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Home My WebLink About199-044Originated: 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!% T41299T41299T41299T41300T41301T41302T41303CD1-4050-103-20298-00-00199044Colville RiverWLRBP-MechCutterFINAL FIELD24-Jan-26Gavin GluyasDigitally signed by Gavin Gluyas Date: 2026.02.02 09:10:17 -09'00' Originated: Delivered to:22-Jul-24 Alaska Oil & Gas Conservation Commiss 22Jul24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 3S-03 50-103-20458-00-00 203-091 Kuparuk River WL Perf FINAL FIELD 27-Jun-24 CD2-45 50-103-20395-00-00 201-212 Colville River WL Patch FINAL FIELD 8-Jul-24 CD1-40 50-103-20298-00-00 199-044 Colville River WL LDL FINAL FIELD 10-Jul-24 CD4-24 50-103-20602-00-00 209-097 Colville River WL LDL FINAL FIELD 11-Jul-24 CD4-93A 50-103-20690-01-00 215-026 Colville River WL LDL FINAL FIELD 13-Jul-24 2W-01 50-029-21273-00-00 185-010 Kuparuk River WL LDL FINAL FIELD 16-Jul-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39255 T39256 T39257 T39258 T39259 T39260 CD1-40 50-103-20298-00-00 199-044 Colville River WL LDL FINAL FIELD 10-Jul-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.22 10:48:54 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-08-08_22041_CRU_CD1-40_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22041 CRU CD1-40 50-103-20298-00 Caliper Survey w/ Log Data 08-Aug-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 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:199-044 T36881 Kayla Junke Digitally signed by Kayla Junke Date: 2022.08.17 09:15:29 -08'00' STATE OF ALASKA A KA OIL AND GAS CONSERVATION CONOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment ❑., 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 199-044 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20298-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25559, 372097 CRU CD1-40 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 15438 feet Plugs measured None feet true vertical 7184 feet Junk measured None feet Effective Depth measured 15438 feet Packer measured 10334 feet true vertical 7184 feet true vertical 6999 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 16" 121' 121' Surface 2940' 9.625" 2976' 2392' p� Intermediate 'CAMEL.) )4 li 1 ) I j Production 12008' 7 12043' 7157' Liner r Perforation depth Measured Depth: Perforations 10650'- 10885'and Open Hole 12043'- 15348' k"J ED True Vertical Depth: Perforations 7120'-7190'and Open Hole 7157'-7184' MAR 0 2 2016 Tubing(size,grade,measured and true vertical depth) 4.5", L-80, 10392' MD, 7025'TVD AOGCC Packers and SSSV(type,measured and true vertical depth) Packer: Baker S-3, 10334' MD, 6999'TVD SSSV: WRDP-2, 1882' MD, 1703'ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10660'- 10885'and 12043'- 15438' 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: 799 537 910 1397 166 Subsequent to operation: 772 563 960 1400 170 14.Attachments(required per 20 AAC 25.070,25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil E 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@cop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature -,�44 Phone 265-6579 Date 1/i 114, Vr--. A04 / Form 10-404 Revised 5/2015 3)11 / i f, RBDMS 1,k, MAR 0 2 2016 Submit Original Only • • CD1-40 Scale Inhibition Treatment 2/3/16—2/4/16 Hybrid Scale Inhibitor Squeeze Job pumped from 07:30 on 2/3/16 to 04:00 on 2/4/16. LRS= Little Red Services - Initial pressure TBG/IA/OA- 300/1300/780 - LRS pumped 40 bbls Diesel/WAW5206/M209 preflush at.5 bpm,TBG/IA/OA- 650/1050/750 - LRS pumped 60 bbls Seawater/SCW3001 scale inhibitor main treatment at.5 bpm,TBG/IA/OA- 500/1100/670 - LRS pumped 500 bbls dead crude overflush at .5 bpm,TBG/IA/OA—0/1550/660 Interval treated (MD): Perforations 10650' - 10885' and Open Hole 12043' - 15348' t]t. ..,' WNS PROD • CD1-40 ConocoPhillips '-'S Well Attributes Max Angle&MD TD Alaska.10C, r Wellbore API/UWI Field Name Wellbore Status Intl(°) MD 10(0) Act Blm(ft513) .,y,o, ,,,,,c „ 501032029800 ALPINE PROD 95.35 11297.77 15,438.0 --. Comment P23(ppm) Date Annotation End Date KB-Grd(tt) `RID Release Date CD1-40,3/123167'.49:00 AM SSSV:WRDP Last WO: 42.66 7/16/2000 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,623.0 3/14/2013 Rev Reason:PULLED PLUG lehallf 3/1/2016 v HANGER;32.0 II ..-= Casing Strings _..I.,- ', - Casing Description OD(In) ID(In) Top(ftKO) Set Depth(ftKB) Set Depth)TVD)...WHLen)I...Grade Top Thread ! CONDUCTOR 16 15.062 37.0 121.0 121.0 62.58 H-40 WELDED ,_ .. Casing Description OD(In) ID(In) Top(ORB) Set Depth(ORB) Set Depth(TVD)...WULen(I...Grade Top Thread ISURFACE 95/8 8.921 36.6 2,976.2 2,392.2 36.00 J-55 BTC-MOD Casing Description OD(in) ID(In) Top(11613) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread 1 PRODUCTION 7 6.276 34.7 12.042.8 7,157.1 26.00 L-80 BTCM Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread - *lb OPEN HOLE 6 1/8 12.042.0 15.438.0 CONDUCTOR,3.0-121 0 . Tubing Strings Tubing Description String Ma ID(In) Top(ftKB) Set Depth(R-..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING Completion Details 4112 3.958 32.0 10.391.6 7,025.2 (2.60 L-80 IBTM Nominal ID ITop(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (In) I 32.0 32.0 0.00 HANGER FMC TUBING HANGER 4.500 WRDP;1,8131.91,881.9 1,703.1 48.75 NIPPLE CAMCO BAL-0 SSSV 3.812 NIPPLE;1,881.9 _ 10,279.2 6,971.9 59.27 NIPPLE HES X NIPPLE 3.813 10,334.4 6,999.0 61.55 PACKER BAKER 5-3 PACKER 3.875 10,379.4 7,019.8 63.68 NIPPLE HESXN NIPPLE 3.725 t 10,390.3 7,024.6 64.19 WLEG WIRELINE GUIDE 3.958 k Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(19 00) )ftKB) 1') Des Com Run Date ID(in) SURFACE;36.8-2,976.2-A 1.881.9 1,703.1 48.75 WRDP 3.81 DB LOCK&WRDP-2(SN:HVS-265) 7/1912015 2.125 - Perforations&Slots Shot GAS LIFT;4.603.1 Dens Top(TVD) situ(TVD) (shots// Top(MB) &m(ftKB) (ftKB) I1169) Zone Date 1) Type Com 10,650.0 10,670.0 7,120.3 7,127.1 2/18/2001 6.0 IPERF 3 3/8"PJ/HC,60 deg ph 10,755.0 10,770.0 7,155,2 7,159.9 2/1772001 6.0 IPERF 3 3/8"PJ/HC,60 deg ph cns LIFT 2.4055 10.780.0 10,790.0 7,163.0 7,166.0 2/16/2001 6.0 IPERF 33/8"PJ/HC,60 deg ph 10.795.0 10,815.0 7,167.5 7,173.2 2/15/2001 6.0 IPERF 33/8"PJ/HC,60 deg ph - 10.830.0 10,850.0 7,177.2 7,182.1 2/14/2001 6.0 IPERF 3 3/8"PJ/HC,60 deg ph GAS LIFT;10.216.2 10.865.0 10,885.0 7,185.6 7,190.1 2/13/2001 6.0 IPERF 3 3/8"PJ/HC,60 deg ph Stimulations&Treatments Min Top Max Btm Depth Depth Top)TVD( Btm(TVD( NIPPLE 10,279.2 (ttKB) (ftKB) (ft613) (ftKB) Type Date Com 10.650.0 10,885.0 7,120.3 7,190.1 C-SAND FRAC 2/10/2006 325.000#16/20 Sllaca and 3000 bbls of YF125ST 10,650.0 10,885.0 7,120.3 7,190.1 C-SAND 4/4/2008 PUMPED C-SAND FRAC 447171#16/30 BADGER REFRAC SAND w/10 PPA ON FORMATION I 10.650.0 10,885.0 7,120.3 7,190.1 C-SAND 3/5/2013 Performed C-sand single-stage refrac placing PACKER;10.334.3 REFRAC 362.320-lbs(100%design)CarboLite 16/20 proppant in 3261-bbl total slurry volume.Treated 0-7-ppa stages at 30-bpm and 3500-psi avg TP. Mandrel Inserts St NIPPLE;10,379.4 atl on Top(TVD) Valve Latch Pont Size TRO Run N Top(ftKB) (ftKB) Make Model 00(In) Sery Type Type (In) (psl) Run Date Com 1 4,603.1 3,383.6 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,043.0 8/19/2014 WLEG'10,390.3 Ill 2 7,405.5 5,182.1 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,950.0 3/17/2013 3 10,218.2 6,938.9 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 7/19/2015 Notes:General&Safety End Date Annotation r- - 8/19/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematgc9.0 IPERF;10,650.0-10,670.0 IPERF;10,755.0-10.770.0 C-SAND REFRAC;10,650.0A _ -- C-SAND REFRAC;10,690,0 C-SAND FRAC;10.650.0 - ' ` ERF 10,780.0-10,790.0 IP IPERF;10,795.0-10,615.0 IPERF;10,830.0-10.850.0 IPERF;10,665 0-10.665.0 re-611'16:. PRODUCTION;34.6-12,042.8 i. 4:*Nati OPEN HOLE;12,S42.0-15,438.0 EA�e}`Ft STATE OF ALASKA AL A OIL AND GAS CONSERVATION CON :SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed SuspendFt Perforate r r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Scale Inhibitor Treatment .17 2.Operator Name. 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 199-044 3.Address: 6.API Number Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20298-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25559,372097 CRU CD1-40 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 15438 feet Plugs(measured) 10960 true vertical 7184 feet Junk(measured) none Effective Depth measured 15438 feet Packer(measured) 10334 true vertical 7184 feet (true vertical) 6999 Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 16 121 121 SURFACE 2940 9.625 2976 2392 PRODUCTION 12008 7 12043 y J. 7157 RECEIVED EII1t, , Iv s`NNN I U L 2 8 201r AOGCC Perforation depth: Measured depth: 10650-10670, 10755-10770, 10780-10790, 10795-10815, 10830-10850, 10865-10885 True Vertical Depth. 7120-7127, 7155-7160, 7163-7166, 7168-7173, 7177-7182, 7186-7190 Tubing(size,grade,MD,and TVD) 4.5, L-80, 10392 MD, 7025 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER S-3 PACKER @ 10334 MD and 6999 TVD NIPPLE-CAMCO BAL-0 SSSV @ 1882 MD and 1703 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10650'-10885' Treatment descriptions including volumes used and final pressure: 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 441 984 1108 1005 169 Subsequent to operation 569 1188 1043 958 159 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15 Well Class after work Daily Report of Well OperationsI7 Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil Pi Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt none Contact Kerry Freedman (aj 265-6579 Email Kerry.C.Freedmanra�conocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature n Phone 265-6579 Date— d...1.1 ate— d 28)tot L V3/1RBDMS..A- AUG - 2 2015 , /— Form 10-404 Revised 5/2015 Submit Original Only CD1-40 Scale Inhibition Treatment 6/28/15 Aqueous Scale Inhibitor Squeeze Job pumped 6/28/15 from 10:00 to 14:40. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA-143/993/600 - ACF pumped 30 bbls produced water tubing flush at 2 bpm,TBG/IA/OA-29/971/600 - LRS pumped 12.2 bbls WAW5206 at .2 bpm while ACF pumped 110 bbls seawater at 3 bpm, TBG/IA/OA-0/1107/600 - LRS pumped 18.3 bbls SCW3001 scale inhibitor at .2 bpm while ACF pumped 104 bbls produced water at 1-2 bpm,TBG/IA/OA—1125/2105/600 - ACF pumped 50 bbls produced water overflush at 1- 2 bpm,TBG/IA/OA-941/1890/600 - Discontinue pumping to diagnose potential TBGxIA communication Interval treated: 10,650-10,885' WNS PROD CD1-40 ConocoPhillips 4 Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UM Field Name Wellbore Status ncl(°) MD(kKB) Act Btm(ftKB) CdlomrleTipa '' 501032029800 ALPINE PROD 95.35 11,297.77 15,438.0 ... .. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CDt-40,7232015121:36 PM SSSV:WRDP Last WO: 4266 7/16/2000 Vertical schematic(actuap Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,623.0 3/14/2013 Rev Reason. RESET WRDP,GLV C/0 lehallf 7/23/2015 Ile HANGER,32.0- _ Casing Strings ----- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(1808) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 37.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID lin) Top(kKB) Set Depth(kKB) Set Depth(ND)... Wt/Len p...Grade Top Thread i/// SURFACE 95/8 8.921 36.6 2,976.2 2,3922 36.00 J-55 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 34.7 12,042.8 7,157.1 26.00 L-80 BTCM -" -_E11(i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread OPEN HOLE 6 1/8 12,042.0 15,438.0 CONDUCTOR;37.0-121.0 Tubing Strings Tubing Description String Ma...ID(in) Top(kKB) Set Depth(ft..Set Depth(ND)(...Wt(lbkt) Grade Top Connection s TUBING 41/2 3.958 32.0 10,391.61 7,025.2 12.60 L-80 IBTM Completion Details ,!:: -- j Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) WRDP;1,881.9 P --- 32.0 32.0 0.00 HANGER FMC TUBING HANGER 4.500 NIPPLE;1'881'91 , _; 1 881.9 1,703 .1 48.75 NIPPLE CAMCO BAL-O SSSV 3.812 T 10,279.2 6,971.9 59.27 NIPPLE HES X NIPPLE 3.813 10,334.4 6,999.0 61.55 PACKER BAKER S-3 PACKER 3.875 10,379.4 7,019.8 63.68 NIPPLE HES XN NIPPLE 3.725 10,390.3 7,024.6 64.19 WLEG WIRELINE GUIDE 3.958 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SURFACE;36.6-2,976.2- Top(TVD) Top Ind Top(ftKB) (ftKB) r) Des Com Run Date ID 5n) 1,881.9 1,703.1 48.75 WRDP 3.81 DB LOCK 8 WRDP-2(SN:HVS-265) 7/19/2015 2.125 10,960.0 7,204.9 80.14 PLUG IBP SET w/SAND PLUG ON TOP 3/29/2008 3/29/2008 GAS LIFT;4,603.1 Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots// I Top(ftKB) Btm(kKB) (ftKB) (ftKB) Zone Date t) Type Corn 10,650.0 10,670.0 7,120.3 7,127.1 2/18/2001 6.0 IPERF 3 3/8"PJ/HC,60 deg ph GAS LIFT,7,405.5 ': rirr 10,755.0 10,770.0 7,155.2 7,159.9 2/17/2001 6.0 IPERF 3 3/8"PJ/HC,60 deg ph h10,780.0 10,790.0 7,163.0 7,166.0 2/16/2001 6.0 IPERF 3 3/8"PJ/HC,60 deg ph 10,795.0 10,815.0 7,167.5 7,173.2 2/15/2001 6.0 IPERF 3 3/8"PJ/HC,60 deg ph GAS LIFT;10,218.2 = 10,830.0 10,850.0 7,177.2 7,182.1 2/14/2001 6.0 IPERF 3 3/8"PJ/HC,60 deg ph 10,865.0 10,885.0 7,185.6 7,190.1 2/13/2001 6.0 IPERF 3 3/8"PJ/HC,60 deg ph NIPPLE;10279.2 a.7 Stimulations&Treatments Min Top Max Btm it Depth Depth Top(ND) Btm IND) 4 (ftKB) (ftKB) (ftKB) (kKB) Type Date Com 10,650.0 10,885.0 7,120.3 7,190.1 C-SAND FRAC 2/10/2006 325,000#16/20 Silaca and 3000 bbls of YF125ST PACKER;10,334.3 m 10,650.0 10,885.0 7,120.3 7,190.1 C-SAND 4/4/2008 PUMPED C-SAND FRAC 447171#16/30 BADGER REFRAC SAND w/10 PPA ON FORMATION 10,650.0 10,885.0 7,120.3 7,190.1 C-SAND 3/5/2013 Performed C-sand single-stage refrac placing i REFRAC 362,320-lbs(100%design)CarboLite 16/20 proppant I in 3261-bbl total slurry volume.Treated 0-7-ppa NIPPLE;10.379.4 stages at 30-bpm and 3500-psi avg TP. Mandrel Inserts St WLEG;10.390.3 at, N Top(ND) Valve Latch Pon Size TRO Run Top(ftKB) (kKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com -1 4,603.1 3,383.6 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,043.0 8/19/2014 2 7,405.5 5,182.1 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,950.0 3/17/2013 /PERF;10,650.410.670.0 3 10,218.2 6,938.9 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 709/2015 Notes:General&Safety IPERF;10,755.0-10,770.0 End Date Annotation C-SAND REFRAC;10,6500 -.. C-SAND FRAC;10,650.0 8/19/2010 NOTE:VIEW SCHEMATIC w/Alaska Schemalic9.0 C-SAND REFRAC;10,6500 I IPERF;10,780.0-10,790.0 I _r I IPERF;10,795.0-10,815.0 Ii IPERF;10,830.0-10,850.0 IPERF;10,865.0-10,885.0 I PLUG;10,960.0 , PRODUCTION;34.6-12,042.8- I; OPEN HOLE;12,042.0-15.4380 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. j¢¢- ~y¢ Well History File Identifier FAN Color items' Grayscale ilems: DIGITAL DATA [] Diskettes, No. [] Other, No/Type [] Poor Quality Originals: Other: TOTAL PAGES:(~~'~ NOTES: ORGANIZED BY: BEVERLY B~HERYL MARIA LOWELL DATE ;¢""'*~ Project Proofing PROOFED BY: BEVERLY BREN ~ERYL MARIA LOWELL DATE: ¢.~ OVERSIZED (Scannable) o Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Other [] Staff Proof By: Date: PAGES: ¢¢ (at the time of scanning) SCANNED BY.' BEVERLY t~ VINCENT SHERYL MARIA LOWELL RESCANNEDBY.' BEVERLY ~ VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: PAGES: Quality Checked {done) Rev1 NOTScnnnecl.~4~cl STATE OF ALASKA AL.A OIL AND GAS CONSERVATION COMIDSION • REPORT OF SUNDRY WELL OPERATIONS sC, 1. Operations Performed: Abandon E Repair w ell I- Plug Perforations j Perforate """ Other I- Alter Casing f Pull Tubing E Stimulate - Frac € % Waiver f Time Extension f Change Approved Program r Operat. Shutdow n E Stimulate - Other E Re -enter Suspended Well """ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Id Exploratory r 199 -044 3. Address: 6. API Number: Stratigraphic j Service [l" P. O. Box 100360, Anchorage, Alaska 99510 d 50 103 - 20298 - 00 G 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25559, 372097 - CD1 - 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 15438 feet Plugs (measured) 10960' true vertical 7184 feet Junk (measured) none Effective Depth measured 15438' feet Packer (measured) 10334 true vertical 7184 feet (true vertical) 6999 Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 16 121 121 SURFACE 2940 9.625 2976 2392 PRODUCTION 12008 7 12043 7158 sCANNEm APR 17 2013 Perforation depth: Measured depth: 10650 - 10670, 10755 - 10770, 10780 - 10790, 10795 - 10815, 10830 - 10850, 10865 -10885 True Vertical Depth: 7120 -7127, 7155 -7160, 7155 -7160, 7163 -7166, 7168 -7173, 7177 -7182, 7185 -7190 Tubing (size, grade, MD, and TVD) 4.5, L -80, 10392 MD, 7025 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER @ 10334 MD and 6999 TVD SSSV - CAMCO BAL -O NIPPLE @ 1882 MD and 1700 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10650' - 10885' Treatment descriptions including volumes used and final pressure: 362320# Carbolite 16/20 proppar 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 742 2330 421 -- 170 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development =v — Service E Stratigraphic f 16. Well Status after work: — Oil Ii Gas fl WDSPL fl Daily Report of Well Operations x GSTOR ["" WINJ F WAG E GINJ F SUSP I- SPLUG E 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: 313 -049 Contact Robert Blakney @ 265 -6417 Email Robert. G. Blakney(a�conocophillips.com Printed Name Robert Blakne Title Completions Engineer Signature Phone: 265 -6417 Date 3 / / 3 17I ,00-f4/,5, Form 10-404 Revise 111AR 2 f IN e c , 9' ` 4/1/1_ „ Submit Original Only w . CD1-40 NS CD1 -40 ConocoPhillips 0� Well Attributes Max Angle & MD TD ' • Alaska. Inc . Wellbore API/UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) conec' -,. 501032029800 ALPINE PROD 95.35 11,297.77 15,438.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ••• Well Gonna CDi -00,3/7I20132'3129PM - SSSV: Last WO: 42.66 7/16/2000 Schematic -Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: FRAC, GLV C /O. FRAC SLEEVE osborl 3/7/2013 Casing Strings HANGER, 32 t ` 11P Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String _. String Top Thrd RI. fi CONDUCTOR 16 15.062 37.0 121.0 121.0 62.58 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 36.6 2,976.2 2,392.2 36.00 J - 55 BTC - MOD IIIIll i Cuing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd I PRODUCTION 7 6.276 34.7 12,042.8 7,157.7 26.00 L - 80 BTCM Casing Description String 0... String ID ... Top (509) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd OPEN HOLE 6 1/8 6.125 12,042.0 15,438.0 Tubinq Strings CONDUCTOR, 37 -121 Tubing Description String 0... String ID .Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... Str ng ... String Top Thrd TUBING I _ 4 1/2 3.958 I 32.0 10,391.6 I 7,025.1 12.60 L-80 IBTM Completion Details Top Depth (TVD) Top Inc! Nomi... imi. Top (ftKB) (RKB) ( °) Item Description Comment ID (in) 32.0 32.0 -0.38 HANGER FMC TUBING HANGER 4.500 SLEEVE, 1,882 1,881.9 1,699.7 45.09 NIPPLE CAMCO BAL-0 SSSV 3.812 NIPPLE, 1,882 j 10,279.2 6,971.9 59.38 NIPPLE HES XNIPPLE 3.813 10,334.4 6,999.0 61.40 PACKER BAKER S-3 PACKER 3.875 10,379.4 7,019.6 63.84 NIPPLE HES XN NIPPLE 3.725 O 10,390.3 7,024.5 64.30 WLEG WIRELINE GUIDE 3.958 • Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth SURFACE, (TVD) Top IneI 37 -2,876 Top (RKB) (ftKB) ( °) Descr Comment Run Date ID (In) 1,881.9 1,699.7 45.09 SLEEVE FRAC SLEEVE (OAL= 45.5 ") SET FOR FRAC JOB 2/14/2013 10,960.0 7,204.5 79.87 PLUG IBP SET w /SAND PLUG ON TOP 3/29/2008 3/29/2008 GAS LIFT, 4,803 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (aft Typo Comment 10,650.0 10,670.0 7,120.3 7,127.1 ALPC, CD1-40 2/18/2001 6.0 IPERF 3 3/8" PJ/HC, 60 deg ph 10,755.0 10,770.0 7,155.2 7,159.6 ALPC, CD1-40 2/17/2001 6.0 IPERF 33/8" PJ/HC, 60 deg ph GAS LIFT, 10,780.0 10,790.0 7,162.9 7,166.0 ALPC, CD1-40 2/16/2001 6.0 IPERF - 33/8" PJ/HC, 60 deg ph 7,408 -_. 10,795.0 10,815.0 7,167.5 7,173.1 ALPC, CD1-40 2/15/2001 6.0 IPERF 33/8" PJ/HC, 60 deg ph - - -- 10,830.0 10,850.0 7,177.1 7,182.1 ALPC, CD1-40 2/14 /2001 6.0 IPERF 33/8" PJ/HC, 60 deg ph 10,865.0 10,885.0 7,185.6 7,190.1 ALPC, CD1 -40 2/13/2001 6.0 IPERF 33/8" PJ /HC, 60 deg ph Stimulations & Treatments GAS LIFT, Bottom 10,218 _ Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (ftKB) (RKB) (ftKB) (ftKB) Type Date Comment 10,650.0 10,885.0 7,120.3 7,190.1 C -SAND FRAC 2/10/2006 325,000# 16/20 Silaca and 3000 bbls of YF125ST 10,650.0 10,885.0 7,120.3 7,190.1 C-SAND 4/4/2008 PUMPED C -SAND FRAC 447171# 16/30 BADGER NIPPLE, 10,279 -- REFRAC SAND w /10 PPA ON FORMATION 10,650.0 10,885.0 7,120.3 7,190.1 C-SAND 3/5/2013 Performed C -sand single -stage refrac placing REFRAC 362,320 -Ibs (100% design) CarboLite 16/20 proppant IIVII in 3261 -bbl total slurry volume. Treated 0 -7 -ppa stages at 30-bpm and 3500 -psi avg TP. PACKER, 70334 Notes: General & Safety End Date Annotation 8/19/2010 I NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 NIPPLE, 10,379 ) 1 f all WLEG, 10,390 I IPERF, 10,650 - IPERF, IPERF, iUAND FRAC, C - C, - SAND R 0 - 1 10. C-SAND SAND REFRAC, 10,650 • CSAND I REFRAC, 10.650 li IPERF, I 10,780 - 10,790 1 I WERE, 10,795 - 10,815 - i :._ 11i IPERF, 10,830- 10,850 - Mandrel Details _ Top Depth Top Port IPERF, g, (TVD) Inc! OD Valve Latch Size TRO Run 10.865 - 10,855 = N... Top (ftKB) (ftKB) (1 Make Model (in) Sent Type Type (!n) (PM) Run Date Com... 1 4,603.1 3,383.6 50.63 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 2/5/2006 PLUG, 10,960 ® 2 7,405.5 5,182.1 51.35 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/24/2008 - -__ 3 10,218.2 6,938.9 55.25 CAMCO'KBG-2 1 GAS LIFT DMY BK 0.000 0.02/13/2013 1 1 PRODUCTION, c c 35- 12,043 \ OPEN HOLE, 12.042 - 15,438 N o TD, 15,438 CD1 -40 Frac Summary DTTMSTART SUMMARY • • 2710/2013 BRUSH AND GAUGE 3.80" TO 1881' RKB, PULLED WRDP @ 1881' RKB, HUNG UP AT 173' SLM, UNABLE TO WORK PAST, LEFT WRDP @ 173' SLM, IN PROGRESS. 2/11/2013 PULLED 3.81" WRDP (HVS -265) FROM 174' SLM, CUT SCALE w/ GAUGE RING FROM 9968' SLM TO 10,108' SLM, TBG. OPEN TO 3.76" IN PROGRESS. 2/12/2013 BROACHED SCALE TO 3.8" TO 10,340' SLM, SET 3.81" CAT SV IN XN NIP @ 10,379' RKB, PULLED OV FROM STA #3 @ 10,218' RKB. READY FOR CIRC OUT. 2/13/2013 CIRCULATE 260 BBLS SEAWATER & 85 BBLS CRUDE, U -TUBE, SET 1" DV IN STA #3, MITT PASS, MITIA PASS. 2/14/2013 PULLED CAT VLV @ 10379' RKB. SET 3.81" FRAC SLEEVE (OAL= 45.5 ") @ 1882' RKB. GAUGE TREE TO 3.91 ". READY FOR FRAC. 3/5/2013 Performed C -sand single -stage refrac placing 362,320 -Ibs (100% desi n) CarboLite 16 /20proppant in 3261 -bbl total slurry volume. Treated 0 -7 -ppa stages at 30 -bpm and 3500 -psi avg TP. II „ OF 7T „, • • hw \ \I s r THE STATE Alaska Oil and Gas 1 L 1 Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0.p; Anchorage, Alaska 99501 -3572 ALAS” Main: 907.279.1433 Fax: 907.276.7542 Robert Blakney SCANNED MAR 14 2013 Completions Engineer ConocoPhillips Alaska, Inc. \ °\9 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1 -40 Sundry Number: 313 -049 Dear Mr. Blakney: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy :. Foerster Chair DATED this 7 ay of February, 2013. Encl. RECEIVED 1 STATE OF ALASKA ;" ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 1 2013 APPLICATION FOR SUNDRY APPROVALS �� 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w of f Change Approved Program r Suspend r j Rug Perforations r j Perforate r- Pull Tubing r Time Extension r j Operational Shuidow n r i Re -enter Susp. Well r Stimulate F, • Alter casing r i Other: r j 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r, Exploratory r 199 - 044 - 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 - 103 - 20298 - 00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r I No PV, CD1 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25559, 372097 Colville River Field 1 Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 15438 7184 15438' 7184' * 10960' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 16 121' 121' SURFACE 2940 9.625 2976' 2392' PRODUCTION 12008 7 12043' 7158' Perforation Depth MD (10650- 10670,10755 -107 Perforation Depth TVD (ft): 7120 -7127, Tubing Size: Tubing Grade: Tubing MD (ft): 1780 - 10790, 10795 - 10815, 10830 - 10850, 10865 - 108 7155 - 7160, 7163 7168, 7168 7173, 7177 7182, 7185 - 7190 4.5 L -80 10392 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER S -3 PACKER • MD. 10334 TVD. 6999 SSSV - CAMCO WRDP -2 • MD =1882 TVD =1700 12. Attachments: Description Summary of Proposal r/, ,. 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r j Stratigraphic r Development F • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/15/2013 Oil Ft* ,„ Gas r WDSPL r Suspended r E 16. Verbal Approval: Date: WINJ r)- \ GINJ fl WAG r i Abandoned r Commission Representative: GSTOR r i SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert Blakney @ 265 -6417 Email: Robert.G.Blakney(aconocoohillios.com Printed Name ki Ro • ert _Fla . - Title: Completions Engineer Signature ' Phone: 285 -6417 Date 1 /31 /13 Commission Use Only Sundry Number Conditions of approval: Notify Commission so that a representative may witness / ~�� Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: r?BDMS FEB 07 iO , e_ 441? Spacing Exception Required? Yes ❑ No i Subsequent Form Required: /& — 4 v � APPROVED BY / Approved by: COMMISSIONER THE COMMISSION Date: 2 - - 7 " t 3 Approved application is valid for 12 months from the date of approval. o por6 1012012) Submit Form and Attachments in Duplicate 4131cSefisiel l 1'7--F 2 /5/l13 :. -`, 4) V' \\ e • • CD1 - 40 Sundry Application Drilling for CD1 — 40 was completed in July of 2000 targeting the C Sand formation, and was completed with 4.5" tubing. The well has been treated twice before, once in 2006 placing 325,000 #'s of 16/20 silica sand and again in 2008 placing 447,000 #'s of 16/30 Badger Sand. We will re- stimulate the C Sand formation with a single stage fracture treatment placing —400,000#'s of CarboLite 16/20. If a successful stimulation is achieved we expect the increased production to be 120 bpd in 2013. Proposed Procedure: Schlumberaer Pumping Services: (C Sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10 -403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 8 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10 %. Load tanks with 100° F seawater (approx. 3600 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 8,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 300 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7500 psi. Stage 1 • 600 bbls YF125ST Pad • 165 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 283 bbls YF125ST w/ 3 ppa 16/20 Carbolite • 272 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 393 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 474 bbls YF125ST w/ 6 ppa 16/20 Carbolite • 148 bbls YF125ST w/ 8 ppa 16/20 Carbolite • 143 bbls YF125ST w/ 9 ppa 16/20 Carbolite • Flush with 104 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 400,000 Ibs 16/20 Carbolite RB • • 12. Monitor the surface pressure fall -off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 15. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (initial flowback fluids to be taken to CD1 -01 disposal well until they are clean enough for production.) Cement Evaluation of CD1 - 40 and wells within 1 /4 mile of CD1 - 40 CD1 -40: 7" Casing cement job was pumped on 5/30/1999 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.2 ppg brine. The plug was bumped at 3500 psi and held for 5 minutes. The float held. CD1 -229: 7" Casing cement job was pumped on 1/22/2001 as designed, indicating competent cement operations. Cement was pumped and displaced my mud. The plug was bumped and the float held. Approximately 96' of cement was drilled from casing and a pressure test was performed at 3500 psi for 30 minutes. CD2 - 51: 7" Casing cement job was pumped on 4/26/2003. The cement pumped was 15.8 ppg Class G cement, displaced by 9.6 ppg mud. The plug was not bumped and float held. Approximately 80' of cement was drilled from casing fallowed by a pressure test on casing at 3500 psi for 30 minutes. This data indicates a competent cement job. CD1 - 39: 7" Casing cement job was pumped on 9/8/1999. The cement pumped was 15.8 ppg cement, displaced by 9.6 ppg mud. The plug was not bumped and float held. Approximately 30' of cement was drilled from casing fallowed by a pressure test on casing at 3500 psi for 30 minutes. This data indicates a competent cement job. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a' /4 mile radius or any other nearby well. II RB WNS • CD1 -40 Conoc l$ Well Attributes Max Angle & MD TD �, Inc. Wellbore API /UWI Field Name Well Status Incl (1 MD (1106) Act Btm (ftKB) 501032029800 ALPINE PROD 95.35 11,297.77 15,438.0 cowaiphake ""° Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: WRDP Last WO: 42.66 7/16/2000 Well Conk, : - CD1 -40, 10/8/2010 9.02'.23 A M Schematic -Actual Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag: Rev Reason: FORMAT UPDATE Imosbor 10/8/2010 HANGER. 32 / ., pp Casing Strings c . Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt . String .. String Top Thrd ' CONDUCTOR 16 15.062 37.0 121.0 121.0 62.58 H WELDED ' Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd SURFACE 9 g0 8.921 36.6 2,976.2 2,392.2 36.00 J - 55 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TM) ... String M... String ... String Top Thrd PRODUCTION 7 6.151 34.7 12,042.8 7,157.7 26.00 L -80 , BTCM I I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd OPEN HOLE 6 1/8 6.125 12,042.0 15,438 0 Tubing Strings CONDUCTOR, 37 -121 Tubing Description Stnng 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... 