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Home My WebLink About207-135Originated: Delivered to:19-May-24 Alaska Oil & Gas Conservation Commiss 19May24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1A-03 50-029-206150-00-00 181-088 Kuparuk River WL Plug FINAL FIELD 3-Feb-24 3S-22 50-10320446-00-00 203-011 Kuparuk River WL IBC-CBL FINAL FIELD 5-Feb-24 3M-05 50-103-20875-00-00 223-126 Kuparuk River WL Isealate FINAL FIELD 10-Feb-24 2F-15 50-029-21048-00-00 183-172 Kuparuk River WL Isealate FINAL FIELD 13-Feb-24 MT7-14A 50-103-20856-01-00 223-064 Greater Mooses Tooth WL PPROF FINAL FIELD 20-Feb-24 MT7-03A 50-103-20830-00-10 223-084 Greater Mooses Tooth WL PPROF FINAL FIELD 29-Feb-24 3G-27 50-103-20801-00-00 219-039 Kuparuk River WL TTiX IPROF FINAL FIELD 2-Apr-24 2W-17 50-029-23370-00-00 207-135 Kuparuk River WL PPROF FINAL FIELD 9-Apr-24 1E-23 50-029-20858-00-00 182-184 Kuparuk River WL IPROF FINAL FIELD 10-Apr-24 1E-01 50-029-20464-00-00 180-039 Kuparuk River WL IPROF FINAL FIELD 11-Apr-24 1D-37 50-029-22992-00-00 200-204 Kuparuk River WL PPROF FINAL FIELD 12-Apr-24 3G-09 50-103-20129-00-00 190-067 Kuparuk River WL Punch-Cut FINAL FIELD 13-Apr-24 2P-420 50-103-20391-00-00 201-182 Kuparuk River WL CIBP-Cut FINAL FIELD 15-Apr-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX Sampling FINAL FIELD 18-Apr-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private Eset # T38800 T38801 T38802 T38803 T38816 T38817 T38818 T38819 T38820 T38821 T38822 T38824 T38823 T38825 2W-17 50-029-23370-00-00 207-135 Kuparuk River WL PPROF FINAL FIELD 9-Apr-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.20 12:41:13 -08'00' WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϮϬϳϭϯϱϬͲ^Ğƚ͗ϯϲϮϳϮJRBy Abby Bell at 1:43 pm, Dec 21, 2021 3M-1750029217290000 KRU WLWFLFINAL FIELD24-Apr-213M-1950029217370000 KRU WLLDLFINAL FIELD25-Apr-213H-0150103200840000 KRU WLCHCFINAL FIELD26-Aug-213H-1250103200880000 KRU WLCCLFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCHCFINAL FIELD29-Aug-213H-1250103200880000 KRU WLCUTTERFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCUTTERFINAL FIELD24-Sep-211L-1250029220330000 KRU WLSBHPSFINAL FIELD6-Nov-213G-2450103201450000 KRU WLTBG CORRFINAL FIELD29-Oct-211A-2550029221160000 KRU WL WHIPSTOCKFINAL FIELD12-Oct-211A-2350029221310000 KRU WLRBPFINAL FIELD12-Jun-211R-2050029222070000 KRU WLPPROFFINAL FIELD2-Jun-212M-1150103201590000 KRU WLPPROFFINAL FIELD27-Aug-212M-0750103201780000 KRU WLBACKOFFFINAL FIELD5-Aug-211Y-1950029223910000 KRU WLPPROFFINAL FIELD31-May-212T-3050103202190000 KRU WLLDLFINAL FIELD2-May-211Q-20A50029225890100 KRU WLSET RECFINAL FIELD2-Aug-212M-3350103202400000 KRU WLLDLFINAL FIELD18-Oct-211F-03A50029208530100 KRU WLPERFFINAL FIELD19-Oct-211Q-08A50029212250100 KRU WLIPROFFINAL FIELD30-Apr-211E-3350029227970000 KRU WLPPROFFINAL FIELD26-Mar-211D-13550029228160000 KRU WLLDLFINAL FIELD16-Jul-213F-13A50029214990100 KRU WLGLSFINAL FIELD17-Jul-212N-318 50103203430000 KRU WLSCMTFINAL FIELD12-Nov-211C-12750029230240000 KRU WLIPROFFINAL FIELD17-Nov-213S-24A50103204560100 KRU WLCUTTERFINAL FIELD25-Oct-213S-0350103204580000 KRU WLIBPFINAL FIELD26-Oct-211B-2050029231640000 KRU WLPPROFFINAL FIELD22-Apr-211E-11950029231980000 KRU WLLDLFINAL FIELD26-Jun-212W-1750029233700000 KRU WLPPROFFINAL FIELD28-Aug-211H-11850029235780000 KRU WLIPROFFINAL FIELD4-Nov-211H-11450029235840000 KRU WLIPROFFINAL FIELD23-Jun-211H-11350029235880000 KRU WLWFLFINAL FIELD22-May-21 C:\Users\aebell\Desktop\April 2021 Data Drop\Read Cased Hole Data Drop 04272021\2021-04-23_15777_KUP 2W-17_LeakPointSurvey_AOGCC_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15777 KUP 2W-17 50-029-23370-00 LeakPoint Survey 23-Apr-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 2071350 E-Set: 35051 Received by the AOGCC 04/27/2021 Abby Bell 0 cu L ...-' jp(v) li ...) p •- •- . . . . . 1- x m moo - CD NOIn o C CO 4- -0 @ U O > r c ^Q O Ill! <10 H. yQYa V apW N N N N N N N Wa Q a Q Q a 1. NQp O N In r co N gl Oil pppppp Cl co 4-4 W J J J J J J J } W W W W W W W 0 OTca0▪ O N a)Eov ? a -,S vcO - C ro uL o a+ ` +U -0 r0 ° Na) E U O c Lo 2 • a) 0 O pcN L ODC4U 4-C) 4-, n N 1- LL LL LL LL LL LL LL , ) (I) a) -0 Q J J J J J J J O" _ +_-' -- 1- aaaaaaa a '^ , .c 4- z O c Z Z Z Z Z Z Z v s v 4E. v LL LL LL LL LL LL LL cC — > r0 > +O-, 4) a 4-4 co O L ° U O B z - v " > U 0 CO `°on ' .. • O R. a Y ( c u a a) a o c a 761 G O 0 p J 0 0 0 c g Y 'I y G m a s f- u) a W sO pa, < d a0h z Li y x al al W o es 0 t▪o V d J J J J J J J , d i° '� E33333 3 es �i CI 4 Z W V t.)11c..1...1 LU CZI 4. W W W W W W W 4 dee VI W > > > > > > > z Y Y Y Y Y Y Y a' a' a' 4) ® w cex w a a a a Q a a CL a a a a a a O ra LI! 0Y Y Y Y Y Y Y -._ cC 0 ~-- x v) W CC O 0) O N 0) O f0 CV O a0 0 M N N C r,3 0 O O O C Cr) ♦rt 0 o o O O O O O W v CO N ►` N to N r� r` r` U o � �03 � � � 03 CO E E E CO > 0. U W p p p p p p p a c *, Y CC 4- 0 L N CC Y O m 0 o O O O O O V Q t.o 0 0 0 0 0 0 0 — v o 0 6 00 CO4, N r) N to r- N N d n') N CO M M M N _ - N - !O O M M M M E — = N �. N NNNNNN yl r Rr) 0) 0) 0) o) 0) 0) c o a F O N N N N N Nrts O1 0 0 O O O O '- 0 OU 0 0 0 0 0 0 0 a+ ~' C O Ol C In In Y7 ID to in in 63O CA H Q)U-I %.1 C U m ar do a W Y p ..... ct N N 'O �� - el O� a N r- O Q o o ate+ v c l- L_ W ? ,_ _,, z N O t� ,_ ,- ,- 4, Vii yam. cu A = v, w ^ W Q LL 3 4 N i i E ro cmom o. Q O N W N N N .- in z 0 0 0 .L N r-1 U ^ @ c d E E STATE OF ALASKA ALIRA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory❑ 207-135 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service❑ 6.API Number: 99510 50-029-23370-00 7.Property Designation(Lease Number): 8.Well Name and Number ADL 25642 KRU 2W-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7,882 feet Plugs measured None feet true vertical 6,301 feet Junk measured None feet Effective Depth measured 7,723 feet Packer measured 7,196 feet true vertical 6,152 feet true vertical 5,673 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 52 feet 16 " 80' MD 80 SURFACE 2,676 feet 9 5/8" 2,704' MD 2397 INTERMEDIATE 7,392 feet 70 7,418' MD 5872 t 'V E D LINER 683 feet 4 1/2 " 7,880' MD 6299 MAY 112017 Perforation depth: Measued Depth 7342-7370, 7516-7522, 7535-7560, 7600-7634 True Vertical depth 5803-5829, 5961 -5966, 5978-6001, 6038-6069 A OGCC Tubing(size,grade,measured and true vertical depth) 3.5" L-80 7,254' MD 5,724'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=ZXP Liner Top Packer 7,196' MD 5,673'TVD SAFETY VLV=TRMAXX-5E SAFETY V 2,159' MD 2010 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A �1 Treatment descriptions including volumes used and final pressure: SCANNEJ M : 2 5 2U1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 30 47 926 1300 180 Subsequent to operation: 47 47 944 1300 175 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Develo ment p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Name: Steve Drake Authorized Name: Steve Drake Contact Email: Steve.G.Drake@conocophillips.com Authorized Title: Sr.Wells Engineer Authorized Signature: z)�: Date:57/// / 7 Contact Phone: (907)263-4062 Form 10-404 evised 4/2017 17- Submit Original Only / VTC S"�l 1 ,x'(21(7 RBS 'iS liv MAY 1 6 2017 • • 2W- 1 7 DTTMST/JOBTYP SUMMARYOPS 4/24/17 PUMPING TRACKI FREEZE PROTECT TUBING AND FLOW LINE PUMP 20 BBL DIESEL DOWN TBG PUMP 20 BBL DIESEL DOWN FL JOB COMPLETE 4/25/17 PERFORATIONS - PERFORATE WITH 9'X 2.125" POWERSPIRAL GUNS. CORRELATE TO HALIBURTON SPERRY DRILLING SERVICES LOG DATED 16-NOV-07 TO 03-DEC-07, ALSO REFERENCE SLB PERFORATION RECORD LOG DATED 19-MAY-2008. SHOOT GUN#1 OVER PERF INTERVAL 7361- 7370' RKB, CCL TO TOP SHOT= 3.6', CCL STOP DEPTH = 7357.4' RKB, ATTEMPT TO SHOOT GUN#2 OVER PERF INTERVAL 7351.5- 7360.5' RKB BUT MISFIRE DUE TO BAD DETO. LAY DOWN FOR THE NIGHT, JOB IN PROGESS 4/26/17 PERFORATIONS - PERFORATE WITH 9' OF 2.125" POWERSPIRAL GUNS. CORRELATE TO HALIBURTON SPERRY DRILLING SERVICES LOG DATED 16-NOV- 07 TO 03-DEC-07, ALSO REFERENCE SLB PERFORATION RECORD LOG DATED 19-MAY-2008. SHOOT GUN OVER PERF INTERVAL 7351.5- 7560.5' RKB, CCL TO TOP SHOT= 3.6', CCL STOP DEPTH = 7347.9' RKB SHOOT GUN 2 OVER PERF INTERVAL 7342-7351' RKB, CCL TO TOP SHOT= 3.6', CCL STOP DEPTH = 7338.4' RKB JOB COMPLETE KUP PD 2W-17 COnocoPhilhhps 1 aI. ' A Well Attributellir Max Angle• TD Wellbore APIIUWI Field Name Wellbore Status Ind(°) MD(ftKB) Act Min(ftKB) {orgcoYhdbps Alaska,Inc. 500292337000 KUPARUK RIVER UNIT PROD 1 45.33 2,441.19 7,880.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(It) Rig Release Date HORIZONTAL-2W-17,5/10/2017 3:19:18 PM SSSV:TRDP 105 12/2/2016 Last WO: 28.30 12/6/2007 Vertical schematic{actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'RKB 7,747.0 3/29/2017 Rev Reason: PERF pproven 4/28/2017 -� Casing Strings HANGER;23.3 dill Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I. Len ..Grade Top Thread II CONDUCTOR 16 15.250 28.3 80.0 80.0 62.50 H-40 Welded s Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.835 27.8 2,704.0 2,397.2 40.00 L-80 BTC ; 6tCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 7 6.276 254 7,417.7 5,871.7 26.00 L-80 BTCM . ..,..."'u.,,,".“,...'r'"r„uu�r n +. n v Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 7,196.9 7.880.0 6,298.9 12.60 L-80 IBT-MOD Liner Details CONDUCTOR;28.3-80.0 • Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 171.11. I: 7,196.9 5,673.0 27.29 PACKER ZXP LINER TOP PACKER 5.250 It 7,216.7 5,690.6 26.76 NIPPLE "RS"Packoff seal nipple jt w/TKC couplings(5.57" 4.250 SAFETY VLV;2,159.2 - OD x 4.25"ID) 7,220.3 5,693.8 26.66 HANGER 5"x 7"Flex-Lock Liner Hgr(5.93"OD x 4.42"ID) 4.420 7,230.1 5,702.6 26.40 SBE 190-47 5"Seal Bore Ext w/TKC coupling (Max OD 4.000 5.60"x 4"ID) 7,249.7 5,720.1 26.20 XO BUSHING XO Bushing 5"BTC x 4 112"IBT(Max OD 5.6 x 3.95" 3.950 ID) SURFACE;27.9-2,704.0 ` Tubing Strings Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ibfft) Grade Top Connection TUBING !String 3 1/21 2.9921 23.31 7,254.11 5,724 9.301 L-80 I EUE8RDMOD Completion Details • Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind I') Item Des Corn (in) GAS LIFT z.asza • 23.3 23.3 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 • • • • 2,159.2 2,009.7 44.01 SAFETY VLV TRMAXX-5E SAFETY VALVE w/2.812 X PROFILE 2.812 7,175.1 5,653.6 27.88 NIPPLE CAMCO D NIPPLE 2.750 7,213.3 5,687.5 26.85 LOCATOR BAKER LOCATOR 3.990 7,242.6 5,713.8 26.27 SEAL ASSY BAKER BONDED SEAL ASSEMBLY 3.000 Perforations&Slots • Shot GAS LIFT;4,330.8 C Dens Top(ND) Btm(TVD) (shots) Top(ftKB) BM)(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 7,342.0 7,370.0 5,803.3 5,828.6 C-3/C-1,2W- 4/26/2017 6.0 APERF 2.125"PowerSpiral,45 17 degree continuous phase GAS LIFT.5 513.5 7,516.0 7,522.0 5,961.0 5,966.5 A-4,2W-17 5/19/2008 6.0 APERF alHSD PJ/HJ, alternating charges,60 deg.random GAS LIFT.6 4156 - 7,535.0 7,560.0 5,978.3 6,001.1 A-3,2W-17 1/11/2008 6.0 IPERF 2.5'HSD guns,PJ/HJ _ alternate charges,60 deg phase 7,600.0 7,634.0 6,037.8 6,069.1 A-2,2W-17 1/11/2008 6.0 (PERF alternateI 5"HSD guns,PJ/HJ 60 deg phase GAS LIFT 7,0972Mandrel Inserts S IE ai on Top(ND) Valve Latch Port Size TRO Run NIPPLE,7.175.1 N Top(ftKB) (ftKB) Make Model OD lin) Sery Type Type (in) (psi) Run Date Corn 2,867.4 2,513.8 CAMCO KBMG 1 GAS LIFT GLV BK 0.125 1,275.0 7/17/2014 2 4,330.8 3,561.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.125 1,269.0 7/17/2014 3 5,513.5 4,406.2 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,295.0 7/17/2014 Il 4 6,415.6 5,0521 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,319.0 7/16/2014 LOCATOR;7,21335 7,097.2 5,585.4 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 716/2014 Notes:General&Safety End Date Annotation . 12/20/2010 NOTE:View Schematic wl Alaska Schematic9.0 SEAL ASSY,7,2426 --.a APERF;7,342.0-7,370.0--+ Ym- INTERMEDIATE;25.4-7,417.7 • APERF;7,516.0-7,522.0 (PERF;7,535.0-7,580.0 r (PERF;7,800 0-7,634.0 0 LINER,1.196 9-r 880. if) a, F- � r x a� co co LL a) L +� 0 N CO o @ - I� N O u 1 „�, `1O a� a) r- u ¢Lf1 Va ❑_ c C C T O F (O 00 6 O_ ( O x) 0 .o U > LO Q O < 0 r r. r r r r r C a) E 0 co u E 4 r -0 O In d F- O a a a c. o. a L -p +-' L J Q Q Q Q Q Q Q c s vi z H 0) o o r) N to N 00 la L C Z z Q.. r N N N N u D td O U L• O C L 1- cc ~ 4.' a)• aJ 0 O ❑ ❑ ❑ ❑ ❑ ❑ ❑ J J J J J J J tin c 4= 0 Y. W W W W W W W vl CU 'C U `- h I LL LL LL LL tL. LL - CU N 0 0 Q 0 > L a) f' Q Q Q Q Q Q Q QJ C `t- 0 ,- a Z Z Z Z Z Z Z aJ a) QJ LL LL LL LL LL LL LL ) -C U C > CU CO O E a, U v O_ v u > Z C O .- > _ +' 0 ": a ~ C CO O_ O .O Rj U I Q C O_ a C a 'V co to 3 L N w❑ U V J d 1) aaN m _9a .� (N./• U z V (-) \ 0� al u ( •r,. > a) 2 J o CD r ' a . E r p ca 0 UJ ' w z 2 Zase CL W CZ EZ CL 0 w w w w w W w _ acelzreccwrece W > > > > > > > r Z Y Y Y Y Y Y Y a. Q' Q' 0: a' a. 0 ce o w Q Q Q Q Q Q Q AI 17. 4 L >a a a a a a a a * 0 Y Y Y Y Y Y Y C u CO F CC CO r r 'Cr L) CO DO X V) = / 0 0 0 0 0 0 0 o 0 0 CO 0 0 0 0 0 > co co co 000 co -0 N N N E ns CD a C S .. 0 0 0 0 0 0 C 0 0 0 0 0 0 0 pp er N CO CO O h O n A E co CO N r L 0 xr O) M M t0 N M N 0 u N a. N N N N N N L _� F Q O M M O M O O) 4! to E N 0 0 N 0 N N 'y E O O O O C. 00 C N Lo) Lo) Loi Li) LO) u01 0 C Q� ▪ Lf1 erg 0. (0 a) co LIJ u u E W V aJ Q 9 e Z .b 5, Z. N N N 0 N O a.+ E 0) 1 Qi *' = oC N C7 H ° ai d Q' 0 J. N N N N N h Z a! (a .0 v I ri C ^ 3 ro t • 0) CO 0 'V9 e 3 Q S i= a a Q • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~~'~ - ~~~ Well History File Identifier Organizing (aone) ^ Two-sided III II'III II III II III ^ Rescan Needed RE AN DIG AL 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: ^ Other:: BY: Maria Date: C ~ /s! (,~ ~' Project Proofing III II'I~I IIIII II III BY: Maria ~ Date: ~ ~ /s/ Scanning Preparation ~ x 30 = ~ + =TOTAL PAGES ~, / I Qount does not include cover sheet ) ( BY: Maria Date: ~ In f7/ l~ /s/ V f 1 Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~YES NO BY: Maria Date: f /~/ /s/ '~ I ~ ! 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 III II II III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III II~III III II'I III 10!6/2005 Well History File Cover Page.doc ~., ,. ,~~ .