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207-180
• lr~~l~lg~ PrOj~l~:# V1/e!I ~-~is#Ory ~~~~~ ~OV~r P~~~ xt-~vzc This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - ~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided III II'lII II III II III ^ Rescan Needed III IIIIII II II III III RESCAN DI TAL DATA OVERSIZED (Scannable) ^ Color Items: Diskettes, No. ~ ^ Maps: ~Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: BY: _ Maria Date: ' ;~ ~` ^ Other:: /s/ Project Proofing II I II ~I II I I III I I III BY: Maria Date: ~ ~ /s/ Scanning Preparation _ 1 x 30 = ~ ~~ + ~ = TOTAL PAGES I ~- ~ BY: Maria Date: ~ ~; ~ ~ ~ ~ t~ ~COUnt does not i ~S~ude cover sheet) ~ n A ,~ ' L/ I Production Scanning Stage 1 Page Count from Scanned File: ~~ :~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~ES NO BY: Maria Date: 1 ~ 3 ~ /s/ !/ ~~ r Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II I II II I (III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III II'II) III IIII III 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS sc.i` stts 1. Operations Performed: Abandon J Repair w ell r Plug Perforations r Stimulate [ Other r Alter Casing E Rill Tubing r Perforate New Pool r Waiver fl Time Extension Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 207 -180 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50 - 103 - 20557 - 0 0 7. Propel Designation (Lease Ntunber): 8. Well Name and Number: ADL 380077, 384211, 372097, 380082 ' CD4 - 301 B 9. Field/Pool(s): . ,120 u'k L {'�, V1 ' a + i )01f Colville River Field / NarTaq- KU{22: Oil Pool e 10. Present Well Condition Summary: Total Depth measured 18806 feet Plugs (measured) None true vertical 6919 feet Junk (measured) None Effective Depth measured 18799 feet Packer (measured) 13429 true vertical 6919 feet (true vertucal) 6566 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 2999 9 -5/8" 3035 2387 INTERMEDIATE 14821 7" 14855 6911 LINER B 4105 3.5" 18799 6919 96444 ED APR 2 5 201r RECEIVED' Perforation depth: Measured depth: 15051'- 17953', 18078'- 18672' True Vertical Depth: 6904'- 6914', 6907' -6906' ' r r} 2 5 2011 Ata ka Oil & Gas Cos. Candliniee Tubing (size, grade, MD, and TVD) 3.5, L - 80, 14716 MD, 6900 TVD Packers & SSSV (type, MD, and TVD) PACKER - PACKER - PREMIER @ 13429 MD and 6566 TVD SAFETY VLV - CAMCO TRMAXX - 5E SSSV @ 2218 MD and 2003 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 15051' - 17953; 18078'- 18672' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 842 2567 1090 -- 305 Subsequent to operation 541 1762 1363 -- 306 13. Attachments 14. Well Class after work: - Copies of Logs and Surveys run Exploratory r Development 1' '' Service r Stratigraphic 15. Well Status after work: - Oil Gas r WDSPL fl Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r 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 Tim Schneider @ 265 -6859 Printed Name Tim Schnei Title Staff Production Engineer Signature Phone: 265 -6859 Date ) A.---ti( I Of —( ( 71 `( Zf !( Form 10 -404 Revised 10/2010 RBDAAS APR 25 21 bmit Ori inal Only CD4 -301B: Scale squeeze pumped 4/2/2011; initial TBG /IA /OA, 299/1382/615 psi; facility pumped 50 bbl pre -flush with injection water; LRS pumped 165 gallons WAW5206 at 0.4 bpm while facility pumped 35 bbls injection water at 4 bpm, 95/1385/665; LRS pumped 1650 gallons SCW4004 at 0.65 bpm while facility pumped 222 bbls injection water at 4.4 bpm, VAC/1343/658; facility pumped over - displacement with injection water at 3.6 bpm; well shut in for 12 hours and returned to service. � r' y t WNS CD4-301B •ps q �� Well Attributes Max Angle Sr MD Alaska Btm API /UWI IF Id N c1 IWell Status Intl IMO Act Btm(11KB) MO 5010320557C2 NANUQ KUPARUK PROD 92.26 14,909.23 _ uxxxoottaltps - I Comment H2S (pp n) Date An t tion End Date KB (M Rig Release Date - SSSV TRDP 1 _ - I - _, . , Last WO: 36.90 4/17/2008 -w 17if#�II� a= CI? 2 06 42 PM .: _ _ -. - - _ SchF.tetig�AGtual _ Annotation Depth IftKB) End Date A.notation Last Mod By End Date Last Tag: Rev Reason- GLV C/O Imosbor 1/27/2009 MANGER,31 , Casing Strings Casing Description String 0... String ID ... Top (f5106) Set Depth (f... Set Depth (1VD) ... String Wt... String String Top Thrd CONDUCTOR 16 15250 36.0 114.0 114.0 65.00 H - 40 1 y . p Casing Description String 0... String ID ... Top (fHCB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.835 35.7 3,035.1 2,380.7 40.00 L I i Gating Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd I . INTERMEDIATE 7 6.276 34.0 14 855.0 6,901.2 26.00 L-80 CasDescription String 0... String ID ._ Top (ftKB) Set Depth (f... Set Depth (ND) ... String WI.. String ... String Top Thrd LINER B 3 1/2 2.992 14,694.4 18,799.0 9.30 L - 80 SLHT CONDUCTOR, 38.114 • PACKOFF 4.400 1, Top Depth OW Top Inc' To fIKB OHO/ (*) Item Descd n Comment ID in ,���'; 14,711.1 6,900.0 87.62 HANGER 'DG' Flex Lock Liner Hanger 4.400 • u 14,721.1 6,903 4 93.63 XO Bushing XO Bushing 4.400 • lir Tubing- Strings Tubing Description String 0... String ID ..ITop (HKB) ISM Depth (f...ISet Depth (TVD) ... String Wt._ String ... String Top Thrd ilto _ TUBING 3 1/2 2.992 31.3 14,716.2 6,900.2 9.30 L-80 EUE SSSV, 2,218 - - - Completion Details Top Depth (ND, Top loci Top MKS) (HKBI (l Item Description Comment ID (in) 31.3 3t3 0.04 HANGER TUBING HANGER 3.958 147.4 147.4 0.70 X0 CROSSOVER 3.500 { 2,218.2 2002_.') S1 23 SSSV TRMAXX -5E SSSV 2.812 13,428.7 6,56 b 8 E 3 55 PACKER Packer - Premier 2.875 SU6FACE,36 - 3.035 - . ` 13,512.1 6,602.1 64.79 NIPPLE XN Nipple 2.750 14,715.2 6,900 2 87.89 WLEG Wireline Guide Muleshoe 3.000 i GAS LIFT, t ) ' Perforations & Slots 5,866 Shot ,," Top (TVD) Ben (TVD) Dens Top MKS) Btm (ftKB) (MB) MKS) Zone Date (sh -. Type Comment 15,051 17,953 6,904.1 6,913.6 4/17/2008 32.0 Slots 18,078 18 672 6,907.0 6,905.6 4/17/2008 32.0 Slots I Notes: General & Safety End Date Annotation 4/17/2008 Note: VIEW SCHEMATIC w /9.0 L. GAS LIFT, 11,351 GAS LIFT,_ 13,343 PACKER. . : ....,,: 13,429 -- at NIPPLE, 13,512 ril I. ili t4; '" , WLEG, 14,715 Mandrel Details Top Depth Top - - -_ Port - -- (TVDI Intl OD Valve Latch Size TRO Run Stn Top&KB) (ftKB) (°) Make Model (In) Sere Type Type (in) (psi) Run Date Can... NTERMEDIATE, 1 5,863.8 3,416.4 68.25 CAMCO KBMG 1 Gas Lift DMY BK-5 0.000 0.0 4/17/2008 34 14'855 2 11,350.7 5,61 59.12 CAMCO KBMG 1 Gas Lift DMY BK-5 0.000 0.0 4/17/2008 Slurs, r""eeo.. 15,051 - 17,953 r ' 3 13,343.3 6,527.8 63.62 CAMCO KBMG 1 Gas Lift OV BK 0.250 0.0 6/28/2008 Sins, IN 18,078 - 18,672 TD (CD4 - 3018), 18,797 LINERS, 14,694- 18,799 s +~ ~~, ~~ Y P ` .~A` '4 %~ ~. W~ ds» `} ~Ar ~r ~ . ~ ~~ ~.~ 4 T ~ ,r ~yl'~~~ ..inr ~ ~f~,a; ~~ ~ s„ > ~. .~ ~.~~. a._ .._ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL .UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc STATE OF ALASKA ALASKE.L AND GAS CONSERVATION COMMIS~J REPORT OF SUNDRY WELL OPERATIONS MAY1~.2010 1. Operations Performed: Abandon ~` Repair w ell ~"` Plug Pbrforations r Stimulate ]ri Z ~' i ~~ ~ g Alter Casin Pull Tubin Pbrforate New Pool g Waiver r~ ~ Ti Extension "°~6 Change Approved Program Operat. Shutdow n Pe=rforate Re-enter Suspended Well ""` 2. Operator Name: 4. Current Well Status: Permit to Drill Number: Inc. ConocoPhillips Alaska Development Exploratory "" 207-180 , 3. Address: Stratigraphic ~' Service ~ ~. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20557-02 7. Propg`rty Desig`nation:\ ` 8. Well Name and N~nber: ADL 380077, 384211, 372097, 380082 CD4-301 B 9. Field/Pool(s): \ ~'~ _ Colville River Field / a ruk O~ 10. Present Well Condition Summary: Total Depth measured 18806 feet Plugs (measured) None true vertical 6919 feet Junk (measured) None Effective Depth measured 18799 feet Packer (measured) 13429 true vertical 6919 feet (true verucal) 6566 Casing Length Size MD ND Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 2999 9-5/8" 3035 2387 INTERMEDIATE 14821 7" 14855 6911 LINER B 4105 3.5" 18799 6919 Perforation depth: Measured depth: blank/slotted liner from 14769'-18672' w ~ Il ~" '~ ~~~ i~ ~ True Vertical Depth: 6910'-6915' v" ~'~`~' ` "~~ Tubing (size, grade, MD, and TVD) 3.5, L-80, 14715 MD, 6900 TVD Packers &SSSV (type, MD, and TVD) PACKER -PACKER -PREMIER @ 13429 MD and 6566 TVD SAFETY VLV - CAMCO TRMAXX-5E SSSV @ 2218 MD and 2003 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 14769'-18672 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 1655 4579 1521 -- 323 Subsequent to operation 1669 4819 1687 -- 329 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory '°` 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 ~ 265-6036 Printed Name Brian Barreda Title WNS Production Engineer Signature Phone: 265-6036 2iN't~- Date h~ 0. ~ j V'~ 2 ~,© /- l ` RBDMS .MAY 1120'~~~j Form 10-404 Revised 7/2009 ,S- /Z is l~Z~l~ Submit Original Only CD4-301 B Well Work Summary DATE SUMMARY 3/6/10 Pump an Aqueous Scale Inhibition'tFeatment. Startjob at 07:00, and finished a~:34. Maximum pumping pressure was 685 psig for sqz, 880 for freeze protect. Average pump rate 3.5 BPM Total of 1682 bbls PW, 33 gal WAW5206, 1375 gal 4004 and freeze protect volume of 45bbls pumped. ~Otlf)CO~"11{{t~5 WNS i CD4-301 B Well Attributes (Max Angle 8 MD TD '.Wellbore APl/UWI Field Name '.Well Status Inc! (°) MD (HKB( Act Btm (ftKB) ' 501032055102 NANUO KUPARUK (PROD 92.26 14,90223 Comment ~.H2S (ppm) End Date iiKB-Grd (ft) (Rig Release Data Annotation Date ( SSSV: TRDP ( ( Last WO: I 36.90 4/17/2008 Annotation Depth (ftKB) it End Date Annotation Last Mod By End Date Last Tag _ Rev Reason: GLV CIO Imoshor ~ 1/27/2009 Casin Strin s Casing Description String 0... String ID ... Top (ftKB) Set Depth (i... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 16 250 36.0 114.0 114.0 65.00 HAO Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String WI... String ... String Top Thrd SURFACE 95/8 5.835 35.7 3,035.1 2,380.7 40.00 L-80 ,Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wl... String ... String Top Thrd UNTERMEDIATE 7 6.276 34.0 14,8550 6,901.2 26.00 L-80 __ Casing Description String 0... ,String ID ... Top (HKB) Set Depth (f... Sel Depth (ND) _. String Wt... String ... String Top Thrd -LINER B 31/2 ; 2.992 14,694.4 18,799.0 9.30 L-80 SLHT Liner Details Top Depth '. (ND) Top Inc! Top (ftKB) (HKB) (°) Item Descriptio n Comm_e_n_t __ ID (in) 14,694.4'( 6,898.8 86.49 PACKOFF 'HR' Liner setting sleeve'RS' Packoff 4.400 14.711.1 ~~ 6,900.Oi 87.62 HANGER 'DG' Flex Lock Liner Hanger 4.400 14,721.1, 6.90341 93631X0 Bushing I XO Bushing '~ 4.400 . ,_ _ Tubing Strings _. Tubing Description String 0... String ID ... Top (ftKB) Set Dep[h (i... Set Depth (ND) ... String Wt... String ... String Top Thrd ',TUBING 31/2 2.992 31.3 14,716.2 6,900.2 9.30 L-80 EUE ;Com letion Details ~, Top Depth (ND) Top Inc! Top (HKB) (ftKB) (°) Item Description _ Comment __ ID (in) 31.3 31.3 0.04 HANGER TUBING HANGER 3.968 147.4 147.4 0.70 XO CROSSOVER 3.500 2.218.2 2,002.9 51.23 SSSV TRMAXX-6E SSSV 2.812 13.428) 6,5658, 6355 PACKER Packer-Premier 2.875 13.512.1 6,602.1 ~ 64)9 ', NIPPLE XN Nipple - --- - --- 2.750 '~ 14, /16.2~~. 6,900.21 87.89 1WLEG Wireline Guitle Muleshoe ~ 3.000 tions 8 Slots '~ i ~ snot ~. , TOP (TVD) Btm (TVD) Dens Top (ftKB) ~ Btrn (ftKB) (ftKB) (kKB) Zone Date (sh-. Type Comment 8 17 953 8,904.1 6,913.6 4/17/2008 32.0 Slots 18,6721 G.907.0 6,905.6 18.07 (4!1712008 32.0 Slots T Notes: General & Safety End Date ___ _ " _ Annotation 4/17/2008 iNOte: VIEW SCHEMATIC w/9.0 Mandrel Details ___ TOp Deplh Top Port (TVD) Intl OD Valve Latch Size TRO Run Top (HKB) (HKB) (°) Make Stn Model Ilnl Serv Type Type (1n1 (psi) Run Data Com..._ 1 5,863.8 3416.4 68.26~~CAMCO KB MG 1Gas Lift DMY BK-6 0.000 0.0 4/17/2008 2 11,350.7 5,615.4 59.12 CAMCO KBMG 1 Gas Lift 'DMY BK-6 0.000 0.0 4/17/2008 ; 1 3 73.343.3 6,527.8 G3.62CAMCO KBMG 1 Gas Lift _ _ OV iBK 10.250 0.0 6/28!2008 slors, 18,0]8-18,6]2 TD (CD6-3018). 18.791 LINER B, ___ 14,696-18,]99 -- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~IaS~a ~lil & Gas Cans. Commission REPORT OF SUNDRY WELL OPERATIONS Ancharag~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnoCOPhillips Alaska, InC. Development ~ Exploratory ^ 207-180 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20557-02 " 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' ` CD4-301 B 8. Property Designation: • 10. Field/Pool(s): ADL 380077, 384211, 372097, 380082 Colville River Field / Nanuq-Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 18806' ~ feet true vertical 6919' feet Plugs (measured) Effective Depth measured 18799' feet Junk (measured) true vertical 6919' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 3035' 9-5/8" 3035' 2387' INTERMEDIATE 14855' 7" 14855' 6911' PRODUCTION 4104' 3.5" 18799' 6919' Perforation depth: Measured depth: blank /slotted liner fro m 14769'-18672' true vertical depth: 6910'-6915' ~~{~ ~ ~~l~ ~ ~ ~~~~ Tubing (size, grade, and measured depth) 3.5", L-80, 14716' MD. Packers &SSSV (type & measured depth) Premier pkr @ ~ 3a2s' SSSV @ 2218' 12. Stimulation or cement squeeze summary: Intervals treated (measured) pumped 626 bbls SW+WAW5206, 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 3076 3194 659 -- 323 Subsequent to operation 2837 2840 850 -- 331 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: 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: none contact Tim Schneider @ 265-6859 Printed Name Tim S/~~/n der Title Alpine Staff Engineer ~ 2~ ~~, D t Signature ~~ { h~~ Phone: 265-6859 a e ~ )) !~ ~n Pr ared b Sharon All u Drake 263-4612 5 ~~~'. Form 10-404 Revised 04/2006 ~' ' ` ~ - - ~ MuY ~ ~. ti~Q~ ~ ~~ Submit O i i al Only ~~ CD4-301 B Well Work Summary DATE SUMMARY 4/12/09 Pump an Aqueous Scale INhibition treatment usin LRS pumpin services. tart job at 11:55am, and finished at 13:42. Maximum pumping pressure was 625psig. Total of 394bb1s SW, 34 gal WAW5206, 340 gal 4004 and freeze protect volume of 33bbls pumped. 4/12/09..Pstmp second lob on well. First squeeze program was not ~Lct. Pumped a total of 626bb1s at and average rate of 5.Obpm and 500 psi into the well. 256 bbls of this was SW+4004 chemical. The well started out at 600psi tbg and ended with well on vac. Pumped 33 bbls of freeze protect. ..- Cc~nocaPh~ilips weu can ~I±oal cl,,, A,LTgp4 ~oJ. _.srn tnapc, ncm HANGER, 31 ~~. xo. 1a] Cross Over Thread, 2,206 sssv,z.zls Cross Over Threatl, 2,225 SURFACE, 36-3,035 GAS LIFT. s.esa GAS LIFT, 11,351 GAS LIFT. 13,343 PACKER, 13,429 NIPPLE, 13,512 NO GO SUB, __._.. 14.690 WLEG, 14.]15 slots. _ _. - 15,OS1-1]953 -! i--- 18,0]8-18 6]2 ](CD4-3018), 18.]9] LINER B, 14,694-18.]99 WNS Vell Attributes ellbore APl(UWI Fieltl Name Well: 501032055702 NANUO KUPARUK PRO ant !Date ) RDP ~ en S ~ ( ) nnotatio~ De h HKB End oa as TaD R ev Reason: CD4-301 B 8MD iTD KB) AR Btm (HKB) ,909 23 d (Tt) Rig Release Date 36 90 ~_ 4/17/2008 End Date 1!27/2009 CONDUCTOR 16 15.250 360 114.0 114.0 65.00 H-40 _ Casing Description String 0... String ID ... Top (ftKB) Set Depth (i... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 9 S/8 i 8.835 35.7 3,035.1 2,380.7 40.00 L-80 _ Casing Description String 0... String ID ... Top (HKB( Set Depth (f... Set Depth (ND) .. String Wt... Str ng String Top Thrd INTERMEDIATE 7 6.276 34.0 14,855.0 6,9012 26.00 L 80 _ _ Casing Description String 0... String ID ... Top (HKB( Sel Depth (f... Set Depth (ND) ... String Wt... String ._ String Top Thrd LINER B 3 112 2.992 14 694.4 18,799.0 9.30 I L-80 SLHT Liner Details Top Dep[h (ND) ~'. ToP Inc! ' 14,694.4 6,898.8 86.49 PACKOFF 'HR' Liner setting sleeve'RS' Packoff 4 auu 14,711.1 6,900.0 87.62 HANGER 'DG' Flex Lock Liner Hanger 4.400 14,721.1 6,903.4 93.63 XO Bushing XO Bushing 4.400 Tubing Strings T bing Des ption String 0... String ID ... Top (HKB( Set Depth (f... Set Depth (ND) .. String Wt... String ... String T p Thrd TUBING 312 2992 31.3 14,716.2 6,900.2 9.30 L-80 EUE Coin le tion Det ails '. Top Depth' ' i1 (ND) Top Inc! 13,51211 6,602.1 I, 64.791 NIPPLE XN Nipple z7su 14.715.2. 6,900.2 ~~ 87.89 _ WLEG _- _. Wireline Guide Muleshoe 3.000 P f tions ora er '. - Shot Top (TVD) Bim (TVD) Dens Top (ftKB) I gtrn (HKB) (ftKB) (HKB) Zone Date (sh,,. Type Commerd ' 15.051.0 17,953.0, 6,904.1 6,913.6 4/17/2008 32.0 Slots ' 18,078.0 18,672.0 6,907.0 6905.6 4!172008 32.0 Slots Nntnc- lLanaral R Rafa} v - ~- - _- _ -_ landrel Details 'Top Depth Top (TVD) Inc! OD n Top (ftKB) (HKB) (°I Make Model Gn) Serv 1 5,863.8 3 416.4 68.25 CAMCO KBMY 1 Gas Lift 2 11,350.7 5,615.4 59.12~~CAMCO KBMG 1 Gas Lift 3 13.343.3 6,527.8 63.62CAMCO KBMG 1Gas Lift Pod Valve Latch Siae CD4-301 Details c ~`-~ - 3D ~ ~, 'r JAS! ~ ~ 20~~ I Cement Detail Report CD4-301 .. String: Surface Casing Cement Job: DRILLING ORIGINAL, 12/812007 14:00 Cement Details Description Surface Casing Cement Cementing Start Date 12/11/2007 23:06 Cementing End Date 12/12/2007 00:45 Wellbore Name CD4-301 Comment Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug for marker wl rig pump -Pumped 3 bbls water w/ Dowell -Pressure test lines to 4000 psi -Dropped btm plug -Mixed & pumped 50 bbls - 10.5 ppg MudPush @ 5.6 BPM @ 445 psi -Mixed ii pump Lead slurry (ArcticSet Lite 3) 10.7 ppg @ 7.5 BPM @ 700 psi Pumped 165 bbls -Continue pumping lead slurry (ASL) 139 bbls @ 10.7 ppg 7.3 bbls/min @ 680 psi (304 bbls total pumped) observed nut plug marker @ shakers -pumped down surge can Pumped 321 bbls total bbls of lead slurry -Switched over to tail slurry Pumped 54 bbls tail slurry (Class G w/ .2% D046 + 1 % S2 + .2% D46 = .35 D65) @ 15.8 ppg @ 4.5 BPM @ 577 psi -Dropped top plug w/ 20 bbls water -Switched to rig pump & displaced w/ 204 bbls 9.8 ppg mud @ 7 BPM @ 438 to 620 psi -Slowed pump to 3.5 BPM for last 24 bbls @ 450 psi to 610 psi Bumped plug t/ 1000 psi - Checked floats OK - CIP @ 0045 hrs. - Recipocated pipe during job -full returns throughout - 125 bbls 10.7 ppg cmt returns to surface Cement Sta es Sta e # <Sta a Number?> Description Objective Surface Casing Cement Primary Top (ftKB) 36.0 Bottom (ftKB) 3,035.0 Full Return? Yes Cmnt Rtrn (... 125.0 Top Plug? Yes Btm Plug? Yes Q (start) (bbl/min) 8 Q (end) (bbl/min) 4 Q (avg) (bbl/min) 6 P (final) (psi) 617.0 P (bump) (psi) 551.0 Recip? Yes Stroke (ft) 25.00 Rotated? No Pipe RPM (rpm) Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Lead Cement fluid Description Estimated Top (ftKB) 36.0 Est Btm (ftKB) 2,535.0 Amount (sacks) 389 Class G Volume Pumped (bbl) 322.0 Yield (ft /sack) 4.45 Mix H2O Ratio (gal/sa... 20.15 Free Water (%) Density (Ib/gal) 10.70 Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 2,535.0 Est Btm (ftKB) 3,035.0 Amount (sacks) 259 Class G Volume Pumped (bbl) 54.0 Yield (fP/sack) 1.17 Mix H2O Ratio (gal/sa... 5.10 Free Water (%) Density (Ib/gal) 15.80 Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Sta e # <Sta a Number?> Description Objective Top (ftKB) Bottom (ftKB) Full Return? No Cmnt Rtrn (... Top Plug? No Btm Plug? No 0 (start) (bbllmin) 0 (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 5/5/2009 Security Level: Development Daily Drilling Report CD4-301 Report Number: 4 ... Rig: DOYON 19 Report Date: 12/11/2007 AFE Type Network/ID # 7ota1 AFE+Sup Drilling 10200417 11,750,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftK8) Depth End (ftK8) CD4-301 Development NANUO KUPARUK 2.55 4.0 86.00 2,960.0 3,046.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 7,047.62 48,193.32 325,333.62 846,542.32 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 12/8/2007 12/9/2007 32.61 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK8) SURFACE, 3,035.1ftKB Ops and Depth @ Morning Report 24hr Forecast Prep to PU 5" DP PU & std back 5" DP -Test BOPE Last 24hr Summary Drill 12 1/4" to 3046' TD -Circ hol e clean -Wiper trip to 895' (Top of HWDP) -Flow ck OK -RIH - circ hole clean -POOH on TT - f/ 3046' to 895' -Flow ck OK - Std back HWDP - LD BHA - RU & run 9 5/8" csg to 3035' (78 jts) RD csg tools - RU cmt head & lines -Circ & cond. mud & hole for cmtjob - Begin 9 5/8" cmt job -Pump water spacer w/ Nut pl ug for marker -Test lines to 4000 psi OK -Pumped 50 bbls MudPush @ 10.5 ppg -Mixed 8~ pumped 165 bbls of lead slurry(ASL-3) @ 10.7 ppg General Remarks Weather Head Count 1/-13 we / SW @ 8 mph / Vis 10 miles 46.0 Supervisor Title Dave Burley, Rig Supervisor Rig Supervisor Don Mickey, Rig Supervisor Rig Supervisor Randy Dexter, Rig Supervisor Rig Supervisor Time Lo Start Time End Time Dur (hrs) Phase Op Code Activity Code Time P-T-x Trbl Code Trbl Class. Depth Start (ftK8) Depth End (ftFC6) Operation 00:00 01:00 1.00 SURFAC DRILL DDRL P 2,960.0 3,046.0 Drill 12 1/4" hole w/ motor f/ 2960' to 3046' MD 2391 TVD ADT - 0.87 hrs =ART- 0.72 hrs AST - 0.15 hrs. WOB 25/35K RPM 60, GPM 625 @2120 psi String wt PU 130, SO 123, Rot 130 Totque on/off btm 9500/6500 ft/Ibs 01:00 01:45 0.75 SURFAC DRILL CIRC P 3,046.0 3,046.0 Circulate hole clean - 625 gpm / 1835 psi / 60 rpm 01:45 05:30 3.75 SURFAC DRILL TRIP P 3,046.0 890.0 Perform wiper trip from 3,046' to 890' - 550 gpm / 1500 psi / 60 rpm -reduced rate to 450 gpm from 1,557' - no problems -flow check well, static 05:30 06:30 1.00 SURFAC DRILL TRIP P 890.0 2,989.0 RIH from 890' to 2,989' 06:30 07:30 1.00 SURFAC DRILL CIRC P 2,989.0 3,046.0 Precautionary wash and ream from 2,989' to 3,046' -Circulate hole clean - 600 gpm / 1760 psi / 60 rpm -mud wt. in & out @ 10.0 ppg -flow check well, static 07:30 09:45 2.25 SURFAC DRILL TRIP P 3,046.0 890.0 POOH on tt from 3,046' to 890' -hole appears in good condition -flow check well, static 09:45 12:00 2.25 SURFAC DRILL TRIP P 890.0 68.0 POOH -stand back hwdp - LD jars and NMDC's& UBHO sub 12:00 13:15 1.25 SURFAC DRILL PULD P 68.0 0.0 LD BHA components -clear tools from floor -clean rig floor 13:15 14:45 1.50 SURFAC CASING RURD P 0.0 0.0 RU to run 9 5/8" casing 14:45 15:00 0.25 SURFAC CASING SFTY P 0.0 0.0 Held Pre-job Safety and Opts meeting with crew Latest BOP Test Data Date Comment Page 1/3 Report Printed: 5/5/2009 Security Level: Development Daily Drilling Report CD4-301 Report Number: 4 .- Rig: DOYON 19 Report Date: 12/11/2007 Time Lo Start Time End Time Dur (hrs) Phase Op Code Activity Code Time P-T-X Trbi Code Trbi Class. Depth Start (ftK8) Depth End (ftK6) Operation 15:00 18:30 3.50 SURFAC CASING RNCS P 0.0 1,726.0 Ran 9 5/8" 40# L-80 MBTC csg as follows: FS(Ray Oil Tool Ssilver bullet) 2 jts csg - FC( Halliburton Super seal) 2 jts csg - 4 jts total (made up w/ BakerLoc - fill pipe & check floats OK) Ran 41 jts 9 5/8" 40# L-80 MBTC csg (45 jts total) to 1726' 18:30 19:00 0.50 SURFAC CASING CIRC P 1,726.0 1,726.0 Break circ- Circ pipe volume -ICP 350 psi @ 3.5 bbls/min -FCP 200 psi @ 4.5 bbls/min 19:00 20:45 1.75 SURFAC CASING RNCS P 1,726.0 3,035.0 Continue running 9 5/8" 40# L-80 MBTC csg 33 jts f/ 1726' to 2996' (78 total jts ran) - PU hanger & landing jt. -Land csg w/ FMC fluted hanger on landing ring w/ FS @ 3035' - FC @ 2955' 20:45 21:00 0.25 SURFAC CASING OTHR P 3,035.0 3,035.0 RD csg equipment & fill-up tool - MU cmt head & lines 21:00 22:30 1.50 SURFAC CEMENT CIRC P 3,035.0 3,035.0 Break circ -Stage pump up to 6.5 bbls/min -ICP - 210 psi @ 1 bbl/min - FCP - 260 psi @ 6.5 bbls/min 22:30 22:45 0.25 SURFAC CEMENT SFTY P 3,035.0 3,035.0 PJSM w/ crew on cementing 22:45 00:00 1.25 SURFAC CEMENT DISP P 3,035.0 3,035.0 Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug for marker w/ rig pump -Pumped 3 bbls water w/ Dowell -Pressure test lines to 4000 psi -Dropped btm plug -Mixed & pumped 50 bbls - 10.5 ppg MudPush @ 5.6 BPM @ 445 psi -Mixed & pump Lead slurry (ArcticSet Lite 3) 10.7 ppg @ 7.5 BPM @ 700 psi Pumped 165 bbls Mud Check Data Type Depth (ftK6) Dens (Ib/gal) Vis (slgt) PV Calc (cp) YP Calc (tbf/100ft~) Gel (tOs) (Ibf/100ft') Gel (tOm) (Ibf/100ft') Gel (30m) (Ibf/100Ft~) MBT (Iblbbl) HTHP Fiii (mU30min) pH Density Temp (°F) Solids, Corr. (%) SPUD 3,046.0 65 25.0 19.0 5.0 7.0 8.000 32.5 9.0 5.2 In'ection Fluid Fluid Source From Lease (bbq Destination Vendor Manifest Number Note Diesel 53.0 CD4-322 Freeze protect Fresh Water 150.0 CD4-322 Annular flush Water Based Mud CD4-301 177.0 CD4-322 Drill Strin s: BHA No. 1 - 8" Mud Motor 415 5.3st /Bit Run No. 1 - 121/4in, Smith, TCT11 E PG4071 Depth In (ftKB) Depth Out (ftK6) TFA (incl Noz) (in') Nozzles (132") IADC Bit Dull String Wt (10001bf) 114.0 3,046.0 0.76 12/15/14/15/14 1-3-WT-G-4-1-NO-TD 44 Drill Strin Com onents Jts Item Description OD (in) ID (inJ Top Conn Sz (in) Top Thread Cum Len (ft) Mud Motor 8 5.000 6 5/8 H 90 31.77 Float Sub 8 2.750 6 5/8 H 90 34.17 Integral Blade Stabilizer 8.11 2.813 6 5/8 H 90 40.90 XO Sub 8.05 3.000 6 5/8 H 90 43.32 MWD (Directional) 8 1.920 6 5/8 Reg 52.52 MWD HCIM 7.98 1.920 6 5/8 Reg 61.11 MWD TM 8 1.920 6 5/8 H 90 70.86 Non Mag UBHO Sub 7.88 2.750 6 5/8 H 90 73.21 NMDC 7.67 2.813 6 5/8 H 90 104.19 NMDC 8.11 3.313 6 5/8 H 90 134.93 Drilling Jars -Mechanical 7 3/4 2.750 4 1/2 IF 170.25 Page 2/3 Report Printed: 5/5/2009 ~ ~• Rig: DOYON 19 Daily Drilling Report CD4-301 Security Level: Development eport Number: 4 Report Date: 12/11/2007 Drill Strin Com onents Jts Item Description OD (in) ID (in) Top Conn Sz (in) Top Thread Cum Len (ft) 24 HWDP 5 3.000 4 1/2 IF 895.75 Drilln Parameters Start (ffK6) End (ffKB) Cum Depth (fl) Cum Drill Time (hrs) Sliding Time (hrs) Flow Rate {9Pm) (9Pm) WOB (Ibfl RPM lrPrn) SPP (psi) PU Str Wt (10001bf) Dnll Str Wt (t0001bt7 SO Str Wt (t0001bt) Off Btm Tq Drill Tq 2,960.0 3,046.0 2,932.00 27.35 625 35.0 60 2,120.0 130 130 123 6,500.0 .9,500.0 Wellbores Wellbore Name CD4-301 Wellbore API/UWI 501032055700 Section Size (in) Act Top {ftK8) Act Btm (ftK8) Start Date End Date PROD1 COND1 SU RFAC INTRMI 6 1/8 36 12 1 /4 8 3/4 36.0 114.0 3,046.0 114.0 3, 046.0 15,883.0 12!3/2007 12/9/2007 12/13/2007 12/4/2007 12/11 /2007 12/18/2007 Surve Data. MD (ftK8) Inc! (°) Azm (°) TVD (ftK8) VS (ft) NS (ft} EW (fl) DLS (°/100ft) 2,997.08 68.00 107.88 2,372.67 1,035.83 -464.74 1,340.77 2.15 Cement Surface Casin Cement -Started 12/11/2007 Type casing Wellbore CD4-301 Cemented String SURFACE, 3,035.1ftKB Cement Evaluation Results Stg No. Description Surface Casing Cement Top (ftK8) 36.0 Bottom (ftK6) 3,035.0 Q (end) (bbl/... 4 P (final) (psi) 617.0 Fluid Class Amount (sacks) V (bbl) Density (Ib/gal) Yield (ft%sack) Est Top (flKB) Est Btm (ffKB) Lead Cement Tail Cement G G 389 259 322.0 54.0 10.70 15.80 4.45 1.17 36.0 2,535.0 2,535.0 3,035.0 Stg No. Description Top (ftK8) Bottom (ftK6) Q (end) (bbl/... P (final) (psi) Page 3/3 Report Printed: 5/5/2009 Security Level: Development Daily Drilling Report CD4-301 Report Number: 5 . .. , Rig: DOYON 19 Report Date: 12/12/2007 AFE Type NeiworWlD # Total AFE+Sup Drilling 10200417 11,750,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD4-301 Development NANUQ KUPARUK 3.55 5.0 0.00 3,046.0 3,046.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,000.00 50,193.32 215, 086.00 1, 061,628.32 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 12/8/2007 12/9/2007 32.61 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 3,035.1ftKB Ops and Depth @ Morning Report 24hr Forecast Making up BHA clean out shoe trk, perform FIT & Drill 8 3/4 hole Last 24hr Summary Continued pumping lead slurry (ASL) 139 bbls @ 10.7 ppg. Pumped 321 total bbls total of lead slurry -Switched over to tail slurry, pumped 54 bbls tail slurry @ 15.8 ppg @ 4.5 BPM @ 577 psi -Dropped top plug w/ 20 bbls water -Switched to rig pump & displaced w/ 204 bbls 9.8 ppg mud -Bumped plug t/ 1000 psi - Checked floats OK -Full returns t hroughout - 125 bbls 10.7 ppg cmt returns to surface. Rigged up and attempted to test 9 5/8" surface casing -test failed. Install well head -tested good to 1000 psi/10 min. N/U BOPE, riser, flowline and wear bushing. RIH picking up and standing back 180 Jts of 5" DP, RIH with 5" DP to 2850', rigged up to test 9 5/8" casing -tested good @ 3500 psi for 30 min. continued standing back 5" DP . RU to test BOPE: Annulus tested good 250/2500 psi for 5 min. General Remarks Weather Head Count 6/-12 WC / W@16 mph/ vis 10 miles 46.0 OC@8000' Supervisor Title Dave Burley, Rig Supervisor Rig Supervisor Don Mickey, Rig Supervisor Rig Supervisor Randy Dexter, Rig Supervisor Rig Supervisor Time Lo Start Time End Time Dur (hrs) Phase Op Code Activity Code Time P-T-x Trbl Code 7rbl Class Depth Start {flfCB) Depth End (ftKB) Operation 00:00 00:45 0.75 SURFAC CEMENT DISP P 3,035.0 3,035.0 Continue pumping lead slurry (ASL) 139 bbls @ 10.7 ppg 7.3 bbls/min @ 680 psi (304 bbls total pumped) observed nut plug marker @ shakers -pumped down surge can Pumped 321 bbls total bbls of lead slurry -Switched over to tail slurry Pumped 54 bbls tail slurry (Class G w/ .2%D046+1%52+.2%D46=.35 D65) @ 15.8 ppg @ 4.5 BPM @ 577 psi - Dropped top plug w/ 20 bbls water - Switched to rig pump & displaced w/ 204 bbls 9.8 ppg mud @ 7 BPM @ 438 to 620 psi -Slowed pump to 3.5 BPM for last 24 bbls @ 450 psi to 610 psi Bumped plug t! 1000 psi -Checked floats OK - CIP @ 0045 hrs. - Recipocated pipe during job -full returns throughout - 125 bbls 10.7 ppg cmt returns to surface 00:45 01:30 0.75 SURFAC CASING DHEQ T Non-rig Well testing 3,035.0 3,035.0 RU and attempted to test casing - Surface Eqp equip change out sensor and attempt to test casing -pressure not building to schedule -total of two bbls pumped 01:30 03:00 1.50 SURFAC CASING RURD P 0.0 0.0 RD Cement head, elevators, long bails - LD Landing joint 03:00 04:00 1.00 SURFAC CASING RURD P 0.0 0.0 PJSM - RD flow line and Riser 04:00 04:45 0.75 SURFAC CASING NUND P 0.0 0.0 Remove speed head from Conductor - Install FMC Wellhead -test M/M seals to 1000 psi for 10 min. -Install short bails and 5" D.P. elevators Latest BOP Test Data Date Comment Page 1/2 Report Printed: 5/5/2009 Security Level: Development Daily Drilling Report CD4-301 Report Number: 5 Rig: DOYON 19 Report Date: 12/12/2007 Time Lo Start End Dur Time Depth Start Depth End Time Time (hrs) Phase ~p Code Activity Code P-T-X Trbl Code Trbl Class. (ftK6) (ftKB) Operation 04:45 07:00 2.25 SURFAC WELCTL NUND P 0.0 0.0 NU BOP stack, riser and flowline -install wear bushing 07:00 07:30 0.50 SURFAC DRILL OTHR P 0.0 0.0 PU and spot GeoSpan skid onto rig floor 07:30 11:30 4.00 SURFAC DRILL PULD P 0.0 0.0 RIH picking up 5" drill pipe (90 jts) - POOH, stand back drill pipe 11:30 15:00 3.50 SURFAC DRILL PULD P 0.0 0.0 RIH picking up 5" drill pipe (90 jts) - POOH, stand back drill pipe 15:00 17:00 2.00 SURFAC DRILL PULD P 0.0 0.0 RIH picking up 5" drill pipe to 2850' (90 jts) 17:00 18:00 1.00 SURFAC CASING DHEQ P 0.0 0.0 RU and test 9 5/8" casing to 3500 psi far 30 minutes - RD and blow down lines 18:00 21:45 3.75 SURFAC DRILL PULD P 0.0 0.0 Continue RIH picking up & standing back 5" DP - 339 total jnts 21:45 22:15 0.50 SURFAC DRILL PULD P 0.0 0.0 Pull wear bushing 22:15 00:00 1.75 SURFAC WELCTL BOPE P 0.0 0.0 PJSM, Rig up and test BOPE Annulus - 250 low/2500 high for 5 min -test good Mud Check Data Type Depth (ftKB) Dens (tblgal) Vis (s/qi) PV Calc (cp) YP Calc (Ibt/'IOOft') Gel (tOs) Qbf/100ft') Gel (10m) (Ibf/100ft') Gel (30m) (Ibf/100ft') MBT (Ib/btil) HTHP Fitt (mtl30min) pH Density Temp (°F) Solids, Corr. (°k) Spud Mud 3,046.0 9.70 52 18.0 19.0 6.0 9.0 11.00 0 1 0.5 9.0 8.5 In action Fluid Fluid Source From lease (bbp Destination Vendor Manifest Number Note Diesel 43.0 CD4-322 Freeze protect Fresh Water 190.0 CD4-322 Auunlar flush Water Based Mud CD4-301 1764.0 CD4-322 Drill Strin s: BHA No. 1 - 8" Mud Motor 4/5 5.3st !Bit Run No. 1 - 12 1/4in, Smith TCT11E PG4071 Depth In (ftK6) Depth Out (ftK6) TFA (incl Noz) (in') Nozzles (/32") IADC Bit Dull String Wt (10001bf) 114.0 3,046.0 0.76 12/15/14/15/14 1 -3-WT-G-4-1-NO-TD 44 Drill Strin Com onents Jts Item Description OD (in) ID {in) Top Conn Sz (in) Top Thread Cum Lert(ft) Mud Motor 8 5.000 6 5/8 H 90 31.77 Float Sub 8 2.750 6 5/8 H 90 34.17 Integral Blade Stabilizer 8.11 2.813 6 5/8 H 90 40.90 XO Sub 8.05 3.000 6 5/8 H 90 43.32 MWD (Directional) 8 1.920 6 5/8 Reg 52.52 MWD HCIM 7.98 1.920 6 5/8 Reg 61.11 MWD TM 8 1.920 6 5/8 H 90 70.86 Non Mag UBHO Sub 7.88 2.750 6 5/8 H 90 73.21 NMDC 7.67 2.813 6 5/8 H 90 104.19 NMDC 8.11 3.313 6 5/8 H 90 134.93 Drilling Jars -Mechanical 7 3/4 2.750 4 1/2 IF 170.25 24 HWDP 5 3.000 4 1/2 IF 895.75 Wellbores Wellbore Name Wellbore API/UWI CD4-301 501032055700 Section Size (in) Act Top (ftK6) Act Btm (ftK6) Start Date End Date PROD1 6 1/8 CON D 1 36 36.0 114.0 12/3!2007 12/4!2007 SURFAC 12 1 /4 114.0 3, 046.0 12/9/2007 12/11 /2007 INTRM1 8 3/4 3,046.0 15, 883.0 12/13/2007 12/18/2007 Page 2/2 Report Printed: 5/5/2009 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-301 Rig: Doyon 19 Date: 12113/2007 Volume In ut Volume/Stroke Pum Rate: Drilling Supervisor: D. Burley 1 D. Mickey Pump used: #2 Mud Pump ~ Strokes ~ 0.1000 gbls/Strk ~ 8.0 Strk/min ~ i Type of Test: Casing Shoe Test LOT/FIT ~ Pumping down annulus and DP. ~ Casin Test Pressure In te ri Test Hole Size: 8-3/4" • Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 36.0 Ft 3,035 Ft-MD 2,387 Ft-TVD 3,066 Ft-MD 2,398 Ft-TVD Strks si Min si Strks si Min si Casing Size and Description. s-s/s^ 4o#/Ft L-80 BTC • 0 0 0 3450 0 15 0 780 Casin Test Pressure Int e ri Tes t 2 110 1 .3450 1 40 0.25 `660 Mud Weight: 9 9 ppg Mud Weight: 9.6 ppg 4 270 2 3450 2 95' 0.5 640 Mud 10 min Gel: . 48.0 Lb/100 Ft2 Mud 10 min Gel: 14.0 Lb/100 Ft2 6 460 3 3450 3 180 1 625 Test Pressure: 3 500 psi Rotating Weight: Lbs 8 650 4 3450 4 280 1.5 62 Rotating Weight: , 125 000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 10 820 5 3450 5 390 2 61 Blocks/Top Drive Weight: , 000 75 Lbs Desired PIT EMW: 18A ppg 12 960 6 3440 6 ,_ 500 2.5 610 , Estimates for Test: 2.7 bbls Estimates for Test: 1043 si 1 bbls 14 1'100 7 3440 7 590 3 610 • • 16 ` 1240 8 3440 8 650 3.5 .605 EMW =Leak-off Pressure + Mud Weight = 650 PIT 15 Second 18 1420. 9 3440 9 690 4 600 + 9.6 0.052 x TVD 0.052 x 2387 Shut-in Pressure si 20 1590 10 3440 10 720. 4.5 =~ 600 EMW at 3035 Ft-MD (2387 Ft-ND) = 14.8 660 22 160 15 3440. 11 750 5 600. L t 20 i d i test held 24 1930 20 3430 12 :7770 5 5 "' ` 600 400o os ps ur n , g . 4 °~ f t t 0 3430 13 780 6 600 99. o es pre ssure . 26 ' 210 25 . 28 2300 30 3430 14 780 6.5 595 3500 ,. >~x.~.a.; , , , ; ,, ~ ,~ ~ ~ -- 30 2b20 15 780 7 ' 590 90 3000 32 2760 7.5 5 34 2990` 8 590 36 3210 8.5 590 w 2500 GC 38 3470 9 590 . 9 5 590 N . zooo w 10 59 a a 1500 1000 500 0 0 1 Barrel 2 s 3 4 0 5 S 1 hut- P 0 1 In tim IT P i 5 2 e, M t 0 2 inute 5 s 30 Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back ~~CASING T EST ~~LEAK-O FF TEST O o n 3.8 Bbls Bbls 1.5 Is bls Comments: Tested 9 518" csq while picking up 5°' DP r ... Cement Detail Report CD4-301 String: Production Casing Cement Job: DRILLING ORIGINAL, 12/8/200714:00 Cement Details Description Production Casing Cement Cementing Start Date 1/8/2008 15:30 Cementing End Date 1/8/2008 18:15 Welibore Name CD4-3018 Comment Perform 1st stage cement job as follows: Pump 5 bbls CW-100 -Test lines to 4400 psi - Drop bottom plug -Pump 35 bbls CW-100 @ 4 bbls/min @ 800 psi - Pump 40 bbls MudPush @ 10.5 ppg @ 4 bbls/min @ 800 psi -Mix & pump 88 bbls (148 sks) 11.0 ppg Lead slurry (LiteCrete w/ .4% D046, 1 % D065, .01 8155, .25%D167) @ 5 bbls/min @ 900 psi -Mix & pump 22 bbls (107 sks) 15.8 ppg tail slurry (Class G w/ .2% D046, .25% D065, .25% D800,.18% D167) @ 3 bbls/min @ 600 psi -Drop top plug w/ 10 bbls water f/ Dowell -Switched over to rig pumps & displaced w/ 238 bbls 10.7 ppg inhibited CaCl2 @ 5 bbls/min @ 570 psi & 315.4 bbls 10.7 ppg CaCl2 @ 6 bbls/min @ 760 psi -slowed pumps to 4 bbls/min for last last 13 bbls -Bumped plug w/ 1500 psi - CIP @ 1815 hrs. -Checked floats OK -Full returns through job -Unable to move pipe during job. Cement Sta es Sta e # 1 Description Production Casing Cement Objective Top (ftKB) 12,084.0 Bottom (ftKB) 14,855.0 Full Return? Yes Cmnt Rtrn (... Top PIug1 Yes Btm Plug? Yes O (start) (bbl/min) 5 Q (end) (bbl/min) 4 Q (avg) (bbl/min) 5 P (final) (psi) 560.0 P (bump) (psi) 1,500.