'String Wt . Str ng Stnng Top Thrd TUBING I 41/2 I 3.958 I 32.0 I 10,391.6 J 7,025.1 12.60 L -80 IBTM Completion Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ('1 Rem Description Comment ID (in) SAFETY VLV. , ; 32.0 32.0 - 0.38 HANGER FMC TUBING HANGER 4.500 1.882 NIPPLE. 1,882 - 1,881.9 1,699.7 45.09 NIPPLE CAMCO BAL-0 SSSV 3.812 10279.2 6,971.9 59.38 NIPPLE HES X NIPPLE 3.813 - -- a 10,334.4 6,999.0 61.40 PACKER BAKER S-3 PACKER 3.875 10,379.4 7,019.6 63.84 NIPPLE HES XN NIPPLE 3.725 10,390.3 7,024. 64.30 WLEG WIRELINE GUIDE 3.958 Other In Hole (Wireline retrievable lu s valves um s fish, etc.) SU Top Depth RFACE, (TVD) Top Inc! 37- 2,87 Top (RKB) (ftKB) (°) Description Comment Run Date ID (In) 7---7 1,881.9 1,699.7 45.09 SAFETY VLV WRDP -2 CAMCO 3.817 (HSS -66) 3/19/2009 2.125 10,960.0 7,204.5 79.87 PLUG IBP SET w/SAND PLUG ON TOP 3/29/2008 3/29/2008 GAS awi -__ - � Perforations & Slots - -- Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (800) (ftKB) Zone Date On- Type Comment 10,650.0 10,670.0 7,120.3 7,127.1 ALPC, CD1-40 2/18/2001 6.0 IPERF 33/8" PJ /HC, 60 deg ph 10,755.0 10,770.0 7,155.2 7,159.6 ALPC, CD1-40 2/17/2001 6.0 IPERF 33/8" PJ /HC, 60 deg ph GAS LIFT, 10,780.0 10,790.0 7,162.9 7,166.0 ALPC, CD1-40 2/16/2001 6.0 IPERF 33/8" PJMC, 60 deg ph 7,406 10,795.0 10,815.0 7,167.5 7,173.1 ALPC, CD1-40 2/15/2001 6.0 IPERF 33/8" PJMC, 60 deg ph 10,830.0 10,850.0 7,177.1 7,182.1 ALPC, CD1-40 2/14/2001 6.0 IPERF 33/8" PJ/HC, 60 deg ph ir 10,865.0 10,885.0 7,185.6 7,190.1 ALPC, CD1 -40 2/13/2001 6.0 IPERF 33/8" PJ /HC, 60 deg ph Iiik Stimulations & Treatments GAS LIFT. __ Bottom 10,218 Min Top Max Btm Top Depth Depth Depth Depth (TVD) IND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 10,650.0 10,885.0 7,120.3 7,190.1 C-SAND FRAC 2/10/ 2006 325, 000# 16/20 Silaca and 3000 bbls of YF125ST 10,650.0 10,885.0 7,120.3 7,190.1 C -SAND FRAC 4/4/2008 PUMPED C -SAND FRAC 447171# 16/30 BADGER NIPPLE, 1o,z79 - -- SAND w /10 PPA ON FORMATION Notes: General & Safety End Date Annotation 8/19/2010 1NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 PACKER, 10.334 illt NIPPLE. 10.379 a WLEG, 10,390 41>. .... IPERF, 1111 1 IPERF, 0 PERF, 10,755 - 10,770 C -SAND FR650 11 0,650 C -SAND FRAC, 10,650 PERF, 1 111 10,780 IPERF. 0 IPERF, ® . 10,795- 10,815 IPERF, 11 10,830 - 10,850 ,.,a es Mandr91,C1r etails Port IPERF, 1 ■ (TVD) ) Incl OD Valve Latch Size TRO Run 10,865. 10,885 Stn Top (ftKB) Top Depth Top (ftKB) ( °) Make Model (In) Sery Type Type (in) (psi) Run Date Corn... 1 4,603.1 3,383.6 50.63 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 2/5/2006 PLUG, 10,960 -1111111111■' 2 7,405.5 5,182.1 51.35 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/24/2008 3 10,218.2 6,938.9 55.25 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 4/4/2008 PRODUCTION, i '''''' .c. 35- 12,043 OPEN HOLE, - 12,042 - 15,438 o T0, 15,438 • CDI-40 Alpine C Frac Model 1 stage stimulation • Frac Design Job Description III Step Pump Fluid Name Step Gel Prop. ' Prop. Name Rate Fluid Cone. Type and Mesh Conc. (bbl/mi Volume (lb/mga (PPA) n) (gal) 1) _ . Pad 40.0 YF125ST 21840 25.0 0.00 2.0 PPA 40.0 YF125ST 6950 25.0 16/20 C-Lite 2.00 4.0 PPA 40.0 YF125ST 10004 25.0 16/20 C-Lite 4.00 5.0 PPA 40.0 YF125ST 9644 25.0 16/20 C-Lite 5.00 6.0 PPA 40.0 YF125ST 11968 25.0 16/20 C-Lite 6.00 7.0 PPA 40.0 YF125ST 12851 25.0 16/20 C-Lite 7.00 ..... 8.0 PPA 40.0 YF125ST 12434 25.0 16/20 C-Lite 8.00 1 . Flush 40.0 WF125 6904 25.0 0.00 III Fluid Totals 85,691 gal of YF125ST 6904 gal of WF125 Proppant Totals 363,400 lb of CarboLite 16/20 1 M odel Initial Fracture Top T'A'D........... 7135.0 ft Initial Fracture Bottom TVD 7160.0 ft ID Propped Fracture Half - Length 101.2 ft EOJ Hyd Height at Well ....... 308.0 ft Average Propped Width 0.731 in • Disclaimer Notice: — This model was generated using vendor supplied modeling software and is based on engineering estimates of reservoir • properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. .. . . • • Stimulation Surface Rig-Up › s \ Bi _ej 1 r_.€(.1 ! itt, f ) , . , ' 1 A • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi m s • Frac pump trip pressure setting are staggered and n set below main treating line PRV . • Tree saver used on all fracs rated for 15,000 psi. P- w _E- . A Y XM1 I thalci 0 Pop-Off Tadc 13 I 5' -5, 1 L E:--t---- Pump Trude, Pup-Off T an*. I 4 t . i . — Frac Pump ?ICH tat 1 1PATA ' Frac Pump Frac Pump hill '-toltill 4 O 18*-1N- Frac Pump 0 2 Frac Pump r AI XF:C. CP lv-J Frac Pump RB . . .. • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION IPRiaz lo mANDRR Nscinp.:,) imAv...::::.. Nce m E Di FRAC IRON (24 I i 1 / CONNECTION , ! /i.' • 1 , , 1 ,ot IA' At " 4'5 4 „Ery REMOTE OPERATED J., ill ixr .., 44, ■ ..1..4 .,,,- 1 i .„ .. ... „, i , MASTER VALVE , 1 , MANUAL OPERATED 1 : / /VASTER VALVE / )klvg,1 .,i Stinger Stinger ( T -- - -) ::.. w il ir , ,......, A i V VE AT NT _am N '''':' Wit 4, ri, Wo Oi#: k. 1 07 FLOW TEE MD VENT VALVE WELOSEAD r:711.1 VALVES •,. T - WELLHEAD VALVES - CLOW) rt4=t,M OSTAD PACKOEF . ......., T. ASSEMBLE IN • • '',.' ' i . PLACE IN TUTTNG I :v4-1 , 'fi,-,•,.,:i' TURING '''''' 1 , _ • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 Y2 tubing and 1.75" down 3 1 /2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm RB \ ........... .... •. :: : • ‘,QL)1-26 '..:....„. %..... .. ,.. '. '... . i .* 1:1 • 4 k % , , .. •. • •. : • : : , : *, 61j:1-33 • , ••• , .. . BErQSCHRO•ND 2A ... .... •.... •• • • • • . . . . , . . ". '.. • . • „ • • - '. • . • •. •. • Ca1-34 ....%. ... ., •.... .... ... . . • - • ... - '... •„ •. 1 ... '. . • . ••. .. ... -.„ „ ..........\...CD1-16 ....... ...... '''t. .. .... ... ., '... %. ••.. ' • • . .. : . .. %.CD1-26 CD1-25 ... .. '•••••• „ . ' CD/i-45 . ., .. 39P B1 t............ ......... .. .. • ' • • ., • , . .., „ . . . ., . .. . .„ ... ••.,.. • 061-39PB1 • • • . .. - • .. , . • • . .... •. . .. . •, ' D-. .. •-. C 2-35 ... '' CD:l . , • .. - . .. • .. ...• , • „ _ CD 27 '.. \ . , .. .. • •. • 0. .. .. \ I • '... ... •• • ALPINE 1E3... % % CD1-38 ' . • • 7\ CD2-44 . CD2-45 1 :•... • ° I. CD1-12L1 "•• ''. .. • „ . •. „ • . t.,.. • . „ . .. • . . %. .. • ' . . . . . . . CD1-37 • . ... „. . . - . • • .. ..... -.. • . „ . . „ '' '. ..• %, .. % CD2-35A ... .. .. . . C . ... . ''.. Cu.,`""1-38 • ... \ .... • • ... • t. • .,, . •. . . .. D1-1 • . % .. .. 2 . • .. .. , .... '.. CD2-39 %. %. • . •• ••. •„ • ... ... • ..% C D1-39 • . • . „ . . „ CD2-44 • „ . . \ \\' .....% „ . .. „ ... .... •„ • . '.C61 -229PB1 • • . Legen .• . d . .. • . •. ...•..,CD2-38 • • • •. . CD_40CD_47Frac A .... •. .. •. . . • • :- . ... • r Well . .. „ ... •. .• ! ... . „ • • • •. .• Suspended • , . . . . .. „ '. .....i. D2-51 CD1-40 . ** A + P + A „ - • . • . . .. . .. . • . . . • . . • • '• • . . . ...... •• ••. . • • ... . . . • • '., CD + Service • . '. ... •• . % „ ‘,.... •. • .- ... % A • Producer . . . •••• CD2-52 VCD2-58L1 %. • •. Uri -229 ......... • Observation •• ... • . • .. . • .. .. • Injection: SW • • . , .., •. .....,"...... A Injection: SAPW -.. . . , ••... ”. ..• CD1-48 • Injection: PW • . . • • . . .. • • • • Injection: MWAG CD2-53 •. • ,...:... •.. . •• . .. CD4-301B • • • ACTIVE, INJ, MG CD-2O8 . CD2-57 • .e. • • • • • . • ACTIVE, INJ, IWAG • . - 4: 1 . CD2-58 A . • • -1, • •••,.. - • ACTIVE, INJ, GAS '. .. 27 . •. CD O8PB1 • . .-. CD' • • ACTIVE, INJ, DG . 64-210 . ..IF • . • • ACTIVE, INJ, <Null> • 3 . ., • Disposal . CD2-36 %, .. s, • • newfraclocs$ Events .••. . ci FracBuffcd14740 '.. •.,, • ConocoPhillips .. • • • ... CD4-301A CD1-40 Fracture Radius %. *--.... • . . .. ........ + N CONFIDENTIAL .-. • . .. ''... ; \ .• ........, . '.• ‘. *. 9 0.25 Y Miles • . '''''''''''''''' ............ .. .. .. ...................... ..+. NAN UK 1 • • . FrasP . • - ........ ..004:320PB1 • rogram2013.mxd COP 1-10-2013 • . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 01, 2011 RECEIVEL : Commissioner Dan Seamount A r k' Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 APR Anchorage, AK 99501 Naga � & Gas .; , Cans. Con�missrotl Commissioner Dan Seamount: iq 9 - 0 4 LI- 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 CD1 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 CD1 -15PB1 50103206190000 2100470 10" n/a 10" n/a 4.3 3/13/2011 CD1 -20 50103205030000 2042400 6" n/a 24" n/a 5.4 3/13/2011 CD1 -21 50103203620000 2010060 6" n/a 13" n/a 8 3/13/2011 CD1 -30 50103203480000 2001320 6" n/a 20" n/a 6.4 3/13/2011 CD1 -31 50103203470000 2001180 6" n/a 14" n/a 6.4 3/13/2011 CD1 -37 50103203020000 1990670 8" n/a 13" n/a 8.3 3/13/2011 CD1 -38 50103203230000 2000030 4" n/a 13" n/a 4.9 3/13/2011 CD1 -39 50103203040000 1990800 4" n/a 15" n/a 4.4 3/13/2011 /> CD1-40 50103202980000 1990440 4" n/a 15" n/a 5.2 3/13/2011 STATE OF ALASKA ALASKA AND GAS CONSERVATION .COMMIS REPORT OF SUNDRY WELL OPERATIONS ~~ V ~~~~~ Other ("'° 1. Operations Pertormed: Abandon Re air w ell Plu Perforations Stimulate SG Z p 9 ~"'` s $ , Alter Casing ~ Pull Tubing Ft'rforate New Pbol j Waiver T1"r~e I'sik~6Kai6}il S CO-15.~~~0 Change Approved F7•ogram ~"""` Operat. Shutdown ~'" Perforate Re-enter Suspended Well k11Cf10t~ 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory ~` 199-044 3. Address: ~ API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic " Service 50-103-20298-00 7. Property DesigQatior-~ 8: Well Name and Number: ADL 372097, 25559 ~ CD1-40 9. Field/Pool(s): Colville River Field /Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 15438 feet Plugs (measured) 10960 true vertical 7184 feet Junk (measured) None Effective Depth measured 15438 feet Packer (measured) 10334 true vertical 7184 feet (true verucal) 6999 Casing Length Size MD TVD °Burst Collapse CONDUCTOR 121 16 121 121 SURFACE 2921 9.625 2976 2392 PRODUCTION 11987 7 12042 7157 ~,, -'~ti 'ft.:~~b~~~~' I-t~jt c5 ~I ~$JE~I Perforation depth: Measured depth: 10650'-10670', 10755'-10770', 10780'-10790', 10795'-10815', 10830'-10850', 10865'-10885' True Vertical Depth: 7120'-7127', 7155'-7160', 7163'-7166', 7168'-7173', 7177'-7182', 7186'-7190' Tubing (size, grade, MD, and TVD) 4.5, L-80, 10391 MD, 7025 TVD Packers & SSSV (type, MD, and TVD) PACKER -BAKER'S-3' PACKER @ 10334 MD and 6999 TVD WRDP - 4.5" CAMCO WRDP (SER #HVS-209) @ 1882 MD and 1703 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 10650'-10885' Treatment descriptions including volumes used and final pressure: refer t0 attachment 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 702 1853 421 -- 200 Subsequent to operation 675 1839 590 -- 200 13. Attachments 't~. Well Class after proposed work: Copies of Logs and Surveys run E~loratory Development Service ~` .Well Status after work: Oil Gas WDSPL Daily Report of Well Operations XXX GSTOR WAG "" GASINJ WINJ ~' SPLUG ( 16. 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 Brian Barreda Cad 265-6036 Printed Name Brian Barreda Title WNS Production Engineer S ~ i` r~" Signature Phone: 265-6036 Date ~~ _~~ ~ / ti ~- S APR 2.3 20~~~- ~.z ~ l ~ ~-~~'/ ~`~~o Form 10-404 Revised 7/20 ~B~ Submit Original Only • CD1-40 Well Work Summary DATE SUMMARY 3/25/09_ Pump a diverted 720 bbl squeeze on into the Alpine fm. Start pumps at 19:00 hrs, g 400psi shut down at 23:18hrs. Squeeze went as planned. See details. 3/29/10 Job pumped 225 am to 345 am 3-29-10. Aqueous squeeze; 50 bbls SW followed by 31 bbls pre flush sea water with WAW 5206 (127 gal) @ 4 bpm/vacuum; 205 bbls SW/SCW-3001WC (1265 gal) @ 4.2 bpm/vacuum; post flush sea water with WAW 5206 (127 gal) @ 4 bpm/vacuum; Displace with 1178 bbls SW @ 5 bpm. 350 SITP at start of displacement; on vacuum at the end of the displacement Well SI for 20 hrs after squeeze before returning to production. M W CanncoPhiilip~ ~.ais:i. IUG, CONDUCTOR, t2t VALVE.1 GAS LIFT, 4,603 GAS LIFT, 7,aos GAS LIFT. 10,216 NIPPLE, 10,279- PACKER, 10.334 NIPPLE, 10,3]9 - WLEG. 10,390 -- IPERF. 10,650-10,6]0 C-SAND FRAC, 10,650 IPERF, 10.76010.]90 IPERF, 10.755-1 D 815 IPERF, -._ 10.630-10,650 IPERF, to.865-10.865 PLUG. 10.566 PRODUCTION. 12.(M2 OPEN HOLE, 15.438 TD, 15.438 WNS Well Attribut Wellbore APVU WI es __ Field Name (Well Staf us 501032029800 ALPINE ~IPROD CD1-40 le 8r MD ~Tl) (ftK6) ''Act Bbn (ftK6) 11.297.77 15.438.0 Comment H25 (ppm) Date Annotation End Date KB-Grd (k) it Rig Release Date iSSSV~ WRDP (Last WO: l 42.66 17/16/2000 ''Annotation Depth (ftK6) ~Entl Date End Date Annotation ~iLast Taq: ( Rev Reason: RESET WRDP 4/20/2009 Casin Strin s i String OD String ID Set Depth Set Depth (ND) String Wt String Casing Description (inl (in1 Top (ftK6) (ftK6) (ftK6) (Ibs/ft) Grade String Top ThN CONDUCTOR 16 15.062 0.0 121.0 121.0 6258 H-00 WELDED SURFACE 9 5/8 8.697 0.0 2,976.0 2,392.0 36.00 J-55 BTC-MOD PRODUCTION 7 6.151 0.0 12042.0 7,157.8 26.00 L-80 BTCM OPEN tIOLE 6 1(8 6-125 12,042.0 15 438.0 Tubing Strings. . __ ___ _ I String OD String ID Set Depth Set Depth (ND) String Wt String Tubing Description (inl (in) Top (ftK8( (ftK6) (ftK6) (Ibslft) Grade String Top Thrd IUBING I 41/2 3.958 0.0 10,391.0 7,024.8 12.60 L-80 IBTM ~ther I n_Hole A ll Jewehbing Run_& Retrievable, Fish, etc.) - _ __ ToP Depth ~ (TVD) Top Inc! ~ Top (ftK8) (ft KB) (°) Description Comment Run Date ID (in) 1,882 1 699.8 45.09 NIPPLE CAMCO BAL-O NIPPLE 7/16/2000 ~ 3.812 1,882 1,699.8 45.09 SAFETY WRDP-2 CAMC03.812"(HSS-66) 3/19/2009 ~ 2.125 VALVE 4,603 3,383.5 50.63 GAS LIFT CAMCO/KBG-2J1/DMY/BKUI Comment: STA 1 - 2/5/2006 ~ 3.938 7405 5,181.8 51.35 GAS LIFT CAMCO/KBG-2/1lDMY/BK///Comment: STA2 3/24/2008 3.938 10,218 6,938.7 55.23 GAS LIFT CAMCO/KBG-2/7lOV/BK/.25// Comment: STA 3 4/4/2008 ~ 3.938 10,279 6,971.8 59.37 NIPPLE HES'X' NIPPLE 7/16/2000 '~ 3.813 10,334 6,998.8 61.38 PACKER BAKER'S-3' PACKER 7/16/2000 '. 3.875 10,379 7,019.4 63.82 NIPPLE HES'XN' NIPPLE 7/16/2000 13.725 10,390 7,024.4 64.28 WLEG BAKER WIRELINE RE-ENTRY GUIDE 7!16/2000 '. 3.875 10,960 7,204.5 79.87 PLUG IBP SET wlSAND PLUG ON TOP 3!29/2008 3129/2008 ~, Aerfora tions 8 Slots -- snot Top (TVD) Btm (TVD) Dens'. Top (ftK8) Btm (ftK6(. (ftK8) (ftK8) Zone Date (sh.- Type Comment _ 10,650 10 670 7,120.3 7,127.1 A LPC, CD7-00 2/18/2001 I 6.0 IPERF 3 3/8" PJ/HC, 60 deq ph 10,755 10,770 7,155.2 7,159.6 ALPC, CD1d0 2/17/2001 'I 6.0 IPERF 3 3/8" PJ/HC, 60 deg ph 10,780 10,790.( 7,162.9 7,166.OALPC, CDl-00 2/16/2001 ~~ 6.O~IPERF 3 3/8" PJ/HC, 60 deg ph 10,795 70,815 ~, 7,167.5 7,173.1iALPC. CD7~0 2/15/2001 I, 6.OIIPERF 33/8"PJ/HC, 60 deg ph 10,830 10,850 7,177.1 7, 1821'ALPC, CD740 2/14/2001 60iIPERF 33/8"PJ/HC, 60 deg ph - ', 10.865 Stimula 10 885 1 tions & 7,185.6 Treatme 1.190.1 ALPC. CD7-00 _. nts 2/13/2001 _.. 6 OIIPERF 3 3/8" PJ/HC, 60 deg ph __._. -__.. __. _. ~: Min Top Max Btm i Top Depth Depth . Depth ~ Dep[h i (ND) (TVDI (ftK6) (ftK8) (ftK8( (ftK6) Type Date Comment 10,650-0 10,885.0 7,120.3 7,190.1!C-SAND FRAC 2/10!2006 1325,00011 16120 Silaca and 3000 bb_IS of YF725ST _ 10,650.0 10,885.0 7,120.3 7,190.1 ~C-SAND FRAC X4/4(2008 (PUMPED C-SAND FRAC 447171ri 16/30 BADGER SAND w/10 PPA ON FORMATION L~ Il~aunder, TMama~ E (DQA~ Frorr~: Maunder, Thomas E (~OA) S~nt; Thursday, .~uly 34, 2009 1:41 PM To; 'S~hneider, T+m S.' Subject: RE: ~Q1-4~ (199-Q44~ - AGAIN ~ f.y3{~~~ F. `} C:-'•' p i t i'• '1 ^~~ ~~ .~+.~/.'-E,~.i~i.~~1~e„J ~'`~,J~..; ,F ., r~ Page 1 of ~n ~ ~'~m, ~~ ~f~~t`~~~~ ~~3~1~ ~ f~i~ ~/~~1~i~ ~~~'~E1d ~ ~i , ~l~ tf-t~ ~ i$ iN~Ei~d ~~ ~1~ ~Y~ ~~~ ~`l~ J~~~It~ t~~1~~i~: ~~r ~!~ 1s tP~+~r~ ~~il~ b~ 3 ~n~l ~v~n ~ ~~r vvith ~ 1 ~~ i~v~tv~~i: ~~18 ~r ~~~~~ ~i~ ~~~ ~~a~~~e~~~.. Tc~t~ ~~ur~c#~rf ~~ ~~~~~ Fro . Schn~ider, Tim S. [mailto;Tim.S.SchneiderC~eanocc~philtips.eom] S~rt, l'hursday, Juiy 30, 2409 1:20 PM To: M n~fer, Thomas E(DC~A) S~tt-ject. : GDl-4Q (199-Q44) - AG~4IN ~C~ttr~, E t~1i~~~ J~~t~r~ ~~ f~ur~d fl~~ r~~~r~ f~r ~ur ~r~~r ~~ ti~~ "~c~p~rty ~ ig~~r~~r~" f~t° 1-4~. `~ra v~tl~ t~e~~ ~~~~~~ "~~!" i~o ~~~ ~~~r~y ~~~i~r~~~i~n ~~~ "t~~ i~ ~~n~~~~r, ` ~t~L i~ fi~ ~ ~fi~r~~n ~ Tim 5. Schneider Subsurfaee Development Staff Produetion En9ineer WNS- Alpine 7~ Phon~. 90~-263-b659 ~ Fauc; 907-265-1~15 ~ Mobile: 9Q7-632-8136 ~ ' Etnail: tim.s.schneider@conocophrllip: From; Shiffiett, Jean~e M Sent; Thur'sday, July 3U, 2Q09 12;45 PM To; Sehneider, Tim 5. Subj~c,t: RE; C~1-40 {199-Q44) - AGAIN Tim, The lease information on the subl well is as foilows: surface location tCD1 Pad}: L025559 Heel o# we11: ADL025559 Toe o# well: ADL372097 Upon reviewing inf ation i~ the we11 fiie, it appears the original pia ed bottom hole iocatian in the }3ermit to driii remained in leas ADL02559, however, before drilling the horizontal se tion of the we1l, a new pianngd bottom hole iocation s requested. The new bottom ho(e location was extende ~~ast intQ the n€~rtf~ of lease AdL~72097. It seems th the Application for Sundry Ap~rovals form at the time of the r uest did not include the "Property Designat~ n"' fieid and thus it's likely that subsequent forms t}~at contained th fielc! used the data from ii;e origin "Permit to Driil" form, which did not have the accurate {final) lease info ation for the weli TD location. Nope this answers your questions! 7/30/2009 Page 1 of 3 ~ ~ Maunder, Thomas E (~4A~ From: Schneider, Tim S, {Tim.S.Sehneider~a conocophillips.comj SQnt: Thursday, July 3Q, 20091:2Q PM To: Ma~r~der, Thomas E (DOA) Subject: FW: CC?1-~i0 (499-Q44} - AGAIN ~~~f ~ ~~~~~~ ~~~r~~~ k~~~ fc~c~~d ~~ r~~~r~ f~r ~u~ ~rrr~r ~r~ th~ "~~~~~r~y ~~i~r~~t~~~~ f~r ~:C~1-~~_ ~3~ v~l1~ ~a~~ ~~v~ th~ ~~~~~~ i~ ~~n~ ~r~~rt~ ~~~~gra~ti~an ~~~ "~~ i~a ~~~t~~r, v~~i~ ~~~. i~ t~+ ~ r~~~sn `~ Tirr~ S. ~chneider Subsurfnce Qevelopment Staft Production Engineer WNS- Alpine 4! Phone: 907-265-6859 ~ Fax: 907-265-1515 •c~ Mabile: 90T-632-8131i -CJ--~' Emaii: tim.s.schneiderC~conocophillips.com From: Shifflett, Jeanie M S~nt; Tl~ursday, luly ~Or 20Q9 1~,:45 PM To: ScMneider, 7im S, Subj~ect: RE: ~i~1=4p (199-044) - AGAIN Tim, The ]ease information on the subject well is as fo~lows: surface ioca#ion (CD1 Pad): RD~.fi2~~59 H~el o# well: ADL025559 Toe of weil: ADL372097 t3pon reviswing infarmati~n in the weil fife, it appears the original planned battom hole location in the permit to drilf remained in lease ADL02559, however, before drilling the horizontal section of the wel), a new planned bottom h~Ie location was requested. The r~ew bottom hole lacation was e~ended just in#ca #he north o# fease Ai3L372Q97. It seems that the Application for Sundry Approvals form at the time of the request did not include the '°Property Designation" field and thus it's likely tha# subsequent forms that contained the fieid used the data from the original "Permit to Dril1" form, which did no# have the accurate (final) lease informafion for the v~rell TD location. Hope t~tis answers your questions! Thanks, Jeanie Jeanie Shifflett Er~girtee~ing Technician Nvrth Stope Operation~ & D~velopmen# Con~coPhilGps Alaska, Inc. Ph~ 9{}7-26a-6488 Fax: 9C17-~~5-ffi15 Email: Jeani~.M.Shifflefit~conocophill+ps.eom 7/3Q/2QQ9 Page 2 of 3 ~ • From; Sehneider, T~m ~, ~n#: Thursday, ,July 3C1, 2009 11;51 AM Tp: ShifflEt~, J+e3nie M Subject: FW: CDi-44 (199-Q44) - AGAIN J~~r~t~, H~~°~`~ t~~ ~-rr~~l ~r~~d, ~~ ~`~~`~ r~c~~ ~~~~ ~n ~p-1 ~~~ 1 ~ 1 ~ ~r~i "~`~~n~~. '~`i~ From: Maunder, Thomas ~ (~OAj [maiito;tom.maunder~a alaska.gov] Sent: T`hur~a~y, 7uly 3QE 2E10~ 1Q:1~ AM Ta: Sehneider, Tim S. 5ubj+~ct: RE: CD1-4~ (199-044) - A~AIN 7i~, ~1~r~ ~~ tta~ ~r~~~ a~~t~ ~~~~~~ i~ ~fi~~ ~i~. T~rrt From. Maunder~ Th~mas E (pOA~ Sent: Thur~day, April 16, 2Q09 1;50 PM To: 'Schneider, Tim S.' Subje+ct: RE: CD1-~0 (199-044) Timr ~t~t ~~r~ tl~~ ~rv~~i~g th~ -~~~~~r~ ~~ ~ri~i~~l ~~ thi~ ~ i~~vv~~r~r ~r~~id ~~~ tl~~ ~s~r~t r~~irr~~r~ ~F~~~ ~u~r~i~ir~~ d~~ ~ ~~~~ld k~ th~ ~i1~, `~h~~o~t~ ~g~in, 1~~~ Frotn; Schneider, Tim S. [mailto:Tim.S.Schneider@conoeQphillips.c~m) Sent. Thursday, Apri1 16, 2Q09 1:36 PM To: Maunder, Thomas E (t3QA) Subj~tt: RE; CD1-40 (199-044) '~`~-~, ~'tt r~ ~r~t~ ~~d ~~Y ~~~~ ~itF°~ y~u ~: ~~~y ~~ t~~ ~~~an~~aa~r~ : Tim S. Schneider Subsurf ace Devetopnnent Sta€f Production Engineer WNS- Alpine 'i~ Phone: 907-265-6859 ~ Fwc: 407-265-i515 fw Mobite: 90fi-632-$136 ~ Email: tims,schneider@conocophillips,com '7/3Qf2f109 Page 3 of 3 ~ Fr~om: Maunder, Thomas E ([~4A) [mailto:tam.maunder@alaska,gov] Sent: Thursday, Apri1 1~, Z009 1;17 PM To; Schneider, Tim S. Suaj~: CQ1~FQ (199-Q44) ~ Tim, i am r,eviewing the 4U4 for the recent scale squeeze operation. Please ch~ck the inf~rmation in Biock 8, property designation. The last time work was dQne (frae 4f2/08), Steue Da~ies mad~ a ncate on the 4Q4 cross~ng aut 2553~ and including 372097 (at TD). Would you ~pnfirm the lease numbers? Thanks, Tom Maunder, PE ApG~C '7/3Q/2009 • ~~~,~ `~" ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMN~I'~ ~~~~~ REPORT OF SUNDRY WELL OP~.1~-~I~,~I~ra~m;ssi~~i 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ~ y'" Stimulate~~~~~~~~ Other ~ Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Wefl ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~~ Exploratory ^ 199-044 /• 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20298-00' 7. KB Elevation (ft): 9. Well Name and Number: RKB 55 CD1-40 ' 8. Property Designatio ~ ~~ ~ ~ 10. Field/Pool(s): ADL / 25559 ~j~ /~~~ ~ ~(~ ~ ~ ' Colville River Field / Alpine Oil Pool ~ 11. Present Well Condition Summary: Total Depth measured 15438' ` feet true vertical 7184' • feet Plugs (measured) 10960' Effective Depth measured 15438' feet Junk (measured) true vertical 7184' feet Casing , Length Size MD TVD Burst Coliapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 2921' 9-5/8" 2976' 2392' PRODUCTION 11987' 7" 12042' 7157' Perforation depth: Measured depth: 10650'-10670', 10755'-10770', 10780'-10790', 10795' -10815', 10830'-10850', 10865'-10885' true vertical depth: 7120'-7127', 7155'-7160' , 7163'-7166', 7168'-7173', 7177'-7182', 7186'-7190' Tubing (size, grade, and measured depth) 4.5", L-80, 10391' MD. Packers & SSSV (type & measured depth) Baker'S-3' pkr @ 10334' SSSV= ~es2' 12. Stimulation or cement squeeze summary: Intervals treated (measured) refer to attachment Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 864 2634 451 -- 187 Subsequent to operation 719 3097 774 -- 187 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WRG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Tim Schneider @ 265-6859 Printed Name Tim neider Title Alpine Staff Engineer ~ p 4 Signature ~~~ ~ Phone: 265-6859 Date Y-~ d~ ' . • ~~`C~`L Pre red Shar n All u Orake 263-4612 ~ Form 10-404 Revised 04/2006 ~ ~ ` ~~~ . , ~~, ~ ~ ~` ~~~° -~~ `~ 1~ ~~~~ Submit Original Only ~I~~p . CCNI~~OPI"1t~~ip5 ... ,~sk~~ (~ir::. CONDUCTOR,_ ~ 121 NIPPLE.1,882 SAFETY VALVE.1,882 St1RFACE, 2,516 GFS LIFT. 4.603 ~~ WNS - CD1-40 ~ Well Attributes , wellboreAPINWI Fieltl Name ~ ~.WeIIStaWS Inclination (°~ MD (ftK8) Total Depth (ttKB) ~ 501032029800 IALPINE jPROD I 9535 I 11,297.I7 I 75,438.0 ~ '~Commant H25 (ppmJ iDate .. _.. -~SSSV: WRDP ~~ ~~~:Annota[ion Depth (kKB) iEnd Date IMnotation LastTaq: I ~~ Rev Reason: Annotation End Date KB-Grd (k) ILast WO: I I 4266 '~ RESET WRDP I Rig Release Date I 7/162000 EnE Date 9/202008 127 7.757.8 STA 1 GAS LIFf. ~.a05 GAS LIFT, ~os~e JIPPLE.10.279-~ - PACKER, 10,336 IIPPLE. 10,3]9 WLEG, 10,390 IPERF, 10,650-10,fi]0 IPERF, 10,755-10,770 \ l :-SAND FRSC, IPERF, 10.780-10.]90 IPERF, 10,795-10.815 IPERF. 10,830~10.850 IPERf, 10,665-10.885 PLUG. 10.960 HES'XN' NIPPLE - 7/16l2000 3J; BAKER WIRELINE R6ENTRY GUIDE 7/i6/2000 3.8- _ IBP SET w/SAND PLUG ON TOP 3/29/2008 ~~~ - _. 3/292008 .. . ... .. __ _ _ _ . . . . . . . $hot . . . . . ..... . . _-- (TVD) Bim (ND) , Dans tKB) (kK6) Typa Zona ~ (shot... Date Comment _ ,120.3 7,12%.1 IPERF ~ALPC, CDl-40 6.0 Z78/2001 3 3/8" PJIHC, 60 deg ph ,1552 /,159.6 IPERF ~~ALPC, CD7-00 6.0 2/17I2001 3 3/8" PJ/HC, 60 deg ph ,162.9 /,166.0 IPERF ~ALPC, CD740 6.Oj ?J16I2007 3 3/8" PJIHC, 60 deg ph ,167.5 7,173.1 IPERF IALPC, CD7-40 i 601 y1512007 3 3/8" PJ/HC, 60 deg ph ,177.1~ 7,182.1 IPERF ~,qLPGCDI-40 I 6.0'2/14/2007 I33l8"PJ/HC,60degph Min Top ~ Man Btrn i Deplh ' Depth (ftKB) (ftKB) Date I Type Comma~rt 10,6W.0, 10 855.0 2n072006 GSAND 325,000# 16/20 Silaca arxi 3000 bGls oi YF72 I FRAC 1Q650.0 70,885 0 4/4/2008 C-SAND PUMPED CSAND FRAC 4471711i 76/30 BAI IFRAC FORMAfION PRODUCTION, _ 12.062 OPEN HOLE, 15,638 ~ TD,i5p38 WSR - Well Service Report ~ ~ Well Service Report Page I of 1 Weil Job Scape CPAI Rep CD 1-40 Scale Inhibition Shirtliffe, Ryan llate Daily Work Unit Number 3/25/2009 44 Initial & Final Pressures: Start T/I/A 400/700/620 End 0/650/640 Field: ALPINE z~ hr. Sunimary Pump a diverted 720 bbl squeeze on into the Alpine fm. Start pumps at 19:00 hrs, tbg 400psi shut down at 23:181irs. Squeeze went as planned. See details. STAI2TTIME OPERA7'ION 07:00 PM Pump first stage of 2 stage job. lObbls SW w/ 9ga1 WAW5206, 2 bbl SW w/2 gal WAW5206, 9 bbls SW w 60.5 gal SCW3001WC, 2 bbls SW w/2 gal WAW5206 followed by 50 bbls SW. Initial pressures at 400/700/620 - final vac/700/620. 08:00 PM Continue on to stage 2 of job. Initiate ball drop with 200 bio-balls launched into intitial stage of 124 bbls SW w/ 104 gal WAW5206. Pressure came up to 350 psi while balls in the tubing then well went on vac after 100 bbls pumped. 09:30 PM Pump 12 bbls SW w/50 ga1 WAW5206 chemical 09:45 PM Pump 79 bbls SW w/495 gal SCW3001 10:03 PM Pump 12 bbls SW w/SOgal WAW5206 10:18 PM Pump the flush volume of 420 bbls SW and chase with 40 bbls diesel freeze protect. Fluid T~~pe To Well F~~om Well Non- recoverable ltiate DIESEL 40 SEAWATER, WAW- 5206 162 SEAWATER,SCW- 3001WC gg SEAWATER 470 http://akapps.conocophillips.net/alaskawelleventquery/worklog.aspx?ID=F2885 C08... 4/3/2009 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED APR 1 8 2008 REPORT OF SUNDRY WELL OPERATIONS4laska Oil & Gas Cons. Commissio 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q Other orage Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development^ Exploratory ^ 199-044 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20298-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB = 37' CD1-40 8. Property Designation: 10. Field/Pool(s): ADL / 25559 ~ 3? Z~I'7 ~' 7,D$ Colville River Field /Alpine Oii Pooi 11. Present Well Condition Summary: Total Depth measured 15438' feet true vertical 7184' ~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' SURF CASING 2921' 9-5/8" 2976' PROD CASING 11987' 7" 12042' OPEN HOLE 3396' 6-1/8" 15438' P f i th M ~i~~G 6@9a~~ ~AV ~ ~ ~Ot18 er orat on dep : easured depth: i; true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10391' MD. Packers &SSSV (type & measured depth) baker "S-3" Packer @ 10334' Camco Bal-O Nipple SSSV @ 1882' 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~~ ~`~,~~ "`) #~LQOQ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1367 737 749 1051 195 Subsequent to operation 1980 8023 51 612 229 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Welf Operations X 16. Well Status after proposed work: Oi10 Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-033 Contact Printed Name ider Title Signature 265-6859 Date c~ /~ _~ p Form 10-404 Revised 04/2004 ~~ ~. ~s,~~ ~~ ~~t /~~ 5", x.1.1$ Submit Original y ~ • • CD1-40 Stimulation Results Summary of stimulation job: 4-2-08: Pump frac in one stage: The frac ramped from 2-10 ppa; 2953 bbls slurry, 70 bbls diesel for freeze protect and 110 bbls SW flush. Frac: AIR-40 BPM, AIP-2600 psi, ISIP-2101 psi, 447,171 Ibs, 16/30 Badger sand in perfs. Well test: 4/11/08: 1980 bopd, 51 bwpd, 8 mmcfpd, 229 psi WHP Test is from the perforated 7" (10,650-10,885') u 1 ~y a ALASKA OIL A1~TD GAS CO1~T5ERQATIOI~T COMI-II5SIOK Tim Schneider Production Engineer ConocoPhillips Alaska, Inc. Po Box 100360 Anchorage, AK 99510 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Alpine Oil Pool, CD 1-40 Sundry Number: 308-033 ~ DEB 2D~~ Dear Mr. Schneider: 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. Sincerely, DATED this day Encl. b`lq •-d-(U ~f~ STATE OF ALASKA • ~'`" tp ~/ ALASKA OIL AND GAS CONSERVATION COMMISSION i-'~~C~~ 1i APPLICATION FOR SUNDRY APPROVAL JAN ~ ~ 2p0$ 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Alaska Oil~ls Cam, ~'pmmn ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^/ Time Exl~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConoCOPhillips Alaska, Inc. Development Q Exploratory ^ 199-044 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20298-00 ~` 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Required? YeS ^ NO ^~ CD1-40 " 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 255587 25559 RKB = 3T - Colville River Field /Alpine Oil Pool - 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15438' 7184' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' SURF CASING 2821' 9-5/8" 2976' PROD CASING 11987' 7" 12042' OPEN HOLE 3396' 6-1/8" 15438' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1 /2" L-80 10391' Packers and SSSV Type: Packers and SSSV MD (ft) pkr-- BAKER'S-3' PACKER pkr= 10334' SSSV= NIP SSSV= 1882' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: March 1, 2008 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider Printed Name T~ ~chnei r Title: Production Engineer ,../ Signature v.., f~~ f`y~,~i,` ~ 265-6859 Date ~-~Cj-~~ Commission Use Onl Sund Number: ~ ~ ' Conditions of approval: Notify Commission so that a representative may witness ~ ~3 3 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~:.' _r Subsequent Form Required: 4~ APPROVED BY ~ / Approved by: ISSIONER E ISSION Date: ~ ~Q Form 10-403 Revised 06/2006 ~Jf,~,~~Su~bmit in Duplicate • Overview: CD1-40: A hydraulic fracture treatment will be performed in the perforated interval (10,650- 10,885') to establish communication with the Alpine "C" sand. An inflatable bridge plug will be set in the 7" below the perforated interval to isolate the open hole section. An FCO will be performed post-frac to recover the inflatable bridge plug. Procedure: 1. RU Coil Tubing and set the inflatable bridge plug at ± 11,000'. POOH. RD CTU. 2. MIRU 8 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) °'~~ 3. Rig up Schlumberger equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 4. Pressure test surface lines to 9500 psi 5. Pump the 100 bbl Breakdown with Schlumberger's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 6. Pump the following schedule at 40 BPM with a maximum pressure of 5000 psi, add breaker as per lab results. Maintain 3000 psi on the IA during the treatment. • 400 bbls YF125ST Pad • 120 bbls YF125ST w/ 2 ppa 16/30 White Sand • 200 bbls YF125ST w/ 4 ppa 16/30 White Sand • 200 bbls YF125ST w/ 6 ppa 16/30 White Sand • 300 bbls YF125ST w/ 8 ppa 16/30 White Sand • 300 bbls YF125ST w/ 9 ppa 16/30 White Sand • 300 bbls YF125ST w/ 10 ppa 16/30 White Sand • Flush with linear gel and freeze protect Total Sand: 325,000 lbs. 7. 