~=~~ ~. ~ -~ ,~~ r~ . MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 5, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~ ~~ '. ~: ~ ~a~ `' j ~,~~, ~o~~ . . ;~~`9~~;:x. ~~7 _ j3~- aw-~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 18th and January 24th, 2009. The corrosion inhibitor/sealant was pumped February 21St through February 23`d , 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. Sincerely, i~ ~! ~'l C M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor ,, ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404j Kuparuk Field Date 3/5/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2U-01 185-004 50' 5.90 3'1" 1/18/2009 9.2 2/22/2009 2U-02 185-005 6' 1.20 22" 1/18/2009 3.4 2/22/2009 2U-03 185-006 34' 7.90 2' 1/18/2009 7.4 2/22/2009 2U-05 185-018 40' 6.50 3'S" 1/18/2009 9.4 2/23/2009 2U-06 185-019 54' 7.00 2' 1/18/2009 7.1 2/23/2009 2U-07A 185-091 6' 0.70 2'2" 1/18/2009 4.5 2/23/2009 2U-08 185-021 80' 11.40 2'10" 1/18/2009 5.2 2!23/2009 2U-09 185-038 12' 1.50 22" 1/18/2009 3.6 2/23/2009 2U-10 185-039 6' 0.80 22" 1/18/2009 3.5 2/23/2009 2U-12 185-041 18'6" 2.70 22" 1/18/2009 3.1 2/23/2009 2U-13 184-246 45' 6.50 2' 1/18/2009 5.9 2/23/2009 2U-14 184-247 22' 4.20 22" 1/18/2009 6.1 2/23/2009 2U-15 184-248 26' 3.90 2'2" 1/18/2009 3.6 2/23/2009 2U-16 184-249 64' 8.40 5'2" 1/18/2009 14.8 2/23/2009 2W-01 185-010 27' 3.50 3'9" 1/18/2009 5.2 2!21/2009 2W-02 185-016 12' 6.50 5'9" 1/18/2009 12.3 2/21/2009 2W-04 185-012 55' 8.10 5'4" 1 /18/2009 15.1 2/21 /2009 2W-05 184-191 22' 2.90 2'3" 1/18/2009 7.6 2/21/2009 2W-06 184-194 16" NA 16" NA 1.4 2/22/2009 2W-07 184-204 56' 6.60 21" 1/24/2009 5.6 2/22/2009 2W-09 184-219 16" NA 16" NA 3.4 2/22/2009 2W-11 184-222 49' 6.00 4'3" 1/18/2009 10.5 2/22/2009 2W-12 184-224 64' 10.00 22" 1 /24/2009 2.1 2/22/2009 2W-13 184-236 6'6" 6.00 23" 1/18/2009 5.2 2/22/2009 2W-14 184-237 20'4" 3.30 22" 1/18/2009 3.7 2/22/2009 2W-15 184-238 41' 7.10 2'10" 1/18/2009 3.9 2/22/2009 2W-17 207-135 8" NA 8" NA 1.1 2/22/2009 DATA SUBMITTAL COMPLIANCE REPORT 12/3/2008 Permit to Drill 2071350 Well Name/No. KUPARUK RIV UNIT 2W-17 MD 7882 TVD 6301 Completion Date 12/6/2007 REQUIRED INFORMATION Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23370-00-00 Completion Status 1-OIL Current Status 1-OIL UIC N Mud Log No DATA INFORMATI ON Types Electric or Other Logs Run: GR / RES Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name D Asc Directional Survey iRpt Directional Survey ~g Pressure GR t LIS Verificati n p o C Lis 15962~nduction/Resistivity k..L~og Induction/Resistivity Lo Gamma Ray ,` Log Gamma Ray ~og Induction/Resistivity f/Log Induction/Resistivity C 15996/5ee Notes Lo ction/Re Ind i ti it g u s v y s /D d 1 " d /R C P s 6201 In uction esistivity Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Scale Log Run Media No Interval Start Stop OH / CH Received Comments 28 7882 Open 1/16/2008 28 7882 Open 1/16/2008 5 Blu 1 7300 7642 Case 2/22/2008 SBHP, Pres, Temp, GR, CCL 20-Feb-2008 108 7882 Open 2/29/2008 LIS Veri, ROP, GR, RPX, FCNT, NPHI, RPD, RPM, RPS, NCNT, DRHO, RHOB 108 7882 Open 2/29/2008 LIS Veri, ROP, GR, RPX, FCNT, NPHI, RPD, RPM, RPS, NCNT, DRHO, RHOB 25 Col 108 7900 Open 3/7/2008 MD EWR-4, DGR, ALD, ROP, CTN, BAT 15-Nov- 2007 25 Col 108 7882 Open 3/7/2008 MD GR, BAT 3-Dec-2007 25 Col 108 6300 Open 3/7/2008 TVD GR, BAT 3-Dec-2007 25 Col 108 7882 Open 3/7/2008 MD ROP, DGR, EWR 3- Dec-2007 25 Col 108 6003 Open 3/7/2008 TVD ROP, DGR, EWR 3- Dec-2007 0 0 3/7/2008 TVD and MD on Mutliple Logs in CDM, EMF and PDF graphics 5 Blu 7215 7720 Case 5/5/2008 PBMS-T, SFRT-A 12-Apr- 2008 7215 7720 Case 5/5/2008 PBMS-T, SFRT-A 12-Apr- 2008 DATA SUBMITTAL COMPLIANCE REPORT 12/3/2008 Permit to Drill 2071350 Well Name/No. KUPARUK RIV UNIT 2W-17 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23370-00-00 MD 7882 TVD 6301 Completion Date 12/6/2007 Completion Status 1-OIL Current Status 1-OIL UIC N g Production 5 Blu 50 7727 Case 6/11/2008 PPL, Deft, Spin, gradio, ', Temp, Pres, GR, CCL 5- P Jun-2008 ~D C Pds roduction 16436 50 7727 Case 6/11/2008 PPL, Deft, Spin, gradio, Temp, Pres, GR, CCL 5- '~ Jun-2008 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Daily History Received? N Chi Rec d? ~TIC~ i F ti T ps e ve orma on ops Analysis ~l'h~ Received? Comments: Compliance Reviewed By: _ __ _ _ _ Date: ____ _ ~-~1 ~ • STATE OF ALASKA ~~~~ 6~ ~~i,.l~, ~ ~ r'ui~8 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA~'~I~~ ~~ ~~v `~~''~~ G~~?~;i~~i~n „~ 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 0 ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ ~ Exploratory ^ 207-135 /. 3. Address: Stratigraphic ^ Service ^ 6. APt Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23370-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 90' - 2W-17 _ 8. Property Designation: 10. Field/Pool(s): ADL 25642. Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7882' feet true vertical 6301' ~ feet Plugs (measured) Effective Depth measured 7723' feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 16" 108' 108' SURFACE 2704' 9.625" 2704' 2400' INTERMEDIATE 7418' 7" 7418' 5872' LINER 689' 4.5" 7880' 6299' Perforation depth: Measured depth: 7516'-7522', 7535'-7560', 7600'-7634' true vertical depth: 5961'-5967', 5978'- 6001' , 6038'-6069' Tubing (size, grade, and measured depth) 3.5", L-80, 7254' MD. Packers 8~ SSSV (type & measured depth) HR 2XP pkr @ 7797 TRDP SSSV= 2159' 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-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 118 1302 839 206 Subsequent to operation 99 1591 1017 - 206 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ 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 John Peirce @ 265-6471 Printed Name John Peirce Title Ph 265 6471 Wells Group Engineer 6 O 8 D t ~Z~'~ Signature s ~ ~. one: - a e a (,~J- 4 P a h n All u Drake 263-4612 ` ~` ,~" Form 10%404 Revised 04/2006 ~w3 ~~' `jUl,. ~ ~QDB Submit Original O DATE SUMMARY 2W-17 Well Events Summary • 05/15/08 TAG 'D' NIP @ 7161' SLM. DRIFT WITH 11' X 2.5" DUMMY GUN & TAG BTM @ 7740' SLM. (NOTE: ADD PERF TARGET OF 7516'-7522') 05/19/08 PERFORATED 7516' - 7522', 6 SPF WITH A 2 1/2" HSD GUN LOADED WITH ALTERNATING HYPERJET II AND POWERJET CHARGES 06/05/08 PRODUCTION PROFILE W/DEFT - 100% OF PRODUCTION FROM PERFORATIONS AT 7535'-7560,, FIRST HYDROCARBON ENTRY AT 7552', GAS LIFT SURVEY SHOWS THAT THE OV AT 7097' IS LIFTING, WELL IS VERY UNSTABLE WITH LARGE PRESSURE SWINGS DOWNHOLE (300 PSI), NO CROSSFLOW DETECTED WITH WELL SHUT IN, DID NOT TAG TD 06/08/08 BRUSH AND FLUSH TBG IN PREP FOR DHSIT. TAG 7723' SLM. IN PROGRESS. 06/09/08 ATTEMPT TO SET DHSIT @ 7175' RKB. SET 2.75" CA-2 PLUG @ SAME. GOOD POSITIVE 8~ DRAW DOWN TEST. IN PROGRESS 06/10/08 PULLED 2.75" CA-2 PLUG FROM 7175' RKB.SET 2.75"CLOCK WITH DHSIT (KOBE K.O. 22" FROM TOP OF C LOCK)SOFTSET AND DUAL HES QUARTZ GAUGES (OAL 166")DHSIT SET TO CLOSE 18:10 ON 6/13/08.REOPEN @ 18:10 ON 6/16/08. '-"~ 06/17/08 PULLED 2.75" C-LOCK ON DHSIT FROM 7175' RKB. A PIECE OF METAL TRASH IN DHSIT COULD HAVE LEAD TO THE TOOL FAILURE. 06/19/08 A SAND SCALE SQUEEZE. PUMPED 50 BBLS SW AHEAD OF TREATMENT. PUMPED 10 BBLS OF SEAWATER PRE-FLUSH CONTAINING 30 GALLONS OF WAW-5206. PUMPED 42 BBLS OF SEAWATER CONTAINING 230 GALLONS OF SCW-4004. PUMPED 180 BBLS SW OVERDISPLACEMENT. ~'~_ -- CcanoeciPhillips s}! ~ - .t Welltro Comma .-,~-.I,~°5rrr~~-x .-._ +~ai F,.I TRDP MANGER, 23 Last WO: ~ nq Date Annotaaon 6I8Y2008 Rev Reason: TAG. ADD PERFS 28.30 2w-T~ 6/2012008 ~j (IfFCBj'l`Ji ~i'osiR) cage _ Top Th_ ,~.-~_... 9.30 L-F'.0 - I@UESrdM GAS LIFT, 5,514 GAS LIFT, 7.os7 NIP, 7,175 NIP. 7.277 HANGER, 7,220 PBR, 7.230 SEAL, 7,243 XO Busting, 7,250 ,578-7,522, SHttI2OOB ,535-7,580, 1/77/2008 00.7.836, IH 1/2008 COLLAR, 7,750 COLLAR, 7,896 Top (TVD) Btm (71/D) Dens Shot Top )itKB) 86n (IIKB) I1tKe) (RKB) Type Zone (shot... Totat Date Comment 7,516.0 7,522.0 5,961.2 5,966.6 APERFS A-3, 2W-17 6.0 36 5/19/2008 2.5" HSD PJ/HJ, alternating charges, 60 deg. random 7,535.0 7,560.0 5,978.4 6,001.1 IPERF A-3, 2W-17 6.0 150 1111/2008 2.5" HSD guns, PJ/HJ alternate charges, 60 deg phase 7,600.0 7,634.0 6,037.9 6,069.1 IPERF A-2, 2W-17 6.0 204 1/11/2008 2.5" HSD guns, PJ/HJ alternate charges, 60 deg phase TD, 7,880 NO. 4741 • Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description ___._w_.___- 06/10/08 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2W-13 11970689 GLS/PROD PROFILE ~ 05/27/08 1 1 3J-17 11970690 GLS/PROD PROFILE /~ - J 05/28/08 1 1 2M-08 11996642 PROD PROFILE/DEFT / / t~ 06/03/08 1 1 iB-10 11994672 PROD PROFILE/DEFT G 05/31/08 1 1 1A-20 11994673 PROD PROFILE/DEFT - 06/01/08 1 1 iG-13 11994674 PROD PROFILE/DEFT 3 - ~(o~la/~ 06/02/08 1 1 1A-03 11994673 PROD PROFILE/DEFT /(®e.®~a./ 06/04/08 1 1 2W-17 11996644 PROD PROFILE/DEFT ~( /~~~ 06/05/08 1 1 1C-125 11994677 INJECTION PROFILE -~- `9! /Co~J3(o 06/05/08 1 1 1C-127 11994675 INJECTION PROFILE ~J _ ~, `tee./ , 06/03/08 1 1 iF-09 11994671 PROD PROFILE/DEFT -/ ®~<.//~ 05/30/08 1 1 iC-27 11994679 SBHP SURVEY ~~ Off 06/07/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ir~llflfril-. Schlumberger -DCS 2525 Gambeli Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~`~ . Log Description ~~E ~~_ ~`~1 /'~r ~~ '~7~~i~~ Date NO. 4678 Company: Alaska Oit & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD 04/30/08 3K-102 NA PRODUCTION PROFILE 04/08/08 1 1 1 E-04 11996622 LDL ~ -T O - ~{ 04/16/08 1 1 2U-13 11996617 PRODUCTION PROFILE - a~( ` 04/10/08 1 1 2W-17 11996618 SFRT - O 7 - /3S 04/12/08 1 1 2L-330 11970662 PERF/SBHP p _ ~ 04/19/08 1 1 3F-18 11970666 LDL G` 04/23/08 1 1 1D-130 11964595 LDL _C' ~-- 04/23/08 1 1 1Y-07 11964596 INJECTION PROFILE -~ / 'a 04/24/08 1 1 2T-217A 11970667 INJECTION PROFILE ...p ~ ((o (~ 04/24/08 1 1 1 F-05 11964597 INJECTION PROFILE / lS r 04/25/08 1 1 3K-102 12021157 MEM PROD PROFILE ( 04/26/08 1 1 i L-09 11970669 PRODUCTION PROFILE t,( 04/26/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. l WELL LOG TRANSMITTAL To: State of Alaska March 6, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2W-17 AK-MW-S38SS28 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99S 18 2W-17 2" x S" MD BAT VDL Logs: 1 Color Log SO-029-23370-00 2" x S" MD BAT Logs: 1 Color Log SO-029-23370-00 2" x S" TVD BAT Logs: 1 Color Log SO-029-23370-00 2" x S" MD TC Logs: 1 Color Log SO-029-23370-00 2" x S" TVD TC Logs: 1 Color Log SO-029-23370-00 Digital Log Images 1 CD Rom SO-029-23370-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services '' # Attn: Rob Kalish G ~ `" ~~ ~ / 6900.4rcti~Blvd. Ane)~rage t~laska-99S 18 Date: ~ - - Signed: ConocoPhillips Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 March 4, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEtVEt~ MAR 0 5 2008 qi Oil S Gas Cons. Commission anchorage Subject: Well Completion Report for 2W-17 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 2W-17. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ~ ~~~~~ Y ED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MqR 0 5 2008 WELL COMPLETION OR RECOMPLETION RE ORT A D O 1a. Well Status: Oil Q ~ Gas Plugged Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 r GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: sAA: Developmen('~~~e Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: December 6, 2007 12. Permit to Drill Number: 207-135 / • 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: November 18, 2007 13. API Number: 50-029-23370-00 ' 4a. Location of Well (Governmental Section): Surface: 770' FNL, 5273' FEL, Sec. 34, T12N, R9E, UM ' 7. Date TD Reached: December 3, 2007 14. Well Name and Number: 2W-17 ' Top of Productive Horizon: 441' FSL, 21' FEL, Sec. 33, T12N, R9E, UM 8. KB (ft above MSL): ~.~, 90.9' RKB Ground (ft MSL): ~ 61' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 220' FSL, 24' FEL, Sec. 33, T12N, R9E, UM 9. Plug Back Depth (MD + ND): 7750' MD / 6177' ND Kuparuk Oil Pool • 4b. Location of Well (State Base Plane Coordinates): Surface: x- 519097 y- 5979793 ~ Zone- 4 10. Total Depth (MD + ND): " 7882' MD / 6301' TVD 16. Property Designation: 14D'G- ,BLYc25642 ~3•S O TPI: x- 519085 y- 5975725 Zone- 4 Total Depth: x- 519083 - 5975504 Zone- 4 11. SSSV Depth (MD + ND): SSSV @ 2159' MD / 2009' ND 17. Land Use Permit: 2573 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 (lVD): not available 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 28' 108' 28' 108' 24" pre-installed 9.625" 40# L-80 28' 2704' 28' 2400' 12.25" 400 sx AS Lite, 160 sx DeepCRETE 7" 26# L-80 28' 7418' 28' 5872' 8.75" 736 sx Class G 4.5" 12.6# L-80 7197' 7880' 5673' 6299' 6.125" 126 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" 7254' 7197 7600'-7634' MD 6037'-6069' TVD 6 spf 7535'-7560' MD 5978'-6001' TVD 6 Spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ g ~ ~ ' i ~ - „ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED i ~ ~~ ~-'I l C~ 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (core) 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes ^ No Q 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. ~a NONE aZ ~ ~ d? 4/F+~!°fED Form 10-407 Revised 2/2007 ,~g~ INUED ON S ~ ,s' ~ D~ 28. GEOLOGIC MARKERS (List all formations and 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 not available not available needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C4 7312' 5776' C3 7339' 5801' C1 734T 5808' B 7373' 5831' A5 7502' 5948' A4 7513' 5958' A3 7533' 59T N/A Formation at total depth: Kuparuk " 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Name Rand Thomas Title: Drillino Team Leader „~ ~ ~ ~~ ~ ~r-~ Phone ~Z~~- ~ ~ 3 ~ Date Signature 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 T3: The APt 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 ~onocoPhillips Time Log Summary WelJV7ew Web Re~ortMg Well Name: 2W-17 Job Type: DRILLING ORIGINAL Time Los ~ _ _ ----- - Date From To Dur S. Dzt~th E De th Phase Code Subcode T COM _ 11/16/2007 12:00 16:00 4.00 0 0 MIRU MOVE DMOB P Rig released - De-Mob rig -Move Pipe shed modules, Boiler module and Motor module from 3A pad to 2W pad and sta e. 19.0 mile move 16:00 18:00 2.00 0 0 MIRU MOVE MOB P Prep and Jackup Pump, Pits and sub - Hook up on Sows and stage on location 18:00 22:00 4.00 0 0 MIRU MOVE MOB P Move Pump, Pits and sub from 3A pad to 2W ad. 22:00 23;00 1.00 0 0 MIRU MOVE MOB P Stage and Set modules on pad. - Return to 3A ad to move cam . 23:00 00:00 1.00 0 0 MIRU MOVE DMOB P De-Mob rig camp 11/17/2007 00:00 05:30 5.50 0 0 MIRU MOVE MOB P Continue move rig camp, shop & sewer plant to 2W 17. Nipple up 16" x 21 1/4" double studded adapter spool, TEE, and knife valve. Set rig mats for Sewer lant. 05:30 06:30 1.00 0 0 MIRU MOVE MOB P Spot camp, truck shop, and sewer lant. 06:30 08:30 2.00 0 0 MIRU MOVE MOB P Spot Sub complex, and set down. 08:30 11:00 2.50 0 0 MIRU MOVE MOB P Lay matting boards and spot Pits, Pump room, Motor room, and Boiler com lexes. 11:00 12:00 1.00 0 0 MIRU MOVE MOB P Lay matting boards and spot Pipe shed com lexes. Crew Chan e 12:00 12:30 0.50 0 0 MIRU MOVE MOB P Continue lay matting boards and spot Pi a shed com lexes. 12:30 13:15 0.75 0 0 MIRU MOVE MOB P Lay matting boards and set Rockwasher in lace. 13:15 16:00 2.75 0 0 MIRU MOVE RURD P Complete rig acceptance checklist. Rig up all cellar & rig pumps. Berm all complexes and secondary containments. Make up all air, water, hydraulic, and steam inter-connects. Install all handrails, stairs and landings. Install rails and rig up pipe skate. Post all signs on pad & post drilling permit. Rig accepted at 1600 HRS as per checklist, Co. Rep, and TP. 16:00 19:00 3.00 0 0 MIRU WELCT NUND P Nipple up Riser assembly with hydraulic lines, and turnbuckles. Make up Diverter buoy line. load pits with water. P<~ge 1 of 1$ J n Time Logs Date From To Dur 5 De th E. De th Pha e Code Subcode T COM 11/17/2007 19:00 20:00 1.00 0 0 MIRU DRILL RURD P _ Install 5" elevators on Top drive. Pull equipment to floor, slips, pups, lift subs etc.. Begin load pipe shed with 150 joints of 5" DP. Begin mixing spud mud as er mud en ineer. 20:00 22:00 2.00 0 0 MIRU RIGMN' SVRG P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to change out saver sub. Rig up and change out saver sub on top drive installing 4 1/2" IF for 5" DP. Continue mixing spud mud as per mud en ineer. 22:00 23:00 1.00 0 0 MIRU DRILL RURD P Load BHA on short side. Strap all DP in pipe shed. Continue mixing spud mud as er mud en ineer. 23:00 00:00 1.00 0 0 MIRU DRILL RURD P Install mousehole in rotary table for picking up drill pipe. Change out heads in Iron roughneck, and rig up to pick up and rack back 5" Drill pipe. Continue mixing spud mud as per mud en ineer. Crew Chan e 11!18/2007 00:00 05:30 5.50 0 0 MIRU DRILL RURD P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to pick up drill pipe from pipe shed. Pick up 150 Joints of 5" DP from pipe shed and rack back same in derrick. Continue load in shed and pick up 14 joints of 5" HWDP and 6 3/4" drillin 'ars. rack same in derrick. 