD API 28.7 453.76 94.5105 19182 2360 11950.5 RPX MWD OHMM 0.32 2000 10.2855 19196 2360 11957.5 RPS MWD OHMM 0.27 2000 10.2236 19196 2360 11957.5 RPM MWD OHMM 0.24 2000 12.9671 19196 2360 11957.5 RPD MWD OHMM 0.14 2000 16.9368 19196 2360 11957.5 FET MWD HOUR 0.18 61.79 6.12515 19196 2360 11957.5 First Reading For Entire File......... .2360 Last Reading For Entire File......... ..11994.5 File Trailer Service name......... ... .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/01 Maximum Physical Record..65535 File Type..... ....... ....LO Next File Name...... .... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .02/10/01 Maximum Physical Record. .65535 File Type....... ........ .LO Previous File Name...... .STSLIB.OOl Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 2 header data for each bit run in separate files. 2 .5000 ') # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR FET ROP $ START DEPTH 2360.0 2360.0 2360.0 2360.0 2360.0 2360.0 2391.5 STOP DEPTH 8692.0 8692.0 8692.0 8692.0 8699.5 8692.0 8732.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Oata Record Type.............. ....0 Data Specification Block Type.....O Logging Direction........... ..... . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing..... ........... .... .60 .1IN Max frames per record..... ...... ..Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') 12-APR-02 Insite 66.16 Memory 8732.0 2391.0 8732.0 .3 85.4 TOOL NUMBER PB02473HWRG6 PB02473HWRG6 8.500 2381.0 LSND 9.70 40.0 8.7 500 5.0 3.500 1. 690 4.000 3.500 66.0 143.6 66.0 66.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 ) RPX RPS RPM RPD FET MWD020 MWD020 MWD020 MWD020 MWD020 OHMM OHMM OHMM OHMM HOUR 4 4 4 4 4 ) 1 1 1 1 1 12 16 20 24 28 4 5 6 7 8 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2360 8732 5546 12745 2360 8732 ROP MWD020 FT/H 1. 44 389.5 152.205 12682 2391.5 8732 GR MWD020 API 45.1 453.76 115.428 12680 2360 8699.5 RPX MWD020 OHMM 0.32 2000 5.41046 12665 2360 8692 RPS MWD020 OHMM 0.27 2000 5.93087 12665 2360 8692 RPM MWD020 OHMM 0.24 2000 7.80473 12665 2360 8692 RPD MWD020 OHMM 0.14 2000 9.79389 12665 2360 8692 FET MWD020 HOUR 0.18 48.39 0.791537 12665 2360 8692 First Reading For Entire File. ........ .2360 Last Reading For Entire File.. ........ .8732 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/01 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name.... ...... .STSLIB.003 Physical EOF File Header . Service name........ .... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/01 Maximum Physical Record. .65535 File Type........... .... .LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 8692.5 8692.5 8692.5 8692.5 8692.5 8700.0 8732.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG STOP DEPTH 11314.0 11314.0 11314.0 11314.0 11314.0 11306.0 11351.0 17-APR-02 Insite 66.37 Memory 11351. 0 8732.0 11351. 0 MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............ .... ..0 Data Specification Block Type.....O Logging Direction........... ..... . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.................... ..-999 Depth Units....................... Datum Specification Block sub-type...O 88.9 93.2 TOOL NUMBER PBOO082GRV4 PBOO082GRV4 6.125 8721.0 Oil Based 8.50 71. 0 27500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR Min 8692.5 0.28 28.7 2.85 4.84 4.85 9.94 0.25 Max 11351 251. 89 70.99 2000 878.09 2000 2000 61.79 First Reading For Entire File........ ..8692.5 Last Reading For Entire File.... ..... ..11351 Mean 10021.8 112.309 53.7683 19.0094 17.9238 23.4217 32.9437 19.9932 Nsam 5318 5238 5213 5244 5244 5244 5244 5244 ) 156.2 First Reading 8692.5 8732.5 8700 8692.5 8692.5 8692.5 8692.5 8692.5 Last Reading 11351 11351 11306 11314 11314 11314 11314 11314 ) File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .02/10/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 11306.5 11314.5 11314.5 11314.5 11314.5 11314.5 11351.5 STOP DEPTH 11950.5 11957.5 11957.5 11957.5 11957.5 11957.5 11994.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 18-APR-02 Insite 66.37 Memory 11994.0 11351.0 11994.0 90.6 96.3 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PBOO088HWM4 PBOO088HWM4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 8721.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: Oil Based 8.50 71. 0 34000 161.2 ) ) MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ...... .....0 Data Specification Block Type.....O Logging Direction.. ... ........... . Down Optical log depth units.......... .Feet Data Reference Point...... .... ....Undefined Frame Spacing............. .... ....60 .1IN Max frames per record.. ...... .....Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11306.5 11994.5 11650.5 1377 11306.5 11994.5 ROP MWD040 FT/H 0.72 1442.73 97.4031 1287 11351.5 11994.5 GR MWD040 API 37.9 116.87 53.5096 1289 11306.5 11950.5 RPX MWD040 OHMM 3.42 26.68 22.7134 1287 11314.5 11957.5 RPS MWD040 OHMM 3.5 24.34 21.0917 1287 11314.5 11957.5 RPM MWD040 OHMM 3.91 23.9 21.1705 1287 11314.5 11957.5 RPD MWD040 OHMM 5.04 24.92 22.0069 1287 11314.5 11957.5 FET MWD040 HOUR 0.31 25.48 2.10518 1287 11314.5 11957.5 First Reading For Entire File... ...... .11306.5 Last Reading For Entire File.......... .11994.5 File Trailer Service name... ........ ..STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/10/01 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name...... ......... . UNKNOWN Continuation Number..... .01 Next Tape Name......... ..UNKNOWN Comments. ...,..... ....,. .STS LIS Writing Library. Scientific Technical Services ) Reel Trailer Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name... ............ . UNKNOWN Continuation Number.... ..01 Next Reel Name......... ..UNKNOWN Comments............... ..STS LIS Physical EOF Physical EOF End Of LIS File ') Writing Library. Scientific Technical Services