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. 8. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. 9. RU CTU and perform FCO to inflatable bridge plug. Latch plug and POOH. RD CTU. . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska - AC:il£C Christine ~ahnken 333 West 7th Ave Suite 100 Anchorage. Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/~echanical Logs and / or Tubing Inspection(Caliper / fv1TT) The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C (\ft.\NED SEP 1 Anchorage, AI< 99518 SG~' Fax: (907) 245-8952 3 2007 1) 2) 3) 4) 5) 6) 7) 1 Report / EDE 1 Report / EDE C01 - 19 CD1 - 40 Caliper Report Caliper Report 04Sep-07 lJ3.8ep-07 U:I.C-- ~ÖO- Cf-{b 1t- 15~ I Ò -e (!')q - cHI .r 1?0) Ri:: . '" ¡.... Signed: fj,jj~ Date : ~4P 1 () ?un07 VLi - G L 1 Print Name: Q.,hrìðtht Q...- rVtQ.l,LlA<~~ Qii& Gas Cons, Commission )~nc:h(.}i,3ge PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AI< 99518 PHONE: (907)245-1951 FAX: (907)245-1952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\Mastør _ Copy _00 ]DSANC.2OxxIZ _ Wotd\Dìstribulion\TransmittaC Shoets\T",nsmiUmginal.doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: CD1-40 Log Oate: September 3, 2007 Field: Alpine Log No. : 9508 State: Alaska Run No.: 2 API No.: 50-103-20298-00 Pipe1 Desc.: 4.5" 12.6 lb. L-80 Top Log fntvl1.: Surface Pipe1 Use: Tubing Bot. Log Intvl1.: 10,390 Ft. (MD) Pipe2 Desc.: T' 26 lb. L-80 Top Log Intvl1.: 10,390 Ft. (MD) Pipe2 Use: Liner Bot. Log Intvl1.: 10,664 Ft. (MD) Corrosive & Mechanical Damage Inspection Inspection Type : COMMENTS: This caliper data is tied into the 4.5" WLEG @ 10,390' (Drillers Depth). This log was run to assess the condition of the 4.5" tubing and 7" liner with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tubing logged is in good condition, No significant wall penetrations, areas of significant cross sectional wall loss, or significant 10 restrictions are recorded. The caliper recordings indicate that the 7" liner interval logged is in good condition. No significant wall penetrations, areas of significant cross sectional wall loss. or significant 10 restrictions are recorded. This is the second time that a PDS caliper is run in the 4.5" tubing of this well (the first time for the 7" liner). A comparison between the current log and the previous (October 15, 2003) indicates slight, if any, increase of wall penetrations in the 4.5" tubing. The comparison chart is presented in this report. 4.5" Tubing - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (>18%) are recorded. 4.5" Tubing - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross sectional wall less (>4%) are recorded. 4.5" Tubing - MAXIMUM RECORDED 10 RESTRICTIONS: No significant 10 restrictions are recorded. 7" Liner - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (>18%) are recorded, excluding the known perforations. 7" Liner - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross sectional wall loss (>100Ál) are recorded, excluding the perforation areas. 7" Liner - MAXIMUM RECORDED ID RESTRICTIONS: No significant 10 restrictions are recorded in the liner interval logged. I Field Engineer: S. Carpenter Analyst: B. Qi Wìtness: T. Crumrine ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I'1Q,044 1* 1f:;L../1I I I I I Well: CD1-40 Field: Alpine Company: ConocoPhm¡ps Alaska, Inc:. Country: USA I Overlay I Max. Rec. Pen. (mils) 0 100 200 0.1 I 10 20 30 I 40 47 57 I 67 77 87 I 97 104 I ~ 114 E ;, 124 Z ë :£ 134 I 144 154 164 I 171 181 191 I 201 211 I 221 231 237 I I I I Survey Date: Prevo Date: Tool: Tubing: September 3, 2007 October 15, 2003 MFC 40 No. 99493 4.5' 12.6Ib l-80 -50 Diff. În Max. Pen. (mils) -25 0 25 !¡¡ .c E ::> Z ë :£ -13 o Approx. Corrosion Rate (mpy) 50 13 I I I Well: Field: CD1-40 Alpine Alaska, Ine. I Country; USA Nom.OD 4.5 ins Weight 12.6 f Grade & Thread L·80 I I Penetration and Metal toss wall) penetration body metal loss I 250 200 150 100 50 o 0 to 1% 1 10 10 10 20 to 40 10 over Î 0% 20"/" 40% 85% 85% I I o o I pene, 0 loss 113 I Configuration (body) 30 I 20 I 10 I o isolated general line ring hole I pos¡; pitting corrosion corro$ton corrosion ¡ble hole I o I I P S Repo Overview Body Region Analysis Date: T ooIT ype: Tool Size: No. of Anal st: Nom.lO 3.958 ins 3, 2007 MFC 40 No. 99493 ;U5 40 B. Nom. Upset 4.5 ins len. 6.0 ins Profile (% wall) penetration metal loss body 50 GLM 1 GlM2 GLM3 Bottom of Survey"" 239.3 Analysis Overview page 2 I I Lower len. 6.0 ins 100 I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Watt: Nominal I.D.: 4.5 in 12.6 ppf L-80 0.271 in 0271 in 3.958 in Well: field: Company: CD1-40 Alpine ConocoPhiUips USA ¡ne. 3,2007 I I I I I Joint it. Depth Pen, Pen. PerL ¡\'lclal Min. P fofile No. (Ft.) (Ins;1 LD. Comments ('Yo wall) (Ins.) (ins. ) 0 50 100 .1 14 om 3.90 PUP 1 17 001 3.92 2 60 om ¡ 1.92 3 104 m 3.88 4 148 3.91 5 192 3.90 6 236 fi 7 280 0.Q2 om 9 I 368 0.01 3.91 10 412 001 ¡ 390 11 4% om 4 3.92 12 500 0.01 4 3.91 13 544 om 3.92 14 588 0.02 3.91 15 h~() :Jt=±0.Q2 3.90 16 674 om Jm1 17 718 o 0.01 18 762 n 0.01 19 806 0.02 20 850 0.01 :> 3.90 21 8!}4 om I 1.91 22 938 1 ·~.90 23 982 :> 3.90 ~ 3.91 I 3.92 6 1114 I 3.91 27 1158 0 4 1 3.90 28 1202 0 3.91 29 1246 0 3.91 30 1290 0 om 4 3.91 31 1334 0 0.01 4 3.91 32 1378 0 0.01 6 ¡ 3.90 33 1422 0 0.01 4+ 3.89 Lt. Demsit$. 34 1466 0 0.01 3.89 35 1510 0 om 3.90 36 1554 n 0.03 1iJ 3.85 Lt. Deoo<;it<;. 37 1596 0 0.01 3.91 38 1640 0 0.01 3.89 39 1682 0 0.Q2 3.90 40 1726 0 0.02 3.89 ¡ Lt Deoosits. 41 1770 0.01 3.89 42 1813 0.04 4. 3.93 Shallow oiUirn!. 4.2.1 1859 0.03 3.91 PUP 42.2 1869 0 ( 2.25 SSSV 423 1873 0.02 3.94 PUP fJ! 43 1882 0.01 3.92 44 1927 0.03 P 3.90 Shallow oiUiml. 45 1970 0.02 3.93 46 2016 0 0.ü3 11 3.91 Body Me!allo$s Body I I I I I I I I I I JOINT TABULATION S Pipe: Body Wall: Upset WaD: Nominal to.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in WeB: Field: CD 1-40 Alpine ConocoPhilips Alaska, Inc. USA Survey 3,2007 I I I I Joint it. Depth F'ei Pen. Pen, Metal Min. Profile No. it 1.0. Comments (Ins.) (Ins.) (Ins.) 0 50 100 47 2061 1 Shallow oíttiruz. 48 210 Shallow nitlÎnl;!. 3.90 50 2196 9 3.91 51 2238 0.02 ! q 3.90 52 2282 3.91 53 2321 3.92 54 2366 ~ l'h.'OW ""no. 55 2409 ""- 56 2452 ~ 57 2496 58 7S tR 0 c........ II! 21): 16 n ~ 59 0 3.90 60 26 8 0 0 3.91 f,1 267 n 3.92 =ti 71 3.92 '75: 3.92 II 805 3.91 Shallow oitlinl;!. 65 848 66 ; 67 2938 [} 001 4 1 3.91 68 2900 0.02 8 :2 Lt. DeOOSÎts. 69 3025 001 5 2 ~ 3070 =+ 0.02 7 ¡ 11 .fH 72 !.01 73 0 74 t-§- 0 3.93 75 3287 0 1* 76 3331 () 0.D3 (J 77 3376 .02 92 78 3417 .02 .91 79 3459 .04 3 .94 Shallow oittimI. 80 3504 .92 81 3549 .93 82 3595 ") 3.91 83 361q '9 3.88 84 3687 () 3.84 Lt. Deoœíts. 8') 3727 n lRq 86 3774 0 't90 87 1817 n 1.89 Shallow nitlinq. 88 3858 () U.Deoosits. I 89 90 Shallow nitlil)2. 91 92 4034 0 '-- 93 4077 3 CJ .81 94 4114 ( 0.02 3.88 95 4154 ~ 't90 96 4207 386 - Body Met,¡1 Loss Body Page 2 I I I I I I I I I I I I I REPORT JOINT TABULATION Wall: Upset Wan: Nominal I.D.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: Field: CD1-40 Alaska, Inc. Count¡y: Date: USA 3, 2007 I I I Joint Jt. Depth PelL Pen. Pen, ¡Vle!a! Min. P fafile No. I(::::*;! ;s !.D. Comments (0/: (Ins.) (Ins.) 0 50 100 4245 3.91 rmmm 4285 i 100 () 101 102 4458 03 4500 2 :H! 104 4'i.11h 0.02 9 ¡ ) 104.1 4588 ( om 3.87 PUP 104.2 4597 ( N/A GLM 1 (Latch @ 7:OOì 1 04.3 4602 PUP Shallow ni\tinŒ. II\W - 106 .391 07 3.91 4743 3.91 109 4787 3.87 110 48?4 () 2 3.93 111 4871 2 3.87 112 4913 1t02 R :; 1.89 113 49 ,0 0.04 14 ) Shallow Ditiina. 114 5m 2 om 4. ¡ 11') I 50 m ( o.m 10 ) 116 50 a p 0.02 117 5134 () 118 'i174 ¡ ihf I n 7i1ff 10 120 'i'/I,i I 121 5301 3.89 122 53 I~ 3.90 om 3.91 124 5< :3 :.91 125 5. '2 1.91 126 5522 ( .90 127 5565 ( 128 <;1;11 i .0 179 5650 i 0.D2 - 130 5695 ( om :......... 131 5735 ( "1 3.91 5777 4. I 3.91 0.03 3.91 134 135 136 n . 1 3.90 137 5973 n L -2 3.93 138 6oo? n I II I 3.91 139 6034 () I II ! 3.91 140 6061 3.91 141 6093 I 1 llii 142 1;174 I 1 143 6154 0 0.02 7 II 3.90 3 REPORT JOINT TABULATION Wall: Upset WaD: Nominal 1.0.: 4.5 in 12.6 ppf l-OO 0.271 in 0.271 in 3.958 in WeD: Fie!d: CD 1-40 Alaska, Ine. Country: Date: USA 3,2007 I I I I I I I I I I I I Joint jt Depth 11;;:~:'1 Pen. Pen. ¡'vlelal Min. ,? rofíle No. ;s 1.0. Comments (0/0 wall) (Ins.) 0 50 100 144 6187 4 I 3.92 145 6 18 146 6 58 147 6 95 II r--- 3.92 148 6348 0 0.01 4" 149 639'1 0 I 0.03 10 150 6434 n 0.Q2 q 3.90 151 6476 0 0.03 11 3.87 1 '12 6'121 n 0.04 I'> 3.90 Sn;:¡!!ow niUinQ. 153 0 O.O~ 390 Sh;:¡l!ow nittiml. 154 '-- 15 156 0.04 Shallow oitlÎntr. 157 6740 O. 5 18 Shallow oiUin¡;¡. 151'1 678' fJ ì'ì I ( .90 159 6827 I) nl10 :.86 1ffi fiE ~LJIJ !fi,) 161 .89 162 3.90 163 3.87 164 7043 3.90 165 7082 0.02 a 3.88 166 7P8 0.02 q ~91 167 7172 0.03 10 3.89 ,.. I mo~ '{JiB Shrillo . . 169 I 7262 ;; i"~ 1 701 0.03 \ 3. !.L DenosiN. 171 7346 0.01 3. 171.1 7388 () PUP 171.2 7400 0 I 2 (latch @ 5:30} 1113 7411 0 J 3.88 I PUP 172 7423 I :5 3.89 173 '1 At:..:: í L( 3.87 174 7510 0 3.87 17') 7 'i,} 1 n ~ 176 . 7597 177 I 3.87 It. DeOl:'lSits. 178 7681 0 3.~8 I 179 7724 0 ¡ 0.04 HID 7766 0 ~780R 0 3.90 7849 0 3.88 181 78(}2 0 "il:02 I R 184 7939 0 ¡ 0.02 I 6 Lt. Denosits. 185 79B2~ 186 8026 ! solated oiWnç¡, 187 R07? 0.0,2 188 8114 f§f I ill 1 fl9 8159 ;; It l)eOf'¥,;Îts. 190 8197 0.03 ] 4 I I I I I I I I I I I I I I I I I I I JOINT TABULATION SH Wall: Upset Wall: Nominal I.D.: 4.5 in 12.6 ppf l-80 0.271 in 0.271 in 3.958 in Well: CD1-40 Field: Alaska, Inc. USA 3,2007 Joint Jt. Depth Pen, Pen. Pen. ¡¡ Min. .0 Profile No. ,t W. Comments (Ins.) (ins.) (ins.) 0 50 100 191 8742 t 0.03 11 'i 3.89 Shallow nittir!l2. 197 I 8288 ( 0.01 10 3.9? 193 833) ¡)~ . 194 8379 Shallow nittin"'. 8424 H468 A509 t ( i.02 q ¡ ),01 .2 A640 ( l' ~ 202 8727 "I '1 CJ) 2(13 R776 3.90 104 8817 I 1..90 205 8862 3.92 206 8903 391 207 8944 4 3:(:¡O- 208 8985 .J \91 209 9m7 ( gm ¡ 2 ~.~~ I' 710 90(;6 i. 211 9105 t om 3 217 q151 I :.~~ I: ] 3.91 ¡ ~91 I :.' =HH 33 0 I 215 9271 0 0.01 I 'ï.89 216 9312 TIt 217 9353 218 9394 3.90 'i19 94'{4 t 3.R8 220 9475 I 3.90 2:;11 9517 I 3.116 222 9559 I 1 I '{Q2 22'1 9597 I 3.90 224 9643 3.90 225 9681 .0 3.91 226 9725 I 3.91 ')')7 Q77') ~ 228 9816 229 QR " I 230 qq 10 I 231 99 0 3.91 232 9992 ¡ 3.92 33 111038 003 ! I ~ 34 10078 35 10121 . 36 10166 3.92 236.1 ~o 3.89 PUP sru.!low niffiti<. 236.2 8 t 011 NiA GI M 3 {latch @ ,10:0Oì 2363 10225 t ! om ! 41 ~.C¡1 l'llP '" 237 10234 ( I 0.Q1 I 6 I 7 3,79 11 5 I REPORT JOINT TABULATION SH I I I I I I I I I I I I I I I I I Wall: Upset WaR: NominalID.: 4.5 in 12.6 0.271 in 0.271 in 3.958 in L·80 Well: Field: Company: Survey Joint No. 6 CD 1-40 Alpine ConocoPhirips Alaska, Inc. USA September 3, 2007 Comments Profile o 100 I I 1 Well: Field: CD1·40 Alpine Alaska, Ine. I USA Nom.OD 7 ins Weight 26 f Grade & Thread l-80 1 1 Penetration and Metal loss wall) penetration body metal loss body 10 1 1 o 1 o Oto 1to 1% 10°;', over 85"/" I Number of pene. 0 0 loss 0 6 sed 6 o o o I I Damage Configuration ( body ) 10 1 1 1 o isolated genera! line ring hole I pO$> pitting corrosion corrosion corrosion ihle hole 1 1 I PDS Report Overview Body Region Analysis Date: Type: Tool Size: No. of Anal t: Nom.tD 6.276 ins September 3, 2007 MFC 40 No, 99493 2.75 40 B. Nom. Upset 7 ins Upper len. 6.0 ins lower len. 6.0 ins Profile (% wall) penetration metal loss body 50 100 BoUom of Survey = 7 Analysis Overview page 2 1 'I I I I I Joint No. I 1 2 3 4 I 5 6 7 I I I I I I I REPORT JOINT TABULATION SH 7. in 26.0 ppf L-8Q 0.362 in 0.362 in 6.276 in WeN: field: CD 1-40 Alpine ConocoPhiR¡ps Alaska, Inc. USA September 3, 2007 Survey Comments 'ts. o 50 100 I I I I I I I I I I I I . . ~ ConocoPhillips Alaska "7 P.o. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 sC;ANNED APR 1 0 2007 tqC¡-OU,4 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ftom the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water ftom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 . 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200~118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 2/16/2007 Alpine Field March 31,2007 e ConocÓÂ,illips e Tim Schneider Staff Production Engineer Alpine Engineering P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6859 March 7, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West yth Avenue Suite 100 Anchorage, Alaska 99501 \qq' tJ\.f\f Subject: Report of Sundry Well Operations for CD1-40 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the Alpine well CD1-40. This report will cover the recent stimulation treatment on ..- this well. If you have any questions regarding this matter, please contact me at 265-6859. Sincerely, ~~ T. Schneider Staff Production Engineer CPAI Alpine Engineering TSS/skad RECEIVED e STATE OF ALASKA e MAR 0 8 '>006 ALASKA OIL AND GAS CONSERVATION COMMISSION . L REPORT OF SUNDRY WELL OPERA TIONS\laska Oil & Gas Cons. Commission 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate [] Other A~orage Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [] Exploratory 0 199-044 1 306-036 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, AnchoraQe, Alaska 99510 50-103-20298-00 , 7. KB Elevation (ft): 9. Well Name and Number: RKB 55' CD1-40 ~ 8. Property Designation: 10. Field/Pool(s): ADL 25558 1 25559 Colville River Field 1 Alpine Oil Pool 11. Present Well Condition Summary: \ , Total Depth measured 15438' feet true vertical 7184' .. feet Plugs (measured) Effective Depth measured 15438' feet Junk (measured) true vertical 7184' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURF CASING 2921' 9-5/8" 2976' 2392' PROD CASING 11987' 7" 12042' 7157' OPEN HOLE 3396' 5-1/2" 15438' 7184' Perforation depth: Measured depth: 10650'-10670', 10755'-10770',10780'-10790', 10795'-10815', 10830'-10850', 10865'-10885' true vertical depth: 7120-7127,7155'-7160',7163'-7166', 7167'-7173', 7177'-7182', 7186'-7190' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10391' MD. Packers & SSSV (type & measured depth) RBDMS 8Ft MARl~ 8 ¡HOB pkr= BAKER 'S-3' PACKER pkr= 10334' Cameo WRDP SSSV @ 1882' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 10650'-15438' MD Treatment descriptions including volumes used and final pressure: 312,413# of 16/30 white sand in 2995 bbls total slurry, ISIP = 1160 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinn Pressure Tubina Pressure Prior to well operation \,)~ \J\./~, 1073 , 1329 190 991 186 Subsequent to operation \ t \ ~ "'/~ 3122 3700 - 972 ., 1181 230 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development [] Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil[] GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: :> '~Ob-O <0 Contact Tim Schneider @ 265-6859 Printed Name --rill.. S"chneider Title Staff Production Engineer Signature 1 R. ~. Phone Date )-) -Cl~ í . Prenared b" Sharon Al/suD-Drake 263-4612 Form 10-404 Revised 04/2004 OR'GH~AL ;)¿~); Submit Original Only e e CDI-40 Stimulation results: Summary of stimulation job: 2-10-06: Pump frac stages in stair steps; 2,4,6,8,9,10 PPA, 2995 bbls total slurry, 40 bbls diesel for freeze protect.. AIR-40 BPM, AIP-3546 psi, ISIP-1160 psi. 312,413 lbs. 16/30 White Sand in perfs. Well test 3/1/06: 3122 bopd, 972 bwpd, 3.7 mmcfpd, 230 psi WHP sssv (1882-1883, 00:3.812) NIP (1882-1883, 00:6.062) Gas Lift MandrelNal\19 1 (4603-4604. Gas Lift MandrelNal\19 2 (7405-7406, TUBING (0-10391, 00:4.500, 10:3.958) Gas Lift MandrelNal\19 3 10218-10219, · 00:5.984) NIP 10279-10280, · 00:5.000) PKR 10334-10335, · 00:5.970) NIP, '10379-10380, · 00:5.000) WLEG '10390-10391, 00:5.000) Perf 10650-10670) Perf 10755-10770) Perf 10780-10790) Perf :10795-10815) Perf 10830-10850) Perf '10865-10885) OPEN HOll- '12042-15438 · 00:6.12~' .LPINE ConocoPhUlips AlaA,lnc. I - CD . .,. I",,}' . ì I ...: . . I t . t ' .L-._. __.-----.. CD1-40 CD1-40 . API: .501032Õ2980~ WeILTYP.e.:.lPROD SSSV Type: WRDP I Orig Completion: i 7/16/2000 ·-···l-· Angle @ TS: º-~ .CãJ Angle @ TD: 87 deg @ 15438 Annular Fluid: Last W/O: RefL To 16.000 0 9.625 "b" 0 7.000 -- --.- 0 6.125 - -1?042 ---T~ Wt I--Gr~ 702S--L1.2.-60::I:::HÞ ' Thread WELDED BTC-~OJL BTCM Thread --- IBTM i ~r ---- as I an re saves St MD TVD' Man Mfr Man-Type! V Mfr V Type-T v OD Latch' Port ! TRO I Date Run 1 4603 3383 CAMCO KBG-2 CAMCO GLV 1.0 BK 0.188 1873 1/10/2001 2 7405 5182 CAMCO KBG-2 CAMCO GLV 1.0 BK 0.188 1844 1/10/2001 _.ª-. 10218 6939._Ct.I'y1CO KBG-2 CAMCO", OV 1.0 BK 0.250 0 9/5/2005 Other (Dluas, eQ!JjQ., etc.) - JEWELRY _ _ º-eDth ! TVD _IY~ .._. ' Description 'h' ,=r- 1882 : 1703 NIP . CAMCO BAL-O NIPPLE ~ _uf882 1703 SSSV" CAMCO WRDP-'ïsËR #HRS-277\ ON DB-6 l..OCK, 2.12.5" ID 91712005 ' 10279 6972 NIP HES 'X' NIPPLE 10334 6999 PKR BAKER'S-3' PACKER 10379 7020 NIP HES 'XN' NIPPLE 10390 7024 WLEG BAKER WIRE LINE RE-ENTRY GUIDE Vlv Cmnt ID 3.812 2.125 3.813 3.875 3.725 3.875 --1 ~ FRANK H. MURKOWSKI, GOVERNOR A1tASIiA OIL AlWD GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Kelli Hanson Alpine Development Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 J qq- o4Lf Re: Colville River Field, CD 1-40 306-036 SCANNED fEB () ~1 2DGü Dear Ms. Hanson: 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. Sincerely, ~~~ Commissioner sl- DATED thisL day of February 2006 Encl. --) -1 Kelli Hanson Production Engineer Alpine Engineering ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6945 January 31, 2006 RECEIVED FEe 0 1 2006 AIB8ka Oil & G as Cons. C . . Anchorage omm;SS101J Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for CD1-40 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Alpine well CD1-40. We are planning to perform a stimulation treatment on this well. If you have any questions regarding this matter, please contact me at 265-6945. Sincerely, 161&' ~ Kelli Hanson Production Engineer CPA I Alpine Engineering KH/skad () [) i C ~, ¡\ '^ , 1. Type of Request: Abandon J n} I RECEIVED STATE OF ALASKA P'1( , ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 1 2006 APPLICATION FOR SUNDRY APPROVMka Oil & Gas Cons C .. 20 AAC 25.280 Anr..hora ~ ommïssmo D Suspend D Operational Shutdown D Perforate D Waiver ~ Other 0 D Repair well D Plug Perforations D Stimulate 0 Time Extension D D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 55' 4. Current Well Class: Development 0 Stratigraphic D Exploratory D Service D 5. Permit to Drill NJI, mber: 199-044 ~ 6. API Number: 50-103-20298-00 ,,j 9. Well Name and Number: CD1-40 8. Property Designation: ADL 25558 1 25559 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 15438' 7184' 15438' Casing Length Size 10. Field/Pool(s): Colville River Field 1 Alpine Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7184' MD TVD Burst Collapse 7" 121' 121' 2976' 2392' 12042' 7157' 15438' 7184' CONDUCTOR SURF CASING PROD CASING OPEN HOLE 121' 2921' 11987' 3396' 16" 9-5/8" 5-1/2" Perforation Depth MD (10650'-10670',10755'-10770' Perforation Depth TVD (ft): 7120'-7127', Tubing Size: 10780'-10790',10795'-10815', 10830'-10850', 10865'-10885' 7155'-7160',7163'-7166',7167'-7173', 7177'-7182', 7186'-7H 4-1/2" Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 'S-3' PACKER pkr= 10334' Camco WRDP SSSV @ 1882' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: February 4, 2006 Oil 0 Gas D 16. Verbal Approval: Date: WAG D GINJ D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name I/~ ~tli,:H~pson Signature ~ ~ Tubing Grade: L-80 Tubing MD (ft): 10391' Service D Plugged D WINJ D Abandoned D WDSPL D Commission Use Only Contact: Kelli Hanson @ 265-6945 Title: Alpine Development Engineer Phone z¿,5""'?9t¡'Ç Date 1/3/ lOb Sundry j?i~. 0 ~ & Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: RBDMS BFL F E8 0 2~ 2U06 Subsequent Form Required: '-\0 ~ Approved by ~ 4~f-- Form 10-403 Revised 7/2005 'V APPROVED BY COMMISSIONER THE COMMISSION Date: 2,-( -q6 ORIGINAL Submit in Duplicate 5. Pump the 100 bbl Breakdown with Dowell's YF125ST fluid system. Bring pumps up to ~ maximum rate ASAP. ~ "",'0 \\ "'>'"'~ ~-.\ \;, ~ \~Y 6. Pump the following schedule at 40 BPM with a maximum pressure of 9000 psi, add breaker 'is-L\,?,(J ~\ as per lab results. Maintain 3000 psi on the IA during the treatment. \ - ~~( --~1 ----7 Overview: CD1-40: Overall goal is to establish an offtake point through previously perforated casing at the heel of CD1-40 (the casing at the heel was perforated in 2001 without stimulation but showed no production contribution in a follow-up spinner survey) resulting in increased production rate and reserves. A sand plug will be set using coil tubing prior to initiating the fracture treatment. After the hydraulic fracture treatment is completed, the sand plug will be cleaned out using coil tubing. Procedure: 1. RU coiled tubing and set sand plug in sump from (11 ,300'MD to 10,800' MD) to isolate open hole. 2. 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)- 3. 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). 4. Pressure test surface lines to 9500 psi · 400 bbls YF125ST Pad 120 bbls YF125ST wi 2 ppa 16/30 White Sand 200 bbls YF125ST wi 4 ppa 16/30 White Sand 200 bbls YF125ST wi 6 ppa 16/30 White Sand 300 bbls YF125ST wi 8 ppa 16/30 White Sand 300 bbls YF125ST wi 9 ppa 16/30 White Sand 300 bbls YF125ST wi 10 ppa 16/30 White Sand Flush with linear gel and freeze protect · · · · · · · Total Sand: -325,000Ibs. 7. Monitor the surface pressure fall-off at the end of the job for 45 min (or until closure is verified) if the well does not screen out. 8. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. 9. RU coiled tubing and clean out sand plug. --------.- C:J~_LO: 3UffiJ an¿ ~un Jro ì~e Little rate benefit from ' 01 perforating job; no stimulation performed to remove LSND mud damage CD1 CD1...39/ I i ,-v' CD2-51 Ç,D1-40 CD2-52 ,/ Top of Cement -10,000' MD Top of C Sand 10,600' MD Perfs added Feb 2001 from 10,650' -10,885' MD 7" Csg Shoe 12,041' MD -~' -=--=====~ -- -=---:--:===----=-=-==---, --------- 20 mâ1;-=-sand~_ - ---- ~ t Drilled with LSND mud - 1.4" invasion Exit C Sand 10,940' MD SSSV (1882-1883, 00:3.812) NIP (1882-1883, 00:6.062) Gas Lift MandrelNalve 1 (4603-4604, Gas Lift MandrelNalve 2 (7405-7406, TUBING (0-10391, 00:4.500, 10:3.958) Gas Lift MandrelNalve 3 '10218-10219, , 00:5.984) NIP '10279-10280, , 00:5.000) PKR '10334-10335, . 00:5.970) NIP '10379-10380, , 00:5.000) WLEG '10390-10391, . 00:5.000) Perf :10650-10670) Perf :10755-10770) Perf :10780-10790) Perf :10795-10815) Perf 10830-10850) Perf 10865-10885) OPEN HOLE 12042-15438, . 00:6.125) ConocoPhillips Ala~, Inc. I 1 I . 1 .. '1 " Ilt r :;'ï",'~'~;; !;;,.-. f\,.:;<::':\ . .....'. ·t. I ---1ALPINE CD1-40 API: 501032029800 SSSV Type: WRDP Angle @ TS: deg @ Angle @ TD: 87 deg @ 15438 Reference Log: Last Tag: Last Tag Date: Casing String - ALL Description CONDUCTOR SURF CASING PROD CASING OPEN HOLE Tubing String - TUBING Size I Top 4.500 0 P,erforatiºn$",S,~l'T'Imary Interval TVD 10650 -10670 7120 - 7127 10755 - 10770 7155 -7160 10780 - 10790 7163 - 7166 10795 -10815 7167 - 7173 10830 -10850 7177 - 7182 10865 - 10885 7186 - 7190 Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type CD1-40 Annular Fluid: Size 16.000 9.625 7.000 6.125 Bottom 10391 Well Type: PROD Orig Completion: 7/16/2000 Last W/O: Rev Reason: SBHP, Pull Gauges, Set OV Last Update: 10/2/2005 Ref Log Date: TD: 15438 ftKB Max Hole Angle: 95 deg @ 11298 Top Bottom TVD Wt Grade Thread 0 121 121 62.58 H-40 WELDED 0 2976 2392 36.00 J-55 BTC-MOD 0 12042 7157 26.00 L-80 BTCM 12042 15438 15438 0.00 TVD I Wt I Grade Thread 7025 12.60 L-80 IBTM Status Ft SPF Date Type Comment 20 6 2/18/2001 IPERF 33/8" PJ/HC, 60 deg ph 15 6 2/17/2001 IPERF 3 3/8" PJ/HC, 60 deg ph 10 6 2/16/2001 IPERF 3 3/8" PJ/HC, 60 deg ph 20 6 2/15/2001 IPERF 33/8" PJ/HC, 60 deg ph 20 6 2/14/2001 IPERF 3 3/8" PJ/HC, 60 deg ph 20 6 2/13/2001 IPERF 33/8" PJ/HC, 60 deg ph Zone V Mfr V Type VOD Latch GLV 1.0 BK GLV 1.0 BK OV 1.0 BK Description Port TRO Date Run 0.188 1873 1/10/2001 0.188 1844 1/10/2001 0.250 0 9/5/2005 Vlv Cmnt 1 4603 3383 CAMCO KBG-2 CAMCO 2 7405 5182 CAMCO KBG-2 CAMCO 3 10218 6939 CAMCO KBG-2 CAMCO Øttìêr'PIÙg$,iêqÛip. ,·'êtc.) ..;; '..JEWELR'V' Depth TVD Type 1882 1703 NIP 1882 1703 SSSV 10279 6972 NIP 10334 6999 PKR 10379 7020 NIP 10390 7024 WLEG CAMCO BAL-O NIPPLE CAMCO WRDP (SER #HRS-277) ON DB-6 LOCK, 2.125" ID 9/7/2005 HES 'X' NIPPLE BAKER'S-3' PACKER HES 'XN' NIPPLE BAKER WIRELlNE RE-ENTRY GUIDE ID 3.812 2.125 3.813 3.875 3.725 3.875 WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To~ AOGCC 333 West 7th Ave. Ste. 1 O0 Anchorage, AK 99501-3539 RE · Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joe¥ Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM BLUE LINE Open Hole I I 1 Res. Eval. CH I 1 1 Mech. CH CD1-38 10-14-03 Caliper Survey ~~- 1 Rpt or 1 Color Print Name: Date · ProActive Diagnostic Services, Inc., Po Box ! 369 Stafford Tx 77477 Phon¢:(~.$1) 565-9085 Fa×:(281) 56~-~13~9 ~,-matl: pd$~m¢~o~log.¢o~ WCbStt¢: ~.~¢~o~log.¢om Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: Log Date: October 15, 2003 Field: Log No.: 5224 State: Run No.: 1 APl No.: Pipe1 Desc.: 4.5" 12.6 lb. L-80 Top Log Intvll.: Pipe1 Use: Tubing Bot. Log Intvll.: CD 1-40 Alpine Alaska 50-103-20298-00 Surface 10,412 Ft. (MD) Inspection Type ' Corrosive & Mechanical Damage Inspection COMMENTS · This log is tied into the WLEG @ 10,406' (ELMD). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. No significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions are recorded. Penetrations of less than 10% wall thickness (< 0.02") may represent minor damage to the tubing or roughness caused by a thin layer of scale buildup. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 11%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 3%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS ' No significant I,D. restrictions are recorded. Field Engineer: N. Kesseru Analyst: M. Lawrence Witness: T. Johns ProActive Diagnostic Services, ~:nc. / P.O. Box 1369, Stafford, TX 77~t.97 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS(g~.memoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-231~t PDS REPORT IOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf NS0 Well: CD 1-40 Bodv Wall: 0271 in Fiekh Alpine Upset Wall: 0.271 in Company: CanocoPhillips Alaska, Inc. Nominal LD.: 3.958 in Country: USA Survey Date: October 15, 200~ Joini Depth Pen Pen Pe~ Metal Min. j Dantage Profile No. [ (Ft.) Upset i Body ?o Loss I.D. i Cornment$ ~ ~ ( ~ o.o ~ 2 2 3.~ g 1~ ( i 0.01 3 [ / [ 3.92 , ~ la7 ' 0 [ )0 2 ~ 2 [ ] [ 0;02 , I i 7 i 290 0 ] 0.03~g_~ [ [ 3.91 8 ~ 334 0 ] 0.01 ] 3 i ~ 3.9l 9 [ 378 0 0.03 10 ~ 2 3,92 I0 [ 422 ~- 0 ]0.0~ 4 , : I -' 12 slo o [ 0,02 i 8 J 3.90 0.0! i 2 15 , 640 0 0.02 8 j I 3. 0 1 ~6 L (~ (~ o.)~ i ~ I ~ ~.B~ i ' 17 727 0= 0.02 ~ 8 2 ,J 3.89 ] ~18 77] 0 0.01 [ ~ ~ 390 28 ~211 0 0.03 j ?~ 1 3.9] 29 . 1255 , 0 ] 0.03 0 ] T 3.91 i ~0 ] 1299 0 [ 0.02 [ 8 ~ 3.91 31 i 1343 0 0.01 j 4 J I j 3.~2 ~ 32 [387 0 0.01 2 i 2 i 3:~] 33 1430 0 0.02 ] 8 1 3.98 3~ [ 1474 ~ o.o2 I (, [ ~ i 3.90 35 i 15~8 0 0,01 4 ~ I j L9I I 3~ 1~90 0 i 0.0~ Jo 3 i 3.9J 40 j ~734 , 0 0.01 ) j 2 ~3.92 41 [ 1778 0 0.01 4 i ] [ 3,86 j 42 , i822 0 0.02 8 i 2 J 3.~1 [ 42.~ , 1866 O _ 0.01 3 1 Lg~ PUP __ , 42.2 1875 0 0 0 [ ) 3 ~ SSSV ~42.~ faa0 0 o.o2 7 ~ ~3.9_2_L pup 45 ~978 0 0.02 i 8 i ~ i 3.90 i 4~ 2022 0 0.02 i 8 1 I 3.~1 i 47 2067 0 0.02 ~ 8 i ' 3,90 Page l PDS Report Overview Body Region Ana[ys]s Welk CID 1 40 Survey Date: Octobel 15, 2003 lie]d: A]pMe Too] Type: MFC 40 No. 00432 ~!!!)!yf !~ M. Lawrence ] ubi%: Nora lsd Weight Gr.<le & Ihread Nora.il) Nora Upset Uppel 4.5 ins 12.6 ppf LB0 3.958 ins 4.5 b~s 1.2 fns Penetration and Metal Loss (% wall) loss 172 78 0 0 0 0 Damage Configuration ( body 0 0 0 0 0 99 GLM 1 Damage Profile (% wall) GLM 2 147 195 GIM3 P, ottom of Survey A~ai;,sis Overview page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf LB0 We!k CD 1-40 Body Wall: 1/.271 in Fid(l: Alpine Upset Wa[[: 0.27I in Company: ConocoPhil[ips Alaska, Inc. Nominal LD.: 3.958 in Country: USA Survey Date: October 15, 2003 Joint Depth I Pen. Pen. Pen. [Metali Min. 49 21s5 ] !~ 0.02 . 8 52 2287 i 0 0.02 B 2 53 3.91 54 2372 ~ 0 i 0.03 9 I 3.90 55 24]6 I 0 j0.02 9 1 3.90 56 2459 ~ / 0 [ ~10~ ' 57 2503 0 i 0.01 5 58 i 2547 0 0.02 8 i 2 3.90 59 [ 2591 0 0.02 8 1 3.90 0.01 , 4 60 i 2635 0 61 2679 0 62 272~ 0 63 L 2768 . 0 64 2812 0 Comments 0.02 ' ' ' ~q i 8 i I 3'90 i ~i 65 2856 ~ i 0,0! i ~ i ] ~:9~ 66 2900 0 0.02 [ 9 ] I 3.88 67 ~944 0 0.02 i 9 [ I 3.89 fig 2986 0 ).0! [ ~ ] ! }:9 69 3031 0 0.0! j 4 1 3.90 70 , 3075 B . 0.01 [ 4 I . 