05:30 06:00 0.50 0 0 MIRU WELCT BOPE P Perform Diverter function test, & koomey test. Witness of test waived by AOGCC rep Bob Noble. Observed Knife valve opened in 14 Seconds, and full closure of annular in 28 seconds. Test flanges with diverter flooded with water. 06:00 07:30 1.50 0 0 SURFA DRILL PULD P Pult BHA componenets to rig floor. Make up 12 1/4" MX Bit, *" motor assembl with 1 stand od 5" HWDP. 07:30 08:15 0.75 0 0 SURFA DRILL CIRC P Held PJSM. Discuss safety & hazard recognition issues. Discuss spudding well, broaching issues. Flood conductor, and pressure test all lines to 1000 PSI. 08:15 09:45 1.50 0 223 SURFA DRILL DDRL P Tag at 80' & Spud well at 0815 HRS. Drill from 80' - 223' as per DD> ADT = .72 HRS. pumps at 640 GPM's - 820 PSI. 60 RPM's. 09:45 10:00 0.25 223 223 SURFA DRILL TRIP P Rack back 2 stands &HWDP. Blow down To Drive. 10:00 11:00 1.00 223 223 SURFA DRILL PULD P Continue make up drilling BHA picking up MWD assembly with UBHO sub. Plu in and u load MWD assembl . 1.1:00 11:30 0.50 223 223 SURFA DRILL PULD P Rig up Halliburton Gyro unit & hang sheaves. 11:30 12:00 0.50 223 223 SURFA DRILL PULD P Orient Mud motor to MWD and TIH. Crew Chan e 4'ac~e 2 of 18 Time Logs _ _ Date From To Dur S De th E. De th Phase Code Subcode T COM 11/18/2007 12:00 12:15 0.25 223 223 SURFA DRILL PULD P Continue TIH picking up MN Flex drill collars from i e shed. 12:15 18:00 5.75 223 600 SURFA DRILL DDRL P Directional drill 12 1/4" Surface hole from 223' - 600'. Utilize GYRO surveys as per DD to 533' MD. ADT = 5.11 HRS. AST = 1.23 HRS. ART = 3.88 HRS. Total Bif Hrs = 5.11. 18:00 00:00 6.00 600 997 SURFA DRILL DDRL P Directional drill 12 1/4" Surface hole from 600' - 997' MD. TVD = 995'. ADT = 3.91 HRS. AST = 3.04 HRS. ART = .87 HRS. Total Bit Hrs = 9.02. Rig down GYRO unit at 2200 HRS after 800', and good clean surveys. Crew Chan e 11/19/2007 00:00 01:15 1.25 997 1,153 SURFA DRILL DDRL P Directional drill 12 1/4" Surface hole from 997' -1153' MD. ADT = 1.15 HRS. Observed mounts on Rockwasher shaker failed. 01:15 03:00 1.75 1,153 1,153 SURFA RIGMN RGRP T Repair rockwasher shaker mounts. Reiprocate drill string for one hour. Pull bit back inside conductor to 73'. Observed good hole conditions. Repair shaker mounts, Put shaker on line - test same. Trip back in hole with 12 1!4" drillin assembl to 1153' MD. 03:00 06:00 3.00 1,153 1,536 SURFA DRILL DDRL P Directional drill 12 1/4" Surface hole from 1153' -1536' MD. TVD = 1502'. ADT = 2.06 HRS. AST = 1.30 HRS. ART = .76 HRS. 06:00 12:00 6.00 1,536 2,407 SURFA DRILL DDRL P Directional drill 12 1/4" Surface hole from 1536' - 2407' MD. TVD = 2186'. ADT = 4.16 HRS. AST = 1.93 HRS. ART = 2.23 HRS. Crew Chan e 12:00 14:00 2.00 2,407 2,709 SURFA DRILL DDRL P Directional drill 121/4" Surface hole from 2407' - 2709' MD. TVD = 2400'. ADT = 1.64 HRS. AST = .46 HRS. ART = 1.18 HRS. 14:00 14:15 0.25 2,709 2,709 SURFA DRILL OWFF P Obtain Survey At TD. Monitor well - static. 14:15 15:45 1.50 2,709 2,035 SURFA DRILL REAM P BROOH from 2709' - 2035' MD. Observed EI Magco Brake bearing on drawworks failed. 15:45 17:30 1.75 2,035 70 SURFA DRILL TRIP T POOH on elevators observing proper hole fill. 17:30 18:00 0.50 70 70 SURFA DRILL PULD T Plug in and download MWD assembl . 18:00 19:00 1.00 70 0 SURFA DRILL PULD T Breakout & lay down BHA #1. Inspect & rade bit to 2/2/BT/A/E/1/16"/ER/TD 19:00 20:00 1.00 0 0 SURFA DRILL PULD T Clean & clear rig Floor. Send out all S er Sun tools. 20:00 00:00 4.00 0 0 SURFA RIGMN RGRP T Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to safely remove EI MAgco Brake from drawworks and rig floor. Disassemble the Brake, and rig up, remove brake from rig floor and trans ort to truck sho .Crew Chan e .e.e_ ._. .. a~€1f; l~~ge 3 t Time Logs __ Date From To Dur 5 De th E. Depth Phase Code Subcode T COM _ 11/20/2007 00:00 06:00 6.00 0 0 SURFA RIGMN' RGRP T Continue repair EI Magco Brake on draw works. 06:00 12:00 6.00 0 0 SURFA RIGMN' RGRP T Continue repair EI Magco Brake on draw works. 12:00 13:00 1.00 0 0 SURFA RIGMN RGRP T Continue repair EI Magco Brake on draw works. 13:00 15:00 2.00 0 566 SURFA RIGMN RGRP T RIH with HWDP to 566' - Up wt 60k, Dn wt 62k, Rot wt 65k 15:00 19:00 4.00 566 2,709 SURFA DRILL TRIP P Back to original wiper trip -RIH from 566' to 2709' MD -Wash down and circu every 8th stand to enhance annulus mud. Noted tight hole @ 1880' and 1975' -Reamed each spot until clean. PR 550 gpm, PP 825 psi, 120 RPMs, 4-7k Rot Tro . 19:00 20:30 1.50 2,709 2,709 SURFA DRILL CIRC P Pump Hi Vis sweep to surface plus 1 complete BU - 550 gpm, PP 825 psi, 120 RPMs ****Note*** EI Mago electric brake that was changed out is showing signs of not working properly - Kicking breaker when applied. Toolpusher has said we will have to repair or replace it before we "Run Casin ". 20:30 22:00 1.50 2,709 0 SURFA DRILL TRIP P Monitor well "Static" -Pump dry job- POOH on elevators - No problems or ti ht hole noted 22:00 23:15 1.25 0 0 SURFA DRILL TRIP P Std Bk HWDP &DCs - UD HO, Flt sub and Stab 23:15 00:00 0.75 0 0 SURFA RIGMN RGRP T Clear Tools from rig floor -Prepare to remove #2 EI Ma o Electric brake. 11/21/2007 00:00 12:00 12.00 0 0 SURFA RIGMN RGRP T Rig Shutdown. Repair Origional EI Maggo Brake. Replaceing all bearing, races ands avers. 12:00 00:00 12.00 0 0 SURFA RIGMN RGRP T Rig Shutdown. Repair Origional EI Maggo Brake. Replaceing all bearing, races ands avers. 11/22/2007 00:00 12:00 12.00 0 0 SURFA RIGMN RGRP T Rig Shutdown. Repair Origional EI Maggo Brake. Replaceing all bearing, races ands avers. 12:00 20:00 8.00 0 0 SURFA RIGMN RGRP T Rig Shutdown. Repair Origional EI Maggo Brake. Replaceing all bearing, races and spacers. Rebuild complete unit. 20:00 00:00 4.00 0 0 SURFA RIGMN RGRP T Move Brake assy to rig -Pick up over Windwall and set in lace. 11/23/2007 00:00 02:30 2.50 0 0 SURFA RIGMN RGRP T Finish Installing rebuild EI Maggo D na-Matic brake on draw works. 02:30 03:30 1.00 0 0 SURFA RIGMN' RGRP T PJSM - MU CO assy BHA - HO, bit sub w/ float. 1 DC, Stab, Flex DCs 03:30 04:30 1.00 0 1,322 SURFA DRILL TRIP T TIH t/ 1322' MD -Tight 04:30 05:30 1.00 1,322 2,709 SURFA DRILL REAM T Precautionary Ream f/ 1322 MD to 2709' MD PR 450 gpm, 90 RPMs, Torq 3k, Up wt 80k, Dn wt 72k, Rot wt 80k Pasy~ ~ t~f 1Y s Time Logs Date._ From To Dur S. De th E. Depth Phase Code Subcode T COM 11/23/2007 05:30 07:00 1.50 2,709 2,709 SURFA DRILL CIRC P Circu & Condition Mud 07:00 09:15 2.25 0 0 SURFA DRILL TRIP P Flow Ck well "static"- Pump dry job - POOH - UD CO ass 09:15 10:00 0.75 0 0 SURFA DRILL PULD P Clean and clear rig floor - UD tools out beaver slide. 10:00 12:00 2.00 0 0 SURFA DRILL RURD P PJSM -Hazard recognition - RU casing running tools and Franks fill tool. 12:00 16:15 4.25 0 0 SURFA DRILL WOW T Phase 3 weather -Waiting for wind to subside and can convoy in equipment to run and CMT casin . 16:15 16:30 0.25 0 0 SURFA CASIN( SFTY P PJSM -Running Casing and all known hazards. 16:30 21:00 4.50 0 2,709 SURFA CASIN( RNCS P Run 9 5/8" 40# L80 casing per well plan. Ran tota163 joints, no problems & no tight hole. Fill csg on each joint and circu down slow with every 10th joint. PR 200 gpm This put all fresh mud in annulus when we reached bttm. MU Hanger and Landing joint and wash to hanger. Up wt 140k, Dn wt 95k 21:00 22:30 1.50 2,709 2,709 SURFA CASIN( CIRC P CBU -Stage up PR to 5 -6 bpm, PP 350-400 psi - @ BU LD Franks tool and PU CMT head. Blow down Top Drive 22:30 00:00 1.50 2,709 2,709 SURFA CASIN CIRC P Circu and Condition Mud for CMT Job. 11/24/2007 00:00 00:45 0.75 2,709 2,709 SURFA CASIN CIRC P Con't circu and condition mud of cmt job - PR 6 bpm, PP 450 psi. Up wt 150k, Dn wt 100k 00:45 04:00 3.25 2,709 2,709 SURFA CEME OTHR P CMT 9 5/8" Surface casing - Up wt 145k, Dn wt 95k -Pump 10 bbls CW100 -Teat Lines to 3500 psi - Pump other 40 bbls CW 100 -Pump 50 bbls 10.5 ppg MudPush -Drop Bttm Plug -Pump 325 bbls 10.7 ppg Lead, 70 bbls 12 ppg Tail, Drop Top Plug and wash up with 20 bbls H2O, Dowell turn over to rig -Rig displaced plug to bump w/ 1781 stks (On calculated) Had 95.4 bbls solid 10.7 lead cmt back to surface. CIP @ 03:30 - Csg Shoe @ 2704' MD / 2398' TVD 04:00 05:00 1.00 2,709 2,709 SURFA CEME~ RURD P Ck Floats "Held" - UD Landing Jt - Clean and clear ri floor 05:00 07:30 2.50 0 0 SURFA DRILL RURD P Nipple down diverter system. 07:30 09:00 1.50 0 0 SURFA WELC NUND P Nipple up well head, Tubing spool (Oreint per FMC per and DSO) Test seal 10 min, 1000 psi 10 min on starter head. 09:00 10:00 1.00 0 0 SURFA WELCT NUND P Change out Bttm rams to 5" i~~s~e ~ of 9~ Time Logs f~atP From To four S I~enth F I~Pnth Phase CndP Suhcnde T COM 11/26/2007 00:00 06:00 6.00 4,091 4,669 INTRM1 DRILL DDRL P Drlg f/ 4091 MD to 4669' MD / 3804' TVD -ADT 4.2 hrs, ART 3.22 hrs, AST .98 hrs -Jars 37.56 hrs, Up wt 140k, Dn wt 96k, ROT 112k, 12.33ppg ECD, PR 615 gpm, PP 2600 psi, RPMs 100, Tor 8-10k, WOB 18-24k 06:00 12:00 6.00 4,669 5,180 INTRM1 DRILL DDRL P Drlg f/ 4669' MD to 5180' MD / 4167' TVD -ADT 4.02 hrs, ART 3.70 hrs, AST .33 hrs -Jars 41.58 hrs, Up wt 150k, Dn wt 97k, ROT 116k, 12.78 ppg ECD, PR 580 gpm, PP 2200 psi, RPMs 100, Torq 8-10k, WOB 18-24k - **Note** Pumped sweeped as needed @ 4561' and 5025' MD -Formation breathing for complete tour. 15% increase in cutting on sweeps. Total mud loss for tour +/- 80 bbls. 12:00 00:00 12.00 5,180 5,706 INTRM1 DRILL DDRL P PJSM - Drlg f/ 5180' to 5706' MD / 4544' TVD ,ART 1.76 hrs, AST 1.76 hrs, ADT 9.59 hrs, Up wt 165k, Dn wt 105k, Rot wt 125k, Torq 8-10k OB, 7-10k Off bttm. Max gas 210 units on connection, Jar hrs 51.17 total hrs. **Note** Hole breathing on connection. Total mud lost +/- 60 bbls this tour. Well will go to "Static" on connections after several minutes. 11/27/2007 00:00 12:00 12.00 5,706 6,231 INTRM1 DRILL DRLG P Drilled 8 3/4" hole from 5,706' to 6,231' MD/ 4,920' TVD (525') ART 8.70 hrs, AST .60 hrs. ave 10.5 ppg MW, ECD 12.0 ,max as 436 units 12:00 00:00 12.00 6,231 7,001 INTRM1 DRILL DRLG P Drilled 8 3/4" hole from 6,231' to 7,001' MD/ 5,502' TVD (770') ART 6.68 hrs, AST 2.94 hrs. Rise Mud weight per well plan f/ 10.5 ppg to 10.9 ppg, ECD 12.4 ppg, Calc. clean hole ECD calculated to be 12.1 ppg, max gas 330 units. 11/28/2007 00:00 06:30 6.50 7,001 7,425 INTRMI DRILL DRLG P Drilled 8 3/4" hole from 7,001' to 7,425" MD! 5,878' TVD (424') ART 5.18 hrs, AST .91 hrs. Rise Mud weight per well plan f/ 10.9 ppg to 11.3 ppg, ECD 12.6 ppg, Calc. clean hole ECD calculated to be 12.1 ppg, max as 3000 units. 06:30 08:15 1.75 7,425 7,425 INTRM1 DRILL CIRC P Circ Btm's up (Gas ranging f/ 800 to 1100 units -Max 1617 units), Circ gas down to +/- 300 units, Pump Hi-vis sweep, Continue to circ total of 3 Btm's up at rate of 500 gpm @ 2400 si, ECD's 12.46 08:15 08:45 0.50 7,425 7,425 INTRM1 DRILL OWFF P Perform 30 min. well beathing test. Record gain & rate every 5 min.- First 5 min. gained 6.7 bbls f/ 80 bph -Last 5 min. gained 1.0 bbl f/ 12 bph. Total ain of 18.6 bbls. J Time Logs _ Da e From To Dur S. De th E_Depth Ph e Code Subcode T COM 11/28/2007 08:45 10:00 1.25 7,425 7,425 INTRM1 DRILL CIRC P Circ Btm's up at rate of 480 gpm @ 2400 psi, 50 RPM, 12-15K TQ, ECD's 12.35 ppg, Max gas 327 units, Lost 32 bbls in 1 hr. 10:00 10:15 0.25 7,425 7,425 INTRMI DRILL OWFF P Monitor well 15 min. and check for breathing, First 5 min. gained 8.8 bbls f/ 105.6 bph, Last 5 min. gained 2.1 bbls f/ 24.7 b h. 10:15 12:00 1.75 7,425 6,512 INTRM1 DRILL TRIP P Pump out of hole f/ 7,425' to 6,512', Pumping @ 2.2 bpm @ 400 psi, Dis lacment 3 bbls over calculated. 12:00 14:30 2.50 6,512 2,772 INTRM1 DRILL TRIP P PJSM, Continue to pump out to 5,956', POOH on trip tank to 2,772', Displacement 3.25 bbls short, Had 30-40K Drag f/ 4,900' to 4,850' & 4,400' to 4,430' -Worked thru 1 time and cleaned u ,Monitor well- Static. 14:30 16:00 1.50 2,772 2,772 INTRM1 DRILL CIRC P Circ 15 min. & Pump 25 bbls Hi-vis sweep, Circ & Recip. pipe f/ 2,772' to 2,715' at rate of 490 gpm @ 1300 psi, Sweep showed 10% increase in cuttings, Continue to circ total of 3 Btm's u . 16:00 19:45 3.75 2,772 6,117 INTRM1 DRILL PULD P Change over to 4" tools, Make up crossover, Pick up & RIH w/ 123 jts 4" XT-39 drill pipe to 6,117', Fill pipe @ 4,632', Monitor well -Static. 19:45 21:45 2.00 6,117 2,772 INTRM1 DRILL TRIP P POOH wet and stand back 41 std's 4" drill pipe, Dispaaement 10 bbls over. Monitor well -Static. 21:45 22:15 0.50 2,772 2,772 INTRM1 DRILL OTHR P Clean Floor and change back over to 5" tools. 22:15 00:00 1.75 2,772 5,117 INTRM1 DRILL TRIP P RIH w/ 5"drill pipe to 5,117', (Good dis lacement ,Fill i e. 11/29/2007 00:00 00:15 0.25 5,117 7,368 INTRM1 DRILL TRIP P Fin RIH from 5,117' to 7,368', calc displ. 36.75 bbls, actual 31.15, (5.6 bbls short 00:15 01:00 0.75 7,368 7,425 INTRMI DRILL CIRC T Filled pipe and attempted to est circ while washing down from 7,368' to btm at 7,425', no problems RIH, took 38 bbls to fill pipe and est circ, began circ at 360 gpm, 1,850 psi, 50 rpm's with 12-14K ft-Ibs torque, began to see a decrease in returns, slowed to 330 gpm then to 250 gpm as losses increased. Pumped a total of 283 bbls of mud and lost 242 bbls. Shut down to build mud volume. 01:00 05:30 4.50 7,425 7,425 INTRM1 DRILL OTHR T Monitored hole and well was static while building mud volume with 34 ppb LCM of Safe Carb 250, Safe Carb 30/50, Nut Plug Fine, Dyna Red-Fiber Fine & Medium. ~ ~ ~ ~a~e d of 1~ ~ ~ Time Logs _ Date From To Dur S Depth E. De th Pha5e Code Su_bcode T COM 11/30/2007 07:30 09:45 2.25 3,644 4,244 INTRM1 CASIN( RNCS P Continue to run 7" casing at 20-25 ft/min, Wash 1 jt down @ 4,244', Continue to run to 4,881'. 09:45 11:30 1.75 4,244 4,244 INTRM1 CASIN CIRC P Circ Btm's up & Reciprocate casing at rate of 2 bpm @ 450 psi, Stage up to 4 bpm @ 350 psi, Lost aprox. 16 bbls, Max gas 416 units, Up 135K, Dn 92K, Total losses as et 51 bbls. 11:30 13:15 1.75 4,244 5,945 INTRM1 CASIN RNCS P Continue to run 7" casing at 20-25 ft/min, Wash 1 jt down @ 5,308', Continue to run to 5,945', Up 165K, Dn 105K. 13:15 14:45 1.50 5,945 5,945 INTRMI CASIN( CIRC P Circ Btm's up 1-1/2 times & Reciprocate casing ,Stage up to f/ 2 to 5 bpm @ 500 psi, Pump total of 270 bbls & Lost aprox. 18 bbls, Max gas 525 units, Heaviest wt. out 11.4+ Circ until 11.0 in & out. 14:45 16:00 1.25 5,945 6,780 INTRM1 CASINC RNCS P Continue to run 7" casing at 20-25 ft/min to 6,780', U 190K, Dn 112K. 16:00 17:15 1.25 6,780 6,780 INTRM1 CASINC CIRC P Circ Btm's up & Reciprocate casing , Stage up to f/ 2 to 5 bpm @ 500 psi, Pump total of 240 bbts & Lost aprox. 14 bbls, Max gas 515 units, Heaviest wt. out 11.4+ ppg, Circ until 11.0 ppg in & out. 17:15 18:30 1.25 6,780 7,417 INTRM1 CASIN RNCS P Continue to run 7" casing at 20-25 ft/min to 7,390', Make up Landing jt. & Wash down on hanger w/shoe @ 7,417', U 215K, Dn 115K. 18:30 20:00 1.50 7,417 7,417 INTRM1 CASINC CIRC P Circ Btm's up 1-1/2 times & Reciprocate casing ,Stage up to f/ 2 to 4 bpm @ 350 psi, Pump total of 300 bbls & Lost aprox. 24 bbls, Max gas 590 units, Heaviest wt. out 11.4+ Circ until 11.0 in & out. 20:00 20:45 0.75 7,417 7,417 INTRM1 CEME RURD P Lay down Frank's fill up tool, Blow down top drive, Make up Dowell cement head, Attempt to work pipe- Stuck, Pulled 275K - Pi a stuck. 