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 12,084.0 Est Btm (ftKB) 14,355.0 Amount (sacks) 148 Class LiteCrete Volume Pumped (bbl) 85.0 Yield (ft /sack) 3.35 Mix H2O Ratio (gal/sa... 11.22 Free Water (%) Density (Ib/gal) 11.00 Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 14,355.0 Est Btm (ftKB) 14,855.0 Amount (sacks) 105 Class G Volume Pumped (bbl) 22.0 Yield (ft /sack) 1.16 Mix H2O Ratio (gal/sa... 15.80 Free Water (%) Density (Ib/gal) 15.80 Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Sta a#2 Description Production Casing Cement Objective Top (ftKB) 7,160.0 Bottom (ftKB) 8,292.0 Full Return? Yes Cmnt Rtrn (... Top Plug? Yes Btm Plug? No O (start) (bbl/min) 4 Q (end) (bbl/min) 1 Q (avg) (bbl/min) 4 P (final) (psi) 760.0 P (bump) (psi) 1,500.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids 8 Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 7,160.0 Est Btm (ftKB) 8,289.0 Amount (sacks) 204 Class G Volume Pumped (bbl) 42.0 Yield (ft /sack) 1.16 Mix H2O Ratio (gal/sa... 5.10 Free Water (%) Density (Ib/gal) 15.80 Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 5/5/2009 i~ ..... Cement Detail Report CD4-301 String: Production Casing Cement Job: Cement Details Description Production Casing Cement Cementing Start Date 1!9/2008 21:30 Cementing End Date 1/9/2008 22:30 Wellbore Name CD4-301 B Comment Tail slurry (Class G w/ .2% D046, .3% D065, 1 % S002)) @ 4 bbls/min @ 400 psi - Drop Dart w/ 10 bbls water f/ Dowell -Switched over to rig pumps & displaced w/ 67 bbls 10.7 ppg un-inhibited brine @ 210 gpm @ 570 psi -Bumped Dart w/ 1800 psi - CIP @ 2230 hrs. Gement Sta es Sta e # <Sta a Number?> Description Objective Top (ftKB) Bottom (ftKB) Full Return? No Cmnt Rtrn (... Top Plug? No Btm Plug? No O (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Cement Fluids 8 Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 5/5/2009 Security Level: Development Daily Drilling Report CD4-301 Report Number: 31 . ,. Rig: DOYON 19 Report Date: 1/7/2008 AFE Type Network/ID # Total AFE+Sup Drilling 10200417 11,750,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) - Depth Start (ftKB) Depth End (ftKB) CD4-3018 Development NANUO KUPARUK 29.55 31.0 0.00 14,860.0 14,860.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 7,795.13 1,002,900.86 158,176.13 10,229, 359.86 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 12/8/2007 12/9/2007 32.61 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 3,035.1ftKB Ops and Depth ~ Morning Report 24hr Forecast Circ & condition mud @ 13,202' Finish running 7" csg & cement Last 24hr Summary Finish Down load MWD - LD MWD & GP -Change top pipe rams to 7" & test - RU to run7" csg -PJSM -Run 7" csg to 9799' (230 jts of 348 to run) General Remarks Weather Head Count -42 / -65 we / S@ 8 mph / Vis. 5 miles 48.0 Supervisor Title Donnie Lutrick, Rig Supervisor Rig Supervisor Don Mickey, Rig Supervisor Rig Supervisor Randy Dexter, Rig Supervisor Rig Supervisor Time Lo Start Time End Time Dur (hrs) .Phase Op Code Activity Code Time P-T-X Trbl Code Trbl Ctass. Depth Start (ftKB) Depth End (ftKB) Operation 00:00 01:00 1.00 INTRM2 DRILL PULD P 83.0 0.0 UD MWD, NIMPC, GP, subs & GS Clear floor and LD elevators & bales 01:00 02:15 1.25 INTRM2 DRILL RURD P 0.0 0.0 PJSM, change to 7" RAMS & 4" saver sub. 02:15 03:15 1.00 INTRM2 WELCTL BOPE P 0.0 0.0 Pull wear ring and set test plug, R/U test equipment, test 7" RAMS - 250/low 3500 psi high, test good RID test equipment. 03:15 04:00 0.75 INTRM2 CASING RURD P 0.0 0.0 Pull test plug & set thin wall wear ring. 04:00 05:30 1.50 INTRM2 CASING RURD P 0.0 0.0 RU csg equipment 05:30 06:00 0.50 INTRM2 CASING SFTY P 0.0 0.0 PJSM on running 7" casing 06:00 09:30 3.50 INTRM2 CASING RNCS P 0.0 2,983.0 Run 7" 26# L-80 BTCM as follows: FS( Ray Oil Tools Silver Bullet) 2 jts. csg - FC (Halliburton Super Seal) 2 jts, csg First four jts. made up w/ BakerLoc -fill pipe & check floats) 66 jts csg (70 jts total) to 2983' 09:30 10:00 0.50 INTRM2 CASING CIRC P 2,983.0 2,983.0 Circulate one csg volume at 9 bpm - 750 psi. 10:00 14:30 4.50 INTRM2 CASING RNCS P 2,983.0 6,395.0 Continue running 7" 26# L-80 BTCM csg f/ 2983 to 6395' (150 jts total) 14:30 15:45 1.25 INTRM2 CASING CIRC P 6,395.0 6,395.0 Break circ & stage pumps up to 4.5 bbls/min -Circ btms up + & condition mud @ 370 psi - PU wt. 170 SO wt 130 15:45 21:00 5.25 INTRM2 CASING RNCS P 6,395.0 9,799.0 Continue running 7" 26# L-80 BTCM csg f/ 6395' to 9799' (230 jts. total) 21:00 00:00 3.00 INTRM2 CASING CIRC P 9,799.0 9,799.0 Break circ & stage pumps up to 4.3 bbls/min -Circ btms up + to condition mud - FCP 500 psi PU wt. 220 SO wt. 125 Mud Check Data Type Depth (ftKB) Dens (Ib/gal) Vis{s/qq PV Calc (cp) YP Calc (Ibf1100ft') Gel (10s) {IbN100ft') Gel (tOm) Qbf/100ftT) Gel (30m) (Ibf/100rN) MBT (Ib/bbp HTHP Flt (mLJ30min) pH Density Temp (°F1 Solids, Corr. (°A) LSND / 14,860.0 10.80 42 12.0 20.0 8.0 9.0 10.000 9.6 6.2 9.5 14.0 Inhibycol Latest BOP Test Data Date Comment 12/29/2007 Tested Annular to 250 & 2500 is / VBR Blinds all vavles to 250 & 3500 si witnessin of test waived b AOGCC Page 1/2 Report Printed: 5/5/2009 Security Level: Development Daily Drilling Report CD4-301 .,, Report Number: 31 Rig: DOYON 19 Report Date: 1/7/2008 In'ection Ftuid Fluid Source From Lease (bbl) Destination Vendor Manifes# Number Note Diesel 15.0 CD4-322 Freeze protect Wellbores Wellbore Name Wellbore API/UWI CD4-301 B 501032055702 Section Size {in) Act Top (ftK6) Act Btm (ftK8) Start Date End Date PROD1 6 1/8 COND1 18 36.0 114.0 12/3/2007 12/4/2007 SURFAC 12 1 /4 114.0 3,046.0 12/9/2007 12/11 /2007 INTRM1 8 3/4 3,046.0 15,883.0 12/13/2007 12/18/2007 INTRMI 8 3/4 9,595.0 14,860.0 1/1/2008 1/5/2008 LINER B 6 1/8 14,846.0 18,797.0 4/7/2008 4/13/2008 Page 2/2 Report Printed: 5/5/2009 Security Level: Development Daily Drilling Report CD4-301 ~ • a' e Report Number: 32 Rig: DOYON 19 Report Date: 1/8/2008 AFE Type Nelwork/ID # Total AFE+Sup Drilling 10200417 11,750,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD4-301B Development NANUO KUPARUK 30.55 32.0 0.00 14,860.0 14,860.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 72,501.68 1, 075,402.54 747,142.68 10,976, 502.54 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 12/8/2007 12/9/2007 32.61 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) INTERMEDIATE, 14,855.OftKB Ops and Depth @ Morning Report 24hr Forecast RIH w/ TAM combo tool on 4" DP RIH w/ Combo tool -perform 2nd stage cmt job -POOH -Run kill string Last 24hr Summary Continue running 7" csg to 13,202' Circ & condition mud -Finish running 7" csg fo 14,821' -PU hanger & land csg w/ shoe @ 14,855' - RD csg equipment - RU cmt equipment -Circ for cmt job - Cmt 7" w/ 85 bbls Litecrete & 22 bbls Class G -Displace w/ 238 bbls inhibited 10.7 ppg CaCl2 & 315.4 bbls uninhibited 10.7 ppg CaCl2 -Bumped plug w/ 1500 psi - CIP @ 1615 hrs. - RD f/cmt job - LD landing jt. Set & test pack-off -Change top pipe rams f/7" to 3 1/2' x 6" VBR 8~ test - Begin LD 5' DP General Remarks Weather Head Count -41/-61 we / SW@ 5 mph / Vis. 2 miles 47.0 Supervisor Title Dave Burley, Rig Supervisor Rig Supervisor Don Mickey, Rig Supervisor Rig Supervisor Randy Dexter, Rig Supervisor Rig Supervisor Time Lo Start Time End Time Dur (hrs) Phase Op Code Activity Code Time P-T-x Trbl Code Trbl Class. Depth Start (ftKB) Depth End (ftKB) Operation 00:00 05:15 5.25 INTRM2 CASING RNCS P 9,799.0 13,202.0 Continue running 7" 26# L-80 BTCM Casing F/9,789' T/13,202' (310 jts total) 05:15 08:00 2.75 INTRM2 CASING CIRC P 13,202.0 13,202.0 Establish circ -Stage pump up f/ 3 bbls/min to 4.2 bbls/min -circ & condition mud - ICR 650 psi FCP 650 psi - PU wt. 290 SO wt. 155 08:00 11:15 3.25 INTRM2 CASING RNCS P 13,202.0 14,855.0 Continue running 7" 26# L-80 BTCM casing f/13,202' to 14,818' (348 jts total) PU FMC fluted csg hanger & landing jt. - Land csg w/ fluted hanger in wellhead w/ FS @ 14,855' - FC @ 14,766' -TAM PC @ 8289' 11:15 12:00 0.75 INTRM2 CASING RURD P 14,855.0 14,855.0 R/D tongs, slips, and Franks. R/U CMT head 12:00 15:00 3.00 INTRM2 CEMENT CIRC P 14,855.0 14,855.0 Establish circulation @ 1.5 bpm / 480 psi -Attempted to reciprocate pipe w/ 425k, unable -stage pumps up to 5.0 bpm - circulate and condition mud until mud wt. in & out @ 10.8 ppg -FCP=550 psi - Total of 984 bbls pumped -full returns throughout 15:00 15:15 0.25 INTRM2 CEMENT SFTY P 14,855.0 14,855.0 Held pre-job safety & ops meeting w/ crew on cementing 7" csg Latest BOP Test Data Date Comment 12/29/2007 Tested Annular to 250 & 2500 is /VBR Blinds all vavles to 250 & 3500 si witnessin of test waived b AOGCC Page 1/3 Report Printed: 5/5/2009 .. Security Level: Development Daily Drilling Report CD4-301 Report Number: 32 A M •," a Rig: DOYON 19 Report Date: 1/8/2008 Time Lo Start Time End Time Dur (hrs) phase Op Code Activity Code Time P-T-X Trbl Code Trbl Class. Depth Star) (ftK8) Depth End (ftK6) Operation 15:15 18:30 3.25 INTRM2 CEMENT DISP P 14,855.0 14,855.0 Perform 1st stage cement job as follows: Pump 5 bbls CW-100 -Test lines to 4400 psi - Drop bottom plug -Pump 35 bbls CW-100 @ 4 bbis/min @ 800 psi - Pump 40 bbis MudPush @ 10.5 ppg @ 4 bbls/min @ 800 psi -Mix & pump 88 bbls (148 sks) 11.0 ppg Lead slurry LiteCrete w/ .4% D046, 1 % D065, .01 8155, .25%D167) @ 5 bbis/min @ 900 psi -Mix & pump 22 bbls (107 sks) 15.8 ppg tail slurry (Class G w/ .2% D046, .25% D065, .25% D800,.18% D167) @ 3 bbis/min @ 600 psi -Drop top plug w/ 10 bbis water f/ Dowell -Switched over to rig pumps & displaced w/ 238 bbls 10.7 ppg inhibited CaCl2 @ 5 bbls/min @ 570 psi & 315.4 bbls 10.7 ppg CaCl2 @ 6 bbis/min @ 760 psi -slowed pumps to 4 bbls/min for last last 13 bbis - Bumped plug w/ 1500 psi - CIP @ 1815 hrs. -Checked floats OK -Full returns through job -Unable to move pipe during job. 18:30 19:00 0.50 INTRM2 CEMENT OTHR P 14,855.0 14,855.0 RD cement equipment 19:00 20:15 1.25 INTRM2 CASING RURD P 14,855.0 14,855.0 LD landing jt. -Pull thin wall wear bushing -Set 7" x 9 5/8" pack-off -Test to 5000 psi for 10 mins. 20:15 22:45 2.50 INTRM2 CASING OTHR P 0.0 0.0 PJSM on changing rams -Changed top pipe rams f/7" to 3 1/2' x 6" VBR -set test plug & test to 250 & 3500 psi w/ 4" test jt. -Pull test plug -set wear bushing 22:45 00:00 1.25 INTRM2 DRILL PULD P 0.0 0.0 RU & LD 5" DP f/ driller's side of derrick via mouse hole Mud Gheck Data YP Calc Gel (tOs) Gel (10m) Gel (30m) HTHP Filt Density Temp Solids, Gorr. Type Depth (ftK8) Dens (Ib/gal) Vis {s/qt) PV Caic (cp) (Ibf/100R') (Ibfl100ft=) (Ibf/t00ft') (ibf/100ft'} MBT (Ib/bbl) (mV30min) pH (°f} (%) CaCl2 10.70 In' ction Fluid fluid Source From Lease (bbl) Destination Vendor Manrfest Number Note Diesel 5.0 CD4-322 Freeze protect Drilling Mud WBM CD4-301 970.0 CD4-322 Wellbores . Wellbore Name Wellbore API/UWI CD4-301 B 501032055702 Section Size (in) Ad Top (ftK6) Act Btm(ftK8) Stan Date End Date PROD1 6 1/8 COND1 18 36.0 114.0 12/3/2007 12/4/2007 SURFAC 12 1 /4 114.0 3,046.0 12/9/2007 12/11 /2007 INTRMI 8 3/4 3,046.0 15,883.0 12/13/2007 12/18/2007 INTRM1 8 3/4 9,595.0 14,860.0 1/1/2008 1/5/2008 LINER B 6 1/8 14,846.0 18,797.0 4/7/2008 4/13/2008 Cement Production Casin Cement -Started 1/8/2008 Type Wellbore Cemented String Cement Evaluation Results casing CD4-3016 INTERMEDIATE, 14,855.OftK6 Page 2/3 Report Printed: 5/5/2009 ig: DOYON 19 Daily Drilling Report CD4-301 Security Level: Development Report Number: 32 Report Date: 1/8/2008 Stg No. 1 Description Production Casing Cement Top (ftKB) 12,084.0 Bottom (ftKB) 14,855.0 Q (end) (bbl/... 4 P (final) (psi) 560.0 Fluid Class Amounl (sacks) V (bbl) Density (IbJgal) Yield (ft'/sack) Est T op (ftKB) Est Btm (ftKB) Lead Cement Tail Cement LiteCrete G 148 105 85.0 22.0 11.00 15.80 3.35 1.16 12,084.0 14,355.0 14,355.0 14,855.0 Stg No. 2 Description Production Casing Cement Top (ftKB) 7,160.0 Bottom (ftKB) 8,292.0 Q (end) (bbll... 1 P (final) (psi) 760.0 Fluid Class Amount (sacks). V (bbl) Density Qblgaf) Yield (ft'/sack) Est T op (ftKB) Est Btm (ftKB) Tail Cement G 204 42.0 15.80 1.16 7,160.0 8,289.0 Page 3/3 Report Printed: 5/5/2009 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-301 Rig: Doyan 19 Date: 1110!2008 Volume In ut Pum Rate: Drilling Supervisor: Burley /Mickey Pump used: Cement unit ~ Barrels ~ 0.1000 Bbls/strk ~ Q•g Bbl/min ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casin Test Pressure Ira te r" Test Hole Size: 8-3/4" ~ Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 3433.0 Ft 3,036 Ft-MD 2,387 Ft-TVD 7,160 Ft-MD 3,902 Ft-TVD Bbls si Min si Bbls si Min si Casing Size and Descriation: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 ' 0 431 Chan es for Annula r Ade ua c Test Pressure Irat e ri Test 1 0.5 110 0.25 382 outer casing shoe test results in comments Mud Weight: 10.7 ppg 2 1 135 0.5 379 Description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 166 1 371 ize is that drilled below outer casing. 4 2 `189' 1.5 36 timated TOC for Hole Depth. 5 _2.5 219 2 3 Enter inner casing OD at right Desired PIT EMW: 16.0 ppg 6 3 232 2.5 362 Estimates for Test: 658 si 0.5 bbls 7 ' 3.5 249 3 359 ~ 8 4 268 3.5 355 EMW =Leak-off Pressure + Mud Weight = 349 PIT 15 Second 9 4.5 284 4 354 0.052 x TVD 0.052 x 2387 + 10.7 Shut-in Pressure si 10 5 309 4.5 355 EMW at 3036 Ft-MD (2387 Ft-TVD) = 13.5 382 15 5.5 320 5 351 20 6 333 5 5 ' 351 500 r . I 25 6.5 349 6 350 30 7 345 6.5 345 7.5 370 7 340 8 374 7.5 343 8.5 =-351 8 343 w 9 '370 8.5 340 j 9.5 368 9 337 y 10 375 9.5 337 N 10.5 388 10 3 ~ 11 ` 405 a 11.5 417 12 ... 411' 12.5 °417 13 .....:426 1.3.5 452 14 431: 0 1 0 1 5 2 0 2 5 30 0 ~ 2 4 6 Barrel 8 1 s 0 1 ` 2 1 F TEST 4 1 6 0 5 S hut- O P In tim IT P i e, M t inute s Vol Pum ume ed Volume Bled Back Volume Pum ed Volume Bled Back 1 CASING TEST LEAK- OF o n 0.0 Bbls Bbls 1 .0 Bbls B Is Comments: 9 5/8" Surface casing FIT = 14.8 ppg • • ConocoPhillips ~~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ,~c~~ - i go ~~~-3o~B Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped March 18~', 2009. 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. Sinc Perry ~c~~~ v ConocoPhillips Well Integrity Projects Supervisor C~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # .cement um ed cement date inhibitor sealant date ft bbls ft al CD4-301 B 207-180 SF NA 7" NA 2.55 3/18/2009 CD4-302 207-056 28" NA 28" NA 22.95 3/18/2009 CD4-304 207-132 8" NA 8" NA 1.70 3/18/2009 CD4-05 207-155 SF NA 7" NA 1.70 3/18/2009 CD4-306 207-094 SF NA 5" NA 1.70 3/18/2009 CD4-07 207-118 SF NA B" NA 0.42 3/18/2009 CD4-208 205-162 SF NA 7" NA 1.27 3/18/2009 CD4-209 206-065 SF NA 6" NA 0.85 3/18/2009 CD4-210 206-077 SF NA 7" NA 1.27 3/18/2009 ` CD4-211 ' 206-153 9" NA 9" NA 3.82 3/18/2009 CD4-214' 206-145 7" NA 7" NA 2.12 3/18/2009 CD4-215 • 206-157 5" NA 5" NA 2.55 3/18/2009 CD4-16 206-131 SF NA 5" NA 2.55 3/18/2009 C 4-17 206-118 SF NA 11" NA 1.27 3/18/2009 CD4-318A 206-113 7" NA 7" NA 1.70 3/18/2009 CD4-319 205-148 SF NA 7" NA 1.27 3/18/2009 CD4-320 206-055 6" NA 6" NA 0.85 3/18/2009 CD4-321• 206-142 SF NA 8" NA 1.70 3/18/2009 CD4-322 207-101 SF NA 5" NA 1.27 3/18/2009 DATA SUBMITTAL COMPLIANCE REPORT 1 /7/2009 Permit to Drill 2071800 Well Name/No. COLVILLE RIV MAN-K CD4-3018 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20557-02-00 MD 18806 TVD 6919 Completion Date 4/17/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFO RMATION Mud Log No Samples No Directional Survey Yes r DATA INFORMATION Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T pe Med/Frmt __ Number Name Scale Media No Start Stop CH Received Comments Rpt -_ LIS Verification 3009 14860 Open 3/24/2008 LIS Veri, NPHI, NCNT, ROP, PEF, RHOB, RPX, DRHO, RPS, FET, RPD, i~ RPM, FCNT, GR QED C Lis 16062~nduction/Resistivity 3009 14860 Open 3/24/2008 LIS Veri, NPHI, NCNT, III ROP, PEF, RHOB, RPX, DRHO, RPS, FET, RPD, RPM, FCNT, GR D Asc Directional Survey 36 14860 Open 3/7/2008 ~tpt Directional Survey 36 14860 Open 3/7/2008 ~og Induction/Resistivity 25 Col 114 6911 Open 4/10/2008 TVD, DGR, EWR, ALD, ~, ~ i / CTN t~D C 16099~nduction/Resistivity 0 0 Open 4/10/2008 TVD on EWR log in PDS, EMF and CGM graphics / r%ED C 16124~nduction/Resistivity 0 0 Open 4/21/2008 MD on EWR log in PDS, EMF and CGM graphics (flog Induction/Resistivity 25 Col 114 14860 Open 4/21/2008 MD ROP, DGR, EWR, ~ ~ // / ALD, CTN 5-Jan-2008 I +IED C Lis 16297 InductionlResistivity 14837 18796 Open 5/23/2008 LIS Veri, GR, ROP, FET, ' RPX, RPS, RPM, RPD ~g Induction/Resistivity 5 Blu 14818 18974 Open 5/23/2008 MD Vision Res 13-Apr- ~~ 2008 4~Log Induction/Resistivity 5 Blu 14818 18974 Open 5/23/2008 TVD Vision Res 13-Apr- 2008 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 9/7/2009 Permit to Drill 2071800 Well Name/No. COLVILLE RIV NAN-K CD4-3018 Operator CONOCOPHILLIPS ALASKA INC MD 18806 TVD 6919 Completion Date 4/17/2008 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y %(~ Chips Received? fi/-ht-- Analysis =r ;,~-= Received? Comments: Compliance Reviewed By: _ ___ __ Daily History Received? ~/ N Formation Tops ~ N API No. 50-103-20557-02-00 UIC N - - - -_ -- - -- Date _~ o,~_ ~.~~ q ConocoPhillips June 2, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD4-301 B Dear Commissioner: • G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 V' MAY 3 0 2008 Alaska (Jii & Gas Cons. Ccmr~issiarf Anc+~oraga ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD4-301 B. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~, G.~. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad ~~-rib NaY ~ (~ t.~+~8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION~laSka Oi(& Gas Cons. Commission WELL COMPLETION OR RECOMPLETION REPORT AN 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development Q ~ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., oraband.: April 17, 2008 12. Permit to Drill Number: 207-180 / 308-092 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~ ~ ~y>,-~,' Jan~u'aT'ry~1, 2008 J ~; 13. API Number: 50-103-20557-02 4a. Location of Well (Governmental Section): Surface: 2882' FNL, 70' FEL, Sec. 24, T11N, R4E, UM 7. Date TD Reached: April 13, 2008 - 14. Well Name and Number: CD4-301B - Top of Productive Horizon: 2442' FNL, 898' FEL, Sec. 20, T11 N, R5E, UM 8. KB (ft above MSL): RKB ssl~ Ground (ft MSL): /q MSL 15. Field/Pool(s): Colville River Field Total Depth: 3483' FNL, 2116' FEL, Sec. 17, T11 N, RSE, UM 9. Plug Back Depth (MD + ND): ~(. 18799' MD / 6919' TVD `, Nanuq-Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 378175 - y- 5957526 Zone- 4 10. Total Depth (MD + ND): 18806' MD / 6919' TVD - 16. Property Designation: , ADL 380077,384211, 372097, 380082 TPI: x- 387592 y- 5957820 Zone- 4 Total Depth: x- 386425 - 5962075 Zone- 4 11. SSSV Depth (MD + ND): 2218' MD / 2006' ND 17. Land Use Permit: ALK LAS2112 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND}: 1500' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~~ %`~~ y~, • dig/j,.J GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE O AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING REC RD PULLED 16" 62.5# H-40 36' 114' 36' 114' 24" pre-installed 9-5/8" 40# L-80 36' 3035' 36' 2387' 12.25" 389 sx AS Lite, 259 sx Class G 7" 26# L-80 36' 14855' 36' 6911' 8.75" 148 sx LiteCRETE, 107 sx Class G and 3.5" 9.3# L-80 14695' 18799' 6909' 6918.5' 6.125" 204 sx Class G 23. Open to production or injection? Yes / No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 14716' 13429' blank /slotted liner from 14769'-18672' MD 6910'-6915' ND 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 26. PRODUCTION TEST Date First Production May 2, 2008 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 5/6/2008 Hours Tested 10 hours Production for Test Period -> OIL-BBL 3557 GAS-MCF 1422 WATER-BBL 0 CHOKE SIZE 100% GASOIL RATIO 653 Flow Tubing press. 363 psi Casing Pressure 952 Calculated 24-Hour Rate -> OIL-BBL 7445 GAS-MCF 4862 WATER-BBL 0 OIL GRAVITY -API (corn) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No ^ Sidewall Cores Acquired? Yes No ~ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. _„ -, ~•~ NONE .4 IEO .. ~ ~~~~ Form 10-407 Revised 212007 ORIGINAL CONTINUED ON REVERSE SIDE _:.~ ~ ~~~: ,;u~. ~ ~ 2aoa ~.~/•oa .'~ ~ ,~ 28. GEOLOGIC MARKERS (List all formations and mar ers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1502' 1500' - needed, and submit detailed test information per 20 AAC 25.071. C-30 3090' 2407' C-20 4113' 2793' K-3 6881' 3801' K-2 7664' 4082' Nanuq 12587' 6195' K-1 14156' 6828' Kuparuk C 14367' 6872' N/A Formation at total depth: Kuparuk C 30. LIST OF ATTACHMENTS Summary of Daily Operations, directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim ru/mrine (~ 265-6402 / / C, U I/ Printed Name hi Alvord Title: Drilling Team Leader ~ ~ ~ ~ Signature ~ Phone Date "' °~~ ZCsS - Ce /'LO INSTRUCTIONS Sharon Allsup-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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 • ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD4 Nanuq Pad CD4-301 B 50-103-20557-02 f ~~ .s .- ~/ Definitive Survey Report 27 May, 2008 `.~ I"" _. ~a'.' ~~~„ Sperry '.Drilling Services ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-0rdlnate Reference; Project: Western North Slope TVD Reference: Slte: CD4 Nanuq Pad MD Reference: Well: CD4-301 North Reference: Wellbore: CD4-3018 Survey Calculation Method: Design: CD4-3016 Database: • Well CD4-301 CD4-301 (36.9+19) @ 55.908 (Doyon 19 (36.9+19)) , CD4-301 (36.9+19) @ 55.90ft (Doyon 19 (36.9+19)) true Minimum Curvature CPAI EDM Production Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well CD4-301 Well Position +NIS 0.00 ft Northing: 5,957,273.28 ft Latitude: 70° 17' 31.779 N +E/-W 0.00 ft Easting: 1,518,208.24 ft Longitude: 150° 59' 22.030 W Position Uncertainty 0.00 ft Wellhead Elevation: 0.00 ft Ground Level: 19.OOft Wellbore CD4 3015 Magnetics Model Name Sample Date Declination DIp Angle Field Strength BGGM200' 4!712008 22.14 80.66 57.576 Design CD4-3018 Audit Notes: Version: 1.0 Phase: ACTUAL lie On Depth: 9,575.95 Vertical Section: Depth From (TVD) +N!-S +El-W Direction (ft) (ft) Ift) (•) 36 90 0 00 0 00 744 00 Survey Program Date 4,15!2008 From To (ft) (tt) Survey (Wellbore) Tool Name Description Survey Date 81.00 444.00 CD4-301 Gyro (CD4-301) CB-GYRO-SS Camera based gyro single shot 12/9/2007 12: 480.19 9,575.95 CD4-301 IIFR+MS+Sag (CD4-301) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/9/2007 12: 9,595.00 14,823.06 CD4-3016 MWD+SAG+IIFR+MS Hallibu MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/1/2008 12:0 14,847.80 18,746.34 CD4-3016 Schlumberger (CD4-301 B) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/14/2008 12: Survey Map Map Vertical MD Inc Azl TVD TVDSS +N.r-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) ('1100') (ff) Survey Tool Name 36.90 0.00 0.00 36.90 -15.00 0.00 0.06 5,557,273.28 1,518,2Gd.24 0.00 0.00 UNDEFINED 81.00 0.45 77.00 81.00 25.10 0.04 0.17 5,957,273.31 1,518,208.41 1.02 -0.01 CB-GYRO-SS (1) 172.00 0.78 98.00 171.99 116.09 0.03 1.13 5,957,273.29 1,518,209.37 0.43 -0.28 CB-GYRO-SS (1) 262.00 1.25 111.00 261.98 206.08 -0.40 2.65 5,957,272.83 1,518,210.89 0.58 -1.12 CB-GYRO-SS (1) 353.00 2.75 122.00 352.92 297.02 -1.92 5.43 5,957,271.27 1,518,213.64 1.69 -3.34 CB-GYRO-SS (1) 444.00 5.40 128.00 443.68 387.78 -5.71 10.66 5,957,267.40 1,518,218.80 2.95 -8.43 CB-GYRO-SS (1) 480.19 5.87 133.01 479.70 423.80 -8.02 13.35 5,957,265.04 1,518,221.46 1.88 -11.39 MWD+IFR-AK-CAZ-SC (2) ~ 570.30 7.85 122.53 569.16 513.26 -74.47 21.91 5,957,258.45 1,518,229.91 2.59 -19.95 MWD+IFR-AK-CAZ-SC (2) 661.37 9.30 119.34 659.21 603.31 -21.42 33.57 5,957,251.31 1,518,241.46 1.68 -29.85 MWD+IFR-AK-CAZ-SC (2) 751.19 9.00 109.43 747.90 692.00 -27.32 46.52 5,957,245.21 1,518,254.31. 1.78 -39.08 MWD+IFR-AK-CAZ-SC (2) 843.01 9.66 110.13 838.50 782.60 -32.36 60.53 5,957,239.94 1,578,268.23 0.73 -47.79 MWD+IFR-AK-CAZ-SC (2) 5/272008 3:35:08PM Page 2 COMPASS 2003.18 Build 42F • ConocoPh illips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ord inate Reference : Well CD4-301 Project: Western North Sl ope ND Reference: CD4-301 (36.9+19) @ 55.90ft (Doyon 19 (36.9+19)) Site: CD4 Nanuq Pad MD Reference: CD4-301 (36.9+19) @ 55.90ft (Doyon 19 (36.9+19)) Well: CD4-301 North Refere nce: True Wellbora: CD4-3018 Survey Calcu lation Method: Minimum Curvature Design: CD4-301B Database: CPAI EDM Production Survey - _ - - - Map Map Vertical MD Inc Azl TVD T4DSS +N/-S +E/-W Northing Easting DLS Section (ft) (~) (~) (ft) (ft) (ft) (ft) (ftJ (tt) (°1100') (ft) Survey Tool Name 537.85 11.7a 1Q8.b'1 ff31.64 875.)4 x8.18 77.18 5,957,133.84 1,518,`[84.78 2.`17 -57.58 MWD*IFR-AK-Gi1Z-SC t2~ 1,033.16 15.30 113.10 1,024.33 968.43 -46.23 97.99 5,957,225.46 1,518,305.46 3.84 -71.45 MWD+IFR-AK-CAZ-SC (2) 1,128.54 18.15 113.76 1,115.66 1,059.76 -57.16 123.17 5,957,214.13 1,518,330.45 2.99 -88.89 MWD+IFR-AK-CAZ-SC (2) 1,223.73 20.24 109.87 1,205.56 1,149.66 -68.73 152.22 5,957,202.09 1,518,359.32 2.57 -108.03 MWD+IFR-AK-CAZ-SC (2) 1,319.10 24.53 109.64 1,293.72 1,237.82 -61.00 186.40 5,957,189.27 1,518,393.29 4.50 -129.24 MWD+IFR-AK-CAZ-SC (2) 1,414.12 27.63 110.40 1,379.06 1,323.16 -95.31 225.64 5,957,174.32 1,518,432.28 3.28 -153.81 MWD+IFR-AK-CAZ-SC (2) 1,509.75 29.24 111.23 1,463.15 1,407.25 -111.50 268.20 5,957,157.44 1,518,474.57 1.73 -181.11 MWD+IFR-AK-CAZ-SC (2) 1,604.43 30.32 110.93 1,545.32 1,489.42 -128.41 312.08 5,957,139.82 1,518,518.16 1.15 -209.46 MWD+IFR-AK-CAZ-SC (2) 1,699.32 33.66 110.63 1,625.79 1,569.89 -146.24 359.07 5,957,121.24 1,518,564.86 3.52 -239.55 MWD+IFR-AK-CAZ-SC (2) 1,794.72 37.15 109.28 1,703.54 1,647.64 -165.07 411.02 5,957,101.56 1,518,616.49 3.75 -271.97 MWD+IFR-AK-CAZSC (2) 1,890.15 39.51 107.54 1,778.40 1,722.50 -183.74 467.18 5,957,081.99 1,518,672.33 2.72 -305.39 MWD+IFR-AK-CAZ-SC (2) 1,984.93 42.94 107.58 1,849.67 1,793.77 -202.58 526.72 5,957,062.18 1,518,731.55 3.62 -339.91 MWD+IFR-AK-CAZ-SC (2) 2,080.54 47.38 107.87 1,917.07 1,867.17 -223.22 591.28 5,957,040.49 1,518,795.76 4.65 -377.55 MWD+IFR-AK-CAZ-SC (2) 2,175.68 50.06 108.42 1,979.83 1,923.93 -245.49 659.21 5,957,017.12 1,518,863.32 2.85 -417.68 MWD+IFR-AK-CAZ-SC (2) I 2,270.80 52.18 109.27 2,039.54 1,983.64 -269.41 729.28 5,956,992.07 1,518,932.98 2.33 -459.99 MWD+IFR-AK-CAZ-SC (2) 2,366.10 55.29 109.42 2,095.90 2,040.00 -294.87 801.77 5,956,965.44 1,519,005.05 3.27 -504.44 MWD+IFR-AK-CAZ-SC (2) 2,461.48 58.90 108.07 2,147.71 2,091.81 -320.58 877.59 5,956,938.50 1,519,080.43 3.97 -550.06 MWD+IFR-AK-CAZ-SC (2) 2,556.47 60.93 106.31 2,195.33 2,139.43 -344.85 956.11 5,956,912.96 1,519,158.54 2.67 -595.03 MWD+IFR-AK-CAZ-SC (2) 2,651.69 63.74 106.82 2,239.53 2,183.63 -368.90 1,036.93 5,956,887.60 1,519,238.95 2.99 X40.43 MWD+IFR-AK-CAZ-SC (2) 2,746.99 67.27 107.96 2,279.04 2,223.14 -394.83 1,119.67 5,956,860.34 1,519,321.26 3.86 -688.15 MWD+IFR-AK•CAZ-SC (2) 2,842.01 68.55 108.09 2,314.77 2,258.87 -422.07 1,203.40 5,956,831.74 1,519,404.52 1.35 -737.42 MWD+IFR-AK-CAZ-SC (2) 2,936.93 67.82 106.50 2,350.05 2,294.15 -448.27 1,287.53 5,956,804.18 1,519,488.21 1.73 -785.79 MWD+IFR-AK-CAZ-SC (2) 2,997.09 68.00 107.88 2,372.67 2,316.77 -464.74 1,340.78 5,956,786.84 1,519,541.18 2.15 -616.31 MWD+IFR-AK-CAZ-SC (2) 3,095.92 68.04 106.58 2,409.67 2,353.77 -491.89 1,428.31 5,956,758.28 1,519,628.25 1.22 -866.53 MWD+IFR-AK-CAZ-SC (2) 3,194.19 66.81 107.24 2,447.39 2,391.49 -518.28 1,515.13 5,956,730.48 1,519,714.62 1.40 -915.83 MWD+IFR-AK-CAZ-SC (2) 3,294.37 67.95 107.95 2,485.92 2,430.02 -546.23 1,603.27 5,956,701.10 1,519,802.29 1.37 -967.00 MWD+IFR-AK-CAZ-SC (2) 3,389.78 68.20 108.23 2,521.55 2,465.65 -573.72 1,687.41 5,956,672.25 1,519,885.96 0.38 -1,016.61 MWD+IFR-AK-CAZ-SC (2) 3,485.18 68.78 108.38 2,556.53 2,500.63 X01.59 1,771.67 5,956,643.07 1,519,969.75 0.63 -1,066.63 MWD+IFR-AK-CAZ-SC (2) 3,580.43 69.20 10926 2,590.68 2,534.78 X30.28 1,855.83 5,956,612.97 1,520,053.43 0.97 -1,117.40 MWD+IFR-AK-CAZ-SC (2) 3,675.81 68.80 108.83 2,624.86 2,568.96 -659.34 1,940.00 5,956,582.55 1,520,137.11 0.59 -1,168.53 MWD+IFR-AK-CAZ-SC (2) 3,770.77 68.08 109.48 2,659.73 2,603.83 X88.29 2,023.38 5,956,552.24 1,520,219.99 0.99 -1,219.35 MWD+IFR-AK-CAZ-SC (2) 3,865.85 67.48 109.76 2,695.71 2,639.81 -717.87 2,106.34 5,956,521.32 1,520,302.45 0.69 -1,270.64 MWD+IFR-AK-CAZ-SC (2) 3,961.04 68.80 109.88 2,732.69 2,676.79 -747.61 2,188.85 5,956,490.25 1,520,384.47 0.72 -1,321.98 MWD+IFR-AK-CAZ-SC (2) 4,055.77 66.47 110.22 2,770.26 2,714.36 -777.42 2,270.54 5,956,459.11 1,520,465.66 0.48 -1,373.15 MWD+IFR-AK-CAZ-SC (2) 4,150.85 67.26 110.61 2,807.62 2,751.72 -807.92 2,352.49 5,956,427.29 1,520,547.09 0.91 -1,425.06 MWD+IFR-AK-CAZ-SC (2) 4,245.76 68.13 110.69 2,843.64 2,787.74 -838.89 2,434.65 5,956,394.99 1,520,628.73 0.92 -1,477.47 MWD+IFR-AK-CAZSC (2) 4,340.81 68.53 108.76 2,878.74 2,822.84 -868.70 2,517.80 5,956,363.84 1,520,711.37 1.93 -1,529.04 MWD+IFR-AK-CAZ-SC (2) 4,435.99 67.42 108.92 2,914.43 2,858.53 -897.19 2,601.30 5,956,334.00 1,520,794.40 1.18 -1,579.45 MWD+IFR-AK-CAZ-SC (2) 4,530.99 68.94 106.86 2,949.74 2,893.84 -924.27 2,685.23 5,956,305.56 1,520,877.86 2.57 -1,628.61 MWD+IFR-AK-CAZ-SC (2) 4,626.22 68.67 106.88 2,984.17 2,928.27 -950.04 2,770.19 5,956,276.41 1,520,962.39 0.28 -1,676.80 MWD+IFR-AK-CAZ-SC (2) 5/27/2008 3:35:OSPM Page 3 COMPASS 2003.16 Build 42F • ConocoPh iitips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ord inate Reference: `Nell CD4-301 Project: Western North Slope ND Reference: CD4-301 (36.9+19) @ 55.91Nt (Doyon 19 (36.9+19)) Slte: CD4 Nanuq Pad MD Reference: CD4-301 (36.9+19) @ 55.90ft (Doyon 19 (36.9+19)) Well: CD4-301 North Refere nce: True Wellbore: CD4-3016 Survey Calcu lation Method: Minimum Curvature Design: CD4-3018 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azl ND NDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (') (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,721.53 6b.73 107.2a 3,u18.72 2,962.82 -576.07 2,ff54.90 5,550,251.09 1,521,040.00 0.41 -t,-125.17 MWG*IFk-AK-GrZ-SG t2) 4,816.33 68.94 106.85 3,053.02 2,997.12 -1,002.07 2,939.58 5,956,223.63 1,521,130.90 0.49 -1,773.52 MWD+IFR-AK-CAZ-SC (2) 4,911.30 68.81 108.28 3,087.25 3,031.35 -1,028.81 3,024.04 5,956,195.53 1,521,214.91 1.41 -1,822.49 MWD+IFR-AK-CAZ-SC (2) 5,007.65 68.93 107.75 3,121.98 3,066.08 -1,056.60 3,109.50 5,956,166.36 1,521,299.90 0.53 -1,872.77 MWD+IFR-AK-CAZ-SC (2) 5,102.79 68.35 107.95 3,156.64 3,100.74 -1,083.76 3,193.84 5,956,137.83 1,521,383.78 0.64 -1,922.12 MWD+IFR-AK-CAZ-SC (2) 5,197.51 67.54 108.16 3,192.20 3,136.30 -1,110.97 3,277.31 5,956,109.27 1,521,466.79 0.88 -1,971.28 MWD+IFR-AK-CAZ-SC (2) 5,292.94 68.41 108.69 3,227.99 3,172.09 -1,138.93 3,361.24 5,956,079.95 1,521,550.24 1.05 -2,021.29 MWD+IFR-AK-CAZ-SC (2) 5,388.21 69.85 107.88 3,261.93 3,206.03 -1,166.86 3,445.76 5,956,050.66 1,521,634.29 1.71 -2,071.43 MWD+IFR-AK-CAZ-SC (2) 5,483.58 70.90 107.60 3,293.96 3,238.06 -1,194.23 3,531.32 5,956,021.90 1,521,719.39 1.14 -2,121.33 MWD+IFR-AK-CAZ-SC (2) 5,578.53 70.64 107.50 3,325.23 3,269.33 -1,221.26 3,616.80 5,955,993.49 1,521,804.41 0.29 -2,170.87 MWD+IFR-AK-CAZ-SC (2) 5,673.73 69.92 108.00 3,357.36 3,301.46 -1,248.58 3,702.15 5,955,964.79 1,521,889.30 0.90 -2,220.66 MWD+IFR-AK-CAZ-SC (2) 5,769.12 69.40 108.55 3,390.51 3,334.61 -1,276.63 3,787.08 5,955,935.36 1,521,973.75 0.77 -2,271.03 MWD+IFR-AK-CAZ-SC (2) 5,864.46 69.41 108.45 3,424.05 3,368.15 -1,304.94 3,871.71 5,955,905.68 1,522,057.91 0.10 -2,321.58 MWD+IFR-AK-CAZ-SC (2) 5,959.28 68.55 107.03 3,458.06 3,402.16 -1,331.91 3,956.01 5,955,877.34 1,522,141.75 1.67 -2,370.74 MWD+IFR-AK-CAZ-SC (2) 6,054.31 68.88 106.57 3,492.56 3,436.66 -1,357.51 4,040.78 5,955,850.36 1,522,226.08 0.57 -2,418.71 MWD+IFR-AK-CAZ-SC (2) 6,149.43 69.48 107.35 3,526.37 3,470.47 -1,383.44 4,125.82 5,955,823.06 1,522,310.68 0.99 -2,467.08 MWD+IFR-AK-CAZ-SC (2) 6,244.70 69.45 108.05 3,559.79 3,503.89 -1,410,57 4,210.81 5,955,794.56 1,522,395.22 0.69 -2,516.58 MWD+IFR-AK-CAZ-SC (2) 6,340.17 69.59 108.16 3,593.19 3,537.29 -1,438.36 4,295.82 5,955,765.39 1,522,479.75 0.18 -2,566.73 MWD+IFR-AK-CAZ-SC (2) 6,435.19 68.95 107.73 3,626.82 3,570.92 -1,465.74 4,380.36 5,955,736.64 1,522,563.83 0.80 -2,616.35 MWD+IFR-AK-CAZ-SC (2) I 6,530.42 67.80 109.14 3,661.92 3,61.02 -1,493.73 4,464.34 5,955,707.30 1,522,647.34 1.83 -2,666.41 MWD+IFR-AK-CAZ-SC (2) 6,625.80 66.96 109.28 3,698.61 3,642.71 -1,522.70 4,547.48 5,955,676.98 1,522,729.99 0.89 -2,717.17 MWD+IFR-AK-CAZ-SC (2) 6,720.91 66.19 109.71 3,736.42 3,680.52 -1,551.82 4,629.75 5,955,646.53 1,522,811.77 0.97 -2,767.84 MWD+IFR-AK-CAZ-SC (2) 6,815.75 65.92 109.86 3,774.91 3,719.01 -1,581.16 4,711.31 5,955,615.87 1,522,892.84 0.32 -2,818.52 MWD+IFR-AK-CAZ-SC (2) 6,910.93 67.95 110.81 3,812.20 3,756.30 -1,611.60 4,793.42 5,955,584.11 1,522,974.43 2.32 -2,870.41 MWD+IFR-AK-CAZ-SC (2) 7,006.07 69.26 111.18 3,846.90 3,791.00 -1,643.34 4,876.12 5,955,551.03 1,523,056.60 1.42 -2,923.72 MWD+IFR-AK-CAZ-SC (2) 7,107.24 66.88 106.69 3,680.91 3,825.01 -1,672.18 4,960.17 5,955,520.83 7,523,140.16 4.42 -2,974.61 MWD+IFR-AK-CAZ-SC (2) 7,196.07 69.47 106.60 3,914.63 3,858.73 -1,697.56 5,045.09 5,955,494.07 1,523,224.65 0.63 -3,022.42 MWD+IFR-AK-CAZ-SC (2) 7,291.15 68.41 106.52 3,948.79 3,892.89 -1,722.65 5,130.14 5,955,467.40 1,523,309.27 1.12 -3,070.17 MWD+IFR-AK-CAZ-SC (2) 7,386.11 69.21 107.16 3,983.12 3,927.22 -1,748.50 5,214.88 5,955,440.38 1,523,393.58 1.05 -3,118.19 MWD+IFR-AK-CAZ-SC (2) 7,481.36 69.13 104.54 4,016.99 3,961.09 -1,772.82 5,300.51 5,955,414.68 1,523,478.79 2.57 -3,165.16 MWD+IFR-AK-CAZ-SC (2) 7,576.34 69.07 103.34 4,050.88 3,994.98 -1,794.79 5,386.63 5,955,391.91 7,523,564.54 1.18 -3,209.44 MWD+IFR-AK-CAZ-SC (2) 7,671.69 69.81 104.09 4,084.36 4,028.46 -1,815.36 5,473.36 5,955,369.33 1,523,650.91 1.07 -3,253.70 MWD+IFR-AK-CAZ-SC (2) 7,766.87 68.88 104.13 4,117.94 4,062.04 -1,837.07 5,559.73 5,955,346.22 1,523,736.91 0.98 -3,298.37 MWD+IFR-AK-CAZ-SC (2) 7,862.38 68.60 106.00 4,152.57 4,096.67 -1,860.20 5,645.68 5,955,321.70 1,523,622.46 1.85 -3,344.30 MWD+IFR-AK-CAZSC(2) ~ 7,957.80 68.48 108.54 4,187.49 4,131.59 -1,886.56 5,730.47 5,955,293.97 1,523,906.81 2.48 -3,393.01 MWD+IFR-AK-CAZ-SC (2) 8,053.14 69.53 109.45 4,221.65 4,165.75 -1,915.54 5,814.63 5,955,263.63 1,523,990.48 1.42 -3,444.06 MWD+IFR-AK-CAZ-SC (2) 8,148.73 68.66 110.66 4,255.74 4,199.84 -7,946.16 5,898.52 5,955,231.65 1,524,073.85 1.48 -3,496.62 MWD+IFR-AK-CAZ-SC (2) 8,243.70 69.13 111.87 4,289.92 4,234.02 -1,976.29 5,981.09 5,955,198.18 1,524,155.88 1.28 -3,550.27 MWD+IFR-AK-CAZ-SC (2) 6,338.95 69.99 110.65 4,323.19 4,267.29 -2,010.65 6,064.26 5,955,164.48 1,524,238.51 1.50 -3,604.30 MWD+IFR-AK-CAZ-SC (2) 8,434.01 72.08 110.01 4,354.08 4,298.18 -2,041.88 6,148.56 5,955,131.88 1,524,322.28 2.29 -3,657.56 MWD+IFR-AK-CAZ-SC (2) 5/27/2008 3:35:08PM Page 4 COMPASS 2003.16 Build 42F • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc . -WNS Local Co-ordi nate Reference: Well CD4-301 Project: Western North Slope ND Referenc e: CD4-301 (36.9+19) @ 55.90ft (Doyon 19 (36.9+19)) Site: CD4 Nanuq Pad MD Reference: CD4-301 (36.9+19) @ 55.908 (Doyon 19 (36.9+19)) Well: CD4-301 North Referen ce: True Wellbore: CD4-3016 Survey Calcu lation Method: Minimum Curvature Design: CD4-3016 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/1D0') (ft) Survey Tool Name 8,524.34 69.80 108.42 4,384.90 4,025.00 -2,071.24 6,232.77 5,555, 101.1b 1,524,406.00 2.89 -3,708.99 MWD+IFR-Ah-(iK-SG t2~ 8,624.08 68.35 108.34 4,419.07 4,363.17 -2,099.43 6,317.60 5,955,071.60 1,524,490.35 1.52 -3,759.47 MWD+IFR-AK-CAZ-SC (2) 8,719.33 67.61 109.01 4,454.79 4,398.89 -2,127.70 6,401.25 5,955,041.98 1,524,573.53 1.01 -3,609.70 MWD+IFR-AK-CAZ-SC (2) 8,815.02 67.95 110.03 4,490.97 4,435.07 -2,157.30 6,484.74 5,955,011.03 1,524,656.52 1.05 -3,861.17 MWD+IFR-AK-CAZ-SC (2) 8,909.68 68.01 110.14 4,526.46 4,470.56 -2,187.44 6,567.16 5,954,979.56 1,524,738.43 0.12 -3,912.85 MWD+IFR-AK-CAZ-SC (2) 9,005.13 68.46 110.39 4,561.86 4,505.96 -2,218.14 6,650.32 5,954,947.51 1,524,821.07 0.53 3,965.29 MWD+IFR-AK-CAZ-SC (2) 9,100.35 68.61 109.99 4,596.70 4,540.80 -2,248.72 6,733.49 5,954,915.58 1,524,903.73 0.42 -4,017.61 MWD+IFR-AK-CAZ-SC (2) 9,195.23 68.48 109.35 4,631.41 4,575.51 -2,278.45 6,816.64 5,954,884.51 1,524,986.38 0.64 -4,069.11 MWD+IFR-AK-CAZ-SC (2) 9,290.27 68.49 109.25 4,666.26 4,610.36 -2,307.67 6,900.09 5,954,853.94 1,525,069.33 0.10 -4,120.20 MWD+IFR-AK-CAZ-SC (2) 9,385.53 69.00 108.15 4,700.79 4,644.89 -2,336.13 6,984.18 5,954,824.11 1,525,152.94 1.20 -0,170.74 MWD+IFR-AK-CAZSC (2) 9,480.98 69.85 107.93 4,734.34 4,678.44 -2,363.81 7,069.15 5,954,795.06 1,525,237.44 0.92 -4,220.76 MWD+IFR-AK-CAZ-SC (2) 9,575.95 69.47 107.92 4,767.35 4,711.45 -2,391.21 7,153.87 5,954,766.29 1,525,321.70 0.40 -4,270.46 MWD+IFR-AK-CAZ-SC (2) 9,595.00 69.41 107.81 4,774.04 4,718.14 -2,396.68 7,170.85 5,954,760.54 1,525,338.59 0.63 -4,280.40 MWD+IFR-AK-CAZ-SC (3) 9,635.60 68.41 107.35 4,788.72 4,732.82 -2,408.18 7,207.14 5,954,748.45 1,525,374.68 2.67 -0,301.45 MWD+IFR-AK-CAZ-SC (3) 9,731.19 66.07 105.63 4,825.62 4,769.72 -2,433.16 7,291.47 5,954,722.11 1,525,458.59 2.96 -4,348.70 MWD+IFR-AK-CAZ-SC (3) 9,626.41 65.96 102.73 4,864.34 4,808.44 -2,454.47 7,375.81 5,954,699.44 1,525,542.56 2.78 -0,392.43 MWD+IFR-AK-CAZ-SC (3) 9,922.37 64.90 99.13 4,904.25 4,848.35 -2,471.02 7,461.47 5,954,681.49 1,525,627.94 3.59 -4,431.96 MWD+IFR-AK-CAZ-SC (3) 10,017.20 63.84 95.35 4,945.28 4,889.38 -2,481.81 7,546.27 5,954,669.33 1,525,712.54 3.76 -4,465.70 MWD+IFR-AK-CAZ-SC (3) 10,112.51 62.43 92.41 4,988.36 4,932.46 -2,487.57 7,631.08 5,954,662.19 1,525,797.24 3.12 -0,494.62 MWD+IFR-AK-CAZ-SC (3) 10,208.09 61.40 89.40 5,033.36 4,977.46 -2,488.92 7,715.38 5,954,659.48 1,525,881.50 2.98 -4,519.15 MWD+IFR-AK-CAZ-SC (3) 10,303.19 60.83 85.94 5,079.31 5,023.41 -2,485.54 7,798.56 5,954,661.50 1,525,964.72 3.24 -4,538.83 MWD+IFR-AK-CAZ-SC (3) 10,398.49 60.56 82.25 5,125.97 5,070.07 -2,476.99 7,881.20 5,954,668.70 1,526,047.48 3.39 -0,553.39 MWD+IFR-AK-CAZ-SC (3) 10,493.70 60.24 78.61 5,173.01 5,117.11 -2,463.24 7,962.81 5,954,681.13 1,526,129.30 3.34 -0,562.67 MWD+IFR-AK-CAZ-SC (3) 10,588.01 59.11 75.09 5,220.64 5,164.74 -2,444.74 8,042.07 5,954,698.33 1,526,208.84 3.44 -4,566.73 MWD+IFR-AK-CAZ-SC (3) 10,683.44 57.86 71.42 5,270.53 5,214.63 -2,421.32 8,119.96 5,954,720.48 1,526,287.09 3.53 -4,565.69 MWD+IFR-AK-CAZ-SC (3) 10,778.63 58.46 67.45 5,320.76 5,264.86 -2,392.92 8,195.64 5,954,747.65 1,526,363.22 3.60 -0,559.24 MWD+IFR-AK-CAZ-SC (3) 10,873.72 58.56 63.61 5,370.45 5,314.55 -2,359.34 8,269.42 5,954,780.02 1,526,437.53 3.44 -0,547.30 MWD+IFR-AK-CAZ-SC (3) 10,968.62 57.81 59.16 5,420.49 5,364.59 -2,320.74 8,340.19 5,954,817.46 1,526,508.91 4.06 -0,529.71 MWD+IFR-AK-CAZ-SC (3) 11,064.03 57.53 54.56 5,471.54 5,415.64 -2,276.69 8,407.67 5,954,860.40 1,526,577.09 4.08 -4,505.96 MWD+IFR-AK-CAZ-SC (3) 11,159.49 58.84 50.37 5,521.88 5,465.98 -2,227.27 8,471.96 5,954,908.76 1,526,642.17 3.97 -4,476.18 MWD+IFR-AK-CAZ-SC (3) 11,254.40 56.83 45.66 5,571.01 5,515.71 -2,172.97 8,532.30 5,954,962.07 1,526,703.38 4.25 -4,440.61 MWD+IFR-AK-CAZ-SC (3) 11,349.53 59.16 41.24 5,620.03 5,564.13 -2,113.79 8,588.35 5,955,020.33 1,526,760.38 4.00 -4,399.18 MWD+IFR-AK-CAZ-SC (3) 11,444.70 59.63 37.35 5,668.50 5,612.60 -2,050.42 8,640.21 5,955,082.85 1,526,813.26 3.55 -4,352.55 MWD+IFR-AK-CAZ-SC (3) 11,539.92 60.21 34.06 5,716.23 5,660.33 -1,983.52 8,688.28 5,955,148.95 1,526,862.41 3.05 -4,301.49 MWD+IFR-AK-CAZ-SC (3) 11,635.16 60.68 30.31 5,763.23 5,707.33 -1,913.40 8,732.40 5,955,218.33 1,526,907.66 3.46 -4,246.26 MWD+IFR-AK-CAZ-SC (3) 11,730.62 61.31 27.11 5,809.52 5,753.62 -1,840.21 8,772.48 5,955,290.86 1,526,948.92 3.01 -4,186.94 MWD+IFR-AK-CAZ-SC (3) 11,825.06 62.85 23.44 5,853.75 5,797.85 -1,764.76 8,808.09 5,955,365.71 1,526,985.74 3.80 -0,124.23 MWD+IFR-AK-CAZ-SC (3) 11,920.21 63.68 21.63 5,896.56 5,840.66 -1,686.27 8,840.65 5,955,443.65 1,527,019.57 1.91 -4,057.76 MWD+IFR-AK-CAZ-SC (3) 12,D15.56 63.00 21.36 5,939.34 5,883.44 -1,606.99 8,871.87 5,955,522.41 1,527,052.08 0.76 -3,990.15 MWD+IFR-AK-CAZ-SC (3) 12,110.90 63.47 20.14 5,982.28 5,926.38 -1,527.39 8,902.03 5,955,601.51 1,527,083.52 1.24 3,921.95 MWD+IFR-AK-CAZ-SC (3) 5/27/2008 3:35:08PM Page 5 COMPASS 2003.16 Build 42F • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Project: Western North Slope TVD Reference: Site: CD4 Nanuq Pad MD Reference: Well: CD4-301 North Reference: Wellbore: CD4-3018 Survey Calculation Method: Design: CD4-3018 Database: Survey Well CD4-301 CD4-301 (36.9+19) @ 55.90ft (Doyon 19 (36.9+19)) CD4-301 (36.9+19) @ 55.90Ft (Doyon 19 (36.9+19)) True Minimum Curvature CPAI EDM Production Map Map Vertical MD Inc Azl TVD TVDSS +Nf-S +E/-W Northing Easting DLS Section (ft) (~) (~) (h) (ft) in) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 12,206.51 43.41 15.2ts ti,UZ4.54 5,565.04 -1,447.05 13,530.81 5,555,5H1.35 1,527,113.60 0.61 -3,it52.65 MWG+IFk-Ah-0i~-Sl. (3) 12,301.44 63.02 20.40 6,067.81 6,011.91 -1,367.16 8,959.63 5,955,760.76 1,527,143.72 1.13 -3,783.81 MWD+IFR-AK-CAZ-SC (3) 12,396.68 63.54 20.74 6,110.63 6,054.73 -1,287.52 8,989.52 5,955,839.90 1,527,174.90 0.63 -3,715.49 MWD+IFR-AK-CAZ-SC (3) 12,491.62 63.59 20.32 6,152.90 6,097.00 -1,207.91 9,019.33 5,955,919.01 1,527,206.00 0.40 -3,647.18 MWD+IFR-AK-CAZ-SC (3) 12,586.76 63.28 20.94 6,195.45 6,139.55 -1,128.27 9,049.31 5,955,998.15 1,527,237.27 0.67 -3,578.89 MWD+IFR-AK-CAZ-SC (3) 12,777.54 63.46 21.81 6,280.96 6,225.06 -969.46 9,111.47 5,956,155.91 1,527,301.99 0.42 -3,443.36 MWD+IFR-AK-CAZ-SC (3) 12,873.12 63.94 22.91 6,323.31 6,267.41 -890.22 9,144.07 5,956,234.61 1,527,335.87 1.15 -3,376.18 MWD+IFR-AK-CAZ-SC (3) ~ 12,967.76 63.47 23.71 6,365.24 6,309.34 -812.30 9,177.64 5,956,311.96 1,527,370.70 0.91 -3,310.53 MWD+IFR-AK-CAZ-SC (3) 13,062.22 63.26 21.87 6,407.59 6,357.69 -734.46 9,210.35 5,956,389.25 1,527,404.67 1.76 -3,244.72 MWD+IFR-AK-CAZ-SC (3) 13,157.24 63.56 19.81 6,450.12 6,394.22 -655.05 9,240.57 5,956,468.75 1,527,436.18 1.96 -3,176.72 MWD+IFR-AK-CAZ-SC (3) 13,252.42 63.34 18.72 6,492.67 6,436.77 -574.68 9,268.66 5,956,548.05 1,527,465.57 1.05 -3,107.21 MWD+IFR-AK-CAZ-SC (3) 13,347.59 63.62 18.81 6,535.16 6,479.26 -094.05 9,296.06 5,956,628.22 1,527,494.27 0.31 -3,037.25 MWD+IFR-AK-CAZ-SC (3) 13,442.62 63.55 18.20 6,577.44 6,521.54 -013.34 9,323.07 5,956,708.47 7,527,522.59 0.58 -2,967.12 MWD+IFR-AK-CAZ-SC (3) 13,537.58 65.06 16.24 6,618.61 6,562.71 -331.61 9,348.39 5,956,789.77 1,527,549.23 2.45 -2,895.53 MWD+IFR-AK-CAZ-SC (3) 13,632.90 66.74 12.76 6,657.54 6,601.64 -247.39 9,370.16 5,956,873.62 1,527,572.36 3.77 -2,820.57 MWD+IFR-AK-CAZ-SC (3) 13,728.17 67.82 10.26 6,694.34 6,638.44 -161.29 9,387.66 5,956,959.42 1,527,591.28 2.67 -2,742.63 MWD+IFR-AK-CAZ-SC (3) 13,823.76 69.47 9.33 6,729.15 6,673.25 -73.56 9,402.82 5,957,046.88 1,527,607.84 1.95 -2,662.46 MWD+IFR-AK-CAZ-SC (3) 13,919.03 71.50 6.46 6,760.98 6,705.08 15.37 9,415.14 5,957,135.59 1,527,621.60 3.55 -2,580.39 MWD+IFR-AK-CAZ-SC (3) 14,074.48 72.99 3.51 6,790.09 6,734.19 105.92 9,423.03 5,957,225.99 1,527,630.96 3.33 -2,495.52 MWD+IFR-AK-CAZ-SC (3) 14,109.11 75.17 0.11 6,816.05 6,760.15 196.85 9,425.89 5,957,316.86 1,527,635.30 4.15 -2,408.90 MWD+IFR-AK-CAZ-SC (3) 14,204.45 76.39 357.85 6,839.48 6,783.58 289.25 9,424.24 5,957,409.26 1,527,635.15 2.63 -2,319.63 MWD+IFR-AK-CAZ-SC (3) 14,300.56 78.60 355.46 6,860.29 6,804.39 382.90 9,418.75 5,957,502.99 1,527,631.19 3.34 -2,228.09 MWD+IFR-AK-CAZ-SC (3) 14,395.21 80.23 352.75 6,877.68 6,821.78 475.44 9,409.19 5,957,595.66 1,527,623.14 3.30 -2,136.51 MWD+IFR-AK-CAZ-SC (3) 14,490.54 83.29 350.00 6,891.34 6,835.44 568.70 9,395.04 5,957,689.12 1,527,610.50 4.30 -2,042.96 MWD+IFR-AK-CAZ-SC (3) 14,583.96 84.91 347.02 6,900.94 6,845.04 659.74 9,376.53 5,957,780.45 1,527,593.48 3.62 -1,950.34 MWD+IFR-AK-CAZ-SC (3) 14,679.85 86.64 343.76 6,908.01 6,852.11 752.26 9,352.41 5,957,873.35 1,527,570.87 3.84 -1,854.75 MWD+IFR-AK-CAZ-SC (3) 14,730.24 88.24 342.69 6,910.26 6,854.36 800.48 9,337.96 5,957,921.79 1,527,557.21 3.61 -1,804.42 MWD+IFR-AK-CAZ-SC (3) 14,775.91 91.33 344.70 6,910.43 6,854.53 844.33 9,325.22 5,957,965.84 7,527,545.18 7.84 -1,758.75 MWD+IFR-AK-CAZ-SC (3) 14,823.06 88.92 345.24 6,910.33 6,854.43 889.87 9,313.00 5,958,011.56 1,527,533.70 5.24 -1,711.62 MWD+IFR-AK-CAZ-SC (3) 14,847.80 88.32 346.68 6,910.93 6,855.03 913.86 9,307.00 5,958,035.65 1,527,528.09 6.30 -1,686.90 MWD+IFR-AK-CAZ-SC (4) 14,909.94 91.89 350.28 6,910.81 6,854.91 974.73 9,294.59 5,958,096.70 1,527,516.68 8.16 -1,624.97 MWD+IFR-AK-CAZ-SC (4) 14,919.17 92.26 350.82 6,910.48 6,854.58 983.83 9,293.08 5,958,105.82 1,527,515.37 7.09 -1,615.80 MWD+IFR-AK-CAZ-SC (4) 14,932.34 91.44 351.58 6,910.05 6,854.15 996.83 9,291.06 5,958,118.86 1,527,513.51 8.49 -1,602.74 MWD+IFR-AK-CAZ-SC (4) 15,024.40 85.76 352.35 6,912.30 6,856.40 1,067.93 9,278.20 5,958,210.14 1,527,502.13 6.23 -1,511.64 MWD+IFR-AK-CAZ-SC (4} 15,118.46 89.83 350.76 6,915.92 6,860.02 1,180.87 9,264.40 5,958,303.29 1,527,489.84 4.64 -1,418.49 MWD+IFR-AK-CAZ-SC (4) 15,214.95 89.80 348.79 6,916.23 6,860.33 1,275.83 9,247.27 5,958,398.51 1,527,474.26 2.04 -1,322.49 MWD+IFR-AK-CAZ-SC (4) 15,307.98 90.04 345.98 6,916.36 6,860.46 1,366.60 9,226.96 5,958,489.59 1,527,455.43 3.03 -1,229.63 MWD+IFR-AK-CAZ-SC (4) 15,403.08 90.14 343.44 6,916.21 6,860.31 1,458.33 9,201.88 5,958,581.71 1,527,431.85 2.67 -1,134.55 MWD+IFR-AK-CAZ-SC (4) 15,499.32 89.69 338.41 6,916.35 6,860.45 1,549.25 9,170.44 5,958,673.12 1,527,401.89 5.25 -1,038.48 MWD+IFR-AK-CAZ-SC (4) 15,591.05 89.93 334.93 6,916.66 6,860.78 1,633.47 9,134.12 5,958,757.91 1,527,366.95 3.80 -947.51 MWD+IFR-AK-CAZ-SC (4) 5/27/2008 3:35:08PM Page 6 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Locat Co-ord[nate Reference: Well CD4-301 Project: Western North Slope TVD Refere nce: CD4-301 (36.9+19) @ 55.90ft (Doyon 19 (36.9+19)) Site: CD4 Nanuq Pad MD Referen ce: CD4-301 (36.9+19) @ 55.90k (Doyon 19 (36.9+19)) Well: CD4-301 North Refer ence: -true Wellbore: CD4-3016 Survey Calculation Method: Minimum Curvature Design: CD4-3016 Database: CPA( EDM Production Survey -- -- -_ Map Map Vertical MD Inc Axl TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name i 15,6x5.59 85.28 336.55 5,y17.31 6,861.41 1,718.54 9,093.07 5,958,843.63 1,527,327.26 1.61 -854.42 MWG+fFR-ivi-ilia-5i. (4) 15,779.62 90.48 332.74 6,917.51 6,861.61 1,802.50 9,050.56 5,958,928.26 1,527,286.15 1.54 -762.00 MWD+IFR-AK-CAZ-SC (4) 15,874.97 90.00 333.18 6,917.11 6,66121 1,887.42 9,007.21 5,959,013.87 1,527,244.19 0.68 -668.42 MWD+IFR-AK-CAZ-SC (4) 15,969.50 89.52 334.54 6,917.50 6,861.60 1,972.28 8,965.56 5,959,099.39 1,527,203.94 1.53 -575.37 MWD+IFR-AK-CAZSC (4) 16,063.09 89.93 335.98 6,917.95 6,862.05 2,057.28 8,926.40 5,959,185.00 1,527,166.16 1.60 -462.87 MWD+IFR-AK-CAZ-SC (4) 16,158.15 89.21 336.44 6,918.67 6,862.77 2,144.26 8,868.05 5,959,272.59 1,527,129.24 0.90 -388.69 MWD+IFR-AK-CAZ-SC (4) 16,249.93 90.00 335.07 6,919.30 6,863.40 2,227.94 8,850.37 5,959,356.86 1,527,092.92 1.72 -297.86 MWD+IFR-AK-CAZ-SC (4) 16,346.43 90.52 337.06 6,918.86 6,862.96 2,316.13 8,811.22 5,959,445.68 1,527,055.22 2.13 -202.29 MWD+IFR-AK-CAZ-SC (4) 16,440.81 90.07 339.60 6,918.38 6,862.48 2,403.83 8,776.37 5,959,533.93 1,527,021.80 2.73 -t08.38 MWD+IFR-AK-CAZ-SC (4) 16,535.54 89.73 344.21 6,918.54 6,862.64 2,493.85 8,746.96 5,959,624.40 1,526,993.86 4.88 -13.74 MWD+IFR-AK-CAZ-SC (4) 16,629.99 89.76 347.77 6,918.96 6,863.06 2,585.48 8,724.10 5,959,716.38 1,526,972.49 3.77 80.64 MWD+IFR-AK-CAZ-SC (4) 16,724.56 90.24 352.39 6,918.96 6,863.06 2,678.61 8,707.81 5,959,809.76 1,526,957.72 4.91 174.65 MWD+IFR-AK-CAZ-SC (4) 16,820.18 90.17 351.65 6,918.62 6,862.72 2,773.30 8,694.53 5,959,904.65 1,526,945.99 0.78 269.33 MWD+IFR-AK-CAZ-SC (4) 16,913.95 90.07 352.56 6,918.42 6,862.52 2,866.18 8,681.65 5,959,997.71 1,526,934.62 0.98 362.16 MWD+IFR-AK-CAZ-SC (4) I 17,008.00 89.21 351.37 6,919.01 6,863.11 2,959.31 8,668.51 5,960,091.03 1,526,922.99 1.56 455.30 MWD+IFR-AK-CAZ-SC (4) 17,101.66 91.47 351.48 6,918.46 6,862.58 3,051.91 8,654.54 5,960,183.84 1,526,910.54 2.42 548.17 MWD+IFR-AK-CAZ-SC (4) 17,195.05 90.86 349.96 6,916.56 6,860.66 3,144.06 8,639.49 5,960,276.21 1,526,896.98 1.75 640.89 MWD+IFR-AK-CAZ-SC (4) 17,291.08 89.18 351.17 6,916.53 6,860.63 3,238.78 8,623.75 5,960,371.17 1,526,882.78 2.16 736.29 MWD+IFR-AK-CAZ-SC (4) 17,386.66 89.14 347.16 6,917.93 6,862.03 3,332.63 8,605.79 5,960,465.29 1,526,866.35 4.20 831.45 MWD+IFR-AK-CAZ-SC (4) 17,479.48 89.55 347.91 6,918.99 6,863.09 3,423.25 6,585.75 5,960,556.22 1,526,847.79 0.92 924.09 MWD+IFR-AK-CAZ-SC (4) 17,573.64 88.70 348.20 6,920.43 6,864.53 3,515.36 8,566.27 5,960,648.63 1,526,829.81 0.95 1,018.00 MWD+IFR-AK-CAZ-SC (4) 17,669.20 89.49 346.39 6,921.94 6,866.04 3,608.57 8,545.25 5,960,742.16 1,526,810.32 2.07 1,113.39 MWD+IFR-AK-CAZ-SC {4) 17,764.14 90.72 343.56 6,921.76 6,865.86 3,700.25 8,520.64 5,960,834.22 1,526,787.20 3.25 1,208.30 MWD+IFR-AK-CAZ-SC (4) 17,859.47 90.27 342.24 6,920.94 6,865.04 3,791.36 8,492.61 5,960,925.77 1,526,760.66 1.46 1,303.61 MIND+IFR-AK-CAZ-SC (4) 17,952.63 90.00 341.14 6,920.72 6,864.82 3,879.80 8,463.35 5,961,014.66 1,526,732.84 1.22 1,396.69 MWD+IFR-AK-CAZ-SC (4) 18,047.54 91.99 343.03 6,919.07 6,863.17 3,970.09 8,434.16 5,961,105.41 1,526,705.12 2.89 1,491.52 MWD+IFR-AK-CAZ-SC (4) 18,142.58 90.89 343.27 6,916.68 6,860.78 4,061.02 8,406.62 5,961,196.76 1,526,679.07 1.18 1,586.52 MWD+IFR-AK-CAZ-SC (4) 18,237.37 91.96 343.48 6,914.32 6,858.42 4,151.82 8,379.51 5,961,287.98 1,526,653.44 1.15 1,681.28 MWD+IFR-AK-CAZ-SC (4) 18,330.76 88.56 340.22 6,913.90 6,858.00 4,240.53 8,350.43 5,961,377.15 1,526,625.80 5.04 1,774.57 MWD+IFR-AK-CAZ-SC (4) 18,422.21 90.41 338.54 6,914.72 6,858.82 4,326.11 8,318.22 5,961,463.24 1,526,595.00 2.73 1,865.71 MWD+IFR-AK-CAZ-SC (4) 18,516.26 89.49 337.72 6,914.81 6,858.91 4,413.39 8,283.19 5,961,551.07 1,526,561.39 1.31 1,959.27 MWD+IFR-AK-CAZ-SC (4) 18,611.79 90.31 338.90 6,914.97 6,859.07 4,502.16 8,247.89 5,961,640.39 1,526,527.54 1.50 2,054.33 MWD+IFR-AK-CAZ-SC (4) 18,706.29 88.53 338.25 6,915.93 6,860.03 4,590.12 8,213.37 5,961,728.89 1,526,494.46 2.01 2,148.39 MWD+IFR-AK-CAZ-SC (4) 18,746.34 88.35 338.23 6,917.02 6,861.12 4,627.30 8,198.53 5,961,766.31 1,526,480.23 0.45 2,188.23 MWD+IFR-AK-CAZ-SC (4) • 18,806.94 88.35 338.23 6,918.76 ~ 6,862.86 4,683.56 8,176.06 5,961,822.92 1,526,458.68 0.00 2,248.49 PROJECTED to TD 5/27/2008 3:35:08PM Page 7 COMPASS 2003.16 Build 42F CJ • Time Logs _ __ __ __ _ Date From To Dur ~ S Depth E. De th Phase Code Subcode T COM 01/10/2008 20:00 00:00 4.00 0 0 INTRM2 RPCOh FRZP X RU on well to pump inhibited CaCl2 brine & diesel -Held PJSM -Test lines to 1000 psi -Pumped 40 bbls 10.7 ppg inhibited brine followed by 54 bbls diesel w/ Dowell -Shut down - shut inwell -Blow down lines - RU line to U-tube fluid to equalize brine f/ 2845 to 1520' & diesel f/ 1520' to surface - Shut in well -Blow down & RD lines -Set BPV -Secure well 01/11/2008 00:00 11:30 11.50 0 0 INTRM1 DRILL PULD P LD 5"DP - 11:30 13:00 1.50 0 0 INTRM1 DRILL OTHR P Clean drains, drip pans, pipe racks Release ri 1300 hrs. 04/02/2008 00:00 12:00 12.00 0 0 INTRM1 MOVE DMOB NP Doyon 141 Rig on standby, waiting on orders to move rig and camp to Alpine CD4-301 B. ADEC considering Air quality permitting issues. Note: Rig crews re-building BOP STack. Crew Chan e 12:00 00:00 12.00 0 0 INTRM1 MOVE DMOB NP Doyon 141 Rig on standby, waiting on orders to move rig and camp to Alpine CD4-301 B. ADEC considering Air quality permitting issues. Note: Rig crews re-building BOP STack. Crew Chan e 04/03/2008 00:00 12:00 12.00 0 0 INTRM1 MOVE DMOB NP Rig on standby, waiting on orders to move rig and camp to Alpine CD4-301 B. ADEC considering Air quality permitting issues. Crew Chan e 12:00 18:00 6.00 0 0 INTRM1 MOVE DMOB NP Rig on standby, waiting on orders to move rig and camp to Alpine CD4-301 B. ADEC considering Air ualit ermittin issues. 18:00 00:00 6.00 0 0 INTRM1 MOVE MOB P Received permission to move. Call for trucks. Demob camp & sewer plant. Load on trucks and move to CD4-103. 0 INTRM1 MOVE 04/04/2008 00:00 03:00 3.00 0 0 INTRMI MOVE MOB P Continue move Doyon 141 rig camp & sewer plant to CD4-1036. On location at 0200HRS. Spot matting boards and cam .Take on water. 03:00 11:30 8.50 0 0 INTRMI MOVE MOB P Mobilize trucks back to Spark DD. Demob Boiler, Motors, Pumps, and Pit complexes. Move to CD4-301 location. Rig communications. Note: Doyon 141 Rig released from Standby at 0430 HRS. Trucks on location movin ri . 11:30 12:00 0.50 0 INTRM1 MOVE MOB P Peak trucks moving back to Spark DD to load u third convo . 12:00 16:00 4.00 INTRM1 MOVE MOB P Move sub structure and derrick, both pipe tub sections, and rock washer from S ark DD. _ 13aga 23 e~f 33 r~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 04/04/2008 16:00 18:00 2.00 INTRM1 MOVE MOB P Spot sub over CD4-301 well. Ensure sub is centered and level over well. 18:00 22:00 4.00 INTRM1 MOVE MOB P Spotting the following buildings and modules: Mud pits, mud pumps, motors, boiler, rock washer and both i e sheds. 22:00 00:00 2.00 INTRM1 MOVE MOB P Work on "Pre-Rig Accept" checklist. Do on 141 Ri acce ted at 00:00 hrs. 04/05/2008 00:00 03:30 3.50 0 0 INTRM1 DRILL RURD P Rig up lines to tbg & annulus to displace well. Spot outside tank for returns. Rig up lines and test same. Install tree scaffolding. Pull BPV as er FMC re . 03:30 04:45 1.25 0 0 INTRM1 DRILL DHEQ P Pressure test down casing, 70 stks total to 3500 PSI. Hold test - 30 minutes, record on chart. Bleed all ressure. 04:45 06:00 1.25 0 0 INTRM1 DRILL CIRC P Pump down tubing staging pumps to 5 BPM - 500 PSI, pumping a total of 120 BBLS of diesel /brine to tank outside. Swap to pits and pump one more bottoms u with 9.2 brine. 06:00 06:30 0.50 0 0 INTRM1 WELCT OTHR P Install two way check valve as per FMC re . 06:30 07:30 1.00 0 0 INTRM1 WELCT NUND P Nipple down scaffold and tree. 07:30 09:30 2.00 0 0 INTRM1 WELC NUND P Nipple up two well head adapters. FMC speed head and double studded ada ter flan e. 09:30 12:00 2.50 0 0 INTRMI WELCT NUND P NU BOP stack, choke & kill lines. Crew Chan e 12:00 15:00 3.00 0 0 INTRM1 WELC NUND P Continue NU BOP stack. Install Koomey lines. Nipple up riser & flan e. Char a Accumulator. 15:00 16:00 1.00 0 0 INTRM1 WELC BOPE P Fill BOP stack with water. Perform body test to 250 / 3500 PSI as per well Ian. 16:00 17:00 1.00 0 0 INTRM1 WELCT OTHR P Clean & clear rig floor and cellar area. Rig up casing equipment, power tongs and elevators. 17:00 17:30 0.50 0 0 INTRM1 RPCOh RURD P Rig up double annulus valve on wellhead. Rig up Anadrill sensors on mud manifold and stand i e. 17:30 18:30 1.00 0 0 INTRM1 RPCO PULD P Make up landing joint to tbg hanger. Drain BOP stack. BOLDS. Pull tbg hanger to rig floor. UP WT = 52K. Breakout & lay down hanger, xo's and landin 'oint. Install stri in rubber. 18:30 22:30 4.00 0 0 INTRM1 RPCOti PULD P Pull and lay down 91 jnts of 3 1/2" tbg. Observed proper displacement. Visually Inspect threads when layed down. 22:30 23:30 1.00 0 0 INTRM1 RPCO RURD P Rig down casing running equipment. Send tongs out. Clean & clear rig floor area. ~~-- ~~a~ 2~# of 3 i ;~ _ Time Loc,~s ~~ _ Date From To Dur S. De th E. De th Ph se Code Subcode T COM 04/05/2008 23:30 00:00 0.50 0 0 INTRM1 WELC BOPE P Rig up test equipment for BOP test. Note: All gas alarms have been tested on this tour. Crew Chan e 04/06/2008 00:00 05:30 5.50 0 0 INTRMI WELCT BOPE P Continue test BOP stack, Choke & kill lines, manuals and HCR's. Test choke mainfold valves. Use 3 1/2", 4", and 4 1/2" test joints. All tests to 250 /300 PSI. Recorded on chart. Witness of test waived by AOGCC rep -Lou Grimaldi. perform Koomey test. observed first 200 PSI increase in 23 seconds. Full pressure in 3 min-23 secs. Rig down test equipment.SIMOPS: Load pipe shed with 4" DP. 05:30 06:00 0.50 0 0 INTRM1 DRILL PULD P Install wear bushing. RILDS. 06:00 06:15 0.25 0 0 INTRM1 DRILL SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to pick up 4" DP and rack in derrick. 06:15 10:45 4.50 0 0 INTRM1 DRILL PULD P Pickup 222 joints of 4" DP, run in hole. 10:45 12:00 1.25 0 0 INTRM1 DRILL PULD P POOH, racking back 25 stands in derrick. Crew Chan e 12:00 13:00 1.00 0 0 INTRM1 DRILL PULD P Continue POOH racking back 4" DP for a totaol of 74 stands in Derrick. 13:00 15:00 2.00 0 331 INTRM1 DRILL PULD P Clean & clear rig floor. Pull tools to floor. Held PJSM with crew &Anadrill reps. Make up BHA #5, 6 1.8" Hycalog bit with a 1.83 deg bent motor assembl .Total BHA len th = 331.71'. 15:00 15:30 0.50 331 331 INTRM1 DRILL PULD P Install Anadrill electronic display unit on rog floor drilling console. Function test same. 15:30 17:00 1.50 331 2,185 INTRM1 DRILL TRIP P Trip in hole picking up singles of 4" DP from shed to 2185'. 17:00 17:45 0.75 2,185 2,185 INTRM1 DRILL PULD P Perform shallow pulse test with pumps at 240 GPM's - 1000 PSI. Good test. Blow down to drive & lines. 17:45 00:00 6.25 2,185 7,978 INTRM1 DRILL TRIP P Continue trip in hole with BHA #5 from 2185' - 7978' MD. UP WT = 100K, SO WT = 60K. Breakout & lay down 1 bad joint of drill pipe. (Galled threads). Crew Chan e 04/07/2008 00:00 01:30 1.50 7,978 8,500 INTRM1 DRILL TRIP P Continue trip in hole from 7978' - 8340' DPM. Observed no tag while wash & .. rotate thr ough port collar ati.~~t~ de th of 8186' DPM. Tagged up at 8340' DPM @ wash & rotate from 8340' - 8407' DPM, observing cement with 200 PSI differential pressure. WOB at 5-10K, and staging to 240 GPM's - 2300 PSI. UP WT = 110K, SO WT = 69K. ROT WT = 85K. Run 3 more joints to 8,500' DPM. Verify no to . Page 25caf 31 \~ l~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcod T COM 04/07/2008 01:30 02:45 1.25 8,500 8,500 INTRM1 DRILL CIRC P Circulate Hi Visc sweep at 240 GPM's - 2200 PSI, to observe cement returns, cleaning up hole. Reciprocate drill strip . 02:45 03:00 0.25 8,500 8,712 INTRM1 DRILL TRIP P Continue trip in hole from 8500' - 8712' DPM, tagging up on cement once a ain. 03:00 06:00 3.00 8,712 8,963 INTRM1 DRILL REAM P Make up Top drive & continue wash & ream from 8712' - 8,963' DPM. WOB at 5-10K, pumping 230 GPM's -1500 PSI, 100 - 200 PSI differential ressure. 06:00 09:15 3.25 8,963 12,678 INTRMI DRILL TRIP P Continue TIH with singles from shed from 8,963' to 12,678' DPM. 09:15 10:15 1.00 12,678 14,658 INTRM1 DRILL TRIP P Continue TIH out of derrick from 12,678' - 14,658' DPM -Tagged up on cement 20 klbs . 10:15 10:30 0.25 14,658 14,658 INTRM1 DRILL SFTY P Pre job safety meeting prior to dis lacin hole with 9.2 brine. 10:30 12:00 1.50 14,658 14,658 INTRM1 DRILL CIRC P Pump high vis sweep and displace casing with 9.2 ppg brine @ 65 stk/min, 2,200 PSI, 30 RPM, 12-13 k Tor ue. Crew chap e 12:00 12:30 0.50 14,658 14,658 INTRM1 DRILL CIRC P Continue pumping high vis sweep and displacing casing with 9.2 ppg brine @ 65 stk/min, 2,200 PSI, 30 RPM, 12-13 k Tor ue. 12:30 14:00 1.50 14,658 14,750 INTRM1 DRILL REAM P Drill out cement from 14,658' to 14,750' DPM. WOB at 5-7 K, 65 SPM, 230 GPM - 1550 PSI, 30 RPM, 14K Tor ue. 14:00 15:00 1.00 14,750 14,750 INTRM1 DRILL OTHR P Perform casin test to 3 500 PSI for 30 MIN. Record on chart. 15:00 17:00 2.00 14,750 14,750 INTRM1 RIGMN' SVRG P Slip and cut drilling line and service to drive 17:00 20:00 3.00 14,750 14,842 INTRM1 DRILL DRLG P Drill out float equipment and cement to 14,842' MD. 65 SPM, 230 GPM - 2,100 PSI, 30 RPM, 15-17KTorque. PU=160, S0=100, ROT=125. 20:00 21:30 1.50 14,842 14,842 INTRM1 DRILL CIRC P Displace web to 9.2 ppg Flo-Pro drilling mud. Total of 1,160 bbl @ 65 SPM, 230 GPM and 2,100 PSI. PU=180, S0=90, ROT=125 with 13 K Tor ue. Obtain slow um rates. 21:30 00:00 2.50 14,842 14,855 INTRM1 DRILL DRLG P _ Drill out float shoe -Took 10k weight @ 14,846' DPM. Line bit up on low ~~ ~ _ ~' ` ~ side. Slide drill 9' of new hole to - ` 14,855' DPM. WOB 3-5k, 65 SPM, 230 GPM, 2,300 PSI. Crew Chan e 04/08/2008 00:00 00:15 0.25 14,855 14,871 INTRM1 DRILL DDRL P Drlg. 6 1/8"directional hole from 14855' MD to 14871' MD 6911' TVD. ADT .49 AST .07 ART .42 00:15 01:30 1.25 14,871 14,871 INTRM1 DRILL CIRC P CBU for FIT @ 70 SPM 2200 psi 30 r m7kt . 01:30 02:00 0.50 14,871 14,871 INTRM1 DRILL LOT P Rig up & perform FIT EMW 12.5# Rig down. P~rg~ 2~ ref 31 • Time Logs ~ Date From To Dur S D th E. De th Ph se Code Subcode T COM 04/08/2008 02:00 12:15 10.25 14,871 15,023 PROD1 DRILL DDRL P Drlg. from 14871' MD to 15023' MD 6905' ND. P/U 150k S/O 95k ROT 116k Bit wt. 5-10k RPM 30 T 7k. 12:15 13:00 0.75 15,023 15,023 PROD1 DRILL CIRC P CBU @ drlg. rates. 13:00 16:30 3.50 15,023 15,081 PROD1 DRILL DDRL P Drlg. from 15023' MD to 15081' MD 6904 ND P/U 155k S/O 98k ROT 125k. 16:30 18:30 2.00 15,081 15,081 PROD1 DRILL CIRC P CBU @ drlg. rates. Obtain SPR,s. 18:30 19:00 0.50 15,081 14,755 PROD1 DRILL TRIP P Pump out from 15081 to 14755' MD 19:00 19:15 0.25 14,755 14,755 PROD1 DRILL OTHR P Monitor well inside 7" shoe. slight flow. Decision made to run back to bottom & brin mud wt. to 9.3 19:15 19:30 0.25 14,755 15,081 PROD1 DRILL TRIP P RIH from 14755' to 15081'. 19:30 22:00 2.50 15,081 15,081 PROD1 DRILL CIRC P Circ. & reciprocate @ drlg. rates, weighting up mud system. 4940 units BGG at bottoms u . 22:00 22:30 0.50 15,081 14,755 PROD1 DRILL TRIP P POH on elevators from 15081' to 14755'. Monitor well. 22:30 00:00 1.50 14,755 14,090 PROD1 DRILL TRIP P Attempt to pull on elevators, well swabbing. Pump out @ 2 bpm 500 psi from 14755' to 14090'. Hole taking ri ht amount of fill. 04/09/2008 00:00 01:00 1.00 14,090 12,400 PROD1 DRILL TRIP P Continue pumping out of hole @ 2.5 bpm 740 psi from 14090' to 12400' MD. 01:00 02:00 1.00 12,400 11,565 PROD1 DRILL TRIP P Attempted to poh on elevators from 12400' to 12262', hole swabbing. Pumped out from 12262' to 11565'. Hole still not takin ro r hole fill. Decision made to o back to bottom & - wt. u 02:00 03:15 1.25 11,565 15,081 PROD1 DRILL TRIP P RIH from 11565' to 15081' MD filling i e 13530'. 03:15 13:00 9.75 15,081 14,930 PROD1 DRILL CIRC P Wt. up mud. After 35 mins. pumping had gas units @ 4320. Wt up mud s stem to 9.9 14930'. 13:00 13:15 0.25 14,930 15,081 PROD1 DRILL TRIP P RIH from 14930' to 15081' MD. 13:15 13:45 0.50 15,081 15,081 PROD1 DRILL CIRC P Circ. & reciprocate. Monitor well. Well Static. 13:45 17:30 3.75 15,081 11,283 PROD1 DRILL TRIP P Pump out of hole from 15081' to 11283' MD @ 25 spm 500 psi flow checking well every 10 stands. Hole takin ro er fill. Monitor well-Static. 17:30 17:45 0.25 11,283 10,818 PROD1 DRILL TRIP P Pull 5 stands wet on elevators from 11283' to 10818'. Hole taking proper fill. Monitor well. Well static. 17:45 18:15 0.50 10,818 10,818 PROD1 DRILL CIRC P Pump dry job & blow down top drive. 18:15 00:00 5.75 10,818 331 PROD1 DRILL TRIP P POH on elevators from 10818' to 331'. 04/10/2008 00:00 00:15 0.25 331 0 PROD1 DRILL PULD P Rack back HWDP & non mag flex dc,s. La down motor, MWD & bit. I~a~e27c~f31 i ~ ~ Time Logs Da e From To Dur 5 De th E. De th Ph e Code Subcode T COM 04/10/2008 00:15 00:30 0.25 0 0 PROD1 DRILL OTHR P Clear & clean rig floor. 00:30 01:45 1.25 0 0 PROD1 DRILL PULD P Pick up bit, bais unit, control collar, xo float sub, tested no good. Lay down same. Pick u back u & tested ood. 01:45 02:30 0.75 0 375 PROD1 DRILL PULD P Continue pick up & make up BHA #6 per schlumberger DD (reciever, xo, periscope, impulse MWD, VPWD, 1 stand flex dc,s xo stands of hwdp & 'ars. 02:30 02:45 0.25 375 1,295 PROD1 DRILL TRIP P RIH from 375' to 1295'. 02:45 03:00 0.25 1,295 1,295 PROD1 DRILL DHEQ P Shallow hole test MWD @ 246 gpm 1170 si ood test. 03:00 07:45 4.75 1,295 14,876 PROD1 DRILL TRIP P Continue run in hole from 1295' to 14876' MD filling pipe @ 1305', 3617', 5944', 8268', 10586', 12913', 14799', 07:45 12:00 4.25 14,876 15,081 PROD1 DRILL CIRC P ECD base line then mad pass from 14876' to 15081' MD @ 250 gpm 2500 si 50 m 6k t . 12:00 00:00 12.00 15,081 15,734 PROD1 DRILL DDRL P Drlg. 6 1/8" horizontal hole from 15081' M D to 15738' M D 6906' ND. P!U 163k S/O 98k ROT 125k TQ 9k Max gas 2071 units. ECD 11.47 ppg ART 8.63 hrs. 71 s m 336 m 2600 si. 04/11/2008 00:00 12:00 12.00 15,738 16,410 PROD1 DRILL DDRL P Drlg. 6 1/8" horizontal hole from 15738' MD to 16,410' MD 6907' ND. ADT 9.14 P/U 165k S/O 95k ROT 125k RPM 150 Tq on 12k off 10k ECD 12.03 max as units 3279. 12:00 00:00 12.00 16,410 17,154 PROD1 DRILL DDRL P Drlg. 6 1/8" horizontal hole from 16,410' MD to 17,154' MD ND 6909'. ADT 8.98 P/U 170k S/O 94k ROT 126k TQ on 12k off 10k ECD 11.9 ppg Max gas 3149 units PP 2500 psi 230 m. 04/12/2008 00:00 12:00 12.00 17,154 17,756 PROD1 DRILL DDRL P Drlg. 6 1/8" horizontal hole from 17154' MD to 17756' MD. 6912' ND. ADT 9.45 hrs. P/U 175k S/O 90k ROT 125k RPM 150 TO on 13k off 11k ECD 11.98 Max Gas 3654 units. 63 spm 2850 PP 12:00 00:00 12.00 17,756 18,477 PROD1 DRILL DDRL P PJSM=DrIg. 6 1/8" horizontal hole from 17,756' MD to 18,477'MD ND 6907'. ADT 8.85 hrs. P/U 175k S/O 90k ROT 126k TO on 13k off 11 k ECD 11.99 ppg Max gas 2748 units. 63 spm 2850 PP. (After drlg. fault @ 18050-18060' lost 3-4% return flow ecd dropped to 11.6 ppg fluid loss 80-90 b h add Icm cut losses to 15-20 b h 04/13/2008 00:00 07:00 7.00 18,477 18,806 PROD1 DRILL DDRL P Drlg. 6 1/8" horizontal hole from 18,477' MD to 18,797' MD ND 6908'. ADT 6.23 hrs. P/U 180k S/O 90k ROT 123k TO on 13k off 12k 150 rpm ECD 11.88 Max Gas 2773 units. PacJe 2~ ~sf 31 i • Time Logs Date From To Dur S. D th E. De th Ph e Code Subcode T CAM 04/13/2008 07:00 07:30 0.50 18,806 18,806 PROD1 DRILL CIRC P Stop drlg. per Geologist-Co. Rep & DD. Called TD (a7 18.806' MD, Circ. & reciprocate. Depth is based on Doyon 19 RKB. 07:30 10:15 2.75 18,806 18,806 PROD1 DRILL CIRC P CBU X 2 @ 210 gpm 2500 psi ECD 11.6 ppg P/U 175k S/O 95k ROT 126k. 10:15 10:30 0.25 18,806 18,806 PROD1 DRILL OTHR P Flow check Static. 10:30 12:00 1.50 18,806 17,913 PROD1 DRILL TRIP P BROOH @ 196 gpm 2050 psi 120 rpm 10k t from 18797' to 17913'. 12:00 15:30 3.50 17,913 14,799 PROD1 DRILL TRIP P PJSM-Continue BROOH from 17913' to 14799' MD. 15:30 15:45 0.25 14,799 14,799 PROD1 DRILL OTHR P Flow check Static. 15:45 17:45 2.00 14,799 14,799 PROD1 DRILL CIRC P Pump 35 bbl. hi-vis sweep-circ. & reciprocate around @ 200 gpm 2150 psi ECD 11.4 ppg 120 rpm Sweep returned 10-15% excess Max gas 98 units losses 22 bbl. Flow check static. 17:45 21:45 4.00 14,799 10,954 PROD1 DRILL TRIP P Continue BROOH from 14799' to 10954' MD 190 m 120 r m. 21:45 22:15 0.50 10,954 10,954 PROD1 DRILL OTHR P Flow check static-pump pill & blow down to drive. 22:15 00:00 1.75 10,954 8,728 PROD1 DRILL TRIP P POH to 8728 & drop 2"drift w/ 100' tail. 04/14/2008 00:00 01:00 1.00 8,728 8,728 PROD1 DRILL OTHR P PJSM=Slip & cut 330' Drlg. line. 01:00 03:45 2.75 8,728 375 PROD1 DRILL TRIP P POH from 8728' to 375' MD. 03:45 05:15 1.50 375 0 PROD1 DRILL PULD P Lay down BHA #6. Hole fill calculations 53 bbl. Actual 79 bbl. Losses of 7-8 BPH Static. 05:15 05:45 0.50 0 0 PROD1 DRILL OTHR P Clear & clean rig floor. 05:45 06:15 0.50 0 0 PROD1 CASIN( OTHR P P/U & Rig up csg. tools to run 3.5" slotted & blank liner. 06:15 06:30 0.25 0 0 PROD1 CASIN SFTY P PJSM on liner run. 06:30 09:30 3.00 0 4,100 PROD1 CASIN RUNL P Pick u & run liner er CD4-3016 slotted liner detail. 09:30 10:30 1.00 4,113 4,113 PROD1 CASIN( OTHR P Make up hanger assembly & let acker fluid set u . P/U 54k S/O 51 k. 10:30 12:00 1.50 4,113 5,135 PROD1 CASIN( RUNL P RIH w/ 4" dp from 4113' to 5135' MD breakin circ. 4206. 12:00 17:00 5.00 5,135 14,784 PROD1 CASIN RUNL P PJSM=Continue RIH w/ 3.5" liner on 4" DP from 5135' to 14784' MD fill pipe eve 20 stands P/U 140k S/O 90k. 17:00 18:00 1.00 14,784 14,784 PROD1 CASIN( CIRC P Circ. drill pipe volume @ 4.5 bpm 1080 si 18:00 20:30 2.50 14,784 18,799 PROD1 CASIN RUNL P Continue RIH w/liner fill every 20 stands from 14784' tag bottom & pick up to 18785'. P/U 175k S/O 95k. Drop Ball pick up to 18770' & slack off to 18799' settin de th. .~- 1 P~cJe ~9 of31 C~ • Time Logs _ Date From To Dur S. D th E. De th Ph e Code Subcode T COM 04/14/2008 20:30 21:30 1.00 18,799 18,799 PROD1 CASIN( OTHR P Pump ball on seat @ 4 bpm. pressure up to 1200 2 mins. pressure up 2500 & set hanger. Stack 60k down & pull 10k over to confirm set. Stack 60k down & pressure to 3200 psi & release setting tool. Bleed off & confirm release w/ 160k up weight. S/O to 95k & shear out ball seat @ 4400 psi. Pick up 32' for brine displacement. 3.5" liner top @ MD 14685'. 21:30 22:00 0.50 18,799 18,799 PROD1 CASIN( OTHR P Blown down top drive & rig down schlumberger stand pipe sensors & drawworks de the ui ment. 22:00 00:00 2.00 18,799 18,799 PROD1 CASIN CIRC P Circ. @ 2.5 bpm 650 psi prepare for brine dis lacement. 04/15/2008 00:00 00:15 0.25 18,790 18,790 PROD1 CASIN SFTY P PJSM-Topic=Displacement of drlg. mud to 9.9 brine. 00:15 03:15 3.00 18,790 18,790 PROD1 CASIN( CIRC P Displace well to 9.9 ppg brine @ 2-5 b m 1050 si. 03:15 12:15 9.00 18,790 2,409 PROD1 CASIN( OTHR P Laying down 4" dp from 18790' to 2409' MD. 12:15 14:00 1.75 2,409 0 PROD1 CASIN OTHR P PJSM-Continue laying down 4" dp from 2409' & la down settin tool. 14:00 15:30 1.50 0 0 PROD1 CASINC OTHR P RIH 47 stands 4" dp. 15:30 18:45 3.25 0 0 PROD1 CASINC OTHR P Laying down remainder of 4" dp. 18:45 19:45 1.00 0 0 PROD1 CASIN OTHR P Clear & clean rig floor. Pull wear ring. Monitor well. Losses 10 b h. 19:45 20:15 0.50 0 0 PROD1 RPCO RURD P Rig up to run 3.5" completion. 20:15 20:30 0.25 0 0 PROD1 RPCOh SFTY P PJSM-Topic=Running completion. 