3.92 71 72 73 74 3119 0 0.02 [ 8 3163 o o.o2 I 8 3207 0 0.01I 4 ~251 0 0.02 8 ~295 0 i 0.03 11 3339 0 0.02 8 3382 0 0.0[ ~ 4 0 002 8 0 0.02 9 0 0.02 6 0 [ 0.02 ' 8 3.90 3.90 3.88 (% wall) i ) 50 100[ 75 76 77 78 3426 , 79 , 3470 80 3514 ail 3558 3.89 3,91 3,9o i3.89 i3.9o 3.91i ] 3.92 ~82 . 3603 0 [ 0.!)! ~ 84 , 3692 , 0 : 003 !0 85 , 3734 0 0.0l 2 [ 1 L90 86 3778 0 0.02 8 ] ~ ] ~9] 87 ~822 0 0.02 8 88 3866 0 0.02 8 [ 2 i 3.83 89 3911 11 4996 0 0,03 10 ~ 2 3.88 92 jQ~0 0 0.03 ~ 1 1 3.91 95 4168 0 ] 0.01 ] 4 3 96 4212 0 ] 0.01 97 4253 0 ] 0.01 4 2 Penetration Body Metal Loss Body Page 2 Pipe: Body Wa[h Upset Wall: Nominal PDS REPORT JOINT TABULATION SHEET 4.5 in 12,6ppf t 80 Welh CD I 40 0.271 in Field: Alpine 0.271 in Company: ConocoPhilNps Alaska, Inc. 3.958 in Country: USA Survey Date: October 15, 2003 50 100 i I05 [ 462o ;1661 4705 4749 4792 4B35 4879 0,01 [ ) 2 3.8A3 _ 112 ~ 4921 l [ 3 4963 i t 4 5008 , i 16 [ 5096 1[8 5183 !lc) ~227 120 5271 _ 121 5/15 125 L 548(, 553!) 128 !29 LI~ ~ ~ 5834 134 5~78 i35 5922-- ~36 595~ 137__ 5982 138 ~ 6012 139 i 6043 140 [ 6 74 142 [ 6134 144 [ 615)6 o 0.02 i 8 0 L ~,ok 3.89 L89 Penetration Body Metal Loss Body Page 3 PDS REPORT K)INT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L 80 Well: CD 1-40 Body Wall: 0.271 in Field: Alpine Upset Wa!l: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I,D.: 3.958 in Countw: USA Survey Da'Le: October 15, 2003 ]oi~t Deplh Pen. Pen. No. (Ft.) Upset Body % Loss j I.D. I Conunent$ I (Ins.) (ins.) % I (fns') ! 0 145 622/ 0 0.0l I 389 146 627l 0.0l 3.85 147 63t3 0 o401 0 j --~-~'4 s 0 oo~ ~ Damage Profile (% wall) I54 ~f20 ~[ 0 0.02 j 8 __ I 39~, 155 6664 0_ [ 0.02 8 1 [ 3.92 J56 6708 157 6752 158 6796 0 0,02 J 8 ] 392 , 0 0 02 8 2 i 3 86 161 6923 0 j 001 4 1 391 163 7012 ().OI i L87 ~04 7056 0 ~Q,h~' ~ 8 'l I 3.90 ~65 i 7o9g o ' 0.02 g 167 ~ 7185 0 [ 0.03 10 l 168 7229 0 0.02 j 8 j I ~ 3.9~ ~J t69 . 7273 . 0 ~ 0.01 ] 2 3.92 ~70 7317 0 I 0.02 7 I i 3.90 [ ~1 I . 7405 0 O.Ol ! 4 I I ~.91 PUP 179 [ 7736 0 i 0.01 180. 7780 0 . 0.02 ~81 z8~9 o j O,Ol [87 L 7862 0 ] 0.0t 183 i 7906 i 3.92i 3.92 ~.92i 0 001 ~ 1 i 3.90 i Page 4 Penetration Body Loss Body PDS REPORT JOINT TABULATION SHEET Pipe: Body Wail: Upset Wa/l: Nominal I.D.: 4.8 iii [ 2,6 ppf [ 80 We[[: CD I 40 0.271 in Field: Alpine 0.271 in Company: ConocoPhi[]ips A[asRa, Inc. 3.958 in Country: USA Survey Date: October t 5, 2003 joint Depth No. (Ft.) 92 830l J97 [ 85~! 198 8565 !~9~ 200 Pen. Pen. Pen. ~ta] [ Min. Upset j Body % Loss j I.D. [ Comments (ms.) [(Ins.) % (Ins,) [ [ *.92 l 0 [ 0.01 f 3 ] 1 3.9I o 0.02 6 ~ 3.9~ 0 0.01 4 1 L90 Damage Profile (% wall) 50 100 i ii 201 202 2O3 i 8786 204 i 8830 2(35 i 88773 206 [ 89[4 207 i 8955 8609 . 0 0.02 9 8652 0 i 0.02 8 8697 0.0[ 3 8741 0,02 6 0 [ 0.01 4 0 0.01 2 0 [ 0.01 4 i 3.92[ i3.92 [ 3.93 [ 3.88~ 3.92 1 3.91 208 j 8996 0 j o.01 4 1 209 9038 0 [ 0.0I 210 9078 0 [ 0.01 4 1 211 9120 212 9161 213 9203 2~4 9244 215 9283 j 216 9324 217 [ 9365 2[8 i 9407 ' 219 i 9448 0 0.01 220 9489 0 0 lo.31 j I 0-01 4 [0.01 4 I 3.9~ i0.0t i 4 i 0.01 2 I 3,91 iO.Ol 4 [ I :3.9o [ 0.0( 4 0.01 I 3 3.90 3.9I 3.88 4 [ I 3.88 3 j I 3.91 L 22[ [ 9531 , i B.01 i 2 i I 3.86 222 9572 0 0.01 I 5 i 1 3.92 223 9613 0 0.01 [ 4 I , 3.9I i 224 9652 0.03 10 1 3.88 225 9696 0.02 [ ~ 3.92 226 974I 0 0.02 [ 1 3.9[ 227 9785 0 0.02 t [ 3.92 228 9829 0 [ 002 ! i ~,9[ i 229 9873 0 0.02 2 [ 388 [ 2~0 9916 0.02 [ I [ 3.88 ~ , . [ Lt. Deposits. 231 9960 0.01 [ I ] 3.92 [ 232 10004 0 [ 0.01 [ I 3.92 2~4 10091 0 0.01 I [ 3.89 235 t0135 0 0.02 2 [ 3.89 Lt Deuosits. 236 ~ 10179 0 0.01 I 3.79 2~1 [ 10222 0 0.01 4 l 379 PUP Lt. Deposils. j 2362 10232 0 0 0 Q Nf~ ~M 3 (La~ch~6:~O) 236.3 [ I0239 0 t 0.01 4 2 i ~.93 j PUP 2~71 [ 10294 0 [ 0 0 0 [ 3.8l [ X N{P ii Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wa!l: Upset Walk Nominal I.D.: 4.5 in 126 ppf b80 WeJ[: CD 1 40 0.271 in FieJd: AJpine 0.271 in Company: ConocoPhil[ips Alaska, Inc. /.958 in Countr,/: USA Surve;, Date: October [5, 2003 238.1 10339 ?38.2 10350 238.3 10354 239 10~64 2~9.1 10395 2~9.2 10397 2~9.3 10406 Po~. ~4&~i[ ~i~. [ % j Loss I.D. Comments I0 [ i ~,!~R J k~,De~osts. ' Dai~iage P~ofiie (% wall) [0 50 100j l 3.73 XN NiP Alpine Field CE)I~ Produc~ C_x)r~etion Sd~rr~ic 1~' C_.a'nlaor to 121' sssv- Immi~d & q,m j ~1/~' ~e to'FD at 15,438' .. '" - ;~1, ,~.:";'. Y..!~': :' ,~"L>'r. ': "~;. , ~ ~ ~ 1~ ~7,111' SS Permitto Drill 1990440 MD 15438 TVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. COLVILLE RIV UNIT CD1-40 Operator PHILLIPS ALASKA INC. 7184 Completion Dat 711612000-- .... Completion Statu 1-OIL APl No. 50-103-20298-00-00 Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N_..9o Sample N._9o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ~T~. Fit ~~' Pre Pressure Name Interval Log Log Run OH I Scale Media No Start Stop CH 2 Blu 1 CDPJART-TVD 2/5 FINAL CDPJART-MD 2/5 FINAL 9754 1 SRVY RPT SRVY RPT · CDR-MD FINAL ADN-MD FINAL ADN-TVD FINAL CDR-TVD FINAL CDR/ADN COMPOSIT 5 FINAL 9219 2-4 ADN-TVD 2/5 FINAL ADN-MD 2/5 FINAL 9389 1-3 Production Profile 2 FINAL (data taken from Logs Portion of Master Well Data Maint) 2950 12055 Open 9400 179585 Open 75 10445 Case 10570 13022 Case 2950 12055 Open 2950 15438 Open 2400 7200 OH 2973 154O0 OH OH 115 15438 OH 115 12055 OH 2986 12019 OH 10000 11759 OH 6800 7178 OH 2400 7200 OH 10022 11815 OH OH 6800 7200 OH 10000 11800 OH OH 10570 13020 ch Received 6/23/1999 7/29/1999 3/30/2001 11/23/1999 10/3/2000 10/3/2000 10/3/2000 10/3/2000 8/10/2000 6/4/1999 6/23/1999 6/23/1999 6/23/1999 6/23/1999 6/23/1999 6/23/1999 11/23/1999 11/23/1999 11/23/1999 3/15/2001 Dataset Number Comments 09219 ,,'~2~50-12055 09264 9400-179585 09976~0570-13022 09389V~50-12055 09754~.,-2950-15438 2400-7200 5/18/99, 2973-15400 5/18/99, 9754 ,..-"SCH LUM IMP/GR/CDR/ADN SCHLUM 115-15438. SCHLUM 115-12055. 2986-12019 10000-11759 6800-7178 2400-7200 10022-11815 9219 ~s~HLuM CDR/ADN 10000-11800 REV 2 9389~CHLUM CDR/ADN-PDC REV 2 10570-13020 BL, Sepia Permitto Drill 1990440 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. COLVILLE RIV UNIT CD1-40 Operator PHILLIPS ALASKA INC. APl No. 50-103-20298-00-00 MD 15438 TVD 7184 Well Cores/Samples Information: Completion Dat 7/16/2000 9976 Completion Statu 1-OIL FINAL 10570 13020 Current Status 1-OIL UIC N 3/15/2001 997~0570-13020 Digital Data Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y ~1~ Chips Received? ~ Analysis ~ R ~.r.~.iv~.d ? Daily History Received? L~/N Formation Tops ~_~N Comments: Compliance Reviewed By: Date: ProActive Diagnostic Services, inc. WELL L TRANSMITTAL To: AOGCC 333 West 7th Ave. Ste. 100 Anchorage, AK 99501-3539 RE ' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Juey Burton/Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[SI OR CD-ROM FILM BLUE LINE Open Hole I I 1 Res. Eval. cH 1 I 1 Mech. CH .............................. Caliper Survey I Rpt or 1 Color Signed' Print Name: Date' PzoActive Diagnostic Servicesr Inc.r 310 K Stzeet Suite 200, Anchozage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pclsanchorage~memorylog, com Wcbsitc: ' ' ~ = ~ ~ Z t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ " "Suspen~l" Operational shutdown_ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate X Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 55 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Colville River Unit 4. Location of well at surface 8. Well number 502' FNL, 2300' FWL, Sec. 5, T11 N, R5E, UM (asp's 385724, 5975629) CD1-40 At top of productive interval 9. Permit number / approval number 1638' FNL, 1340' FEL, SEC. 7, T11 N, R5E, UM (asp's 382003, 5969273) 199-044 At effective depth 10. APl number 50-103-20298 At total depth 11. Field / Pool 648' FNL, 894' FWL, Sec. 17, T11 N, R5E, UM (asp's 384188, 5964948) Alpine Oil Pool 12. Present well condition summary Total depth: measured 15438 feet Plugs (measured) true vertical 7184 feet Effective depth: measured 15438 feet Junk (measured) true vertical 7184 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 66' 16" 10 cu yds Portland Type 3 66' 66' Surface 2921' 9-5/8" 530 sx AS III LW, 230 sx Class G 2976' 2392' Production 11 987' 7" 317 sx Class ~ 12042' 7157' Perforation depth: measured 10650'-10670', 10755'-10770', 10780'-10790', 10795'-10815', 10830'-10850' truevertioal 7120'-7127, 7155'-7160', 7163'-7166', 7168'-7173', 7177'-7182'RECEIVED Tubing (size, grade, and measured depth 4-1/2",12.6 ppf, L-80, Mod-BTCFEB 0 2_001 Packers & SSSV (type & measured depth) Camco WRDP SSSV @ 1882' MD Alaska Oil & Gas Cons. Commission Baker S-3 Packer at 10,334' MD Anchorage 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X 14. Estimated date for commencing operation 15. Status of well classification as: February 10, 2001 16. If proposal was verbally approved Oil __X Gas__ Suspended __ Name of approver Date approved Service 17. I hereby,certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Michael Erwin @ 265-1478. Signe Title: Alpine Production Engineer Date Michael D. IErwin FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity_ BOP Test ~ Location clearance__ ,._~D ~ Mechanical Integrity Test__ Subsequent form required 10- L,~,~_~ ~, ___ _A_pp_[oved by order of the Commission ~/ /~/b '~-.(.,(//)*o-¢~~ Commissioner Date ......................... Form 10-403 Rev 06/15/88 · ORi®I 4AL ~'~SUBMIT IN TRIPLICATE Proposed Work Program CD1-40 Summary of Planned Activities 1 Slickline to drift, tag and run dummy guns to verify no obstructions are present. 2 CTU convey 3-3/8" HSC perf guns loaded 6 spf and perforate the following casing intervals. 10,830 - 10,850' MD 7177' - 7182' TVD 10,795 - 10815' MD 7168' - 7173' TVD 10,780 - 10790' MD 7163' - 7166' TVD 10,755 - 10770' MD 7155' - 7160' TVD 10,650 - 10,670' MD 7120' - 7127' TVD Depth control from Schlumber LWD-Density dated 5/18/1999. 3 Return the well to production. RECEIVED F£B 0 2, Z00 Alaska Oil & Gas Cons. Commissior~ Anchorage C T Drilling Wellhead Detail ~~'-CT Injector Head ~- Stuffing Box (Pack-Off), 10,000 psi Working Pressure T®ll-,-I: I '-- 7" Riser Methanol Injection 8t(jSnn"7~LA Ou'!ck'- I' ' '1 · , i Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure I 1 Alignment Guide Flange _ ~ ,~~5") I ~ "' ~ Cutters or 7-1/16", 5M Ram Type Dual _-~ ~ ~ ,~ · P~l Combination Cutter/Blinds Gate BOPE "'"'~ ~ Sli[~ / Pipe rams Flanged Fire Resistant Man~e Kelly Hose to Dual HCR Choke Manifold Manual Valves Ddiling spool 7-1/16', 5M ~ by 7-1/16', 5M Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Master Valve · 0.458' (5.5') 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8' Annulus 13-3/8' Annulus RECEIVED FEB 02 200! Alaska Oil & Gas Cons. Commissior~ Anchorage 9/26/00 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 548 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job if Log Description Date BL Sepia Prints CD CD1-40 20347 GRICDRIADNIIMPULSE '~ 4:J~l~c[ 000715 1 CD1-40 20347 MD CDR "~n-.,.~*"""i-. 000715 I 1 ,~ ~-..-- 000715 I 1 CD1-40 20347 TVD CDR V SIGNED'~ ~'~__~...~~ DATE: 0CT ~J ~ ~000 Naska 0il & Gas Cons. C0maissi0~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 551-8317. T~JI~JJ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r~ Gas E] Suspended r~ Abandoned [~ Service · 7. Permit Number 2. Name of Operator 1~i 99-44 Phillips Alaska, Inc. 3. Address ' [?~~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~ 50-103-20298-00 4. Location of well at surface .... ~ ~ ~ i' 9. Unit or Lease Name 502' FNL, 2300' FWL, Sec. 5, T11N, R5E, UM (ASP: 385724, 5975629) i g,?4~. ~:;:i ; Colville River Unit At Top Producing Interval ~ '.'~ 'i. ~ 1~). Well Number 1638' FNL, 1340' FEL, Sec. 7, T11N, R5E, UM (ASP: 382003, 5969273) i -'~"/~&'~': CD1-40 At Total Depth ~ \ '?ii~ i,:: 11. Field and Pool 648' FNL, 894' FWL, Sec. 17, T11N, R5E, UM (ASP: 384188, 5964948) ~. ........ - .... Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool 37' RKB feetI ADL 25558/25559 {2. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions May 15, 1999 July 15, 2000 July 16, 2000I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 15438' MD /7184' TVD 15438' MD /7184' TVD YES r~] No I~I 1882' feet MD 896' 22. Type Electric or Other Logs Run G R/Re siN eut/Den s 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD i CASINGSIZE WT. PERFT. GRADE TOP BO-I-rOM HOLE SIZE CEMENTING~EOOR~ I AMOUNT PULLED 16" 62.5# H-40 Surface 121' 42" lO cu yds Portland Type 3 9.625" 36# J-55 Surface 2976' 12.25" 530 sx AS III LW, 230 sx Class G 7" 26# L-80 Surface 12042' 8.5" 317 sx Class G ORIG IINlhk 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 10390' 10334' 6.125" open hole completion from 12055'-15438' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTER~L~? F!V ~A~'~)UNT & K,ND OF MATER,AL USED N/A :-,,, 1.~[ C-L 0 "-" ~ ~7. PRODUCTION TEST Aiask~ Date First Production Method of Operation (Flowing, gas lift, etc.) Waiting on Facility Start-Up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > 'l~low Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL iOIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit In duplicate 29. Alpine D Base Alpine NAME GEOLOGIC MARKERS MEAS. DEPTH 10540' 10942' TRUE VERT. DEPTH 7082' 72O2' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 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. Signed JJ~,~'~,~ ~, ' G.C. Alvord Title A p ne Dr Ilin.q Team Leader Questions? Call Scott Reynolds 265-6253 INSTRUCTIONS Prepared by Sharon A//sup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24.' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23.' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". f~ E C E I V E' D Form 10-407 Alaska'. '3i[ & 6,% Cons. /:,nchoracJe, Date: 08/28/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-40 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: ALPINE SPUD:05/15/99 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20298-00 05/15/99 (D1) MW: 8.9 VISC: 145 PV/YP: 16/35 APIWL: 11.0 TD/TVD: 1251/1216 (1251) WIPER TRIP AT 1820' SUPV:DONALD LUTRICK Move rig to CD1-40. MIRU. Function test diverter. Drilling from 121' to 1251' UPCOMING OPERATIONS:TD WELL 05/16/99 (D2) MW: 9.6 VISC: 140 PV/YP: 21/50 APIWL: 9.8 TD/TVD: 2986/2398 (1735) RIH W/ CSG SUPV:DONALD LUTRICK Drilling from 1251' to 2986' Wiper trip to 1100' Swabbing at 1100'. Pump out. RIH. No problems. UPCOMING OPERATIONS:CEMENT 05/17/99 (D3) MW: 9.6 VISC: 38 PV/YP: 8/13 APIWL: 10.0 TD/TVD: 2986/2398 ( 0) KILL DRILL SUPV:DONALD LUTRICK PJSM. RIH w/9-5/8" casing. Pump 9-5/8" casing. ND diverter. NU BOPE and test to 300/3500 psi. UPCOMING OPERATIONS:CSG TEST, LOT AND DRILL AHEAD 05/18/99 (D4) MW: 9.4 VISC: 47 PV/YP: 9/27 TD/TVD: 3806/2887 ( 820) DRLG AT 3900' SUPV:DONALD LUTRICK APIWL: 7.5 Kill drill. Clean out cement to FC at 2887'. Drill out float equipment, cement and 20' new formation to 3006' Performed FIT, 16 ppg EMW. Drilling from 3006' to 3086' Performed open hole LOT, 15.4 ppg EMW. Drilling from 3086' to 3806'. Motor not responding directionally as expected. UPCOMING OPERATIONS:DRLG 05/19/99 (D5) MW: 9.5 VISC: 47 PV/YP: 10/25 APIWL: 5.8 TD/TVD: 5357/3871 (1551) DRLG AT 5896' SUPV:DONALD LUTRICK Drilling from 3806' to 5262'. Wiper trip to 3933' Light swabbing. Wash and ream from 5200' to 5262'. Drilling from 5262' to 5357' UPCOMING OPERATIONS:DRILL 05/20/99 (D6) MW: 9.4 VISC: 44 PV/YP: 8/25 TD/TVD: 7041/4952 (1684) WIPER TRIP @ 7260' SUPV:DONALD LUTRICK Drilling from 5357' to 7041' UPCOMING OPERATIONS:DRILL APIWL: 4.8 Date: 08/28/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 05/21/99 (D7) MW: 9.5 VISC: 46 PV/YP: 7/29 TD/TVD: 8042/5575 (1001) DRLG SUPV:DONALD LUTRICK Drilling from 7141' to 8042' UPCOMING OPERATIONS:DRLG APIWL: 5.4 05/22/99 (D8) MW: 9.6 VISC: 44 PV/YP: 9/22 APIWL: 4.2 TD/TVD: 9114/6248 (1072) DRLG SUPV:DONALD LUTRICK Drilling from 8042' to 9114' UPCOMING OPERATIONS:BHA CHANGE FOR BUILD AND TURN 05/23/99 (D9) MW: 9.7 VISC: 46 PV/YP: 10/25 APIWL: 4.0 TD/TVD:10116/6876 (1002) SUPV:DONALD LUTRICK Drilling from 9114' to 10116'. POH. Slight swabbing at 9700' UPCOMING OPERATIONS:RIH W/ BUILD ASSEMBLY 05/24/99 (D10) TD/TVD:10116/6876 ( SUPV:DONALD LUTRICK MW: 9.8 VISC: 44 PV/YP: 8/24 0) DRILLING AT 10,280' APIWL: 4.8 POH to 3823' Tight. Ream out tight spot at 3823' PJSM. MAD pass from 9085' to 9522' RIH to 10100' Hole packed off. Worked pipe out of hole to 9750' Wash and ream from 9750' to 10116' UPCOMING OPERATIONS:TD WELL 05/25/99 (Dll) MW: 9.7 VISC: 48 PV/YP: 7/34 TD/TVD:10961/7203 ( 845) DRLG AT 11,160' SUPV:DONALD LUTRICK Drilling from 10116' to 10961' UPCOMING OPERATIONS:TD WELL. WIPERTRIP FOR CSG. APIWL: 4.4 05/26/99 (D12) "MW: 9.7 VISC: 45 PV/YP: 9/22 APIWL: 4.4 TD/TVD:l1718/7180 ( 757) CIRC @ ll,841'MD - 7,172'TVD - WAIT ON ORDERS SUPV:MIKE WHITELEY Drill from 10961' to 11717' UPCOMING OPERATIONS:DRILL AHEAD 05/27/99 (D13) MW: 9.6 VISC: 45 PV/YP: 10/21 TD/TVD:l1850/7172 ( 132) RIH WITH BIT ~4 SUPV:MIKE WHITELEY Drill from 11718' to 11850' UPCOMING OPERATIONS:DRILL TO TD APIWL: 4.4 05/28/99 (D14) MW: 9.7 VISC: 43 PV/YP: 9/21 APIWL: 4.8 TD/TVD:12055/7156 ( 205) LAYING DOWN BHA SUPV:MIKE WHITELEY Finished testing BOPs. Floor valve leaked, tested back up valve. Pulled test plug. Kick drill, no problems, wash 120' to bottom at 11850' Drill from 11850' to 12055' TD. Date: 08/28/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 UPCOMING OPERATIONS:RUN 7" CSG 05/29/99 (D15) TD/TVD:12055/7156 ( SUPV:MIKE WHITELEY MW: 9.6 VISC: 41 PV/YP: 7/11 APIWL: 6.2 0) WAIT ON CEMENT - FLOW OUT ANNULUS AFTER CEMENTING POOH, tight at 3820'. Clean up hole from 3820' to 3780' Ran 7" casing to 10950'. Circ and cond mud for cement job. UPCOMING OPERATIONS:INSTALL PACKOFF, LAND TUBING HANGER W/ ONE JT 4.5" TBG , NU TEST TREE, ECT. 05/30/99 (D16) TD/TVD:12055/7156 ( SUPV:MIKE WHITELEY MW: 9.2 VISC: 0 PV/YP: 0/ 0 0) RIG RELEASED @ 12:00 HRS 5-30-99 APIWL: 0.0 PJSM. Pump cement. WOC, weak flow out 7" annulus. Shut in well. Installed 7" pack off and test to 5000 psi. ND BOPs' NU tree and test to 3500 psi. Freeze protect well. Released rig @ 1200 hrs. 5/30/99. UPCOMING OPERATIONS:MOVE RIG TO CD1-01 07/11/00 (D17) MW: 9.2 VISC: 49 PV/YP: 11/28 APIWL: 5.0 TD/TVD:12055/7156 ( 0) SWAPPING OUT OLD 9.2 PPG FLO PRO WITH NEW 9.2 PPG FLO SUPV:REYNOLDS/REILLY Move rig and spot over CD1-40. Accept rig 0700 hrs. 7/11/00. PJSM. ND tree, NU BOPE and test to 250/3500 psi. Displace brine with Flo Pro. Drill float collar, cement, float shoe and new hole to 11962' 07/12/00 (D18) MW: 9.2 VISC: 46 PV/YP: 9/18 APIWL: 4.0 TD/TVD:12230/7145 ( 175) SLIDING @ 12,649' SUPV:REYNOLDS/REILLY Drill out float equipment, drill new hole to 12073'. Circ and cond. mud. Perform FIT, 12.5 EMW. PJSM. Displace to Flo-Pro. Pump out to 10795'. Circ bttms up, check flow, static. TOOH. Install corrosion ring. RIH to 12073'. Drill from 12073' to 12230' 07/13/00 (D19) MW: 9.2 VISC: 46 PV/YP: 13/25 APIWL: 4.0 TD/TVD:13888/7140 (1658) DRILLING AHEAD @ 13,888' SUPV:REYNOLDS/REILLY Drill from 12230' to 13473'. Circ sweep. Pump out to shoe, 12042', check flow. Circ lo vis sweep. RIH. 07/14/00 (D20) MW: 9.2 VISC: 47 PV/YP: 12/22 APIWL: 3.9 TD/TVD:14742/7151 ( 854) DRILLING AHEAD @ 15048' SUPV:REYNOLDS/REILLY Drill from 13473' to 14142'. Replace swivel packing. Drill from 14142' to 14742' ECEiVED · °l ~,'U., Date: 08/28/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 07/15/00 (D21) MW: 9.2 VISC: 49 PV/YP: 10/24 APIWL: 4.0 TD/TVD:15438/7184 ( 696) CIRCULATING FLO-VIS PILL. LOSSES @ 30 BPH @ 0500 HRS. SUPV:REYNOLDS/REILLY Drill from 14742' to 15162' Pump lo vis/high vis sweep. Rec. rot. sweeps to surface. Drill from 15162' to 15438' Circ sweep until clean. Pump out to 13376'. Check flow RIH. CBU. PJSM. Displace mud with brine. 07/16/00 (D22) MW: 9.2 VISC: 28 PV/YP: 1/ 1 APIWL: 0.0 TD/TVD:15438/7184 ( 0) DISPLACING WELL WITH INHIBITED BRINE. SUPV:REYNOLDS/REILLY Displace mud with brine. TOOH to shoe. Monitor losses @ 12036'. RIH to 13283' Spot flo-vis pill. Monitor well. TOOH to 11842'. Monitor well, 9.6-12 bph losses. TOOH to 6100' PSJM. Run 4.5" tubing. 07/17/00 (D23) MW: 0.0 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:15438/7184 ( 0) N/A SUPV:REYNOLDS/REILLY Install 2-way check & test hanger seals t/5000 psi. ND BOPE. NU tree and test to 5000 psi, good test. Pull 2-way check. Set packer. Displace well w/brine and diesel. Set BPV and secure well. Release rig @ 0930 hrs. 7/17/00. SURVEY CALCULATION AND FIELD WORKSHEET Job No, 0451-05050 Sidetrack No, Page I of 9 · ~' [ ! [~ -' I =~'~ Company ARCO ALASKA INC, Rig Contractor & No, DOYON DRILLING - 19 Field ALPINE . . . ,~ -,~~ Well Name & No, CD#1/40 Survey Section Name ANADRILL BHI Rep, CHIP MILCHAK/BOB HENDERSON i i WELL DATA , , Target TVD (FT) Target Coord, N/S Slot Coord, N/S -501,13 Grid Correction -0,890 Depths Measured From: RKB ~ MSL [~ SS~- Target Description Target Coord, E/W Slot Coord, F_,JW 2301,84 Magn, Declination 0,000 Calculation Method MINIMUM CURVATURE , Target Direction (DD) Buil~Walk\DL per: lOOft~ 3Omni lOm~ Vert, Sec, Azim, 151,99 Magn, to Map Corr, 0,890 Map North to: OTHER ii ii SURVEY DATA Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool "N(+)/'S(-) E(+) /W(-) DL Build (+) Right (+) Comment Depth Angle Direction Length TVD Section Type . (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) UNKN 0.00 0,00 0,00 0,00 0,00 0,00 0,00 0,00 TIE IN POINT 15-MAY-99 MWD 115,00 0,00 0,00 115.00 115.00 0,00 0,00 0,00 0,00 0,00 MWD 200,30 0,39 191,90 85,30 200,30 0,22 -0,28 -0,06 0.46 0,46 MWD 276,94 1,46 196,40 76,64 276,93 1,12 -1,48 -0,39 1,40 1,40 MWD 380,60 2,72 191,90 103,66 380,52 3,95 ' -5.15 -1.27 1.22 1,22 MWD 471,08 4,64 193,90 90,48 470.81 8,32 -10,80 -2,59 2,13 2,12 .... MWD 559,47 7,50 193,40 88,39 558,69 15,31 -19,89 -4,79 3,24 3,24 -0,57 MWD 651,03 9,92 192,40 91,56 649,19 25,80 -33,40 -7,87 2,65 2,64 -1,09 MWD 742,26 11,33 194,70 91,23 738,85 38,37 -49,75 -11.83 1.61 1,55 2,52 MWD 831,31 13,86 197,40 89,05 825,75 52,28 -68,39 -17,24 2,92 2,84 3,03 ,,, MWD 917,59 16,00 198,90 86,28 909,12 67,66 -89,50 -24,18 2,52 2,48 1,74 MWD 1006,84 18,81 201,50 89,25 994,27 85,41 -114,53 -33,44 3,27 3,15 2,91 MWD 1097,16 23,26 204,30 90,32 1078,56 105,78 -144,35 -46.12 5,05 4,93 3.10 MWD 1192,66 27.34 205,70 95,50 1164,88 130,30 -181,31 -63,40 4,32 4,27 1,47 16-MAY-99 MWD 1287,79 29,92 206,00 95,13 1248,37 157,18 -222,33 -83.28 2,72 2,71 0,32 MWD 1382,93 32,19 206,60 95,14 1329,87 185,80 -266,32 -105,03 2,41 2.39 0.63 MWD 1478,78 36,76 208,80 95,85 1408,87 216,31 -314,31 -130,29 4,94 4,77 2,30 MWD 1573,33 40.08 209,70 94,55 1482,93 248,06 -365,56 -159,01 3,56 3,51 0,95 MWD 1669,00 42,63 210,40 95,67 1554,74 281,49 -420,26 -190,67 2,71 2,67 0,73 MWD 1763,64 45,19 210,50 94,64 1622,92 315,82 -476,84 -223,93 2,71 2.70 O, 11 MWD 1858,07 48,72 209,60 94.43 1687,36 352,34 -536,57 -258,47 3,80 3,74 -0,95 MWD 1953,42 48,84 209,60 95,35 1750,19 390,76 -598,93 -293,90 0o13 0,13 0,00 MWD 2048,26 53,82 211,20 94.84 1809,44 429,50 -662,76 -331,38 5,41 5,25 1,69 MWD 2143,82 53,05 210,40 95,56 1866,37 469.25 -728,68 -370,68 1,05 -0.81 -0,84 iii SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-05050 Sidetrack No. Page 2 of 9 · · _= [l_rr] =- I :=['--"~ Company ARCO ALASKA INC. Rig Contractor & No. DOYON DRILLING - 19 Field ALPINE Well Name & No, CD#1/40 Survey Section Name ANADRILL BHI Rep. CHIP MILCHAK/BOB HENDERSON i i i ii i WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -501,1,3 Grid Correction -0,890 Depths Measured From: RKB ~] MSL ~ SS~ Target Description Target Coord, E/W Slot Coord, E/W 2301.84 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft[-){ 30m0 lOm~ Vert. Sec. Azim. 151.99 Magn. to Map Corr. 0.890 Map North to: OTHER i SURVEY DATA Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Type Depth Angle Direction Length TVD Section N(+) / $(-) E(+) / W(-) DL (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per lO0 F'q Drop (-) Left (-) MWD 2238,91 52.35 211.10 95.09 1923.99 508.48 -793.69 -409.36 0.94 -0.74 0.74 · MWD 2334,25 51.88 210,80 95,34 1982,54 547,28 -858.22 -448,06 0,55 -0,49 -0.31 MWD 2429,13 51,34 210,70 94,88 2041,46 585,84 -922,13 -486,08 0.58 -0.57 -0.11 MWD 2524,75 51.12 210.60 95.62 2101,33 624,62 -986.27 -524,09 0.24 -0.23 -0,10 MWD 2619,45 50,54 211.00 94,70 2161.15 662.64 .1049.33 -561,68 0,69 -0,61 0,42 ......... MWD 2714,20 50.09 210,80 94,75 2221,65 700.29 '1111.90 -599,12 0,50 -0,47 -0.21 .... MWD 2810.20 49.73 21 O, 10 96,00 2283,48 7,38,71 -1175,21 -636,34 0.67 -0,38 -0.73 ,. MWD 2904.85 49.02 210,20 94,65 2345,10 776.61 -1237,33 -672.43 0.75 -0,75 O, 11 ~ MWD 2926,34 48.82 210,60 21,49 2359.22 785,09 -1251.30 -680,62 1,68 -0.93 1.86 18-MAY-99 MWD 2995.85 48,22 209,20 69,51 2405.27 812,75 -1296.44 -706,58 1,74 -0.86 -2,01 MWD 3089,66 48.12 209,60 93.81 2467.83 850,40 -1357,34 -740.90 0,34 -0.11 0.43 MWD 3185,04 48.20 207,00 95,38 2531,46 889,82 -1419,90 -774,58 2.03 0,08 -2.73 - MWD 3280,10 49,54 205,80 95,06 2593,99 931,49 -1484,03 -806,41 1,70 1.41 -1,26 MWD 3375.42 50.73 204;00 95,32 2655.09 975.62 -1550.39 -837.20 1.91 1.25 -1,89 ~ MWD 3471.39 51,02 205.00 95.97 2715.65 1020.93 -1618.14 -868.07 0.86 0.30 1.04 MWD 3566.79 58.61 207.00 95.40 2770.58 1066.66 -1688.13 -902.28 8.14 7.96 2.10 MWD 3662.21 61.41 210.10 95.42 2818.28 1112.16 -1760.69 -941.80 4.07 2,93 3.25 19-MAY-99 MWD 3755.36 59.06 214.00 93.15 2864.53 1152.53 -1829.22 -984.68 4.42 -2.52 4.19 MWD 3850.43 56.85 212.20 95.07 2914.98 1191.44 -1896.71 -1028.68 2.82 -2,32 -1.89 MWD 3945.85 53.82 211.80 95.42 2969.24 1230.67 -1963.25 -1070.27 3.19 -3.18 -0.42 MWD 4042.08 51.77 211.60 96.23 3027.43 1269.32 -2028.46 -1110.54 2.14 -2.13 -0.21 MWD 4137.43 51,03 212.20 95.35 ~.91 1306.68 -2091.72 -1149.92 0.92 -0.78 0.63 MWD 4232.40 49.94 210.90 94.97 3147.34 1343.79 -2154.15 -1168.26 1.56 -1.15 -1.37 i MWD 4327.78 50.70 211.00 95.38 3208,24 1381.64 -2217.11 -1226.01 0.80 0,80 O. 10 i iii SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-05050 Sidetrack No. Page 3 of 9 · '- [11~ = I =~"~ Company ARCO ALASKA INC. Rig Contractor & No. DOYON DRILLING - 19 Field 'ALPINE Well Name & No. CD#1/40 Survey Section Name ANADRILL BHI Rep. CHIP MILCHAK/BOB HENDERSON WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -501.13 Grid Correction -0.890 Depths Measured From: RKB ~] MSL~ SSt- Target Description Target Coord. E/W Slot Coord. E/W 2301.84 Magn. Declination 0.000 ' Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m~ 10m ~] Vert. Sec. Azim. 151.99 Magn. to Map Corr. 0.890 Map North to: OTHER SURVEY DATA' , Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'r) (FT) (F"I~ (FT) (per ~00 F'r)Drop (-) Left (-) MWD 4422.82 50.02 210.00 95.04 3268.87 1419.87 -2280.16 -1263.15 1.08 -0.72 -1.05 '~. MWD 4517.92 50.69 209.20 95.10 3329.55 1459.10 -2343.84 -1299.32 0.96 0.70 -0.84 ,, MWD 4613.93 50.62 209.20 96.01 3390.42 1499.31 -2408.65 -1335.55 0,07 -0.07 0.00 MWD 4708.88 50.12 209.10 94.95 3450.98 1538.96 -2472.52 -1371.17 0.53 -0.53 -0.11 ,,, MWD 4804.39 49.96 210.30 95.51 3512.33 1578.07 -2536.10 -1407.44 0'.98 -0.17 1.26 ..... MWD 4900.10 49.91 212.00 95.71 3573.93 1615.62 -2598.79 -1445.32 1.36 -0.05 1.78 MWD 4995.50 49.79 212.70 95.40 3635.45 1651.68 -2660.39 -1484.34 0.57 -0.13 0.73 ..... MWD 5091.99 49.54 211.80 96.49 3697.90 1688.17 -2722.59 -1523.59 0.76 -0.26 -0.93 MWD 5186.74 49.25 212.30 94.75 3759.57 1724.07 -2783.56 -1561.76 0.50 -0.31 0.53 MWD 5280.43 49.13 212.30 93.69 3820.80 1759.19 -2843.50 -1599.65 0.13 -0.13 0.00 20-MAY-99 MWD 5376.15 48.71 212.30 95.72 3883.70 1794.93 -2904.49 -1638.21 0.44 -0.44 0.00 MWD 5471.80 50.03 212.10 95.65 3945.98 1831.00 -2965.92 -1676.89 1.39 1.38 -0.21 MWD 5567.90 49.61 211.70 96.10 4007.98 1867.81 -3028.25 -1715.69 0.54 -0.44 -0.42 MWD 5663.13 50.56 211.70 95.23 4069.09 1904,65 -3090.39 -1754,07 1.00 1.00 0.00 ?' MWD 5759.16 50.42 211.60 96.03 4130.18 1942.07 -3153.46 -1792.94 0.17 -0.15 -0.10 MWD 5853.31 49.81 211.70 94.15 4190.56 1978.56 -3214.96 -1830.85 0.65 -0.65 0.11 MWD 5949.19 48.88 210.30 95.88 4253.02 2016.01 -3277.30 -1868.32 1.47 -0.97 -1.46 MWD 6043.07 49.63 211.40 93.88 4314.30 2052.78 -3338.36 -1904.79 1,19 0.80 1.17 MWD 6137.65 49.59 210.90 94.58 4375.59 2089.71 -34(X).01 -1942.06 0.40 -0.04 -0,53 MWD 6232.92 51.15 211.10 95.27 4436.35 2127.49 -3462.90 -1979.85 1.65 1.64 0.21 MWD 6327,62 51.74 211.30 94.70 4495.37 2165.40 -3526.25 -2018.21 0.64 0.62 0.21 MWD 6422.58 51.18 210.60 94.96 4554.54 2203.70 -3589.95 -2056.41 0.82 -0.59 -0.74 MWD 6519.54 50.31 210.80 96.96 4615.89 2242.69 -3654.50 -2094.74 0.91 -0.90 0.21 MWD 6613.43 50.27 209.80 93.89 4675.88 2280.63 -3716.86 -2131.18 0.82 -0.04 -1.07 __ I SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-05050 Sidetrack No. Page 4 of 9 · -' [~,r~ =- I ::~"~ Company ARCO ALASKA INC. Rig Contractor & No. DOYON DRILLING - 19 Field ALPINE Well Name & No. CD#1/40 Survey Section Name ANADRILL BHI Rep. CHIP MILCHAK/BOB HENDERSON ~llrr~~ WELL DATA Target TVD (FT) Target Coord, N/S Slot Coord, N/S -501,13 Grid Correction -0,890 Depths Measured From: RKB ~] MSL [~ SS~ Target Description Target Coord, E/W Slot Coord, E/W 2301,84 Magn, Declination 0,000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m[~ Vert, Sec, Azim, 151,99 Magn, to Map Corr, 0.890 Map North to: OTHER i SURVEY DATA Total Coordinate Build Rate Walk Rate Survey Survey Incl, Hole Course Vertical Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /'W(-) DL Build (+) Right (+) Comment Type (F~ (DD) (DD) (F'~ (FT) (F'r) (F-T) (Per ~00 F'r)Drop (-) Left (-) MWD 6708,20 49,52 209,90 94.77 4736,93 2319,19 -3779,73 -2167,26 0,80 -0,79 0,11 MWD 6804,44 49,78 209,70 96,24 4799,24 2358,27 -3843,38 -2203,71 0,31 0,27 -0,21 , , MWD 6899,46 49,30 210,20 95,02 4860,90 2396,62 -3906,02 -2239,80 0,64 -0,51 0,53 21-MAY-99 MWD 6993,88 49,93' 211,20 94,42 4922,08 2433,97 -3967,86 -2276,52 1,05 0,67 1,06 'MWD 7089,51 50,47 211,60 95,63 4983,29 2471,36 -4030,57 -2314,80 0,65 0,56 0,42 MWD 7185,10 51,10 212,50 95,59 5043,73 2508,32 -4093,34 -2354,11 0,98 0,66 0,94 MWD 7280,59 50,82 211,40 95,49 5103,87 2545,45 -4156,27 -2393,35 0,94 -0,29 -1.15 ....... · MWD 7375,95 51,53 211,00 95,36 5163,66 2583,48 -4219,82 -2431,84 0,81 0,74 -0,42 MWD 7470,31 50,94 211,30 94,36 5222,74 2621,20 -4282,78 -2469,89 0,67 -0,63 0,32 MWD 7566,04 51,78 211,50 95.73 5282,51 2659,25 -4346,60 -2508,85 0,89 0,88 0,21 MWD 7660,51 52,19 211,60 94,47 5340,69 2696,95 -4410,03 -2547,80 0,44 0,43 0,11 MWD 7754,73 51,43 210,90 94,22 5398,95 2734,80 -4473,34 -2586,21 1,00 -0,81 -0,74 MWD 7850,43 52,06 210,90 95,70 5458,20 2773,61 -4537,82 -2624,81 0,66 0,66 0,00 -- MWD 7945,06 51.63 210.50 94,63 5516,66 2812,25 -4601,80 -2662,80 0,56 -0,45 -0,42 22-MAY-99 MWD 8040.82 51,94 210,10 95,76 5575,90 2851,78 -4666,76 -2700,76 0,46 0,32 -0,42 MWD 8136,48 51.58 208,90 95,66 5635,11 2892,13 -4732,15 -2737,75 1,05 -0,38 -1,25 MWD 8231,69 51,20 209,70 95,21 5694,53 2932.32 -4797,03 -2774,16 0,77 -0,40 0,84 MWD 8327,58 51.55 209.30 95,89 5754,38 2972,56 -4862,24 -2811,05 0,49 0,37 -0,42 MWD 8422,78 51,19 208,60 95,20 5813,82 3013,10 -4927,31 -2847,05 0.69 -0,38 -0,74 MWD 8517,66 50,76 208,60 94.88 5873,56 3053,67 -4992,03 -2882,33 0,45 -0,45 0,00 MWD 8612,74 50,56 208,80 95.08 5933,83 3094,03 -5056,53 -2917,65 0,27 -0,21 0,21 MWD 8708.21 50,62 209,40 95,47 5994,44 3134.08 -5120,98 -2953,52 0,49 0,06 0,63 MWD 8803,61 51,38 209,40 95,40 6054,48 3174,02 -5185.57 -2989,91 0,80 0.80 0,00 MWD 8897,56 51,58 209,40 93,95 6112,99 3213,61 -5249,61 -3026,00 . 