20:45 00:00 3.25 7,417 7,417 INTRM1 CEME CIRC P Circ & Condition Mud prior to cement, Stage rate f/ 2 to 5 bpm @ 500 psi, Final properties Mud wt. 11.0 ppg, vis 44 sec., YP 12, PV 14, PJSM w/all persona- for Stage 1 cement job, Batch mix 76.7 bbls (365 sxs) Tail cement, Final loss rate 9 to 13 bph Est loss while Circ 36 bbls, Est. total losses for 24 hours = 143 bbls. F~~ge 1tl of 1~ i Time Logs _ !Date From To Dur S Depth E Denth Phase ' CndP Suhrode T CnM 12/01/2007 00:00 01:45 1.75 7,417 7,417 INTRM1 CEME DISP P STAGE ONE- Turn over to Dowell, Dowell pumped 5 bbls fresh water to the rig floor (Not down hole), Shut down & test lines to 4000 psi, Mix & Pump total of 41.4 bbls 12.5 ppg MudPUSH, Followed by 60.9 bbls (240 sxs) 14.5 ppg Lead cement w/ .20% D46, 1.4% D20, .25% D65, .40% D167, 1 Ib/bbl CemNET pumped at rate of 5.0 bpm @ 200 to 165 psi, Followed by 76.7 bbls (365 sxs) 15.8 ppg Tail cement w/ .20 gal/sk D47, .080 gaf/sk D185A, 2.00 gal/sk D600G, .180 gal/sk D186, .070 gal/sk D110, .20% D153, 1 Ib/bbl CemNET pumped at rate of 5 bpm @ 140 to 165 psi, Shut down open cement head and hand drop Weatherford Btm plug, Displace cement w/ 10.0 bbls fresh water at rate of 5 bpm @ 80 psi, Turn over to rig and displace total of 272.7 bbls mud (Inc. water = 282.7 bbls) at rate of 5.0 bpm @ 250 to 910 psi f! 202.0 bbls mud w/ 25 to 27% returns flow, Observed flow to start to decrease to 23% (After 63.3 bbls cmt around shoe), Slow rate to 4 bpm @ 1000 psi w/flow of 23 to 13% f/ 248.4 bbls, Slowed rate to 3 bpm @ 1030 psi w/flow f/ 13 to 7% f/ 270.1 bbls, Slowed to 2 bpm @ 1060 psi & Bumped Insert baffle w/ 272.7 bbls w/ 1600 psi, C.I.P @ 01:35 hrs 12/1/07, Check floats- OK, Pressure up to 3250 psi & open Weatherford Stage Collar @ 3, 728', 7" Float Shoe @ 7417'., Float collar @ 7329', Baffle Insert @ 3728', Calculated TOC @ 3700'. 01:45 04:30 2.75 7,417 7,417 INTRM1 CEME CIRC P Establish Circ thru stage collar @ 3,728' at rate of 4 bpm @ 500 psi w/ returns 14% at start and increasing to 23%, Dumped Thick MudPUSH and Cement contaminated mud at Btm's up. Condition mud due to cement contamination, Stage rate up to 5 bpm @ 425 psi w/ 28% flow, Mud loss rate 13 b h. ~~e 11 of 18 ~ ~ Time Logs _ _ Dat From To Dur S De th E. Depth Phase Code Subcode T COM _ _ 12/01/2007 04:30 06:00 1.50 7,417 7,417 INTRM1 CEME DISP P STAGE TWO- Turn over to Dowell, Dowell pumped 5 bbls fresh water, Shut down & test lines to 4000 psi, Mix & Pump total of 27.0 bbls 12.5 ppg MudPUSH at rate of 5 bpm @ 215 psi, Followed by 33.5 bbls (131 sxs) 14.5 ppg Lead cement w/ .20% D46, 1.4% D20, .25% D65, .40% D167, .050% D186, 1.0 Ib/bbl CemNET pumped at rate of 5.0 bpm @ 230 psi, Shut down open cement head and hand drop Weatherford top plug, Displace cement w/ 10.0 bbls fresh water at rate of 5 bpm @ 20 psi, Turn over to rig and displace total of 131.8 bbls mud (Inc. water = 141.8 bbls) at rate of 5.0 bpm @ 500 psi f/ 70.7 bbls mud w/ 28% returns flow, Observed flow to start to decrease to 23% (After 12.1 bbls MudPUSH around Stage collar), Slow rate to 4 bpm @ 500 psi w/flow of 23 to 21 % f/ 101.0 bbls, Slowed rate to 3 bpm @ 500 psi w/ flow f/ 21 to 15% f/ 111.1 bbls, Slowed to 2 bpm @ 500 psi w/flow 15 to 9%, Slowed rate to 1 bpm @ 450 psi w/ flow of 9 to 7% to bump plug w/ 2000 psi to close Stage collar @ 3728', C.I.P @ 06:05 hrs 12/1/07, Check flow back- OK, Observed possible loss of 30.4 bbls thru out job. Calculated TOC 2800'. 06:00 06:30 0.50 INTRM1 CASIN RURD P Lay down landing joint. 06:30 08:00 1.50 INTRM1 CASINC NUND P Rig up & Set 7" Pack Off, Test same to 5000 si f/ 10 min. 08:00 09:00 1.00 INTRM1 CASIN OTHR P Clear & clean rig floor of casing tools. 09:00 09:45 0.75 INTRMI DRILL LOT P Rig & Perform Infectivity test on 7" x 9-5/8"Annulus - 470 psi, 2,398' TVD, 11.0 ppg = 14.8 ppg EMW, Used total 8 bbls for test. 09:45 11:30 1.75 INTRM1 WELC EORP P PJSM, Change bottom 7" rams to 4". 11:30 13:30 2.00 INTRM1 DRILL OTHR P PJSM, Change top drive saver sub to 4" XT-39, NOTE: Flush 7" x 9-5/8" Annulus with total of 84 bbls fresh water at initial rate of 1.0 bpm @ 645 si, Final rate of 1.5 b m 850 si. 13:30 15:00 1.50 INTRM1 WELC BOPE P Set test plug, Fill stack w/water, Rig up & test 4" pipe rams, 4"floor valves, Test waived by AOGCC Chuck Scheve. 15:00 16:00 1.00 INTRM1 RIGMN SVRG P Service top drive (Charge top drive accumulators ~ ~ ~~ F'~€~e 1~ c't Time Lomas Date From To Der S De th E. De th Ph se Code Subcode T COM 12/01/2007 16:00 17:30 1.50 INTRM1 WELC BOPE P Make up 3-1/2" test jt. & test annular w/ VBR's to 250 psi low & 3500 psi hi h, Pull test lu ,Set wear bushin . 17:30 18:45 1.25 INTRM1 RIGMN SVRG P PJSM, Cut & Slip drilling line 64', Inspect & adjust brakes, Check crown-o-matic. 18:45 00:00 5.25 INTRM1 DRILL PULD P PJSM, Set mouse hole, Lay down 5" HWDP & Jars, Lay down 5" Drill pipe from derrick, NOTE; Little Red service freeze protected 7" x 9-5/8"Annulus w/ 75 bbls diesel ar rate of 1.5 bpm @ 850 si. 12/02/2007 00:00 02:00 2.00 INTRM1 DRILL PULD P Continue to lay down a115" drill pipe. 02:00 02:45 0.75 INTRM1 DRILL OTHR P Clean rig floor, Lay down mouse hole, Change out elevators, Change out heads in Iron rou hneck. 02:45 04:45 2.00 140 INTRM1 DRILL PULD P Make up BHA #5. 04:45 06:30 1.75 140 140 INTRM1 DRILL DHEQ P Program MWD tools, Continue to pick up BHA, Shallow test MWD tools, Blow down to drive. 06:30 07:00 0.50 140 214 INTRM1 DRILL PULD P PJSM, Load R.A. Bourses. 07:00 07:45 0.75 214 396 INTRM1 DRILL PULD P Continue to pickup BHA - 2 jts Flex collars, 5'ts HWDP, Jars, RIH to 396'. 07:45 10:00 2.25 396 3,630 INTRM1 DRILL PULD P Single in w/ 4"drill pipe from pipe shed to 3,630' (Tag cmt above Stage collar 3,728 10:00 12:00 2.00 3,630 3,737 INTRM1 CEME DRLG P Drill out cement to Stage collar @ 3,728' & Drill out same, Work thru and dress up, 210 gpm @ 2100 psi, 50 RPM, torque 3-5K, Clean out to 3,737'. 12:00 13:15 1.25 3,737 7,239 INTRM1 DRILL PULD P PJSM, Continue to single in hole w/ 4" D.P. f/ pipe shed to 4,426', RIH w/ stands f/derrick to 7,239', Break circ w/ 210 gpm @ 2600 psi, Up 115K, Dn 80K, Rot 100K, T 7K. 13:15 13:45 0.50 7,239 7,285 INTRM1 CEME~ DRLG P Tag cement @ 7,265', Drill cement & Tag plug on Baffle @ 7,285' (Baffle @ 7,286' 13:45 14:15 0.50 7,285 7,285 INTRM1 DRILL CIRC P Circ Btm's up for casing test, Mud wt in & out 11.0 14:15 15:15 1.00 7,285 7,285 PROD1 CABIN DHEQ P RU and tested csg to 3,000 psi for 30 min and charted same. 15:15 18:00 2.75 7,285 7,425 INTRM1 CEME~ DRLG P Drill out Baffle @ 7,286' (1-1/4 hrs), Drill shoe track & Clean out to 7,425'. 18:00 18:30 0.50 7,425 7,445 INTRM1 DRILL DRLG P Drill 20' of new hole f/ 7,425' to 7,445', chan a over to new 11.3 mud. 18:30 20:00 1.50 7,445 7,392 INTRM1 DRILL CIRC P Continue to change over to 11.3 ppg mud, Had 316 units gas on Btm's up, Stand back 1 stand to 7,392' (Had 240 units gas from standing back 1 stand), Blow down to drive. ~.®®~ ~~_ ~~~~ 13 of 1~ • • Time Logs _ _____ Date From To Dur_ 5 De th E Depth Ph2se Code Subcode T COM 12!03/2007 20:15 00:00 3.75 689 4,158 COMPZ CASINC RUNL P RIH w/ 1 stand 4" drill pipe, Break circ & circ at 3 bpm @ 200 psi, Up 35K, Dn 40K, RIH w/ liner to 4,158' at 40 to 50 ft/min, Fill pipe with hose on each stand, Fill i e eve 10 stands. 12/04/2007 00:00 02:30 2.50 4,158 7,345 PROD1 CASINC RUNL P RIH w/ liner from 4,158 to 7,345' at 40 to 50 ft/min, Filled DP every 10 stands. 02:30 03:15 0.75 7,345 7,392 PROD1 CASIN< RURD P Run stand #72, Lay down top jt., Pick up Baker top drive cement head & Lay same w/ 1 more jt from stand #72 71-1l3 in hole , Pick u 15' u 't. 03:15 04:00 0.75 7,392 7,392 COMPZ CASIN CIRC P Circ Btm's Stage rate up to 4.5 bpm @ 950 psi, No losses, Blow down top drive 04:00 05:15 1.25 7,392 7,882 COMPZ CASINC RUNL P Continue to RIH w/ liner to 7,859', Make up Baker top drive cement head, est circ. at 2 bpm and RIH tagging btm at 7,882'. St wt up 145K, do wt 83K. 05:15 08:30 3.25 7,882 7,882 COMPZ CEME CIRC P Cont to circ and cond. mud for cementing while circ 3X btms up, staged pump rate up from 2 bpm at 700 psi to 5 bpm at 1,100 psi, with no losses, 11.7 ppg MW in and out. Reciprocated liner while circ hole, max gas at btms up 160 units, st wt up 145K, do wt 83K. Held PJSM with crew and Dowell on cementjob while circ. 08:30 09:00 0.50 7,882 7,882 COMPZ CEME DISP P Dowell pumped 5 bbls of water then pressure tested lines to 4,500 psi, then pumped 15 bbls of 13.5 ppg mudpush at 4.5 bpm at 1,300 psi.. Batch mixed cement then pumped 22 bbls, 100 sx of "G" cement at 15.8 ppg and 1.16 yield with Gasblok and additives, ave 4.5 bpm at an ave of 1,200 psi, reciprocated liner while cementing. Shut down and washed up to the ri floor. 09:00 09:30 0.50 7,882 7,880 COMPZ CEME DISP P Dropped Baker pump down wiper plug and Dowell followed the plug with 5 bbls of water then fin. displacing the cement with 11.7 ppg LSND mud at 4.5 bpm, initial pressure was 1,100 psi, max pressure at 4.5 bpm was 1,500 psi, slowed to 3 bpm at 1,200 psi and saw LWP plug shear and cont. to pump and bumped LWP on calc displacement 81.4 bbls. Pressured up to 4,100 psi and held for 5 minutes, bled off 1 bbl and checked floats and floats held. Reciprocated liner and had good returns through out the job. CIP at 09:30 hrs. PU liner to settin de th of 7,880', 2' off btm f~~c~e 1~ cif `18 ~ ~ ~ Time Logs Date From To Dur .$. d2pth E. De th Phase Code Subcode T COM _ 12/04/2007 09:30 10:15 0.75 7,880 7,880 COMPZ CEME~ OTHR P Pressured back up to 4,000 psi and set Baker Flex Lock liner hanger, hanger set on 2nd attempt, bled off the pressure and PU then rotated down setting 35K down to set ZXP packer saw running tool release from liner, PU and confirmed running tool was free. st wt up 135K. Set 4 1/2" TOL at 7,196.95' with insert landing collar at 7,750' and float shoe at 7,880'. (221' of liner la 10:15 11:00 0.75 7,880 7,220 COMPZ CEME~ CIRC P PU to 7,220' with running tool and circ hole clean the long way, circ hole at 300 gpm at 1,850 psi, at btms up had 15 bbls of cmt contaminated mud back. Heaviest mud at BU was 12.9 11:00 12:15 1.25 7,220 7,220 COMPZ CEMEt` RURD P RD Baker cement head and single and LD same. RU to reverse out. 12:15 14:00 1.75 7,220 7,220 COMPZ CEME CIRC P Circ hole clean by reverse circ a annulus volume at 300 gpm at 1,700 psi then circ the long way while reciprocating DP and circ 2X btms up at 390 gpm at 2,100 psi, circ with 11.7 ppg MW in and out and was clean at the shakers, monitored well and was static, blew down to drive. 14:00 20:30 6.50 7,220 0 COMPZ DRILL TRIP P POOH with Baker running tool LD 4" DP, LD a total of 231 'nts. 20:30 21:45 1.25 0 0 COMPZ RPCOh PULD P Breakout & lay down Baker running tool. Breakout & lay down cement head & crossovers. 21:45 23:15 1.50 0 0 COMPZ RPCOh PULD P Run in hole with 2 stands of HWDP and 7 stands of 4" DP. POOH, breakout & la down same. 23:15 00:00 0.75 0 0 COMPZ RPCO OTHR P BOLDS & Pull wear bushing. Clear & clean ri floor area. 12/05/2007 00:00 01:30 1.50 0 0 COMPZ RPCOh OTHR P Continue clean rig floor area, and re are for tubin run. 01:30 02:00 0.50 0 0 COMPZ RPCO PULD P Held PJSM with crew, BOT rep, and casing hand. Discuss safety & hazard recognition issues. Discuss procedure to run 31/2" production tbg. Rig up tubing running equipment. Double check runnin order in i e shed. 02:00 12:00 10.00 0 7,166 COMPZ RPCOh RCST P Make up Baker Locator sub & seal assembly with spaceout pups as per detail. Continue run 3 1/2" production tbg, with make up torque averaging 3100 FUlbs. Run tbg to 5090' MD. Make up SSSV. Pull Control line spool to rig floor. Make up control line, & test same to 5000 PSI. Continue run tbg to 7166' MD. Observed proper dis lacement. Crew Chan e Page 1~, raf'E$ • 2W-17 Well Events Summary • DATE Summary 12/28/07 DRIFT TO 7733' SLM WITH 2.71" GAUGERING.SET 2.75" CAT SV @ 7175' RKB.IN PROGRESS 12/29/07 PULL SOV @ 7097' RKB.DRIFT FOR TREE SAVER TO 10' SLM WITH 2.90". DISPLACE TBG/IA WITH 250 BBL'S DIESEL.SET 1" DV ON BK LATCH @ 7097' RKB. MITIA 3500# WITH 1500# ON TBG.PASS.PULL SV FROM 7175' RKB. READY FOR MUD SWAP. 1/1/08 Perform mud swap with SSW/Diesel/ methonal freeze protect. Achieved 'for PBTD utilizing SSW to flush 4.5" liner. Diesel from 2,000'-7,250'. Methanol from surface to 2,000' MD. Well flagged and tagged freeze protected. 1/11/08 PERFORATED INTERVAL 7620' - 7634' WITH ALTERNATING POWERJET/HYPERJET CHARGES. DID NOT TAG. ((IN PROGRESS)) 1/16/08 PERFORATED INTERVALS: 7600'-7620' & 7535'-7560' WITH 2.5" HSD GUNS - PJ/ HJ ALTERNATING CHARGES 6 SPF 60 DEG RANDOM PHASING. LOGGED JEWELRY PASS. • ~~ ~•, KRU 2W-17 ~ Conc~coPhl~ps A1asc~l, inc. 2w-y 7 - -- - API: 500292337000 Well T e: PROD An le ~ TS: de TUBING SSSV Type: TRDP Orig Angle @ TD: 20 deg @ (a725a, pD:3 5o0 Com letion: . , ID:zss2) , , Annular Fluid: Last W/O: Rev Reason: NEW WELL 'RODUCTION (0-7416, OD:7.000, Wt:26.00) Gas Lift MandrelNalv~e 5 (7os7aosa, NIP (7175-7176, OD:4.520) LINER (7196-7950, OD:4.500, Wt:12.60) NIP (7217-7218, OD:5.570) HANGER (722a7221, OD:5.930) PBR (7230-7231, OD:5.600) Reference Lo Ref Lo Date: Last U ate: 12/8/2007 Last Ta TD: 7882 ftKB Last Taq Date: Max Hole Angle• 45 deg n 2441 'Casing String -ALL STRINGS LINER 4.500 7196 I 7880 I 6299 I 12__60 I L-80 I IBTM ~ Tubing String -TUBING _ i, Size Top Bottom TVD Wt Grade Thread 3.500 i 0 i 7254 i 5724 i 9.30 i L-80 i EUE8rdM Gas Lift MandrelsNalves 2 4331 3562 CAMCO KBMG DMY 1.0 BK-5 0.000 0 12/5/2007 3 5514 4407 CAMCO KBMG DMY 1.0 BK-5 0.000 0 12/5/2007 4 6416 5052 CAMCO KBMG DMY 1.0 BK-5 0.000 0 12/5/2007 5 7097 5585 CAMCO KBMG SOV 1 0 BEK-5 0.000 2000 12/5/2007 IOihsr plugs, equip.,_eiC.) -COMPLETION De th TVD T e Descri tion ID 23 23 HANGER FMC GEN IV TUBING HANGER 3.500 2159 2009 SSSV TRMAXX-53 SCSSV w/2.812" PROFILE 2.812 7175 5654 NIP CAMCO'D' NIPPLE 2.750 7213 5687 LOCATOR BAKER LOCATOR 3.990 7243 5714 SEAL BAKER BONDED SEALS _ _ _ 3.000 Other lugs, equip., etc.) - LIFER DETAIL _ ___ De h TVD T e Descn tion iD 7197 5673 PACKER LINER'HR' ZXP LINER TOP PACKER w/11.77 EXT. w/5.25" ID 4.430 7217 5691 NIP LINER'RS' PACKOFF SEAL NIPPLE 4.250 7220 5694 HANGER LINER FLEX-LOCK LINER HANGER 4.420 7230 5702 PBR LINER 190-47 SEAL BORE EXTENSION 4.000 7250 5720 XO Bushing LINER CROSSOVER BUSHING 5" TO 4.5" 3.950 7750 6177 COLLAR LINER BAKER INSERT LANDING COLLAR 4.500 7846 6267 COLLAR LINER WEATHERFORD 403 FLOAT COLLAR 4.500 7878 6297 SHOE LINER WEATHERFORD 303 FLOAT SHOE 4.500 SEAL (7243-7244, OD:3.980) • • Halliburton Company Survey Report (bmpan}~: ConocoPhillips Alaska Inc. Date 12/21/2007 ~Iimc: 08:38:45 Page Field: Kuparuk River Unit Co -ordinatc(!~'E1 Reference: Well: 2W-17, True North Site Kuparuk 2W Pad ~~c rtical C11'D) Reference: 2W-17 (61.4+28) 89.4 well: 2W-17 Sec tion I~ S) Kefer eucc: WeEI (O.OON,O.OOE,180.29Azij ~1'cllpath: 2W-17 Su rvey Calculation Method: Minimum Curva ture ~ I)h: Oracle Field: Kuparuk 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: 2W-17 Slot Name: ~' 50-029-23370-00 Well Position: +N/-S 453.74 ft Northing: 5979793.16 ft Latitude: 70 21 21.453 N +E/-W 185.09 ft Fasting : 519093.75 ft Longitude: 149 50 41.782 W Position Uncertainty: 0.00 ft Wellpath: 2W-17 Drilled From: Well Ref. Point 50-029-23370-00 Tie-on Depth: 28.00 ft Current Datum: 2W-17 (61.4+28) Height 89.40 ft Above System Datum: Mean Sea Level Magnetic Data: 11/18/2007 Declination: 22.96 deg Field Strength: 57617 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft - ft - deg 28.00 0.00 0.00 180.29 Survey Program for Definitive Wellpath Date• 12/3/2007 Validated: Yes Version: 3 ~ Actual From To Survey Toolcode Tool Name ft ft 100.00 533.00 2W-17 Gyro (100.00-533.00) C B-MAG-SS Camera based mag single shot 560.20 7835.41 2W-17 IIFR+MS+SAG (560.20-7835 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC - C Survey --- -- -- ~Ill Incl Azim TVD S}ti TVD N/S Eiti~ ~IapN MapE Tool I ft deg deg ft ft ft ft ft ft ~i 28.00 0.00 0.00 28.00 -61.40 0.00 0.00 5979793.16 519093.75 TIE LINE 100.00 0.31 273.89 100.00 10.60 0.01 -0.19 5979793.17 519093.56 CB-MAG-SS 200.00 0.35 195.16 200.00 110.60 -0.26 -0.54 5979792.90 519093.21 CB-MAG-SS ', 300.00 0.51 214.83 300.00 210.60 -0.92 -0.88 5979792.23 519092.87 CB-MAG-SS 351.00 0.35 239.61 350.99 261.59 -1.19 -1.14 5979791.97 519092.61 CB-MAG-SS 450.00 1.24. 