20:30 00:15 3.75 0 2,862 PROD1 RPCO RCST P Running 3.5" 9.3# L-80 EUE 8rd tbg. Ran 89 'ts. 04/16/2008 00:00 07:00 7.00 2,862 12,472 PROD1 RPCO RCST P PJSM. Continue RIH with 3-1 /2" completion equipment from 2862' to 12,472'. Total of 395 'ts. 07:00 09:30 2.50 12,472 12,472 PROD1 RPCO WOEQ NP Wait on Cameo rep to arrive on location with control line and spooler. Rep was held up due weather and Brooks Ran a cam move. 09:30 10:45 1.25 12,472 12,472 PROD1 RPCOh RURD P RU Cameo equipment. Attach control line to SSSV and test to 5800 si. 10:45 12:00 1.25 12,472 12,800 PROD1 RPCO RCST P Continue RIH with 3-1/2" completion e ui ment Total 409 'ts. 12:00 14:45 2.75 12,800 14,691 PROD1 RPCO RCST P PJSM=Continue run in hole w/ 3.5" tb . w/ control line Total 461 'ts. 14:45 16:15 1.50 14,691 14,691 PROD1 RPCOb HOSO P Make up xo,s &RIH 2 stands 4" dp & tag TOL. Space out & set back stands. Pick up 4 1/2" 12.6# IBTM tbg. pups & 2 jts 4 1/2" tbg. Make up hanger & landing jt.. total 75 ss bands. - - ~ C~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 04/16/2008 16:15 17:00 0.75 14,691 14,691 PROD1 RPCO HOSO P Bleed off close sssv. Cut & connect control line to hanger & test connection to 5000 psi. Land tbg. 35k on hanger Locator @ 14691' MD. Monitor well Pit #5 on gravity feed brine on annulus. 17:00 18:00 1.00 14,691 14,691 PROD1 RPCO DHEO P RILDS Back out landing jt. Install 2 wa check. Make up landing jt. Rig up test pump & test hanger seals w/ 5k psi 5 mins. rig down & lay down landin 't. 18:00 18:15 0.25 14,691 14,691 PROD1 RPCOh SFTY P PJSM-Topic=Nipple down BOPE & ni le u tree. 18:15 21:15 3.00 14,691 14,691 PROD1 RPCOh NUND P Nipple down kill & choke lines-valves-bo -dsa- & ada ter s ool. 21:15 23:00 1.75 14,691 14,691 PROD1 RPCO NUND P Nipple up tree-test adapter flange void w/ 5k psi 10 mins. fill tree w/diesel & test tree w/ 5k psi 10 mins. pull 2 way check. 23:00 00:00 1.00 14,691 14,691 PROD1 RPCOh RURD P Rig up circ. lines to pump corrosion inhibited brine. 04/17/2008 00:00 00:30 0.50 14,691 14,691 PROD1 RPCO RURD P Finish RU circulating equipment. 00:30 00:45 0.25 14,691 14,691 PROD1 RPCO SFTY P PJSM on displacing well with treated brine and diesel. 00:45 03:00 2.25 14,691 14,691 PROD1 RPCOh CIRC P Pump 325 bbls treated 9.9 ppg brine at 3 b m - 500 si. 03:00 05:00 2.00 14,691 14,691 PROD1 RPCOb CIRC P Little Red Hot Oil pumped 170 bbls diesel at 3 b mat 1900 si. 05:00 05:30 0.50 14,691 14,691 PROD1 RPCO RURD P RU lubricator. Drop ball and rod. RD lubricator. RU tree ca um in sub. 05:30 06:45 1.25 14,691 14,691 PROD1 RPCO DHEQ P Pressure tbg to 4900 psi to set pkr. Held pressure for 30 min for tbg test. OK. Bled tb ressure to 2500 si. 06:45 07:30 0.75 14,691 14,691 PROD1 RPCOb DHEQ P RU to annulus. Pressure annulus to 3500 si for 30 min. OK 07:30 08:00 0.50 14,691 14,691 PROD1 RPCOh OTHR P RU Hot Oil to tbg. Bled tbg to 2000 psi. DCK-2 valve sheared. Bled tbg to 900 si with annulus to 0 si. 08:00 09:00 1.00 14,691 14,691 PROD1 RPCOh OTHR P RU lubricator. Install BPV. RD lubricator. 09:00 09:15 0.25 PROD1 RPCO OTHR P Remove secondary annulus valve. Install au es. Secure well. 09:15 10:00 0.75 PROD1 RPCOh PULD P LD 3 stds 4" DP in mousehole. LD mouse hole. 10:00 12:00 2.00 PROD1 RPCOM1 OTHR P Lay down slips, elevators & subs from ri floor. 12:00 00:00 12.00 PROD1 RPCO OTHR P PJSM. Cleaning mud tanks, drain ans & ri . 04/18/2008 00:00 12:00 12.00 PROD1 MOVE RURD P Clean mud tanks-clean wind walls. Clean i e skate. 12:00 00:00 12.00 PROD1 MOVE RURD P PJSM= clean mud tanks & rig. Pre are mud um s for stack out. P~g~ ~1 at 31 05/22/08 ~i~~~~~l~i~~r Schlumberger-DCS 2525 Gambeil Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth c~U~- Irv ~ l(c,~~" N0.4721 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Prints CD CD4-3018 40016897 OH MWD EDIT 04/13/08 2 1 SIGNED:. DATE: , ~ ~~ , ' Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Conan. April 7, 2008 Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-301B AK-MW-5355766 CD4-301B: 2" x 5" MD TC Logs: 50-103-20557-02 1 Color Logs Digital Log Images: 50-103-20557-00,01,02 1 CD Rom This log was not in the first distribution. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 - ~, "~ _. ~ ~~~ Date: '` `° ~ ~;, ~~. ~ ~ ~~ ~o~--lib ;i Signed: V ~-ll~/~2 ~v`~--1 ~ c~ # ~ ~ l~_3 ~o~--r~so ~ ~~~~~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-301+A+B • March 28, 2008 AK-MW-5355766 CD4-301+A+B: 2" x 5" MD TC Logs: 1 Color Logs 50-103-20557-00,01 2" x 5" TVD TC Logs: 1 Color Logs 50-103-20557-00,01,02 Digital Log Images: 1 CD Rom 50-103-20557-00,01,02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: M Signed: ,M - 'L~ ~ 6 ~~ ~b~-~5 v l~ ~~~_` ~a ~t~o~~ Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 09, 2008 4:03 PM To: 'Galiunas, Elizabeth C' Cc: Chambers, Mark A; Alvord, Chip Subject: RE: CD4-301 B sin Kuparuk C sand Thanks Liz. Keep me or have the rig keep the Inspectors advised. Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conomphillips.com] Sent: Wednesday, April 09, 2008 3:13 PM To: Maunder, Thomas E (DOA) Cc: Chambers, Mark A; Alvord, Chip Subject: CD4-3018 Gas in Kuparuk C sand Tom, I wanted to follow up with an email on my voice mail to you. Here is a summary of Doyon 141's operations over the passed day on CD4-301 B. 1. Reach point in Kuparuk C sand with motor to POOH to PU a rotary steerable assembly at TD of 15099' MD (250' from casing shoe at 14864' MD) -of the 250' drilled out of the casing shoe only 100' is actually in the Kuparuk C sand. 2. Doyon 141 pumped out from TD to the casing shoe and monitored well. There was slight flow and 4900 units of gas was measured. 3. The decision was made to go back to bottom and increase the mud weight from 9.2 ppg to 9/3+/9.4 ppg. While CBU, 4200 units of gas was measured 4. The decision was made to bump up the MW to 9.7ppg. After CBU with 9.7 ppg, 400 units of gas was measured. 5. The well currently has a MW of 9.9 ppg and a flow check is being performed. Looks so far like 9.9 ppg will hold back the gas. The well has not been shut in. Plan is still to POOH and PU a RSS assembly to drill the lateral. The length may be greatly shortened if a fault is crossed and losses are a problem. I will keep you posted. Regards, Liz Galiunas Drilling Engineer Alpine ~rilling Team ConocoPhillips Alaska ATO--1704 4/9/2008 . • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Saturday, April 05, 2008 3:31 PM To: Galiunas, Elizabeth C; Doyon 141 Company Man; Chambers, Mark A; Aivord, Chip Cc: Anderson, Nina M .Subject: RE: CD4-301 B BOPE testing ~~ ~ `~~ Liz, Sorry I missed responding. What you propose is acceptable. 1 believe we approved the same on another well. Key is verifying the casing integrity. Call or message with any questions. Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophiliips.com] Sent: Tue 4/1/2008 11:36 AM To: Maunder, Thomas E (DOA); Doyon 141 Company Man; Chambers, Mark A; Aivord, Chip Cc: Anderson, Nina M Subject: CD4-3016 BOPE testing Tom, Doyon 141 is planning to move onto CD4-301 B at the end of this week to finish off the intern! (sundry #: 308-092 and permit to drill # 207-180). The cement job on this well had full returns throughout job (1/8/2008). The plug was bumped with 1500 psi and the floats held. The casing was tested on 1/10/2008 to 3500 psi for 30 min. The plan is as follows: 1.1.1. Move on Doyon 141. Confirm that a BPV has been installed. 1.1.2. Rig up over CD4-301B, check cellar, dewater as required. 1.1.3. Pull BPV. Pressure test casing to 3500 psi / 30 minutes & record on chart. If the test does not pass, then aroceed with a standard test of the BOPE to 3500 psi. Circulate out inhibited brine and diesel with 9.2 ppg brine through kill string, taking diesel returns to an open top tank. 1.1.4. Once freeze protect is circulated out with 9.2 ppg brine, install two way check. 1.1.5. ND Tree. NU BOPE. Test body and flange break to 250/3500 psi. 1.1.6. Pull two way check. 1.1.7. Make up un-fluted landing joint to tubing hanger. 1.1.8. Pull Tbg Hanger, 91 jts 3-1/2" tbg, and WLEG. Lay down tubing, etc. Visually inspect the jts of 3-1/2" tubing as it will be re-run for the upper completion string. 1.1.9. Set test plug and perform full BOPE test to 3500 psi (Notify State 24 hrs in advance). We wanted to get approval to follow the proposed procedure and test BOPEs after the kill 4/7/2008 Page 2 of 2 string is laid down, contingent on a good casing test once the BPV is removed with Doyon 141 on the well. Liz Galiunas Drilling Engineer Alpine Drilling Team ConocoPhillips Alaska ATOr1704 Office: (907)~2G5~G247 Cell: (907)~441r4871 4/7/2008 ConocoPhillips March 24, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for CD4-301 B Dear Commissioner: G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 ~~~~' Y MAR 2 5 20Q8 Alaska Oit 8 Gas ~, Commission Arn''horage ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent drilling operations on the Alpine well CD4-301 B. We are intending to re-enter this well at a future date to complete it. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, !~ ~~ .~`~ ~_ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad ~b~-c~ ~ STATE OF ALASKA ~ ~'i~K ;~ J 2O0$ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS~aska Gib ?~ Gds Cc~f~s. Comtl~gipl 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other 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 ^ 207-180 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20557-02 ` 7. KB Elevation (ft): 9. Well Name and Number: MSL 56', 36' RKB CD4-301 B 8. Property Designation: 10. Field/Pool(s): ADL 380077, 384211, 372097, 380082 Colville River Field, Nanuq Kuparuk Oil Pool • 11. Present Well Condition Summary: Total Depth measured 14860' feet true vertical 6911' feet Plugs (measured) Effective Depth measured 2845' feet Junk (measured) true vertical 2315' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 114' 114' Surface 2999' 9-5/8" 3035' 2387' Intermediate 14819' 7" 14855' 6911' Perforation depth: Measured depth: none true vertical depth: none p~'~ ~ ~ ~~ Tubing (size, grade, and measured depth) 3.5" kill string, 9.3#, 2845' MD. ~-S `.-J'~~~` ~`~~-~ w + a ~ ~~~~~ \~~ ~ ` Packers &SSSV (type & measured depth) no packer ('\ ~( \ P~;~.~I. ~ . ~~ ~ O~ ~V L no SSSV \ `~ V~ .~. 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbt Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation na Subsequent to operation na 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oi10 ~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Nina Anderson @ 265-64031 Printed Name C. Alvord Tit-e Alpine Drilling Lead Engineer Signature ~ ~~ Phone Date ?~~,,~.. ~ ~ ~~ - ~ r ~ - - Pre a b h ron llsu rak 263-4612 %~~ Form 10-404 Revised 04/2004 ! 1 K I ~ I 1 v H ~ ~ ~~, ~~~ ~ ~ ~ (D~ Submit Original Only \.J t ~ 111 ~,, ~?~ ' j . Z~..' c' Naming of CD4-301, 301A, and 301 B Rig accept 12-8-07 KOP 2: 9600' KOP 1: 10000' CD4-301 Permit #: 207-150 API: 50-103-20557-00 12-18-07 TD 15883' MD / 6913' TVD Updated 1/31/08 LCG TD of 14,860' MD / 6911' TVD 12/23/07-12/28/08 1 /1 /08-1 /5/08 CD4-301A -Lost BHA CD4-301 B -Suspended at Intrm Casing 15431' MD / 6920' TVD Permit #: 207-180 Permit #: 207-174 API : -02 API: -01 ~~yy ConocoPhillips Time Log Summary Welfr7ew Web Reportfng Well Name: CD4-301 Job Type: DRILLING ORIGINAL Time Lo s ----g - Date From To Dur S. De th E. De th Phase Code Subcode T COM _ 12/08/2007 14:00 15:00 1.00 MIRU MOVE DMOB P Blow down steam & water lines -prep to move ri 15:00 21:30 6.50 MIRU MOVE MOB P PJSM w/ crew on moving rig -Skid ~i~, w y ~ ~0~ `~ ^~v r~~,j ~ ~ ® floor to move position -Move pipe shed & motor/pit complexes -Move rig to CD4-301 -center rig over hole - Skid floor to drilling position -move in i e shed & motor/ it com lexes 21:30 22:30 1.00 MIRU MOVE RURD P Hook up service lines -switch to high line power Acce t ri 2230 hrs 22:30 00:00 1.50 SURFA DRILL RURD P Install surface riser 12/09/2007 00:00 01:00 1.00 SURFA DRILL RURD P Continue with surface riser installion - MU drain lines - set in mouse hole - Take on s un mud 01:00 01:30 0.50 SURFA DRILL OTHR P Move 14 stds. 4" Dp f/ ODS to DS 01:30 05:00 3.50 SURFA DRILL PULD P PU & Std back 8 std HWDP & 15 stds 5" DP 05:00 05:30 0.50 SURFA DRILL PULD P Bring BHA componets to rig floor subs, XO's & stabs 05:30 07:30 2.00 SURFA DRILL PULD P Continue picking up & std back 5" DP 28 stds total & 8" NMDC's & Jars 07:30 09:30 2.00 0 73 SURFA DRILL PULD P MU BHA #1 -bit -motor -float sub - Stab - XO -MWD - UBHO -Orient MWD to motor 09:30 10:00 0.50 73 73 SURFA DRILL SFTY P Held pre-spud & safety meeting w/ crew while down loadin MWD 10:00 10:15 0.25 73 73 SURFA DRILL OTHR P Fill hole & check for leaks -Pressure test surface lines to 3000 si 10:15 10:45 0.50 73 114 SURFA DRILL PULD P MU NM flex DC's & jars -Establish circ -wash down to btm 114' 10:45 12:00 1.25 114 170 SURFA DRILL DDRL P Spud - in @ 10:45 hrs. Drill 12 1/4" hole w/ motor f/ 114' to 170' MD 170' ND ADT .32 hrs WOB - 10/15 RPM 40 GPM 450 @ 670 psi String wt. PU 95 SO 90 Rot 95 Tor ue on/off btm.- 4000/3000 ft/Ibs Page 1 csf 23 ~~ Time Logs _ _ _ Date From To Dur S De th E. De th Phase Code Subco e T COM 12/09/2007 12:00 00:00 12.00 170 _ 1,271 SURFA DRILL _ DDRL P Drill 12 1/4" hole w/ motor f/ 170' to 1271' MD, 1249 TVD. ADT 7.48, ART 4.99, AST 2.49. WOB 20/30 k, RPM 60, GPM 500 @ 1300 PSI PW 124 ,SOW 124 ,Rot 124 Tor ue on/off btm. 7500/4500 fUlbs 12/10/2007 00:00 12:00 12.00 1,271 2,333 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/ 1271' to 2333' MD 2077' TVD ADT - 8.67 hrs =ART - 5.58 hrs AST- 3.09 hrs. WOB 25/35 k RPM 60 GPM 625 @ 2000 psi String wt. PU 128 SO 122 Rot 126 Tor ue on/off btm,. - 8500/6500 ft/Ibs 12:00 00:00 12.00 2,333 2,960 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f! 2333' to 2960' MD 2358 TVD ADT - 10.10 hrs =ART- 6.56 hrs AST - 3.45 hrs. WOB 20/30K RPM 60, GPM 625 @2050 psi String wt PU 130, SO 123, Rot 130 Tot ue on/off btm 8500/6500 Wlbs 12/11/2007 00:00 01:00 1.00 2,960 3,046 SURFA DRILL DDRL P Drill 12 1/4" hole w/motor f/ 2960' to 3046' MD 2391 TVD ADT - 0.87 hrs =ART- 0.72 hrs AST - 0.15 hrs. WOB 25/35K RPM 60, GPM 625 @2120 psi String wt PU 130, SO 123, Rot 130 Tot ue onloff btm 9500/6500 ft/Ibs 01:00 01:45 0.75 3,046 3,046 SURFA DRILL CIRC P Circulate hole clean - 625 gpm ! 1835 si/60r m 01:45 05:30 3.75 3,046 890 SURFA DRILL TRIP P Perform wiper trip from 3,046' to 890' - 550gpm / 1500 psi / 60 rpm -reduced rate to 450 gpm from 1,557' - no roblems -flow check well, static 05:30 06:30 1.00 890 2,989 SURFA DRILL TRIP P RIH from 890' to 2,989' 06:30 07:30 1.00 2,989 3,046 SURFA DRILL CIRC P Precautionary wash and ream from 2,989' to 3,046' -Circulate hole clean - 600gpm / 1760 psi / 60 rpm -mud wt. in & out @ 10.0 ppg -flow check well, static 07:30 09:45 2.25 3,046 890 SURFA DRILL TRIP P POOH on tt from 3,046' to 890' -hole appears in good condition -flow check well, static 09:45 12:00 2.25 890 68 SURFA DRILL TRIP P POOH -stand back hwdp - LD jars and NMDC's& UBHO sub 12:00 13:15 1.25 68 0 SURFA DRILL PULD P LD BHA components -clear tools from floor -clean ri floor 13:15 14:45 1.50 0 0 SURFA CASIN RURD P RU to run 9 5/8" casing 14:45 15:00 0.25 0 0 SURFA CASIN SFTY P Held Pre-job Safety and Opts meeting with crew 1'ac~~ 2 of 23 Time Logs ___ ~ __ _ ~ _ Date From To Dur S. De th E. De th Ph e Code Subcode T COM 12/11/2007 15:00 18:30 3.50 0 1,726 SURFA CASIN( RNCS P Ran 9 5/8" 40# L-80 MBTC csg as follows: FS(Ray Oil Tool Ssilver bullet) 2 jts csg - FC( Halliburton Super seal) 2 jts csg - 4 jts total (made up w/ BakerLoc -fill pipe & check floats OK) Ran 41 jts 9 5/8" 40# L-80 MBTC csg 45 ~ts total to 1726' 18:30 19:00 0.50 1,726 1,726 SURFA CASIN CIRC P Break circ - Circ pipe volume -ICP 350 psi @ 3.5 bbls/min - FCP 200 si 4.5 bbls/min 19:00 20:45 1.75 1,726 3,035 SURFA CASIN RNCS P Continue running 9 5/8" 40# L-80 MBTC csg 33 jts f/ 1726' to 2996' (78 total jts ran) - PU hanger & {anding jt. - Land csg w/ FMC fluted hanger on landing ring w/ FS @ 3035' - FC @ 2955' 20:45 21:00 0.25 3,035 3,035 SURFA CASIN( OTHR P RD csg equipment & fill-up tool - MU cmt head & lines 21:00 22:30 1.50 3,035 3,035 SURFA CEME~ CIRC P Break circ -Stage pump up to 6.5 bbls/min -ICP - 210 psi @ 1 bbl/min - FCP - 260 si 6.5 bbls/min 22:30 22:45 0.25 3,035 3,035 SURFA CEME SFTY P PJSM w! crew on cementing 22:45 00:00 1.25 3,035 3,035 SURFA CEME~ DISP P Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/nut plug for marker w/ rig pump -Pumped 3 bbls water w/ Dowell -Pressure test lines to 4000 psi -Dropped btm plug - Mixed & pumped 50 bbls - 10.5 ppg MudPush @ 5.6 BPM @ 445 psi - Mixed & pump Lead slurry (ArcticSet Lite 3) 10.7 ppg @ 7.5 BPM @ 700 si Pum ed 165 bbls 3,035 SURFA CEME~ 12/12/2007 00:00 00:45 0.75 3,035 3,035 SURFA CEME~ DISP P Continue pumping lead slurry (ASL) 139 bbls @ 10.7 ppg 7.3 bbls/min @ 680 psi (304 bbls total pumped) observed nut plug marker @ shakers- pumped down surge can Pumped 321 bbls total bbls of lead slurry - Switched over to tail slurry Pumped 54 bbls tail slurry (Class G w/ .2% DO46 + 1 °lo S2 + .2% D46 = .35 D65) @ 15.8 ppg@4.56PM@577psi- Dropped top plug w/ 20 bbls water - Switched to rig pump & displaced w/ 204 bbls 9.8 ppg mud @ 7 BPM @ 438 to 620 psi -Slowed pump to 3.5 BPM for last 24 bbls @ 450 psi to 610 psi Bumped plug t/ 1000 psi - Checked floats OK - CIP @ 0045 hrs. - Recipocated pipe during job -full returns throughout - 125 bbls 10.7 ppg cmt returns to surface Page 3 of F~ l J C~ Time Logs _ Date From To Dur S. Depth E. De th Pha e Code Subcode T COM 12/13/2007 10:30 12:00 1.50 2,845 2,845 SURFA RIGMN SVRG P Slip and Cut drilling line -Service top drive, drawworks and crown -adjust brakes on drawworks 12:00 12:30 0.50 2,845 2,955 SURFA DRILL CIRC P Wash down f/ 2845' to 2953' -Tag up on wiper plugs - 650 gpm @ 2100 psi w/ 60 r m 12:30 18:15 5.75 2,955 3,066 SURFA CEMEI~ COCF P Drill wiper plugs -Clean out shoe tract FC @ 2955' to 2957' - cmt to 3033' - FS @ 3033' to 3035' -Clean out rat hole to 3046' Drill 20' new hole to 3066' MD 2395' TVD WOB 8/12 RPM 90 GPM 550 @ 1550 psi ADT - .35 hrs. 18:15 18:45 0.50 3,066 3,066 SURFA CEME CIRC P Circ hole clean for FIT 550 gpm @ 1530 psi w/ 90 rpm Flow ck -static 18:45 19:30 0.75 3,066 3,066 SURFA CEME~ LOT P PU & attempt to perform FIT to 18.0 ppg EMW -formation went to leak-off @ 720 psi - 15.4 ppg EWM -LOT - RD 19:30 21:00 1.50 3,066 3,066 INTRM1 DRILL CIRC P Change well over f/ 9,6 ppg spud mud to 9.6 ppg LSND 550 gpm @ 1050 psi w/ 90 rpm Flow ck -static 21:00 00:00 3.00 3,066 3,320 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 3066' to 3320' MD 2498' TVD ADT:2.65 WOB: 8/12 RPM: 120 GPM:625 @ 1450 PSI PUW: 140K, SO: 110K Tor ue on/off: 9500/8500 ft/Ibs 12/14!2007 00:00 12:00 12.00 3,320 4,712 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 3320' to 4712' MD 3015' TVD ADT:8.79 ECD - 11.21 ppg WOB: 15/20 RPM: 120 GPM:650 @ 2180 PSI PUW: 140K, SO: 120K RotWt: 130K Tor ue on/off: 9000/7000 ft/Ibs 12:00 21:00 9.00 4,712 5,648 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 4712' to 5648' MD 3348' TVD ADT:5.96 WOB: 15/20 RPM: 155 GPM:650 @ 2200 PSI PUW: 140K, SO: 120K RotWt: 140K Tor ue on/off: 9000/7000 ft/Ibs 21:00 21:30 0.50 5,648 5,648 INTRM1 DRILL CIRC T Circulate bottoms up due to ECD of 11.68 to 12.1 -brought ECD down to 11.1 Page 5 crt 23 Time Logs Date From To Dur S De th E. De th PhBSe Code Subcode T COM 12/14/2007 21:30 00:00 2.50 5,648 5,896 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 5648' to 5896' MD 3434' TVD ADT:1.45 hrs. ECD - 11.16 ppg WOB: 15/20 RPM: 155 GPM:650 @ 2200 PSI PUW: 140K, SO: 120K RotWt: 140K Tor ue on/off: 10000/9000 ft/Ibs 12/15/2007 00:00 12:00 12.00 5,896 7,230 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 5896' to 7230' MD 3926' TVD ADT: 8.31 hrs. ECD - 11.16 ppg WOB: 18/25 RPM: 120/160 GPM:650 @ 2580 PSI PUW: 168K, SO: 130K RotWt: 147K Torque on/off: 11500/11000 fUlbs ECD: 11.27 12:00 21:15 9.25 7,230 8,365 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 7230' to 8365' MD 4332' TVD ADT: 5.19 hrs. ECD - 10.84 ppg WOB: 18/25 RPM: 120/160 GPM:650 @ 2260 PSI PUW: 200K, SO: 135K RotWt: 160K Tor ue on/off: 14500/14000 ft/fbs 21:15 21:45 0.50 8,365 8,365 INTRM1 RIGMN SVRG P Service rig 21:45 00:00 2.25 8,365 8,811 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 8365' to 8811' MD 4490' TVD ADT: 2..15 hrs. ECD - 10.84 ppg WOB: 18/25 RPM: 120/160 GPM:650 @ 2580 PSI PUW: 200K, SO: 135K RotWt: 160K Tor ue on/off: 14500/14000 fUlbs 12/16/2007 00:00 12:00 12.00 8,811 10,476 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f! 8811' to 10,476' MD 5,094' TVD ADT: 8.19 hrs. ECD - 10.8 ppg WOB: 20/25 RPM: 160/170 GPM:650 @ 2230 PSI PUW: 198K, SO: 145K RotWt: 170K Tor ue on/off: 15500/14500 ft/Ibs 12:00 00:00 12.00 10,476 12,130 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f! 10,476' to 12130' MD 5702' TVD ADT: 7.91 hrs. ECD - 11.01 ppg WO B: 25 RPM: 160/170 GPM:650 @ 2300 PSI PUW: 215K, SO: 145K RotWt: 178K Tor ue on/off: 16500/15500 ft/Ibs Pac~a; 6 csf 23 • Time Logs Date From To Dur S. Depth E. D~th Phase Code Subcode _ T COM 12/17/2007 00:00 12:00 12.00 12,130 13,605 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 12,130' to 13,605' MD 6313' TVD ADT: 8.02 hrs. ECD - 11.98 ppg WOB: 28/30 RPM: 170 GPM:650 @ 2550 PSI PUW: 265K, SO: 145K RotWt: 190K Tor ue on/off: 21500/20000 ft/Ibs 12:00 00:00 12.00 13,605 14,760 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 13,605' to14760' MD, 6745' TVD ADT: 8.18 hrs. ECD - 11.21 ppg WOB: 20/25 RPM: 160 GPM:625 @ 2800 PSI PUW: 250K, SO: 155K RotWt: 192K Tor ue on/off: 20500/19500 ft/Ibs 12/18/2007 00:00 11:15 11.25 14,760 15,883 INTRM1 DRILL DDRL P Drill 8 3/4" hole w! GP f/ 14,760' to15,883' MD, 6910' TVD ADT: 7.59 hrs. ECD - 11.31 ppg WOB: 28/32 RPM: 160 GPM:650 @ 3060 PSI PUW: 265K, SO: 145K RotWt: 195K Tor ue on/off: 20,000/19,000 ft/Ibs 11:15 14:45 3.50 15,883 15,502 INTRM1 DRILL CIRC P Circulate and condition mud - 650 gpm / 2950 psi / 150 rpm -increased mud wt. from 9.8 ppg to 10.0 ppg -stood back four stands to 15,502' -slight flow on connections -well static in 10 minutes. 14:45 17:30 2.75 15,502 13,979 INTRM1 DRILL TRIP P POOH with pump from 15,502' to 13,979'. 625 GPM 120 RPM. 17:30 22:45 5.25 13,979 8,174 INTRM1 DRILL TRIP P POOH on trip tank from 13,979' to 8,174'. Hole ti ht. 50 K over ull. 22:45 00:00 1.25 8,174 7,698 INTRM1 DRILL TRIP P POOH with pump from 8,174' to 7,698'. 550 GPM 120 RPM. 12/19/2007 00:00 01:30 1.50 7,698 6,937 INTRMI DRILL TRIP P POOH with pump from 7,698' to 7,603' - 3 bpm / 450 psi -POOH on TT from 7603' to 7508' wiped through tight spots -POOH with pumps from 7,508' to 6,937' - 550 gpm / 1750 psi / 100 rpm -Blow down top drive -flow check well, static 01:30 06:00 4.50 6,937 3,036 INTRM1 DRILL TRIP P POOH on TT from 6,937' to 3,036 - worked through tight spot at 5220' - flow check well, static 06:00 07:45 1.75 3,036 2,465 INTRM1 DRILL TRIP P POOH from 3,036'- swabbing well - Pump out from 3036' to 2,465'- 650 gpm / 1100 psi / 120 rpm -monitor well - sli ht flow static in 8 minutes 07:45 10:15 2.50 2,465 743 INTRMI DRILL TRIP P POOH on TT from 2,465' to 743' -hole taking proper fill -flow check well, static 10:15 12:00 1.75 743 103 INTRM1 DRILL TRIP P POOH from 743' to 103' -Stand back hwdp -recover corrosion ring - PJSM on nukes -Stand back nmfc's - remove source from nuke tool ?~~e7of2a Time Logs Date_ _ From To Dur S De th E. De th Ph se Code Subco e T COM 12/19/2007 12:00 14:45 2.75 103 0 INTRM1 DRILL PULD P PU to GeoPilot -down load tools - service GeoPilpot - LD fs -nuke collar - bit - EWR RLL -stab - PWD - DM and GeoPilot -Clear tools from rig floor 14:45 17:15 2.50 0 936 INTRM1 CEME TRIP P PJSM - RU to run tubing - MU mule shoe and pick up 30 joints of 3 1/2" tubin w/ XO's to 4 1/2" IF 17:15 20:00 2.75 936 7,117 INTRM1 CEME TRIP P RIH from 936' to 7,117'. 20:00 21:00 1.00 7,117 7,117 INTRM1 CEME CIRC P Circulated to clear tubing. Thawed Grabber on To Drive. 21:00 23:15 2.25 7,117 10,923 INTRM1 CEME TRIP P RIH from 7,117' to 10,923'. 23:15 00:00 0.75 10,923 10,993 INTRM1 CEME CIRC P Broke circulation and thawed Top Drive. Tem -42. 12/20/2007 00:00 01:45 1.75 10,993 14,065 INTRM1 CEME TRIP P RIH from 10,993' to 14,065' PUW 230K SOW 150K 01:45 02:15 0.50 14,065 14,065 INTRMI RIGMN OTHR T Service top drive grabs -weather related problem -42 degrees ambient tem 02:15 04:00 1.75 14,065 14,065 INTRM1 CEME CIRC P Circulate and condition mud for cementing 500 gpm / 1950 psi -PUW 235K SOW 145K - FCP=1840 psi - mud wt. 10.2 04:00 04:30 0.50 14,065 14,065 INTRM1 CEME CIRC P Pum 35 bbls hi h el ill -displace to equalization - 14 bpm / 2350 psi - Blow down lines -Flow check well, Static. 04:30 05:00 0.50 14,065 13,715 INTRMI CEME TRIP P POOH to 13 715' - RU cement lines 05:00 06:00 1.00 13,715 13,715 INTRMI CEME PLUG P PJSM -establish circulation with Dowell pump -test lines to 3000 psi - lu ed back 8 3/4" o en hole from 13 715' with 238 sxs of 15. G - cement 15% excess 1.21 cf/sx Id - displaced toe ualization - CIP 0600 hrs - ETO 11 ' 06:00 07:00 1.00 13,715 12,732 INTRM1 CEME TRIP P RD cement lines -POOH to 12,732' PUW 225K SOW 145 -flow check well, static 07:00 07:15 0.25 12,732 12,732 INTRM1 CEME CIRC P RU circ head and line -Circulated 80 bbls of mud to clear tubing -10 bpm /1310 si - RD & blow down lines 07:15 08:45 1.50 12,732 10,734 INTRM1 CEME TRIP P POOH from 12,732' to 10,734' PUW 190K SOW 135K 08:45 09:15 0.50 10,734 10,734 INTRM1 CEME CIRC P RU and establish circulation -Pumped 35 bbls hi h el ill -displaced to equalization - 12 bpm / 1650 psi - RD & blow down lines 09:15 09:30 0.25 10,734 10,417 INTRMI CEME TRIP P OOH from 10,734' to 10,417' 09:30 10:30 1.00 10,417 10,417 INTRM1 CEME PLUG P With tubing tail @ 10,417': plugged back 8 3/4" o en hole with 293 sxs of G cement 1 cf/sx yld -displaced to equalization with 10.2 ppg mud - 1025 hrs. ETOC 9817' PasJ~ 8 of 23 `~ ~ n Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T COM 12/20/2007 10:30 11:30 1.00 10,417 9,815 INTRM1 CEME TRIP P RD lines -POOH from 10,417' to 9815' - RU circulatin head in and hose 11:30 13:15 1.75 9,815 9,815 INTRM1 CEME CIRC P Circulate and condition mud - 12 bpm ! 1600 psi -observed water ahead of plug back to shakers -dumped 125 bbls of high PH mud -flow check well, static 13:15 18:45 5.50 9,815 3,025 INTRM1 CEME TRIP P POOH from 9,815' to 3,025' on TT. Held Safe Stand down with crew. 18:45 20:30 1.75 3,025 3,025 INTRM1 RIGMN' SVRG P Installed bell guide on topdrive. Sli ed and cut drillin line. 20:30 21:00 0.50 3,025 3,025 INTRM1 DRILL SFTY P Stopped work and had Safety Stand Down with Ni ht Crews. 21:00 22:15 1.25 3,025 937 INTRMI CEME TRIP P POOH from 3,025' to 937' on TT. 22:15 00:00 1.75 937 400 INTRM1 CEME PULD P Rigged up and POOH 3.5" cement strin la in down to 400'. 12/21/2007 00:00 01:15 1.25 400 0 INTRMI CEME PULD P Laid down 3.5" tubing. 01:15 02:30 1.25 0 90 INTRM1 DRILL PULD P Picked up and made ug Drilling BHA. Could not u load Nuke tool. 02:30 05:30 3.00 90 0 INTRM2 DRILL PULD T Trouble shoot nuke tool. Pumped through tool while warming up with steam. -46 Tem . 05:30 07:30 2.00 0 735 INTRM2 DRILL PULD P Uploaded tools and loaded nukes. RIH W BHA. 07:30 08:30 1.00 735 1,901 INTRM2 DRILL TRIP P RIH to 1,901' and tested tools OK. 08:30 13:30 5.00 1,901 9,415 INTRM2 DRILL TRIP P RIH from 1,901' to 9,415' filling every 20 stands. 13:30 14:45 1.25 9,415 9,842 INTRM2 DRILL REAM P Washed and reamed from 9,415' to TOC 9,842'. 14:45 15:30 0.75 9,842 9,912 INTRM2 DRILL KOST P Dressed cement to 9,912' and Kicked off well. KOP 9,912'. 15:30 00:00 8.50 9,912 10,841 INTRM2 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 9,912' to10,841' MD, 5292' TVD ADT: 5.1 hrs. ECD - 10.84 ppg WOB: 25/28 RPM: 170 `~~ n .~j- ~ ~~ GPM:650 @ 2380 PSI PUW: 230 K, SO: 140 K RotWt: 175 '~(~ ~~~ ~~ h S 1'" ~ ~ K Tor ue on/off: 17,500/16,500 ft/Ibs 12/22/2007 00:00 12:00 12.00 10,841 12,093 INTRM2 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 10,841' to 12,093' MD, 5892' ND ADT: 7.41 hrs. ECD - 10.76 ppg WOB: 25/28 RPM: 160 GPM:650 @ 2430 PSI PUW: 264 K, SO: 149 K RotWt: 186 K Tor ue on/off: 20,000/19,000 ft/Ibs Pays 9 ~# 2u ' ...,:Time Logs Date From To Dur S De th E. Depth Ph se Code Subcode T COM 12/22/2007 12:00 00:00 12.00 12,093 13,515 INTRM2 DRILL DDRL P Drill 8 314" hole w/ GP fl 12,093' to 13,515' MD, 6,462' TVD ADT: 7.79 hrs. ECD - 10.82 ppg WOB: 25!28 RPM: 160 GPM:650 @ 2640 PSI PUW: 265 K, SO: 150 K RotWt: 195 K Tor ue on/off: 21,000/20,000 ft/Ibs 12/23/2007 00:00 12:00 12.00 13,515 14,682 INTRM2 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 13,515' MDto 14,682 6,850' TVD ADT: 8.11 hrs. ECD - 11.21 ppg WOB: 25/30 RPM: 160 GPM:650 @ 2980 PSI PUW: 267 K, SO: 149 K RotWt: 196 K Tor ue on/off: 19,500/18,000 ft/Ibs 12:00 18:00 6.00 14,682 15,431 INTRM2 DRILL DDRL P _Drill 8 3/4" hole w/ GP f/ 14,682' MDto 15431 6919'TVD ADT: 5.5 hrs. ECD - 11.2 ppg WOB: 25 RPM: 160 GPM:650 @ 3,010 PSI PUW: 267 K, SO: 145 K RotWt: 196 K Tor ue on/off: 21,000/20,000 ft/Ibs 18:00 18:45 0.75 15,431 15,431 INTRM2 WELCT KLWL T Driller noted increase in flow and flocheck indicated well was flowing. Shut in well and monitered pressures. Pit ain 9 Bbls. There was 100 Bbls of 10 PPG mud in DP. Stabilized pressure after 15 min. SIDPP 40 psi, SICPP 40 psi. Started pumping with 10.0 PPG mud @ 40 SPM maintaing 40 psi on choke. ICP 537 psi. Pressure was increasing to 530 psi with 30 SPM. DP pressure continued to increase indicating well packed off. Attem ted to move DP throu h ba did not beeak loose. SICP 0 si.. 18:45 00:00 5.25 15,431 15,330 INTRM2 DRILL REAM T Opened Bag well dead. Started working Packed off DP to establish circulation. Worked pipe from 15,431 to 15,409' and stood back stand. Continued to work pipe with rotation (No Circulation) from 15,409' to 15 330'. Notified AOG C re resentatives b hone 2200 hrs. 12/24/2007 00:00 11:00 11.00 15,330 15,323 INTRM2 DRILL REAM T Worked packedoff pipe using rotary from 15330' to 15 323' no more ro ress. Worked pipe without upward progress. Pulling to 410 k. No iar action. 11:00 11:30 0.50 15,323 15,323 INTRM2 DRILL CIRC T Attempted to establish circulation 10 SPM 1350 si. No success. I Page 'i0 4af 23 J Time Logs _ D to From To Dur S. De th E. D th Phase Cod _ Subcode T COM 12/24/2007 11:30 20:00 8.50 15,323 15,307 INTRM2 _ DRILL OTHR T Worked packedoff pipe from 15323' to 15,307' (@370 k) no more progress. Worked pipe without upward progress. Pulling to 430 k. No jar action or rotation. 20:00 00:00 4.00 15,307 15,323 INTRM2 DRILL RURD T Rigged up Schlumberger pressure Equipment and hung WL sheave. Making up backoff charge. Monitoring well flowin throw h DP. 12/25/2007 00:00 00:45 0.75 15,323 15,323 INTRM2 DRILL RURD T Continue RU Schlumberger. Monitor volume of back flow from DP. Gained 36 bbls. SIDPP - 380 si. 00:45 01:45 1.00 15,323 15,323 INTRM2 WELC CIRC T Bullhead 37 bbls 10.5 mud at 2 bpm. Chase with 10 bbls 10.2 mud. Bleed off pressure. Close bleeder. SIDPP - 380 si.. 01:45 02:45 1.00 15,323 15,323 INTRM2 FISH ELNE T Schlumberger RIH w/ string shot. Monitor flow back. 28 bph. Stop Schlumber er. SIDDP - 320 si. 02:45 03:15 0.50 15,323 15,323 INTRM2 WELCT CIRC T Line up and bullhead 37 bbls 10.7 mud followed by 10 bbls 10.2 mud. Bleed off ressure. 03:15 04:15 1.00 15,323 15,323 INTRM2 FISH ELNE T Schlumberger continued in hole with string shot. Back flowed 23 bbls in 1 hour. Stop eline at 6900'. SIDPP - 280 si. 04:15 06:45 2.50 15,323 15,323 INTRM2 WELC OTHR T Line up and bullhead 224 bbls 10.3 PPG mud followed by 37 bbls 11 PPG mud. Then 30 Bbls of 10.3 PPG Mud. ICP 1740 psi final 1540 psi. Pumped 2 BPM. 06:45 08:45 2.00 15,323 15,323 INTRM2 WELC OWFF T Bled back 9 Bbls. Well. Closed choke to observe pressure. Observed well for 1 hour. Well dead 08:45 11:45 3.00 15,323 15,323 INTRM2 FISH ELNE T Opened Packoff and RIH with back off shot to 7,300' Could not o down. 11:45 13:45 2.00 15,323 15,323 INTRM2 FISH ELNE T POOH with Schlumberger tools and rearran a swivel. 13:45 17:00 3.25 15,323 15,323 INTRM2 FISH RURD T Changed packoff to grease head and installed side ent sub. 17:00 00:00 7.00 15,323 15,323 INTRM2 FISH ELNE T RIH with Schlumberger back off shot to 13,475' Pumping in as needed to move tool. Tool stuck @ 13,475'. Worked pipe and surged pipe attem tin to free strin shot. 12/26/2007 00:00 01:15 1.25 15,323 15,323 INTRM2 FISH ELNE T Work pipe up and down while applying torque to free eline tools. Put in 10 rounds left hand for ue. 14k ft lbs. 01:15 02:00 0.75 15,323 15,323 INTRM2 FISH ELNE T Pump 2 bpm at 1610 psi for Schlumberger to place string shot on ' de th at 13,41 ' 02:00 02:45 0.75 15,323 15,323 INTRM2 FISH ELNE T Place 4 strand string shot across tool joint at 13,445'. Had indication of , strin shot firin at surfs .. No change in string weight or torque. Worked pipe with left hand torque. id not back off. P<~~~~ ~ 1 of 23 • Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T COM 12/26/2007 02:45 03:45 1.00 15,323 15,323 INTRM2 FISH ELNE T POH with a-line to 300'. 03:45 05:30 1.75 15,323 15,323 INTRM2 FISH ELNE T Set slips. Break out pup below y-swivel. LD tools. Monitor well whole re-head and re-dress string shot w/ 6 strands of rimer cord. 05:30 06:15 0.75 15,323 15,323 INTRM2 FISH ELNE T Start string shot assembly in hole. MU -swivel assembl . 06:15 08:45 2.50 15,323 15,323 INTRM2 FISH ELNE T RIH w/ string shot to 13,500'. Starting bullheading 1.5 bpm at 4700' and increased to 2 b mat 10,000'. 08:45 10:45 2.00 15,323 15,323 INTRM2 FISH ELNE T Worked 8 rounds left hand torque into string. Connection below y-swivel broke. Apply 15 rounds right hand torque to string. Got 14 rounds back. Work 9 rounds left hand torque into strip .Tor ue - 16k ft Ilbs. 10:45 11:15 0.50 15,323 15,323 INTRM2 FISH ELNE T Place string shot across tool joint at 13,414'. (2 jts above top ghost reamer). Fired shot. No indication that shot fired at surface. No change in string weight or torque. Back out left hand for ue. 11:15 14:15 3.00 15,323 15,323 INTRM2 FISH ELNE T POH with a-line tools. 14:15 21:00 6.75 15,323 15,323 INTRM2 FISH ELNE T Rigged down String Shot tools Shot had fired. Rigged up to run Freepoint on "Bi "line. 21:00 00:00 3.00 15,323 15,323 INTRM2 FISH ELNE T PJSM. Rigged up Schlumberger and attempted to RIH. Cable was bad. Laid down tools and cut 300' of bad cable. 12/27/2007 00:00 00:30 0.50 15,323 15,323 INTRM2 FISH ELNE T Schlumberger. Re-headed rope socket. 00:30 01:45 1.25 15,323 15,323 INTRM2 FISH ELNE T MU Y-Block assembly. RIH with free oint tool to 2000'. 01:45 03:30 1.75 15,323 15,323 INTRM2 FISH ELNE T Calibrate free point tool in free pipe. 03:30 05:45 2.25 15,323 15,323 INTRM2 FISH ELNE T RIH to 3500'. Start bull heading ?bpm. Continue RIH to 6840'. Grease head was leaking. Change to heavier grease. Grease head still leaking. Concerned about possible head washout. 05:45 06:45 1.00 15,323 15,323 INTRM2 FISH ELNE T Obtain free oint at 6840' to check tool. 06:45 08:00 1.25 15,323 15,323 INTRM2 FISH ELNE T POH with free point tool to 300'. 08:00 09:00 1.00 15,323 15,323 INTRM2 FISH ELNE T Break off Y-Block assembly. LD tools. RD .39 WL sheaves. 09:00 12:00 3.00 15,323 15,323 INTRM2 FISH ELNE T RU .23 WL for perf gun run. Re-head same. F~~g~ ~~ czf ~3 ~ i Time Logs i i Date From To Dur S De th E. De th Phase Code Subcode T OM C 12/27/2007 _ 12:00 _ 16:30 4.50 15,323 15,323 INTRM2 FISH ELNE _ T _ Picked up tools and RIH with pert gun 1 5116" gun 2' Loaded 5 shots first foot 4 shots second foot for a total of 9 shots in 2' to 13,428'. Assisted with pump from 5,400' to 13,428' Pumped 193 Bbls 10.5 PPG mud to formation. Fired un and erforated from 13 428' to 13,430'. Had 400 si on DP which went to 20 si at shot. 16:30 18:15 1.75 15,323 15,323 INTRM2 FISH ELNE T POOH with Slumberger tools. Laid down tools. 