0,21 0,21 0,00 i i SURVEY CALCULATIONAND FIELD WORKSHEET Job No. 0451-05050 Sidetrack No. Page 5 of 9 a-'[l[~-'l=~"~ Company ARCO ALASKA INC. Rig Contractor & No. DOYONDRILLING- 19 Field ALPINE Well Name & No. CD#1/40 Survey Section Name ANADRILL BHI Rep. CHIP MILCHAK/BOB HENDERSON 1~l14e"~""~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -501.13 Grid Correction -0.890 Depths Measured From: RKB ~ MSL ~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 2301.84 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec. Azim. 151.99 Magn. to Map Corr. 0.890 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 (F~) (DD) (DO) (F'r) (F'r) (FT) (FT) (Per lO0 ET) Drop (-) Left (-) MWD 8992.45 50.87 209.10 94.89 6172.42 3253.62 -5314.15 -3062.15 0.79 -0.75 -0.32 23-MAY-99 MWD 9087.88 51.12 210.00 95.43 6232.48 3293.40 -5378.66 -3098.72 0.78 0.26 0.94 MWD 9183.35 50.91 209.60 95.47 6292.54 3332.93 -5443.06 -3135.60 0.39 -0.22 -0.42 ,,, MWD 9278.45 50.76 210.50 95.10 6352.60 3371.94 -5506.88 -3172,52 0.75 -0.16 0.95 ...... MWD 9374.10 51.25 210.70 95.65 6412.79 3410.66 -5570.87 -3210.36 0.54 0.51 0.21 MWD 9469.62 50.65 211.20 95.52 6472.97 3448.91 ,5634.48 -3248.51 0.75 -0.63 0.52 MWD 9565.05 51.05 211.60 95.43 6533.22 3486.57 -5697.65 -3287.07 0.53 0.42 0.42 MWD 9659.85 52.97 212.90 94.80 6591.57 3523.62 -5760.83 -3326.94 2.30 2.03 1.37 MWD 9754.92 52.47 212.20 95.07 6649.15 3560.80 -5824.59 -3367.65 0.79 -0.53 -0.74 MWD 9849.71 51.71 211.60 94.79 6707.39 3598.29 -5888.08 -3407.17 0.94 -0.80 -0.63 · MWD 9945.14 50.91 210.90 95.43 6767.05 3636.36 -5951.76 -3445.81 1.02 -0.84 -0.73 MWD 10040.05 50.12 210.50 94.91 6827.40 3674.40 -6014.74 -3483.21 0.89 -0.83 -0.42 25-MAY-99 MWD 10060.33 50.12 211.10 20.28 6840.40 3682.46 -6028.11 -3491.18 2.27 0.00 2.96 MWD 10094.36 49.77 211.60 34.03 6862.30 3695.73 -6050.35 -3504.73 1.52 -1.03 1.47 ~ MWD 10125.58 50.02 211.10 31.22 6882.41 3707.91 -6070.74 -3517.15 1.46 0.80 -1.60 MWD 10154.75 51.38 208,40 29.17 6900.89 3719.95 -6090.34 -3528.35 8.55 4.66 -9.26 MWD 10189.26 53,34 206.90 34.51 6921,96 3735,37 -6114.55 -3541.02 6.64 5.68 -4.35 MWD 10219.81 55.35 204.10 30.55 6939.77 3750.13 -6136.95 -3551.70 9.94 6.58 -9.17 MWD 10249.99 57.29 202.30 30.18 6956.51 3765.87 -:6160.03 -3561,59 8.12 6.43 -5.96 MWD 10283,03 59.53 200.40 33.04 6973,82 3784.20 -6186.24 -3571,83 8.36 6.78 -5.75 MWD 10315.00 60.81 198.50 31.97 6989.72 3802.95 -6212.39 -3581.06 6.53 4.00 -5.94 MWD 10346.86 62.03 196.30 31.86 7004.96 3822.59 -6239.09 -3589.42 7.17 3.83 -6.91 MWD 10378.24 63.62 195,10 31,38 7019.30 3842.77 -6265.96 -3596.97 6.10 5,07 -3.82 MWD 10410.16 65.13 193.20 31.92 7033.10 3864.11 -6293.87 -3604.01 7.15 4.73 -5.95 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-05050 Sidetrack No. Page 6 of 9 · _' [ =£~ _- I ::~-~ Company ARCO ALASKA INC, Rig Contractor & No, DOYON DRILLING - 19 Field ALPINE ..... Well Name & No, CD#1/40 Survey Section Name ANADRILL BHI Rep, CHIP MILCHAK/BOB HENDERSON i I~r~l~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -501.13 Grid Correction -0.890 Depths Measured From: RKB ]~ MSL ~ SS~' Target Description Target Coord. E/W Slot Coord. E/W 2301.84 Magn, Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOftr~ 30m~] lom~ Vert. Sec. Azim. 151.99 Magn. to Map Corr. 0.890 Map North to: OTHER ii SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (ET) (DD) (DD) (FT) (FT) (FT) (FT) (Per ~00 F'r)Drop (-) Left (-) MWD 10441,90 66,46 191,50 31.74 7046,12 3886.16 -6322,15 -3610,19 6,44 4,19 -5,36 MWD 10473,44 67,93 189,70 31,54 7058.34 3908,88 -6350,72 ;3615.54 7,03 4,66 -5,71 ..... MWD 10505,21 68,99 187,90 31,77 7070,01 3932,54 -6379,93 -3620,06 6,24 . 3,34 -5,67 MWD 10537.24 69,48 185,50 32,03 7081,36 3957,16 -6409,67 -3623,55 7,17 1,53 -7,49 MWD 10568,45 69,74 183,40 31.21 7092,24 3981,84 -6438,83 -3625,82 6,36 0,83 -6,73 MWD 10599,57 69,80 180,60 31,12 7103,00 4007,13 -6468.01 -3626,84 8,44 0,19 -9,00 MWD 10630,43 69,89 178,70 30,86 7113,63 4032,78 -6496,98 -3626,66 5,79 0,29 -6,16 MWD 10664,01 70,19 175,60 33,58 7125,10 4061,35 -6528,50 -3625,09 8,72 0,89 -9,23 ...... MWD 10696,37 70.68 172,80 32,36 7135,94 4089,57 -6558,83 -3622,01 8,29 1,51 -8,65 .... MWD 10726,00 70,71 169,40 29,63 7145,74 4115,99 -6586,45 -3617,69 10,83 0,10 -11,47 .... MWD 10759,19 71,49 167,70 33,19 7156,49 4146,09 -6617,23 -3611,45 5,39 2,35 -5,12 MWD 10791,04 72,61 165,90 31,85 7166,30 4175,38 -6646,72 -3604,53 6,42 3,52 -5,65 MWD 10820.68 74.48 164,10 29.64 7174,70 4203,08 -6674,18 -3597,17 8,59 6,31 -6,07 MWD 10854,38 76,40 161,30 33.70 7183,17 4235,12 -6705.31 -3587,47 9,85 5,70 -8,31 ~ .., MWD 10886,39 77,61 158,20 32.01 7190,37 4266,02 -6734,57 -3576,68 10,17 3,78 -9,68 MWD 10917.01 78,36 155,20 30,62 7196,75 4295,86 -6762,07 -3564,83 9,89 2,45 -9,80 MWD 10949,22 79,40 153,30 32.21 7202,96 4327,44 -6790,54 -3551,10 6,63 3,23 -5,90 MWD 1098'1,01 81,57 152,20 31,79 7208,22 4358,79 -6818,41 -3536,74 7,63 6,83 -3,46 _ MWD 11010,82 83,99 151,40 29,81 7211,96 4388,36 -6844,47 -3522,77 8,54 8,12 -2.68 MWD 11044,30 86,66 149.80 33,48 7214,69 4421,72 -6873,54 -3506,39 9,29 7,98 -4,78 MWD 11073,18 88,86 149,00 28.88 7215,82 4450,54 -6898,37 -3491,70 8,10 7,62 -2,77 MWD 11108.30 91,20 147.70 35.12 7215,80 4485,59 -6928,27 ~3473,27 7,62 6,66 -3,70 MWD 11139,96 92.94 147,10 31.66 7214,66 4517,13 -6954,92 -3456.23 5.81 5,50 -1.90 MWD 11171,75 93.86 146,10 31.79 7212,77 4548,72 -6981,41 -3438,76 4,27 2,89 -3.15 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-05050 Sidetrack No. Page 7 'of 9 i_.Lil~_.l:=[...l Company ARCO ALASKA INC. Rig Contractor & No. DOYONDRILLING- 19 Field ALPINE Well Name & No. CD#1/40 Survey Section Name ANADRILL BHI Rep. CHIP MILCHAK/BOB HENDERSON j~l~'~l~ WELL DATA ..... ....... Target TVD (FT) Target Coord. N/S Slot Coord. N/S -501.13 Grid Correction -0.890 Depths Measured From: RKB ~] MSL [-] SS~ Target Description Target Coord. E/W Slot Coord. E/W 2301.84 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE i Target Direction (DP) Build\Walk\DL per: lOOft~ 3Omni lOm~ Vert. Sec. Azim. 151.99 Magn, to Map Corr. 0.890 Map North to: OTHER ii i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 F-D Drop (-) Left (-) MWD 11203.89 93.89 146.00 32.14 7210.60 4580.61 -7008.01 -3420.85 0.32 0.09 -0.31 MWD 11235.39 93.94 146.90 31.50 7208.45 4611.89 -7034.20 -3403.48 2.85 0.16 2.86 MWD 11267.21 95.20 146.60 31.82 7205.91 4643.48 -7060.73 -3386.09 4.07 3.96 -0.94 MWD 11297.78 95135 146.60 30.57 7203.10 4673.78 -7086.14 -3369.34 0.49 0.49 0.00 MWD 11329.75 95.26 146.80 31.97 7200.15 4705.48 -7112.75 -3351.86 0.68 -0.28 0.63 MWD 11362.51 94.23 146.40 32.76 7197.44 4737.98 -7140.01 -3333.89 3.37 -3.14 -1.22 ,,. MWD 11393.32 92.66 147.00 30.81 7195.59 4768.61 -7165.71 -3317.00 5.45 -5.10 1.95 ,, MWD 11425.16 92.26 147.10 31.84 7194.22 4800.30 -7192,40 -3299.70 1.29 -1.26 0.31 MWD 11456.94 92.11 147.40 31.78 7193.01 4831.95 -7219.11 -3282.52 1.05 -0.47 0.94 MWD 11488.67 92.11 147.30 31.73 7191.84 4863.55 -7245.81 -3265.41 0.31 0.00 -0.32 MWD 11583.77 92.86 147.90 95.10 7187.72 4958.28 -7326.03 -3214.51 1.01 0.79 0.63 MWD 11679.31 93.46 147.50 95.54 7182.45 5053.41 -7406.66 -3163.53 0.75 0.63 -0.42 MWD 11748.31 93.94 147.70 69.00 7178.00 5122.06 -7464.80 -3126.64 0.75 0.70 0.29 __._ MWD 11773.37 93.74 147.50 25.06 7176.32 5146.99 -7485.91 -3113.24 1.13 -0.80 -0.80 MWD 11849.22 93.48 147.90 75.85 7171.54 5222.48 -7549.90 -3072.79 0.63 -0.34 0.53 _ MWD 11945.19 93.77 147.60 95.97 7165.47 5318.00 -7630.90 -3021.68 0.43 0.30 -0.31 MWD 11979.78 95.15 148.60 34.59 7162.78 5352.40 -7660.17 -3003.46 4.92 3.99 2.89 12-JUL-O0 MWD 12079.85 95.18 144.96 100.07 7153.77 5451.64 -7743.54 -2948.87 3.62 0.03 -3.64 4 3/4"MACH 1X-AKO-1.2 DEG. _ 12-JUL-O0 MWD 12175.92 92.71 145.90 96.07 7147.16 5546.84 -7822.45 -2894.49 2.75 -2.57 0.98 13-JUL-O0 MWD 12273.14 92.06 149.21 97.22 7143.12 5643.67 -7904.41 -2842.39 3.47 -0.67 3.40 13-JUL-O0 MWD 12369.70 89.59 150.89 96.56 7141.73 5740.16 -7988.06 -2794.19 3.09 -2.56 1.74 13-JUL-O0 MWD 12466.31 90.82 147.90 96.61 7141.38 5836.65 -8071.20 -2745.01 3.35 1.27 -3.09 13-JUL-O0 MWD 12562.66 89.18 150.57 96.35 7141.38 5932.88 -8153.98 -2695.73 3.25 -1.70 2.77 13-JUL-O0 MWD 12658.69 91.06 149.36 96.03 7141.1 8 6028.85 -8237.11 -2647.67 2.33 1.96 -1.26 _ ' ' SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-05050 Sidetrack No. Page 8 of 9 · -= [!_r~ -= I :=[~-'-~ Company ARCO ALASKA INC. Rig COntractor & No. DOYON DRILLING - 19 Field ALPINE J~Jl~Jl"~{l~ Well Name &No. CD#1/40 Survey Section Name ANADRILL BHI Rep, CHIP MILCHAK/BOB HENDERSON WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/$ -501.13 Grid Correction -0.890 Depths Measured From: RKB ~ MSL E~ sst- Target Description Target Coord, E/W Slot Coord. ENV 2301.84 Magn, Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 30m[-] lOm[-] Vert. Sec, Azim, 151,99 Magn. to Map Corr. 0.890 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) (DB) (DD) (FT) (FT) (FT) (FT) (Per lO0 F'r)Drop (-) Left (-) 13-JUL-O0 MWD 12754,55 90.96 151.12 95.86 7139.49 6124.64 -8320.31 -2600.10 1.84 -0.10 1,84 13-JUL-O0 MWD 12851.39 90.38 153.55 96.84 7138.36 6221.46 -8406.07 -255,5.14 2.58 -0.60 2.51 ....... 13-JUL-O0 MWD 12946.63 89.35 153,08 95,24 7138,58 6316,68 -8491.16 -2512.37 1.19 -1.08 -0.49 13-JUL-O0 MWD 1,3041.43 88,32 153,46 94,80 7140,51 6411,43 -8575,81 -2469,74 1,16 -1.09 0,40 13-JUL-O0 MWD 13134,85 89,45 152,94 93,42 7142,33 6504,81 -8659,18 -2427.63 1,33 1,21 -0.56 13-JUL-O0 MWD 13229.29 90,69 153.76 94,44 7142.21 6599,23 -8743,58 -2385,27 1,57 1.31 0187 13-JUL-O0 MWD 13325.24 90.99 154,40 95.95 7140,81 6695.10 -8829.87 -2343,33 0,74 0.31 0.67 13-JUL-O0 MWD 13418,55 89,73 155.36 93,31 7140.22 6788.29 -8914.35 -2303,72 1.70 -1,35 1,03 14-JUL-O0 MWD 13515,35 89,79 156.93 96,80 7140.62 6884,83 -9002.88 -2264.58 1.62 0,06 1,62 14-JUL-O0 MWD 13611.56 89,01 155.78 96.21 7141.63 6980,75 -9091,01 -2225,99 1.44 -0.81 -1.20 14-JUL-O0 MWD 13707,46 90,17 154,94 95.90 7142.32 7076.48 -9178.17 -2186,01 1,49 1.21 -0.88 14-JUL-O0 MWD 1380,3.11 91.23 154.66 95.65 7141.15 7172.01 -9264,71 -2145.29 1,15 1.11 -0,29 14-JUL-O0 MWD 13900,16 89,59 153,30 97.05 7140,45 7268,99 -9351.92 -2102,72 2.20 -1.69 -1.40 14-JUL-O0 MWD 13996,74 88.94 152.44 96.58 7141.69 7365.55 -9437,86 -2058,68 1.12 -0.67 -0.89 14-JUL-O0 MWD 14088.34 89.83 150.12 91.60 7142.68 7457.13 -9518.18 -2014,67 2.71 0,97 -2,53 14-JUL-O0 MWD 14181.08 90.82 151.47 92,74 7142,15 7549,85 -9599,13 -1969.42 1.81 1.07 1.46 14-JUL-O0 MWD 14275.04 89,93 152.91 93.96 7141,54 7643,80 -9682,23 -1925.59 1,80 -0.95 1.53 14-JUL-O0 MWD 14365.92 88.90 151.52 90.88 7142.46 7734.67 -9762.63 -1883.23 1.90 -1.13 -1.53 14-JUL-O0 MWD 14459,42 88,70 152.01 93.50 7144.42 7828.15 -9844.98 -1839,00 0,57 -0,21 0,52 14-JUL-O0 MWD 14552.43 89.18 155.67 93,01 7146.14 7921.08 -9928.44 -1798.01 3.97 0.52 3.94 14-JUL-O0 MWD 14645.10 88.42 154.03 92.67 7148.08 8013.61 -10012.30 -1758.64 1.95 -0.82 -1.77 14-JUL-O0 MWD 14738.55 87.84 152.99 93.45 7151.13 8106.98 -10095.89 -1716.98 1.27 -0.62 -1.11 15-JUL-O0 MWD 14829.85 87.87 151.23 91.30 7154.55 8198.21 -10176.53 -1674.30 1.93' 0.03 -1.93 15-JUL-O0 MWD 14922.66 88.18 154.61 92.81 7157.75 8290.94 -10259.10 -1632.08 3.65 0.33 3.64 · i sURVEY CALCULATION AND FIELD WORKSHEET Job No, 0451-05050 Sidetrack No, Page 9 of 9 · -' [I [-4 -= I ::~/ Company ARCO ALASKA INC, Rig Contractor & No, DOYON DRILLING - 19 Field ALPINE II Well Name & No, CD#1/40 Survey Section Name ANADRILL BHI Rep, CHIP MILCHAK/BOB HENDERSON WELL DATA Target TVD (F'r) Target Coord, N/S Slot Coord, N/S -501,13 Grid Correction -0.890 Depths Measured From: RKB ~ MSL~] SSO Target Description Target Coord, E/W Slot Coord, E/W 2301,84 Magn, Declination 0,000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft[-X[ 30m~ 1omo Vert, Sec, Azim, 151,99 .Magn, to Map Corr, 0,890 Map North to: OTHER SURVEY DATA Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Type Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL (F'r) (DD) (DD) (F'r) .... (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) ..... 15-JUL-O0 MWD 15017,15 89,04 150,50 94,49 7160,04 8385,38 -10342,91 -1588,56 4,44 0,91 -4,35 4 3/4"MACH 1X-AKO-1,2 DEG, 15-JUL-O0 MWD 15108,97 86,50 149,01 91,82 7163,62 8477.04 -10422,17 -1542,35 3,21 -2,77 -1,62 15-JUL-O0 MWD 15200,38 85,33 148,68 91,41 7170,13 8568,08 -10500,19 -1495,18 1,33 -1,28 -0,36 15-JUL-O0 MWD 15294,00 86,47 149,52 93,62 7176,82 8661,34 -10580,32 -1447,22 1,51 1,22 0,90 15-JUL-O0 MWD 15386,00 87,46 148,77 92,00 7181,69 8753,10 -10659,18 -1400,11 1,35 1,08 -0,82 15-JUL-O0 MWD 15438,00 87,46 148,77 52,00 7184,00 8804,97 -10703.61 -1373,17 0,00 0,00 0,00 PROJECTED TO TD ..... ANADRILL SCHLUMBERGER Survey report Client ................... : PHILLIPS Alaska, Inc. Field .................... : Colville River Well ..................... : CD1-40 API number ............... : 50-103-20298-00 Engineer ................. : Galperin RIG: ..................... : Doyon 19 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : GROUND LEVEL Depth reference .......... : Driller's Tally GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 55.06 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 151.99 degrees 15-Jul-2000 18:32:16 Page OR!G NAL Spud date ................ : 12 July 00 Last survey date ......... : 15-Jul-00 Total accepted surveys...: 197 MD of first survey ....... : 115.00 ft MD of last survey ........ : 15438.00 ft 1 of 8 Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 12-Jul-2000 Magnetic field strength..: 1147.14 HCNT Magnetic dec (+E/W-) ..... : 25.69 degrees Magnetic dip ............. : 80.54 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.14 HCNT Reference Dip ............ : 80.54 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6_.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.75 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.75 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6 lB 48] -- -- RECEIVED AUG I0 2000 Alaska Oi! &,:,~'~.~ Cons. CommissJor~ Anchorage ANADRILL SCHLUMBERGER Survey Report 15-Jul-2000 18:32:16 Page 2 of 8 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 1 115.00 0.00 0.00 2 200.30 0.39 191.90 3 276.94 1.46 196.40 4 380.60 2.72 191.90 5 471.08 4.64 193.90 6 559.47 7.50 193.40 7 651.03 9.92 192.40 8 742.26 11.33 194.70 9 831.31 13.86 197.40 10 917.59 16.00 198.90 11 1006.84 18.81 201.50 12 1097.16 23.26 204.30 13 1192.66 27.34 205.70 14 1287.79 29.92 206.00 15 1382.93 32.19 206.60 16 1478.78 36.76 208.80 17 1573.33 40.08 209.70 18 1669.00 42.63 210.40 19 1763.64 45.19 210.50 20 1858.07 48.72 209.60 21 1953.42 48.84 209.60 22 2048.26 53.82 211.20 23 2143.82 53.05 210.40 24 2238.91 52.35 211.10 25 2334.25 51.88 210.80 26 2429.13 51.34 210.70 27 2524.75 51.12 210.60 28 2619.45 50.54 211.00 29 2714.20 50.09 210.80 30 2810.20 49.73 210.10 [(c)2000 Anadrilt IDEAL ID6 lB 48] __ -- TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 0.00 115.00 0.00 0.00 0.00 85.30 200.30 0.22 -0.28 -0.06 76.64 276.93 1.12 -1.48 -0.39 103.66 .380.52 3.95 -5.15 -1.27 90.48 470.81 8.32 -10.80 -2.59 88.39 558.69 15.31 -19.89 -4.79 91.56 649.19 25.80 -33.40 -7.87 91.23 738.85 38.37 -49.75 -11.83 89.05 825.75 52.28 -68.39 -17.24 86.28 909.12 67.66 -89.50 -24.18 89.25 90.32 95.50 95.13 95.14 95.85 94.55 95.67 94.64 94.43 95.35 94.84 95.56 95.09 95.34 94.88 95.62 94.70 94.75 96.00 994.27 1078.56 1164.88 1248.37 1329.87 1408.87 1482.93 1554.74 1622.92 1687.36 1750.19 1809.44 1866.37 1923.99 1982.54 2041.46 2101.33 2161.15 2221.65 2283.48 85.41 -114.53 -33.44 105.78 -144.35 -46.12 130.30 -181.31 -63.40 157.18 -222.33 -83.28 185.80 -266.32 -105.03 216.31 -314.31 248.06 -365.56 281.49 -420.26 315.82 -476.84 352.34 -536.57 -130.29 -159.01 -190.67 -223.93 -258.47 390.76 -598.93 429.50 -662.76 469.25 -728.68 508.48 -793.69 547.27 -858.22 -293.90 -331.38 -370.69 -409.36 -448.06 585.84 -922.13 -486.08 624.62 -986.27 -524.09 662.64 -1049.33 -561.68 700.29 -1111.90 -599.12 738.71 -1175.21 -636.34 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) i00f) type 0 0 1 5 il .00 .29 .53 .30 .11 0.00 ' 0.00 TIP 191.90 0.46 MWD M 194.78 1.40 MWD M 193.85 1.22 MWD M 193.49 2.13 MWD M 20 34 51 70 92 .46 .32 .14 .53 .71 193.54 3.24 MWD M -- 193.25 2.65 MWD M -- 193.37 1.61 MWD M 194.15 2.92 MWD M -- 195.12 2.52 MWD M -- 119 151 192 237 286 .32 .54 .08 .41 .28 196.28 3.27 MWD M -- 197.72 5.05 MWD M -- 199.27 4.32 MWD M 200.53 2.72 MWD M 201.52 2.41 MWD M -- 340.25 398.64 461.49 526.80 595.58 202.52 4.94 MWD M -- 203.51 3.56 MWD M -- 204.40 2.71 MWD M -- 205.16 2.71 MWD M -- 205.72 3.80 MWD M -- 667 740 817 893 968 .16 .99 .55 .04 .14 206.14 0.13 MWD M 206.57 5.41 MWD M -- 206.96 1.05 MWD M 207.28 0.94 MWD M 207.57 0.55 MWD M -- 1042 1116 1190 1263 1336 .4O .87 .20 .04 .43 207.79 0.58 MWD M -- 207.99 0.24 MWD M 208.16 0.69 MWD M 208.32 0.50 MWD M -- 208.43 0.67 MWD M -- RECEIVED AUG 10 2000 Alaska Oil & Gas Cons. Commission Anchoraa[e Tool qual type ANADRILL SCHLUMBERGER Survey Report 15-Jul-2000 18:32:16 Page 3 of 8 Seq Measured Inct Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS Srvy depth section +N/S- +E/W- displ Azim (deg/ tool (ft) (ft) (ft) (ft) (ft) (deg) i00f) type 31 2904.85 49.02 210.20 94.65 2345.10 32 2926.34 48.82 210.60 21.49 2359.22 33 2995.85 48.22 209.20 69.51 2405.27 34 3089.66 48.12 209.60 93.81 2467.83 35 3185.04 48.20 207.00 95.38 2531.46 36 3280.10 49.54 205.80 95.06 2593.99 37 3375.42 50.73 204.00 95.32 2655.09 38 3471.39 51.02 205.00 95.97 2715.65 39 3566.79 58.61 207.00 95.40 2770.58 40 3662.21 61.41 210.10 95.42 2818.28 41 3755.36 59.06 214.00 42 3850.43 56.85 212.20 43 3945.85 53.82 211.80 44 4042.08 51.77 211.60 45 4137.43 51.03 212.20 93.15 95.07 95.42 96.23 95.35 94.97 95..38 95.04 95.10 96.01 46 4232.40 49.94 210.90 47 4327.78 50.70 211.00 48 4422.82 50.02 210.00 49 4517.92 50.69 209.20 50 4613.93 50.62 209.20 2864.53 2914.98 2969.24 3027.43 3086.91 3147.34 3208.24 3268.87 3329.55 3390.42 51 4708.88 50.12 209.10 94.95 3450.98 52 4804.39 49.96 210.30 95.51 3512.32 53 4900.10 49.91 212.00 95.71 3573.93 54 4995.50 49.79 212.70 95.40 3635.45 55 5091.99 49.54 211.80 96.49 3697.90 56 5186.74 49.25 212.30 94.75 3759.57 57 5280.43 49.13 212.30 93.69 3820.80 58 5376.15 48.71 212.30 95.72 3883.70 59 5471.80 50.03 212.10 95.65 3945.98 60 5567.90 49.61 211.70 96.10 4007.98 [(c)2000 Anadrill IDEAL ID6 lB 48] 776.61 -1237.33 785.09 -1251.30 812.75 -1296.44 850.40 -1357.34 889.82 -1419.90 -672.43 -680.62 -706.58 -740.90 -774.58 931.49 -1484.03 975.62 -1550.39 1020.93 -1618.14 1066.66 -1688.13 1112.16 -1760.69 -806.41 -837.20 -868.07 -902.28 -941.80 1152.53 -1829.22 -984.66 1191.44 -1896.71 -1028.68 1230.66 -1963.25 -1070.27 1269.32 -2028.46 -1110.54 1306.68 -2091.72 -114'9.92 1343.79 -2154.15 '1188.26 1381.64 -2217.11 -1226.01 1419.87 -2280.16 -1263.16 1459.10 -2343.84 -1299.32 1499.31 -2408.65 -1335.55 1538.96 -2472.51 -1371.17 1578.07 -2536.10 -1407.44 1615.62 -2598.79 -1445.32 1651.68 -2660.39 -1484.34 1688.17 -2722.59 -1523.59 1724.07 -2783.56 -1561.76 1759.19 -2843.50 -1599.65 1794.93 -2904.49 -1638.21 1830.99 -2965.92 -1676.89 1867.80 -3028.25 -1715.69 1408.24 1424.43 1476.49 1546.38 1617.43 208.52 0.75 MWD M -- 208.54 1.68 MWD M -- 208.59 1.74 MWD M 208.63 0.34 MWD M -- 208.61 2.03 MWD M 1688.98 1761.99 1836.28 1914.13 1996.75 208.52 1.70 MWD M -- 208.37 1.91 MWD M -- 208.21 0.86 MWD M -- 208.12 8.14 MWD M -- 208.14 4.07 MWD M 2077.40 2157.70 2236.03 2312.56 2386.97 208.29 4.42 MWD M 208.47 2.82 MWD M 208.60 3.19 MWD M -- 208.70 2.14 MWD M 208.80 0.92 MWD M -- 2460.15 2533.51 2606.67 2679.89 2754.14 208.88 1.56 MWD M -- 208.94 0.80 MWD M 208.99 1.08 MWD M -- 209.00 0.96 MWD M -- 209.01 0.07 MWD M -- 2827.27 2900.47 2973.66 3046.46 3119.91 209.01 0.53 MWD M 209.03 0.98 MWD M -- 209.08 1.36 MWD M 209.16 0.57 MWD M -- 209.23 0.76 MWD M -- 3191.76 3262.58 3334.64 3407.14 3480.50 209.30 0.50 MWD M -- 209.36 0.13 MWD M 209.42 0.44 MWD M 209.48 1.39 MWD M -- 209.53 0.54 MWD M -- RECEIVED AUG Alaska Oil & G~.,s Co~s. Com!r:issJor~ Anchomge Tool qual type ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 15-Jul-2000 18:32:16 Page 4 of 8 TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) I00f) type type 1904.64 -3090.39 -1754.07 1942.07 -3153.46 -1792.95 1978.56 -3214.96 -1830.85 2016.01 -3277.30 -1868.32 2052.78 -3338.36 -1904.80 61 5663.13 50.56 211.70 95.23 4069.09 62 5759.16 50.42 211.60 96.03 4130.18 63 5853;31 49.81 211.70 94.15 4190.56 64 5949.19 48.88 210.30 95.88 4253.02 65 6043.07 49.63 211.40 93.88 4314.30 66 6137.65 49.59 210.90 94.58 4375.58 2089 67 6232.92 51.15 211.10 95.27 4436.35 2127 68 6327.62 51.74 211.30 94.70 4495.37 2165 69 6422.58 51.18 210.60 94.96 4554.54 2203 70 6519.54 50.31 210.80 96.96 4615.89 2242 71 6613.43 50.27 209.80 72 6708.20 49.52 209.90 73 6804.44 49.78 209.70 74 6899.46 49.30 210,.20 75 6993.88 49.93 211.20 4675.88 4736.93 4799.24 4860.90 4922.08 4983.29 5043.73 5103.87 5163.66 5222.74 76 7089.51 50.47 211.60 77 7185.10 51.10 212.50 78 7280.59 50.82 211.40 79 7375.95 51.53 211.00 80 7470.31 50.94 211.30 93.89 94.77 96.24 95.02 94.42 95.63 95.59 95.49 95.36 94.36 81 7566.04 51.78 211.50 95.73 5282.51 82 7660.51 52.19 211.60 94.47 5340.69 83 7754.73 51.43 210.90 94.22 5398.95 84 7850.43 52.06 210.90 95.70 5458.20 85 7945.06 51.63 210.50 94.63 5516.66 5575.90 5635.11 5694.53 5754.38 5813.81 86 8040.82 51.94 210.10 87 8136.48 51.58 208.90 88 8231.69 51.20 209.70 89 8327.58 51.55 209.30 90 8422.78 51.19 208.60 95.76 95.66 95.21 95.89 95.20 .71 -3400.01 -1942.06 .49 -3462.90 -1979.85 .40 -3526.25 -2018.21 .70 -3589.95 -2056.41 .69 -3654.50 -2094.74 2280 2319 2358 2396 2433 .63 -3716.86 -2131.18 .19 -3779.73 -2167.26 .27 -3843.38 -2203.71 .62 -3906.02 -2239.81 .97 -3967.86 -2276.53 2471 2508 2545 2583 2621 .36 -4030.57 -2314.80 .32 -4093.34 -2354.11 .45 -4156.27 -2393.36 .48 -4219.82 -2431.84 .19 -4282.78 -2469.90 2659.24 -4346.60 -2508.85 2696.95 -4410.03 -2547.80 2734.80 -4473.34 -2586.22 2773.61 -4537.82 -2624.81 2812.25 -4601.80 -2662.80 2851.78 -4666.76 -2700.76 2892.13 -4732.15 -2737.76 2932.32 -4797.03 -2774.16 2972.56 -4862.23 -2811.05 3013.10 -4927.31 -2847.05 [(c)2000 Anadrill IDEAL ID6 lB 48] __ -- 3553.49 3627.53 3699.73 3772.45 3843.55 209.58 1.00 MWD M 209.62 0.17 MWD M -- 209.66 0.65 MWD M -- 209.69 1.47 MWD M -- 209.71 1.19 MWD M -- 3915.57 3988.92 4062.96 4137.22 4212.29 209.73 0.40 MWD M -- 209.76 1.65 MWD M -- 209.78 0.64 MWD M 209.81 0.82 MWD M 209.82 0.91 MWD M 4284.51 4357.00 4430.34 4502.64 4574.55 209.83 0.82 MWD M -- 209.83 0.80 MWD M -- 209.83 0.31 MWD M 209.83 0.64 MWD M -- 209.84 1.05 MWD M -- 4647.99 4722.00 4796.12 4870.39 4943.95 209.87 0.65 MWD M 209.90 0.98 MWD M -- 209.94 0.94 MWD M -- 209.95 0.81 MWD M -- 209.97 0.67 MWD M 5018.70 5093.10 5167.13 5242.27 5316.68 209.99 0.89 MWD M -- 210.02 0.44 MWD M -- 210.03 1.00 MWD M -- 210.05 0.66 MWD M -- 210.06 0.56 MWD M -- 5391.92 210.06 0.46 MWD M -- 5467.04 210.05 1.05 MWD M -- 5541.44 210.04 0.77 MWD M -- 5616.35 210.03 0.49 MWD M -- 5690.70 210.02 0.69 MWD M REC£1¥ D - ANADRILL SCHLUMBERGER Survey Report 15-Jul-2000 18:32:16 Page 5 of 8 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 91 8517.66 50.76 208.60 92 8612.74 50.56 208.80 93 8708.21 50.62 209.40 94 8803.61 51.38 209.40 95 8897.56 51.58 209.40 94.88 95.08 95.47 95.40 93.95 TVD depth (ft) 5873.56 5933.83 5994.44 6054.48 6112.99 96 8992.45 50.87 209.10 94.89 6172.41 97 9087.88 51.12 210.00 95.43 6232.48 98 9183.35 50.91 209.60 95.47 6292.54 99 9278.45 50.76 210.50 95.10 6352.60 100 9374.10 51.25 210.70 95.65 6412.79 101 9469.62 50.65 211.20 95.52 6472.97 102 9565.05 51.05 211.60 95.43 6533.22 103 9659.85 52.97 212.90 94.80 6591.57 104 9754.92 52.47 212.20 95.07 6649.15 105 9849.71 51.71 211.60 94.79 6707.39 106 9945.14 50.91 210.90 107 10040.05 50.12 210.50 108 10060.33 50.12 211.10 109 10094.36 49.77 211.60 110 10125.58 50.02 211.10 111 10154.75 51.38 208.40 112 10189.26 53.34 206.90 113 10219.81 55.35 204.10 114 10249.99 57.29 202.30 115 10283.03 59.53 200.40 95.43 94.91 20.28 34.03 31.22 29.17 34.51 30.55 30.18 33.04 31.97 31.86 31.38 31.92 31.74 116 10315.00 60.81 198.50 117 10346.86 62.03 196.30 118 10378.24 63.62 195.10 119 10410.16 65.13 193.20 120 10441.90 66.46 191.50 [(c)2000 Anadrill IDEAL ID6 lB 48] _ -- 6767.05 6827.40 6840.40 6862.30 6882.41 6900.89 6921.96 6939.77 6956.51 6973.82 6989.72 7004.96 7019.29 7033.10 7046.11 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 3053.67 -4992.02 -2882.34 3094.03 -5056.53 -2917.65 3134.08 -5120.98 -2953.52 3174.02 -5185.57 -2989.92 3213.61 -5249.61 -3026.00 3253.62 -5314.15 -3062.15 3293.39 -5378.66 -3098.72 3332.93 -5443.06 -3135.60 3371.93 -5506.88 -3172.52 3410.65 -5570.86 -3210.37 3448.90 -5634.48 -3248.51 3486.56 -5697.65 -3287.07 3523.61 -5760.83 -3326.95 3560.79 -5824.59 -3367.65 3598.29 -5888.08 -3407.17 3636.36 -5951.75 -3445.81 3674.40 -6014.74 -3483.21 3682.46 -6028.11 -3491.18 3695.73 -6050.35 -3504.73 3707.90 -6070.74 -3517.15 3719.95 -6090.34 -3528.35 3735.36 -6114.55 -3541.02 3750.13 -6136.95 -3551.70 3765.86 -6160.03 -3561.59 3784.20 -6186.24 -3571.83 3802.95 -6212.39 -3581.06 3822.59 -6239.09 -3589.42 3842.77 -6265.96 -3596.98 3864.10 -6293.87 -3604.01 3886.16 -6322.15 -3610.20 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) i00f) type type 5764.39 210.00 0.45 MWD M -- 5837.90 209.99 0.27 MWD M -- 5911.66 209.97 0.49 MWD M 5985.79 209.97 0.80 MWD M 6059.29 209.96 0.21 MWD M 6133.27 209.95 0.79 MWD M 6207.42 209.95 0.78 MWD M -- 6281.63 209.95 0.39 MWD M 6355.36 209.95 0.75 MWD M -- 6429.70 209.95 0.54 MWD M -- 6503.86 209.97 0.75 MWD M 6577.85 209.98 0.53 MWD M -- 6652.50 210.01 2.30 MWD 6728.07 210.04 0.79 MWD M 6802.81 210.06 0.94 MWD M -- 6877.28 210.07 1.02 MWD M -- 6950.53 210.08 0.89 MWD M 6966.09 210.08 2.27 MWD M -- 6992.13 210.08 1.52 MWD M -- 7016.00 210.09 1.46 MWD M -- 7038.57 210.09 8.55 MWD M 7065.87 210.08 6.64 MWD M 7090.61 210.06 9.94 MWD M 7115.54 210.04 8.12 MWD M -- 7143.36 210.00 8.36 MWD M -- 7170.62 209.96 6.53 MWD M -- 7197.93 209.91 7.17 MWD M -- 7224.99 209.86 6.10 MWD M 7252.70 209.80 7.15 MWD M -- 7280.32 209.73 6.44 MWD M -- RECEIVED AUG 10 Alaska Oii &u0,o" .... Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report 15-Jul-2000 18:32:16 Page 6 of 8 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 121 10473.44 67.93 189.70 122 10505.21 68.99 187.90 123 10537.24 69.48 185.50 124 10568.45 69.74 183.40 125 10599.57 69.80 180.60 126 10630.43 69.89 178.70 127 10664.01 70.19 175.60 128 10696.37 70.68 172.80 129 10726.00 70.71 169.40 130 10759.19 71.49 167.70 131 10791.04 72.61 165.90 132 10820.68 74.48 164.10 133 10854.38 76.40 161.30 134 10886.39 77.61 158.20 135 10917.01 78.36 155.20 136 10949.22 79.40 153.30 137 10981.01 81.57 152.2'0 138 11010.82 83.99 151.40 139 11044.30 86.66 149.80 140 11073.18 88.86 149.00 141 11108.30 91.20 147.70 142 11139.96 92.94 147.10 143 11171.75 93.86 146.10 144 11203.89 93.89 146.00 145 11235.39 93.94 146.90 146 11267.21 95.20 146.60 147 11297.78 95.35 146.60 148 11329.75 95.26 146.80 149 11362.51 94.23 146.40 150 11393.32 92.66 147.00 [(c)2000 Anadrill IDEAL ID6 lB 48] __ -- 31.54 31.77 32.03 31.21 31.12 30.86 33.58 32.36 29.63 33.19 31.85 29.64 33.70 32.01 30.62 32.21 31.79 29.81 33.48 28.88 35.12 31.66 31.79 32.14 31.50 31.82 30.57 31.97 32.76 30.81 TVD depth (ft) 7058.34 7070.00 7081.36 7092.24 7103.00 7113.63 7125.10 7135.94 7145.74 7156.49 7166.30 7174.70 7183.17 7190.37 7196.75 7202.96 7208.21 7211.96 7214.69 7215.82 7215.80 7214.66 7212.77 7210.60 7208.45 7205.91 7203.10 7200.15 7197.44 7195.58 Vertical Displ Displ Total section +N/S- +E/W- displ (ft) (ft) (ft) (ft) 3908.88 -6350.72 3932.54 -6379.92 3957.16 -6409.67 3981.84 -6438.83 4007.13 -6468.01 -3615.54 -3620.06 -3623.55 z3625.82 -3626.84 4032.78 -6496.98 4061.35 -6528.50 4089.57 -6558.83 4115.99 -6586.45 4146.09 -6617.23 -3626.67 -3625.10 -3622.01 -3617.69 -3611.45 4175.38 -6646.72 4203.07 -6674.18 4235.12 -6705.31 4266.02 -6734.57 4295.86 -6762.07 -3604.53 -3597.18 -3587.47 -3576.68 -3564.83 4327.44 -6790.54 4358.79 -6818.41 4388.36 -6844.47 4421.71 -6873.54 4450.54 -6898.37 -3551.10 -3536.75 -3522.77 -3506.39 -3491.70 4485.59 -6928.27 4517.12 -6954.92 4548.72 -6981.41 4580.61 -7008.01 4611.89 -7034.20 -3473.28 -3456.23 -3438.76 -3420.86 -3403.49 4643.48 -7060.73 4673.78 -7086.14 4705.48 -7112.75 4737.98 -7140.00 4768.60 -7165.71 -3386.10 -3369.34 -3351.86 -3333.89 -3317.01 At DLS Srvy Tool Azim (deg/ tool qual deg) 100f) type type 7307.79 209.65 7.03 7335.41 209.57 6.24 7363.01 209.48 7.17 7389.53 209.38 6.36 7415.47 209.28 8.44 MWD M 74.40.66 7467.44 7492.48 7514.59 7538.59 209.17 5.79 MWD M 209.04 8.72 MWD M 208.91 8.29 MWD M -- 208.78 10.83 MWD M 208.62 5.39 MWD M 7561.19 7581.84 7604.68 7625.42 7644.19 208.47 6.42 MWD M 208 . 