182.00 449.98 360.58 -2.41 -1.44 5979790.74 519092.32 CB-MAG-SS 533.00 3.75 171.06 532.90 443.50 -5.99 -1.05 5979787.17 519092.72 CB-MAG-SS 560.20 4.10 170.75 560.04 470.64 -7.83 -0.76 5979785.33 519093.01 MWD+IFR-AK-CAZ-SC 652.17 3.98 167.73 651.78 562.38 -14.19 0.45 5979778.97 519094.24 MWD+IFR-AK-CAZ-SC 747.87 4.95 164.24 747.19 657.79 -21.41 2.28 5979771.76 519096.08 MWD+IFR-AK-CAZ-SC 841.98 3.96 158.26 841.01 751.61 -28.34 4.59 5979764.84 519098.41 MWD+IFR-AK-CAZ-SC '. 888.62 4.57 158.60 887.52 798.12 -31.56 5.86 5979761.61 519099.69 MWD+IFR-AK-CAZ-SC 938.97 6.51 159.00 937.63 848.23 -36.10 7.61 5979757.09 519101.46 MWD+IFR-AK-CAZ-SC ii 985.26 9.49 160.18 983.47 894.07 -42.14 9.85 5979751.05 519103.71 MWD+tFR-AK-CAZ-SC 1033.39 13.20 160.12 1030.65 941.25 -51.04 13.06 5979742.16 519106.94 MWD+IFR-AK-CAZ-SC ~ I 1078.05 16.09 160.50 1073.85 984.45 -61.67 16.87 5979731.54 519110.77 MWD+IFR-AK-CAZ-SC ', 1124.77 18.27 161.82 1118.49 1029.09 -74.74 21.31 5979718.49 519115.25 MWD+IFR-AK-CAZ-SC 1170.74 19.64 164.69 1161.96 1072.56 -89.03 25.60 5979704.20 519119.57 MWD+IFR-AK-CAZ-SC 1221.72 21.24 167.76 1209.73 1120.33 -106.32 29.82 5979686.92 519123.84 MWD+IFR-AK-CAZ-SC 1316.45 20.87 168.41 1298.14 1208.74 -139.62 36.85 5979653.65 519130.95 MWD+IFR-AK-CAZ-SC ~I 1411.61 21.86 168.15 1386.76 1297.36 -173.57 43.89 5979619.72 519138.08 MWD+IFR-AK-CAZ-SC ~~ 1506.71 23.03 168.93 1474.65 1385.25 -209.15 51.10 5979584.16 519145.38 MWD+IFR-AK-CAZ-SC 1601.68 27.52 170.16 1560.51 1471.11 -249.02 58.42 5979544.31 519152.80 MWD+IFR-AK-CAZ-SC 1694.85 30.47 171.05 1641.99 1552.59 -293.57 65.78 5979499.78 519160.27 MWD+IFR-AK-CAZ-SC 1790.64 33.75 173.73 1723.12 1633.72 -344.03 72.46 5979449.35 519167.08 MWD+IFR-AK-CAZ-SC j 1884.65 36.15 174.54 1800.17 1710.77 -397.60 77.95 5979395.80 519172.71 MWD+IFR-AK-CAZ-SC I 1978.32 39.20 175.03 1874.31 1784.91 -454.61 83.15 5979338.81 519178.05 MWD+IFR-AK-CAZ-SC 2071.28 41.51 177.80 1945.15 1855.75 -514.67 86.88 5979278.77 519181.93 MWD+IFR-AK-CAZ-SC II 2164.08 44.15 179.62 2013.20 1923.80 -577.73 88.27 5979215.71 519183.48 MWD+IFR-AK-CAZ-SC ; Halliburton Company Survey Report Compan}: ConocoPhillips Alaska Inc. Irate: 12/21!2001 1'in-e: 08:38:45 Pa~c: 2 Field: Kuparuk River Unit Co-ordu~afc(~ F.) ucfcrence: Well: 2W-17, tr ue North Site: Ku paruk 2W Pad ~"crtical (t1~D) Referc~ce: 2W-17 (61.4+28) 89.4 ', Well: 2W-17 Sectio n (VS) Reference: Well (O.OON.O.O OE,18~029Azi) Wellpath: 2W-17 Survey Caktilati on 1lethod: Minimum Curvature Db: Oracle Survey MD hicl Azim l'~'D SysT~~D V'!S F,!~~' ~~tapN STapti 1~oul ft deg deg ft ft ft ft ft ft 2257.03 44.37 180.76 2079.77 1990.37 -642.60 88.05 5979150.85 519183.43 MWD+IFR-AK-CAZ-SC 2348.75 44.39 180.22 2145.32 2055.92 -706.75 87.51 5979086.71 519183.05 MWD+IFR-AK-CAZ-SC j 2441.19 45.33 181.95 2210.85 2121.45 -771.93 86.26 5979021.53 519181.97 MWD+IFR-AK-CAZ-SC 2534.32 44.71 181.69 2276.68 2187.28 -837.78 84.17 5978955.69 519180.05 MWD+IFR-AK-CAZ-SC 2627.37 44.73 181.63 2342.80 2253.40 -903.22 82.27 5978890.24 519178.32 MWD+IFR-AK-CAZ-SC 2651.02 44.85 181.33 2359.58 2270.18 -919.88 81.84 5978873.59 519177.93 MWD+IFR-AK-CAZ-SC 2728.11 44.62 181.46 2414.34 2324.94 -974.12 80.52 5978819.35 519176.75 MWD+IFR-AK-CAZ-SC 2761.51 44.42 181.54 2438.16 2348.76 -997.53 79.91 5978795.94 519176.19 MWD+IFR-AK-CAZ-SC 2822.21 44.58 181.87 2481.45 2392.05 -1040.06 78.64 5978753.41 519175.04 MWD+IFR-AK-CAZ-SC 2916.39 43.50 181.82 2549.15 2459.75 -1105.49 76.54 5978687.98 519173.10 MWD+IFR-AK-CAZ-SC I 3011.64 44.24 181.94 2617.82 2528.42 -1171.47 74.37 5978622.00 519171.10 MWD+IFR-AK-CAZ-SC ~ 3103.90 44.44 181.65 2683.80 2594.40 -1235.92 72.35 5978557.55 519169.24 i MWD+IFR-AK-CAZ-SC i j 3199.41 44.57 180.96 2751.92 2662.52 -1302.85 70.83 5978490.63 519167.89 MWD+IFR-AK-CAZ-SC 3294.34 44.38 181.45 2819.66 2730.26 -1369.34 69.43 5978424.14 519166.66 MWD+IFR-AK-CAZ-SC 3389.32 44.88 182.36 2887.25 2797.85 -1436.03 67.21 5978357.45 519164.61 MWD+IFR-AK-CAZ-SC ; 3483.70 44.19 182.59 2954.53 2865.13 -1502.16 64.35 5978291.32 519161.92 MWD+IFR-AK-CAZ-SC 3575.80 44.13 181.26 3020.60 2931.20 -1566.28 62.19 5978227.20 519159.93 MWD+IFR-AK-CAZ-SC 3671.75 43.49 180.84 3089.84 3000.44 -1632.69 60.98 5978160.79 519158.88 ~ MWD+IFR-AK-CAZ-SC 3768.11 44.40 180.57 3159.22 3069.82 -1699.56 60.15 5978093.93 519158.23 MWD+IFR-AK-CAZ-SC 3862.31 44.25 180.75 3226.61 3137.21 -1765.37 59.40 5978028.12 519157.64 MWD+IFR-AK-CAZ-SC 3956.94 44.40 181.02 3294.31 3204.91 -1831.49 58.37 5977962.01 519156.79 I MWD+IFR-AK-CAZ-SC 4051.72 43.78 180.69 3362.38 3272.98 -1897.43 57.39 5977896.08 519155.97 MWD+IFR-AK-CAZ-SC 4145.44 44.67 180.98 3429.54 3340.14 -1962.79 56.44 5977830.72 519155.18 MWD+IFR-AK-CAZ-SC 4240.74 44.31 182.80 3497.53 3408.13 -2029.53 54.24 5977763.98 519153.15 MWD+IFR-AK-CAZ-SC 4334.29 44.53 182.04 3564.35 3474.95 -2094.95 51.47 5977698.56 519150.56 MWD+IFR-AK-CAZ-SC ~ 4428.87 43.70 181.49 3632.25 3542.85 -2160.75 49.44 5977632.76 519148.69 MWD+IFR-AK-CAZ-SC i 4521.64 43.99 182.04 3699.16 3609.76 -2224.98 47.46 5977568.53 519146.88 MWD+IFR-AK-CAZ-SC 4614.35 44.43 182.75 3765.61 3676.21 -2289.57 44.76 5977503.94 519144.34 MWD+IFR-AK-CAZ-SC 4707.04 44.85 182.83 3831.56 3742.16 -2354.62 41.59 5977438.89 519141.34 MWD+IFR-AK-CAZ-SC 4799.53 44.18 183.31 3897.52 3808.12 -2419.37 38.12 5977374.13 519138.03 MWD+IFR-AK-CAZ-SC 4891.87 45.12 182.26 3963.21 3873.81 -2484.19 34.97 5977309.32 519135.05 MWD+IFR-AK-CAZ-SC 4985.10 44.60 182.67 4029.29 3939.89 -2549.89 32.14 5977243.62 519132.39 MWD+IFR-AK-CAZ-SC 5077.98 45.12 182.42 4095.13 4005.73 -2615.34 29.23 5977178.16 519129.65 MWD+IFR-AK-CAZ-SC 5170.59 44.50 182.60 4160.83 4071.43 -2680.54 26.38 5977112.96 519126.96 MWD+IFR-AK-CAZ-SC 5263.53 43.94 181.93 4227.44 4138.04 -2745.31 23.81 5977048.19 519124.56 MWD+IFR-AK-CAZ-SC 5356.04 44.22 181.44 4293.89 4204.49 -2809.64 21.92 5976983.87 519122.83 MWD+IFR-AK-CAZ-SC 5448.73 44.65 182.89 4360.08 4270.68 -2874.48 19.47 5976919.03 519120.54 + ~ MWD IFR-AK-CAZ-SC 5541.07 44.68 182.86 4425.75 4336.35 -2939.31 16.21 5976854.19 519117.45 MWD+IFR-AK-CAZ-SC ~i 5633.99 44.06 183.00 4492.18 4402.78 -3004.20 12.89 5976789.30 519114.30 MWD+IFR-AK-CAZ-SC 5726.16 44.61 182.93 4558.10 4468.70 -3068.53 9.56 5976724.97 519111.13 MWD+IFR-AK-CAZ-SC 5818.97 44.12 182.55 4624.45 4535.05 -3133.35 6.46 5976660.15 519108.19 MWD+IFR-AK-CAZ-SC 5914.17 43.63 182.30 4693.08 4603.68 -3199.27 3.66 5976594.23 519105.57 MWD+IFR-AK-CAZ-SC 6006.39 44.40 182.50 4759.40 4670.00 -3263.29 0.98 5976530.20 519103.05 MWD+IFR-AK-CAZ-SC 6099.01 44.70 181.61 4825.40 4736.00 -3328.23 -1.35 5976465.27 519100.88 MWD+IFR-AK-CAZ-SC 6191.66 43.86 181.25 4891.73 4802.33 -3392.89 -2.97 5976400.61 519099.43 MWD+IFR-AK-CAZ-SC 6285.13 44.14 181.78 4958.97 4869.57 -3457.80 -4.68 5976335.71 519097.88 MWD+IFR-AK-CAZ-SC 6377.67 44.59 181.89 5025.13 4935.73 -3522.47 -6.76 5976271.04 519095.97 MWD+IFR-AK-CAZ-SC ~ 6470.03 44.60 180.44 5090.90 5001.50 -3587.30 -8.07 5976206.21 519094.82 MWD+IFR-AK-CAZ-SC ! 6566.20 43.72 180.06 5159.89 5070.49 -3654.29 -8.37 5976139.22 519094.70 MWD+IFR-AK-CAZ-SC " 6661.56 41.43 180.76 5230.11 5140.71 -3718.80 -8.82 5976074.72 519094.41 MWD+IFR-AK-CAZ-SC 6756.59 38.35 182.40 5303.02 5213.62 -3779.71 -10.47 5976013.81 519092.91 MWD+IFR-AK-CAZ-SC ~ ~ Gi51.~G 3G.~1 112.45 537~.~~ 52i~.G~ - 3i37.2~ - 12.91 5~7595G.23 51~~~~.G2 WD+IFR-AK-C - M AZ SC i~ i Halliburton Company Survey Report Cumpam~: ConocoPhillips Alaska Inc. Datr. 1 212 1 72 0 07 Time D8-38.45 Pa~!c: 3 Field: Kuparuk River Unit Co-or dinatefNEi Retcrcnre: Well: 2Ud-17. True North Site: Ku panik 2W Pad Vertical(1'~ D> Kefcrence: 2W-17 (61.4}2$) 59.4 ~~cll_ 2W-17 Section (VS) Ke(erencc Well (O.OON,O.OOE,~ 80.29Azi) ~~ cllpath: 2W-17 Sun•e~ Calculation Method: Minimum Curvature Dh: Oracle Sur~c~ ~~ID Incl ~zim CFU SysTVD V'S _- t:~V4 MapA _ - MapE r ~I'uol ft deg deg ft ft ft ft ft ft ~ J 6946.30 33.19 182.23 5456.64 5367.24 -3890.81 --- -15.10 _ 5975902.71 - _ --- 519088.57 _ _ MWD+IFR-AK-CAZ-SC ' 7041.21 30.93 181.54 5537.07 5447.67 -3941.16 -16.77 5975852.36 519087.03 MWD+IFR-AK-CAZ-SC ~ 7136.03 28.93 181.65 5619.24 5529.84 -3988.45 -18.08 5975805.07 519085.83 MWD+IFR-AK-CAZ-SC 7229.56 26.41 181.28 5702.07 5612.67 -4031.86 -19.20 5975761.66 519084.83 ~ MWD+IFR-AK-CAZ-SC i 7325.34 25.41 179.05 5788.22 5698.82 -4073.71 -19.33 5975719.82 519084.80 MWD+IFR-AK-CAZ-SC ' 7385.29 25.34 180.17 5842.39 5752.99 -4099.40 -19.16 5975694.13 519085.04 MWD+IFR-AK-CAZ-SC 7470.15 24.74 180.37 5919.27 5829.87 -4135.31 -19.33 5975658.22 519084.96 MWD+IFR-AK-CAZ-SC 7563.73 23.90 180.86 6004.55 5915.15 -4173.85 -19.74 5975619.69 519084.65 MWD+IFR-AK-CAZ-SC 7658.36 22.40 181.04 6091.56 6002.16 -4211.05 -20.35 5975582.49 519084.13 MWD+IFR-AK-CAZ-SC 7752.03 20.72 180.76 6178.67 6089.27 -4245.46 -20.90 5975548.08 519083.67 MWD+IFR-AK-CAZ-SC 7835.41 19.65 181.89 6256.93 6167.53 -4274.22 -21.56 5975519.32 519083.09 MWD+IFR-AK-CAZ-SC 7882.00 19.65 181,89 6300.80 6211.40 -4289.88 -22.07 5975503.66 519082.61 PROJECTED to TD ~ ~ WELL LOG TRANSMITTAL To: State of Alaska February 26, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 2W-17 AK-MW-538552 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23 3 70-00 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: ' ~`~" ~ `~'~`~ Signed: ~~ ~ ~~~a • Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # -., ~' r..V ~ v) a, ~~ ~~ 1„~(,~'y Log Description OZIZOIOS NO.4595 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2L-319 11970619 SCMT - I 12131/07 1 1A-02 11994615 INJECTION PROFILE (- 02/11/08 1 1F-10 11994616 INJECTION PROFILE - / 02/12108 1 2X-08 11996603 INJECTION PROFILE U=C / ~, - (1~( 02/13/08 1 3N-11 11968841 , INJECTION PROFILE - ~~ 02/16/08 1 1J-152 11994623 PRODUCTION PROFILE (o - / 02118/08 1 2W-17 N/A SBHP SURVEY '~ _ ~ ` 02/20108 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 10-Jan-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2W-17 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 28.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 7,882.00' 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 ~ ~~d~ Signed ~' Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) i • a ~ a ~ ~ SARAH PAUN, GOVERNOR ~-7~ O~ ~ ~ 333 W. 7th AVENUE, SUITE 100 C0111-SERQA7'IOAT COl-II-IISSI011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2W-17 ConocoPhillips Alaska, Inc. Permit No: 207-135 Surface Location: 770' FNL, 5273' FEL, SEC. 34, T12N, R9E, UM Bottomhole Location: 5126' FNL, 5156' FEL, SEC. 34, T12N, R9E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill 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 conditior_s of this permit may result in the revocation or suspension of the permit. 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). Sin rel Dan T. Seamount Commissioner DATED thi~ day of October, 2007 cc: Department of Fish 8a Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com September 27, 2007 Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Dri112W-17 Dear Commissioners, '. ~~~~~ ~~~ 2 ~ 2007 ~~'s,... ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore production we112W-17. The well will be drilled and completed using Doyon Rig #141. The planned spud date for 2W-17 is October 31st, 2007. Please fmd attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Mike Greener at 907-263-4820. Sincerely, Randy Thomas Kuparuk Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION s ~~~~ PERMIT TO DRILL ~~ .~:~~~~'~l~~~i~as~ 20 AAC 25.005 ~~~5~~ ~~ ;. , 1a. Type of Work: Drill ^/ Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 a 11. Well Name and Number: 2W-17 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 7967' ~ ND: 6366' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 770' FNL, 5273' FEL, Sec. 34, T12N, R9E, UM ' 7. Property Designation: ADL 25642 ~ Kuparuk Oil Pool Top of Productive Horizon: 4852' FNL, 5155' FEL, Sec. 34, T12N, R9E, UM 8. Land Use Permit: ALK 2573 13. Approximate Spud Date: 10/31/2007 Total Depth: 5126' FNL, 5156' FEL, Sec. 34, T12N, R9E, UM 9. Acres in Property: 2560 14. Distance to ~ Nearest Property: > 1 mile 4b. Location of Well (State Base Plane Coordinates): Surface: x- 519097 ° y- 5979793 ~ Zone- 4 10. KB Elevation ~D.q :'~~ y.a~ (Height above GL): 3:0.9' AMSL/~ feet 15. Distance to Neare t /' jC/2uZi~/-O~ /~a00 Well wdhin Pool: 00- 16. Deviated wells: Kickoff depth: 500 ft. Maximum Hole Angle: 44° deg 17. Maximum Anticipated Pressurels in psig (see 20 AAC 25.035) ,~ ~.3`i Downhole:~psigW~~~~~'~ Surface: psig ~~j'' 18. Casing Program cific S ti Setting Depth Quantity of Cement Size pe a ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 24" 16" 62.5# H-40 Welded 80' 28' 28' 120' 120' Driven 12.25" 9-5/8" 40# L-80 BTC 2728' 28' 28' 2728' - 2400' - 400 sx AS Lite, 160 sx DeepCRETE 8.75" 7" 26# L-80 BTCM 7429' 28' 28' 7429' - 5878' ' 340 sx Class G w/ GasBLOK 6.125" 4.5" 12.6# L-80 IBTM 738' 7229' 5696' 7967 ~ 6365' ~ 100 sx Class G w/ GasBLOK 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 TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program / Time v. Depth Plot ^ Shallow Hazard Analysis / Properly Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q/ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Drilling Team Leader / Signature ~ ` Phone ~~ 6~ 3v Date ~ f 2~ trf3'1 h n Alls r k Commission Use Only Permit to Drill Number: ,~ ~~'" ~ ~ API Number: ~~++,, 50- ~~-~ '" ~ ~~ ~v ~ ~ Permit Approval - Date: See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [-~ Other: ~~~`-.y,~ y,~~'s~~~N.vS~~j~~ ~~~H2S measures: Yes [V]~ No ^ Directional svy req'd: Yes [~ No ^ / O ~ APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 7 ~ Submit~ff Duplicate ~d7 ~L i~ ~o z•d7 ,~ (O~~®7 Ap~on for Permit to Drill, Well 2W-17 Saved: 27-Sep-07 Permit It - Kuparuk We112W-17 ' ' ~., Application for Permit to Drill Document '~~ m srt +~~tt yv~ue Table of Contents 1. Well Name .................................................................................................................................2 9 .f (~ ........................................................................................................................ Re uirements o 20 AAC 25.005 2 I.y ................................................................................................................... 2. Location Summa 2 q f ~~~~ ................................................................................................ Re uirements o 20 AAC 25.005 c 2 •••••••'••••"••••' 2 q f (~~ ........................................................................................................................ Re uirements o 20 AAC 25.050 2 3. Blowout Prevention Equipment Information ........................................................................3 q .f ~~~) ................................................................................................................... Re uirements o 20 AAC 25.005 c 3 3 4 Drilling Hazards Information ................................................... ..............................................3 . q .f (~() ............................................................ Re uirements o 20 AAC 25.005 c 4 ...................................................... 