18:15 22:45 4.50 15,323 15,323 INTRM2 FISH CIRC T Checked well no flow or pressure. Broke circulation and circulated staging pumps up to final rate of 4.5 BPM. Monitored returns for rate and MW. Circulated through open choke for precaution. MW 10.5 in and out. Shut down pumps and observed well for flow then checked for pressure. Well d 22:45 00:00 1.25 15,323 15,323 INTRM2 FISH ELNE T Picked up Rackoff shot and RIH with Schlumberger to 8,000'. Circulated 2 BPM from 3,700' to help tool down hole. 12/28/2007 00:00 02:00 2.00 15,323 15,323 INTRM2 FISH ELNE T Continue RIH with string shot while circulating at 2.5 bpm - 410 psi. Tools stopped at perforations at 13,428'. Close annular. Bullhead 28 bbls at 1.5 b m - 610 si.. Bleed off ressure. 02:00 03:30 1.50 15,323 15,323 INTRM2 FISH ELNE T Put 15 rounds right hand torque in drill pipe. Work in 18K ft Ibls left hand for ue and hold with ri ton s. 03:30 04:30 1.00 15,323 15,323 INTRM2 FISH ELNE T Place string shot accross tool joint at 13 345'. Fire strin shot. No surface indication of firing. Pull tools up hole 300'. Reciprocate pipe while holding left hand for ue: No se eration. 04:30 05:30 1.00 15,323 15,323 INTRM2 FISH ELNE T POH with tools to 300'. 05:30 06:00 0.50 15,323 15,323 INTRM2 FISH ELNE T Break out Y-Block assembly. LD tools. Strin shot fired 06:00 07:00 1.00 15,323 15,323 INTRM2 FISH ELNE T Schlumberger made up and checked 1 7!8" collision tool strin . 07:00 07:30 0.50 15,323 15,323 INTRM2 FISH ELNE T PU collision tool. Make up Y-Block assembl . 07:30 08:45 1.25 15,323 15,323 INTRM2 FISH ELNE T RIH with tools while circulating at 3 b mat 480 si. 08:45 11:00 2.25 15,323 15,323 INTRM2 FISH ELNE T Correlate tools to tool jt at 13,445'. Check line several times for tool movement after line is stopped. Estimate 2' of over travel. Fire collision tool with 350k string wt. No change in 11:00 16:15 5.25 15,323 15,323 INTRM2 FISH ELNE T POOH with Schlumberger tools and laid down same. Laid down Y block lubracator. ~ ~ ~--~ Page 13 of 23 Time Logs Date From To Dur S. De th E. Depth Phase Code Subcode T COM __ 12/28/2007 16:15 18:15 2.00 15,323 15,323 INTRM2 FISH CIRC T Circulating @ 10 BPM working stuck i e. 18:15 19:30 1.25 15,323 15,445 INTRM2 FISH CIRC T Pi a cam free. Circulate and condition mud 10 BPM. 19:30 21:45 2.25 15,445 11,478 INTRM2 FISH TRIP T POOH from 13,445' to 11,478' on TT Wi er Tri .Observed well, static. 21:45 22:45 1.00 11,478 13,435 INTRM2 FISH TRIP T RIH from 11,478'to 13,435'. 22:45 00:00 1.25 13,435 13,435 INTRM2 FISH CIRC T Circulated and raised MW to 10.8 PPG. 10 BPM 50 RPM 920 si. 12/29/2007 00:00 01:15 1.25 13,435 13,435 INTRM2 FISH CIRC T Continue to circulate at 10 bpm - 920 psi. Increase mud weight to 10.8. Flow check well. Static. Pump Brie job. Blow down to drive. 01:15 01:45 0.50 13,435 13,037 INTRM2 FISH TRIP T POH on trip tank from 13,435' to 13,037'. Im ro er hole fill. 01:45 02:15 0.50 13,037 13,435 INTRM2 FISH TRIP T RIH to 13,385'. Wash to 13,435'. 02:15 03:45 1.50 13,435 13,435 INTRM2 FISH CIRC T CBU plus 60 bbls 10-12 bpm at 920 - 1180 si. No influx. 03:45 06:15 2.50 13,435 11,479 INTRM2 FISH TRIP T POOH on trip tank from 13,435' to 11,479'. 06:15 13:30 7.25 11,479 2,917 INTRM2 DRILL TRIP T Pumped slug and continue POOH on TT from 11,479' to 2,917'. 13:30 14:00 0.50 2,917 2,917 INTRM2 WELC OWFF T Observed well. No flow. 14:00 16:00 2.00 2,917 0 INTRM2 FISH TRIP T POOH on TT from 2,917' to surface and laid down cut off stub.. Severed about 3' above Tool 'oint. 16:00 17:15 1.25 0 0 INTRM2 DRILL PULD T Moved HWDP in derrick. 17:15 23:30 6.25 0 0 INTRM2 WELCT BOPE T Pulled wear ring. PJSM, Rig up and test BOPE Annulur - 250 low/2500 hi h 500 for min -test good. Tested closing unit OK. 23:30 00:00 0.50 0 0 INTRM2 CEME~ RURD T Rigged up to pick up tubing tail. 12/30/2007 00:00 00:15 0.25 0 0 INTRM2 CEME~ CIRC T PJSM on picking up 3?" tbg. 00:15 02:15 2.00 0 928 INTRM2 CEME~ TRIP T PU and RIH w/ 30 jts 3?" tbg to 928'. ~~ ~>~ 02:15 02:45 0.50 928 928 INTRM2 CEME~ RURD T Change elevators. Make up XO's. 02:45 10:30 7.75 928 13,398 INTRM2 CEME~ TRIP T RIH with 5" DP from 928; to 13,398'. Break circulation every 20 stds to clear i e. 10:30 13:00 2.50 13,398 13,430 INTRM2 CEME CIRC T Break circulation. Wash from 13,398' to 13,430'. Circulate and condition mud at 12 b m - 1260 si. rage 14 of 23 • Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T COM 12/30/2007 13:00 14:00 1.00 13,430 13,430 INTRM2 CEME DISP T PJSM -establish circulation with Dowell pump -test lines to 3000 psi - Plu ed back 8 3/4" o en hole from 13,430' to 12,830' with 304 sxs 54 Bbls of 17 ppg G cement (20% excess) 1 cf/sx yld -displaced to equalization -CIP @ 1400 hrs - ETOC 12,830'. 14:00 15:00 1.00 13,430 12,446 INTRM2 CEME TRIP T POOH from 13,440' to 12,446' on TT. 15:00 16:30 1.50 12,446 12,446 INTRM2 CEME CIRC T Circulate and conditioned mud 14 BPM 1480 si. 16:30 18:00 1.50 12,446 10,543 INTRM2 CEME TRIP T Flow checked well Static. POOH on TT from 12,446' to 10,543'. 18:00 22:00 4.00 10,543 10,543 INTRM2 CEME WOC T WOC until 2200 hrs. Circulating 5 BPM 340 si. 22:00 23:15 1.25 10,543 12,680 INTRM2 CEME TRIP T RIH from 10,543' to 12,702'. Tagged cement. 23:15 23:30 0.25 12,680 12,702 INTRM2 CEME OTHR T Broke circulation and retagged TOC @ 12,702' with 15K. Tag witnessed by AOGCC State Re resentative Bob Noble. 23:30 00:00 0.50 12,702 12,446 INTRM2 CEME TRIP T Picked up to 12,636' and blew down to drive. POOH on TT to 12,446'. 12/31/2007 00:00 01:45 1.75 12,446 10,194 INTRM2 CEME TRIP T POH on trip tank from 12,636' to 01:45 02:15 0.50 10,194 10,194 INTRM2 CEME CIRC T Spot 40 bbl hi-vis pill at 10 bpm - 760 si. 02:15 02:30 0.25 10,194 10,004 INTRM2 CEME TRIP T POH from 10,194'to 10,004'. 02:30 03:00 0.50 10,004 10,004 INTRM2 CEME CIRC T MU head pin. Establish circulation at 10 b m - 1060 si. 03:00 03:45 0.75 10,004 10,004 INTRM2 CEME DISP T PJSM -establish circulation with Dowell pump -test lines to 3000 psi - Plu ed back 8 3/4" o en hole from 10 004' to 9404' with 304 sxs 54 B I of 17 G cement 20% excess 1 ft?/sk yld -displaced to equalization - CIP 0332 hrs - ETOC 9404'. 03:45 04:45 1.00 10,004 9,021 INTRM2 CEME TRIP T POH slow from 10,004' to 9021'. 04:45 06:15 1.50 9,021 9,021 INTRM2 CEME CIRC T CBU at 12 bpm. Smalll amount cement contaminated mud at surface. 06:15 10:30 4.25 9,021 2,836 INTRM2 CEME TRIP T POH on trip tank from 9121' to 8070'. Pump dry job. Blow down. POH to 2836. No hole roblems. 10:30 10:45 0.25 2,836 2,836 INTRM2 RIGMN SFTY P PJSM on slip and cut drilling line. 10:45 12:15 1.50 2,836 2,836 INTRM2 RIGMN SVRG P Slip and cut drilling line. Service top drive. 12:15 13:15 1.00 2,836 938 INTRM2 CEME TRIP T POH with 5" DP from 2836' to 938'. 13:15 16:30 3.25 938 0 INTRM2 CEME PULD T PJSM and laid down 30 jts 3.5" tubing and muleshoe. 16:30 18:45 2.25 0 266 INTRM2 DRILL PULD T Picked up Geopilot BHA and RIH to 266'. Shallow tested. Pay 1 S cat 23 Time Leas ~\a~ Dade From To Dur 5 Depth E. De th Phase Code Subcode T COM 12/31/2007 18:45 20:15 1.50 266 2,719 INTRM2 DRILL TRIP T RIH with HWDP and stands to 2,719'. 20:15 21:30 1.25 2,719 2,719 INTRM2 DRILL SRVY T Filled pipe and tested tools. No signal to geopilot. Trouble shoot tools. Tools OK. 21:30 22:45 1.25 2,719 4,465 INTRM2 DRILL TRIP T RIH from 2,719' to 4,465' string taking wei ht. 22:45 00:00 1.25 4,465 4,908 INTRM2 DRILL REAM T Washed and reamed from 4,465' to 4,908'. 100 r m 550 m 1680 si. 01/01/2008 00:00 08:00 8.00 4,908 9,571 INTRM2 DRILL REAM T Wash and ream several sections from 4908' to 9571' 550 gpm - 100 rpms. No firm cement encountered. 08:00 12:00 4.00 9,571 9,629 INTRM2 STK KOST T Control drill and attem t to sidetrack well from 9571' to 9629'. TVD - 4786'. RPM = 100 WOB = 3k/7k 605 gpm @ 2420 psi ECD = 11.46 12:00 23:15 11.25 9,629 10,618 INTRM2 DRILL DDRL T Drill 8 3/4" w/ GP f/ 9629' to 10,618' MD 5235' TVD ADT - 7.92 hrs ECD - 11.8 ppg WOB - 18/22 k RPM 150 GPM 650 ` `l ~~ ~ ~ @ 2770 psi String wt. PU 228 SO 137 Rot 170 t0 ~ a ~ ~ t~ t ' ~ Torque on/off btm. - 17,000/15,500 ft/Ibs 23:15 00:00 0.75 10,618 10,618 INTRM2 RIGMN' RGRP T Blow Down TD - RU head pinto circ - Chan a swivel ackin 01/02/2008 00:00 00:30 0.50 10,618 10,618 INTRM2 RIGMN RGRP T Change out and grease wash pipe packing while circulating at 5 bpm - 520 psi. RD head pin. Bring pumps up to s eed to check for leaks. 00:30 12:00 11.50 10,618 11,760 INTRM2 DRILL DDRL T Drill 8 3/4" w/ GP f/10,618' to 11,760' MD 5824' TVD ADT - 6.85 hrs ECD - 11.8 ppg WOB - 18/22 k RPM 150 655 gpm @ 2970 String wt. PU 175 SO 142 Rot 186 Torque on/off btm. -19,500!19,500 ft/Ibs Observed sli ht flow on connections 12:00 00:00 12.00 11,760 12,997 INTRM2 DRILL DDRL T Drill 8 3/4" hole w/ GP f/ 11,760' to 12,997' MD 6377' TVD ADT - 7.31 hrs ECD - 11.85 ppg WOB 22-25 k RPM 150 GPM 650 @ 3100 psi String wt. PU 275 SO 145 Rot 187 Torque on/off btm - 21,000/19,500 ft/Ibs Observed sli ht flow on connections Pace 16 of ~3 • Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T COM 01/03/2008 00:00 12:00 12.00 12,997 13,966 INTRM2 DRILL DDRL ~ T Drill 8 3/4" hole w/ GP f! 12,997 to 13' 966 MD 6775' TVD ADT - 7.2 hrs ECD - 11.94 ppg WOB 18/30 k RPM 150 GPM 550 2540 psi String wt. PU 260 SO 150 Rot 195 Torque on/off btm - 19,000/18,000 ft/Ibs Observed sli ht flow on connections 12:00 23:00 11.00 13,966 14,615 INTRM2 DRILL DDRL T Drill 8 3/4" hole w/ GP f/ 13,966' to 14,615' MD 6900' TVD ADT - 8.87 hrs ECD - 11.77 ppg WOB 25/30 k RPM 150 GPM 550 2630 psi String wt. PU 260 SO 150 Rot 195 Torque onloff btm. -19,500118,00 ft/Ibs. 23:00 00:00 1.00 14,615 14,615 INTRM2 DRILL CIRC T Circ btms up for wiper trip - 550 gpm 2630 psi w/ 120 rpm -Std back 1 std to 14,520' 01/04/2008 00:00 02:45 2.75 14,615 14,615 INTRM2 DRILL REAM T Back ream from 14,520' to 13,187' 120 RPM 550 GPM 2510 ICP, 2450 FCP 02:45 04:00 1.25 14,615 14,615 INTRM2 DRILL REAM T TiH to 14,520', wash and ream to 14,615 04:00 07:00 3.00 14,615 14,729 INTRM2 DRILL DDRL T Drill 8 3/4" hole w/ GP f/ 14,615' to 14,729' MD 6910' TVD ECD - 11.62 ppg WOB 14/30 k RPM 150 GPM 550 2520 psi String wt. PU 280 SO 142 Rot 198 Torque onloff btm. - 21,500/20,00 ft/Ibs. 07:00 08:30 1.50 14,729 14,729 INTRM2 DRILL CIRC T Stand back 1 stand of 5" DP, circulate buttoms up rotate at 120 RPM 550 GPM 2520 is 08:30 12:00 3.50 14,729 14,829 INTRM2 DRILL DDRL T Wash and ream to bottom Drill 8 3/4" hole w/ GP f/ 14,729' t/ 14829' MD,6907' TVD ECD - 11.62 ppg WOB 14/30 k RPM 150 GPM 550 2520 psi String wt. PU 280 SO 142 Rot 198 Torque on/off btm. - 21,500/20,00 ft/Ibs. ADT 4.37 Page 17 cif ~3 l I Time Logs Date From To Dur S: Depth E. De th Phase Code Subcode T COM 01/05/2008 22:45 00:00 1.25 12,425 12,425 INTRM2 DRILL CIRC P Flow check -static. Circulate btms up 550 GPM, 2410 psi, 120 rpm * Observed 1st WBSP @ shakers - Circ to et ill out of hole 01/06/2008 00:00 04:45 4.75 12,425 8,620 INTRM2 DRILL TRIP P Flow Check well -static. POOH on TT F/12,425' to 8,620' 04:45 05:30 0.75 8,620 8,429 INTRM2 DRILL REAM NP Back ream F/ 8,620' T/8,429' 450 GPM, 1420 PSI, 120 RPM 05:30 06:00 0.50 8,429 8,144 INTRM2 DRILL TRIP P POOH on TT F/8,429' T/8,144' 06:00 07:15 1.25 8,144 7,573 INTRM2 DRILL REAM NP Back ream F/8,144 T/7,573' 450 GPM, 1400 PSI, 120 RPM 07:15 08:30 1.25 7,573 7,477 INTRM2 DRILL CIRC NP CBU reciprocating and rotating DP F/7,573' T/7,47T 450 GPM, 1390 PSI, 120 RPM 08:30 08:45 0.25 7,477 7,287 INTRM2 DRILL TRIP P TOOH on TT F/7,447 T/7,287' Over ull and im ro er 08:45 10:30 1.75 7,287 6,336 INTRM2 DRILL REAM NP Back Ream F/7287 T/6336' 450 GPM, 1320 PSI, 120 RPM Flow Check -well static, blow down TD 10:30 10:45 0.25 6,336 6,240 INTRM2 DRILL TRIP P POOH on TT F/6240' T/6145 swabbin 10:45 11:45 1.00 6,145 5,765 INTRM2 DRILL REAM NP Back ream F/6240 T/5765 GPM 450, 1300 PSI, 120 RPM Blow down TD and flow check -static 11:45 12:00 0.25 5,765 5,670 INTRM2 DRILL TRIP P POOH on TT F/5765 T/5670' 12:00 16:00 4.00 5,670 3,861 INTRM2 DRILL REAM NP Back ream f/ 5670' to 3861' - 450 gpm 1250 si w/ 120 r m 16:00 16:45 0.75 3,861 3,861 INTRM2 DRILL CIRC P Circ hole clean - 450 gpm @ 1200 psi w/120r m 16:45 18:00 1.25 3,861 3,005 INTRM2 DRILL TRIP P Flow ck( static) -Blow down TD - POOH on TT f/ 3861' to 3005' 18:00 18:45 0.75 3,005 2,434 INTRM2 DRILL TRIP P Monitor well (static) Cont. POOH on TT f/ 3005' to 2434' Hole fill 'ust under ro er fill 18:45 19:30 0.75 2,434 2,434 INTRM2 DRILL CIRC P Circ to clean BHA tools - 450 gpm @ 1000 psi w/ 120 rpm Last fill 'ust short of ro er fill 19:30 22:15 2.75 2,434 720 INTRM2 DRILL TRIP P Blow down TD -POOH on TT f/ 2434' to 720' - LD ghost reamer -Monitor well for 15 mins. static 22:15 00:00 1.75 720 83 INTRM2 DRILL PULD P Std back HWDP & jars - LD NM flex DC's -Plug in & down load MWD - Pull up & service Geo-Pilot & break bit while down loadin MWD 01/07/2008 00:00 01:00 1.00 83 0 INTRM2 DRILL PULD P UD MWD, NIMPC, GP, subs & GS Clear floor and LD elevators & bales 01:00 02:15 1.25 0 0 INTRM2 DRILL RURD P PJSM, change to 7" RAMS & 4" saver sub. ~~~ 19 of 23 Time Logs ~ Dare From To Dur 5 De th E. De th Pha e Cade Subcode T COM I 01/07/2008 02:15 03:15 1.00 0 0 INTRM2 WELC ROPE P Pull wear ring and set test plug, R/U test equipment, test 7" RAMS - 250/low 3500 psi high, test good R/D test a ui ment. 03:15 04:00 0.75 0 0 INTRM2 CASINC RURD P Pull test plug & set thin wall wear ring. 04:00 05:30 1.50 0 0 INTRM2 CASINC RURD P RU csg equipment 05:30 06:00 0.50 0 0 INTRM2 CASIN SFTY P PJSM on running 7" casing 06:00 09:30 3.50 0 2,983 INTRM2 CASIN RNCS P Run 7" 26# L-80 BTCM as follows: FS( Ray Oil Tools Silver Bullet) 2 jts. csg - FC (Halliburton Super Seal) 2 jts, csg ( First four jts. made up w/ Bakertoc - fill pipe & check floats) 66 jts csg (70 'ts total to 2983' 09:30 10:00 0.50 2,983 2,983 INTRM2 CASINC CIRC P Circulate one csg volume at 9 bpm - 750 si. 10:00 14:30 4.50 2,983 6,395 INTRM2 CASINC RNCS P Continue running 7" 26# L-80 BTCM cs f/ 2983 to 6395' 150 'ts total 14:30 15:45 1.25 6,395 6,395 INTRM2 CASINC CIRC P Break circ & stage pumps up to 4.5 bbls/min -Circ btms up + & condition mud @ 370 psi - PU wt. 170 SO wt 130 15:45 21:00 5.25 6,395 9,799 INTRM2 CASINC RNCS P Continue running 7" 26# L-80 BTCM cs f/ 6395' to 9799' 230 'ts. total 21:00 00:00 3.00 9,799 9,799 INTRM2 CASINC CIRC P Break circ & stage pumps up to 4.3 bbls/min -Circ btms up + to condition mud -FCP 500 psi PU wt. 220 SO wt. 125 01/08/2008 00:00 05:15 5.25 9,799 13,202 INTRM2 CASINC RNCS P Continue running 7" 26# L-80 BTCM Casing F/9,789' T/13,202' (310 jts total 05:15 08:00 2.75 13,202 13,202 INTRM2 CASIN CIRC P Establish circ -Stage pump up f/ 3 bbls/min to 4.2 bbls/min -circ & condition mud - ICR 650 psi FCP 650 si - PU wt. 290 SO wt. 155 08:00 11:15 3.25 13,202 14,855 INTRM2 CASIN RNCS P Continue running 7" 26# L-80 BTCM casing f/13,202' to 14,818' (348 jts total) PU FMC fluted csg hanger & landing jt. -Land csg w/fluted hanger in wellhead w/ FS @ 14,855' - FC @ 14,766' -TAM PC 8289' 11:15 12:00 0.75 14,855 14,855 INTRM2 CASINC RURD P R/D tongs, slips, and Franks. R/U CMT head 12:00 15:00 3.00 14,855 14,855 INTRM2 CEME~ CIRC P Establish circulation @ 1.5 bpm / 480 psi -Attempted to reciprocate pipe w/ 425k, unable -stage pumps up to 5.0 bpm -circulate and condition mud until mud wt. in & out @ 10.8 ppg - FCP=550 psi -Total of 984 bbls um ed -full returns throu hout 15:00 15:15 0.25 14,855 14,855 INTRM2 CEME~ SFTY P Held pre job safety & ops meeting w/ crew on cementin 7" cs Pag€; 2tl of 23 r~ ~~ Time Logs _ _ _ Date From To Dur S De th E. De th Phase Code Subcode T COM 01/08/2008 15:15 18:30 3.25 14,855 _ 14,855 INTRM2 CEME DISP P _ Pertorm 1st stage cementjob as follows: Pump 5 bbls CW 100 -Test lines to 4400 psi - Drop bottom plug - Pump 35 bbls CW-100 @ 4 bbls/min @ 800 psi -Pump 40 bbls MudPush @ 10.5 ppg @ 4 bbls/min @ 800 psi - Mix & pump 88 bbls (148 sks) 11.0 ppg Lead slurry (LiteCrete w/ .4% D046, 1 % D065, .01 % 6155, .25%D167) @ 5 bbls/min @ 900 psi - Mix & pump 22 bbls (107 sks) 15.8 ppg tail slurry (Class G w/ .2% D046, .25% D065, .25% D800,.18% D167) @ 3 bbls/min @ 600 psi -Drop top plug w/ 10 bbls water f! Dowell - Switched over to rig pumps & displaced w/ 238 bbls 10.7 ppg inhibited CaCl2 @ 5 bbls/min @ 570 psi & 315.4 bbls 10.7 ppg CaCl2 @ 6 bbls/min @ 760 psi -slowed pumps to 4 bbls/min for last last 13 bbls - Bumped plug w/ 1500 psi - CIP @ 1815 hrs. -Checked floats OK -Full returns through job -Unable to move i e Burin 'ob. 18:30 19:00 0.50 14,855 14,855 INTRM2 CEME OTHR P RD cement equipment 19:00 20:15 1.25 14,855 14,855 INTRM2 CASINC RURD P LD landing jt. -Pull thin wall wear bushing -Set 7" x 9 5/8" pack-off - Test to 5000 si for 10 mins. 20:15 22:45 2.50 0 0 INTRM2 CASIN OTHR P PJSM on changing rams -Changed top pipe rams f!7" to 3 1!2' x 6" VBR - set test plug & test to 250 & 3500 psi w/ 4" test jt. -Pull test plug -set wear bushin 22:45 00:00 1.25 0 0 INTRM2 DRILL PULD P RU & LD 5" DP f/ driller's side of derrick via mouse hole 01/09/2008 00:00 02:45 2.75 0 0 INTRM2 DRILL PULD P Lay down 5"drill pipe from derrick 02:45 03:15 0.50 0 0 INTRM2 CEME OTHR P Change elevators and dress iron rou hneck for 4"drill i e 03:15 03:45 0.50 0 0 INTRM2 CEME PULD P Pick up and MU Baker plug dropping assembly -torque all connections - La down com lete assembl 03:45 04:00 0.25 0 0 INTRM2 CEME SFTY P Held pre job safety and Opts meeting on Tam Combo tool 04:00 04:30 0.50 0 38 INTRM2 CEME PULD P PU & MU Tam Port Collar Premium Combo tool 04:30 09:00 4.50 38 2,784 INTRM2 CEME TRIP P RIH from 38' to 2,784' with 4" drill pipe from derrick -ran slowly to avoid fluid runnin over to of stands CaCl2 09:00 10:30 1.50 2,784 2,784 INTRM2 RIGMN SVRG P PJSM -Slip and cut drilling line - Service Top Drive and Drawworks - ad~usted brakes Page 21 of 23 L J C~ Time Logs ~ __ D e From To Dur 5_D~~th E. De th Phase Code _ Subcode T COM 01/09/2008 10:30 17:30 7.00 2,784 8,291 INTRM2 CEME TRIP P RIH F/ 2,784' to 8,280' picking up 4" drill pipe from shed -locate shifting sleeve in port collar @ 8,291' - adjusted space out pups to have access to Top rams or annular reventor. 17:30 18:30 1.00 8,291 8,291 INTRM2 CEME RURD P PJSM- M\U Plug dropping head & R/U for CMT 'ob 18:30 21:30 3.00 8,291 8,291 INTRM2 CEME OTHR P PJSM- Establish CIRC @ 105 GPM, 230 PSI, Displace DP w/10 BBLS water, Drop ball and pump 84 BBLS Of 10.8 PPG mud. After ball seated, attempted to test cups @ 1000 PSI -observed slight flow at flow line, open PC and close top rams. Establish circulation with 10.8 ppg mud taking returns out 9 5/8" x 7" annulus at 1.0 bpm / 290 psi -staged pump up to 4.5 b m and CBU - FCP=810 si 21:30 22:30 1.00 8,291 8,291 INTRM2 CEME DISP P PJSM -Cement 2nd stage as follows: Pump 5 bbls CW 100 -test lines to 2300 PSI -Pump 30 bbls MudPush @ 10.5 ppg @ 4 bbls/min @ 800 psi - Mix & pump 40 bbls (204 sks) 15.8 ppg Tail slurry (Class G w/ .2% DO46, .3% DO65, 1 % SOO2}} @ 4 bbls/min @ 400 psi - Drop Dart w/ 10 bbls water f/ Dowell -Switched over to rig pumps & displaced w! 67 bbls 10.7 ppg un-inhibited brine @ 210 gpm @ 570 psi -Bumped Dart w/ 1800 psi - CIP 2230 hrs. 22:30 23:30 1.00 8,291 8,291 INTRM2 CEME OTHR P Shear Dart @ 2100 PSI, close PC, shear ball seat @ 2600 PSI. RU & reverse circulate 2 DP Volumes @ 168 GPM 750 PSI -observed slight trace of cmt on btms u 23:30 00:00 0.50 8,291 8,291 INTRM2 CEME RURD P R/D Plug dropping head 01/10/2008 00:00 01:15 1.25 8,291 8,280 INTRM2 CASIN( DHEQ P Release closing tool from port collar - Pull up to 8,280'- LD 2 pup joints - RU and test 7" casing to 3500 psi for 30 minutes -Blow down kill line 01:15 02:45 1.50 8,280 8,280 INTRM2 CASIN OTHR P RU and pumped 208 bbls 10.7 ppg inhibited CaCl2 brine -followed by 19 bbls 10.7 ppg CaCl2 to equilize inhibited brine to 2850' 02:45 09:00 6.25 8,280 38 INTRM2 CEME TRIP P POOH laying down 4"drill pipe from 8,280' to 38' 09:00 09:30 0.50 38 0 INTRM2 CEME PULD P Service break and lay down Tam Combo tool assembl 09:30 10:00 0.50 0 0 INTRM2 CEME OTHR P PU and service break Baker plug dro in assembl - LD same 10:00 10:45 0.75 0 0 INTRM2 RPCOh OTHR X Clear tools from rig floor -pull wear bushin 10:45 11:15 0.50 0 0 INTRM2 RPCOb RURD X RU to run 3 1/2" tubing E=ag~ 22 ~f 23 • l~ Time Logs _ _ ~ Date From To Dur 5 De th E. Depth Ph e Code Subco e T COM 01/10/2008 11:15 11:30 0.25 0 INTRM2 RPCO SFTY X PJSM on running tubing 11:30 15:15 3.75 0 2,845 INTRM2 RPCO RCST X Run 3 1/2" kill string as follows: WLEG - 91 jts 3 1/2" 9.3# L-80 EUE Mod - XO (3 1/2" EUE(P) to 4 112" IBT - (B) - MU FMC tbg hanger (w/ elastmer seals) & land tbg hanger in wellhead w! tail 2845' 15:15 16:15 1.00 0 0 INTRM2 RPCO RCST X LD landing jt. A - set TWC - PU lading jt. B -test hanger seals to 5000 psi - LD landin 't. B 16:15 18:00 1.75 0 0 INTRM2 WELCT NUND X ND ROPE -Change saver sub & grab dies in TD 18:00 20:00 2.00 0 0 INTRM2 RPCOh OTHR X NU & test tree to 5000 psi -Pull TWC 20:00 00:00 4.00 0 0 INTRM2 RPCOb FRZP X RU on well to pump inhibited CaCl2 brine & diesel -Held PJSM -Test lines to 1000 psi -Pumped 40 bbls 10.7 ppg inhibited brine followed by 54 bbls diesel w/ Dowell -Shut down - shut in well -Blow down lines - RU line to U-tube fluid to equalize brine f/ 2845 to 1520' & diesel f/ 1520' to surface - Shut in well -Blow down & RD lines -Set BPV -Secure well 01/11/2008 00:00 11:30 11.50 0 0 INTRM2 DRILL PULD P LD 5"DP - 11:30 13:00 1.50 0 0 INTRM2 DRILL OTHR P Clean drains, drip pans, pipe racks Release ri 1300 hrs. F~~g~ 23 cef 23 • • Halliburton Company Survey Report CumpAn~: Conoco Phillips Alaska Inc. Date: 2/1/2003 Time 10'.49'06 Pat;c: Field: Colville River Unit (~u -ordinalr(vH.l Refcrcncr: Well: CDr+-301, True North ~ Site: EJanuq CD4 ~~c rtical IY'~ D) Re (crence: CD4-301 (19+36.9) 55.9 ' Well: CD4-301 Section f~'S> Ke&r rnce: Well (O OON.O.OOE,84.32Azi) Wellpath: CD4-3018 .5u rcey Calculation licthod: Tvlirrimum Curvature Db: Oracle __- Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 ~ Well: CD4-301 Slot Name: 50-103-20557-00 Well Position: +N/-S 0.02 ft Northing: 5957526 .12 ft Latitude: 70 17 32.966 N +E/-W 0.03 ft Easting : 378174 .73 ft Longitude: 150 59 10.762 W Position Uncertainty: 0.00 ft Wellpath: CD4-301 B Drilled From: CD4-301 50-103-20557-02 Tie-on Depth: 9575.95 ft Current Datum: CD4-301 (19+36.9) Height 55 .90 ft Above System Datum: Mean Sea Level Magnetic Data: 1219!2007 Declination: 22.32 deg Field Strength: 57567 nT Mag Dip Angle; 80.65 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.90 0.00 0.00 84.32 Survey Program for Definitive Wellpath Date: 2/1/2008 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 81.00 444.00 CD4-301 Gyro (81.00-444.00) (0 CB-GYRO-SS Camera based gyro single shot 480.19 9575.95 CD4-301 IIFR+MS+SAG (480.19-15 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9595.00 14823.06 CD4-301 B IIFR+MS +SAG (9595.00- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Inc! ~zim TVl) tiys~F~~D N/S EM Flap,A MapE Tuul ft deg deg ft ft ft ft ft ft 36.90 0.00 0.00 36.90 -19.00 0.00 0.00 5957526.12 378174.73 TIE LINE 81.00 0.45 77.00 81.00 25.10 0.04 0.17 5957526.16 378174.90 CB-GYRO-SS 172.00 0.78 98.00 171.99 116.09 0.03 1.13 5957526.13 378175.86 CB-GYRO-SS 262.00 1.25 111.00 261.98 206.08 -0.40 2.65 5957525.67 378177.38 CB-GYRO-SS 353.00 2.75 122.00 352.92 297.02 -1.92 5.43 5957524.12 378180.13 CB-GYRO-SS 444.00 5.40 128.00 443.68 387.78 -5.71 10.66 5957520.24 378185.29 CB-GYRO-SS 480.19 5.87 133.01 479.70 423.80 -8.02 13.35 5957517.88 378187.95 MWD+IFR-AK-CAZ-SC j 570.30 7.85 122.53 569.16 513.26 -14.47 21.91 5957511.29 378196.40 MWD+IFR-AK-CAZ-SC 661.37 9.30 119.34 659.21 603.31 -21.42 33.57 5957504.16 378207.95 MWD+IFR-AK-CAZ-SC 751.19 9.00 109.43 747.90 692.00 -27.32 46.52 5957498.05 378220.80 MWD+IFR-AK-CAZ-SC 843.01 9.66 110.13 838.50 782.60 -32.36 60.53 5957492.79 378234.72 MWD+IFR-AK-CAZ-SC 937.81 11.79 108.61 931.64 875.74 -38.19 77.18 5957486.69 378251.27 MWD+IFR-AK-CAZ-SC 1033.16 15.30 113.10 1024.33 968.43 -46.23 97.99 5957478.31 378271.95 MWD+IFR-AK-CAZ-SC 1128.54 18.15 113.76 1115.66 1059.76 -57.16 123.17 5957466.98 378296.94 MWD+IFR-AK-CAZ-SC 1223.73 20.24 109.87 1205.56 1149.66 -68.73 152.22 5957454.94 378325.81 MWD+IFR-AK-CAZ-SC 1319.10 24.53 109.64 1293.72 1237.82 -81.00 186.40 5957442.12 378359.78 MWD+IFR-AK-CAZ-SC 1414.12 27.63 110.40 1379.06 1323.16 -95.31 225.64 5957427.17 378398.78 MWD+IFR-AK-CAZ-SC 1509.75 29.24 111.23 1463.15 1407.25 -111.50 268.20 5957410.30 378441.06 MWD+IFR-AK-CAZ-SC 1604.43 30.32 110.93 1545.32 1489.42 -128.41 312.08 5957392.68 378484.66 MWD+IFR-AK-CAZ-SC 1699.32 33.66 110.63 1625.79 1569.89 -146.24 359.07 5957374.10 378531.35 MWD+IFR-AK-CAZ-SC 1794.72 37.15 109.28 1703.54 1647.64 -165.07 411.02 5957354.43 378582.99 MWD+IFR-AK-CAZ-SC 1890.15 39.51 107.54 1778.40 1722.50 -183.74 467.18 5957334.85 378638.83 MWD+IFR-AK-CAZ-SC 1984.93 42.94 107.58 1849.67 1793.77 -202.58 526.72 5957315.05 378698.05 MWD+IFR-AK-CAZ-SC ~ 2080.54 47.38 107.87 1917.07 1861.17 -223.22 591.28 5957293.37 378762.26 MWD+IFR-AK-CAZ-SC ~ i 2175.68 50.06 108.42 1979.83 1923.93 -245.49 659.21 5957270.00 378829.82 MWD+IFR-AK-CAZ-SC j , 2270.80 52.18 109.27 2039.54 1983.64 -269.41 729.28 5957244.95 378899.49 MWD+IFR-AK-CAZ-SC 2366.10 55.29 109.42 2095.90 2040.00 -294.87 801.77 5957218.32 378971.55 MWD+IFR-AK-CAZ-SC 2461.48 58.90 108.07 2147.71 2091.81 -320.58 877.59 5957191.39 379046.94 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report Cumpan}: ConocoPhillips Alaska Inc. ...Date: 2/1/2008 I imc: 10:49:06 1'a~c 2 Field: Colville River Unit Co-ordiuate(~H:) Reference: WeIL' CD4-301, True North Site NanUq CD4 Vertical (T~'DI Reference: CD4-301 (19+36.9) 55.9 ~~'cll: CD4-301 Section (~~S) Keferencc: Well (0.00N,O.OOE,84.32Azi) 1~cllpath: CD4-301B Sun~e}~ Calculation Methodi Minimum Curvature llb: Oracle ~urcc~ ND Licl Azim l~~ll SysTVD \/S F/)1' tiiapA ~1apl: Tool ft deg deg ft ft ft ft ft ft -- _ - _ __ _ 2556.47 60.93 106.31 2195.33 2139.43 -344.85 956.11 5957165.85 379125.05 MWD+IFR-AK-CAZ-SC 2651.69 63.74 106.82 2239.53 2183.63 -368.90 1036.93 5957140.50 379205.46 MWD+tFR-AK-CAZ-SC 2746.99 67.27 107.96 2279.04 2223.14 -394.83 1119.67 5957113.24 379287.77 MWD+IFR-AK-CAZ-SC 2842.01 68.55 108.09 2314.77 2258.87 -422.07 1203.40 5957084.64 379371.03 MWD+IFR-AK-CAZ-SC 2936.93 67.82 106.50 2350.05 2294.15 -448.27 1287.53 5957057.08 379454.72 MWD+IFR-AK-CAZ-SC 2997.09 68.00 107.88 2372.67 2316.77 -464.74 1340.78 5957039.75 379507.69 MWD+IFR-AK-CAZ-SC 3095.92 68.04 106.58 2409.67 2353.77 -491.89 1428.31 5957011.19 379594.76 MWD+IFR-AK-CAZ-SC 3194.19 66.81 107.24 2447.39 2391.49 -518.28 1515.13 5956983.40 379681.13 MWD+IFR-AK-CAZ-SC 3294.37 67.95 107.95 2485.92 2430.02 -546.23 1603.27 5956954.02 379768.81 MWD+IFR-AK-CAZ-SC 3389.78 68.20 108.23 2521.55 2465.65 -573.72 1687.41 5956925.18 379852.48 MWD+IFR-AK-CAZ-SC 3485.18 68.78 108.38 2556.53 2500.63 -601.59 1771.67 5956895.95 379936.27 MWD+IFR-AK-CAZ-SC 3580.43 69.20 109.26 2590.68 2534.78 -630.28 1855.83 5956865.90 380019.95 MWD+IFR-AK-CAZ-SC 3675.81 68.80 108.83 2624.86 2568.96 -659.34 1940.00 5956835.49 380103.63 MWD+IFR-AK-CAZ-SC 3770.71 68.08 109.48 2659.73 2603.83 -688.29 2023.38 5956805.18 380186.52 MWD+IFR-AK-CAZ-SC 3865.85 67.48 109.76 2695.71 2639.81 -717.87 2106.34 5956774.27 380268.98 MWD+IFR-AK-CAZ-SC 3961.04 66.80 109.88 2732.69 2676.79 -747.61 2188.85 5956743.20 380351.00 MWD+IFR-AK-CAZ-SC 4055.77 66.47 110.22 2770.26 2714.36 -777.42 2270.54 5956712.07 380432.19 MWD+IFR-AK-CAZ-SC 4150.85 67.26 110.61 2807.62 2751.72 -807.92 2352.49 5956680.25 380513.62 MWD+IFR-AK-CAZ-SC 4245.76 68.13 110.69 2843.64 2787.74 -838.89 2434.65 5956647.96 380595.27 MWD+IFR-AK-CAZ-SC 4340.81 68.53 108.76 2878.74 2822.84 -868.70 2517.80 5956616.81 380677.91 MWD+IFR-AK-CAZ-SC 4435.99 67.42 108.92 2914.43 2858.53 -897.19 2601.30 5956586.97 380760.94 MWD+IFR-AK-CAZ-SC 4530.99 68.94 106.86 2949.74 2893.84 -924.27 2685.23 5956558.54 380844.40 MWD+IFR-AK-CAZ-SC 4626.22 68.67 106.88 2984.17 2928.27 -950.04 2770.19 5956531.40 380928.93 MWD+IFR-AK-CAZ-SC 4721.33 68.73 107.29 3018.72 2962.82 -976.07 2854.90 5956504.00 381013.20 MWD+IFR-AK-CAZ-SC 4816.33 68.94 106.85 3053.02 2997.12 -1002.07 2939.58 5956476.63 381097.45 MWD+IFR-AK-CAZ-SC 4911.30 68.81 108.28 3087.25 3031.35 -1028.81 3024.04 5956448.53 381181.45 MWD+IFR-AK-CAZ-SC 5007.65 68.93 107.75 3121.98 3066.08 -1056.60 3109.50 5956419.36 381266.45 MWD+IFR-AK-CAZ-SC 5102.79 68.35 107.95 3156.64 3100.74 -1083.76 3193.84 5956390.84 381350.33 MWD+IFR-AK-CAZ-SC 5197.51 67.54 108.16 3192.20 3136.30 -1110.97 3277.31 5956362.28 381433.33 MWD+IFR-AK-CAZ-SC 5292.94 68.41 108.69 3227.99 3172.09 -1138.93 3361.24 5956332.97 381516.79 MWD+IFR-AK-CAZ-SC 5388.21 69.85 107.88 3261.93 3206.03 -1166.86 3445.76 5956303.68 381600.84 MWD+IFR-AK-CAZ-SC 5483.58 70.90 107.60 3293.96 3238.06 -1194.23 3531.32 5956274.93 381685.94 MWD+IFR-AK-CAZ-SC 5578.53 70.64 107.50 3325.23 3269.33 -1221.26 3616.80 5956246.51 381770.96 MWD+IFR-AK-CAZ-SC 5673.73 69.92 108.00 3357.36 3301.46 -1248.58 3702.15 5956217.82 381855.85 MWD+IFR-AK-CAZ-SC 5769.12 69.40 108.55 3390.51 3334.61 -1276.63 3787.08 5956188.40 381940.31 MWD+IFR-AK-CAZ-SC 5864.46 69.41 108.45 3424.05 3368.15 -1304.94 3871.71 5956158.72 382024.47 MWD+IFR-AK-CAZ-SC 5959.28 68.55 107.03 3458.06 3402.16 -1331.91 3956.01 5956130.39 382108.31 MWD+IFR-AK-CAZ-SC 6054.31 68.88 106.57 3492.56 3436.66 -1357.51 4040.78 5956103.42 382192.64 MWD+IFR-AK-CAZ-SC 6149.43 69.48 107.35 3526.37 3470.47 -1383.44 4125.82 5956076.12 382277.25 MWD+IFR-AK-CAZ-SC 6244.70 69.45 108.05 3559.79 3503.89 -1410.57 4210.81 5956047.62 382361.78 MWD+IFR-AK-CAZ-SC 6340.17 69.59 108.16 3593.19 3537.29 -1438.36 4295.82 5956018.46 382446.32 MWD+IFR-AK-CAZ-SC ~ 6435.19 68.95 107.73 3626.82 3570.92 -1465.74 4380.36 5955989.71 382530.40 MWD+IFR-AK-CAZ-SC 6530.42 67.80 109.14 3661.92 3606.02 -1493.73 4464.34 5955960.37 382613.91 MWD+IFR-AK-CAZ-SC 6625.80 66.96 109.28 3698.61 3642.71 -1522.70 4547.48 5955930.06 382696.56 MWD+IFR-AK-CAZ-SC 6720.91 66.19 109.71 3736.42 3680.52 -1551.82 4629.75 5955899.61 382778.34 MWD+IFR-AK-CAZ-SC 6815.75 65.92 109.86 3774.91 3719.01 -1581.16 4711.31 5955868.95 382859.41 MWD+IFR-AK-CAZ-SC 6910.93 67.95 110.81 3812.20 3756.30 -1611.60 4793.42 5955837.19 382941.01 MWD+IFR-AK-CAZ-SC I 7006.07 69.26 111.18 3846.90 3791.00 -1643.34 4876.12 5955804.12 383023.17 MWD+IFR-AK-CAZ-SC 7101.24 68.88 106.69 3880.91 3825.01 -1672.17 4960.17 5955773.93 383106.74 MWD+IFR-AK-CAZ-SC 7196.07 69.47 106.60 3914.63 3858.73 -1697.56 5045.09 5955747.17 383191.23 MWD+IFR-AK-CAZ-SC 7291.15 68.41 106.52 3948.79 3892.89 -1722.85 5130.14 5955720.50 383275.85 MWD+IFR-AK-CAZ-SC 7386.11 69.21 107.16 3983.12 3927.22 -1748.50 5214.88 5955693.49 383360.16 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. l}etc: 2/1/008 Time: 10:49:06 Pa~c: 3 Field: Colville RIVBf Unit Co-~irdinatelNE}Reference: Wetl: CD4-301. True Plorth Site: Nanuq CD4 Vertical (l~~~D}Reference: CD4-301 (19+36.9) 55.9 ~~ell: CD4-301 Section (~'S) Reference: Well (O.OON.O.OOE.84.32Azi) ~~ellpath: CD4-3018 SurveyEalculation}tethod: Minimum Curvature Db: Oracle Survev ~~ MD LuI ,1aim I'U'D Sys ~f~~U 'V/S E/~1' MapA ~1apF: Tool ft deg deg ft ft ft ft ft ft 7481.36 69.13 104.54 4016.99 3961.09 -1772.82 5300.51 5955667.79 383445.38 MWD+IFR-AK-CAZ-SC 7576.34 69.07 103.34 4050.88 3994.98 -1794.19 5386.63 5955645.03 383531.13 MWD+IFR-AK-CAZ-SC i 7671.69 69.81 104.09 4084.36 4028.46 -1815.36 5473.36 5955622.46 383617.49 MWD+IFR-AK-CAZ-SC 7766.87 68.88 104.13 4117.94 4062.04 -1837.07 5559.73 5955599.35 383703.50 MWD+IFR-AK-CAZ-SC 7862.38 68.60 106.00 4152.57 4096.67 -1860.20 5645.68 5955574.83 383789.05 MWD+IFR-AK-CAZ-SC 7957.80 68.48 108.54 4187.49 4131.59 -1886.56 5730.47 5955547.10 383873.40 MWD+IFR-AK-CAZ-SC 8053.14 69.53 109.45 4221.65 4165.75 -1915.54 5814.63 5955516.77 383957.07 MWD+IFR-AK-CAZ-SC 8148.73 68.68 110.66 4255.74 4199.84 -1946.16 5898.52 5955484.80 384040.44 MWD+IFR-AK-CAZ-SC 8243.70 69.13 111.87 4289.92 4234.02 -1978.29 5981.09 5955451.33 384122.48 MWD+IFR-AK-CAZ-SC 8338.95 69.99 110.65 4323.19 4267.29 -2010.65 6064.26 5955417.63 384205.11 MWD+IFR-AK-CAZ-SC 8434.01 72.08 110.01 4354.08 4298.18 -2041.88 6148.56 5955385.04 384288.88 MWD+IFR-AK-CAZ-SC 8528.38 69.80 108.42 4384.90 4329.00 -2071.24 6232.77 5955354.32 384372.60 MWD+IFR-AK-CAZ-SC 8624.08 68.35 108.34 4419.07 4363.17 -2099.43 6317.60 5955324.77 384456.95 MWD+IFR-AK-CAZ-SC 8719.33 67.61 109.01 4454.79 4398.89 -2127.70 6401.25 5955295.15 384540.13 MWD+IFR-AK-CAZ-SC 8815.02 67.95 110.03 4490.97 4435.07 -2157.30 6484.74 5955264.20 384623.12 MWD+IFR-AK-CAZ-SC 8909.68 68.01 110.14 4526.46 4470.56 -2187.44 6567.16 5955232.73 384705.04 MWD+IFR-AK-CAZ-SC 9005.13 68.46 110.39 4561.86 4505.96 -2218.14 6650.32 5955200.69 384787.68 MWD+IFR-AK-CAZ-SC 9100.35 68.61 109.99 4596.70 4540.80 -2248.72 6733.49 5955168.76 384870.33 MWD+IFR-AK-CAZ-SC 9195.23 68.48 109.35 4631.41 4575.51 -2278.45 6816.64 5955137.70 384952.99 MWD+IFR-AK-CAZ-SC 9290.27 68.49 109.25 4666.26 4610.36 -2307.67 6900.09 5955107.13 385035.94 MWD+IFR-AK-CAZ-SC 9385.53 69.00 108.15 4700.80 4644.90 -2336.13 6984.18 5955077.31 385119.56 MWD+IFR-AK-CAZ-SC 9480.98 69.85 107.93 4734.34 4678.44 -2363.81 7069.15 5955048.27 385204.06 MWD+IFR-AK-CAZ-SC 9575.95 69.47 107.92 4767.35 4711.45 -2391.21 7153.87 5955019.49 385288.32 MWD+IFR-AK-CAZ-SC 9595.00 69.41 107.81 4774.04 4718.14 -2396.68 7170.85 5955013.75 385305.21 MWD+IFR-AK-CAZ-SC 9635.80 68.41 107.35 4788.72 4732.82 -2408.18 7207.14 5955001.67 385341.30 MWD+IFR-AK-CAZ-SC 9731.19 66.07 105.63 4825.62 4769.72 -2433.16 7291.47 5954975.33 385425.21 MWD+IFR-AK-CAZ-SC 9826.41 65.96 102.73 4864.34 4808.44 -2454.47 7375.81 5954952.66 385509.18 MWD+IFR-AK-CAZ-SC 9922.37 64.90 99.13 4904.25 4848.35 -2471.02 7461.47 5954934.72 385594.56 MWD+IFR-AK-CAZ-SC 10017.20 63.84 95.35 4945.28 4889,38 -2481.81 7546.27 5954922.56 385679.16 MWD+IFR-AK-CAZ-SC 10112.51 62.43 92.41 4988.36 4932.46 -2487.57 7631.08 5954915.42 385763.86 MWD+IFR-AK-CAZ-SC 10208.09 61.40 89.40 5033.36 4977.46 -2488.92 7715.38 5954912.71 385848.12 MWD+IFR-AK-CAZ-SC 10303.19 60.83 85.94 5079.31 5023.41 -2485.54 7798.56 5954914.74 385931.34 MWD+IFR-AK-CAZ-SC 10398.49 60.56 82.25 5125.97 5070.07 -2476.99 7881.20 5954921.95 386014.10 MWD+IFR-AK-CAZ-SC 10493.70 60.24 78.61 5173.01 5117.11 -2463.24 7962.81 5954934.38 386095.92 MWD+IFR-AK-CAZ-SC 10588.01 59.11 75.09 5220.64 5164.74 -2444.74 8042.07 5954951.59 386175.46 MWD+IFR-AK-CAZ-SC 10683.44 57.86 71.42 5270.53 5214.63 -2421.32 8119.96 5954973.74 386253.71 MWD+IFR-AK-CAZ-SC 10778.63 58.46 67.45 5320.76 5264.86 -2392.92 8195.64 5955000.91 386329.84 MWD+IFR-AK-CAZ-SC 10873.72 58.56 63.61 5370.45 5314.55 -2359.34 8269.42 5955033.29 386404.15 MWD+IFR-AK-CAZ-SC i 10968.62 57.81 59.16 5420.49 5364.59 -2320.74 8340.19 5955070.73 386475.53 MWD+IFR-AK-CAZ-SC 11064.03 57.53 54.56 5471.54 5415.64 -2276.69 8407.67 5955113.67 386543.71 MWD+IFR-AK-CAZ-SC 11159.49 58.84 50.37 5521.88 5465.98 -2227.27 8471.96 5955162.04 386608.78 MWD+IFR-AK-CAZ-SC 11254.40 58.83 45.66 5571.01 5515.11 -2172.97 8532.30 5955215.35 386669.99 MWD+IFR-AK-CAZ-SC 11349.53 59.16 41.24 5620.03 5564.13 -2113.79 8588.35 5955273.61 386726.99 MWD+IFR-AK-CAZ-SC 11444.70 59.63 37.35 5668.50 5612.60 -2050.42 8640.21 5955336.13 386779.86 MWD+IFR-AK-CAZ-SC 11539.92 60.21 34.06 5716.23 5660.33 -1983.52 8688.28 5955402.24 386829.00 MWD+IFR-AK-CAZ-SC 11635.18 60.68 30.31 5763.23 5707.33 -1913.40 8732.40 5955471.62 386874.25 MWD+IFR-AK-CAZ-SC 11730.62 61.31 27.11 5809.52 5753.62 -1840.20 8772.48 5955544.15 386915.51 MWD+IFR-AK-CAZ-SC 11825.06 62.85 23.44 5853.75 5797.85 -1764.76 8808.09 5955619.01 386952.33 MWD+IFR-AK-CAZ-SC 11920.21 63.68 21.63 5896.56 5840.66 -1686.27 8840.65 5955696.95 386986.15 MWD+IFR-AK-CAZ-SC 12015.56 63.00 21.36 5939.34 5883.44 -1606.99 8871.87 5955775.71 387018.66 MWD+IFR-AK-CAZ-SC 12110.90 63.47 20.14 5982.28 5926.38 -1527.38 8902.03 5955854.81 387050.10 MWD+IFR-AK-CAZ-SC 12206.31 63.41 19.28 6024.94 5969.04 -1447.04 8930.81 5955934.66 387080.17 MWD+IFR-AK-CAZ-SC 12301.44 63.02 20.40 6067.81 6011.91 -1367.16 8959.63 5956014.06 387110.28 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: CortacoPhillips Alaska Inc. Bate: 2/1/2008 Time: 10:49:06 Pa~c: -t Ficld: Colville River Unit 'Co-ordiuate(NE)Referrncr. Well: CD4-301, True North Site Nanuq C`J4 VerticalfFy'D)Referencc CD4-301 (19+36.9) 55.9 ~~'cll: CD4-301 Secriou t~"S) Reference: WeEI {O.OON,O.OOE,84.32Azi) ~~ ellpa[h: CD4-301 B Survey Calculation Method: Minimum Curvature Db: Oracle Sung ~1I) Lul Azim f~'D Sys "I'~D N/S El~~' Stap\ ~1:~pF. Tool ft deg deg ft ft ft ft ft ft 12396.68 63.54 20.74 6110.63 6054.73 -1287.52 8989.52 5956093.21 387141.46 MWD+IFR-AK-CAZ-SC 12491.62 63.59 20.32 6152.90 6097.00 -1207.91 9019.33 5956172.32 387172.55 MWD+IFR AK-CAZ-SC 12586.76 63.28 20.94 6195.45 6139.55 -1128.27 9049.31 5956251.45 387203.82 MWD+IFR-AK-CAZ-SC i 12777.54 63.46 21.81 6280.96 6225.06 -969.46 9111.47 5956409.22 387268.54 MWD+IFR-AK-CAZ-SC 12873.12 63.94 22.91 6323.31 6267.41 -890.22 9144.07 5956487.92 387302.41 MWD+IFR-AK-CAZ-SC 12967.76 63.47 23.71 6365.24 6309.34 -812.30 9177.64 5956565.28 387337.24 MWD+IFR-AK-CAZ-SC 13062.22 63.26 21.87 6407.59 6351.69 -734.46 9210.35 5956642.57 387371.20 MWD+IFR-AK-CAZ-SC 13157.24 63.56 19.81 6450.12 6394.22 -655.05 9240.57 5956721.47 387402.71 MWD+IFR-AK-CAZ-SC 13252.42 63.34 18.72 6492.67 6436.77 -574.68 9268.66 5956801.37 387432.09 MWD+IFR-AK-CAZ-SC 13347.59 63.62 18.81 6535.16 6479.26 -494.05 9296.06 5956881.54. 