32 8 . 59 MWD M 208.15 9.85 MWD M 207.97 10.17 MWD M 207.80 9.89 MWD M 7663.01 7681.10 7697.84 7716.23 7731.72 207.61 6.63 MWD M 207.42 7.63 MWD M 207.23 8.54 MWD M 207.03 9.29 MWD M 206.85 8.10 MWD M 7750.13 7766.37 7782.37 7798.36 7814.33 206.63 7.62 MWD M -- 206.42 5.81 MWD M 206.22 4.27 MWD M 206.02 0.32 MWD M 205.82 2.85 MWD M 7830.68 7846.39 7862.96 7880.01 7896.20 205.62 4.07 MWD M 205.43 0.49 MWD M -- 205.23 0.68 MWD M 205.03 3.37 MWD M 204.84 5.45 MWD M RECEIVED AUG i 0 Alaska Oil & Gas ~.~hora~,~ ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 151 11425.16 92.26 147.10 152 11456.94 92.11 147.40 153 11488.67 92.11 147.30 154 11583.77 92.86 147.90 155 11679.31 93.46 147.50 156 11748.31 93.94 147.70 157 11773.37 93.74 147.50 158 11849.22 93.48 147.90 159 11945.19 93.77 147.60 160 11979.78 95.15 148.60 161 12079.85 95.18 144.96 1 162 12175.92 92.71 145.90 163 12273.14 92.06 149.21 164 12369.70 89.59 150.89 165 12466.31 90.82 147.90 166 12562.66 89.18 150.57 167 12658.69 91.06 149.36 168 12754.55 90.96 151.12 169 12851.39 90.38 153.55 170 12946.63 89.35 153.08 171 13041.43 88.32 153.46 172 13134.85 89.45 152.94 173 13229.29 90.69 153.76 174 13325.24 90.99 154.40 175 13418.55 89.73 155.36 176 13515.35 89.79 156.93 177 13611.56 89.01 155.78 178 13707.46 90.17 154.94 179 13803.11 91.23 154.66 180 13900.16 89.59 153.30 31.84 31.78 31.73 95.10 95.54 69.00 25.06 75.85 95.97 34.59 00.07 96.07 97.22 96.56 96.61 96.35 96.03 95.86 96.84 95.24 94.80 93.42 94.44 95.95 93.31 96.80 96.21 95.90 95.65 97.05 [(c)2000 Anadrill IDEAL ID6 lB 48] -- -- 15-Jul-2000 18:32:16 TVD Vertical Displ Displ Total depth section +N/S- +E/W- 'displ (ft) (ft) (ft) (ft) (ft) 7194.22 7193.01 7191.84 7187.71 7182.45 7178.00 7176.32 7171.54 7165.47 7162.78 7153.77 7147.16 7143.12 7141.73 7141.38 7141.38 7141.18 7139.49 7138.36 7138.58 7140.51 7142.33 7142.21 7140.80 7140.22 7140.62 7141.63 7142.32 7141.15 7140.45 4800.30 -7192.40 -3299.70 4831.95 -7219.11 -3282.52 4863.55 -7245.81 -3265.42 4958.28 -7326.03 -3214.51 5053.41 -7406.66 -3163.54 5122.06 -7464.80 -3126.64 5146.99 -7485.91 -3113.24 5222.48 -7549.90 -3072.79 5318.00 -7630.90 -3021.68 5352.40 -7660.17 -3003.46 5451.63 -7743.53 -2948.87 5546.84 -7822.45 -2894.49 5643.67 -7904.41 -2842.39 5740.16 -7988.06 -2794.19 5836.65 -8071.20 -2745.01 5932.88 -8153.98 -2695.74 6028.84 -8237.11 -2647.67 6124.64 -8320.31 -2600.10 6221.46 -8406.07 -2555.14 6316.68 -8491.16 -2512.37 6411.43 -8575.81 -2469.74 6504.81 -8659.18 -2427.63 6599.22 -8743.58 -2385.27 6695.10 -8829.87 -2343.34 6788.29 -8914.35 -2303.73 6884.83 -9002.88 -2264.58 6980.75 -9091.00 -2226.00 7076.48 -9178.17 -2186.02 7172.01 -9264.71 -2145.29 7268.99 -9351.91 -2102.72 Page 7 of 8 At DLS Srvy Tool Azim (deg/ tool qual (deg) IOOf) type type 7913.20 204.64 1.29 MWD M -- 7930.35 204.45 1.05 MWD M -- 7947.62 204.26 0.31 MWD M -- 8000.23 203.69 1.01 MWD M -- 8053.98 203.13 0.75 MWD M 8093.15 202.73 0~75 MWD M 8107.47 202.58 1.13 MWD M 8151.26 202.15 0.63 MWD M 8207.38 201.60 0.43 MWD M 8227.94 201.41 4.92 MWD M 8286.02 200.85 3.62 IMP 8340.79 200.31 2.75 IMP 8399.93 199.78 3.47 IMP 8462.66 199.28 3.09 IMP 8525.22 198.78 3.35 IMP 8588.04 198.29 3.25 IMP 8652.18 197.82 2.33 IMP 8717.11 197.35 1.84 IMP 8785.82 196.91 2.58 IMP 8855.04 196.48 1.19 IMP 8924.36 196.07 1.16 IMP 8993.04 195.66 1.33 IMP 9063.10 195.26 1.57 IMP 9135.53 194.86 0.74 IMP 9207.22 194.49 1.70 IMP 9283.33 194.12 1.62 IMP 9359.56 193.76 1.44 IMP 9434.91 193.40 1.49 IMP 9509.84 193.04 1.15 IMP 9585.39 192.67 2.20 IMP RECEIVED AUG Alaska {}ii & G~.s Co~s. Commission Anchoraqe 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 15-Jul-2000 18:32:16 Page 8.of 8 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 181 13996.74 88 94 152.44 182 14088.34 89.83 150.12 183 14181.08 90.82 151.47 184 14275.04 89.93 152.91 185 14365.92 88.90 151.52 186 14459.42 88.70 152.01 187 14552.43 89.18 155.67 188 14645.10 88.42 154.03 189 14738.55 87.84 152.99 190 14829.85 87.87 151.23 191 14922.66 88.18 154.61 192 15017.15 89.04 150.50 193 15108.97 86.50 149.01 194 15200.38 85.33 148.68 195 15294.00 86.47 149.52 196 15386.00 87.46 148.77 Projected to TD 197 15438.00 87.46 148.77 96.58 91.60 92.74 93.96 90.88 93.50 93.01 92.67 93.45 91.30 92.81 94.49 91.82 91.4'1 93.62 92.00 52.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) lOOf) 7141.69 7142.68 7142.15 7141.54 7142.46 7144.42 7146.14 7148.08 7151.13 7154.55 7157.75 7160.04 7163.62 7170.13 7176.82 7181.69 7184.00 7365.55 -9437.86 -2058.69 7457.13 -9518.18 -2014.67 7549.84 -9599.13 -1969.43 7643.80 -9682.23 -1925.59 7734.67 -9762.62 -1883.23 Srvy tool type 9659.78 192.31 1 12 IMP 9729.06 191.95 2.71 IMP 9799.08 191.59 1.81 IMP 9871.85 191.25 1.80 IMP 9942.60 190.92 1.90 IMP 190.58 0.57 IMP 190.26 3.97 IMP 189.96 1.95 IMP 189.65 1.27 IMP 189.34 1.93 IMP 7828.15 -9844.98 -1839.01 10015.27 7921.08 -9928.43 -1798.02 10089.93 8013.61 -10012.30 -1758.64 10165.58 8106.97 -10095.89 -1716.98 10240.85 8198.21 -10176.53 -1674.31 10313.34 .10 -1632.09 10388.11 .91 -1588.56 10464.20 .17 -1542.35 10535.67 .19 -1495.18 10606.11 .32 -1447.23 10678.84 189.04 3.65 IMP 188.73 4.44 IMP 188.42 3.21 IMP 188.10 1.33 IMP 187.79 1.51 IMP 8290.94 -10259 8385.37 -10342 8477.04 -10422 8568.08 -10500 8661.34 -10580 8753.10 -10659.18 -1400.11 10750.74 187.48 1.35 0.00 8804.96 -10703.60 -1373.18 10791.33 187.31 IMP Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis Projected [(c)2000 Anadrill IDEAL ID6 lB 48] RECEIVED AU6 10 AIasK,:~ tm & Sas Co:~s. Anchorage Client ................... : ARCO Alaska, Inc. Field .................... : Colville River Well ..................... : CD1-40 API number ............... : 50-103-20298-00 Engineer ................. : Dammeyer Rig: ..................... : Doyon 19 State: ................... : Alaska ANADRILL SCHLUMBERGER Survey report Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Rig Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 56.07 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point---~ ........... Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 207.65 degrees [ (c)1999 Anadrill IDEAL ID5 0C 01R] 28-May-99 15:22:25 Page 1 of 7 Spud date ................ : 15-May-99 Last survey date ......... : 28-May-99 Total accepted surveys.,,: 161 MD of first survey ....... : 115.00 ft MD of last survey ........ : 12055.00 ft Geomagnetic data Magnetic model ........... : BGGM version 1997 Magnetic date ............ : 02-Aug-1998 Magnetic field strength..: 1143.99 HCNT Magnetic dec (+E/W-) ..... : 26,35 degrees Magnetic dip ............. : 80.49 degrees NA L MWD survey Reference Criteria Reference G .............. : Reference H .............. : Reference Dip ............ : Tolerance of G ........... : Tolerance of H ........... : Tolerance of Dip ......... : 1002.68 mGal 1143.99 HCNT 80,49 degrees (+/-) 3.00 mGal (+/-) 7.00 HCNT (+/-) 0.30 degrees Corrections Magnetic dec (+E/W-) ..... : 26.35 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 26.35 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 RECEIVED ,JUN 04 1999 Oil & Gas Co s. Commission ., orage ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 1 115.00 0.00 0.0 2 200.30 0..39 191.9 3 276.94 1.46 196.4 4 380.60 2.72 191.9 5 471.08 4.64 193.9 Course length (ft) 0.00 85.30 76.60 103.70 90.50 6 559.47 7.50 193.4 7 651.03 9.92 192.4 8 742.2'6 11.33 194.7 9 831.31 13.86 197.4 10 917.59 16.00 198.9 88.40 91.50 91.30 89.00 86.30 11 1006,84 18.81 201.5 12 1097.16 23.26 204.3 13 1192.66 27.34 205.7 14 1287.79 29.92 206.0 15 1382.93 32.19 206.6 89 90 95 95 95 .20 .40 .50 .10 .10 16 1478.78 36.76 208.8 17 1573.33 40.08 209.7 18 1669.00 42.63 210.4 19 1763.64 45.19 210.5 20 1858.07 48.72 209.6 95.90 94.50 95.70 94.60 94.50 21 1953.42 48.84 209.6 22 2048.26 53.82 211.2 23 2143.82 53.05 210.4 24 2238.91 52.35 211.1 25 2334.25 51.88 210.8 95.30 94.90 95.50 95.10 95.30 26 2429.13 51.34 210.7 27 2524.75 51.12 210.6 28 2619.45 50.54 211.0 29 2714.20 50.09 210.8 30 2810.20 49.73 210.1 94.90 95.60 94.70 94.80 96.00 depth (ft) 115.00 200.30 276.89 380.52 470.83 558.72 649.16 738.89 825.74 909.13 994.24 1078,5.9 1164.91 1248.38 1329.84 1408.88 1482.91 1554.74 1622.89 1687.38 1750.18 1809.46 1866.35 1923,98 1982.51 2041.44 2101.30 2161.12 2221.65 2283.48 28-May-99 15:22:25 Vertical Displ section +N/S- (ft) (ft) 0.00 0.00 0.28 -0.28 1.49 -1.48 5.15 -5.15 10.77 -10.81 19.84 -19.89 33.23 -33.40 49.56 -49.76 68.58 -68.39 90.51 -89.51 116.96 -114.52 149.29 -144.37 190.05 -181.33 235.59 -222.33 284,63 -266,30 338.89 -314.32 397.58 -365.54 460.75 -420.26 526.27 -476.81 595.26 -536.59 Displ +E/~- (ft) O.00 -0.O6 -0.39 -1.27 -2.59 -4.79 -7.87 -11.83 -17.24 -24.18 -33.44 -46.13 -63.41 -83.28 -105.02 -130.30 -159.00 -190.67 -223.92 -258.48 Total displ (ft) 0.00 0.29 1.53 5.30 11.11 Page 2 of 7 At Azim (deg) 0.00 191.90 194.78 193.85 193.49 20.46 34.31 51.14 70.53 92.71 119.30 151.56 192.09 237.42 286.26 340.25 398.62 461.49 526.77 595.60 193.54 193.25 193.37 194.15 195.!2 196.28 197.72 199.27 200.53 201.52 202.52 203.51 204.40 205.16 205.72 666.91 -598.92 -293.89 667.14 206.14 740.88 -662.78 -331.40 741.02 206.57 817.47 -728,67 -370,68 817.53 206.96 893.01 -793.68 -409.35 893.03 207.28 968.10 -858.18 -448,04 968.10 207.57 1042.37 -922.11 -486.07 1042.38 207.79 1116.81 -986.23 -524.06 1116.83 207.99 1190.11 -1049.30 -561.66 1190.16 208.16 1262.95 -1111.90 -599.12 1263.04 208.32 1336.30 -1175.21 -636,34 1336.43 208.43 DLS (deg/ 100f) 0.00 0.46 1.40 1.22 2.13 3.24 2.65 1.61 2.92 2,52' 3.27 5.05 4.32 2.72 2.41 4.94 3.56 2.71 2.71 3.80 0.13 5.41 1.05 0.94 0.55 0.57 0.24 0.69 0.50 0.67 Srvy tool type TIP MWD MWD MWD MWD M-ND MWD M'WD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c) 1999 Anadrill IDEAL ID5 0C 01R] . : ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 31 2904.85 49,02 210.2 94.60 2345.07 32 2926.34 48.82 210.6 21.50 2359.20 33 2995.85 48.22 209.2 69.60 2405.30 34 3089.66 48.12 209.6 93,80 2467.86 35 3185.04 48.20 207.0 95.30 2531.43 28-May-99 15:22:25 Vertical Displ section +N/S- (ft) (ft) 1408.04 -1237.29 1424,22 -1251.27 1476.32 -1296.47 1546.18 -1357.36 1617.17 -1419.87 Displ +E/w- (ft) -672,41 · -680.61 -706.60 -740,91 -774,56 36 3280.10 49.54 205.8 95.10 2593.99 1688.78 -1484.03 -806 37 3375.42 50.73 204.0 95.30 2655.08 1761.83 -1550.37 -837 38 3471.39 51.02 205.0 96.00 2715.65 1836.19 -1618.14 -868 39 3566.79 58.61 207.0 95.40 2770.59 1914.07 -1688.13 -902 40 3662.21 61.41 210.1 95.40 2818.28 1996.66 -1760.68 -941 41 3755.36 59.06 214.0 93.20 2864.56 2077,30 -1829.24 42 3850.43 56.85 212.2 95.00 2914.96 2157.45 -1896.68 43 3945.85 53.82 211.8 95.40 2969.22 2235.68 -1963.22 44 4042.08 51.77 211.6 96.30 3027.44 2312.19 -2028.47 45 4137.43 51.03 212.2 95.30 3086.90 2386.46 -2091.70 46 4232.40 49.94 210.9 95.00 3147.35 2459.57 -2154.15 47 4327,78 50.70 211.0 95.40 3208.26 2532.87 -2217.12 48 4422.82 50.02 210.0 95.00 3268.87 2605.94 -2280.15 49 4517.92 50.69 209.2 95.10 3329.54 2679.12 -2343.82 50 4613.93 50.62 209.2 96.00 3390.41 2753.34 -2408.62 51 4708.88 50.12 209.1 95.00 3451.00 2826.48 -2472.52 52 4804.39 49.96 210.3 95.50 3512.34 2899.63 -2536.11 53 4900.10 49.91 212.0 95.70 3573,94 2972.73 -2598.78 54 4995.50 49.79 212.7 95.40 3635.45 3045.40 -2660.39 55 5091.99 49.54 211.8 96.50 3697.91 3118.72 -2722.59 56 5186.74 49.25 212.3 94.70 3759.55 3190.41 -2783.53 57 5280.43 49.13 212.3 93.70 3820.78 3261.09 -2843.48 58 5376.15 48.71 212.3 95.80 3883.73 3333.07 -2904.52 59 5471,80 50.03 212.1 95.60 3945.99 3405,39 -2965.91 60 5567.90 49.61 211.7 96,10 4007,99 3478.61 -3028.25 .41 .19 .08 .28 .79 -984.68 -1028.66 -1070.24 -1110.55 -1149.90 -1188.25 -1226.01 -1263.14 -1299.31 -1335.53 -1371 -1407 -1445 -1484 -1523 .17 .44 .32 .34 .59 -1561.74 -1599.64 -1638.22 -1676.89 -1715.68 Page 3 Total disp1 (ft) 1408.20 1424.40 1476.52 1546.41 1617,40 At Azim (deg) 208.52 208.54 208.59 208.63 208.61, 1688.97 1761.97 1836.28 1914.14 1996.74 2077.43 2157.67 2235.99 2312.58 2386.94 2460.14 2533.52 2606.65 2679.87 2754.11 2827.28 2900.47 2973.65 3046.46 3119.91 3191.72 3262.55 3334.67 3407.14 3480.49 208.52 208.37 208.21 208.12 208.14 208.29 208.47 208.60 208.70 208.80 208.88 208.94 208.99 209.00 209.01 209.01 209.03 209.08 209.16 209.23 209.30 209.36 209.42 209.48 209.53 of 7 DLS (deg/ i00f) 0.75 1.68 1.74 0.34 2.03 1.70 1.91 0.86 8.14 4.07 4.42 2.83 3,19 2.14 0.92 1.56 0.80 1.08 0.96 0.07 0.53 0.98 1.36 0.57 0.76 0.50 0.13 0.44 1.39 0.54 Srvy tool type MWD MWD mD M MWD ~D M MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD M-W'D MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis -- 6-axis -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [ (c) 1999 Anadrill IDEAL ID5_0C_01R] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 61 5663,13 50,56 211,7 62 5759,16 50,42 211,6 63 5853,31 49,81 211,7 64 5949,19 48,88 210,3 65 6043,07 49,63 211,4 Course length (ft) 95,20 96,10 94,10 95,90 93,90 66 6137.65 49,59 210,9 67 6232,92 51,15 211,1 68 6327,62 51,74 211,3 69 6422,58 51,18 210,6 70 .6519,54 50,31 210,8 94,50 95,30 94,70 95,00 96,90 71 6613,43 50,27 209,8 72 6708,20 49,52 209,9 73 6804,44 49,78 209,7 74 6899,46 49.30 210,2 75 6993,88 49,93 211,2 93,90 94,80 96,20 95.10 94,40 76 7089,51 50,47 211,6 77 7185,10 51,10 212,5 78 7280,59 50,82 211,4 79 7375,95 51,53 211,0 80 7470,31 50,94 211,3 95.60 95.60 95,50 95,30 94,40 81 7566,04 51,78 211,5 82 7660,51 52,19 211,6 83 7754,73 51,43 210,9 84 7850,43 52,06 210,9 85 7945,06 51,63 210,5 95,70 94,50 94,20 95,70 94,70 86 8040,82 51,94 210,1 87 8136,48 51,58 208,9 88 8231,69 51,20 209,7 89 8327,58 51,55 209,3 90 8422,78 51,19 208,6 95.70 95,70 95,20 95,90 95,20 28-May-99 15:22:25 Page 4 of 7 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 4069,07 4130,21 4190,55 4253,03 4314,32 4375,56 4436,34 4495,36 4554,55 4615,87 4675.86 4736.93 4799.22 4860.93 4922.09 4983,29 5043.73 5103,88 5163,63 5222,74 5282,49 5340,69 5398,93 5458,19 5516,69 3551,45 -3090,37 3625,41 -3153,48 3697.44 -3214,95 3770,06 -3277,31 3841,09 -3338,38 -1754,05 -1792,96 -1830,85 -1868,32 -1904,80 3912,93 -3399,98 3986,20 -3462,89 4060,12 -3526,23 4134,30 -3589,96 4209.23 -3654,47 -1942,03 -1979,84 -2018.20 -2056,42 -2094,72 4281,38 -3716,84 4353,84 -3779,73 4427.10 -3843,35 4499,40 -3906,04 4571,20 -3967,87 -2131,17 -2167.26 -2203,69 -2239,82 '-2276,53 4644,49 -4030,56 4718,34 -4093,34 4792,30 -4156,27 4866,41 -4219,78 4939,87 -4282,77 -2314,80 -2354,10 -2393,35 -2431,81 -2469,89 5014.46 -4346,57 5088,74 -4410,02 5162,63 -4473,31 5237,66 -4537,80 5312,02 -4601,83 -2508,83 -2547.79 -2586,20 -2624,79 -2662,81 5387,13 -4666,75 5462,25 -4732,16 5536,61 -4797.04 5611,49 -4862,24 5685.84 -4927.32 -2700,75 -2737,76 -2774,16 -2811,05 -2847,05 5575,89 5635,13 5694,54 5754.40 5813,83 3553,46 3627,56 3699,72 3772,45 3843,57 Srvy tool type 3915,52 3988,90 4062.94 4137,23 4212,25 209,58 1,00 MWD 209,62 0,17 MWD 209,66 0.65 MWD 209,69 1.47 MWD 209,71 1,19 MWD 4284,48 4356.99 4430,30 4502,66 4574,56 209,73 0,41 MWD 209,76 1,64 MWD 209,78 0,64 MWD 209,81 0,82 MWD 209,82 0,91 MWD 4647,98 4721.99 4796,12 4870,34 4943,93 209,83 0,82 MWD 209,83 0.80 MWD 209,83 0.31 MWD 209,83 0,64 MWD 209,84 1,05 MWD 5018,66 5093,08 5167,10 5242,24 5316,71 209,87 0,65 MWD 209,90 0,98 MWD 209,94 0,94 MWD 209,95 0,81 MWD 209,97 0,67 MWD 5391,90 5467,06 5541,44 5616,36 5690,71 209,99 0,89 MWD 210,02 0,44 MWD 210,03 1,00 MWD 210,05 0,66 MWD 210.06 0,56 MWD 210,06 0,46 MWD 210.05 1.05 MWD 210.04 0,77 MWD 210,03 0,49 MWD 210.02 0,69 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c) 1999 Anadrill IDEAL ID5_0C_01R] ANADRILL Seq 91 92 93 94 95 SCHLUMBERGER Survey Report Measured Incl Azimuth Course depth angle angle length (ft) (deg) (deg) (ft) 28-May-99 15:22:25 Page 5 of 7 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 8517.66 50.76 208.6 94.90 5873.58 5759.56 -4992.05 8612.74 50.56 208.8 95.00 5933.81 5833.02 -5056.50 8708.21 50.62 209.4 95.50 5994,44 5906.78 -5120.97 8803.61 51.38 209.4 95.40 6054.47 5980.89 -5185.56 8897.56 51.58 209.4 94,00 6113.02 6054.40 -5249.63 96 8992.45 50.87 209.1 94.90 6172.45 6128.35 -5314.18 97 9087.88 51.12 210.0 95.40 623Z.49 6202,44 -5378.67 98 9183.35 50.91 209.6 95.50 6292.57 6276.63 -5443.09 99 9278.45 50.76 210.5 95,10 6352.63 6350.29 -5506.91 100 9374.10 51.25 210.7 95.60 6412.79 6424.49 -5570.86 101 9469.62 50.65 211.2 95.50 6472.96 6498.54 -5634.47 102 9565.05 51.05 211,6 95.40 6533.19 6572.36 -5697.62 103 9659.85 52.97 212.9 94.80 6591.54 6646.82 -5760.79 104 9754.92 52.47 212.2 95.10. 6649.14 6722.22 -5824.57 105 9849,71 51.71 211.6 94.80 6707.39 6796.80 -5888.07 95.40 95.00 20.20 34.10 31.20 29.20 34.50 30.50 30.20 33.00 32.00 31.90 31.30 32.00 31.70 106 9945.14 50.91 210.9 107 10040.05 50.12 210.5 108 10060.33 50.12 211.1 109 10094.36 49,77 211.6 110 10125.58 50.02 211.1 6767.02 6827.43 6840.38 6862.33 6882.43 6900.92 6921.99 6939.77 6956.52 6973.80 6989.72 7004.98 7019.28 7033.12 7046.12 111 10154.75 51.38 208.4 112 10189.26 53.34 206.9 113 10219.81 55.35 204.1 114 10249.99 57,29 202.3 115 10283.03 59.53 200.4 6871.12 -5951.73 6944.33 -6014.77 6959.81 -6028.08 6985.86 -6050.38 7009.67 -6070.75 7032.25 -6090.37 7059.57 -6114.57 7084.33 -6136.94 7109.38 -6160.04 7137.31 -6186.21 7164.79 -6212.39 7192.35 -6239.12 7219.59 -6265.92 7247.64 -6293.90 7275.53 -6322.14 -2882.35 -2917.63 -2953.51 -2989.91 -3026.01 -3062.16 -3098.72 -3135.62 -3172.54 -3210.36 -3248.50 -3287.05 -3326.92 -3367.64 -3407.16 -3445.79 -3483.23 -3491.16 -3504.74 -3517.16 -3528.36 -3541.04 -3551.70 -3561.59 -3571.82 -3581.06 -3589.43 -3596,96 -3604.01 -3610.20 116 10315.00 60.81 198.5 117 10346.86 62.03 196.3 118 10378.24 63.62 195.1 119 10410.16 65.13 193.2 120 10441.90 66.46 191.5 5764.41 210.00 0.45 5837.87 209.99 0.27 5911.64 209.97 0.49 5985.78 209.97 0.80 6059.32 209.96 0.21 6133.30 6207.43 6281.66 6355.40 6429.69 Srvy tool type 6503.84 6577.80 6652.45 6728.05 6802.80 MWD MWD MWD MWD MWD 6877.25 6950.56 6966.06 6992.16 7016.01 209.95 0.79 MWD 209,95 0.78 M~D 209,95 0.39 MWD 209.95 0.75 MWD 209.95 0.54 MWD 209.97 0.75 MWD 209.98 0.53 MWD 210.01 2.30 MWD 210.04 0.79 MWD 210.06 0.94 MWD 210.07 1.02 MWD 210.08 0.89 M~D 210.08 2.28 MWD 210.08 1,52 MWD 210.09 1,46 MWD 7038.61 210.09 8.54 7065.90 210.08 6.64 7090.60 210.06 9.95 7115.54 210.04 8.12 7143.33 210.00 8.37 7170.62 7197.96 7224.95 7252.73 7280.32 MWD MWD MWD MWD MWD 209.96 6.52 MWD 209.91 7.16 MWD 209.86 6.12 MWD 209.80 7.14 MWD 209.73 6.44 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis .6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c) 1999 Anadrill IDEAL ID5 0C 01R] ANADRILL SCHLUMBERGER Survey Report 28-May-99 15:22:25 Page 6 of 7 Seq Measured Incl A~imuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 10473.44 67.93 122 10505.21 68.99 123 18537.24 69.48 124 10568.45 69.74 125 10599.57 69.80 126 10630.43 69.89 127 10664.01 70.19 128 10696.37 70.68 129 10726.00 70.71 130 10759.19 71.49 131 10791.04 72.61 132 10820.68 74.48 133 10854.38 76.40 134 10886.39 77.61 135 10917.01 78.36 136 10949.22 79.40 137 10981.01 81.57 138 11010.82 83.99 139 11044.30 86.66 140 11073.18 88.86 141 11108.30 91.20 142 11139.96 92.94 143 11171.75 93.86 144 11203,89 93,89 145 11235.39 93.94 146 11267.21 95.20 147 11297.78 95.35 148 11329.75 95.26 149 11362.51 94.23 150 11393.32 92.66 --- TVD Vertical Displ depth section +N/S- (ft) (ft) (ft) .-- Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type 189.7 31.50 7058.33 7303.29 -6350.68 -3615.53 7307.75 209.65 7.04 MWD 6-axis 187.9 31.80 7070.00 7331.28 -6379.91 -3620.06 7335.40 209,57 6.23 MWD 6-axis 185.5 32.00 7081.35 7359.22 -6409.63 -3623.55 7362.97 209.48 7.18 MWD 6-axis 183.4 31.20 7092.22 7386.09 -6438.78 -3625.81 7389.48 209.38 6.36 MWD 6-axis 1'80.6 31.20 7103.01 7412.48 -6468.03 -3626.84 7415,48 209.28 8.42 MWD 6-axis 178.7 30.80 7113.63 7438.01 -6496.95 -3626.66 7440,63 209.17 5.80 MWD 6-axis 175.6 33.60 7125.10 7465.22 -6528.48 -3625.09 7467.42 209.04 8.72 MWD 6-axis 172.8 32.40 7135.95 7490.69 -6558.85 -3622.00 7492.49 208.91 8.28 MWD 6-axis 169.4 29.60 7145.74 7513.12 -6586.45 -3617.68 7514.58 208.78 10.84 MWD 6-axis 167.7 33.20 7156.49 7537.50 -6617.23 -3611.45 7538.59 208.62 5.38 MWD 6-axis 165.9 31.80 7166.29 7560.38 -6646.68 -3604.54 7561.15 208.47 6.43 MWD 6-axis 164.1 29.70 7174.71 7581.32 -6674.19 -3597.16 7581.85 208.32 8.57 MWD 6-axis 161,3 33.70 7183,18 7604.40 -6705.33 -3587.46 7604.69 208.15 9.85 MWD 6-axis 158,2 32.00 7190.38 7625.30 -6734.58 -3576.67 7625.42 207.97 10.17 MW]) 6-axis 155.2 30.60 7196.75 7644,15 -6762.06 -3564.83 7644.18 207.80 9.90 MWD 6-axis 153.3 32.20 7202.96 7662.99 -6790.52 -3551.10 7662.99 207.61 6.63 MWD 6-axis 152,2 31.80 7208.21 7681.02 -6818.40 -3536.74 7681.09 207.42 7.63 MWD 6-axis 151.4 29.80 7211.96 7697,62 -6844.45 -3522.78 7697.82 207.23 8,55 MWD 6-axis 149.8 33.50 7214.69 7715.77 -6873.53 -3506.39 7716.23 207,03 9.28 MWD 6-axis 149.0 28.90 7215.82 7730.97 -6898.39 -3491.69 7731.73 206.85 8.10 MWD 6-axis 147.7 35.10 7215.80 7748.89 -6928.26 -3473.27 7750.13 206.63 7.63 MWD 6-axis 147.1 31.70 7214.66 7764.61 -6954.95 -3456.20 7766.38 206.42 5.81 MWD 6-axis 146.1 31,80 7212.77 7779.97 -6981.45 -3438.73 7782.39 206.22 4.27 MWD 6-axis 146.0 32.10 7210.60 7795.20 -7008.02 -3420.84 7798.36 206,02 0,32 MWD 6-axis 146.9 31.50 7208,45 7810.34 -7034.21 -3403.47 7814,33 205.82 2.85 MWD 6-axis 146.6 31.80 7205.92 7825.76 -7060.72 -3386.10 7830.67 205.62 4.07 MWD 6-axis 146.6 30.60 7203.10 7840.51 -7086.16 -3369.32 7846.40 205.43 0.49 MWD 6-axis 146.8 31.90 7200.15 7855.93 -7112.70 -3351.88 7862.93 205.23 0.69 MWD 6-axis 146,4 32.80 7197,44 7871.75 -7139.99 -3333.89 7880.00 205.03 3.37 MWD 6-axis 147.0 30.80 7195.59 7886.68 -7165.69 -3317.01 7896.18 204.84 5.46 MWD 6-axis [ (c) 1999 Anadrill IDEAL ID5 0C 01R] ANABRILLSCHLUMBERSER Survey Report 28-May-99 15:22~25 Page 7 of 7 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical depth section (ft) (ft) Displ Displ Total At DLS Srvy Tool +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (deg) 100f) type type 151 11425.16 92.26 152 11456.94 92.11 153 11488.67 92.11 154 11583.77 92.86 155 11679.31 93.46 147.1 31.90 7194.22 7902.33 -7192.43 -3299.68 7913.21 204.64 1.29 MWD 6-axis 147.4 31.70 7193.01 7917.97 -7219.07 -3282.54 7930.33 204.45 1.06 MWD 6-axis 147.3 31.80 7191.84 7933,72 -7245.83 -3265.40 7947.63 204.26 0.31 MWD 6-axis 147.9 95.10 7187.72 7981.15 -7326.05 -3214.49 8000.25 203.69 1.01 MWD 6-axis 147.5 95.50 7182.45 8028.90 -7406.65 -3163.53 8053.97 203.13 0.75 MWD 6-axis 156 11748.31 93.94 157 11773 37 93 74 158 11849.22 93.48 159 11945.19 93.77 160 11979.78 95.15 147.7 69.00 7178.00 8063.28 -7464.79 -3126.64 8093.14 202.73 0.75 MWD 6-axis 147.5 25.10 7176.32 8075.78 -7485.93 -3113.22 8107.48 202.58 1.13 MWD 6-axis 147.9 75.80 7171.55 8113.66 -7549.88 -3072.80 8151.24 202.15 0.63 MWD M - 147.6 96,00 7165.48 8161.71 -7630.90 -3021.67 8207.39 201.60 0.43 MWD 6-axis 148.6 34.60 7162.79 8179.19 -7660.19 -3003.44 8227,95 201.41 4.92 MWD 6-axis Last Survey Projected To TD (linear projection) 161 12055.00 95.15 148.6 75.20 7156.04 8217.71 -7724.11 -2964.42 8273.44 201.00 0,00 MWD_M [ (c) 1999 Anadrill IDEAL ID5_0C_01R] Customer Well No MWDILWD Log Product Delivery , . Dispatched To: CD I~0 ~' O~ ~ Date Dispatche AOGCC 9-Aug-00 0 Installation/Rig Doyon 19 Dispatched By: LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 RECEI /ED AUG 10:OuO Alas~ a 0il & Gas C0'~,~. Commission Anch0ra~e Received By: Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 rose@anchorage.anadrill.slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 25, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Second Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the second quarter of 2000, as well as total .volumes injected into annuli for which injection authorization expired during the second quarter of 2000. Annular Injection during the second quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-341 20406 100 0 20506 0 20506 2L-313 4640 100 0 4740 12533 17273 CD1-40 108 100 0 208 32669 32877 CD1-23 16751 100 0 16851 17135 33986 CDI-16 25 0 0 25 29025 29050 CD1-32 82 100 0 182 33331 33513 CD1-38 11056 100 0 11156 9164 20320 CD1-27 32333 100 0 32433 381 32814 1L-28 5853 100 0 5953 3984 9937 --- 1D-11 135 100 0 235 0 235 1D-14 1337.6 100 0 1437.6 0 1437.6 CD1-25 8141 100 0 8241 386 8627 CD1-34 278 100 0 378 0 378 Ms. Wendy Mahan AOGCC Second Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the second quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CDI-19 33933 100 0 34033 Open, Freeze Protected 1C-25 34836 100 0 34936 Open, Freeze Protected ~ CD1-40 32777 100 0 32877 Open, Freeze Protected 1C-23 34470 100 0 34570 Open, Freeze Protected ~- 1C-18 0 0 0 0 Open, Freeze Protected ~' CD1-35 217 100 0 317 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Doug Chester Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files il. Type of request: Abandon_ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS _ _ well S/~Ii Suspend Operational shutdown Re-enter suspended Time extension _ mulate _ Other_ Alter casing _ Repair well _ Change approved program _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 502' FNL, 2300' FWL, Sec.5, T11N, RSE, UM At target (Top Alpine)) 2140' FNL, 1144" FEL, Sec.7, T11N, R5E, UM At effective depth At REVISED total depth 850' FNL, 979' FWL, Sec.17, T11N, R5E, UM Plugging _ Pull tubing _ t5. Type of Well: Development _X Exploratory _ Stratigraphic __ Service _ per APD requested new TD Vadance _ Perforate _ Annular Injection 6. Datum elevation (DF or KB feet) RKB 56' feet 7. Unit or Property name Colville River Unit 8. Well number CD1-40 9. Permit number / approval number 199-044 10. APl number 50-103-20298-00 11. Field / Pool Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: Effective depth: Casing Conductor measured 12055 true vertical 7156 measured 11959 true vertical 7163 Length Size 77' 16" Surface 2940' 9.625" Production 12008' 7" feet feet feet landing collar in 7" casing. feet Cemented 10 cu.yds, Portland Type 3 530 sx ASL3, 230 sx Class G 317 sx Class G ORIGINAL Measured Depth True vertical Depth 114 114 2976' 2392' 12042' 7157' Per the attached memo. CD1-40 has been temporarily suspended at the 7" casing point. It is requested that the horizontal section be extended paSt the point proposed in the original APD. In addition, the proposed completion plan has been altered to reflect current completion practices as opposed to what was envisaged at the time of writing the permit. ~.,,.¢ ¢,:-: ...... f~ i: ..... The new TD coOrdinates for the well will be as indicated above. 08 :000 13. Attachments Description summary of proposal_ Detailed operations program ~ I 15. Status of well classification as: I Oil X Gas ~ Date approved IService _ i17 I hereby certify that the foregoing is true and correct to the best of my knowledge. 14. Estimated date for commencing operation July 5, 2000 16. If proposal was verbally approved Name of approver Signed off, Va ==Conditions I: Title: Drilling Team Leader Approved by order of the Commission FOR COMMISSION USE ONLY Notify Commission so representative m/ay witness Plug integrity __ BOP Test ~ Location clearance __ Mechanical IntegritY Test __ Subsequent form required lo- ORIGINAL 51(.~NbD BY D Taylor Seamount commissioner .Approved Copy BOP sketch __ Suspended __ Date Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE , . . . 7. 8. 9. 10. 11. 12. 13. 