3 5 Procedure for Conducting Formation Integrity Tests ........... ..............................................3 . q .f (~() ........................................................... Re uirements o 20 AAC 25.005 c S ...................... ••••••••••••••••••••••'••••""" 3 6. Casing and Cementing Program ................................................... .........................................4 q f ~~~~ .................................................................. Re uirements o 20 AAC 25.005 c 6 4 ................................................. 7. Diverter System Information ......................................................... .........................................4 9 f ~~(~ .................................................................. Re uirements o 20 AAC 25.005 c 7 4 ................................................. 8. Drilling Fluid Program .................................................................. ..........................................4 4 q .f (~~) .................................................................. Re uirements o 20 AAC 25.005 c 8 ................ ••••••••••••••••••••'••••"""" 9. Abnormally Pressured Formation Information ....................................................................4 q .f ~)(~ ................................................................. Re uirements o 20 AAC 25.005 c 9 4 ................................................. 10. Seismic Analysis ............................................................................. 10 ..........................................5 .......... ••••••••••••••••'••••••""' S 4 f ~~~ ~ .............................................................. Re uirements o 20 AAC 25.005 c .......... ., 11. Seabed Condition Analysis ............................................................ ..........................................5 q .f ~~~ ~ .............................................................. Re uirements o 20 AAC 25.005 c 11 5 .................................................. g ...................................................................... 12. Evidence of Bondin .......................................... 5 S R' .f ~~~ ~ .............................................................. Re uirements o 20 AAC 25.005 c 12 .................................................. 13. Proposed Drilling Program ........................................................... ..........................................5 S 9 .~ ()~ ) .............................................................. Re uirements o 20 AAC 25.005 c 13 ........ •••••••••••••••••••••••••••••'•••••"""' 2W-17 APD Page 1 of 7 Printed: 27-Sep-07 ~~~~~~ r Appli~ for Permit to Drill, Well 2W-17 Saved: 27-Sep-07 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................................... 6 ............................................................... Requirements of 20 AAC 25.005 (c)(14) •••'•""""""""""""""""""' 15. Attachments .............................................................................................................................. Attachment 1 Directional Plan .............................................................................................................................. 6 6 ................ ... .... Attachment 2 Drilling Hazar ummary ............................................................................................................. 6 Attachment 3 Well Schematic ......................................................................................................... Attachment 4 Cement Summary ............................................................................................................................. 6 1. Well Name Requirements of 20 AAC 25.005 (fl Each hell must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a a~nigue name and API number by adding a suffix to the name designated for the well by the operator and to the number- assigned to the ~rel7 by the commission. The well for which this application is submitted will be designated as 2W-17. 2. Location Summary Requirements of 20 AAC 2S.OOS(c)(2) An application for a Permit to Drill must be accompanied by each of the follaN ing items, except for an item already on file ~a;ith thz commission and identified in the application: (7) a plat ident fj~ing the property and the property's o~sners and showing (A) the coordinates of the proposed location of the well at the surface, at the Lop of each objective formation, and at total depth, referenced to governmental section lines. stem or this state as maintained (B) tl~e coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate s} f by the National Geodetic Suwey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 770' FNL, 5,273' FEL, Sec 34, T12N, R9E, UM NGSCoordinates RKB Elevation 90.9' AMSL Northings: 5,979,793 Eastings:. 519,097 Pad Elevation 28' AMSL Location at Top of Productive Interval 4,852' FNL, 5,155' FEL, Sec 34, T12N, R9E, UM (Ku aruk) NGSCoordtnates Measured De th, RKB: 7,321' Northings: 5,975,712 Eastings: 519,231 Total Vertical De th, RKB: 5,781' Total Vertical De th, SS: 5,690' Location at Total De th 5,126' FNL, 5,156' FEL, Sec 34, T12N, R9E, UM NGS coordinates Measured Depth, RKB: 7,967' Northings: 5,975,438 Eastings: 519,231 Total Vertical Depth, RKB: 6,366' Total Vertical Depth, SS: 6,275' mid (DJ other infornzation required by 20 AAC 2.i.0.50(h); Requirements of 20 AAC 25.050(6) If a i+~ell is to be intentionally deviatec~~ the application for a Permit to Dri17 (Form 10-401) must (IJ include a plat. drain n to a suitable scale, shol+~ing tlae path of the proposed wellbore, including all adjacent wellbores i+~ithin 200 feet of mzy poriian of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells ~rithin 200 feet of the proposed 1+ ellbore (A) list the names of the operators of those ~reRs, to the extent that those names are known or discoverable in public records, a~ul show that each named operator has been furnished a copy of die application by certified mail; or (B) state that the applicant isthe only affected owner. 2W-17 APD Page 2 of 7 Printed: 27-Sep-07 1 The Applicant is the only affected owner. App~n for Permit to Drill, Well 2W-17 Saved: 27-Sep-07 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on f le with the commission acrd identified in the application: (3) a diagram and description of the blowout prevention equipment (HOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 141. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item ab•eady on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the nurximum downhale pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The closest offset well data shows a max BHP of 4,100 psi at 5,960' TVD. .,,, Equivalent Mud Weight @ TD = 4,100 / (5,960*.052) = 13.2 ppg The maximum potential surface pressure (MPSP) while dri g 2W-17 is calculated using the predicted 4,100 psi reservoir pressure, a 0.11 psi/ft g~~~adient, and an Kuparuk A sand top TVD of 5,960'. MPSP = (5,960 ft TVD)*(0,~- 0.11 psi/ft) 2 psi w _ ~~~ ~c (B) data on potential gene ~ ~~ The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo yressured strata, lost circulation =ones, and pones that have a propensity for differential sticking; Please see Attachment 2 -Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Permit to Drill must be accompmried by each of the following items, exceptfor an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.0300; Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT /FIT procedure that ConocoPhillips Alaska has on file with the Commission. 2W-17 APD Page 3 of 7 n` Printed: 27-Sep-07 ~~ 1 ~~~ App~n for Permit to Drill, Well 2W-17 Saved: 27-Sep-07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) A» applicadorz for a Permit to Drill must be accompanied by each of the following items, except far an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed; Casin and Cementin Pro ram Hole Top Btm CsglTbg Size Weight Length ft MDlTVD (ft MD/TVD (ft Cement Program OD in) in) (Ib/ft Grade Conn. ( Driven 16 24 62.5 H-40 Welded 80' Surf 120' / 120' Cemented to Surface with 9-5/8 12-1/4 40.0 L-80 BTC 2,728' Surf 2,728' / 2,400' 160 ~x Dee LCRETE a ail Cement Top planned @ 5,429' MD / 7 8-3/4" 0 26 L-80 BTCM 7,429' Surf 7,429' / 5,878' 4,331' TVD. Cemented w/ " " . G 340 sx GasBLOK Class Cement Top planned @ 7,079' MD / 4-1/2 6-1/8 12.6 L-80 IBTM 738' 7,229' / 5,696' 7,967' / 6,365' 100 sx GasBLOK w/ ClaasWG" 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of floe follor+~ing items, exceptfor an item already on file with the commission and identified In the application: (7) a diagram and description of the diverter system as required by 20 AAC 15.035, unless this requirement is waived by the commission under 20 AAC 25.035(hJ(1); Please reference diverter schematic on file for Doyon 141. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) ` An application for a Permit to Drill must be accompanied by each of the following items, except for an item a]ready on file ia~ith the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid systern, as required by 20 AAC 25.033; Drilling will be done using mud systems having the following properties: Sur ace Interval Intermediate Interval Production Interval Mud Type S ud Mud LSND LSND Densi ( ) 9.1- 9.6 9.5 -11.5 ~ Funnel Viscosity(sec) 150 - 250* 45 - 55 45 - 55 Yield Point (cP) 30 - 45 18 - 22 22 - 25 API Filtrate (cc) NC - <10 <6 < 4 pH 9.0-9.5 9.5-10 9.5-10 *Spud mud should be adjusted to a FV between 150-250 sec/qt to drill gravel beds Diagram of Doyon 141 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. ~~~~Y'~~ 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of dre following items, except for mz item already on ftle with the commission and identified in the application: (9) for an exploratory or stratigraphic test 1+~ell, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 1~.033(~; 2W-17 APD Page 4 of 7 Printed: 27-Sep-07 ~~~~1 App~n for Permit to Drill, Well 2W-17 Saved: 27-Sep-07 N/A -Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by eac1~ of the following items, except for an item already on fide with the commission and identified in the application: (10) for an exploratory or stratlgraphlc test well, a seismic refraction or reflection analysis as reguired by 20 AAC 25.061(a); N/A -Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (e)(I1) An application for a Permit to Drill must be accompanied by each of the follol+~ing items, except for an item already on file with the commission and ident~ed in the application: (11) for a well drilled from an offshore platform, mobile bottom founded sn-ucture, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A -Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the foddoiving items, except forma item already on file with the commission mid identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the follol+=ing items, exceptfor an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 141 on 2W-17 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. y 4. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point{2,728' MD/ 2,400' TVD) according to directional plan. Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if requgirerd~'to e ,h bring cement to surface. 1J4~~~ ~sv~.~.<;.~~,~ ~~~ti~ ~~ 6. Nipple down diverter, remove warning signage, and install wellhead and test to 5000 psi.. Nipple up BOPE and test to required pressure as per AOGCC approved permit to drill. Record results. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT. 9. Directionally drill8-3/4" hole to 7,429' MD / 5,878' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. Run 7" 26# L-80 BTCM casing to 7,429' MD / 5,878' TVD. Pump cement and displace with mud, land casing hanger and bump plug. 11. PU 4-3/4" packed drilling assembly and 6-1/8" bit and clean out to shoe. Shut in BOP and test casing to 3,000 psi. Record results. Drill 20' minimum to 50' maximum of new hole. Perform LOT. 12. Directionally dri116-1/8" hole to 7,967' MD / 6,365' TVD. Run MWD/LWD logging tools in drill string as 13. POOH and lay down BHA. 2W-17 APD Page 5 of 7 ~ ~ Printed: 27-Sep-07 _v . '~' Appl~n for Permit to Drill, Well 2W-17 Saved: 27-Sep-07 14. Log well with FMI and Sonic Scanner. `"' 15. Run 4-1/2" liner completion with +/- 200' overlap into intermediate casing and cement same. 16. Run 3-1/2" tubing with GLMs and chemical injection mandrel with control line attached for paraffin inhibition) to OD of tbg. Land 3-1/2" completion tubing string in the seal bore in the 4-1/2" liner top and pressure test to 3000 psi. Record results. 17. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 18. Pressure up to shear out valve in lowest GLM and freeze protect outer annulus with diesel to below the permafrost. Set BPV. Release rig. 19. Clean location and RDMO. 20. MIRU coiled tubing. Displace mud from well with brine. 21. RU E-Line, perforate well. Flow test well. 22. RU Dowell, frac well. 23. RD Dowell, secure well, handover to production 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dri11 mustc be accompanied by each of the following items, exceptfor mz item already on frle with the commission and identified in the application: (14) a general description of hrnv the operator plans to dispose of driIIing mud and cuttings and a statement of whether the operator intends to request authorisation under 20 ,4AC 2.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II ~ disposal well. All cuttings'generatedwill be hauled'to the Prudhoe Bay Gririd and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary 2W-17 APD Page 6 of 7 Printed: 27-Sep-07 ' Alaska Inc ConocoPh~llips , CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 8/14/2007 Time: 14:40:27 Page: 1 True North Well: Plan: 2W-17 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Vertical (T VD) Reference: , Plan: 2W-17 (28+62.9) 90.9 ~ Site: Kuparuk 2W Pad Well: Plan: 2W-17 Section (VS) Reference: ~ Well (O.OON,O.OOE,178.34Azi) Db: Oracle ' Survey Calculation Method: Minimum Curvature cllpath: Plan: 2W-17 ~S Plan: 2W-17wp03 Date Composed: 8/14/2007 direct south azimuth Version: Tied-to: 4 From Well Ref. Point Principal: Yes Field: Kuparuk 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 Site: Kuparuk 2W Pad Site Position: Northing: 5979339.00 ft Latitude: 70 149 21 16.990 N 193 W 50 47 From• Map Easting: 518909.82 ft Longitude: . True Position Uncertainty: 0.00 ft North Reference: 14 deg 0 Ground Level• 0.00 ft Grid Convergence: . Well: Plan: 2W-17 Slot Name: surf coordinates are estimates only 70 454 N 21 21 Well Position: +N/-S 453.88 ft Northing: 59797 93.30 ft Latitude: 149 . 783 W 50 41 +E/-W 185.06 ft Easting : 519093.72 ft Longitude: . Position Uncertainty: 0.00 ft Wellpath: Plan: 2W-17 Drilled From: Well Ref. Point 00 ft 28 Tie-on Depth: . Current Datum: Plan: 2W-17 (28+62.9) Height 90.90 ft Above System Datum: Mean Sea Level Magnetic Data: 7/16/2007 Declination: l 23,14 deg 82 deg 80 Field Strength: 57608 nT e: Mag Dip Ang . ction Di Vertical Section: Depth From (TVD) +N/-S +E/-W re de ft ft ft g 28.00 0.00 0.00 178.34 Survey Program for Definitive Wellpath Date: 7/17/2007 Validated: No Version: 1 Toolcode Tool Name , Actual From To Survey ft ft Plan Section Information A1D Incl lzim TVD +N/-S +E/-W DLS Build 'T'urn TFO Target ~ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 00 00 0 0 0.00 0.00 00 00 0 0 500.00 0.00 0.00 500.00 00 178.12 799.45 00 6 800 0.00 -15.69 . . 0.00 0.51 2.00 2.00 . . 0.00 178.12 . . 