387460.79 MWD+IFR-AK-CAZ-SC 13442.62 63.55 18.20 6577.44 6521.54 -413.34 9323.07 5956961.79 387489.10 MWD+IFR-AK-CAZ-SC 13537.58 65.06 16.24 6618.61 6562.71 -331.61 9348.39 5957043.09 387515.74 MWD+IFR-AK-CAZ-SC 13632:90 66.74 12.76 6657.54 6601.64 -247.39 9370.16 5957126.94 387538.87 MWD+IFR-AK-CAZ-SC 13728.17 67.82 10.26 6694.34 6638.44 -161.29 9387.68 5957212.74 387557.78 MWD+IFR-AK-CAZ-SC 13823.76 69.47 9.33 6729.15 6673.25 -73.56 9402.82 5957300.20 387574.34 MWD+IFR-AK-CAZ-SC 13919.03 71.50 6.46 6760.98 6705.08 15.37 9415.14 5957388.92 387588.10 MWD+IFR-AK-CAZ-SC 14014.48 72.99 3.51 6790.09 6734.19 105.92 9423.03 5957479.32 387597.45 MWD+IFR-AK-CAZ-SC ~ 14109.11 75.17 0.11 6816.05 6760.15 196.85 9425.89 5957570.19 387601.79 MWD+IFR-AK-CAZ-SC 14204.45 76.39 357.85 6839.48 6783.58 289.25 9424.24 5957662.59 387601.63 MWD+IFR-AK-CAZ-SC 14300.56 78.60 355.46 6860.29 6804.39 382.90 9418.75 5957756.31 387597.67 MWD+IFR-AK-CAZ-SC 14395.21 80.23 352.75 6877.68 6821.78 475.44 9409.19 5957848.98 387589.61 MWD+IFR-AK-CAZ-SC 14490.54 83.29 350.00 6891.34 6835.44 568.70 9395.04 5957942.45 387576.97 MWD+IFR-AK-CAZ-SC 14583.96 84.91 347.02 6900.95 6845.05 659.74 9376.53 5958033.78 387559.94 MWD+IFR-AK-CAZ-SC 14679.85 86.64 343.76 6908.01 6852.11 752.26 9352.41 5958126.67 387537.32 MWD+IFR-AK-CAZ-SC 14730.24 88.24 342.89 6910.26 6854.36 800.48 9337.96 5958175.11 387523.66 MWD+IFR-AK-CAZ-SC 14775.91 91.33 344.70 6910.43 6854.53 844.33 9325.22 5958219.16 387511.63 MWD+IFR-AK-CAZ-SC 14823.06 88.92 345.24 6910.33 6854.43 889.87 9313.00 5958264.88 387500.15 MWD+IFR-AK-CAZ-SC 14860.00 88.92 345.24 6911.03 6855.13 925.58 9303.59 5958300.74 387491.32 PROJECTED to TD ~~ i SARAH PAUN, GOVERNOR ~It>•-7~ OITj ~ G~ 333 W. 7th AVENUE, SUITE 100 CO1~T5C' RQA7`I011T COl~il-II55IO1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 C. Alvord - Alpine Drilling T.ead Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Wield, Nanuq Kuparuk Oil Pool, CD4-301B Sundry Number: 308-092 Dear Mr. Alvord: 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, Daniel T. Seamount, Jr. L Chair DATED thi ~ ` day of March, 2008 Encl. „~ .._.. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 20, 2008 RECEIVED Alaska Oil and Gas Conservation Commission MAR 2 1 2008 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 A18Ska Oil 8~ ~ Cons. Commission Re: Application to Re-Enter CD4-301 B (permit no. 207-180) '~~~~ Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Sundry to re-enter well CD4-301 B and resume drilling operations. Well CD4-301 B was sidetracked with the 8-3/4" hole section landed in the Kuparuk sand horizontally. The well was suspended with Intermediate casing cemented in place on January 8, 2008. At the completion of exploration season, Doyon 141 will move onto CD4-301 B and de-complete the well by pulling the kill string set on January 10, 2008. The productive interval will be drilled horizontally and completed as a slotted liner producer. The earliest date anticipated to re-enter CD4-301 B is April 1St Please find attached the information: 1. Form 10-403 Application for sundry approval If you have any questions or require further information, please contact Nina Anderson at 265-6403, Liz Galiunas at 265-6247 or Chip Alvord at 265-6120. Si ly, /~ ~ Ni Anderson Dr ling Engineer Attachments cc: CD4-301A Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Liz Galiunas ATO 1702 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation ConocoPhillips ~ ~,~~,~~ RECEIVED ~ _ ~ STATE OF ALASKA ~~~, MAR 2 '4~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ APPLICATION FOR SUNDRY APPROVA~I~s~a ~ & Gas Cons. 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Ext r~~l,Y ~~ ~ ~~ y ~ lUe l1 ~ . Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter 9u~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development 0 Exploratory ^ ~ 207-180 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20557-02 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y2S ^ NO Q CD4-301 B 9. Property Designatiorr. , .V 10. KB Elevation (ft): 11. Field/Pool(s): ~ ~~ADL 380077, 384211, 372097, 380082 MSL 56', 36' RKB Colville River Field, Nanuq Kuparuk 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): 14860' 6911' 2845' 2315' Casing Length Size MD TVD Burst Collapse Conductor g0' 16" 114' 114' Surface 2999' 9-5/8" 3035' 2387' Intermediate 14819' 7" 14855' 6911' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 3.5" kill strip 9.3# 2845' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV 13. Attachments: Description Summary of Proposal ^ 14. Well Class aft~~- proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: April ~, 2oos 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: Nina Anderson @ 265-6403 Printed Name C. AIVOrd Title: Alpine Drilling Lead Engineer Signature Phone 265-6120 Date jr(~~ ~®„~~,; Commission Use Onl Sundry Number: ~ i t ti C diti f l N tif C i th t it ~~~' Q~ o approva a represen a on ons o : o y omm ss on so a ve may w ness Clearance ^ Plug Integrity ^ BOP Test `~ Mechanical Integrity Test ^ Location ' Other. 35 V® ~S \ ~o~ ~S~ . ~" LOK3l~•c7E`-S O~ ~V \-\ ~~J ~ \ \ ~~~ t Subsequent Form Required: ~V~ APPROV D BY ~ ~~ c, jJ Approved by: gAMIS I T Date: Form 10- ev' ed 06/20 ~` ~. ~ Submit in Duplicate g~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Data: CD4-301B March 19, 2008 AK-MW-535576 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: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API# : 5 0-103 -205 5 7-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~ Date: ~~ ~` }~`'~~~' j,,~~„ _. Signed: ~0`~-1~~~(~D(o~ ~ ~ 05-Mar-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-301 B Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 9,575.95' MD Window /Kickoff Survey: 9,595.00' MD (if applicable) Projected Survey: 14,860.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 /~ ~ ~ , „ /~ Date f /"IAvI..DUV ~d Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~.o~ - ~ 8a l~ , ' -' ~l -.a Date 1/24/2008 Class INFORMATION Category Information Request Subj. Doug Hastings Start 3:00:19 PM End 4:52:55 PM Priority ~- PTD /Proj BrooksRg Sundry No. ~- Applications TASK LIST PSP PPT P J roj Current - - Proi$ t Note ad EmaN Home Pa a Calendar Description New development welts request. 100% UIC 30%UIC Notes: Follow-up Needed Contact - 2nd ~- Ceii - 2nd ~- Company: ~- Fax - 2nd ~- Tele - 2nd Email: well Log Directories ,j...~ 2008 Docs Read Tea Geology ac ~~~~~~ CO's Notices FiekllPool Gooale Naturally Speaking Permitting 401 Leds~er 407 Ledger 401's Duplica PTD Text LAS Mapper Quads t to Mud Wt. H2S STab~e Orders RE Info Requests Database Find Stuff Contact State Employee Finder Project Report C Reporting Weekly Weekly Summary Ltr V ~~~ ~~~ ~ ~~ Contact -1st ~- Ceii -Primary Company: ~- Fax -Primary ~- Tele -Primary ~- Emaii STATE OF ALASKA ~ ~ 2~1~b ALASKA OIL AND GAS CONSF,RVATION COMMISSION W. 7th Ave. Suite 100 ANCHORAGE, ALASKA 99501-3192 REQUEST FOR EXAMINATION OF AOGCC RECORDS 1, the undersigned, request that I be authorized to examine the AOGCC records listed below, [agree not to remove or alter the contents of records and 1 agree not to remove the records from the room designated for examination. I, certify that lam nei~er a party, nor representing or acting on behalf of a party, involved in litigation in a judicial or administrative forum with the State Alaska or public agency to which these records are relevant. Signature: Printed name: Company/Firm: Address: AOGCC RECORDS REQUESTED Phone No: _j 3 ~ T~rl'lo ~~ C ~ - 3a/ ~ FOR AOGCC USE ONLY: Date and Time Records Requested (6 AAC 96.320): Date and Notice of Receipt of Request Sent (6 AAC 96.3 l0): Date Additional Information Requested (6 AAC 96.315): Date and Time Records Provided for Review: Date and Time Records Returned: Name of AOGCC Employee Handling Request: AOGCC will respond to this request as soon a practicable, but no later than the 10th working day after the request is received (6 AAC 96.325) This request is a public record. (6 AAC 96.320) \\ Common\l_ibrary\Request for Examination of Records Form.doc SARAH PAL/N, GOVERNOR 7~T S~ ~~ ~ ~ 333 W. 7th AVENUE, SUITE 100 COl`S~R~~iiDis CQ~II,5SI~1` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 C. Alvord WNS Drilling Team Lead Conoco Phillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 Re: .Colville RiverField, Nanuq Kuparuk Oil Pool, CD4-301B Conoco Phillips Alaska, Inc Permit No: 207-180 Surface Location: 2882 FNL, 70 FEL, SEC.24, T11N R4E Bottomhole Location: 2491 FNL, 2381 FEL, SEC 17, T11N R5E Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness y required test, contact the Commission's petroleum field inspector at (90;~~j~6~9-3607 (pager). DATED thist~ day of December, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Z1~'~,~'1 ~ PERMIT TO DRILL ~~ 20 AAC 25.005 1a. Type of Work: , 1b. Current Well Class: Exploratory ^ Development Oil ^/ ' 1c. Specify'rfwell is proposed for. Drill ^ Re-driA ^ Siratigraphic Test ^ Service ^ Development Gas ^ Coalbed Methane ~as Hydrates ^ Re-entry ^ Multiple Zone ^ Single Zone ^ Shale Gas ^ 2.Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180' CD4-3016 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 ~ MD: 19813' ND: 6920' ~ Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: '~ ~ ~ Nanuq Kuparuk Oil Pool Surface: 2882 FNL, 70 FEL, Sec. 24 , T 11 N R 4 E ADL 380077, 384211, 372097, 380082 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2005 FNL, 1000 FEL, Sec. 20 , T 11 N R 5 E LAS2112 12/31/2007 ~ Total Depth: 9. Acres in Property: 14. Distance to Nearest Property L3 ~ 1 86 2491' FNL, 2381 FEL, Sec. 17 , T 11 N R 5 E 5759 p$Z ~ /~ 3f. ~ 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well within Pool: s Surface: x- 378174.73 ' y- 5957526.12 Zone- 4 (Fleignt above G~): 55.9 MSL CD4-302 3610.8' at 14225' MD 16. Deviated wells: Kickoff depth: 9600 ft. 17. Maximum Antiapated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90° deg Downhole: 3778 psig Surface: 3086 psig ' 18. Casing Program Setting Depth Quantity of Cement Specifications Bottom T or sacks c f Size op . . Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 24" 16" 62.5# H-40 Welded 77 37 37 114 114' pre-installed 12.25" 9-5/8" 40# L-80 BTC 3009 37 37 3046 2387 389 sx AS Lite, 259 sx 15.8 G ~" 8.75" 7" 26# L-80 BTCM 14903 37 37 14940 6920 481 sx Class G, 1855 Sx class G for K2 r 3.5" 9.3# L-80 EUE 14768 32 32 14800 6869 tubing 6.125" 3.5" 9.3# L-80 SLHT 5023 ~ 14790 6869 19813 ~ 6920 ~ Slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural 77.00 16" 114 114.00 Surface 3,009,00 9-518" 389 sx AS Lite, 259 sx 15.8 G 3046 2,387.00 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling program Q Time v. Depth Plot ^ Shallow Hazard Analysis ^/ Property Plat ^ Diverter Sketch^ Seabed Report ^ Drilling Fluid Program 0 20 AAC 25.050 requiremenis 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact N Woods Printed Name C. Ivord Title WNS Drilling Team Lead Signature .~~.Q Phon265-6120 Date 1zn9/2007 ~/'~ ~ Commission Use Only " Permit to Drill API Number. Permit Approval See er letter Number: ~~ _ ~~ 50- ~~~ ~ L.~y ~ S ~ ~ Date: ~~ ~, ~ fo oth requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed me ane, gas hydrates, o gas Mained in shales: ^ N [~ Y 'd o es : Samples req'd: Yes ^ No ud I req ~, ~~~ _t~,,,~ H2S measures: Yes ^ No [~ recti r Yes P^ ^ Other: ~~~ ~ O Q ROVED BY THE COMMISSION r ^ (` ,COMMISSIONER DATE: nrm evrse , , mi m up ica e ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ~Qt1G1CQ h1~li~JS December 31, 2007 Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 ~~,~~~ ~~ ~ ±;' ~ ZOOM Re:Application for permit to dri{I: CD4301 B Dear Sir or Madam: '`~~~ ~ ~~!r:~ Sl gyn9n 1da11 iltflsc7~Q1" c'i~e^Y ~~:x'3 ~i ~'? ~. ConocoPhillips Alaska, Inc. hereby applies for a Permit to change the approved program for CD4-301 B. The intended start date for this work is 01/01/2008. Operations for CD4-301A began on December 21st, 2007 with Doyon 19. While drilling .the intermediate section on December 23rd, operations encountered an over pressured Kuparuk formation. Per well control guidelines, CD4-301A was shut in and monitored at surface. Circulation was shortly resumed following stabilized well conditions at which time the wellbore packed off and circulation was lost. The BHA was stuck in the hole and It was decided to plug back the existing well bore with cement and sidetrack to another in board location west of the previous location (CD4-301 B).'+~j° K~c~t~~u.~~' The old wellbore, .CD4-301A will be abandoned with a cement plug which will also cover the Nanuq ~~ ~~, 3~, e sands. An additional plug wilt be set for kicking off. (See sundry application submitted 12-31-07 for more information). A mud gap will be left between the kick off plug and the abandonment plug. The welt, CD4-301 B, will be kicked off at approximately 9,600' MD and re-landed in the Kuparuk C sand horizontally. After setting and cementing 7" intermediate casing, the well will be suspended and Doyon 19 will move to CD3 to optimize drilling time during the short ice road season. The horizontal section will be drilled by either Doyon 19 or 141 later and completed as a slotted liner producer. The well will be flowed back to mitigate formation damage and then be closed in awaiting completion of well work for the well to begin production. It is expected that both the K2 (Qannik) and the Nanuq sand will be considered a significant hydrocarbon bearing zone. The Nanuq sand will be cemented 500' above top of the sand with the primary cement job. For the Qannik sand (K2), it is planned to use a stage tool for a two stage cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. The 8-3/4" plugged back hole will maintain the name CD4-301A and once re-drilled the new sidetracked hole will become CD4-301 B with an API extension -02. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed plug back schematic 5. Proposed completion schematic 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directions{ drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 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 Nina Woods at 265- 6403, Liz Galiunas at 265-6247, or Chip Alvord at 265-6120. Sincerely, Nina Woods Drilling Engineer Attachments cc: CD4-301A Welf File /Sharon Allsup DrakeATO 1530 Chip AlvordATO 1577 Vern JohnsonATO 1702 Jack WalkerATO 1740 Lanston Chin Kuukpik Corporation L~ ~ 1 U CD4-301 B Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 8-3/4" Hole / 7" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 10.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control practices, mud scaven ers 6-1 /8" Hole /Horizontal Production Hole Event Risk Leve! Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium ROPE drills, Keep mud weight above 10.6 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers Nanuk-Kuparuk : CD4-301 B Procedure 1. Pick up and run in hole with 8-3/4" drilling BHA. 2. Kick off old wellbore at +/- 9,600' MD and drill 8-3/4" hole to intermediate casing point in the Kuparuk C sand +/- 14,940' MD. (LWD Program: GR/RES/PWD) 3. Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 4. Pick up and run +/- 1500' 4-1/2" tubing as a circulation string. 5. Pick up hanger, land hanger, run in lock down screws and test seals to 5000 psi. 6. Set and test two way check. 7. Nipple down BOP. 8. Nipple up and test tree. 9. Pull two way check. 10. Displace to diesel freeze protection through tubing string. 11. Set back pressure valve. 12. Rig down and move off Doyon 19. 13. Return to well with either Doyon 19 or Doyon 141. 14. Nipple down tree and nipple up BOP 15. BOPE test to 3500 psi. 16. Displace diesel to brine through circulation string. 17. Pull 4-1/2" tubing string and lay down same. 18. Pick up cleanout assembly and run in hole. 19. Clean out stage collar and float shoe. 20. Test 7" casing to 3500 psi and pull out of hole. 21. Run drilling assembly. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 22. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 23. Circulate the hole clean and pull out of hole. 24. Run lower completion of 3-'/", 9.3# L-80 SLHT blank and slotted liner and liner hanger. 25. Run upper completion of 3-'/z, 9.3#, L-80 tubing with SSSV, packer, 3 GLMs with shear out valve in bottom mandrel, XN profile and wireline entry guide. Land hanger. 26. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 27. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove Z way check. 28. Circulate tubing to diesel and install freeze protection in the annulus. 29. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 30. Shear valve in the gas lift mandrel. 31. Set BPV and secure well. Move rig off. Post rig well work will include pulling the ball and rod assembly, and GLV change out. Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD4-302 is the nearest existing well to the CD4-301 B plan with 8.6' well to well separation at 523' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting and low reservoir pressure within the Kuparuk reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD4-3016 will be injected into a permitted annulus on CD4 pad or the class 2 disposal well on CD1 pad. The CD4-301 B surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zones are the Nanuq, Kuparuk, and the Qannik reservoir. There will be 500' of cement fill above the top of the Nanuq and Qannik reservoirs. Upon completion of CD4-301A form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) ` (Surf. Shoe TVD} + 1,500 psi _ (12.0 ppg) ~ (0.052) * (2387') + 1,500 psi = 2989 psi Pore Pressure = 1,086 psi Therefore Differential = 2989 - 1086 = 1903 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: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi DRILLING FLUID PROGRAM Intermediate hole to 7" casin oint - 8 3/" Production Hole Section - 6 1/8" Density 10.6-11 ppg 10.6 ppg PV 10 - 25 10 -15 YP 15 - 25 25 -30 Funnel Viscosity Initial Gels 4 - 8 10-15 10 minute gels <18 12-20 API Filtrate 4 - 12 cc/30 min NA HPHT Fluid Loss at (drilling) 12-14 cc/30 min 160 9.0 - 10.0 9.0-9.5 PH 6% KCL 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 reservoir is penetrated. Maintain mud weight at or below 10.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with t 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. CD4-301A Plugback Schematic RKB-GL=36.3' 10.8 ppg drilling mud in hole 9,404 KOP 9,600' ~~, 2 ~~~Li~ ~~ 10 004 30 bbls Hi Vis Pill ~lpdated 12f31t0~ Wellhead 16" Conductor to 114' 9-5/8" 40 ppf J-80 BTCM Surface Casing @ 3046' MD / 2387' TVD cemented to surface Plug #2:600' Kick off nlug Top at +!- 9404' MD 17.0 pna. 4 X200 ft x~ Tca ~tanu t~escrvoir a ~ Plug #1 : +/- 700' Ton (7a +{_12 855° _ 1 428' MD ~'ILtg ~"~'' 728 +/- 12.700' MD 17.0 nna (c, ' ~ ~~ BHA Fish TOF 13445' BOF 15319' Hole @ +/- 85 deg TD at +/- 15,431' MD Completion Schematic Planned CD4 - 301 B Nanuq Kuparuk Producer Completion 12-31-07 16" Insulated Conductor to ~-114' 2 Jts 4-''/z' 12.6 ppf L-801ST Mod Tubing 3-'/i' X 4-'/~" Cross over 13" TRMAXX-5E SSSV 9-5/8" 40 ppf L-80 BTCM Surface Casing 3046' MD / 2387' TVD 3-%2' 9.3 ppf L-80 EUE Mod Tubing 7~ J Cement to +/- 7160' ~; MD / 3901' TVD ?" Qannik interval top +/- 7660' MD / 4080' TVD Stage '~ ; cementin to ol ~ g +l-8188'MD/ 4270' TVD Top of cement ~ 12365' MD / 6004' TVD (+!- 500' above Nanuq) Top Reservoir at +/- Nanuq 12874' MD / 6206' TVD Kuparuk 14818' MD / 6916' TVD 7" 26 ppf L-80 BTC Mod Production Casing +/-90° 14940' MD, 6920' TVD Sperry sun Direcfic~nal Plan WP07 2{3'i Ifl7 Uoo er Completion: Too MD TVD Item 1) Tubing Hanger 32' 32' 2) 4-''/i' 12.6 #/ft IBT-Mod Tubing 2 jts 3) 3 Y" X 4-%" Crossover 4) 3-Yi' 9.3 #/ft EUE-M Tubing 5) Camco TRMAXX SCSSSV W/ X profile (2.812") 2207' 2000' 6) 3-'/" 9.3 #!ft EUE-M Tubing 7) Camco KBMG GLM 5796' 3400' 8) 3-''/i' 9.3 #/ft EUE-M Tubing 9) Camco KBMG GLM 11472' 5600' 10) 3-%" 9.3 #!ft EUE-M Tubing 11) Camco KBMG GLM 13640' 6513' With DCk-2 shear out valve (pinned for 3000 psi) 12) 3-%" 9.3 #/ft EUE-M Tubing (2) 13) Baker Premier Packer 13720' 6546' 14) 3 Y~' 9.3 #/ft EUE-M Tubing (2) 15) NES "XN" (2.725 Min ID")- 65° inc 13800' 6579' 16) 3-%' 9.3 #/ft EUE-M Tubing 17) BOT Stinger w! fluted WLEG/ pup/shear sub 14787' 6869' 3' space out above top of liner Lower Completion: Top MD TVD Item 18) Baker 5" x 7" Flexlock Liner Hanger 14790' 6869' 19) 3-%', 9.3#/ft, SLHT Tubing +/- 3 jts 20) 3-Yz" 9.3 #/ft, SLHT liner w/ blank across shale and slots across sand 21) Baker Shoe 19803' 6920' 3-%' 9.3#/ft L-80 SLHT Mod Slotted liner Pattern: 8 slots / ft, 2-'/." x 1/8" slots TD 6-1l8" hole 19813' MD / 6920' TVD C D4-301 A PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 3035 / 2387 14.5 1080 1561 7" / TD 14940 / 6916 16.0 3778 3086 N/A 19813 / 6920 16.0 3778 N/A NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP=[(FGx0.052)-0.1]D Where:ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where;FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D _ [(10.9x0.052}-0.1]x 114=53 psi OR ASP =FPP - (0.1 x D) = 1080 - (0.1 x 2387') = 841 psi 2.Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1 ] x 2387 = 1561 psi OR ASP =FPP - (0.1 x D) = 3778 - (0.1 x 6916') = 3086 psi 3.Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3778 - (0.1 x 6920) = 3086 psi Cementing Program: 7" Intermediate Casing run to 14940' MD / 6920' TVD Cement from 14940' MD to 12374 +/-' MD (minimum 500' MD above top of Nanuq reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (14940' - 12374') X 0.1503 ft3/ft X 1.4 (40% excess) = 539.9 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 539.9 + 17.2 = 557.1 ft3 => 481 Sx @ 1.16 ft3/sk System: 481 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 1.16 ft3/sk Second Stage: Cement from ports in a ES stage collar set 500' below the K2 interval to +/- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (8188'- 7160') X 0.1503 ft3/ft X 1.4 (40% excess) = 216.3 ft3 annular vol. Total Volume = 216.3 ft3 => 185 Sk @ 1.17 ft3/sk System: 185 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk Operator: ConocoPhllllps(Alaska) Inc. •WNS Grid Correction: - •0.93 lob No: #N/A Feld: Western Noth Slope Magnetic Declination: 22.29 Datum NAD 27: Weli: CD4.301Bwp07 Plan Dip: 80.66 API No: #N(A RIg: #N/A Dngleg per: 100 ft North Reference: TRUE Surface Location Original V5 Plane: 344.00 Parent Weil: Rig: CD4.301 X: 378174.73 ri View VS Plane: 344.00 RKB Height: 55.90 ff Y: 5957526.12 9 Meas. Incl. TNUE ,-_sec ., , cal - Dogleg cJriGinol _ .mac 8uilc Turn Course Drilled Depth (K) Angle Ide91 Ari.. (deg) f`~~~::i tk'0 rnt ~,5{-j E{+}/W(-) (i4) 'S1~" ,4 Y; E{+}/W(-} Dep. (X} Sever:: Fy I°/700 fP. VS (:344"} (131 ?'c~cn ,ar,5?7 I°/100 fti ('1900 K} Leng}h (ft) Distance (R) Q' Comments 100.00 O.S. 43.56 44_' .. ;>r' ~ ' ~. 3 "~ "; ,>~,,.;fi 378775.06 ~ -:; 6.Ci3 200.00 0.92 143.45 .44 :'% 74..a 1.55 ~ .;i]:i 378376.28 0.4r' -0.50 47 OA': 19.90 100.00 700.00 CB-GYRO-SS (1) 300.00 1.87 177.73 :4~ ,) :'4,98 -I" 3.78 9 1:.05 37$778.49 ' 00 -2.02 27 0.95 74.28 100.00 200.00 400.00 4.11 126.46 34392 399.82 -3.rr, 8.72 59575"_2.1 378782.79 22:3 -5.98 75 2.24 8.33 100.00 300.00 500.00 6.28 730.75 -~143.SC 499,45} -/.:i2 15.20 751 o.:3f 378189.77 2.20 -13.35 72 2.17 4.09 100.00 400.00 MWD+IFR-AK-CAZ-SC (2) 600.00 8.32 127.37 1 : 598.59 1 ci ~°,: 25.56 ). 7 378200.07 2.3^_ -23,21 •33 2 ~4 -8.78 100.00 500.00 700.00 9.14 175.16 .l -. 897.43 Q3.9o 38.92 „4 378273.26 :.25 •33.76 •52 0.8"< •6.21 100.00 600.00 800.00 9.35 104.87 74ti2~ 74o.ya ~3C.r,~9 55.76 - 378227.94 C.88 •43J4 •74 0.27 -5.35 100.00 700.00 900.00 10.94 709.75 --5..',% -s.;.9c: 70.36 z:9.O3 378244.56 7.59 -53.96 -5 7.,59 -0.66 100.00 800.00 1000.00 14.07 117.74 vsh.29 -45.58 90.62 5,.015 378264.6$ 3.18 -66.87 12- 3.13 264 100.00 900.00 1100.00 17.30 173.5& .s..". =.C4 775.54 " ;,21 3"18289.38 5.27 -83.84 9 3.23 1.79 100.00 1000.00 7200.00 19.71 11tlJ7 .2~ : -6597 744,94 -.;1 378318.5& 2.57 •763.37 ''..4 •2.81 100.00 1100.00 1300.00 23.67 >p9.bA -7t3J'r. 779.62 "i 378353.05' 398 -125.78 -6 3.96 •1,09 100.00 1200.00 1400.00 27.17 170.30 274.95 .'6 378393.73 3.Si -75'6.42 3.50 O.b2 100.00 1300.00 7500.00 29.08 171.75 ,svE~ ' -I 10'.9 264.63 3'78433.94 +5 •7 78.67 72 1.91 0.85 100.00 1400.00 1600.00 30.27 716.94 -12 .?;:% 370.24 378482.85 15' •268.44 I.IH •0.21 100.00 1500.00 1700.00 33.68 710.62 .. 7626.37 -146.6 ~:~ 359.74 ,..... 378532.04 3.41 •240.73 .. -3 , t •0.32 100.00 1600.00 1800.00 37.28 109.*$ ~~ 'r -i55.3r 474.32 „>;; 'i 3785&6.29 3.70 -274.13 ?d •74 3.oC •7.44 100.00 1700.00 1900.00 39.87 797.54 :.i ~;% 7785.96 1;5.98 473,49 ;.: 4:t'~ 378645.74 ~-'8 -309.30 -22 2.5'1 •l.bb 100.00 1800.00 2000.00 43.64 107.63 "~41^: 7&60.5^ '1'06 C 535,97 S.i 37870$.2& •346.13 3.17 0.04 100.00 1900.00 2100.00 47.93 107.99 ~-1..:17 ?9&4.27 ",~tr.';.G2 605.78 378776.13 43:] •3&6.07 4 4.29 0.36 100.00 2000.00 2200.00 50.60 108.64 :,?.62 149.5.52 51 ?4 677.77 5157263.355 378&47.66 2J2 •428.73 77 2.67 O.bS 100.00 2100.00 2300.00 53.13 109.32 7 751.48 378921.67 2 59 •473.82 72 2.53 O.dB 100.00 2200.00 2400.00 56.57 108.43 < ;., 43 828.72 i, '. 378498.47 3.45 -520.84 -5 3.44 -039 100.00 2300.00 2500.00 59.72 107.35 _ ~. 1 1 -'~ 904.43 379078.67 3.42 -568.50 3.15 -3.58 100.00 2400.00 2600.00 62.21 106.55 ~ n`.: x.23 +56.V! 993&6 ,,~,;;' 1 374761.8& 259 -676,05 -'S 249 -D.BD 100.00 2500.00 2700.00 65.53 107.41 ~~!.'% -3?_'.;~3 7078.97 ..3;s 379247.29 3.41 -664.92 73 3.::2 0,86 100.00 2600.00 2800.00 67.98 148.03 ~?4sJ3 -- -- ~~410.:3C 7166.42 - I 379334.34 2.52 •715.92 12. 2.:5 0.62 100.00 2700.00 2900.00 68.10 147.12 -"__°~l!3 -4:18:: 1254.84 379422.29 0.85 -767.21 -32 0.12 •0.91 100.00 2800.00 3000.00 68.00 707,84 %~i8. 1 -4:;^.b 7343.31 .x8.21 374570.24 '~.6fi -878.38 ., S"1 -6.10 0.72 100.00 2900.00 b. 107.24 `i%' -~0.79.J'? 1383,98 ' '7 379556.75 '.21 -841.94 ? -8& 0.^:4 •1.30 46.00 2946.00 9-5/8"x12-1/4"TD 3100.00 67.99 708.67 -493.50 1437.88 - - ' 379598.47 .Ofi -&64.18 -93 -6.06 .7.17 54.00 3000.00 3200.00 66.88 147.2$ r:.33 1520.21 r ?; .,; i 3796&6.29 127 •979.38 751 -'.11 0.67 100.00 3100.00 3300.00 67.96 70'7.47 s'.'£i ~48~i7 7648.27 a :.62 379773.$2 .25 •9%0.51 37 1:)8 0.69 100.00 3200.00 3400.00 68.26 108.25 2470:'i'~. 2E .91 d>.%;%.3 7696.46 -? ti921.Fi5 37488L54 :0.40 -1022.54 47 0.30 0.28 100.00 3300.00 3500.00 68.85 708.52 5;16." 2:~ ?.47 -60<:.~r~7 1784.73 95( ;9(:.57 , 379944.37 0.64 -7075.17 , 23 0.59 0.27 100.00 5400.00 3600.00 69.12 109.77 2(142.43 2598....1 -535.F?2. 7873.07 5`?5f F5.53.93 380037.22 0.66 •7728.44 di 86 0.27 O.bS 100.00 3500,00 3700.00 68.62 109.00 "578.41! 2634.38 -Gz;7.3"<. 7967.22 ,1956E%7 ~~6 380724.86 0.52 -1782.06 -162 -0.50 -0.17 100.00 3600.00 3800.00 67.90 709.57 261`.1.52. 2677,4'x. -u9;%.99 2048.89 595C>;94.96 380272.03 0.89 -1235.77 744 -0.72 0.57 100.00 3700.00 3900.00 67.24 704.80 ':'(ias.ti8 2764.58 -729.':3 2739.93 9^;n76:.`.42 380298.54 O.c9 -7289.63 76`:. -0.66 0.23 700.00 3800.00 4000.00 66.66 710.02 2692.;53 2748.73 -760.4E 2222.44 5955729,L?i 3803&4.54 0.61 -7343.60 Tat -0.58 0.22 100.00 3900.00. 4100.00 66.84 770.40 '::7:5'1.30 2788.26 -79::%.I1 2308.66 6^96.^::~ 380470,23 6.39 -1397,88 d3 0.18 0.38 100.00 4000.00 4200.00 67.71 770.65 ?li'O.c%3 2A26.fl3 -82%:.55 2345.05 .5956612.81 386556.6& 0.90 •1452.77 15 07 0.25 100.00 4100.00 4300.00 68.36 109.59 _:308.';, 2864.24 -856 <4 2482.13 59 cb^_';>.°~0 380$42,63 1.18 •7567,44 -57 U.65 -7.Ob 100.00 4200.00 4400.00 67.84 168.86 i.~'; ..54 .2:40':.64 -8£i .00 2569.73 ),15'9).53 380729.73 (:'.85 -7560.46 •123 -0.52 -0.73 100.00 4300.00 4500.00 68.44 767.53 2938.7' ~ 159' 2657.40 ~ 380877.47 -1673.71 -R4 U.60 •1.33 100.00 4400.00 ~I t J Plan Page 1 of 4 (CD4-301 Bwp07 (NAD 27).zls) 12/31/2007 3:19 PM Meas. Incl. TRUE ..ubsc=a RF;d col - ealeg Original ..,<.. 9vild Turn Course Drilled Depth (fF) Angle (deg) azi, {deg) iY': ?VO its} ~,1+r~~~j (lt) [(+}(W(-) (8) ~: 1;~~ 'I ~'Ti [(+)jW{.) DeP~ {~ Sever;ty f°iICD f'.; VS [344"} (ft) ... ('1C0 Yt; ("1704 h} Length (fi) Distance (H) Comments O 4600.00 68.74 14fi.87 ",19.33 2975.28 -'43,5"~ 2746.84 -9SGSa8.':o 380405.89 v".G8 •i 464.09 0.30 -O.bb 100.00 4500.00 4700.00 68.72 707,20 c'S5.6:: 3021.55 -97C °~"v 2835.94 9w E C9.4i 384994.53 0.37 -1774.89 -C.02 0.33 100.00 4600.00 4800.00 68.90 144.93 1811 ) 998.iG 2925,07 G ,1111 387083.21 Gsl •1745.74 0.18 -0.27 100.00 4700.00 4900.00 68.82 708.17 ~:'J.8'7 F 'G.24 3474.41 t~<151 ^" 38]772.49 ':.10 -1877.27 44 -0:03 1.78 100.00 4800.00 5000.00 68.92 107.79 )f~~3.97 _ ~ :054.99 3202.7§ '~95G42091 382259.94 0.31 -7869.34 -72 O.IC -0.32 100.00 4900.00 5100.00 68.37 207.94 ,, ,tr.;:;y :;;33.56 3192.39 :..: t.. A'? 387348.17 JS7 -1927.26 ldb -CSS 0.15 700.00 5000.00 5200.00 67.56 P 08. T 7 ,' 35 3 ? ~;~ 7 1229 3274.52 - , 5:is 5!, . ," 381435.76 0.84 -7 973.16 € b5 ii F l 0.23 100.00 5100.00 5300.00 68.52 108,43 , i4 3237.' 8 -:141 .Sfi 33b7.S2 r c .; - 381523.28 i)5 -2025.56 24 095 0.46 100.00 5200.00 5400.00 69.98 147.85 3""<.7i?-G7 32&6.57 -I 77;.:a-3 3456.33 'rSG:'99.:r:i 382631.63 1.G3 -2078.77 -27 1.46 -0.78 100.00 5300.00 5500.00 70.86 707.58 3.''~~i3 33:0^8 -:199.5:; 3S4d.0$ olc,:!.23 381740.$8 092 -2330.47 •'€4 0.;,43 -0.27 100.00 5400.00 5600.00 70.48 147.67 z ';.%,3 3933.18 -`22i~;?c 3434.03 r S. sJ.;;; 382790.35 0.38 •2282.68 174 -:!.3Fi 0.03 100.00 5500.00 5700.00 69.78 108.55 371%7.7r ~:b.itY 3725.53 ::1: 1;.92 387879.37 0.86 -2235.11 744 0.54 100.00 5600.00 5800.00 69.40 ?48.52 < 3402.OS '2EL.:?(> 3814.50 ,:.,l, d::;:) 382967.85 0.51 -2287.97 338 ;; 38 D.37 100.00 5700.00 5900.00 69.09 707.92 5 'r 31a7.d8 31F S: ?903.32 I<.. 382464.78 C64 -2340.56 179 :'31 -0.60 100.00 5600.00 6000.00 68.69 104.83 t 6.. ,7 "" "' Y :.;=3,47 3992.35 ,,,,>, l,. ;:. 382144.75 ,15 -2391.88 ., r2 _r .,.40 -7.04 100.00 5900.00 6100.00 69.17 20695 i3..i 3'. J.-; 4081.64 ~;;).37 382233.59 0.49 -2442.55 E3 0.48 0.72 100.00 6000.00 6200.00 69.46 107.72 ?,..-, '? 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# 90 90 . 0 00 . 0.00 . 100.00 16500.00 16600.00 90.00 343.70 6864.89 6920.79 2591.81 8808.35 5959974.62 387023.99 0.01 6 . . 0 00 00 0 100 00 16600.00 16700.00 90.00 343.70 6864.89 6920.79 2687.79 8780.28 5960071.04 306997.48 0.01 163.49 49 263 # # 90 90 . 0 00 . 0.00 . 100.00 16700.00 16800.00 90.00 343.70 6864.89 6920.79 2763.77 8752.21 5960167.47 386970.97 0.01 . # 90 . 0 00 0 00 100.00 16800.00 16900.00 90.00 343.70 6864.89 6920.79 2879.75 8724.15 5960263.89 386944.47 0.01 363.49 48 463 # 90 . 00 0 . 0.00 100.00 16900.00 17000.00 90.00 343.70 6864.89 6920.79 2975.73 8696.08 5960360.31 386917.96 0.01 . . 00 0 00 0 100 00 17000.00 17100.00 90.00 343.70 6864.89 6920.79 3071.71 8668.01 5960456.74 386891.A6 0.01 563.48 # 90 90 . 00 0 . 00 0 . 100 00 17100.00 17200.00 90.00 343.70 6564.89 6920.79 3167.69 8639.95 5960553.1E 386864.95 0.01 01 0 663.48 763 48 # # 90 . 0.00 . 0.00 . 100.00 17200.00 17300.00 90.00 343.70 6864.89 6920.79 3263.67 8611.88 5460649.58 386838.45 . . 0 00 00 0 00 100 17300.00 17400.00 90.00 343.70 6864.89 6920.79 3359.65 8583.81 5960746.01 386811.94 0.01 863.48 48 963 # # 90 90 . 0 00 . 0.00 . 100.00 17400.00 17500.00 90.00 343.70 6864.89 6920.79 3455.63 8555.75 5960842.43 386785.44 0.01 . . 00 0 0 00 00 100 17500.00 17600.00 90.00 343.70 6864.89 6420.79 3551.61 8527.68 5960438.85 386758.93 0.01 1063.48 47 3 # # 90 90 . 00 0 . 00 0 . 100.00 17600.00 17700.00 90.00 343.70 6864.89 6920.79 3647.59 8499.61 5961035.28 386732.43 0.01 116 . . 0 00 . 00 0 00 100 17700.00 17800.00 90.00 343.70 6864.89 6920.79 3743.57 8471.55 5961131.70 386705.92 0.01 0 1263.47 47 1363 # # 90 90 . 00 0 . 0.00 . 100.00 17800.00 17900.00 90.00 343.70 6864.89 6920.79 3839.56 8443.48 5961228.12 386679.42 1 0. . . 0 00 00 0 100 00 17900.00 18000.00 90.00 343.70 6864.89 6920.79 3935.54 8415.41 5961324.55 386652.41 0.01 1463.47 47 1 3 # # 90 90 . 0 00 . 0.00 . 100.00 18000.00 18100.00 90.00 343.70 6864.89 6920.79 4031.52 8387.35 5961420.97 306626.41 0.01 . 56 . . 00 0 00 0 00 100 18100.00 18200.00 90.00 343.70 6864.89 6920.79 4127.50 8359.28 5961517.39 386599.90 0.01 1 1663.47 47 1763 # # 90 90 . 00 0 . 0.00 . 100.00 18200.00 18300.00 90.00 343.70 6864.89 6920.79 4223.48 8331.21 5961613.82 386573.40 0.0 . 90 . 00 0 00 0 00 100 18300.00 18400.00 90.00 343.70 6864.89 6920.79 4319.46 8303.15 5961710.24 386546.89 0.01 1863.47 1963 46 # # 90 . 0 00 . 0.00 . 100.00 18400.00 18500.00 90.00 343.70 6864.89 6920.79 4415.44 8275.08 5961806.67 366520.39 0.01 . 90 . 0 00 00 0 00 100 18500.00 18600.00 90.00 343.70 6864.89 6920.79 4511.42 8247.01 5961903.09 386493.88 0.01 2063.46 46 163 # # 90 . 0 00 . 0.00 . 100.00 18600.00 18700.00 90.00 343.70 6864.89 6920.79 4607.40 8218.95 5961949.51 386467.38 0.01 . 2 9 . 00 0 0 00 100 00 18700.00 18800.00 90.00 343.70 6864.89 6920.79 4703.38 8190.88 5962095.94 386440.87 0.01 2263.46 # 0 . 