14. Note: CD1-40 Program ,.,atline (Production Hole and Com~_=tion Operations) Move on Doyon 19. Remove the BPV and install the 2-way check. Remove tubing head adapter assembly. Install BOPE. Pressure test BOPE to 3500 psi. Recover the 2-way check. Remove the tubing hanger and single joint of tubing. Make up a mill tooth bit / slick clean out assembly. RIH and tag up on the float collar at 11959'. Displace the well to 9.2 ppg 'clean out' mud. Pressure test casing to 3500 psi / 30 mins. Drill out the float equipment and 20' of new formation. Perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off to drill ahead is 11.5 ppg EMW. Displace the well to 9.2 ppg FIo-Pro drill in fluid. POH. M/U and run the drilling assembly. Drill 6 1/8" horizontal section to well TD at 15656' MD / 7136' TVD. Displace the well to 9.2 ppg brine and pull out of hole. Run 4 Y2, 12.6 #, L-80 tubing with S-3 packer, gas lift mandrels (bottom with DCK-2 shear valve, others with dummy valves), BAL-O ported SSSV nipple (packing sleeve installed) and control line. M/U hanger and pressure test the control line to 5000 psi. Land hanger. Back out landing joint. Install 2-way check with rods. M/U landing joint and test hanger seals to 5000 psi. Nipple down BOP. Install wellhead adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2-way check with lubricator. Drop RHC ball and set packer. Test tubing to 3500 psi/30 rains. Test casing annulus to 3500 psi / 30 rains. (hold 2500 psi tubing pressure to avoid shearing out the DCK-2 valve). Bleed off tubing pressure to shear out the DCK-2 valve. Circulate in 9.6 ppg inhibited brine and sufficient diesel to fill the tubing to the lowermost gas lift mandrel plus provide 2000' TVD of diesel freeze protection on the annulus. Set BPV and secure well. Move rig off. A slickline unit will return to the well to remove the packing sleeve and RHC nipple prior to preparing the well for production. This will be done after the rig moves off location. Colville River Field CD1-40 Temporary Suspension Schematic- as built Diesel Freeze Protection in casing and annulus to 1309' MD / 1270' TVD. I,, 9.6 ppg drilling mud in annulus Wellhead installed with tubing hanger and BPV set and pressure , tested to 3500 psi 1 jt tubing and WEG below the hanger 16" Conductor to 114' 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2976' MD / 2392' TVD cemented to surface 9.2 ppg brine Suspended 05/30/99 Calculated TOC at 10100' Casing pressure tested to 3500 psi on plug ). Float Collar at 11959' TD at 12055' MD / 7156' TVD 7" 26 ppf L-80 R3 BTC-Mod Production Casing at 12042' MD / 7157' TVD Colville River Field CD1-40 Production Well Completion Plan 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID)at 1700' TVD = 1877' MD ' Isolation Sleeve with DB-6 No-Go Lock (3.812" OD)run in profile I?iiii, I I I I ,iiiii!~ - SINGLE 1/4"xO.049"s/scontrollines 9'5/8'' 36 ppf J.SS BTC Surface Casing @ 2976' MD / 2392' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch \ \ \ \ & 1" Camco DCK-2 Shear Valve \ \ \ ~.Pinned for casing side shear @ +/- 2000 psi ~~~nll above the X landing nipple +/- 10324' Calculated TOC at 10100" MD WRDP-2 SSSV (2.125"1D) w/ DB-6 No-Go Lock (3.812" OD) - to be installed later Completion Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap Tubing Supended with diesel to lowest GLM Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 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 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) HES "X" (3.813" ID) 4-1/2" tubing joint (1) Baker S3 Packer 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 4-1/2" 10' pup joint WEG (+/- 65 dog) MD TVD 35' 35' 1877' 1700' 4629' 34OO' 7434' 5200' 10223' 6942' 10292' 6978' 10324' 6994' 10389' 7024' 10400' 7029' Run 1 per joint Weatherford thermal centralizers between 4500' TVD (=6335' MD) and 2976' MD (approx. 110 in total). 7" 26 ppf L-80 BTC Mod Production Casing @ 12042' MD / 7157' TVD @ 95 dog Well TD at 15656' MD / 7136' TVD For: B Robert~on rru. Vertical O.pU~ PHILLIPS Alaska, Inc. Structure : CD#1 Field : Alpine Field Well: 40 Location : North Slope, Alaska <- West (feet) 4200 .5900 5600 5500 5000 2700 2400 21 O0 1800 51.99 AZIMUTH (TO TO) ***Plane of Proposal*** Pt. EOC CD1-40 Interrn Pt 1269' FSL, 141' F'EL SEC. 7, T11N, R5E Final Bid/Tm Interm Pt-EOC CD1-40 TD LOCATION: 850' FNL, 979' FWL SEC. 17, T11N, R5E 1500 1200 900 TD - Csg Pt. 600 300 600O 6500 6600 6900 7200 7500 7800 8100 84O0 8700 9O00 9500 9600 9900 10200 10500 10800 11100 11400 0 I V Cr.ot~d by bmichool FOr: B RobeTtaon Dote plotted: 2-Jun-2000 Plot Reference ;,, 4.0 Veralon#6. C~rdinotoa ore in feet reference slot ~140. true Vertical Depths ore reference RKB (Doyo~ ~19). PHILLIPS Alaska, Inc. Structure: CD#I Well: 40 Field : Alpine Field Looofion: North Slope, Alaska 151.99 AZIMUTH 9026' (TO TD) ***Plane of Proposal*** (D 6250 (- 6500 6750 ..l-- t.. 7000 7250 750o FINAL ANGLE 90.24 DEG Beg Final Bid/rrm TD - Csg Pt. ~ 94.44 EOC Interm Pt-EOC --~. KOP-Csg Pt. ] i i i ] i i i i i i i i i i i i [ I i i i ! i i i i i i i i i i i i i [ i i i i [ i i i 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250 8500 8750 9000 9250 Vertical Section (feet)-> Azimuth 151.99 wlfh reference 0.00 N, 0.00 E from slot #40 Creoted by bm]choel For: B Robert~on 0ore plotted: Plot Reference is 40 Coordinotu ore in fo~ r~erm~ ulo~ ~40, True VerUcol ~pths ore r~ereflco PHILLIPS Alaska, Inc. Structure: CD#1 Field : Alpine Field Well : 40 Location: North Slope, Alaska PROFILE COMMENT DATA Point MD Inc Dir TVD North East V. Sect Deg/1 O0 KOP-Csg Pt. 12055.00 95.10 148.60 7159.23 -7723.52 -2962.54 5427.55 0.00 EOC 12411.64 89.82 153.40 7143.91 -8034.97 -2789.94 5783.57 2.00 Beg Final BId/Trn 13108.65 89.82 153.40 7146.08 -8658.23 -2477.89 6480.37 0.00 Interm Pt-EOC 13256.23 90.24 151.99 7146.00 -8789.36 -2410.19 6627.94 1.00 TD - Csg Pt. 15656.32 90.24 151.99 7136.00 -10908.28 -1283.01 9028.01 0.00 lin PHILLIPS Alaska, Inc. Sfrucfure: CD#I Field : Alpine Field Well: 40 Location : North Slope, Alaska <- West (feet) 4200 5900 3600 3500 3000 2700 2400 '2100 1800 1500 1200 900 600 500 I I I I I I , I I I I I I I I I I I I I I I I I I I I _1 I ~\\\\\\\ · 7159 7146 ~ 56 6000 6500 6600 6900 7200 7500 7800 8100 8,,oo 870{1 9000 I V 9300 9600 9900 10200 10500 10800 11100 11400 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 June 07,2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Change the Well Program: CD1-40~ Permit No. 199-447 APl No. 50-103-20298 Dear Sirs: Phillips Alaska, Inc. hereby requests approval to modify the program on production well CD1-40. These modifications relate to: a. b, An extension of the length of the horizontal section over what was originally proposed. The new planned bottom hole location is 850' FNL, 979' FWL, Sec 17, T11 N, R5E. A modified completion configuration. This reflects current completion practices as opposed to what was envisaged at the time the permit was submitted. Please find attached form 10-403 plus the following information: a. An outline program. A suspension schematic showing the current well status. A proposed final completion drawing. Directional drilling information. The well is presently suspended with 7" casing set in the Alpine reservoir at 12042' MD / 7157' TVD. It is estimated that the well will be re-entered around 5 July 2000. Well construction operations will then re-commence and the horizontal production section will be drilled prior to running a 4-1/2" gas lift completion. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincere~~/ Brian Robertson Senior Drilling Engineer CC, CD1-40 Well File Sharon AIIsup-Drake Doug Chester Mike Erwin Gracie Stefanescu ATO-1054 ANO-382 ANO-383 Anadarko Colville River Unit CD 1-40, Permit...perwork ~ equired for Work Stoppage Subject: Colville River Unit CD1-40, Permit No. 99-44 API No. 50-103-20298 RE: Clarification of Paperwork Required for Work Stoppage Date: Thu, 16 Sep 1999 17:09:02 -0900 From: "Brian Robertson" <BROB ERT4~mail.aai.arco.com> To: blair wondzell~admin, state.ak.us CC: "Sharon Allsup-Drake" <SALLSUP~mail.aai.arco.com>, "Douglas K Chester" <DCHESTER~mail.aai.arco.com> Further to your clarification e-mail dated 09/02/99, the suspension details for well CD1-40 are as follows: A. There were both logistical and reservoir damage avoidance reasons for not drilling the horizontal / reservoir section of the well upon the initial rig visit. It was deemed better to suspend the well at the 7" casing point and incur the cost of a move back to the well than leave the reservoir open to wellbore fluid for what would be in excess of 1 year before start up. B. CD1-40 was spudded on 15 May 1999. Rig release date was 30 May 1999. C. Well TD (at intermediate casing point) was 12055' MD / 7156' TVD. D. 7" casing depth was 12042' MD / 7157' TVD. Bumped plug and pressure tested casing to 3500 psi. Floats held. Diesel freeze protection to 1200' was pumped as part of the cement displacement. E. 9-5/8" x 7" casing was flushed with 255 bbls of fresh water followed by 36 bbls of diesel to freeze protect to +/- 950' F. 1 joint of 4-1/2" tubing was run and landed off on a tubing hanger. The tubing hanger was pressure tested after installation of the wellhead adapter valves to 3500 psi. A BPV was set in the casing hanger profile. G. The expected date for moving back on to the well is June 2000. At this point the 7" casing will be drilled out and the horizontal section drilled prior to the well being completed (as per the permit submission). If you require further information on this well, please respond to this e-mail or call me on 265-6034. Regards Brian Robertson - Drilling Eng. - Alpine Project 1 of 1 9/17/99 8:07 AM Re: Colville River Unit CD 1-24, Pe...perw( ~- Required for Work Stoppage Subject: Re: Colville River Unit CD1-24, Permit No. 99-26, AP1 No. 50-103-20295 RE' Clarification of Paperwork Required for Work Stoppage Date: Thu, 02 Sep 1999 14:44:07 -0800 From: Blair Wondzell <blair wondzell@admin state.ak.us> J ~! - 5'5-' q C?-O,~D -- ' o Organization: State ofAlaska, Dept of Admin, Oil & Gas _5 1)¢ - ~ c/S0 "0'%{ To: Brian Robertson <BROBERT4~mail.aai.arco.com> Brian, I pulled the CD1-24 well file and noted that Step 9 "Suspend well and move off rig." and Step 10 "Move in rig. Install and test BOPE to 3500 psi." There are no reasons for moving off and back on nor are there dates, or events. For these wells we would like to see an E-mail, fax, or equivalent for each well immediately after suspension that provides the following information: 1. Spud date and suspend date. 2. Condition of well, e.g., 7" csg was run and cemented at ~' and will not be drilled out; freeze protected annulus to ' with . 2. Event and approximate date for move back----~n for completion. (e.g., prior to start up in June 2000 is ok). Brian, this would be about the easiest way to have our files reflect well conditions. When you are ready to enter and complete the wells, you could notify us by E-mail of a single well or a schedule of wells. If you want to discuss, please call me at 279-1433 ext 226. Thanks, Blair 9/2/99 Brian Robertson wrote: > Blair, > > Referencing our discussion this morning. Attached is a copy of an e-mail that > doug Chester sent previously. > Regards > Brian. > Forwarded by Brian Robertson/AAI/ARCO on 09/02/99 12:19 >PM > Douglas K Chester > 07/29/99 03:39 PM > To: blair wondzell@admin.state.ak.us -- > cc: (bcc: Brian Robertson/AAI/ARCO) > Subject: Colville River Unit CD1-24, Permit No. 99-26, API No. 50-103-20295 > RE: Clarification of Paperwork Required for Work Stoppage > > Mr. Wondzell, > > Currently the CD1-24 well is closed in after running and cementing the 7" > intermediate casing per plan submitted to the AOGCC by form 10-401. The well > was secured with plans to drill the productive interval and complete the well > before production facility start-up in June 2000. ARCO Alaska Inc. requests > clarification on what paperwork is required to satisfy the AOGCC's requirements > without creating unnecessary paperwork. Currently ARCO Alaska Inc. has two > additional wells with this same status: CD1-35 and CD1-40. > > ARCO Alaska Inc. sees three possible options: > 1) Submit a 10-403 with suspended status and revise upon well completion in > March of 2000. > 2) Submit a 10-404 now and then submit a 10-403 upon well completion in March > of 2000 referencing any redundant data submitted with the 10-404. > 3) No paperwork required at this time because the plan submitted and approved > in the permit has not changed. 1 of 2 9/2/99 2:51 PM ~ Re: Colville River Unit CD1-24, Pe...perwr 2,equired for Work Stoppage We would propose option number 3 as the scope is consistent with the approved permit. This would help reduce the amount of paperwork for both organizations, which would be a positive result. ARCO Alaska Inc. will be happy to supply any additional information or discuss this further at your convenience. Doug Chester Alpine Drilling Team Leader 263-4792 FAX 265-1515 2 of 2 9/2/99 2:51 PM Scblamberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 12928 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 11/12/99 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-24(REPROCESSED) bi, t(_. 9923-5 CDR/ADN {PDC) ~ q'~'.'~q {~,) 990503 1 CD1-24 (REPROCESSED) I 9923-5 ADN 990503 I 1 CD1-24 (REPROCESSED),,~ 9923.5 ADN TVD 990503 I 1 CD1-40 (REPROCESSED) 99251 ADN/CDR ([=DC) ~ C[,'~-~ 990527 1 CD1-40 (REPROCESSED) 99251 3~ON 990527 I 1 CD1-40 (REPROCESSED) 99251 ADN ~ 99052? I 1 CD1-01 (REPROCESSED) 99286 CDR/ADN (PDC) ~ ~~ 990626 1 CD1-01 (REPROCESSED) 99286 iADN 990626 I 1 CD1-01 (REPROCESSED) 99286 ADN TVD 990626 I 1 CD1-13 99403 SCMT 991001 I Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the third quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 1999. Annular b~./ection during tile third quarter of 1999: h(1) ~ h(2) h(3) Total for Previous New Well Name Volume i Volume Volume Quarter Total Total 1C-25 520 i 100 I 0 620 34316 34936 CD1-40 20079 ] 100 0 20179 12171 32350 CD1-01 4905 i 100 0 5005 0 5005 1C-23 24865 ,~ 100 0 24965 9605 34570 CD1-23 16079 i 100 ~ 0 16179 0 16719 CD1-37 17173 I 100 ~ 0 17273 0 17273 CD1-39 3917 i 100 ~ 0 4017 i 0 4017 ' , ' 0 4405 1D.12 4305 100 I 0 4405 ct9.62s - Total Volumes into Annuli for which btjection Authorization Expired durin~j the quarter Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume I Volume i Volume Injected Status of Annulus 1D-09 32540 I 100 t 0 32640 Open. Freeze Protected 2N-337A 30539 ! 100 0 30639 Open, Freeze Protected 2N-313 32758 i 100 0 32858 Open, Freeze Protected 2N-321A 27507 I I00 . 0 27607 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, PaulMazzolini i~EC~~--- i-VE~ Drilling Team Leader 999 ~asi(a Oil & Gas Cons. Commisston Anchoraqe CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Momson and Winfree S baron Allsup-Drake Well Files Ms. Wendy Mahan AOGCC Third Quarter 1999 Annular Injection Report Page Two ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 24, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Revised Kuparuk Area Annular Injection, Fourth Quarter, 1999 Dear Ms. Mahan: : rCEIVED ?-8 2000 cqas cons. Commission Anchorage Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the fourth quarter of 1999. Annular Injection during the fourth quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-37 15214 100 0 15314 17273 32587 CD1-39 27391 100 0 27491 4017 31508 1D-12 27089 100 0 27189 5702 32891 CDI-16 28925 100 0 29025 0 29025 CD1-32 7449 100 0 7549 0 7549 CD1-03 285 100 0 385 0 385 CD1-42 287 100 0 387 0 387 CD1-40 20 0 0 20 32649 32669 CD1-45 274 100 0 374 0 374 CD1-36 293 100 0 393 0 393 CD1-35 217 100 0 317 0 317 CD1-23 20 0 0 20 17085 17105 CDI-13 89 100 0 189 0 189 CD1-01 20 0 0 20 5201 5221 Total Volumes into Annuli for which Injection Authorization Expired during the fourth quarter ;Fetal - Total h(1) I Total h(2) Total h(3) Volume Well Name VolumeI Volume Volume Injected Status of Annulus 2N-315 25326 100 0 25426 Open, Freeze Protected 2L-329A 33971 100 0 34071 Open, Freeze Protec'ied 2L-325 20280 100 0 20380 Open, Freeze Protected 2L-313 12433 ! 100 0 12533 Open, Freeze Protected Ms. Wendy Mahan AOGCC Fourth Quarter 1999 Annular Injection Report Page Two Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Well Files ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 27, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Second Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the second quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the second quarter of 1999. Annular Injection duEng the second quaner of 1999: h(1 ) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 1C-15 34380 100 0 32195 16795 48990 2L-313 3779 100 0 3879 8654 12533 CDI-19 33933 100 0 34033 0 34033 1C-25 34216 100 0 34316 0 34316 CD1-40 12071 100 0 12171 0 12171 1C-23 9505 100 0 9605 0 9605 Total Volumes into A~nuli for which Injection Authorization Expired during the quarter ;I'otal v . Total h(1) Total h(2) Total h(3) . Volume Well Name Volume Volume Volume Injected Status of Annulus 1D-10 35473 100 0 35573 Open, Freeze Protected 2N-323 32696 100 0 [ 32796 Open, Freeze Protected 17995 Open, Freeze Protected 2N-343 17895 100 0 2N-329 9 100 I 0 . 109 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader Ms. Wendy Mahan AOGCC Second Quarter 1999 Annular Injection Report Page Two CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Momson and Winfree Sharon Allsup-Drake Well Files 6/21/99 GeoQuest GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503 AI'rN: Sherrie NO. 12663 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Well Job # Log Description Date BL Sepia CD-R CD1-40 'I~-c'i'r~l~ 99251 ADN/CDR 990527 1 CD1-40 99251 CDR 990527 1 1 CD1-40 99251 CDR ~D 990527 1 1 CD1-40 99251 ~z~ 990527 1 1 :CD1-40 99251 ADN TVD 990527 1 1 CD1-40 99251 ADN/CDR 990527 1 1 SIGNE Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: Anadrill MWDILWD Log Product Delivery Customer Arco Alaska, Inc. ~~C~ Dispatched To: AOGCC Well No CD1-40 Date Dispatche 1-Jun-99 Installation/Rig Doyen 19 Dispatched By: Joey LeBlanc LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes , Perform Letter ,.~.z"----' /,J'o'"'~ ~('-('.,~, (~(~ .... Surveys (Paper) 2 Received By: { Anadrill LWD Division 3940 Arctic Blvd Anchorage, Alaska 99503 Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Annular Inlection 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 502' FNL, 2300' FWL, Sec. 5, T11 N, R5E, UM At top of productive interval 2140' FNL, 1144' FEL, Sec. 7, T11N, RSE, UM At effective depth At total depth 687' FSL, 156' FWL, Sec. 8, T11N, R5E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic _ Service _ 6. Datum elevaUon (DF or KB feet) RKB 57 feet 7. Unit or Property name Colville River Unit 8. Well number CD1-40 9. Permit number / approval number 99-44 10. APl number 50-103-20298 11. Field / Pool Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical -Casing Length Conductor 64' Surface 291 9' Production 1 1 985' Uner 12055 7156 12055 7156 Size 16" 9.625" 7" feet Plugs (measured) feet feet Junk (measured) feet Cemented Pre-installed 530 sx AS IIIL, 230 sx Class G 317 sx Class G ORIGINAL Measured Depth True vertical Depth 121' 121' 2976' 2400' 12042' 7150' Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth N/A Packers & SSSV (type & measured depth) N/A RECEIVED d '-' 1999 Naska 0il & Gas Cons. C0mmissi0r, Anchorage 13. Attachments Description summary of proposal_ Detailed operations program_ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: June 4, 1999 16. If pr, gpgsal was verbally approved Oil __ Name of approver Date approved Service __X 17. I hereby certify that t/I;~e for;going is true and correct to the best of my knowledge. // Signed Title: Drilling Team Leader Do~c/Chester '~.~ v ' - ~'/' v /'/ FOR COMMISSION USE ONLY Conditions of approv~. Notify Commission so representative may witness Gas __ Suspended__ Questions? Carl Brian Robertson 265-6034 Date 4/¢/7? Prepared b~/ Sharon AIIsup-Drake Plug integrity_ BOP Test _ Mechanical Integrity Test _ OEIGINAL SIGNED BY Approved by order of the Commission ~oJ~i't N. Christenson Form 10-403 Rev 06/15/88 · Commissioner SUBMIT IN TRIPLICATE Casing Detail 9 5/8" Csg Detail WELL: CD1-40 ARCO Alaska, Inc. DATE: 5/17/99 Subsidiary ol=Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Doyon 19 RKB to landing ring = 36.57' 36.57 FMC Gen V mandrel Hgr 2.29 36.57 26 jts 9 5/8", 36#, J-55 BTC Jt#47 - Jt #72 1068.90 38.86 9 5/8" TAM port collar 3.00 1107.76 44 jts 9 5/8" 36# J-55 BTC csg Jt #3 & Jt 46 1777.08 1110.76 9 5/8" Davis Lynch Float Collar 1.52 2887.84 2 its 9 5/8" 36# J~55 BTC csg Jt #1 & Jt #2 85.11 2889.36 9 5/8" Davis Lynch Float Shoe 1.77 2974.47 2976.24 TD>>> 2986.00 Rathole>>> 9.76 . · .... 43 Gemeco Bow Spring CENTRALIZERS .... Run centralizers in center of Jts. 1,2, over stop collars .... and over casin~l collars on Jts. 3-12 and over collars of ever~ 2nd it to surface. Run port collar between Jt'#46 and #47 1 straight blade centralizer on Jt#46 and Jt#47 Leave out 10 jts csg. Jts #73 - Jts #82 · ,,. Used Best-o-Life 2000 thread compound Remarks: '~ "~' Anchorage Doyon 19 Drilling Supervisor; Donald Lutrick CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-40 Date: 5/17/99 Supervisor: Donald Lutrick Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG Casing Setting Depth: 2,976' TMD 2,392' TVD Hole Depth: 3,006' TMD 2,411' TVD Mud Weight: 9.1 ppg Length of Open Hole: 30' 860 860 psi EMW = 0.052 x 2411 + Mud Weight - ~- 9.1 ppg 0.052 x 2,411' EMW = 16.0 ppg Pump output = .101 BPS Fluid Pumped = 1.2 bbl BLED BACK = lbbl TIME LINE: 2,800 psi 2,700 psi 2.600 psi 2,500 psi 2,400 psi 2,300 psi 2,2OO psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi .......... ~ ~_ JONE MINUTE TICK~ ~CASING TEST LOT SHUT IN TIME CASING TEST SHUT IN TIME TIME LINE 0 2 4 6 8 I0 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 ~ 70 72 74 76 78 80 82 84 86 88 stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE l ................... j..s. Lk.s. ....... .2.~.o..e~L. .................... ~_.s.t..k..s. ....... ~.g..o..e. sj... .................... .3...s. Lk.s. ....... .4..~..o..e~L. ................... .4...s.t..k..s_ ...... .4..8..o..e. sj... ................... ..5..sJ..k.s. ....... .s..4..o..e. sj... ................... ~..s.t..k..s. ...... .s..g..o..e.s.i .... .................... .?..s. Lk.s. ....... ~.~..o..e~.~ .... 8 stks 680 psi ................... . .9..s. Lk.s_: ...... 7.~.o..e. sj..., 10 stks 770 psi i 12 stks 860 psi ~ i ............... J ............... dl ................. i ............................... . ................. i i i i i I SHUT IN TIME SHUT IN PRESSURE .. j..o_m.j.n. ...................... _8~o..p.s.i__j 2.0 min 810 psi j "§i~-~Tr~ ...................... ~-'1~-~i'--i . .......... % ................................. .;---J 4.0 mtn 790 psi j 5.0 min 780 psi j 6.0 min ............... 770 psi j 7.0min ., 770 psi j ..8_..0...m.i_n. ................. 760 psi i 1 ....9...0._m..i.n_ .................. 760 psi J ,. j..o...o_m_i.n. _ .,, .............................. ' ................... ..4..s..t.k..s. ...... .6_6..0..R.s.i....j 6 stks 860 psi l ............... ............... ................... L2...s. Lk..s..... ! ,..Ls.o__.P..S. L ~ .................. L4.. ~.t.k..~...j, .S._8_0_ p.~!.j 16stks 1,790psi i i i ' i ............... ..L._Ls...s_t.k..s...L ~: .0_ .o.o_e.s.:. ................. _ .2.0. _.s.!.k..s. _ ._2.,.2..~.O...P..S. L .................. ..~3..s. Lk..s. .... ~:.4._s.o...p..sj_ 23 stks 2,520 psi ! ! ! i. .............. ,.~ .............. ,.1. ................ j i I i I SHUT IN TIME SHUT IN PRESSURE "'b-.-6"r;;[~"T ............... 10.0 min ,., ! 2,490 psi ":l',~:~'~J'r~' J .............. 1 2,480 psi J j'~:'~'~J'~l'I ........... ~ 2,470 psi, '~?'~-.~'~[~' j ............. | 2,460 psi j 30.0 min 2,460 psi i I- .............. -I', .............. -t' ................ i i r .............. '-r ............. "r" .............. I I L ............. ! ............. J ! I ! I .............. -L ............. -~ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-40 Date: 5/17/99 Supervisor: Donald Lutrick Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG Casing Setting Depth: 2,976' TMD 2,392' TVD Hole Depth: 3,086'TMD 2,465' TVD Mud Weight: 9.6 ppg Length of Open Hole: 110' EMW = 740 740 psi - + Mud Weight = + 9.6 ppg 0.052 x 2411 0.052 x 2,465' EMW = 15.4 ppg Pump output = .101 BPS Fluid Pumped = 4.2 BLED BACK = 1.6 TIME LINE · 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi -- 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi -- 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi stk stk stk slk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk slk stk stk stk slk stk stk stk stk stk stk slk stk stk stk stk stk stk stk stk s~k stk slk stk slk stk stk STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE I ................... .4.__s. Lk..s' ...... .s..~..o.._p.s.i...j 6stks . 660 psi j .................... ~';~'; ...... ¥~a",;~i'"l 10 stks 760 psi l ................... Z4._.sJ._k_s. ....... Z.~.9...p. sj__j 16 stks 760 psi J ............... 1 ............... ] ............. ';--- ............... l_j.B_eLkm_,._Z!.O._~_s_:...j 20 stks 700 psi J .................. &4._.s!.k..s. ..... Z.O..O.e. sj...j 26 stks 700 psi i .................. _2.~..s!.~.s. ...... Z.°..°_..P.s.i._i 30 stks 690 psi j .................. ~.2.._s.t..~..s. ..... ~.?..es._L..j ................... 9..4_s. Lk.s. ...... P.~.°_.Rs.i_.j 36 stks 680 psi j .................. ..3.8...s. Lk.s. ...... ~.~..o.._p. sj_.i .................. _4..o...s_t_.k.s._ ..... .s..s..o.._p.s..i_.j .................. .4~..s.t_.k_s_ ...... .s..s..o_.p_s._i...j ! I SHUT IN TIME SHUT IN PRESSURE -.'i~16-[fiiiT1 ............... i-'"~5-G-~i"-; .... : .......... ~ ............... '- ................ t -&-°-m-Ln--J ............... !-s-~-°.e-s]. ~ i__.2....O...m.j.n..l ............... j, 510 psi { 3.0min { j 500 ps{ j ................. , ............... ~ ................ ! 4.0min { { 500 psi j L.6:.o_._m_i.n_.j ............... .,', 490 psi ! 7.0 min ,. ................[ 490 psi j i 8.0min ~ ! 490 psi , 0 stks 140 psi j .................. -~.--ai~ ...... ................... ..4_s.!.k_s. ...... .6..6_.O._p..s.i_..j 6 stks 860 psi i lOstks 1,200psi 1 .................. !?_ .s.!.k_s_ _ !,..L~.9. P_s. L ................... Z')_.s.!.k..s. .... !,.s_sg_p_s.L 16 stks 1,790 psi ................... ................. '~'~9;ii~;' '~;~-:~'~-i;~;i" ................. ?A.s.!.k_s....,.~,s.?.o...p..sj.. , ............... -,- .............. .4- ................ 4 ! , , , , ; .............. ; .............. i ................ ] ! , I SHUT IN TIM.E.j. SHUT IN PRESS.U..~RE "'B'F6'-,~i'FF' ' ............................... 2,510 psi ~_ ..5.._0_ _m.i..n..., .................. .2., .4_g.0_ .p_s L ] 10.0 min I 2,490 psi 15.0 min, 2,480 psi '-~-D'.'6'~G-T ............... 2,470 psi "'~',~'.~-~'~' ................ 2,460 psi [-§b'.-O'~;r~i ............... 2,460 psi [ .............. ," ............................... i- .............. -i- ............................. I' .............. T ........................... I.. .............. ..i. ............. .~ ................ i 9.Omin i I 490 psi i ~ ................. { NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ARCO Alaska, Inc. Cementing Details Well Name: CD1-40 Report Date: 05/17/99 Report Number: 3 Ri(] Name: Doyon 19 AFC No.: 998B23 Field: Alpine I I Casing Size Hole Diameter: Angle thru KRU: I Shoe Depth: I LC Depth: % washout: 9.625 12.25 52 deg at TDI 2976'I 2887' Centralizers State type used, intervals covered and spacing Comments: Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: I CBU at 5 bpm. Increase to 9.5 Gels before: Gels after: Total Volume Circulated: bpm. 1000 bbls Wash 0 Type: Volume: Weight: Comments: FW 75 8.4 2 ppb Biozan Spacer 0 Type: Volume: Weight: Comments: ARCO Spa, cer 50 10.5 Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS III LWI 70 (leg 530 10.7 4.44 Additives: G+30%D053+0.6%D046+1.5%D079+1.5%S001+50%D124+9%D044 Comments: G 70 deg 230 15.8 . 1.15 Additives: G+0.2%D046+0.3%D065+1%S001 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 9.5 bpm 9.5 bpm 155k Reciprocation length: Reciprocation speed: Str. Wt. Down: 20' 10 fpm 130k Theoretical Displacement: Actual Displacement: Sir. Wt. in mud: 225 224.5 Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:5-17-99 yes yes Time:14:30 Remarks:RIH w/no problems. Circ and condition mud. No mud loss. Added Desco and water for thinner. Pumped 75 bbls viscosified FW wi nut plug ahead of spacer. Switched to tail when nut plug at shakers and MW dropped from 9.9 to 9.4. Had approx 90 bbls 10.7 cement to surface. Cement Company: Rig Contractor: Approved By: DS DOYON Dona d Lutrick Colville River Field CD1-40 Temporary Suspension Schematic Wellhead installed with tubing hanger and BPV set and pressure (] , tested to 3500 psi Diesel Freeze Protection in casing and annulus to 1200' TVD. r 16" Conductor to 121' 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2919' cemented to surface -9.7 ppg drilling mud in annulus i Updated 06/04/99 9.2 ppg brine with diesel freeze protection to 1200' TVD. Casing pressure tested to 3500 psi on p lugbump. 7" 26 ppf L-80 R3 BTC-Mod Production Casing at 11,985' @ 90 deg facsimile transmittal !'o: Blair Wondz¢ll - AOGCC ~ax: 276-7542 From: Brian Robcrtson Date: 95124/99 ............................ ~ ......................................................................................................................................................................................................................... , ,,, , ....................... Re: Disposal of Diesel / Methanol Pages: 1 El Urgent El For Review [3 Please X Please Reply !"1 Please Comment Reo, cle Further to my telephone message of Thursday 20 May. We are holding approximately 20 bbls of diesel/methanol (19 bbls diesel/1 bbl methanol) in a tank on the Alpine CD1 pad. This fluid was recovered from the diesel line from Kuparuk to Alpine when the line was commissioned last week, Previous information that this fluid would contain glycol was incorrect, Please confirm that we may dispos~of this fluid when freeze protecting the 9-5/8" x 7" annulus on the CD1-40 well that is currently being drilled, Best regards Brian Robertson 2.~,~- ~; o 3tt Drilling Engineer- Alpine ,= TONY KNOI/VLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION May 13, 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Doug Chester Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Colville River Unit CD1-40 ARCO Alaska. Inc. Permit No: 99-44 Sur Loc: 502'FNL? 2300'FWL, Sec. 5, T1 IN? R5E. UM Btmhole Loc. 687'FSL, 156'FWL, Sec. 8, TI IN? R5E, UM Dear Mr. Chester: Enclosed is thc approved application for permit to drill thc 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. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus ora well approved for annular disposal on the same drill site must comply with thc 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 thc annular space of a single well or to usc that well for disposal purposes for a period longer than one year. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that thc requirements of 20 AAC 25.080 arc met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10.403 prior to the start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allmv a representative of thc Commission to witness a test of BOPE installed prior to drilling nmv hole. Notice may be given by contacting thc Commission petroleum field inspector on thc North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dl ffEnclosurcs cc; Department of Fish & Game, t tabitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Bo.. , 00360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 May 6, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-40 Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is May 16, 1999. It is intended that Doyen Rig 19 be used to drill the well. The well will be drilled to horizontally penetrate the Alpine reservoir. It is intended that operations on this well be split into two distinct phases. The first visit by the drilling rig will drill the well down to the 7" intermediate casing point. The well will then be suspended and the rig moved onto other operations. At a later date, estimated at March / April 2000, the rig will return and the horizontal reservoir leg will be drilled prior to completion. Upon completion, the well will be closed in awaiting field start up. 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 · . 2. 3. 4. . 6. 7. 8. 9. 10. 11. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). Plat, identifying the property and location of the proposed CD1-40 well. A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Proposed suspension diagram. Proposed completion diagram. Proposed completion diagram with open hole isolation options. Pressure information as required by 20 ACC 25.035 (d)(2). Proposed cementing program and calculations. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robertson Senior Drilling Engineer ARCO Alaska, Inc, is a Subsidiary of Atlantic Richfield Company ECEirVED Oil & ~as Cons. C0mmissi0~ Anchorage AR3B-6003-C Attachments CC: CD1-40 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Lanston Chin ATO 1 O54 ANO 382 ANO 384 Kuukpik Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill / lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 57' feet Colville River Field 3. Address 6. Property Designation ~ Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25558//.2...,¢'..¢.5" ~ 4. Location of well at Surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 502' FNL, 2300' FWL, Sec.5, T11N, R5E, UM Colville River Unit Statewide At base of productive interval (=@ TARGET ) 8. Well number Number 2140' FNL, 1144' FEL, Sec. 7, T11N, R5E, UM CD1-40 #U-630610 At total depth 9. Approximate spud date Amount 687' FSL, 156' FWL, Sec. 8, T11N, R5E, UM 5/16/99 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD1-35 13,884' MD 502' at surface feet 50' (~ 333' feet 2560 7,119' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 96° Maximum surface 2517 psig At total depth (TVD) 3215 at psig 7000' 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 84' 37' 37' 121' 121' Pre-installed 12.25" 9.625" 36# J-55 BTC 2933' 37' 37' 2970' 2400' 546 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 11067' 37' 37' 11104' 7141' 186 sx Class G N/A 4.5" 12.6# L-80 IBT-M 11017' 37' 37' 11054' 7144' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Perforation depth: measured true vertical ~Jask~ 0ii & Gas Cons. 20. Attachments Filing fee X Property plat X BOP Sketch Diverter Sketch ~il~'~l~lJ~m X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby ce~fy¢, that the foregoing is true and correct to the best of my knowledge~"--~""~/¢/'~ Signed /~N.~ ~~,,,,,~ Title Drilling Team Leader Date. See cover letter for Perm um APl number Approval date ~,j,~. _ ?f .z o Other requirements L, on^ d't'~ons o approval Samples required.,,.,...~ Yes ~ Mud Icg required~ Yes (~ Hydrogen sulfide measures Yes ~No~ Directional survey required ('rr'es ~ No Required working pressure for DOPE 2M 3M ~ 10M 15M Other: ORIGINAL SIGNED'BY by order of Date~/~ Approved by F~QblBll; N~ Cl~dstenson Commissioner the commission Form 10-401 Rev. 7-24-89 Submit in triplicate Scate. 1" = ARCO EXHIBIT "1" Well Name: Alpine CD1-40 Surface Location: 501' FNL, 2302' FWL,Sec. 5, Tt1N, R5E, UM Target Location: 2140' FNL, 1144' FEL, Sec. 7, T11N, R5E, UM Bottomhole Location: 687' FSL, 156' FWL, Sec. 8, T11N, R5E, UM 2,000' 5-6-99 A~aska, ~nc, ~ APO '22 8 UTA 22 99050602A00 APC , UTA Surface Location / / Target Location Bottomhole Location VICINITY MAP NOT TO SCALE ~ 70+6 9 08 / 23+'22 / ~ 31 0+30 / 33°+32 ~++~ LEGEND ~++~ ~ ~ Ex~sT~C CONDUCTORS ~5+o~ + NEW CONDUCTOR LOCATION ~ Y o PLAN CONDUCTOR LOCATION ,~ & ASSOCIATES, INC ABCO A~aska, ~nc. ~k ~,~ ~oo~c~ ~ c~ ~ co~ouc~o~s S~bs~diory of AUont]c Richfield Compony AS-~U[~T LOCA~ONS LK663D1 3/5/99 ,CE-CD10-665D1 ~ oF 3 1 . 14.10.991MRT F A99001ACS ,, , .... ALL CONDUCTORS ARE LOCATED IN SEC 5, T 11 N, R 5 E, UMIAT MERIDIAN Sec Line O/S Well 'Y' 'X' Lat. (N) Lonq. (.W) FNL FWL Gnd Pad .... CD1-1 5,975,904.92 .385,999.99 70' 20' .34.9.22" 150' 55' .30.868" 222' 2,572'. 1.3.0' 19.5' CD1-2 5,975,897.89 .385,992.91 70' 20' 34.852" 150' 55' `31.071" 229' 2,565' 1.3.0' 19.5' CD1-3 5,975,890.99 385,985.82 70' 20' .34.783" 150' 55' .31.275" .2.36' 2,55S' 15.1' 19.5' CD1-4 5,975,883.8`3 .385,978.79 70'20' .34.711" 150'55' .31.478" 24.5' 2,551' 1`3.2' 19.i5' CD1-5 5,975,876.67 385,971.58 70' 20' `34.640" 150' 55' 31.685" 251' 2,544' 1`3.3' 19.5' C91-6 5,975,869.89 385,964.83 70' 20' 34.572" 150' 55' `31.879" 258' ...2,538' 13.4' 19.5' CD1-7 CD1-8 CDI-9 5,975,848.42 585,943..41 70' 20' 34.358" 150' 55' `32.495" 279' 2,5'17' 1.3.1' 19.'5' CDI-IO 5,975,841.34 585,936.18 70' 20' 34.287" 150, 55' `32.70.3" 286' 2,510' 1.3.0' 19.5' CD1-11 CD1-12 CD1-1`3 5,975,820.00 .385,915.06 70' 20' .34.074" 150' 55' `3`3..311" '.308' '2,489' 12.7' 19.5' CD1-14 5,975,812.97 .385,908.00 70' 20' .34.004" 150' 55' `35.514" 315' ,..2,482' 12.6' 19;5'... CD1-15 CD1-16 5,975,798.86 385,894.08 70' 20' 33.863". i50. 55' .:i3.914" 330' 2,468' "12.4' 19.5' CD1-17 5,975,791.81 385,886.84 70' 20' 33.793" 150' 55' 34.12`3" 537' 2,461' 12.3' 19.5' CD1-18 5,975,784.91 385,879.88 70' 20' 33.724" 150' 55' .34.`32`3" .344' 2,4.54' 12.2' 19.5' CD1-19 5,975,777.92 585,872.81 70' 20' ,3.3.654" 150' 55' `34.526" .351' 2,447' 12.1' 19.5' CD1-20 5,975,770.66 .385,865.67 70' 20' ,3.3.581" 150' 55' .34.732" .358' 2,440' 12.0' 19.5' CD1-21 5,975,765.76 385,858.49 70' 20' 3.3.512" 150' 55' 34.938" 365' 2,4`33' 11.9' 19.5' *CD1-22 5,975,756.46 `385,851.10 70' 20' 33.440" 150' 55' .34.151" .373' 2.426' 11.9' 19.5' CD1-2.3 5,975,749..31 `385,844.44 70' 20' 3.3..368" 150' 55' .35..342" .380' ...2,419' 12.0' 19.5' CD1-24 5t975,742.40 .385,8.37.30 70.' 20' .3.3.299" 150' 55' .35.548" .387' 2,412' 12.2' 19.5' CD1-25 5,975,7.35.34 385,8.30.26 70' 20' `3.3.229" 150' 55' `35.750" .394' 2,405' 12.4' 19.5' CD1-26 5,975,728.10 .385,823.14 70' 20' 3.3.156" 150' 55' 3,5.955" 401' 2,`398' 12.6' 19.5' CD1-27 5,975,721.21 `385,816.08 70' 20' `33.088" 150' 55' `36..158" 408' 2,.391' 12.8' 19.5' CD1-28 5,975,714.15 385,809.10 70' 20' 3.3.017" 150' 55' `36.359" 416' 2,.384' 1.3.0' 19.5' CD1-29 5,975,707.14 .385,802.20 70' 20' 32.947" 150' 55' .36.558" 422' 2,.3.77' 1.3.2' 19.5' CD1-.30 5,9,75,700.17 .385,794.75 70' 20' `32.877" 150' 55' .36.772" 4.30' 2,3.70' 1.3.4' 19.5' CD1 -.31 CD1-32 5,975,685.92 .385,7'80.68 70' 20' 32.7.35" 150' 55' 37.177" 444' 2,.356' 13.2' 19.5' CD1 -.3.3 CD1 -.34 CD1-`35 5,975,664.72 .385,759.63 70' 20' 32.524" 150' 55' `37.782" 466' 2,`3.35' 12.9' 19.5' CD1-.36 5,975,657.49 385,752.52 70' 20' 32.451" 150' 55' 37.987" 473' 2,.328' 12.8' 19.5' ..C_D1-.37 5,975,650.51 .385,745.40 70' 20' 32.381" 150' 55' 38.191" 480' 2,.321' 12.7' 19.5' CD1-.38 5,975,643.79 .385,7.38.44 70' 20' 32.315" 150' 55' 38.391" 487' 2,`314' 12..6' 19.5' CD1-.39 5,975,656..34 .385,7.31.37 70'.20' 32.240" 150' 55' 38.595;' 495' 2,.307' 12.5' 19.5' CD1-40 5,975,629.19 .385,724.32 70' 20' .32.168" 150' 55' 38.797" 502' 2,.300' 12.4' 19.5' CD1-41 5,975,622..37 .385,717.40 70' 20' 32.101" 150' 55' 38.997" 509' 2,29.3' 12..3' 19.5' CD1-'42 5,975,615.01 385,710.21 70' 20' 32.027" 150' 55' 39.204" 516' 2,286' 12.2' 19.5' CD1-43 5,975,607.63 .385,702.97 70' 20' 31.954" 150' 55' 39.412" 52.3' 2,279' 12.1' 19.5' ....CD 1... 44 CD1-45 5,975,593.74 .385,689.04 70' 20' .31.815" 150' 55' 39.813" 538' 2,265' 12.'0' 19.5' * CD1-22 CONDUCTOR WAS AS-BUILT 2/11/98. '- _ ~ LOUNSBURY ~/J,5~_ & ASSOCIATES, INC. ARCO Alaska, Inc. ALPINE PROJECT ~' CD1 WELL CONDUCTORS Subsidiary of Atlantic Richfield CompanyAS-BUILT LOCATIONS LK66.3D! ..... 5/5/99 CE-CD10-663D1 2 OF 3 1 ,.~vI o^~ i.~ i~ i ^..i ~.. ~ 14/~O/991MRTIAJ. RI I ;r A99001ACS DESCRIPTION NOTES 1. ALL COORDINATES ARE ALASKA STATE PLANE, ZONE 4, NAD 27. 2. ELEVATIONS ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS ARE INTERPOLATED FR~M MICHAEL BAKER JR. DWG. CE-CDIO-102, SHT 1, REV. O. 3. BASIS OF LOCATION AND ELEVATION ARE TEMPORARY ALPINE MONUMENTS 3 & 4 BY LOUNSBURY & ASSOCIATES.' 4. DATE OF SURVEY: WELL CONDUCTORS 10, 13, 14, & 16-19 WERE AS-BUILT 3/10/99, REF. FIELD BOOK L99-20, PAGES 3--11. CONDUCTORS 1-3 WERE AS-BUILT 3/25/99, REF: FIELD BOOK L99-24, PG. 28-31, CONDUCTORS 4-6, 9, 20, 21, 23-30, & 35 WERE AS-BUILT 3/29/99, REF: FIELD BOOK L99-23, PG. 65, 67-73. CONDUCTORS 36-43, & 45 WERE AS-BUILT 4/6, 4/9/99, REF: FIELD BOOK L99-26, PG. 35-38, & 48, ~nchorag~ ARCO Alaska, Inc. Subsidiory of Atlontic Richfield Compony LK663D1 3,,/'5/99 SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 4/09/99. LOUNSBURY ASSOCIATES, INC. E~NEERS PLANNERS SURVEYORS CE-CD10-663D1 ALPINE PROJECT CD1 WELL CONDUCTORS AS-BUILT LOCATIONS J SHE£T: J , 3 OF'3 REV: Alpine: CD1-40 PROPOSED DRILLING PROGRAM . 3. 4. 5. 6. 7. . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Procedure Move in drilling rig. Install diverter and function test. (16" conductor pre-installed) Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 1/2 hole to the intermediate casing point in the Alpine Reservoir. Note LWD will be run over this section. Run and cement 7 inch casing as per program. Displace cement with brine. Top of cement 500 feet above Alpine reservoir as per Rule 20 AC 25.030. Freeze protect casing annulus and casing. Suspend well and move off rig. Move in drilling rig. Install and test BOPE to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test. Drill 6 1/8" horizontal section to well TD. Contingency- set ECP scab liner or slotted liner if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). - See Note 1. Displace well to weighted brine and pull out of hole. Run liner hanger (without liner) with flapper valve and 2 7/8" displacement string. Displace horizontal section to diesel. POH. Run 4 Y2, 12.6 #, L-80 tubing and sting into liner hanger. Freeze protect completion with diesel. Test tubing and tubing-casing annulus separately to 3500 psi. Nipple down BOP. Nipple up x-tree. Pressure test to 5000 psi. Set BPV and secure well. 21. Move rig off. Note 1 :The Alpine development wells will have open hole completions. Rock mechanic studies have indicated that there is sufficient rock strength to maintain wellbore stability throughout the life of the well. However this assumes that a. the 6-1/8" horizontal well stays within the sand section over it's full length and b. the well does not cross any weaker formations (e.g. faulted or fractured zones). In the event that the conditions described in either a. or b. are seen while drilling the horizontal section, it will be necessary to cover these sections. The proposed methods for doing this is utilize ECP liner assemblies. The attached drawing shows the various options for formation isolation that are proposed. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-35 will be the closest well to CD1-40 (49.6' at 333' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 47.8' at 356' MD. Note that CD1-35 has not been drilled at the time of this permit application. These figures are based upon direction planning files. Drillinq Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. There are no mapped faults within 500 ft of the proposed target polygon; therefore the likelihood of incurring severe lost circulation is considered Iow. Good drilling practices will be followed to ensure that mechanically induced losses are kept to a minimum. 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. There is potential for differential sticking in the reservoir. The BHA design and 9.2 ppg mud weight have been developed to minimize this potential. However; vigilance through careful adherence to the directional plan will be required to ensure that wellbore geometry does not aggravate the potential for differential sticking. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD1-40 will be injected into the annulus of a permitted well. The CD1~40 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing. 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 0D1-40 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 at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi CD1-40 DRILLING FLUID PROGRAM SPUD to Intermediate hole to Production Hole 9-5/8"surface casing 7" casing point - 8 Y2" Section - 6 1/8" point- 12 ¼" Density 8.8 - 9.6 ppg 9.4 - 10.0 ppg 9.2 ppg PV 10 - 25 12 -18 YP 20 - 60 15 - 25 35 - 45 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 18 - 22 10 minute gels <18 23 - 27 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min HPHT Fluid Loss at 160 8.5 - 9.0 9.0 - 10.0 <10 cc/30 min pH 9.0 - 9.5 Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _ 200 sec/qt while drilling permafrost and gravel, then reducing to 100-120 sec/qt by casing depth. Pump hi-vis sweeps if needed for supplemental hole cleaning. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 10 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and FIo-Trol starch will be used for viscosity and fluid loss control respectively. Colville River Fielo CD1-40 Temporary Suspension Schematic Wellhead installed with tubing hanger and BPV set and pressure tested to 3500 psi Diesel Freeze Protection in casing and annulus to 1200' TVD. [ 16" Conductor to 121' 9.8 - 10.0 ppg drilling mud in an,nulus 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2970' MD / 2400' TVD cemented to surface 9.2 ppg brine with diesel freeze protection to 1200' TVD. Updated 05/04/99 7" 26 ppf L-80 R3 BTC-Mod Production Casing at 11104' MD / 7141' TVD @ 90 deg Colville River Field CD1-40 Production Well Completion Plan 16" Conductor to 121' 9-5/8" TAM Port Collar @ +/- 1000' 4-1/2" Camco TRM-4PE-CF (5.937" OD, 3.812" ID) SSSV and DB-6 Lock (3.812" ID) with single 1/4" x 0.049" s/s control line @ 1,000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2970' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-5 Top Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Packer Fluid mix: 9.2 ppg KCI Brine with 1200' TVD diesel cap Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-5 Top Latch 4-1/2" Tailpipe Assembly: (~)- Baker GBH-22 seal assembly (3.958" ID) with 12' stroke, combo nitrile/viton seals TOC 500' MD above Alpine @ +/- 9997' MD / 6802' TVD HES "X" (3.813" ID) Set at 60-65 deg Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2900 psi set 2 joints above the X landing nipple Baker Packer set +/-50' above 7" shoe ®(Z) 7" 26 ppf L-80 BTC Mod Production Casing @ 11104' MD / 7141' TVD, 90 deg Packer Assembly (~)- Baker SLZXP Dbl Grip ZX Liner Packer (4.75" ID) with 12' Type 2 Extension on top (~)- 4-1/2" joint (1) blank pipe (3.958" ID) (~)- HES "XN" (3.725" ID) landing nipple (~- 4-1/2" x 10' pup joint w/centralizer (~- Baker Model 'C' KOIV flapper check (3.81" ID) (~)- 4-1/2" joint (1) blank pipe (3.958"1D) (~- 1/2 muleshoe joint Well TD at 13884' MD / 7119' TVD Updated 5/4/99 Colville River Field CD1-40 Production Well Completion Plan (w/ Isolation Options) 16" Conductor to 121' 9-5/8" TAM Port Collar @ +/- 1000' 4-1/2" Camco TRM-4PE-CF (5.937" OD, 3.812" ID) SSSV and DB-6 Lock (3.812" ID) with single 1/4" x 0.049" s/s control line @ 1,000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2970'MD /2400'TVD cemented to surface Packer Fluid mix: 9.2 ppg KCI Brine with 1200' diesel cap Camco KBG-2 GLM (3,909" ID) at 3400' TVD for E Dummy with 1" BK-5 Top Latch 4-1/2" Tubing Tailpipe Assembly; (~) - Baker GBH-22 seal assembly (3.958" ID) with 12' stroke, combo nitrile/viton seals, 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-5 Top Latch Hydraulics Set Liner Hanger Packer Assembly (~ - Baker SLZXP Packer (4.75" ID) with 12' Type 2 Extension on top (~) - 4-1/2" joint (1) blank tubing (~) - HES "XN" (3.725" ID) LN Q - blank 4-1/2" liner (TBD) Q - Baker Payzone ECP (~) - 4-1/2" joints (2) blank tbg ~ - Baker Model 'C' KOIV (~) - 4-1/2" joint (1) blank tbg ~ - wireline entry guide with ECP cement inflated TOC +/- 500' MD above Alpine HES "X" (3.813" ID) Set at 60-65 deg Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2900 psi set 2 joints above the X landing nipple Baker packer +/-150' above 7" shoe 7" 26 ppf L-80 BTC Mod Production Casing 11104' MD / 7141' TVD@ 90 deg Open Hole Scab Liner (~)- Baker Payzone ECP (~) - 4-1/2" joints (TBD) blank tbg with centralizers as required (~) - Baker Model XL-10 ECP with ECP's cement inflated Open Hole Bridge Plug (~)- Baker Payzone ECP (~- 4-1/2" joints (TBD) blank tbg and centralizers as required (~- 4-1/2" guide shoe with ECP's cement inflated ® ® ): .......... ...u. ........... ...................................... ............ ..u.. .... : 4-1/2" 12.6 ppf L-80 blank IBT Mod. liner Well TD at 13884' MD / 7119' TVD Updated 5/4/99 CD1-40 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 the Alpine CD1-40 well · Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 121 / 121 10.9 52 56 9 5/8 2970 / 2400 14.2 1086 1532 7" 11104 / 7141 16.0 3231 2517 N/A 13884 / 7119 16.0 3221 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 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]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP- (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point . ASP CALCULATIONS Drilling below conductor casing (16") . ASP = [(FG x 0.052) - 0.1} D = [(10.9 x 0.052)- 0.1] x 121 = 56 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') - 846 psi Drilling below surface casing (9 5~8") ASP = [(FG x 0.052) - 0.1} D = [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR ASP - FPP - (0.1 x D) = 3231 - (0.1 x 7141') = 2517 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3231 - (0.1 x 7141') = 2517 psi Alpine CD1-40 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 5OO -500 -1500 -2500 -3500 PR -4500 -5500 -6500 -75OO 9 10 11 12 13 14 15 EQUIVALENT MUD WEIGHT & Gas Cons. Commissio~ Anchorage Alpin=, CD1-40 Well Cementinq Requirements 9 5/8" Surface Casing run to 2970' MD/2400' TVD, TAM port Collar @ +/- 1000' MD Cement from 2970' MD to 2470 (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2470 to surface with Arctic Set Lite 3. Assume 500% excess annular volume in permafrost and 50% excess belowthe permafrost. -- ~ Lead slurry: (2470'-896') X 0.3132 ft3/ft X 1.5 (50% excess) = 739.5 ft3 below permafrost 896' X 0.3132 ft3/ft X 6 (500% excess) = 1683.8 ft3 above permafrost Total volume = 739.5 + 1683.8 = 2423.3 ft3 => 546 Sx @ 4.44 ft3/sk System: 546 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 11104' MD/7141' TVD Cement from 11104' MD to +/- 9997' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (11104' - 9997') X 0.1268 ft3/ft X 1.4 (40% excess) = 196.5 ft3 annular volume 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 196.5 + 17.2 = 213.7 ft3 => 186 Sx @ 1.15 ft3/sk System: 186 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3/sk ~ By Weight Of mix Water, all other additives are BWOCement Created by jones For: B Robertson Date platted: 20-Apr-1999 Plot Reference Is CD1-40 Version ~4. Coordrnates ore tn feet reference slot il40. True Verticol Depths 2~n~ Estimated RKB. Alaska, Inc. Sfrucfure: CD#1 Field : Alpine Field Well : 40 Location : Norfh Slope, Alaska 450 450 go0 1550 1800 2250 2700 5150 5600 4050 4500 4950 54O0 585O 6500 6750 72OO 7650 451 EsUmoted RKB ELEVATION: 57' KOP 5.00 DLS: 3.00 deg per 100 ft 6.00 9.00 Benin Turn [o Target 1 t.84 = 14.87 17.56 Permafrost 20.48 West Sok 26.37 52.29 38.24 44.20 50.17 EOC C40 g 5/8 Casing Pt C30 i , i [ i i l 0 450 900 1550 C20 207.65 AZIMUTH 7716' (TO TARGET) ***PLANE OF PROPOSAL*** TANGENT ANGLE 51.~ 1 DEG K-5 K-2 Albion -97 Albion -96 TARGET ANGLE 90.45 DEG Begin F~nal Build & Turn LqU Miluveoch A Alpine D Alpine i I i i I i i i i i i ii i i ~800 ~250 2700 3~'50 ~600 4050 4500 4950 Verficol Secfion (feef) -> 5400 5850 6500 Azimufh 207.65 wifh reference 0.00 S, 0.00 E from sial #40 HRZ K-1 52,97 61.86 i i i i i 6750 7200 7650 Created i~/~ones For: B RoberLson Dote plotted: 20-.a~or-1999 Plot Reference Ts CD1-40 Version Coordinates are ~n feet reference slot 1~40. Tru, V, rt'cal Depth .... fslic Est,meted ,KB. I i~?][q I ANCO Alaska, ][nc Structure : CD#1 Field : Alpine Field Well: 40 Location : North Slope, Alaska 207.65 AZIMUTH 7716' (TO TARGET) ***PLANE OF PROPOSAL*** 6700 · '~ 6800 6900 ~ 7000 71 O0 7200 7300 I V 7400 TANGENT ANGLE 90.45 DEG ~ TD i i t i i i i i i i i i i i i i i i i i i i i i i i i I i i i i i i i i i i i i i i i ~ i i 7200 7500 7400 7500 7600 7700 7800 7900 8000 81 O0 8200 8500 8400 8500 8600 8700 15800 8900 9000 91 O0 9200 9500 9400 Vertical Section (feet) -> Azimuth 207.65 with reference 0.00 S, 0.00 E from slot #40 Created by jones For: B Robert~on Date plotted: 20-Apr-lgg9 Plot Reference is CD1-40 VemTon #4. Coordinates ore in feet reference slot i~4-0. i:rue Vertical Depths are reference Estimated RKB. · 45O 450 900 1350 1800 225O 2700 5150 3600 405O 495o- I V 54oo 585O 63OO 675O 7200 765O 8100 8550 go00 9450 9900 4.50O i 4500 Alaska, Structure: CD#1 Field : Alpine Field 40,~U 5600 3150 2700 I II II II ESTIMATED SURFACE LOCATION: 501' FNL, 2502' FWL SEC. 5, T11N, R5E Inc. K-1 LCU F~nal BuTId & Turn Alpine D iluveach A Bose Alpine i i i i i i 4050 5600 5150 2700 Well: 40 Location :Norfh Slope, Alaska FGT - Dpst PT - EOT TAEGET - 7 Csg Pt -EOC <- West (feet) 2250 1800 1350 I I I I I i i i i i i i 2250 1800 1350 <- West (feet) 900 450 0 Begin Turn [o Targef. I Wes[ Sak 450 900 I I I 9 5/8 Casing 'C50 TARGET LOCATION: 2140' FNL, 114¢' FEL SEC. 7, T11N, RSE TD LOCATION: 687' FSL, 156' FWL SEC. 8, T11N, R5E i i i i i i i 900 450 0 450 i 9OO 45O 45O 900 1350 1800 22.5O 2700 5150 5600 4O5O ~ 0 --I- 4500 ~ 4950 ~ I 5400 V 5850 63OO 6750 7200 7650 B100 8550 9000 9450 9900 Cre<3ted by jones For: B Eobertson Dote platted: 20-Apr-lggg Plot Reference is CD1-40 Version Coordinates are in feet reference slot ~40. ARCO Alaska, Inc. Structure: CD#1 Field : Alpine Field Well: 40 Location : North Slope, Alaska Deg/1 001 Point KOP Begin Turn to Target Permafrost West Sa k EOC C40 C50 9 5/8 Casing Pt C20 K-3 K-2 Albian-97 Albian-96 HRZ K-1 Begin Final Build & LCU Miluveach A Alpine D Alpine Base Alpine TGT - Dpst PT - EOT iEnd Angle Build Begin Angle Drop TARGET - 7 Csg Pt - TD MD 300.00 655.55 896.34 1072.00 2O54.67 2645.76 2965.00 2969.79 3571.55 5215.64 5582.77 8439.97 8998.64 9760.0`3 10047.55 10148.86 10199.95 10410.O6 10459.66 10496.51 10755.56 1 0883.09 10945.65 11046.28 11103.83 13884.19 PROFILE tnc 0.00 10.00 17.45 22.59 51.21 51.21 51.21 51.21 51 21 51 21 5121 51 21 51 21 51 21 51.21 51.21 52.97 62.58 64.98 66.98 82.04 90.00 95.63 95.63 9O.45 90.45 COMMENT DATA Dir TVD North East V. Sect 189.00 300.00 0.00 0.00 0.00 189.00 651.64 -28.66 -4.54 27.49 200.39 887.00 -88.27 -21.88 88.34 203.81 1052.00 -143.86 -44.69 148.18 210.75 1814.16 -646.10 -316.99 719.42 210.75 2197.00 -1055.42 -560.55 1195.02 210.75 2397.00 -1269.25 -687.79 1443.48 210.75 2400.00 -1272.45 -689.70 1447.21 210.75 2777.00 -1 675.53 -929.55 1915.55 210.75 3807.00 -2776.76 -1584.85 3195.12 210.75 4037.00 -3022.67 -1731.17 3480.85 210.75 5827.00 -4936.46 -2869.99 5704.57 210.75 6177.00 -5510.67 -5092.66 6159.58 210.75 6654.00 -5820.66 -5596.1 5 67,31.96 210.75 6834.00 -6015.11 -3510.65 6955.57 210.75 6897.60 -6081.10 -5551.11 7054.58 205.57 6929.00 -611 6.66 -5570.04 7074.86 185.88 7042.00 -6286.57 -3615.93 7246.67 181.83 7064.00 -6330.92 -5618.91 7287.55 178.94 7079.00 -6364.56 -5619.15 7517.2,3 160.64 7148.00 -6606.22 -3574.14 7510.42 152.10 7157.00 -6724.58 -3522.40 7591.08 152.10 715`3.9`3 -6779.59 -3493.17 7626.42 152.10 7144.05 -6868.09 -5446.31 7683.08 151.9..5 71 41.00 -6918.82 -5419.35 771 5.51 151.93 7119.00 -9371.98 -2110.94 9281.45 O.t 5.00 3.00 `3.00 ,3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O.C 0.00 0.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 0.00 9.00 0.00 Creot.d by ]on~,, For: B Rober~son Dote plotted: 2fl-Apr-1999 A ';C 0 Alaska, Structure : CD#1 Field : Alpine Field Well: 40 Location : North Slope, Alaska ,*8O 440 400 560 320 280 160 I 120 BO -I.- 0 40 Z 240 200 %%6100 ~ 6100 ~ 6000 ~ 6000 East (feet) -> 24-0 200 ! 60 120 80 4-0 0 4-0 80 120 160 200 240 280 I I I I I I I I I I I I I I I I I I I I I I I I 70 3 ~1100 /3800 \ ooo /7,00 ,,oo /, oo ~, 800 x.. 700 ~oo /3500 ~oo /a~oo ~40~ 900 ~~ 1100 1200 ~ ~ 1500 ~5900 5800 \ % 5700 \ X 5600 %5500 5400 ~ ~_.~_ ._~___~500 0 ~)100 ~500 ~ 600 40 / 700 ~ 800 / 80 Z goo / /lOOO 12o ~ / Zl100 160 ~ 1100 / Z12oo 200 ~ 1200 / 240 ~/1300 ~1300 / 280 ~1400 I i i i i i i i [ I i i i i i i i i [ i i i i I 240 200 160 120 80 4-0 0 4-0 80 120 160 200 240 280 East (feet) -> 480 440 400 36O 320 280 24-0 200 160 I 12o Z 0 80 40 12O 160 200 240 280 ARCO Alaska, Inc. ~ Kuparuk Unit Disbursement Account P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: ALASKA DEPT OFf:REVENuE ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE :'DRIVE' 230096191 APRIL 30, 1999 *** .: VOID AFTER 90 DAYS *** : : . . 73-426 839 ~'. : EXACTLY *********** 100 :DOLLARS AND O0 CENTS $*********** 100.00 . . . The First National Bank of Chicago-0710 Chicago, Illinois ~ / ¢~ Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 230096191 0997587 ,' 8 ~OOCir. &el &,' ,:DS 5ciOh 8B 8,: OCiC~ ? 58 ?,' ARCO Alaska, Inc. CD~I 40 slot #40 Alpine Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : CD1-40 VersionS4 Our ref : prop3029 License : Date printed : 20-Apr-99 Date created : 1-Jul-98 Last revised : 19-Apr-99 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 32.169,w150 55 38.801 Slot Grid coordinates are N 5975629.228, E 385724.229 Slot local coordinates are 501.00 S 2301.71E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath CD1-35 Version #4A,,35,CD~1 CD1-24 Version#4A,,24,CD~l PMSS <0-10548'>,,19,CD~1 PMSS <0-10255'>,,WD2,CD~1 PMSS <0-9714'>,,22,CD~1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 22-Mar-99 49.6 333.3 333.3 13-Apr-99 160.0 300.0 300.0 19-Apr-99 209.2 311.1 311.1 13-Apr-99 1323.5 200.0 200.0 1-Apr-99 179.4 300.0 300.0 , ./ WELL,PERMIT CHECKLIST COMPANYA,,~"~...<-~ WELL NAME~--,~ff-~ ~ / -- ~ ~ PROGRAM: exp ~ FIELD & POOL /.Z~/~..2 INIT CLASS ~_..~.,, _/ ADMinISTRATION 1. Permit fee attached ....................... 2. 3. ENGINEERING Lease number appropriate ................... 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 ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9, Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. 35. GEOL Y N Y. N Y N Y N Y N Y N Y N Y N Y N Y N Y N GEOLOG~Y ANNULAR DISPOSAL AREA Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Y N Conductor string provided ................... C~ N Surface casing protects all known USDWs ........... ~ N CMT vol adequate to circulate on conductor & surf csg ..... ~ N CMT vol adequate to tie-in long string to surf csg ........ Y N CMT will cover all known productive horizons .......... 4,~ N Casing designs adequate for C, T, B & permafrost ....... (~ N Adequate tankage or reserve pit ................. (~) N If a re-drill, has a 10-403 for abandonment been approved... ,¥---N" Adequate wellbore seParation proposed ............. (~ N If diverter required, does it meet regulations .......... ~;~ N Drilling fluid program schematic & equip list adequate ..... ;i~ N BOPEs, do they meet regulation ................ (~) N BOPE press rating appropriate; test to ~O psig. Y N Choke manifold complies w/APl RP-53 (May 84) ........ Y N Work will occur without operation shutdown ........... Y (~) Is presence of H2S gas probable ................. Y q.7./J~ Permit can be issued w/o hydrogen sulfide measures ..... Y N Data presented on potential overpressure zones ....... /7 Seismic analysis of shallow gas zones ............. y--/. Seabed condition survey (if off-shore) ............. / ' Contact name/phone for weekly progress reports [exploratory o~] Y N With proper cementing records, thisplan /~)01,u. Jc.~ pr..x~/2~,'~ FT.~t/.c;~'/~ (A) will contain waste in a suitable receiving zone; ....... Y (B) will not contaminate freshwater; or cause ddlling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N dev ~ redrll ~ serv ~ wellbore seg ~ APPR DATE ann. disposal para req ~ UNIT# ...~'"O ~'4::~ ON/OFF SHORE GEOLOGy: ENGINEERING: UIC/Annular COMMISSION: JDH . .-..,~...__ co c.,o ~]/~/~ Comments/Instructions: O Z O ITl c:~soffice\wordian\diana\checklist