2076.86 44.31 178.12 1933.83 -548.06 18.01 3.00 3.00 00 0 0.00 0.00 00 00 0 0 6571.74 44.31 178.12 5150.47 -3685.98 . 121.14 0.00 49 50 -3 3 . . 39 37 177 0 7120.91 25.12 180.14 5599.81 90 5780 -3997.15 04 -4082 . . 127.20 99 0.00 0.00 126 . . 0.00 0.00 2W-17wp03 T1 . 7320.91 25.12 180.14 14 5940.90 12 180 62 25 7497 . -4157.05 . 126.80 0.00 0.00 0.00 0.00 2W-17wp03 T2 . . . 7967.00 25.12 180.14 6365.90 -4356.29 126.30 0.00 0.00 0.00 0.00 2W-17wp03 TD ORIGINAL WELL DETAILS Name +N/-S +E/-W Northing Easting Latitude Longitude Slot ` .,,__. ~w ,~ nc~ uu 1R5 nh 5979793.30 519093.72 70°21'21.454N 149°50'41.783W N/A WELLPATH DETAILS Plan: 2W-17 Rig: Doyon 141 Ref. Datum: Plan: 2W-17 (28+62.9) 90.90ft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 178.34° 0.00 0.00 28.00 T M Azimuths to True North Magnetic North: 23.14° Magnetic Field Strength: 57608nT Dip Angle: 80.82° Date: 7/16/2007 Model: bggm2007 s a S +^ 1 __ SURVEY PROGRAM -4000 - ~ 00 ~ I Depth Fm Depth To Survey/Plan Tool ~ 2W-17 03 28.00 1000.00 Planned: 2W-17wp03 V4 CB-GYRO-SS ~ _ 1000.00 7967.00 Planned: 2W-17wp03 V4 MWD+IFR-AK-CAZ-SC ._ e ....r V ~ ~( 200 a a ~ 40C F 2000 4000 West(-)/East(+) [2000R/in] PLAN DETAILS 2W-17wp03 direct south azimuth Version 4 8/14/2007 Start Point MD Inc Azi TVD +N/-S +E/-W 28.00 0.00 0.00 28.00 0.00 0.00 REFERENCE INFORNUITION taVenkal~ )Relererce: Plenl 2W~1](26+62.9)9U 90~NoM Se<tion NS) Relerence: Slot- (O OON,O OOE) Meawred Depth Releren<e: Vlan: ZW-1] 126+62.9) 90.90 Calculation Merho4: Minimum CUrvaWre Interpolation ~Iethod:~ID Interval: 25.00 Depth Range From: 28.00 'I'o: 7967.00 Maximum Range: 993.90 ReTerenc~e: Plan: 2W-17Wp03 From Colour To MD 28 250 250 500 500 750 750 '•-~ 1000 1000 1250 1250 1500 2W-16 (2W-16) 1500 1750 ~ aW->« t7v~-><~so 2000 ' -~ 2000 2soo 2500 3000 _~~ 3000 L 3500 F _ 3.500 4000 000 4500 4 0 . 5000 \ _ 500 6000 6000 7000 000 8000 8000 9000 ~ 90'00 ~ 10000 ~" 1000 ~~ ~ 12000 "' 12000, - ~ \ 14000 ~ 140001 ~~6000 16000 1 8000 18000 1 20000 25000 30 2W-O1 ~' COMPANY DETAILS CunocoPhiaips Alaska Inc. Engineenug Calculation Mcthod: Mmmtwn Curvatwe F ur Scstcm: [SCWSA Scan Mehod Trav C)'lind<r Nnnh ErturSwrace. Elliptical+Casiug Warning Method: Rules based - -20 ~~-"~ 20 -10 ,- 0 27 50 10 Cylinder Azimuth (TFO+AZq [degJ vs Centre to Centre Separation [IOOft/ink SURVEY PROGRAM pth Fm Depth To Survey/Plan Tool .00 1000.00 Planned: 2W-17wp03 V4 CB-GYRO-SS 00.00 7967.00 Planned: 2W-17wp03 V4 MWD+IFR-AK-CAZ SECTION UF:rAILS Sec MD Inc Azi TVD +N/-S +1:/-W DLeg TFace VSec 'l'arger 1 zRlro ooD Don zaa3 n3w oar ola o.al o.Do 2 SW.DO O.UO 0.00 500.00 0.00 0.00 0.00 000 0.00 3 ROO.OD (v00 178.12 79945 -15.59 0.51 2.00 178.12 I5 G9 4 1076 RG 44.31 178.12 1933.83 -544 06 IR 01 3 W aal 544.35 5 657174 44 i1 178-12 515047 -358598 12114 000 D00 3687.94 6 7120.91 '25.12 IRO-14 559981 -3997.15 12720 6 99 3.50 OW 177.39 W O 3999-IS 01 2W-17wp03 T1 4D34 7 7320.')1 25.12 62 25 12 A 7497 IA0.14 140 14 178090 59411.M1 -0042.04 -015705 . 12 IZG.RO nal . (1 W . 415898 2W-17xyD3 T2 . . 9 7967.00 25.12 . 180.14 6365.90 -035629 126.30 0.00 0.00 4358.12 2W-17xp03 TD a 0 --- From Colour _ To i _ _ ~ 28 250 33 250 500 500 ~ 750 " "; -- - -30~ ~ 750 100 /' . ~ ~ -~~~ 0 1 125 -' ~~ ~-. ~ ~ , 1 ~ 150 %' ' .= ,- ~ : "- .-'y' -- SOb[ 1 ,~ ~ .w...~ 20-, 750 175 200 ,' y~r % ~ ; " ' . ~. , 1 ~`• ~ 2000 ~~ ~ 250 / t ~, - , ~ ~ 2500 300 ;' /~`~ ~~~ ~~ ~ ~'~ ~~ 3000 -}~ 35C ~ / " ~ y - ; ~ , A%~ ~ ' .3500 ~ 40C -1--f~ " (' ! ~ ~~ •~1~, `, ~. X4000 45C ,t ,t ' t ~ 7000 , 8 l `\ ~~~\`x ;" ~- ` `tt ' '~„ '8000 9 \ ~ ``~ t~ ~, \ ~ . - i 9000 / 1 , -~ , ~,' ~` ~ ` ` , ' ~ 10000 2000 / 1 ~, ., ~. ~ . ~~ ~ ~ A ~ ~ 1 14000/` 1 ~ >'. ~; ~ -- ~ ' ~f)'" ~. 1600,0 ?.~ - 1 ,`~ - ~ ~ 18 , ~ \ 0 ~ - --- ~ ~" 21 ~ ~ ~ 50 180 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Sepazation [20fUin] A!~~rl-coLl,lslorr sH:rTrncs luterpolation 1~lcthod:P1 D Interval: 50.00 Depth Range Frou-: 28.00 To: 79G7.OU 1~n~anunu R.r,n~c: 993.90 Rcfcreucc: Plan: 2W-17Wp03 125 100 5 ~ 2W-16 (2W-16) Tool C&GYRO-SS From Colour To MD 28 --° 250 250 500 500 750 750 1000 1000 1250 1250 1500 1500 1750 1750 ~r.a - . 2000 2000 2500 2500 3000 3000 3500 3500 400 4000 450 4500 5000 5000 6000 6000 7000 7000 8000 8000 9000 9000 --' 10000 10000 12000 12000 14000 14000 16000 16000 18000 18000 20000 20000 25000 ~~ 00 150 170 S[JRVEY PROGRAM Fm Depth To Survey/Plan 1000.00 Planned: 2W-17wp03 V4 D 7967.00 Planned: 2W-17wp03 V4 Travelling Cylinder Azimuth (TFO+AZI) [deg[ vs Centre to Centre Separation [SOft/in[ ' li s Alaska Inc ConocoPhil p , CPAI Plan Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 2W Pad Well: PIan:2W-17 ~I_ ~Vellpath: Plan: 2W-17 Survev 1D Incl Azim TVD Sys TVD n/S ft deg deg ft ft ft 28.00 0.00 0.00 28.00 -62.90 0.00 100.00 0.00 0.00 100.00 9.10 0.00 200.00 0.00 0.00 200.00 109.10 0.00 300.00 0.00 0.00 300.00 209.10 0.00 400.00 0.00 0.00 400.00 309.10 0.00 500.00 0.00 0.00 500.00 409.10 0.00 600.00 2.00 178.12 599.98 509.08 -1.74 700.00 4.00 178.12 699.84 608.94 -6.97 800.00 6.00 178.12 799.45 708.55 -15.69 900.00 9.00 178.12 898.59 807.69 -28.73 1000.00 12.00 178.12 996.90 906.00 -46.94 1100.00 15.00 178.12 1094.13 1003.23 -70.27 1200.00 18.00 178.12 1190.00 1099.10 -98.65 1300.00 21.00 178.12 1284.25 1193.35 -132.01 1400.00 24.00 178.12 1376.63 1285.73 -170.26 1500.00 27.00 178.12 1466.88 1375.98 -213.28 1600.00 30.00 178.12 1554.75 1463.85 -260.96 1700.00 33.00 178.12 1640.00 1549.10 -313.18 1800.00 36.00 178.12 1722.40 1631.50 -369.78 1900.00 39.00 178.12 1801.73 1710.83 -430.62 2000.00 42.00 178.12 1877.76 1786.86 -495.52 2076.86 44.31 178.12 1933.83 1842.93 -548.06 2100.00 44.31 178.12 1950.39 1859.49 -564.21 2200.00 44.31 178.12 2021.95 1931.05 -634.02 ` 2300.00 44.31 178.12 2093.51 2002.61 -703.83 2400.00 44.31 178.12 2165.08 2074.18 -773.64 2500.00 44.31 178.12 2236.64 2145.74 -843.46 2600.00 44.31 178.12 2308.20 2217.30 -913.27 2700.00 44.31 178.12 2379.76 2288.86 -983.08 2728.28 44.31 178.12 2400.00 2309.10 -1002.82 2800.00 44.31 178.12 2451.33 2360.43 -1052.89 2900.00 44.31 178.12 2522.89 2431.99 -1122.70 3000.00 44.31 178.12 2594.45 2503.55 -1192.51 3100.00 44.31 178.12 2666.01 2575.11 -1262.32 3200.00 44.31 178.12 2737.57 2646.67 -1332.13 3300.00 44.31 178.12 2809.14 2718.24 -1401.94 3400.00 44.31 178.12 2880.70 2789.80 -1471.75 3500.00 44.31 178.12 2952.26 2861.36 -1541.57 3600.00 44.31 178.12 3023.82 2932.92 -1611.38 3700.00 44.31 178.12 3095.39 3004.49 -1681.19 3800.00 44.31 178.12 3166.95 3076.05 -1751.00 3900.00 44.31 178.12 3238.51 3147.61 -1820.81 4000.00 44.31 178.12 3310.07 3219.17 -1890.62 4100.00 44.31 178.12 3381.64 3290.74 -1960.43 4200.00 44.31 178.12 3453.20 3362.30 -2030.24 4300.00 44.31 178.12 3524.76 3433.86 -2100.05 4400.00 44.31 178.12 3596.32 3505.42 -2169.87 4500.00 44.31 178.12 3667.88 3576.98 -2239.68 4600.00 44.31 178.12 3739.45 3648.55 -2309.49 4700.00 44.31 178.12 3811.01 3720.11 -2379.30 4800.00 44.31 178.12 3882.57 3791.67 -2449.11 4900.00 44.31 178.12 3954.13 3863.23 -2518.92 ~nnann 4x.31 178.12 4025.70 3934.80 -2588.73 llate: 8/14/2007 Cime: 14:40:27 Page: 2 Co-ordinate(1F) Reference: Well: Plan: 2W-17, True North Vertical (TVD) Reference: Plan: 2W-17 (28+62.9) 90.9 Section (VS) Reference: Well (O.OON,O.OOE,178.34Azi) Surrey Calculation Method: Minimum Curvature DbOracle E/V1' Mapti MapE DLS TP'O Comment ft ft ft deg/100ft deg 0.00 5979793.30 519093.72 ° 0.00 0.00 0.00 5979793.30 519093.72 0.00 0.00 0.00 5979793.30 519093.72 0.00 0.00 0.00 5979793.30 519093.72 0.00 0.00 0.00 5979793.30 519093.72 0.00 0.00 0.00 5979793.30 519093.72 0.00 0.00 KOP °' 0.06 5979791.56 519093.78 2.00 0.00 0.23 5979786.33 519093.97 2.00 0.00 0.51 5979777.62 519094.27 2.00 0.00 0.94 5979764.58 519094.74 3.00 360.00 1.54 5979746.37 519095.38 3.00 360.00 2.31 5979723.04 519096.21 3.00 360.00 3.24 5979694.67 519097.21 3.00 360.00 4.34 5979661.31 519098.39 3.00 360.00 5.59 5979623.08 519099.75 3.00 360.00 7.01 5979580.06 519101.27 3.00 360.00 8.57 5979532.39 519102.96 3.00 360.00 10.29 5979480.18 519104.81 3.00 360.00 12.15 5979423.59 519106.81 3.00 360.00 14.15 5979362.76 519108.97 3.00 360.00 16.28 5979297.87 519111.26 3.00 360.00 18.01 5979245.35 519113.12 3.00 360.00 18.54 5979229.19 519113.70 0.00 0.00 20.83 5979159.40 519116.17 0.00 0.00 23.13 5979089.60 519118.64 0.00 0.00 25.42 5979019.80 519121.11 0.00 0.00 27.72 5978950.00 519123.58 0.00 0.00 30.01 5978880.20 519126.06 0.00 0.00 32.31 5978810.41 519128.53 0.00 0.00 32.96 5978790.67 519129.23 0.00 0.00 9 5/8" x 12 1 /4" 34.60 5978740.61 519131.00 0.00 0.00 36.90 5978670.81 519133.47 0.00 0.00 39.19 5978601.01 519135.95 0.00 0.00 41.48 5978531.21 519138.42 0.00 0.00 43.78 5978461.42 519140.89 0.00 0.00 46.07 5978391.62 519143.36 0.00 0.00 48.37 5978321.82 519145.83 0.00 0.00 50.66 5978252.02 519148.31 0.00 0.00 52.96 5978182.22 519150.78 0.00 0.00 55.25 5978112.43 519153.25 0.00 0.00 57.55 5978042.63 519155.72 0.00 0.00 59.84 5977972.83 519158.19 0.00 0.00 62.13 5977903.03 519160.67 0.00 0.00 64.43 5977833.23 519163.14 0.00 0.00 66.72 5977763.44 519165.61 .0.00 0.00 69.02 5977693.64 519168.08 0.00 0.00 71.31 5977623.84 519170.56 0.00 0.00 73.61 5977554.04 519173.03 0.00 0.00 75.90 5977484.24 519175.50 0.00 0.00 78.20 5977414.45 519177.97 0.00 0.00 80.49 5977344.65 519180.44 0.00 0.00 82.78 5977274.85 519182.92 0.00 0.00 85.08 5977205.05 519185.39 0.00 0.00 h ` ,' 4 ' Alaska Inc ConocoPhillips , CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 8/14/2007 Time: 14:40:27 Page: 3 Cicld: Kuparuk River Unit Co-ordin ate(NE) Referenc e: Well: Plan: 2W-1 7, True N orth Site: Kuparuk 2W Pad Vertical ('TVD) Reference: Plan: 2W-17 (28+62.9) 90 .9 Well: Pla n: 2W-17 Section ( ~'S) Reference: Well (O .OON,O.OOE,178.34Azi) ~'cllpaih: Pla n: 2W-17 Survey C alculation Aletho d: Minimum Curvat ure Dh: Oracle ~ Survey _ ' m MD Incl Azim TVD Sys TVU N1S E11Y MapN MapE DLS TF O Com ft deg deg ft ft ft ft ft ft deg/100ft deg 00 5100 44.31 178.12 4097.26 4006.36 -2658.54 87.37 5977135.25 519187.86 0.00 0.00 . 5200.00 44.31 178.12 4168.82. 4077.92 -2728.35 89.67 5977065.46 519190.33 0.00 0.00 5300 00 44.31 178.12 4240.38 4149.48 -2798.16 91.96 5976995.66 519192.80 0.00 0.00 . 5400.00 44.31 178.12 4311.94 4221.04 -2867.98 94.26 5976925.86 519195.28 0.00 0.00 5500 00 44.31 178.12 4383.51 4292.61 -2937.79 96.55 5976856.06 519197.75 0.00 0.00 . 5600 00 44.31 178.12 4455.07 4364.17 -3007.60 98.85 5976786.26 519200.22 0.00 0.00 . 5700.00 44.31 178.12 4526.63 4435.73 -3077.41 101.14 5976716.47 519202.69 0.00 0.00 00 5800 44.31 178.12 4598.19 4507.29 -3147.22 103.43 5976646.67 519205.16 0.00 0.00 . 5900 00 44.31 178.12 4669.76 4578.86 -3217.03 105.73 5976576.87 519207.64 0.00 0.00 . 6000 00 44.31 178.12 4741.32 4650.42 -3286.84 108.02 5976507.07 519210.11 0.00 0.00 . 00 6100 44.31 178.12 4812.88 4721.98 -3356.65 110.32 5976437.27 519212.58 0.00 0.00 . 6200.00 44.31 178.12 4884.44 4793.54 -3426.46 112.61 5976367.48 519215.05 0.00 0.00 00 6300 44.31 178.12 4956.00 4865.10 -3496.27 114.91 5976297.68 519217.53 0.00 0.00 . 00 6400 44.31 178.12 5027.57 4936.67 -3566.09 117.20 5976227.88 519220.00 0.00 0.00 . 00 6500 44.31 178.12 5099.13 5008.23 -3635.90 119.50 5976158.08 519222.47 0.00 0.00 . 74 6571 44.31 178.12 5150.47 5059.57 -3685.98 121.14 5976108.01 519224.24 0.00 0.00 . 6600.00 43.32 178.18 5170.86 5079.96 -3705.53 121.77 5976088.46 519224.92 3.50 177.39 6700 00 39.82 178.44 5245.66 5154.76 -3771.85 123.73 5976022.16 519227.05 3.50 177.34 . 6800 00 36.33 178.73 5324.37 5233.47 -3833.49 125.26 5975960.53 519228.74 3.50 177.15 . 00 6900 32.83 179.08 5406.69 5315.79 -3890.22 126.36 5975903.80 519229.98 3.50 176.92 . 7000.00 29.34 179.50 5492.32 5401.42 -3941.84 127.01 5975852.19 519230.76 3.50 176.63 7100.00 25.85 180.02 5580.93 5490.03 -3988.15 127.22 5975805.88 519231.09 3.50 176.27 91 7120 25.12 180.14 5599.81 5508.91 -3997.15 127.20 5975796.89 519231.10 3.50 175.81 . 7200 00 25.12 180.14 5671.42 5580.52 -4030.72 127.12 5975763.32 519231.10 0.00 0.00 . 7300 00 25 12 14 180 5761.97 5671.07 -4073.16 127.01 5975720.88 519231.10 0.00 0.00 . 91 7320 . 25 12 . 180.14 5780.90 5690.00 -4082.04 126.99 5975712.00 519231.10 0.00 0.00 2W-17wp03 T1 . 7338.58 . 25.12 180.14 5796.90 5706.00 -4089.54 126.97 5975704.50 519231.10 0.00 0.00 C3 7349 63 12 25 180.14 5806.90 5716.00 -4094.23 126.96 5975699.82 519231.10 0.00 0.00 C1 . 7371.72 . 25.12 180.14 5826.90 5736.00 -4103.60 126.94 5975690.44 519231.10 0.00 0.00 B 00 7400 12 25 180.14 5852.51 5761.61 -4115.61 126.91 5975678.44 519231.10 0.00 0.00 " " . 15 7429 . 25 12 180.14 5878.90 5788.00 -4127.98 126.87 5975666.07 519231.10 0.00 0.00 x 8 3/4 7 . 7486.58 . 25.12 180.14 5930.90 5840.00 -4152.36 126.81 5975641.69 519231.10 0.00 0.00 A5 62 7497 25.12 180.14 5940.90 5850.00 -4157.05 126.80 5975637.00 519231.10 0.00 0.00 2W-17wp03 T2 . 7500 00 25 12 180.14 5943.05 5852.15 -4158.06 126.80 5975635.99 519231.10 0.00 0.00 . 71 7519 . 25.12 180.14 5960.90 5870.00 -4166.42 126.78 5975627.63 519231.10 0.00 0.00 A3 . 7600 00 25.12 180.14 6033.60 5942.70 -4200.50 126.69 5975593.55 519231.10 0.00 0.00 . 7700.00 25.12 180.14 6124.14 6033.24 -4242.95 126.58 5975551.11 519231.10 0.00 0.00 7800 00 25.12 180.14 6214.69 6123.79 -4285.40 126.48 5975508.67 519231.11 0.00 0.00 . 00 7900 12 25 14 180 6305.23 6214.33 -4327.84 126.37 5975466.22 519231.11 0.00 0.00 . . 7967.00 . . 25.12 . 180.14 6365.90 ~ 6275.00 -4356.29 126.30 5975437.78 519231.11 0.00 0.00 2W-17wp03 TD Targets ~~ ~~ - _ ~~ - ~ Map Map < --- Latitu de ----> <--- Longih~dc ---' Name Description TVD +N/-S +~;/-W Northing Casting D eg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 2W-17wp03 T1 5780.90 -4082.04 126.99 5975712.00 519231.10 70 20 41. 308 N 149 50 38.073 W -Plan hit target 2W-17wp03 T2 5940.90 -4157.05 126.80 5975637.00 51 9231.10 70 20 40. 570 N 149 50 38.078 W -Plan hit target 2W-17wp03 TD 6 365.90 - 4390.07 126.21 5975404.00 51 9231.11 70 20 38 .278 N 149 50 38.096 W -Plan out by 33 .78 at 6365.90 -4356.29 126.30 5975437.78 51 9231.11 70 20 38 .611 N 149 50 38.093 W O'~IGINAL . . ConocoPh~lhps CPAI Plan Alaska Inc. Report Company: ConocoPhillips Alaska Inc. Date: 8/14/2007 Time: 14:40:27 Page: ~+ True North WeII: Plan: 2W-17 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Vertical (T VD) Refcrence: , Plan: 2W-17 (28+62.9) 90.9 Site: Kuparuk 2W Pad Section (VS) Refcrence: Well (O.OON,O.OOE,178.34Azi) WeII: Plan: 2W-17 Sun ey Calculation Alethod: Minimum Curvature Db: Oracle - I ath: ~i el p Plan: 2W-17 -- - - Annotation _ - - -- - --~ 111D TVD ft ft - -- J 500 00 500 00 KOP Casing Poi nts -- - --- ~~1D T~'D Diameter Hole Size Name ft ft in in - - _ - 2728.28 2400.00 9.625 12.250 9 5/8" x 12 1/4" 7429.15 5878.90 7.000 8.750 7"x 8 3/4" 7967.00 6365.90 4.500 6.125 4 1 /2" x 6 1 /8" orations _ or __ ~ - ' _ - Litholog ~ >' - - --~ Dip Angle Dip Direction MD D Formations T~ deg deg ft ft _- -. - - _ _.