00 0 . 00 0 . 100 00 18800.00 18900.00 90.00 343.70 6864.89 6920.79 4799.36 8162.81 5962192.36 386414.37 7 86 0.01 01 0 2363.46 46 2463 # # 90 90 . 0.00 . 0.00 . 100.00 18900.00 19000.00 90.00 343.70 6864.89 6920.79 4895.34 8134.75 5962288.78 . 38638 . . 0 00 00 0 100 00 19000.00 19100.00 90.00 343.70 6864.89 6920.79 4991.32 8106.68 5962385.21 386361.36 0.01 2563.46 # # 90 90 . 00 0 . 00 0 . 100.00 19100.00 19200.00 90.00 343.70 6864.89 6920.79 5087.30 8078.61 5962481.63 386334.85 0.01 2663.45 . 00 0 . 00 0 00 100 19200.00 19300.00 90.00 343.70 6864.89 6920.79 5183.28 8050.55 5962578.05 386308.35 0.01 2763.45 # 90 . 0 00 . 00 0 . 00 100 19300.00 19400.00 90.00 343.70 6864.89 6920.79 5279.26 8022.48 5962674.48 386281.84 0.01 2863.45 45 2963 # # 90 9D . 00 0 . 0.00 . 100.00 19400.00 19500.00 90.00 343.70 6864.09 6920.79 5375.24 7994.41 5962770.90 386255.34 0.01 . . 00 0 00 0 100 00 19500.00 19600.00 90.00 343.70 6864.89 6920.79 5471.22 7966.35 5962867.32 386228.83 0.01 3063.45 # 90 . 00 0 . 0 00 . 00 100 19600.00 19700.00 90.00 343.70 6864.89 6920.79 5567.20 7938.28 5962963.75 386202.33 0.01 3163.45 # 90 . 0 00 . 0 00 . 00 100 19700.00 19800.00 90.00 343.70 6864.89 6920.79 5663.19 7910.21 5963060.17 386775.82 0.01 3263.45 # 90 . 0 00 . 0 00 . 13 28 19713.28 CD4301Bw 06 North 19813.28 90.00 343.70 6864.89 6920.79 5675.93 7906.49 5463072.97 386172.30 0.06 3276.73 # 90 . . . • Page 4 of 4 (CD4-3018wp07 (NAD 27).xls) 12/3112007 12:20 PM Maas. Incl. TRUE Subsea RKB Loc al ASP or Grid Dogleg Original 'l e~ Tool Bvild Tvm Course Drlllad ^' Depth (ff) 4600.00 4700.00 4800.00 Angle (deg) 68.74 68.72 68.90 Azl. (deg) 106.87 107.20 106.93 ND (ft) 2919.38 2955.65 2991.80 TVD (ff) 2975.28 3011.55 3047.70 N(+(/51-) (ft) -943.50 -970.80 -998.16 E(+)/wF) (ff) 2746.84 2835.94 2925.07 IJ(+1/SI-I Lat. (Y) 5956538.16 5956509.41 5956480.61 E(+)/W(•) Dep. (X) 380905.89 380994.53 381083.21 Severity (°/100 ft) 0.68 0.31 0.31 VS (944°) 1 (#) I -1664.09 -1714.89 -1765.76 817 27 3• ftl # # # # Face (deg) -64 94 •54 94 (°/100 fi) 0.30 -0.02 0.18 08 -0 (°/100 H) -0.66 0.33 •0.27 1 18 Length (ff) 100.00 100.00 100.00 100.00 Dlsfance (ff) 4500.00 4600.00 4700.00 4800.00 Comments 4900.00 5000.00 68.82 68.92 108.11 107.79 3027.87 3063.92 3083.77 3119.82 -1026.24 -1054.99 3014.01 3102.75 5956451.09 5956420.91 381171.69 381259.94 1.10 0.31 . •1 •1869.36 1 26 9 # # •72 166 . 0.10 55 -0 . •0.32 0 15 100.00 100.00 4900.00 5000.00 5100.00 5200.00 68.37 67.56 107.94 108.17 3100.33 3137.85 3156.23 3193.75 -1083.56 -1112.29 3191.39 3279.52 5956390.90 5956360.75 381348.11 381435.76 0.57 0.84 . -1 2 •1973.16 56 # # 165 24 . -0.81 0 96 . 0.23 46 0 100.00 100 00 5100.00 5200.00 5300.00 5400.00 68.52 69.98 100.63 107.85 3175.24 3210.67 3231.14 3266.57 -1141.56 -1170.83 3367.52 3456.33 5956330.05 5956299.35 381523.28 381611.61 1.05 1.63 -2025. -2078.17 47 0 # # -27 16 . 1.46 0 88 . •0.78 27 -0 . 100.00 100.00 5300.00 5400.00 5500.00. 5600.00 70.86 70.48 107.38 107.61 3244.18 3277.28 3300.08 3333.18 -1199.50 -1228.02 3546.08 3636.03 5456269.23 5956239.25 381700,80 381790.35 0.92 0.38 . -213 •2182.68 1 # # - 176 144 . -0.38 -0 70 . 0.03 O S4 100.00 100 00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 69.78 69.40 69.09 68.69 69.17 108.15 108.52 107.92 106.83 106.95 3311.27 3346.15 3381.58 3417.60 3453.55 3367.17 3402.05 3437.48 3473.50 3509.45 -1256.89 -1286.38 -1315.61 -1343.47 -1370.58 3725.53 3814.50 3903.32 3992.35 4081.64 5956208.92 5456178.00 5956147.33 5956118.02 5956089.47 381879,37 301967.85 382056.18 382144.75 382233.59 0.86 0.51 0.64 1.09 0.49 •2235.1 •2287.97 •2340.56 •2391.88 •2442.55 # # # # # 138 -119 -112 13 68 . -0.38 -0.31 -0.40 0.48 29 0 . 0.37 -0.60 -1.09 0.12 77 0 . 100.00 100.00 100.00 100.00 100 00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 69.46 69.53 107,72 108.11 3488.87 3523.90 3544.77 3574.80 -1398.46 •1427.27 4170.94 4260.06 5956060.15 5956029.89 382322.42 382471.07 0.78 0.37 -2493.96 •2546.22 # 79 4 . 0.07 34 0 . 0.39 22 0 . 100.00 00 100 6200.00 6300 00 6400.00 6500.00 69.19 68.17 107.89 108.69 3559.15 3595.51 3615.05 3651.41 -1456.19 -1485.42 4349.07 4437.51 5955999.53 5955968.87 382499.59 382587.55 0.40 1.26 •2598.55 •2651.03 04 04 # #' # -1 9 144 153 . - -1.02 -0 98 - . 0.80 0 55 . 100.00 100.00 . 6400.00 6500.00 6600.00 6700.00 67.19 66.36 109.24 109.62 3633.49 3672.92 3689.39 3728.82 -1515.48 -1546.05 4525.00 4611.66 5955437.39 5955905.42 382674.5-0 382760.69 1.10 0.90 -27 . -2757.31 # 157 . -0.83 40 -0 . 0.38 0 22 100.00 00 100 6600.00 6700 00 6800.00 6900.00 65.96 67.72 109.84 110.70 3713.34 3752.67 3769.24 3808.57 -1576.93 -1608.79 4697.76 4784.00 5955873.15 5955839.90 382846.28 382931.99 0.45 1.93 -2010.73 •2865.12 # # 153 24 . 1.76 46 1 . 0.86 46 0 . 100.00 100 00 . 6800.00 6900 00 7000.00 7100,00 69.18 68.88 111.16 106.75 3789.40 3825.20 3845.30 3881.10 -1642.01 -1672.34 4870.87 4959.15 5955805.27 5955773.51 383018.31 383706.09 1.52 4.13 -2921.00 •2974.49 9 # # # ib -95 14 . -0.30 55 0 . -4.41 15 •0 . 100.00 100 00 . 7000.00 7100.00 7200.00 7300.00 69:43 68.48 106.60 106.58 3860.79 3896.70 3916.69 3952.60 -1699.15 -1725.80 5048.68 5138.12 5455745.25 5955717.15 383195.17 383284.16 0.57 0.95 •3024. 4 -3075.21 # • -179 15 . -0.95 0 72 . -0.02 20 0 . 100.00 100 00 7200.00 7300.00 7400.00 7500.00 69.20 69.12 106.78 104.30 3932.79 3968.38 3988.69 4024.28 -1752.57 -1777.60 5227.46 5317.49 5955688.94 5955662.44 383373.05 383462.67 0.74 2.32 -3125.56 •3174.45 # # -92 80 . -0.08 0 13 . •2.48 77 -0 . 100.00 100 00 7400.00 7500.00 7600.00 7700.00 69.25 69.53 103.53 104.10 4003.91 4039.11 4059.81 4095.01 -1800.08 -1822.43 5408.22 5499.11 5955638.x9 5955614.67 383553.02 383643.53 0.73 0.60 •3221.06 •3267.60 # # • 62 . 0.28 . 0.57 68 0 . 100.00 100 00 7600.00 00 7700 7800.00 7900.00 68.78 68.55 104.78 107.00 4074.70 4111.08 4130.60 4166.98 -1845.74 -1871.24 5589.61 5679.19 5955589.90 5955562.95 383733.65 383822.80 0.98 2.08 •3314.95 •3364.15 # # # 140 97 78 -8.75 -0.23 34 0 . 2.22 1 94 . 100.00 00 100 . 7800.00 7900.00 8000.00 8100.00 68.94 69.11 108.94 110.0-0 4147.34 4183.13 4203.24 4239.03 -1899.99 -1931.14 5767.84 5855.86 5955532.76 5955500.19 383910.97 383998.47 1.85 1.04 •3416.22 -3470.43 # # 81 99 . 0.17 19 -0 . 1.10 1 27 . 100.00 100.00 8000.00 8100.00 8200.00 8300.00 68.92 69.64 111.31 111.15 4218.95 4254.33 4274.85 4310.23 -1964.11 -1997.97 5943.21 6030.39 5955465.81 5955430.53 384085.28 384171.90 1.20 0.74 •3526.20 •3582.78 9 # # -12 27 . 0.72 1 69 . •0.16 41 •0 100.00 lOD.00 8200.00 8300.00 8400.00 8500.00 71.33 70.48 110.24 108.90 4287.73 4320.45 4343.63 4376.35 -203).28 -2062.93 6118.56 6207.60 5955395.80 5955362.?1 384259.52 384348.03 1.90 1.53 .10 •363 •3694.07 # - -124 164 . -0.85 77 -1 . •1.34 54 -0 100.00 00 100 8400.00 8500.00 8600.00 8700.00 68.71 67.76 108.36 108.87 4355.31 4392.39 4411.21 4448.29 -2092.87 -2122.52 6296.41 6384.42 5455331.33 5455300.26 384436.34 384523.86 1.84 1.06 •3747.33 -3800.09 # # - 154 82 . -0.95 0 14 . 0.51 00 1 . 100.00 100 00 8600.00 8700.00 8800.00 8900.00 67.90 68.00 109.87 110.13 4430.13 4467.67 4486.03 4523.57 -2153.23 -2184.93 6471.78 6558.88 5955268.13 5955235.02 384610.71 384697.28 0.94 0.26 •3853,69 •3908,17 # # 68 . 0.10 44 0 . 0.26 25 0 . 100.00 100 00 8800.00 8900.00 9000.00 9100.00 68.44 68.61 110.38 109.99 4504.77 4541.38 4560.67 4597.28 -2217.08 -2249.19 6646.00 6733.34 5955201.46 5955167.94 384783.87 38487D.68 0.50 0.40 •3963.09 •4018.03 # # # 28 -65 102 . 0.17 13 -0 . -0.39 -0 65 . 100.00 100.00 9000.00 9100.00 9200.00 9300.00 68.48 68.54 109.34 109.14 4577.96 4614.59 4633.86 4670.49 •2280.51 -2311.17 6820.98 6908.83 5955135.20 5955103.12 384957.80 385045.14 0.62 0.20 •4072.29 •4125.98 # - -72 . 0.06 54 0 . •0.20 02 1 100.00 100 00 9200.00 9300 00 9400.00 9500.00 69.13 69.77 108.12 107.93 4650.70 4685.80 4706:60 4741.70 -2340.96 -2369.93 6997.20 7086.24 5955071.90 5455041.48 385133.01 385221.57 1.12 0.66 •4178.97 •4231.37 # #~ -58 •16 . 0.64 0 37 - . •0.14 15 0 . 100.00 100 00 . 9400.00 9500.00 KOP; 3.5 DLS 9600.00 9645.00 69.40 68.62 107.78 109.24 4720.68 4736.80 4776.58 4792.70 -2398.67 -2412.01 7175.45 7215.28 5955011.30 5954997.32 385310.30 385349.92 0.40 3.49 -4283.58 -4307.38 # # # -159 120 115 . - -1.73 44 -1 . - 3.24 44 -3 . 45.00 55.00 9545.00 9600.00 MWD+IFR-AK-CAZ-SC 3) 9700.00 9800.00 67.83 66.45 107.35 103.86 4757.21 4796.07 4813.11 4851.97 -2428.04 -2452.84 7263.77 7352.50 5954980.50 5954954.27 385398.14 385486.45 3.50 3.50 -4336.16 -4384.45 # - -114 . -1.38 . -3.49 100.00 9700.00 i Pian Page 2 of 4 (CD4-301 Bwp07 (NAD 27).xls) 12/3112007 12:20 PM ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD4 Nanuq Pad Rig: CD4-301 Prelim: CD4-301B (9k) Plan: CD4-301 Bwp07 Standard Proposal Report 28 December, 2007 e N~4D e3 ,fig, LC.! B 1~FIy'Ti~l ~l Sperry Grilling Seruaea~ i • ' enor sy:ayn: iscwsA sranNetho°: T"".`'~p~pqp'"°°rN""" ~~le Ertor 8lrFax: EpRW ' ""° ° Western North Slope tp5 CAnoCOP1~~ es """' "° '° ~ Geo°e6c Dahu¢ NMh Amerinn Dahun 7983 N °"""°°"~ ~`""'~'°°' CD4 Nanuq Pad CD4-301 Bwp07 '~ Rig: CD4-301 Ground Level: 19.00 Prelim: CD4-301 B (9k) RKB: Rig: CD4-301 (36.9+19) ~ 55.908 (OOyon 19 (36.9+~9~~ CD4301 Bwp07 Northing/ASP Y: 5957273.28 EastinglASP X: 1578208.24 ~ppl 301g A- Gp j D4-301 Bwp06 North 5000 .-. c _ 0 ~ 2500 ' " x 8-3! 1` O ryo ~ D4-301 Bwp06 South Z ~ o ~ 9-5/8" x 12-1/4" TD O 301 R~9 SuNeYs CD4- 0 - - -------- - ---- - -2500 -- - -2500 0 2500 5000 7500 10000 12500 West(-)/East(+) (2500 ft/in) 0 ~ 10 0 30 0 ~ ~ -5/8" x 12-1/4" TD ~ X500 'o O ^ ~, is U ti j 5000 ~ m ~, o 0 L ~ 0 U "~4c~8- D 7" x 8-3/43" TD Q v -1/2" x 6-1/8" ~ o ~` ro° D4-301 Bwp06 South CD4-301 Bwp06 North 7500 --- -7500 -50 00 -2500 ~ 0 2500 5000 e • ! ConocoPhillips Alaska, Inc. ~~ Standard Proposal Report Database: EDM Alaska Prod v16 Local Co-ordinate Referenc e: Well Rig: CD4-301 .~' Company: ConocoPhillips(A{aska) Inca-WNS ND Reference: Rig: CD4-301 (36.9+19) @ 55.90ft (Doyon 19 (3r Project: Western North Slope MD Reference: Rig: CD4-301 (36.9+19) @ 55.90ft (Doyon 19 (3r Site: CD4 Nanuq Pad North Reference: True Well: Rig: CD4-301 Survey Calculation Method: Minimum Curvature Wellbore: Prelim: CD4-3016 (9k) Design: CD4-3016wp07 >; - Project ~ -- - - ~Nestern North Slope, North Slope Alaska. U . ,,.._,. ~.. _.~ ,..... nitPtf States ~,,, ..,,,. ,..r.,~ Map System: US State Plane 1983 System Datum: Mean Sea Level '~ Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site CG4 Nanuq Pad Site Position: Northing: 5,957,273.268 Latitude: 70° 1T 31.779 N From: Map Easting: 1,518,208.21 ft Longitude: 150° 59' 22.031 W ° Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.93 E YVell' - Rig' CD4-3111 , --- Well Position +N/-S 0.00 ft Northing: 5,957,273.28 ft Latitude: 70° 1 T 31.779 N +E/-W 0.00 ft Easting: 1,518,208.24 ft Longitude: 150° 59' 22.030 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.OOft -Wellbore Prelim: CD4-3018 (9ki Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM`LU07 12128lL007 2229 80.1'v = ~ . `'63 Design C C4 ~+11E3wp07 - ., ,..:,.o, --a , Audit Notes: Version: Phase: PROTOTYPE Tie On Depth: 9,600.00 Vertical Section: Depth From (ND) +N/-S +EI-W Direction (ft) (ft) (ft) (~) ~_ ~ 36.90 0.00 D 00 344 UC1 Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +FJ-W Rate Rate Rate Tool Face (ft) (°} (°) (ft) ft (ft) (ft) (°I100ft) (°1100ft) (°1100ft) (°) 9,600.00 69.40 107.78 4,775.80 4,719.90 -2,398.11 7,175.31 0.00 0.00 0.00 0.00 9,645.00 68.62 109.24 4,791.92 4,736.02 -2,411.45 7,215.15 3.50 -1.74 3.26 120.00 11,911.60 63.42 20.76 5,894.09 5,838.19 -1,692.85 8,838.80 3.50 -0.23 -3.90 -114.53 13,455.48 63.42 20.76 6,584.77 6,528.87 -401.73 9,328.20 0.00 0.00 0.00 0.00 14,663.97 86.50 343.70 6,906.74 6,850.84 734.55 9,351.51 3.50 1.91 -3.07 -63.36 14,813.97 86.50 343.70 6,915.90 6,860.00 878.25 9,309.49 0.00 0.00 0.00 0.00 14,818.97 86.50 343.70 6,91621 6,860.31 883.04 9,308.08 0.00 0.00 0.00 0.00 14,939.98 90.00 343.70 6,919.90 6,864.00 999.11 9,274.14 2.89 2.89 0.00 0.04 19,813.28 90.00 343.70 6,919.90 6,864.00 5,676.47 7,906.18 0.00 0.00 0.00 -90.00 1228/2007 3:30:32PM Page 2 COMPASS 2003.16 Build 42F ~~~~ Database Company Project: Site: Well: Wellbore: Design: EDM Alaska Prod v16 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD4 Nanuq Pad Rig: CD4-301 Prelim: CD4-301 B (9k) CD4-301 Bwp07 • ConocoPhiitips Alaska, Inc. Standard Proposal. Report Local Co-ordinate Reference: Well Rig: CD4-301 TVD Reference: Rig: CD4-301 (36.9+19) t~ 55.90ft (Doyon 19 (3t MD Reference: Rig: CD4-301 (36.9+19) t~ 55.90ft (Doyon 19 (31 North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Map Map Depth Incl ination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS (ft} (°) {°) (ft) ft (ft) (ft) (ft} (ft) 4,719.90 9,600.00 69.40 10%]3 4,%%5.80 4,719.90 -2,393.1 i i,1i5.31 5,9`,~5`J.04 1,525,3~3.0Z 0.?0 KOP; 3.5 DLS, 120 TF 9,645.00 68.62 109.24 4,791.92 4,736.02 -2,411.45 7,215.15 5,954,745.06 1,525,382.63 3.50 9,700.00 67.83 107.35 4,812.32 4,756.42 -2,427.49 7,263.64 5,954,728.23 1,525,430.85 3.50 9,800.00 66.45 103.86 4,851.18 4,795.28 -2,452.29 7,352.36 5,954,702.00 1,525,519,16 3.50 9,900.00 65.16 100.30 4,892.17 4,836.27 -2,471.38 7,441.53 5,954,681.46 1,525,608.00 3.50 10,000.00 63.95 96,66 4,935.16 4,879.26 -2,484.70 7,530.82 5,954,666.69 1,525,697,05 3.50 10,100.00 62.83 92.95 4,979.96 4,924.06 -2,492.20 7,619.89 5,954,657.74 1,525,785.97 3.50 10,200.00 61.81 89.17 5,026.43 4,970.53 -2,493.85 7,708.40 5,954,654.66 1,525,874.44 3.50 10,300.00 60.90 85.32 5,074.38 5,018.48 -2,489.64 7,796.04 5,954,657.44 1,525,962.13 3.50 10,400.00 60.10 81.40 5,123.64 5,067.74 -2,479.59 7,882.46 5,954,666.09 1,526,048.70 3.50 10,500.00 59.41 77.43 5,174.03 5,118.13 -2,463.73 7,967.36 5,954,680.56 1,526,133.83 3.50 10,600.00 58.85 73.40 5,225.34 5,169.44 -2,442.13 8,050.40 5,954,700.80 1,526,217.21 3.50 10,700.00 58.42 69.33 5,277.41 5,221.51 -2,414.87 8,131.29 5,954,726.75 1,526,298.53 3.50 10,800.00 58.12 .65.23 5,330.02 5,274.12 -2,382.04 8,209.72 5,954,758.29 1,526,377.47 3.50 10,900.00 57.94 61.11 5,382.98 5,327.08 -2,343.77 8,285.40 5,954,795.32 1,526,453.76 3.50 11,000.00 57.91 56.98 5,436.10 5,380.20 -2,300.21 8,358.05 5,954,837.69 1,526,527.10 3.50 11,100.00 58.00 52.86 5,489.18 5,433.28 -2,251.51 8,427.38 5,954,885.26 1,526,597.21 3.50 11,200.00 58.23 48.74 5,542.02 5,486.12 -2,197.86 8,493.16 5,954,937.83 1,526,663.85 3.50 11,300.00 58.59 44.65 5,594.42 5,538.52 -2,139.45 8,555.13 5,954,995.22 1,526,726.75 3.50 11,400.00 59.08 40.60 5,646.18 5,590.28 -2,076.51 8,613.05 5,955,057.20 1,526,785.69 3.50 11,500.00 59.69 36.60 5,697.12 5,641.22 -2,009.27 8,666.72 5,955,123.56 1,526,840.44 3.50 11,600.00 60.43 32.65 5,747.05 5,691.15 -1,937.98 8,715.94 5,955,194.03 1,526,890.80 3.50 11,700.00 61.28 28.76 5,795.77 5,739.87 -1,862.90 8,760.51 5,955,268.37 1,526,936.58 3.50 11,800.00 62.23 24.94 5,843.11 5,787.21 -1,784.32 8,800.28 5,955,346.28 1,526,977.62 3.50 11,900.00 63.30 21.19 5,888.89 5,832.99 -1,702.53 8,835.09 5,955,427.49 1,527,013.75 3.50 11,911.60 63.42 20.76 5,894.09 5,838.19 -1,692.85 8,838.80 5,955,437.11 1,527,017.62 3.50 12,000.00 63.42 20.76 5,933.63 5,877.73 -1,618.92 8,866.83 5,955,510.56 1,527,046.84 0.00 12,100.00 63.42 20.76 5,978.37 5,922.47 -1,535.30 8,898.52 5,955,593.66 1,527,079.89 0.00 12,200.00 63.42 20.76 6,023.11 5,967.21 -1,451.67 8,930.22 5,955,676.75 1,527,112.94 0.00 12,300.00 63.42 20.76 6,067.85 6,011.95 -1,368.04 8,961.92 5,955,759.85 1,527,146.00 0.00 12,400.00 63.42 20.76 6,112.58 6,056.68 -1,284.41 8,993.62 5,955,842.94 1,527,179.05 0.00 12,500.00 63.42 20.76 6,157.32 6,101.42 -1,200.78 9,025.32 5,955,926.04 1,527,212.10 0.00 12,600.00 63.42 20.76 6,202.06 6,146.16 -1,117.15 9,057.02 5,956,009.13 1,527,245.15 0.00 12,700.00 63.42 20.76 6,246.80 6,190.90 -1,033.52 9,088.72 5,956,092.23 1,527,278.20 0.00 12,800.00 63.42 20.76 6,291.53 6,235.63 -949.90 9,120.42 5,956,175.32 1,527,31126 0.00 12,900.00 63.42 20.76 .6,33627 6,280.37 -866.27 9,152.12 5,956,258.42 1,527,344.31 0.00 13,000.00 63.42 20.76 6,381.01 6,325.11 -782.64 9,183.82 5,956,341.52 1,527,377.36 0.00 13,100.00 63.42 20.76 6,425.74. 6,369.84 -699.01 9,215.52 5,956,424.61 1,527,410.41 0.00 13,200.00 63.42 20.76 6,470.48 6,414.58 -615.38 9,247.22 5,956,507.71 1,527,443.46 0.00 13,300.00 63.42 20.76 6,515.22 6,459.32 -531.75 9,278.92 5,956,590.80 1,527,476.52 0.00 13,400.00 63.42 20.76 6,559.96 6,504.06 -448.12 9,310.62 5,956,673.90 1,527,509.57 0.00 13,455.48 63.42 20.76 6,584.77 6,528.87 -401.73 9,328.20 5,956,719.99 1,527,527.90 0.00 13,500.00 64.13 19.21 6,604.45 6,548.55 -364.19 9,341.85 5,956,757.30 1,527,542.16 . 3.50 13,600.00 65.78 15.80 6,646.79 6,590.89 -277.81 9,369.08 5,956,84323 1,527,570.79 3.50 Vert Section 4,«;x.00 -4,306.80 -4,335.58 -4,383.87 -4,426.81 -4,464.22 -4,495.98 -4,521.97 -4,542.07 -4,556.23 -4,564.39 -4,566.52 -4,562.61 -4,552.67 -4,536.75 -4,514.89 -4,487.19 -4,453.75 -4,414.68 -4,370.15 -4,320.30 -4,265.34 -4,205.46 -4,140.89 -4,071.86 -4,063.58 -4,000.24 -3,928.59 -3,856.94 -3,785.28 -3,713.63 -3,641.98 -3,570.33 -3,498.68 -3,427.03 -3,355.38 -3,283.72 -3,212.07 -3,140.42 -3,068.77 -2,997.12 -2,957.37 -2,925.05 -2,849.51 127282007 3:30:32PM Page 3 COMPASS 2003.16 Build 42F r i ConocoPh illips Alaska, Inc. Standard ProposaLReport Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well Rig: CD4-301 Company: ConocoPhillips(Alaska) Inc. -WNS TVD Reference: Rig: CD4-301 (36.9+19) @ 55.90ft (Doyon 19 (3r ' Project: Western North Slope MD Reference: Rig: CD4-301 (36:9+ 19) @ 55.90ft (Doyon 19 (3~ ' Site: CD4 Nanuq Pad North R eference: True Well: Rig: CD4-301 Survey Calculation Method: Minimum Curvature Wellbore: Prelim: CD4-3016 (9k) Design: GD4-301Bwp07 Planned Survey Measured Vertical Map Map Depth In clination Az imuth Depth TVDss +N/-S +FJ-W Northing Easting DLS Vert Section (ft) (°) {°) (~) ft (ft) (ft) (ft) (ft) 6,630.55 13,700.00 67.50 12.48 6,686.45 6,630.55 -188.80 9,391.49 5,956,931.85 1,527,594.64 3.50 -2,770.13 13,800.00 69.28 9.24 6,723.29 6,667.39 -97.51 9,408.99 5,957,022.83 1,527,613.62 3.50 -2,687.20 13,900.00 71.13 6.08 6,757.15 6,701.25 -4.28 9,421.51 5,957,115.84 1,527,627.66 3.50 -2,601.03 14,000.00 73.03 2.99 6,787.93 6,732.03 90.55 9,429.03 5,957,210.53 1,527,636.71 3.50 -2,511.94 14,100.00 74.97 359.96 6,815.50 6,759.60 186.63 9,431.49 5,957,306.55 1,527,640.74 3.50 -2,420.27 14,200.00 76.95 356.99 6,839.76 6,783.86 283.59 9,428.90 5,957,403.53 1,527,639.72 3.50 -2,326.35 14,300.00 78.97 354.06 6,860.62 6,804.72 381.08 9,421.26 5,957,501.12 1,527,633.67 3.50 -2,230.54 14,400.00 81.01 351.18 6,878.00 6,822.10 478.72 9,408.61 5,957,598.95 1,527,622.61 3.50 -2,133.19 14,500.00 83.08- 348.33 6,891.85 6,835.95 576.16 9,390.99 5,957,696.66 1,527,606.57 3.50 -2,034.66 14,600.00 85.16 345.50 6,902.09 6,846.19 673.04 9,368.46 5,957,793.88 1,527,585.62 3.50 -1,935.33 14,663.97 86.50 343.70 6,906.74 6,850.84 734.55 9,351.51 5,957,855.65 1,527,569.68 3.50 -1,871.54 14,700.00 86.50 343.70 6,908.94 6,853.04 769.06 9,341.42 5,957,890.32 1,527,560.15 0.00 -1,835.58 14,800.00 86.50 343.70 6,915.05 6,859.15 864.86 9,313.40 5,957,986.55 1,527,533.70 0.00 -1,735.76 14,813.97 86.50 343.70 6,915.90 6,860.00 878.25 9,309.49 5,958,000.00 1,527,530.00 0.00 -1,721.82 ,...CD4-301Bwp06 South 14,818.97 86.50 343.70 6,916.21 6,860.31 883.04 9,308.08 5,958,004.81 1,527,528.68 0.00 -1,716.83 14,900.00 88.84 343.70 6,919.50 6,863.60 960.74 9,285.36 5,958,082.86 1,527,507.22 2.89 -1,635.87 14,939.98 90.00 343.70 6,919.90 6,864.00 999.11 9,274.14 5,958,121.41 1,527,496.63 2.89 -1,595.90 7,. x 8-314" 15,000.00 90.00 343.70 6,919.90 6,864.00 1,056.71 9,257.30 5,958,179.28 1,527,480.72 0.00 -1,535.88 15,100.00 90.00 343.70 6,919.90 6,864.00 1,152.69 9,229.23 5,958,275.69 1,527,454.22 0.00 -1,435.88 15,200.00 .90.00 343.70 6,919.90 6,864.00 1,248.68 9,201.16 5,958,372.11 1,527,427.72 0.00 -1,335.88 15,300.00 90.00 343.70 6,919.90 6,864.00 1,344.66 9,173.09 5,958,468.53 1,527,401.22 0.00 -1,235.88 15,400.00 90.00 343.70 6,919.90 6,864.00 1,440.64 9,145.03 5,958,564.94 1,527,374.72 0.00 -1,135.88 15,500.00 90.00 343.70 6,919.90 6,864.00 1,536.62 9,116.96 5,958,661.36 1,527,348.22 0.00 -1,035.88 15,600.00 90.00 343.70 6,919.90 6,864.00 1,632.60 9,088.89 5,958,757.77 1,527,321.72 0.00 -935.89 15,700.00 90.00 343.70 6,919.90 6,864.00 1,728.58 9,060.82 5,958,854.19 1,527,295.22 0.00 -835.89 15,800.00 90.00 343.70 6,919.90 6,864.00 1,824.56 9,032.76 5,958,950.61 1,527,268.71 0.00 -735.89 15,900.00 90.00 343.70 6,919.90 6,864.00 1,920.54 9,004.69 5,959,047.02 1,527,242.21 0.00 -635..89 16,000.00 90.00 343.70 6,919.90 6,864.00 2,016.52 8,976.62 5,959,143.44 1,527,215.71 . 0.00 -535.89 16,100.00 90.00 343.70 6,919.90 6,864.00 2,112.50 8,948.55 5,959,239.85 1,527,189.21 0.00 -435.89 16,200.00 90.00 343.70 6,919.90 6,864.00 2,208.48 8,920.48 5,959,336.27 1,527,162.71 0.00 -335.89 16,300.00 90.00 343.70 6,919.90 6,864.00 2,304.46 8,892.41 5,959,432.68 1,527,136.20 0.00 -235.90 16,400.00 90.00 343.70 6,919.90 6,864.00 2,400.44 8,864.35 5,959,529.10 1,527,109.70 0.00 -135.90 16,500.00 90.00 343.70 6,919.90 6,864.00 2,496.42 8,836.28 5,959,625.51 1,527,083.20 0.00 -35.90 16,600.00 90.00 343.70 6,919.90 6,864.00 2,592.40 8,808.21 5,959,721.93 1,527,056.69 0.00 64.10 16,700.00 90.00 343.70 6,919.90 6,864.00 2,688.38 8,780.14 5,959,818.35 1,527,030.19 0.00 164.10 16,800.00 90.00 343.70 6,919.90 6,864.00 2,784.36 8,752.07 5,959,914.76 1,527,003.69 0.00 264.10 16,900.00 90.00 343.70 6,919:90 6,864.00 2,880.34 8,724.00 5,960,011.18 1,526,977.19 0.00 364.10 17,000.00 90.00 343.70 6,919.90 6,864.00 2,976.32 8,695.93 5,960,107.59 1,526,950.68 0.00 464.09 17,100.00 90.00 343.70 6,919.90 6,864.00 3,072.29 8,667.86 5,960,204.01 1,526,924.18 0.00 564.09 17,200.00 90.00 343.70 6,919.90 6,864.00 3,168.27 8,639.79 5,960,300.42 1,526,897.67 0.00 664.09 17,300.00 90.00 343.70 6,919.90 6,864.00 3,264.25 8,611.72 5,960,396.84 1,526,871.17 0.00 764.09 17,400.00 90.00 343.70 6,919.90 6,864.00 3,360.23 8,583.65 5,960,493.25 1,526,844.67 0.00 864.09 17,500.00 90.00 343.70 6,919.90 6,864.00 3,456.21 8,555.58 5,960,589.67 1,526,818.16 0.00 964.09 1228/2007 3:30:32PM Page 4 COMPASS 2003.16 Build 42F Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. -VVNS Project: Western North Slope Site: CD4 Nanuq Pad Well: Rig: CD4-301 Wellbore: Prelim: CD4-3016 (9k) Design: CD4-301Bwp07 Planned Survey ConocoPhillips Alaska, Inc. Standard Proposal Report Local Co-ordinate Reference: Well Rig: CD4-301 ND Reference: Rig: CD4-301 (36.9+19) @ 55.90ft (Doyon 19 (31 MD Reference: Rig: CD4-301 (36.9+19) (t7~ 55.90ft (Doyon 19 (31 North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Map Map Depth Inc lination Az imuth Depth NDss +NI-S +FJ-W Northing Easting DLS Vert Section eft? (~) (°) (ft) ft (ft) (ft) (ft) {ft) 6,864.00 17,600.00 90.00 343.70 6,919.90 6,864.00 3,552.19 8,527.51 5,960,686.08 1,526,791.66 0.00 1,064.09 17,700.00 90.00 343.70 6,919.90 6,864.00 3,648.17 8,499.44 5,960,782.50 1,526,765.15 0.00 1,164,09 17,800.00 90.00 343.70 6,919.90 6,864.00 3,744.15 8,471.36 5,960,878.91 1,526,738.65 0.00 1,264.08 17,900.00 90.00 343.70 6,919.90 6,864.00 3,840.13 8,443.29 5,960,975.33 1,526,712.14 0.00 1,364.08 18,000.00 90.00 343.70 6,919.90 6,864.00 3,936.11 8,41522 5,961,071.74 1,526,685.64 0.00 1,464.08 18,100.00 90.00 343.70 6,919.90 6,864.00 4,032.09 8,387.15 5,961,168.16 1,526,659.13 0.00 1,564.08 18,200.00 90.00 343.70 6,919.90 6,864.00 4,128.07 8,359.08 5,961,264.57 1,526,632.63 0.00 1,664.08 18,300.00 90.00 343.70 6,919.90 6,864.00 4,224.05 8,331.01 5,961,360.99 1,526,606.12 0.00 1,764.08 18,400.00 90.D0 343.70 6,919.90 6,864.00 4,320.02 8,302.93 5,961,457.40 1,526,579.62 0.00 1,864.08 18,500.00 90.00 343.70 6,919.90 6,864.00 4,416.00 8,274.86 5,961,553.81 1,526,553.11 0.00 1,964.07 18,600.00 90.00 343.70 6,919.90 6,864.00 4,511.98 8,246.79 5,961,650.23 1,526,526.60 0.00 2,064.07 18,700.00 90.00 343.70 6,919.90 6,864.00 4,607.96 8,218.72 5,961,746.64 1,526,500.10 0.00 2,1.64.07 18,800.00 90.00 343.70 6,919.90 6,864.00 4,703.94 8,190.65 5,961,843.06 1,526,473.59 0.00 2,264.07 18,900.00 90.00 343.70 6,919.90 6,864.00 4,799.92 8,162.57 5,961,939.47 1,526,447.08 0.00 2,364.07 19,000.00 90.00 343.70 6,919.90 6,864.00 4,895.90 8,134.50 5,962,035.89 1,526,420.58 0.00 2,464.07 19,100.00 90.00 343.70 6,919.90 6,864.00 4,991.88 8,106.43 5,962,132.30 1,526,394.07 0.00 2,564.07 19,200.00 90.00 343.70 6,919.90 6,864.00 5,087.85 8,078.35 5,962,228.72 1,526,367.56 0.00 2,664.06 19,300.00 90.00 343.70 6,919.90 6,864.00 5,183.83 8,050.28 5,962,325.13 1,526,341.06 0.00 2,764.06 19,400.00 90.00 343.70 6,919.90 6,864.00 5,279.81 8,022.21 5,962,421.54 1,526,314.55 0.00 2,864.06 19,500.00 90.00 343.70 6,919.90 6,864.00 5,375.79 7,994.13 5,962,517.96 1,526,288.04 0.00 2,964.06 19,600.00 90.00. 343.70 6,919.90 6,864.00 5,471.77 7,966.06 5,962,614.37 1,526,261.53 0.00 3,064.06 19,700.00 90.00 343.70 6,919.90 6,864.00 5,567.75 7,937.98 5,962,710.79 1,526,235.03 0.00 3,164.06 19,800.00 90.00 343.70 6,919.90 6,864.00 5,663.73 7,909.91 5,962,807.20 1,526,208.52 0.00 3,264.06 19,813.28 90.00 343.70 6,919.90 - 6,864.00 ,r 5,676.47 7,906.18 5,962,820.00 1,526,205.00 0.00 3,277.33 < CD4-301Bwp06 North Targets Target Name - hiUmiss tar get Di p Angle Dip Dir. ND +Nl-S +EJ-W Northi ng Easting -Shape 1°) ~~) (R) eft) (~) _~n) {ft) CD4-301Bwp06 North 0.00 0.00 6,919.90 5,676.47 7,906. 18 5,962, 820.00 1,526,205.00 - plan hits target - Point CD4-3016wp06 South 0.00 0.00 6,915.90 878.25 9,309. 49 5,958, 000.00 1,527,530.00 -plan hits ta rget - Point Casing Points Measured Ve rtical Casing Hole Depth D epth Diameter Diamete ( ) r (ft) fft) Name O 3,046.00 2,390.99 9-518" x 12-1 /4" 7D 9-5/8 12-114 14,939.98 6,919.90 7" x 8-3/4" 7 8-3/4 19,813.2 8 6,919.90 3- 1/2" x 6-1/8" 3-1/2 6-1/8 1228/2007 3:30:32PM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips Alaska, Inc. -~ Standard Proposal Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference: `dJell Rig: CD4-301: Company: ConocoPhillips(Alaska} Inc. -WNS ND Reference: Rig: CD4-301 (36.9+19) @ 55.90ft (Doyon 19(31 Project: Western North Slope MD Reference: Rig: CD4-301 (36.9+19) @ 55.90ft (Doyon 19 (31 Site: CD4 Nanuq Pad North Reference: True Well: Rig: CD4-301 Survey Calculation Method: Minimum Curvature Wellbore: Prelim: CD4-3016 (9k) Design_ C; D4-301Bwp07 Plan Annotations - Measured Vertical Local Coor dinates Depth Depth +N/-S +EJ-W (ft) (ff) (ft) (ft) Comment ~ 9,600.00 4,775.80 -2,398.11 7,175.31 KOP; 3.5 DLS, 120 T1= 12128/2007 3:30:32PM Page 6 COMPASS 2003.16 Build 42F ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD4 Nanuq Pad Rig: CD4-301 Prelim: CD4-301B (9k) CD4-301Bwp07 ';~iperry Grilling Servicees Anticollision Summary Report 28 December, 2007 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD4 Nanuq Pad -Rig: CD4-301 -Prelim: CD4-301 B (9k) -CD4-301 Bwp07 Well Coordinates: 5,957,273.28 N, 1,518,208.24E (70° 17' 31.78" N, 150° 59' 22.03" W) Datum Height: Rig: CD4-301 (36.9+19) @ 55.90ft (Doyon 19 (36.9+19)) Scan Range: 9,600.00 to 19,813.28 ft. Measured Depth. Scan Radius is 2,177.64 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 i~iparry DriUirsg ~larvice~ Edged h: '~? 7513, Oacem'ii 187 Cc~no~o hillips Project: Western North Slope Site: CD4 Nanuq Ped Well: Rig: CD4-301 Parent Well: TDed: CD4-301 Welibore: Prelim: CD4-3010 (9k) REFERENCE INFORMATION J CD4-301 Bwp07 9600.00 To 19813.28 ANTI~COLLIeION 9ETT1NG9 Inferpoletlon MONod MDIntervel t00.4a Cakuletlon Meth d MI I um Corvatvra Maalmum R 0 x177.fi1 ErtorM d I 19CW9A Scan McUOd. Trav. Cypntler North Error 9urlaca: Elllptkal Conlc Wamin9 Mefhotl: Rules Based .SIIRf~EY F'ROC:I1A1,1 ua<: xodi-ti-xaran:oo,oo v.llda<d: vM c.de~: tkpn, rrem D<pm To. surt<ymlxn Ted el.no a+.nn rnaanl ~R C.,e CrBrv. c7Nanp Z'0-cvnosc 7X0.19 ?600.W (IMJOI IUr hI\VD (rued, CENJO)) 17~\'Ur1I~R-.1k-C.\ZSC venrtnn IsXO.xa rT>vanlm.pa7lrrdhn:cw~otnryup mwD.l ~-nh-r>t~cc trdinale (NIE) Reference: Well Rig: CD4-307, Trve North lerticai (ND) Reference: Rig: CD4-301 (36.9+19) ~ 55.90ft (Doyon 19 (36. 79)) Section (VS) Reference: Slot - (O.OON, O.OOE) esured Depth Reference: Rig: CD4.301 (36.9+19) (~ 55.90ft (Doyon 19 (36. 79)) 0 / 360 C CI tICa[ [SSl.It:S: 1 0!360 From Colour To MD -150 / 210 f _ _ 50_ ""~-°~ 4. ~ j - CD4.801 Rlg 3urvays -180 / 180 CD4-301A Rig Survays Travelling Cylinder Azimuth (TFO+qZI) [°] vs Centre to Centre Separation Geodetic System: US Stale Plane 1983 Delum: North American Datum 1 Ellipsoid: GRS 7880 Zone: Alaska Zone 4 SECTION DETAILS Stt MD Inc Azi TVD +NlS +FJ•W DLcg TFace VSec Target 1 9600.00 69.40 107.78 777,5,80 -2398.11 7175.31 0.00 0.00 4283.00 2 9645.00 68.62 109.24 779192 -2411.4,5 7215.15 3.50 120.00 4306.80 J 11911.60 67.42 20.76 5897.09 -1692.85 8878.80 7.50 -114.53 4067.58 4 13455A8 63.42 20.76 6584.77 -001.77 9328.20 0.00 0.00 -2957.37 5 14663 97 86..50 377.70 6906.74 737.55 9751.51 3.50 fi3.36 -1871.54 6 . 14813.97 86,50 743.70 691.5.90 878.25 9309A9 0,00 0.00 -1721.82 CD4JO1Hwp06 South 7 17818.Y7 86.50 343.70 6916.21 883.04 9308.08 0.00 0.00 -1716.8) B 17939.98 90.00 343.70 6919.90 999.11 9277.14 2.89 0.04 0 00 -1595.90 06 North 73 CD4-301Hw 3277 9 1981718 90.00 ;W7.70 6919.90 5676.47 7906.18 0.00 . A p . ConocoPhillips(Alaska) Inc. -WNS I~"'~/~-L.L.IBU1~~'C~RI Western North Slope Anticollision Summary Report for Rig: CD4-301/CD4-301Bwp07 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD4 Nanuq Pad -Rig: CD4-301 -Prelim: CD4-301 B (9k) -CD4-301 Bwp07 Scan Range: 9,600.00 to 19,813.28 ft. Measured Depth. Scan Radius is 2,177.64 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Reference Well Comparison Weil Proximity Measured Vertical Measured Vertical Between Between Relative Site Name.. Depth Depth Depth Depth Centres Eilipsolds North Clearance (ft) Bearing Factor Warning ft Comparison Well Name -Design (ft) (ft) (ft) (ft) ) ( CD1 AlpinePad-= CD4 Nanuq Pad Survey tool program From To Survey/Plan Survey Tool (ft) lft) 81.00 444.00 CB-GYRO-SS 480.19 9,600.00 MWD+IFR-AK-CAZ-SC 9,600.00 19,813.28 CD4-3018wp07 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 28 December, 2007 - 15:39 Page 2 of 4 COMPASS ConocoPhillips(Alaska) Inc. -WNS NLL~~R~~ Western North Slope Anticollision Summary Report for Rig: CD4-30'UCD4-301Bwp07 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Rig: CD4-301 (36.9+19) Q 55.90ft (Doyon 19 (36.9+19)). Northing and Easting are relative to Rig: CD4-301. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150A0°, Grid Convergence at Surface is: -0.93 °. on Ladder Plot 15~- Q uCi C f~7 ([1 ~' ~f7 C N f~ ~~ ate-. C tl} U' I - I I I I I ( I I A 1 I I I I I I I I I I I I I t I I I I I I I I I I I I I I I I I - 1 ~ 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 I I t I ~ ~ I I ~ I --- J I I I I ----I---- - I I I I I 1 I ( ----J_-_ _-._-1___ I I Y I ----'i---- i i I I .. _.. .. .J_-_.. - I - --- I I I I I I i I I I I I I I I t I I ~ I I I I I i I I I I I I I 1 I ~ I i ~ t I I ' 1 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 D 3~Ii~0 ~(J100 1Q~t~l~ 1~C100 175QQ Measured Depth (~~Q~ ft~in~ LEtiEND '>~C" P:1g:CDt.'1qt.TDtd:GD1~IR.GDiU1AItIg~lNeytttq RIg:C01,7g1,TDed:GDi<7g1,CD1~7q1 RIgS14#yt VO ~- CD ti2z9 Qlft a No •). Ga t23g, Cat-,229 V 1 PIw!11: GO t-49, G p' ~ ~, ~t1 t-49 pkltm~ V2 .~ CDJ.lgT, P b-; G D3-tD7A. Ca3-iq'A~pgi Y t GD it'11a, C D1-0tf, GDl-0S Vq ~° GD 4q6, G D4-DS, GDS-051upa1 tiff CD 4{It ,Gat-Dt , GDt-0t t/ 1 .c~ Ctki~1T,CDi-0t,Cbi•OtapigVi6 ~+ CD 1.2D8, G al 2gF. C D 1.288 titT +~} GO1,2Dtt,GDl2gEP0i,GDl2g8pli tii6 CD iy2g9, C 01 205. CD42g9 Vl .~. CD i^slD9, C Dl-zq5, C D 1209gpgt Y3 .~. GOi-~1q.C0121C,G0i-2tg V3 *~« Cp/~21q,C01=21(;,CDt2tgrrpgitir~ .~}. GD1811,CD12tt,GDl21t vz * C013g2,C01~3gi,CDt~7qZ V3 ~- CD 1~3gz,CDl~3gs,Gal-002apDZYt ~+ GD l~ql. C 01~3g1, GD1-3111 VB *~ G013Dl,GD#-3gl,GD4701gpgT Yl ~^ GDI~lD+1,GD1~7g1p91,GDi-3gtP11 VtB . CD i,2gtt, C D1~3gE, CD 4-0q6 ti! t gpt,~R6,QD#-lftE,4Rl~ilktlpllP vg Na~Aq~.NasRgs Na1~q~V1 NaMigS, PIa~:CDlii12,Ga1211"MpD1 Yi PIa~:G01~3D3,P6~:Ga1,9g3,CD1~3g3wpq6V9 -~- PIa~:CD1~g3,PIati:CDtJDdSTt,COt~g3ST1wpD5Vi -~ RIg: G a l,'101, P m ~: G d 101 A ~(t 3F), G O 1301 A Ylpq's V3 -~ RIg:CD~~Dt,Tpea:GDtaat,catiaDtxpa3va -~} RIg:Ca~.301,TDetl:CD~-aatA,COi.~tArJp05V3 .g. Ga+a01 D tiupOT SS • 28 December, 2007 - 15:39 Page 3 of 4 COMPA ConocoPhillips(Alaska) Inc. -WNS E'"IA.LLIBlJRTC~~11 Western North Slope Anticollision Summary Report for Rig: CD4-3011CD4-301Bwp07 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor LEGEW^ ~^ RIg:CDi-aD1,TDeG:CD~~DIA,CD~~01ARIg8~uRy~VD ~ pg:Cdl~01,Toed:CL1~~01,CGl~~iRlgS~tuevx'U~ ~- FIk~:CD~JD1,PIa~:GD~~018 Q7k),CDt~D18MippGV3 Rg:CD;701,TDeG:C0~~01,CD~~01Y1pD3V~ .~. Rg:eD~aDt,TDed:cD~aD~a,cD~.:Dta~posua 28 December, 2007 - 15:39 Page 4 of 4 COMPASS Oparelor iI.W: Weft uff sede.e te.ollon Comment L ~. 01 O U f 0) 0) 2 E m CenoeePhlRpNAbrka)be. •WN1 W.N.m Nodh Slop. wwonwpor ~N/A x, tstelse.:f n y, srsnrl.]e R POOL: CD4-3016wp07 Plan: 6790' to 6910' TVDss CD4-302: 6790' to 6910' TVDss CD1-40: 6790' to 6910' TVDss CD1-46: 6790' to 6910' TVDss CD1-229P61: 6790' to 6910' TVDss A 90 leb No: AN/A Grid Gert.cibn: . 12]I • AF] Ne: 0.N/A Me9n.lle Deeenollen: eN/A Mp e0.fd II • API Ne: SYN.m (NO) 0..I.r.nc.: M.en Sea lsv.l Dp9b9 Per ~flglnal VS Plan@: 100 344.00 PmenlW.1: 0.b: CD4-S01 9D s ss Vlew VS Plane: 344.00 ese x.lpnc . uMl srNem: APi eared / IPS Hcllpn {VS)0..I.ren<r. Sbl oPlan View S g 8 ~ g $ g g R R S 9 $ 977000 976000 '.975000 974000 X973000 1972000 1971000 1970000 1969000 5968000 5967000 5966000 5965000 64000 63000 64000 '61000 160000 159000 >SB000 757000 156000 155000 954000 953000 7000 comma ~ of ~ fCnd 301 Bwo07 Toolbox.xls) 12/31/2007 11:20 AM 7 V ~ ~ ~ 1~ a0 O` O~ N ~ ~ ~ ~ (V 1 Verticgl Section along "View VS Plane" Closest in POOL Closest A roach: Reference Well: CD4-3 01 Bw 0 7 Plan C?ffsefi Well: =CD 4-302.... Coords. - C oords. - ASP 3-D ctr-ctr •` ' Meas. Subsea ASP N(+)!S(-) View VS ° nts C Meas. De th I cl. An le S TRUE Azi. T ubsea VD N(+)/S(-) E + /VN - View VS 344° ommen s Distance. " > De th I ncl. An le T RUE Azi. TVD E + IW - 344 omm POOL Min Distance ( 3610.8 ft) in POOL POOL Min Distance (6790 - 6910 NDss) ( 3610.8 ft) in POOL t o CD4-301 Bwp07 Y (6790 - 6910 TVDss) Plan (6790 - 6810 45 356 25 28 6790 5957428 1527640 -2303.17 to CD4-302 (6790 - 6910 TVDss) 9460.28 44.47 96.73 6927.13 5956610 1524125 -2178.74 NDss) 361().8 Closest A roa ch: 14225 Referen 77. ce Well . : CD4-3 . 01Bw 0 7 Plan Offset W ell: Cp l-46 Coords, - Coords. - ASP 3-D ctr-ctr t3; Meas. Subsea ASP N + /S O (-) View VS ° Meas. De th An le Incl TRUE Azi. Subsea TVD N(+)/S(-) E + /W - View VS 344° Comments Distance. De th Incl. An le TRUE Azi. ND E + /W - 344 Comments . POOL Min Distance (5071.46 ft) in POOL POOL Min Distance (6790 - 6910 TVDss) (5071.46 ft) in POOL to CD4-301 Bwp07 (6790 - 6910 NDss) Plan (6790 - 6910 7 894 6864 5962820 1526206 3276.726 to CD1-46 (6790 - 6910 TVDss) 10984.94 64.79 158.66 6919.39 5967654 1527740 -7942.99 NDss) 5071.46 "~ :` 19813.28 90 343. . C ll D1 40' nce Well f R : CD4-3 01Bw 07 Plan Uffset, : We - Closest A roach: ere e Coords. - Coords. - ASP 3-D ctr-ctr ' Meas. Subsea ASP N(+)/5(-) View VS ° Meas. De th An le Incl TRUE Azi. Subsea TVD N(+)/S(-) E + /W - View VS 344° Comments Distance. De th Incl. An le TRUE Azi. TVD E + /W - 344 Comments . POOL Min Distance (7634.66 ft) in POOL POOL Min Distance (6790 - 6910 NDss) (7634.66 ft) in POOL to CD4-301 Bwp07 (6790 - 6910 TVDss) Plan (6790 - 6910 90 343 7 894 6864 5962820 1526206 3276.726 to CD1-40 (6790 - 6910 TVDss) 10274.99 58.98 200.85 6914.65 5969252 1522093 -4956.52 TVDss) 7634.66 19813.28 . . Offset Well: "C D1-229PB1 Closes t A roach: Reference Wel l: CD4- 301 Bw 07 Plan Coords. - Coords. - ASP 3-D ctr-ct r ': Meas. Subsea ASP N + /5 - O ( ) View VS ° ments C Meas. De th Inc(. An le TRUE Azi. Subsea TVD N(+)/S(-) E + IW - View VS 344° Comments Distance. -r~::c; De th incl. An le TRUE Azi. TVD E + /W - 344 om POOL Min Distance (3770.22 ft) in POOL POOL Min Distance (6790 - 6910 NDss) (3770.22 ft) in POOL to CD4-301 Bwp07 (6790 - 6910 NDss) Plan (6790 - 6910 0 343 894 7 6864 5962820 1526206 3276.72 to CD1-229PB1 6 (6790 - 6910 TVDss) 1230 3 45.24 166.43 6913.28 5966090 152808 2 -9626.64 TVDss) 3770,22 v 19813.28 9 . . C~ 1213112007 11:01 AM CD4-301Bwp07 POOLSummary.xls ~ ~ ~ ~ 4 4/3/07 AG GD C.A. UPDATED PER K07041 ACS 3 0'. CZ ~ DB ~ C.A.~ UPDATED PER K06059ACS ~ ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.24, T 11 N, R 4 E, U.M. SEC.LINE 0 S EXIST ,.,~~ ~ ~~~ 'Y' I nT lNl LONG.(W) FSL EL GND PAD CD4 `201 5 957 273.28 1 518 208.24 70' 17' 31.779' 150' S9 22.030 2397 70 12.4 19.0 CD4-202 5 957 268.38 1 518 188.64 70' 17 31.728 150' 59' 22.599" 2392 90 12.4 19.6 6 19 CD4-203 5 957 263.99 1 518 169.26 70' 17 31.681 150' 59 23.162 ' 2387 82 109 128' 12.4 4 12 . 19 5 CD4-204 5 957 259.26 1 518 149.87 70' 17 31.632 ' S9 23.725 150 293' ' 59 24 23 2377 148 . 12 4 . 19.5 CD4-205 CD4-206 5 957 254.43 76 5 957 249 1 518 130.28 1 518 110.87 17 31.581 70 70' 17 31.532 . 150 150' S9 24.857' 2372 167 . 12.4 19.6 CD4-207 . . 5 957 245.29 1 518 091.49 70' 17' 31.485" 150' 59 25.419" ' ' ' .2367 186 ' 12.4 4 12 19.7 19 8 CD4-208 5 957 240.13 1 518 071.80 70' 17 31.431 " 25.991 150 S9 " ' ' 2362 206 226' . 4 12 . 7 19 CD4-209 5 957 235.77 1 518 052.15 70' 17' 31.385 26.561 59 150 ' 2357 . 12 4 . 6 19 CD4-210 5 957 230.92 1 518 032.98 70' 17 31.334 S9 27.118 150 ' ' 2352 2348' 245 264' . 12 4 . 0 20 CD4-211 5 957 226.94 1 518 013.75 70' 17 31.292 243" 7 31 7 ' 27.676 150 59 238 150' 59' 28 2343 283' . 12.4 . 19.6 CD4-212 CD4-213 5 957 222.25 5 957 217.19 1 517 994.40 1 517 974.60 . 0 1 70' 17 31.190' . 150' 59' 28.812 2337' ' 303 12.4 19.9 CD4-214 5 957 212.46 1 517 955.51 70' 17 31.140 ' 150' 59 29.367 7 ' 2332 2327' 322 341' 12.4 12 4 19.8 19 8 CD4-215 5 957 208.07 1 517 935.87 17 31.094 70 ' 59 29.93 150 495' 150' 59 30 2322 361 . 12.4 . 19.5 CD4-216 CD4-217 5 957 203.17 80 5 957 198 1 517 916.63 1 517 897.14 17 31.043 70 70' 17 30.997 . 150' 59 31.061 2318 380 12.4 19.5 CD4-318 . 5 957 193 71 1 517 877.38 70' 17' 30.944 150' 59 31.634 2312 400 12.4 19.6 CD4-319 . 5 957 189.64 1 517 857.90 70' 17' 30.900 150' 59 32.200" " 2308 419 12.4 19.7 . 19 7 CD4-320 5 957 185.03 1 517 838.65 70' 17 30.852 150' S9 32.759 2303 438 12.4 . 0 19 CD4-321 5 957 180.22 1 517 819.26 70' 17 30.802 150' S9 33.322 ' 2298 ' 458 12.4 . 19 0 CD4-X22 5 957 175.24 1 517 799.90 70' 17 30.749 150' S9 33.884 2292 ' 477 12.4 . 0 19 CD4-X23 5 957 170.76 1 517 780.38 70' 17 30.702 ' 150' S9 34.450 ' 2288 2283 496 516' 12.4 4 12 . 0 19 CD4-X24 5 957 166.23 1 517 760.82 30.655 70' 17 603" 7 30 ' 59 35.018 150 584' 150' S9 35 2278 535 . 12.4 . 19.0 CD4-X25 CD4-X26 5 957 161.34 5 957 157 10 1 517 741.31 1 517 721.97 . 1 70 70' 17 30.558" . 150' 59' 36.146" 2273' 554 12.4 19.5 CD4-227 . 5 957 151.94 1 517 702.56 70' 17 30.505 150' 59 36.709 2268 574 12.4 19.6 KUUKPIK NOTES: £ ~ 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. - ~^~^~,.~„~ 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) q~Pj„e survey Office ALPINE MODULE: CD40 UNIT: CD C~no~~Phllllps ~ ALPINE PROJECT CD-4 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE N0. DRAWING N0: PART: REV: 05-03-03-1B-2 10/11/05 CE-CD40-121 2 of 3 4 CD4-301B New Permit to Drill 12-31-07 Regg, James B (DOA) l~ Page 1 of 1 From: Woods, Nina [Nina.Woods@conocophillips.com] Sent: Monday, December 31, 2007 3:33 PM To: Regg, James B (DOA); Davies, Stephen F (DOA) Cc: Johnson, Vern(Halliburton Energy Services); Alvord, Chip Subject: CD4-301 B New Permit to Drill 12-31-07 Attachments: CD4-301 B new permit to drill 12-31-07.pdf Gentlemen, Attached is the scanned copy of the 401 Permit to Drill application for CD4-301 B. The following changes were made: • Drilling Hazards Summary Page: Updated Mud weight for both 8-3/4" hole and 6-1l8" hole to 10.6 ppg • Step #2 of the drilling procedure updated to include correct TD for 8-3/4" hole of 14,940' MD • Updated Planned Schematic with correct Surface casing depth of 3,046' MD • Pages # 1-4 of directional plan survey in NAD 27 format Please let me know if you have any further questions or concerns. Thanks, «CD4-301 B new permit to drill 12-31-07.pdf» Nina Woods Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907) 575-3256 12/31 /2007 ConocoPhillips Alaska, Inc. Post Office Box 100360 ^ `/ • • Anchorage, Alaska 99510-0360 ~ ConocQP'hillips Telephone 907-276-1215 \~ ,~I December 31, 2007 ~~'' Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 ~~ F (~ ~ ~ ~ I Anchorage, Alaska 99501 ~i taska tai! f~ C~ _. ~~~~~l~i~>g~~~ Re:Application for permit to drill: CD4-3016 v x ~ ~ -~. .._, a Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies f a Permit to change the approved program for CD4-301 B. The intended start date for this work is 01/ /2008. Operations for CD4-301A began on De tuber 21st, 2007 with Doyon 19. While drilling the intermediate section on December 23rd, operations ncountered an overpressured Kuparuk formation. Per well control guidelines, CD4-301A was sh in and monitorecT'at surface. Circulation was shortly resumed following stabilized well conditions a which time the wellbore packed off and circulation was lost. The BHA was stuck in the hole and It s decided to plug back the existing well bore with cement, and sidetrack to another in board loca on west of the previous location (CD4-301 B). 'z'°'° N""~tO"r s°`' `~'~ °"`~'~ The old wellbore, CD4-301A wi be abandoned with a cement plug which will also cover the Nanuq ~Z~ 3(07 sands. An additional plug will a set for kicking off. (See sundry application submitted 12-31-07 for more information). A mud gap wil a left between the kick off plug and the abandonment plug. The well, CD4-301 B, will be kicked off at approximately 9,600' MD and re-landed in the Kuparuk C sand horizontally. After setting and cementing 7 intermediate casing, the well will be suspended and Doyon 19 will move to CD3 to optimize drilling time during the short ice road season. The horizontal section will be drilled by either Doyon 19 or 141 later and completed as a slotted liner producer. The well will be flowed back to mitigate formation damage and then be closed in awaiting completion of well work for the well to begin production. It is expected that both the K2 (Qannik) and the Nanuq sand will be considered a significant hydrocarbon ~' bearing zone. The Nanuq sand will be cemented 500' above top of the sand with the primary cement job. For the Qannik sand (K2), it is planned to use a stage tool for a two stage cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. The 8-3/4" plugged back hole will maintain the name CD4-301A and once re-drilled the new sidetracked hole will become CD4-301 B with an API extension -02. ~ Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 "APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2: A proposed drilling program 3. A drilling fluids program summary. 4. Proposed plug back schematic 5. Proposed completion schematic 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b)• • Information pertinent to the application that is presently on file at the AOGCC: 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 Nina Woods at 265- 6403, Liz Galiunas at 265-6247, or Chip Alvord at 265-6120. Sincerely, Nina Woods Drilling Engineer Attachments cc: CD4-301A Well File /Sharon Allsup DrakeATO 1530 Chip AlvordATO 1577 Vern JohnsonATO 1702 Jack WalkerATO 1740 Lanston Chin Kuukpik Corporation • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ia. Type of Work: a 1b. Current We11 Class: Exploratory ^ Devebpment 01 ^ • 1c. Speciry'rfwell is proposed for. ^ ~as Hydrates d M th Doll ^ Re-doll 0 Stratigraphic Test ^ Service ane e ^ Development Gas ^ Coalbe ^ G l Re-entry ^ Multiple Zone ^ Single Zone ^ as Sha e Bond: ~ Blanket Single Well 5 11. Well Name and Number. .Operator Name: . 59-52-180 Bond No CD4-30iB ConocoPhiilips Alaska, Inc. . 6. Proposed Depth: 12. Field/Pool(s): ~. Address: P.O. Box 100360 Anchorage, AK 99510-0360 MD: 19813' TVD: 6920' Colville River Field la. Location of Weil (Governmental Section): 7. Property Designation: ` Nanuq Kuparuk Oii Pooi Surface: 2882 FNL, 70 FEL, Sec. 24 , T 11 N R 4 E ~ ADL 380077, 384211, 372097, 380082 Land Use Permit: 6 13. Approximate Spud Date: fop of Productive Horizon: . 12!31!2007 1000 FEL, Sec. 20 , T 11 N R 5 E 2005 FNL LAS2112 , iota) Depth: 9. Arras in Property: 14. Distance to Nearest Property: .> 1.86 mi from ADLy~9*90~~ 2491' FNL, 2381 FEL, Sec. 17 , T 11 N R 5 E 5759 fZ • $ /• ~''7 ~ aZ'~' Location of Well (State Base Plane Coordinates): 4b 10. KB Elevation 15. Distance to Nearest Well within Pool: . Surface' x- 378174.73 ~ y- 5957526.12 Zone- 4 (Height above GL): 55.9 MSL CD4-302 3610.8' at 14225' MD i ~ iGckoff depth: Deviated wells: 16 9600 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) . Maximum Hole Angle: 9D° deg Downhole: 3778 psig ' Surface: 3086 psig Setting Depth Quantity of Cement 1 e. Casing Program Specifications Top Bottom c. f. or sacks Si ze TVD (including stage data) Hole Casing Weigh Grade Coupling Length MD TVD MD ' re-installed 24" 16" 62.5# H-40 Welded 77 37 37 114 114 p 12.25" 9-5/8" 40# L-80 BTC 3009 37 37 3046 2387 389 sx AS Lite, 259 sx 15.8 G g 75" 7" 26# L-80 BTCM 14903 37 37 14940 6920 481 sx Class G, 185 Sx class G for K2 69 bi 5" 3 9.3# L-80 EUE 14768 32 32 14800 68 tu ng 125" 6 . 5" 3 9.3# L-80 SLHT 5023 14790 6669 19813 6920 Slotted Liner . . PRESENT WELL CONDITION SUMMARY (To be com pleted for Redrill and Re-Entry Operations} ; 1 g Total Depth MD (ff): Total Depth TVD (R): Plugs (measured) Eftedive Depth MD (H): Effective Depth TVD (ft): Junk (measured) TuD Casing Length Size Cement Volume MD Conductor/Structural 77.00 16" 114 114.00 Surface 3,009.00 9-518" 389 sx AS Lite, 259 sx 15.8 G 3046 2,387.00 I termediate ] n Production er Li n Perforation Depth MD (ft): Perforation Depth TVD (ft): Attachments: Fling Fee ^ BOP Sketch 20 Drilling Program ^/ Time v. Depth Plot ^ Shallow Hazard Analysis ^ . r Sketch^ t ^ Di Seabed Report ^ Drilling Fluid Program Q J 20 AAC 25.050 requirements ^ ver e Propedy Plaf Verbal Approval: Commission Representative: 21 Date: . 22. I hereby rectify that the foregoing is true and coned to the hest of my knowledge. Contact N Woods Printed Name C. Ivord Title WNS Drilling Team Lead Signature ~ ~/,Q ~~~---aaa... f/'~ ~ Phon 265-6920 Date 17/15/2007 Commission Use Only l it A See cover letter j Pennil to Drill API Number. pprova Perm ~~~' ~~U Number. 50. ~(~~ ~~SS7^0Z pate: for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbedrmfethane, gas hydrates, or gas contained in shales: Yes ^ No [g 'd Samples req'd: Yes ^ No L10 : Mud log req s ~ ^ f ' HZS measures: Yes ^ No [~ Directiona d: e l svy req Other. APPROVED BY THE COMMISSION _ . _ MISS{ONER , COM U CD4-301 B Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further disc~ion of these risks) R_3/d" Hnlp / 7" Casino Interval Event Risk Level Miti ion Strate ~b• Abnormal Pressure in low BOPE drills, Keep ud weight abov ppg. ly' Surface Formations Check for flow d ring connections and if needed, >2000' TVD increase mud ei ht. Lost circulation Low Reduced pu prates, reduced trip speeds, real time equivalent irculating density (ECD) monitoring, mud rheolo ost circulation material Hole swabbing on trips Moderate Reduc d trip speeds, mud properties, proper hole fillin pumping out of hole, real time equivalent cir lating density (ECD) monitoring, weighted s ee s. Abnormal Reservoir low ell control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers R_1/St" Hnla~ / Hnri~nntal Prnrf'~~ctian Hole Event Risk evel Miti ation Strate Lost circulation m derate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. a. to Abnormal Reservoir Medium BOPE drills, Keep mud weight above , . ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers n v M n/ 'n t "/ ~,o~ gi,c~7 • Nanuk-Kuparuk : CD4-301 B Procedure 1. Pick up and run in hole with 8-3/4° drilling BHA. 2. Kick off old wellbore at +/- 9,600' MD and drill 8-3/4" hole to intermediate casing point in th Kuparuk C sand +/- 14,' MD. (LWD Program: GR/RES/PWD) 3. Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect Iasi annulus and casing. 4. Pickup and run +/-1500' 4-1/2" tubing as a circulation string. 5. Pick up hanger, land hanger, run in lock down screws and test seals to 5 0 psi. 6. Set and test two way check. 7. Nipple down BOP. 8. Nipple up and test tree. 9. Pull two way check. 10. Displace to diesel freeze protection through tubing i ~ 11. Set back pressure valve. ~ m 12. Rig down and move off Doyon 19. ~ 13. Return to well with either Doyon 19 or Doyon 1 14. Nipple down tree and nipple up BOP 15. BOPE test to 3500 psi. 16. Displace diesel to brine through circulatio string. 17. Pull 4-1/2" tubing string and lay downs me. 18. Pick up cleanout assembly and run i hole. 19. Clean out stage collar and float sh e. 20. Test 7" casing to 3500 psi and p II out of hole. 21. Run drilling assembly. Drill o and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 1 .0 ppg EMW. 22. Dril( 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 23. Circulate the hole clean and pull out of hole. 24. Run lower completion of 3'/z", 9.3# L-80 SLHT blank and slotted liner and liner hanger. 25. Run upper completion of 3-'/z, 9.3#, L-80 tubing with SSSV, packer, 3 GLMs with shear out valve in bottom mandrel, XN profile and wireline entry guide. Land hanger. 26. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. • 27. Install tubing head adapter assembly. Pressure test adapter assembly to 000 psi. Remove 2 way check. 28. Circulate tubing to diesel and install freeze protection in the annulus 29. Drop ball and rod, set packer and test tubing and annulus to 35 psi / 30 mins. 30. Shear valve in the gas lift mandrel. 31. Set BPV and secure well. Move rig off. Post rig well work will include pulling the ball and rod ~sembly, and GLV change out. `' J M ~N . • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD4-302 is the nearest existing well to the CD4-301 B plan with 8.6' well to well separation at 523' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting and low reservoir pressure within the Kuparuk reservoir section is c sidered to be the most likely cause of lost circulation. Standard LCM material and well bore streng ening pills are expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing ick w n drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize t e of ial of taking swabbed kicks. ~ 0 ~~ ~~ Annular Pumping Operations: ~/ Incidental fluids developed from drilling operations on well CD4-301 II be injected into a permitted annulus on CD4 pad or the class 2 disposal well on CD1 pad. The CD4-301 B surface/intermediate casing annulus will be flushe ~ th 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydro zones are the Nanuq, Kuparuk, and the Qannik reservoir. There will be 500' of cement fill above the t p the Nanuq and Qannik reservoirs. Upon completion of CD4-301A form 10-403, Application for S dry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regula ' n 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing sig ficant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open b ow the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclo ed directional drilling plan for other formation markers in this well Surface casing will be set near the base of the Schrad r Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to pr vide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down he annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid ensities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid d the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum press eat 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)' (2387') + 1,500 psi = 2989 psi Pore Pressure = 1,086 psi Therefore Differential = 2989 -1086 = 190 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: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2,992 psi 7" 26 L-80 3 8TC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi r C~ DRILLING FLUID PROGRAM • Intermediate hole to 7" casin oint - 8 3/" Production Hole Section - 6 1/8" Density 10.6-11 ppg / 10.6 ppg /" PV 10 - 25 10 -15 YP 15 - 25 25 -30 Funnel Viscosity Initial Gels 4 - 8 10-15 10 minute gels <18 12-20 API Filtrate 4 -12 cc/30 min NA HPHT Fluid Loss at 160 (drilling) 12-14 cc/30 in PH 9.0 - 1 0.0 9.0-9.5 KCL D 6% Intermediate Hole Section: P., Fresh water gel /polymer mud system. Ens re good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is p tential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or Belo 108 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and intenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will a drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carb Hate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for iscosity and fluid loss control respectively. • • CD4-301A Pluaback Schematic RKB-GL=36.3' Updated 12/31/07 ~~ Wellhead 16" Conductor to 114' 9-5l8" 40 ppf J-80 BT M Surface Casin @3046'MD/23 'TVD 10.8 ppg drilling mud in hole KOP 9,600' Tou Nanua Reservoir at +/-12 855' -13.428' MD .^ ~~ ~'` J ~\• N Plua #2 • 600' Kick off olua Too at +/- 9404' MD 17.0 ooa. 30 bbls~Vis ~ X200 ft Pi Plug #1 : +/- 700' Too CrD 728 +/-12 700' MD 17 0 ooa BHA Fish ~ / TOF 13445' BOF 15319' Hole @ +/- 85 deg TD at +/- 15,431' MD ~ Completion Schematic Planned v m C 16" Insulated Conductor to --114' 2 Jts 4'/=" 12.6 ppf L-80 IBT Mod Tubing 3-''/z' X 4-''/z' Cross over X2.813" TRMAXX-5E SSSV 9-5/8" 40 ppf L-80 BTCM Surface Casing 3064' MD / 2387' TVD 3-''/z' 9.3 ppf L-80 EUE Mod Tubing Cement to +/- 7160' ~ MD ! 3901' TVD Qannik interval top +/- 7660' MD / 4080' TVD Stage cementing tool +/- 8188' MD / 4270' TVD Top of cement ~ 12365' MD / 6004' TVD (+/- 500' above Nanuq) Top Reservoir at +/- Nanuq 12874' MD / 6206' TVD Kuparuk 14818' MD / 6916' TV~ Sperry Sun Directional Plan WP07 12/31 /07 C I i Items 1) Tubing nger 32' 32' 2) 4?h" 1 .6 #/ft IBT-Mod Tubing 2 jts 3) 3-'/z" 4-'/z" Crossover 4) 3?/' 9.3 #/ft EUE-M Tubing ' 5) C co TRMAXX SCSSSV W/ X profile (2.812") 2207' 2000 6) ?/i' 9.3 #/ft EUE-M Tubing 7) Camco KBMG GLM 5796' 3400' 8) 3?h" 9.3 #/ft EUE-M Tubing 9 Camco KBMG GLM 71472' 5600' 0) 3-'/i' 9.3 #/ft EUE-M Tubing ' 11) Camco KBMG GLM 13640', 6513 With DCk-2 shear out valve (pinned for 3000 psi) 12) 3-'/i' 9.3 #/ft EUE-M Tubing (2) ' 13) Baker Premier Packer 13720' 6546 14) 3?/~' 9.3 #/ft EUE-M Tubing (2) 15) HES "XN" (2.725 Min ID")- 65° inc 13800' 6579' 16) 3 'h" 9.3 #/ft EUE-M Tubing 17) BOT Stinger w/fluted WLEG/ pup/shear sub 14787' 6869' 3' space out above top of liner ~ ower Completion: T ~ MD ND L~ 18) Baker 5" x 7" Flexlock Liner Hanger 14790'- 6869' 19) 3?/z', 9.3#/ft, SLHT Tubing +/- 3 jts 20) 3-'/:" 9.3 #/ft, SLHT liner w/ blank across shale and slots across sand 21) Baker Shce 19803' 6920' 3 '/2' 9.3#/ft L-80 SLHT Mod Slotted liner Pattern: 8 slots / ft, 2?/a" x 1/8" slots ---- n; 7" 26 ppf L-80 BTC Mod Production Casing @ +/-90° 14940' MD, 6920' TVD TD 6-1/8" hole 19813' MD / 6920' TVD ~ CD4301A PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this we f Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 3035 / 2387 14.5 1080 1561 7" / TD 14940 / 6916 16.0 3778 ~'' 3086 •~" N/A 19813 / 6920 16.0 3778 N/A NOTE: The Doyon 19 5000 psi BOP equipment is aaequate. i est rs~r s w ~w~ N~~. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the for ation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less 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 Ib/gal 0.052 =Conversion from Ib./gal to psi/ft v 0.1 =Gas gradient in psi/ft ' D =true Vertical depth of casing seat in ft RKB 1 n OR '~ 2) ASP =FPP - (0.1 x D) "/ Where;FPP =Formation Pore Pressure at the next sing point ASP CAL CATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =((10.9x0.052)-0.1]x114-53 psi OR ASP =FPP - (0.1 x D) = 1080 - (0.1 x 2387') = 841 psi 2.Drilling below surface casing (9 5/8" ASP = [(FG x 0.052) - 0.1 _ [(14.5 x 0.052) - 0 ] x 2387 = 1561 psi OR ASP =FPP - (0.1 x D) = 3778 - (0.1 x 6 16') = 3086 psi 3.Drilling below intermediat casing (7") ASP =FPP - (0.1 x D) = 3778 - (0.1 x 6920) = 3086 psi ~' Cementing Program: 7" Intermediate Casing run to 14940' MD / 6920' TVD r' Cement from 14940' MD to 12374 +/-' MD (minimum 500' MD ab a top of Nanuq reservoir) with Class G + adds @ 15.8 PPG. Assume 40% exces annular volume. Tail: (14940' -12374') X 0.1503 ft3/ft X 1.4 (40% a cess) = 539.9 ft3 annular vol. 80' X 0.2148 ft3/ft =17.2 ft3 shoe joint volu e Total volume = 539.9 + 17.2 = 557.1 ft3 => 481 Sx @ 1 6 ft3/sk System: 481 Sx Class G + 0.2% D046 antifoer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss dditive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a ES stage ollar set 500' below the K2 interval to +/- 500' above the K2 interval with Class G + additives 15.8 ppg. Assume 40% excess annular volume Lead: (8188'- 7160') X 0.150 ft3/ft X 1.4 (40% excess) = 216.3 ft3 annular vol.. Total Volume = 216. ft3 => 185 Sk @ 1.17 ft3/sk System: 185 Sx Class G + .2% D046 antifoamer, 0.3% D065 dispersant and 1 % S002 accelerator @ 15. PPG yielding 1.17 ft3/sk a M~ fn° N V/ ~ • • TRANSMITTAL L`E~TTER C~H/ECKLIST,Q WELL NAME ~~1~. ~ 7" ' 3~ /JJ PTl># 2~ 7 - /8Z~ Development Service Exploratory Stratigraphic Teat Non-Conventional Well Circle Appropriate Letter / Paragraphs M be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new welibore segment of existing well (If last two digits in permit No. , API No. 50- API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all c~ecords, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- _) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest do the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no Beater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Weil for dame Qf well) until after (Com}~y Name) has designed and implemented a water well testing program to provide baseline dam on water quality and quantity. {Company Namel must contact the Commission to obtain advance approvat of such water welt testing ro m. Rev: 7!132007 WELL PERMIT HECKLIST Field & Pool COLVILLE RIVER, NANUQ-KUPK OIL -120185 _ Well Name: COLVILLE RIV NAN-K CD4-3018 Program DEV Well bore seg ^ PTD#:2071800 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 Unit 50360 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_feeattached__---__-_ _------------- ----- ---------- -- -- 2 Lease number appropriate_ - .. - Yes - - Surface location in ADL 3$0077, wellbore passes thru ADL 380082,1op- 3 lJnique well_name and numbe[ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . - _ - - _ _ - - - - - . - . Yes _ - - _ prod interval-in ADL 384211_, Tl) in ADL 372097_ _ _ - _ 4 We_II located in a-defined pool . - - Yes Colville-River Field,_ Colville River Unit, Nan_uq-Kuparuk Oil Pool, governed by Conservation Order No. 563. - 5 Well located proper distance_from drilling unit-boundary_ Yes Conservation Order No. 563 contains no spacing restrictions with respect_to drilling unit boundaries. 6 Well located proper distance-from other wells- . - Yes Conservation Order No. 563 has no in_terwell-spacing-restrictions, - 7 Sufficient acreage available in_drilling unit - - . - - - Yes - - exte-mat property line-where_ownershi o[landownershi -chan es. - p p g 1 8 If deviated,is_wellboreplat-included______ ________ _ __________ _ Yes_ ___.--.___ _____-- 9 Operator only affected party_________________ _ Yes- ---________.-._.--_ 10 Operator has_appropriate-bond in force - Yes 11 Permitcan be issued without conservation order_ - - - Yes - - - . - Appr Date 12 Permitcan be issued without administrative_approval Yes .. - - - 13 Can permit be approved before 15-day_wa_it- - - - - - _ _ - _ _ Yes _ _ _ SFD 12/3112007 14 Well located within area and strata authorized by-Injection Order # (prat_1O# in-comments)_{For_ Yes Colville_River Field,_Colville River Unit, Nanug-Kuparuk-Oil-Pool, governed by Area Injection Order 27 15 All wells within 114_mile area of review identified (For service well only) NA- 16 Pre-produced injector; duration of pre production Less than 3 months-(For service well only} . - NA- 17 Nonconven: gas conforms to A$31,05,030(~.1_.A),G2.A-pl NA 18 ---__-- Conductor string_provided - . - - NA, - -- r_edrill; see 207-150_ - ---------------- Engineering 19 Surface casing_proteetsoll known_ USDWS - . - .. - - - - - Yes no aquifers pe_r A1O18A, conclusion_ 3 20 CMT-vol-adequate_to circulate on conductor_& surf-csg . - Yes - - - redrill; see 207-150_ 21 CMT_vol_ adequate_to tie-in long string to surf csg_ _ _ _ _ No_ - - - . 22 CMT will cover all known productive horizons- - . - Yes - - - - -yes for Qannik and Nuqsut; slotted liner Kuparuk com letion p 23 Casing designs adequate for C, T, B & pemlafrost _ _ _ _ _ _ _ Yes _ _ _ 1 24 Adequate tankage-or reserve pit - . Yes - - - Rig equipped w/steel-pits; no reserve pit planned; wastes to approved annuli 25 If_a_re-drill, has-a-10-4.03 fo_r abandonment been approved Yes 307-386 26 Adequate welllwre separation proposed- - Yes proximity_analysislanti-collision_analysis performed. . 27 If_diverter required, does it meet regulations_ _ _ _ - - - - - _ - _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 28 Drilling fluid_program schematic_&_equip listadequate_ Yes Max anticipa_ted_formation.pressure updated to 10,6ppg EMW_(CD4-3Q1_A) ~ iZ 31 ~~ ~ ~ 29 BOPES,.do they meet_regulahon ~ Yes - _ - ~ ~ 30 BOPE_ ress ratin a ro Hate; test to ut si in comments .. p- 9 Pp p (p p 9 ) Yes - - MA$P calculated to be 3086 psi; 3500psi test 31 Choke_manifold complies w/API-RP-53 (_May 84)_ - - Yes . . - - - - - i 32 Work will occur without operation shutdown_ - . - - - - - - No_ temp S/l) after cementing 7" csg; drill horizontal_sectionofter ice road season - ! 33 Is_presence_ofH2Sgas_probable- - - - - - - No- rig equipped wlmonitoring-equipment- - - 34 Mechanical condition of wells within AQR verified fFor_service well only) NA_ 35 Permitcan be issued w/o_ hydrogen sulfide measures Yes - H2S not encountered in offset wells;-however, rig is equipped with sensors, Geology 36 Data-presented on potential oye-rpressure zones - - - - - - - - - - - - - - - - . - - - - Yes - _ _ - _ _ _ Estimated pressure is 10.5 ppg EMW based on drilling-of CD4-301A; productive-interval will_be drilled with _ - _ . _ Appr Date . 37 Seismic analysis_of shallow gas_zones_ _ _ _ - NA _ _ _ -10.6 ppg mud._ SFD 12/3112007 38 Seabed condition survey_(ifoff-shore) NA_ 39 Contact name/phone for weekly_progress reports-[exploratory only] - - - NA- - - - - -_---- Geologic Engineering Re-drill to new bottom hole location necessitated by loss of bottom hole drilling assembly and two nuclear sources in CD-301A. Commissioner: Date: Co~m;,missioner: Date o mi r r Date The trajectory of this well will lie about 300' west of, and parallel with, CD4-301A. ~~~~ ~~3~ ~ -D u Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made io chronologically organize this category of information. F cd4-301b.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Mar 12 15:30:13 2008 Reel Header Service name .............LISTPE Date . ...................08/03/12 Origin ...................STs Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/03/12 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF Comment Record TAPE HEADER Colville River MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW-000535576 J. BOBBITT D. BURLEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical services scientific Technical services CD4-3016 501032055702 ConocoPhillips Alaska, Inc. Sperry Sun 12-MAR-08 MWD RUN 4 MW-000535576 E. QUAM D. LUTRICK 24 11 4 E 2882 70 .00 55.90 19.00 Page 1 ~v`~ -(~6 ~IGb~O~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: • cd4-301b.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.750 9.625 3035.0 8.750 9.625 3035.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTRONMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-Phase 4), GEOPILOT ROTARY-STEERABLE BHA (GP), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AT-BIT GAMMA (ABG), PRESSURE WHILE DRILLING (PWD) AND ACOUSTIC CALIPER (ACAL). 5. MWD RUN 4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MULLER TUBE DETECTORS, ELECTRONMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-PHASE 4), GEOPILOT ROTARY-STEERABLE BHA (GP) AND PRESSURE WHILE DRILLING (PWD). 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. THIS WELLBORE WAS SIDETRACKED FROM CD4-301 OFF A CEMENT PLUG AT 9595'MD/4774'TVD. 8. MWD RUNS 1-2,4 REPRESENT WELL CD4-3018 WITH API#: 50-103-20557-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14860'MD/6911'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP Page 2 • ~ cd4-301b.txt SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.75" BIT) AVG OFFSET: ACAL-DERIVED MUD WEIGHT: 9.6 PPG MUD SALINITY: 300 - 450 PPM CHLORIDES FORMATION WATER SALINITY: 14545 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH NPHI 3009.0 9594.5 NCNT 3009.0 9594.5 RoP 3009.0 14860.0 PEF 3009.0 9594.5 RHOS 3009.0 9594.5 RPx 3009.0 14808.0 DRHO 3009.0 9594.5 RPS 3009.0 14808.0 FET 3009.0 14808.0 RPD 3009.0 14808.0 RPM 3009.0 14808.0 FONT 3009.0 9594.5 GR 3009.0 14821.0 Page 3 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED cd4-301b.txt ~, J DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 4 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 3009.0 9594.5 9595.0 14860.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MwD FPH 4 1 68 48 13 NPHI MWD PU 4 1 68 52 14 First Last Name servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 3009 14860 8934.5 23703 3009 14860 FCNT MWD CP30 525.14 2193.56 917.711 13172 3009 9594.5 NCNT MWD CP30 99438.6 161749 125743 13172 3009 9594.5 RHOB MwD G/CC 1.212 2.813 2.32615 13172 3009 9594.5 DRHO MWD G/CC -3.738 0.188 0.0331812 13172 3009 9594.5 RPD MWD OHMM 0.44 2000 22.879 23599 3009 14808 RPM MWD OHMM 0.42 2000 10.7304 23599 3009 14808 RPS MWD OHMM 1.5 1207.86 6.62531 23599 3009 14808 RPX MWD OHMM 1.26 1125.91 6.37019 23599 3009 14808 FET MWD HR 0.19 392.51 0.847153 23599 3009 14808 GR MWD API 47.96 459.42 121.229 23625 3009 14821 PEF- MWD B/E 2.04 13.97 2.79127 13172 3009 9594.5 ROP MWD FPH 0.77 482.85 168.049 23703 3009 14860 NPHI MWD Pu 15.74 59.47 33.7441 13172 3009 9594.5 Page 4 cd4-301b.txt First Reading For Entire File..........3009 Last Reading For Entire File...........14860 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER • FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 3009.0 9594.5 PEF 3009.0 9594.5 GR 3009.0 9594.5 FET 3009.0 9594.5 RPx 3009.0 9594.5 NPHI 3009.0 9594.5 RPS 3009.0 9594.5 RHOB 3009.0 9594.5 RPM 3009.0 9594.5 FONT 3009.0 9594.5 RPD 3009.0 9594.5 DRHO 3009.0 9594.5 CNT 3009.0 9594.5 $ LOG HEADER DATA DATE LOGGED: 18-DEC-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 5 ~ ~ MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ASLD cd4-301b.txt BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuthal Litho-Den BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LBfG): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 62.9 86.4 TOOL NUMBER 120557 145654 174114 143783 8.750 3035.0 Fresh water Gel 9.70 37.0 9.1 350 7.4 6.000 69.0 3.035 143.0 10.000 69.0 5.000 69.0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FONT MWD020 cP30 4 1 68 4 2 NCNT MwD020 CP30 4 1 68 8 3 RHOB MWD020 G/CC 4 1 68 12 4 DRHO MWD020 G/CC 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPx MwD020 oHMM 4 1 68 32 9 FET MWD020 HR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 Page 6 ~ ~ cd4-301b.txt PEF MWD020 B/E 4 1 68 44 12 ROP MwD020 FPH 4 1 68 48 13 NPHI MWD020 PU 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3009 9594.5 6301.75 13172 3009 9594.5 FCNT MWD020 CP30 525.14 2193.56 917.711 13172 3009 9594.5 NCNT MWD020 CP30 99438.6 161749 125743 13172 3009 9594.5 RHOB MwD020 G/CC 1.212 2.813 2.32615 13172 3009 9594.5 DRHO MWD020 G/CC -3.738 0.188 0.0331812 13172 3009 9594.5 RPD MWD020 OHMM 0.44 2000 13.7434 13172 3009 9594.5 RPM MWD020 OHMM 0.42 2000 10.16 13172 3009 9594.5 RPS MWD020 OHMM 1.5 1207.86 6.13762 13172 3009 9594.5 RPX MWD020 OHMM 1.26 1125.91 5.98767 13172 3009 9594.5 FET MwD020 HR 0.19 67.56 0.838732 13172 3009 9594.5 GR MWD020 API 47.96 202.11 118.52 13172 3009 9594.5 PEF MWD020 B/E 2.04 13.97 2.79127 13172 3009 9594.5 ROP MWD020 FPH 6.74 482.85 180.26 13172 3009 9594.5 NPHI MWD020 Pu 15.74 59.47 33.7441 13172 3009 9594.5 First Reading For Entire File..........3009 Last Reading For Entire File...........9594.5 File Trailer service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 9595.0 14808.0 ROP 9595.0 14860.0 GR 9595.0 14821.0 Page 7 ~ ~ cd4-301b.txt FET 9595.0 14808.0 RPx 9595.0 14808.0 RPD 9595.0 14808.0 RPM 9595.0 14808.0 LOG HEADER DATA DATE LOGGED: 05-JAN-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 57.5 MAXIMUM ANGLE: 8$.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 EWR4 ELECTROMAG. RESTS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3035.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 10.70 MUD VISCOSITY (S): 38.0 MUD PH: 9,9 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3): 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.600 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.224 152.0 MUD FILTRATE AT MT: 1.200 68.0 MUD CAKE AT MT: 2.200 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Page 8 r1 U cd4-301b.txt Depth Units. .. . . ..... Datum specificat ion Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPx MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 RoP MwD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9595 14860 12227.5 10531 9595 14860 RPD MwD040 OHMM 4.01 2000 34.4196 10427 9595 14808 RPM MWD040 OHMM 3.57 2000 11.4511 10427 9595 14808 RPS MWD040 OHMM 2.85 71.81 7.24139 10427 9595 14808 RPx MWD040 OHMM 2.47 32.57 6.8534 10427 9595 14808 FET MwD040 HR 0.25 392.51 0.857791 10427 9595 14808 GR MWD040 API 54.7 459.42 124.641 10453 9595 14821 ROP MWD040 FPH 0.77 280.19 152.776 10531 9595 14860 First Reading For Entire File..........9595 Last Reading For Entire File...........14860 File Trailer service name... .......STSLIB.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/03/12 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/03/12 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services writing Library. Page 9 scientific Technical services . • • cd4-301b.txt Physical EOF Physical EOF End Of LIS File Page 10