- - -- 0.00 0.00 7320.91 5780.90 C4 0.00 0.00 7338.58 5796.90 C3 0.00 0.00 7349.63 5806.90 C1 0.00 0.00 7371.72 5826.90 B 0.00 0.00 7486.58 5930.90 A5 0.00 0.00 7497.62 5940.90 A4 0.00 0.00 7519.71 5960.90 A3 ''1~1~1~,1~~ ConocoPhilli s Alaska, Inc. P Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 8/14/2007 Time: 15:27:10 Page: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 2W Pad Co-ordinate(NF.) Reference: Well: Plan: 2W-17, True North Reference Well: Plan: 2W-17 Vertical (TVD) Reference: Plan: 2W-17 (28+62.9) 90.9 ~~ Db: Oracle-~ ~cference Wellpath: Plan: 2W-17 _ - - - GLOBAL SCAN APPLIED: All wel-paths within 200'+ 100/1000 of reference Reference: Plan: 2W-17wp03 & NOT PLANNED PR Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.00 to 7967.00 ft Scan Method: Trav Cylinder North Maximum Radius: 993.90 ft Error Surface: Ellipse + Casing Casing Points -- MD TVD Diameter Hole Size Name ft ft In in - - 2728.28 2400.00 9.625 12.250 9 5/8" x 12 1/4" 7429.15 5878.90 7.000 8.750 7"x 8 3/4" 7967.00 6365.90 4.500 6.125 4 1 /2" x 6 1 /8" Plan: 2W-17wp03 Date Composed: 8/14/2007 direct south azimuth Verson: 4 Fro Point m Well Ref Principal: Yes Tied-to: . Summary - - -- -- -~ - - <______________________ OffsetWellpath - ----------------------~ Reference Offset Ctr Ctr No-Go allowable iation D Warning We0 Site V1'ellpath MD MD Distance Area cft ft ft ft ft _ Kuparuk 2W Pad 2W-01 2W-01 V1 1941.35 1875.00 70.84 4 32.07 82 30 38.77 52 193 Pass: Major Risk Pass: Major Risk Kuparuk 2W Pad 2W-02 2W-02 V1 2018.12 1900.00 00 07 1950 2211 224.3 58 353 . 38.96 . 314.63 Pass: Major Risk Kuparuk 2W Pad 2W-03 2W-03 V1 2W-04 V1 . . 2281.42 2125.00 . 262.47 39.31 223.15 Pass: Major Risk Kuparuk 2W Pad 2W-04 2W-13 V1 497.89 500.00 241.22 11.26 229.95 Pass: Major Risk Kuparuk 2W Pad 2W-13 2W-14 V1 521.62 525.00 183.33 12.34 170.99 Pass: Major Risk Kuparuk 2W Pad 2W-14 2W-15 V1 522.06 525.00 119.24 10.55 108.69 Pass: Major Risk Kuparuk 2W Pad 2W-15 2W-16 V1 522.46 525.00 61.37 10.29 51.08 Pass: Major Risk Kuparuk 2W Pad 2W-16 Site: Kuparuk 2W Pad Rule Assigned: Major Risk Well: 2W-01 Inter-Site Error_ 0.00 ft Wellpath: 2W-01 V1 _ ~ ~ Reference Offset Scmi-M ajor Axis TPO+AZI TFO-IIS Casing/ Ctr-Ctr HSDistance No-Go Arca Altawable ation De Warning ~ 11D TVD Mp TVD Ref Offset i ft ft fl ft ft ft ft ft ft n deg deg __ _~ 90.90 90.90 95.00 95.00 0.07 0.00 202.18 202.18 490.16 1.72 80 1 488.43 35 488 Pass Pass 95.90 95.90 100.00 100.00 0.08 0.01 202.18 202.18 490.16 13 490 . 2 28 . 85 487 Pass 120.90 120.90 125.00 125.00 0.13 0.04 0 08 202.18 202.18 18 18 202 202 . 490.10 . 2.76 . 487.33 Pass 145.90 145.90 150.00 0 150.00 0.19 24 00 0 175 . 11 0 . . 18 202.18 202 490.07 3.25 486.82 Pass 170.90 170.90 175.0 . . . . 90 195.90 200.00 195 200.00 0.30 0.14 202.19 202.19 490.04 3.74 19 4 486.30 81 485 Pass Pass . 220.90 220.90 225.00 225.00 0.36 0.17 202.19 202.19 490.01 97 489 . 4 65 . 32 485 Pass 245.90 245.90 250.00 250.00 0.41 0.19 22 0 202.19 202.19 19 19 202 202 . 489.92 . 5.11 . 484.81 Pass 270.90 270.90 275.00 275.00 0.47 53 00 0 0 . 24 0 . . 19 202.19 202 489.87 5.57 484.30 Pass 295.90 295.90 300.00 . . 30 . . 320.90 320.90 325.00 325.00 0.58 0.27 202.19 202.19 489.81 6.03 49 6 483.78 26 483 Pass Pass 345.90 345.90 350.00 350.00 0.64 0.29 202.19 202.19 489.76 70 489 . 96 6 . 74 482 Pass 370.90 370.90 375.00 375.00 0.70 0.32 34 0 202.19 202.19 19 19 202 202 . 489.64 . 7.42 . 482.23 Pass 395.90 395.90 400.00 400.00 0.75 81 00 0 425 . 35 0 . . 19 202.19 202 489.59 7.82 481.77 .Pass 420.90 420.90 425.00 . . . . 90 445.90 450.00 445 450.00 0.87 0.35 202.19 202.19 489.54 8.23 63 8 481.32 87 480 Pass Pass . 470.90 470.90 475.00 475.00 0.92 0.35 202.19 202.19 489.50 47 489 . 03 9 . 44 480 Pass 495.90 495.90 500.00 500.00 0.98 0.35 202.19 202.19 24 08 . 35 489 . 9.31 . 480.05 Pass 524.76 524.76 525.00 525.00 0.99 0.34 33 0 . 202.20 10 22 24 202 . 489.00 9.57 479.43 Pass 554.37 554.37 550.00 550.00 0.99 . . . 583.98 583.96 575.00 575.00 0.99 0.31 202.24 24.12 488.40 56 487 9.83 01 10 478.58 477 56 Pass Pass 613.56 613.53 600.00 600.00 0.96 0.30 33 0 202.28 24.16 22 34 24 202 . 486.49 . 10.20 . 476.29 Pass 643.11 643.05 625.00 00 650 625.00 0.89 83 00 0 650 . 0.35 . . 202.40 24.28 485.18 10.39 474.78 Pass . 672.64 672.53 702.13 701.96 675.00 . . 675.00 0.76 0.38 202.48 24.36 483.63 10.59 473.04 Pass SRAM t • i 2W-17 Drilling Hazards Summary 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Miti anon Strate Broach of Conductor Low Monitor cellar continuousl durin interval. Gas Hydrates Moderate +/ If observed -control drill, reduce pump rates, reduce drilling fluid tem eratures, Additions of Lecithin. Gravel /Sand Sloughing Moderate Increase mud weight /viscosity, High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill (use of Tri s trip sheets), Pum in out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur -reduce pum rates and mud rheolo ,use LCM 8-3/4" Hole / 7" Casing Interval Event Risk Level Miti anon Strate Shale stabili in HRZ and K-1 Moderate Control with hi her MW and ro er drillin ractices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on tri s as a last resort. Abnormal Reservoir Pressure Low f Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance rior to drilling ay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 6-1/8" Hole / 4-1/2" Liner Interval Event Risk Level Miti anon Strate Differential Sticking Moderate Periodic wiper trips. Do not leave pipe static for extended period of time. Lube pills will be ready to be s otted if a stuck pi a incidents occurs. Difficulties getting liner to bottom Moderate Pump out of hole on final trip out prior to running liner to with swell packers ensure hole is clean. Spot lube pills in open and cased hole if needed. Lost Circulation Moderate Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, pre-treat with LCM prior to drilling fault crossings. S~~ ~C:y~l~~ ~ Y~~~~~~ r' 2W-17 Hazards prepared by Tim Billingsley 6/29/05 Page 1 of 1 oRicin~n~ 2W-17 Producer Top Set 3-1 /2" Completion String 3 '/2" TRMAXX-SE SCSSV with 2.812" X profile @ 2,228' MD / 2,000' TVD (w/'/4" line to surface) Drift everything except SCSSV & D nipple with 2.867" drift 9-5/8" 40# L-80 BTC -/- 2,728' MD / 2,400' TVD ~{)1tJ+CO~~'11 ~ ~ 1 X15 GLM #1 at +/- X,XXX' MD/ X,XXX' TVD GLM #2 at +/- X,XXX' MD/ X,XXX' TVD GLM #3 at +/- X,XXX' MD/ X,XXX' TVD GLM #4 at +/- X,XXX' MD/ X,XXX' TVD GLM #5 at +/- X,XXX' MD/ X,XXX' TVD (GLM locations still to be determined) Lowest 3 ''/2" x 1" Camco'KBMG' mandrel w/ 1" DCK-2 shear valve, pinned for 2000 psi casing to tubing shear two jts above "D"Nipple. Load rest of GLMs with dummy valves 3 'h" Camco'D' nipple w/ 2.75" No-Go Profile. Set at one jt above seals TOC @ 5,429' MD / 4,331' TVD 7" 26# L-80 BTCM @ 7,429' MD / 5,878' TVD 3 '/2" Baker 80-40 GBH-22 casing seal assembly w/ 15' stroke Baker Seal Liner top, with ZXP packer and SBE set at +/- 200' MD above 7" casing shoe Production Liner 4-1/2" 12.6# L-80 IBT Mod +/- 7,967' MD / 6,365' TVD ORIGINAL ina Job Desi n Schl~mberger CemCADE Prellm ry 9 9 518" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 9/26/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 1,928' MD. Max ECDs expected to be 11.4 ppg. Lead Slurry Minimum pump time: 220 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk I 0.7632 ft3/ft x (80') x 1.00 (no excess) = 61.1 ft3 < TOC at Surface 0.3132 ft3/ft x (1425' - 80') x 3.50 (250% excess) = 1474.4 ft3 0.3132 ft3/ft x (1928' - 1425') x 1.35 (35% excess) = 212.7 ft3 61.1 ft3 + 1474.4 ft3+ 212.7 ft3 = 1748.2 ft3 1748.2 ft3 / 4.45 ft3/sk = 392.9 sks Round up to 400 sks Previous Csg. < 76", 62.6# casing at 80' MD < Base of Permafrost at 1,425' MD (1,400' TVD) < Top of Tail at 1,928' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 2,728' MD (2,400' TVD) * Mark of Schlumberger Have 240 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 180 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3132 ft3/ft x (2728' - 1928') x 1.35 (35% excess) = 338.3 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 338.3 ft3 + 34.1 ft3 = 372.4 ft3 372.4 ft3/ 2.47 ft3/sk = 150.8 sks Round up to 160, sks BHST = 52`F, Estimated BHCT = 65~. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time Stage (bpm) (bbl) (min) (min) Comments CW100 5 50 10.0 10.0 Start Pumping Wash Drop Bottom Plug 15.0 25.0 MudPUSHlI 6 50 8.3 33.3 Start Pumping Spacer Lead Slurry 7 317 45.3 78.6 Mix and Pump Lead Slurry Tail Slurry 6 70 11.7 90.3 Mix and Pump Tail Slurry Drop Top Plug 8.0 98.3 Water 5 20 4.0 102.3 Switch to Rig Pumps 5.0 107.3 Displacement 7 171 24.4 131.7 Start Displacement Slow Rate 3 10 3.3 135.0 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 9.4 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 17-21, TY = 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. 'mina Job Desi n Schlamberger CemCADE Prell ry g 7" Intermediate Casin Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 9/26/2007 Prepared by: Maureen Tome Location: Anchorage, AK Phone: (907) 276-1215 Mobile: (907) 952-0445 email: mtorrie@slb.com Previous Csg. < 9 5/8", 40.0# casing at 2,728' MD ~~ < Top of Tail at 5,429' MD Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above Ugnu C formation - (Ugnu C at 6546' MD, TOC at 6046' MD, 2000' MD annular length). Max ECDs expected to be 14.3 ppg. Tail Slurry Minimum thickening time: 250 min. (Pump time plus 120 min.) 15.8 ppg Class G + 2.0 gps D600G + 0.02% 6155 + 0.3% D65 + 0.2 gps D47 + 1/4# per Sack D29 - 1.16 ft3/sk 0.1503 ft3/ft x 2000' x 1.25 (25% excess) = 375.8 ft3 0.2148 ft3/ft x 80' (Shoe Joint) = 17.2 ft3 375.8 ft3 + 17.2 ft3 = 393.0 ft3 393.0 ft3/ 1.16 ft3/sk = 338.8 sks Round up to 340 sks BHST = 129`F, Estimated BHCT = 60~. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time ' Stage (bpm) (bbl) (min) (min) Comments Drop Bottom Plug 10.0 10.0 MudPUSH II 6 25 4.2 14.2 Start Pumping Spacer Tail Slurry 6 70 11.7 25.9 Mix and Pump Tail Slurry Drop Top Plug 10.0 35.9 Water 5 20 4.0 39.9 Switch to Rig Pumps 5.0 44.9 Displacement 7 251 35.9 80.8 Start Displacement Slow Rate 3 10 3.3 84.1 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 11.5 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. < 7^, 2s.o# casing Spacer Properties: 12.5 ppg MudPUSH* II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement in 8 3/4" off placement. TD at 7,429' MD (5,878' ND) ORIGINAL ' ob Desi n Schlumberger CemCADE Prellminary J g 4 1/2" Liner Preliminary Job Design based on limited input data. For estimate purposes only. - Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska Revision Date: 9/26/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Top of Tail at < 7,079' MD < Liner Top at 7,229' MD Previous Csg. 7", 26.0# casing at 7,429' MD < 4 1/2", 12.6# casing Volume Calculations and Cement Systems Volumes are based on 25% excess. Displacement is calculated with a 3.5"- 15.5# drill string. Cement job is designed to seal off liner top by bringing cement 150' above liner top, with 15.8 ppg G cement. Maximum dynamic pressure experienced during cement job is expected to be 14.0 ppg. Tail Slurry Minimum thickening time: min. (pump time plus 120 min.) 15.8 ppg Class G + 2.0 gps D600G + 0.02% 6155 + 0.3% D65 + 0.2 gps D47 - 1.16 ft3/sk Liner Cap: 0.1480 ft3/ft x 150' x 1.00 (no excess) = 22.2 ft3 Liner Lap: 0.1044 ft3/ft x (7429' - 7229') x 1.00 (no excess) = 20.9 ft3 Annular Volume: 3 0.0942 ft3/ft x (7967' - 7429') x 1.25 (25% excess) = 63.3 ft Shoe Volume: 3 0.0854 ft3/ft x 80' x 1.00 (no excess) = 7.7 ft Totals: 22,2 ft3+20.9ft3+63.3ft3+7.7ft3= 114.1 ft3 114.1 ft3/ 1.16 ft3/sk = 98.4 sks Round up to 100 sks BHST = 139`F, Estimated BHCT = 109. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time Stage in) Comm in 6 1/8"off MudPUSH II 6 15 2.5 2.5 Start Pumping Spacer Tail Slurry 6 21 3.5 6.0 Mix and Pump Tail Slurry Drop Wiper Dart 3.0 9.0 Displacement 6 48 10.0 19.0 Start Displacement Slow Rate 3 10 3.3 22.3 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 12 ppg, Pv < 15, TY < 22. As thin and light as possible to TD at 7,967' MD aid in mud removal during cementing. (6,365' TVD) Spacer Properties: 13.5 ppg MudPUSH* II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint for proper cement placement. Mark of Schlumberger 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 Page 1 of 2 Maunder, Thomas E (DOA) From: Greener, Mike R. [Mike.R.Greener@conocophillips.com] Sent: Tuesday, October 02, 2007 1:46 PM To: Maunder, Thomas E (DOA) Subject: RE: 2W-17 The original reservoir pressure prediction for this well was based on a material balance calculation which indicated that the reservoir pressure in the "A" sand (below the top set point) could be as high as 4,100 psi which would be equivalent to the 13.2 ppg EMW listed in section 4. Since that calculation was made, some measurements have been taken in offset we112W- 04 which indicates "C" sand pressure at 3,000 psi and the "A" sand pressure at 3,500 psi which would be 10 ppg for the "C" .sand and 11.3 for the "A" sand. To be safe we need. to respect the 4,100 psi material balance calculation and expect a +/- 13.2 ppg pressure in the "A" sand. SO: Item 1: Using the predicted 4,100 psi reservoir pressure the formula should be changed to: MPSP = (5,960 ft TVD)*(.69-.ll psi/ft) MPSP = 3,444 psi. Item 2: The 11.5 ppg MW for the production section is incorrect. We will plan fora 13.2 ppg pressure based on the material balance calculations for the "A" sand and up to 11.5 ppg for the "C" sand Original Message----- From: er, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, r 02, 2007 1:06 PM To: Greener, Mike R. Subject: 2W-17 Mike, We are beginning review of the permit application. There area of questions ... 1. Please check your calculations for MPSP. On page 3, it appears that the ect gradient is used in the calculation. 10/2/2007 Page 1 of 1 Maunder, Thomas E {DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, October 02, 2007 1:06 PM To: 'Greener, Mike R.' Subject: 2W-17 Mike, We are beginning review of the permit application. There are a couple of questions 1. Please check your calculations for MPSP. On page 3, it appears that the incorrect gradient is used in the calculation. 2. Based on the BH EMW, it appears that the production interval MW is insufficient. Look forward to your reply. Call or message with any questions. Tom Maunder, PE AOGCC 10/2/2007 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~~ ~ ~ p' PTD# ~Y ~'~ ~~ °~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing welt (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(f), all records, 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 to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater 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 Well for name f2 well) until after SComnany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. !Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 r ~ '~ N rn o ~~ ~ ~ ~ ~ ~ ~ ~ ~ Q ~ ~ ~ ~ ~ ~~ ~ ~ N. 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M __. . ~- ~ O ~ O I ~`` O ~ p C ~ N i. ~ N ii 1~6 N U p M y 0 N , I ~ ~ M O ~ N 0 ~N ~jJ ~ ~ O C O O ~ O i W i ~ O N •C ~ ~ l ~ o U w o ~ a E ¢ Q Q o N I rn w a a w F- a ~ Q acn Well History File APPENDIX • Information of detailed nature that is not particularly germane to the Well Pennitiing Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 2W-17.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Feb 20 15:46:31 2008 Reel Header Service name .............LISTPE Date . ...................08/02/20 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Tape Header Service name .............LISTPE Date . ...................08/02/20 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: scientific Technical services Library. scientific Technical services 2W-17 500292337000 ConocoPhillips Alaska, Inc Sperry Sun 20-FEB-08 MWD RUN 1 MWD RUN 2 MWD RUN 3 MW-000538552 MW-000538552 MW-000538552 P. ORTH P. ORTH T. GALVIN D. GLADDEN D. GLADDEN P. WILSON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 34 T12 9E 770 5273 .00 89.40 61.40 Page 1 ~ 6~ -~a5 # 15~~a ~ ~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 2w-17.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 8.750 9.675 2704.0 6.125 7.000 7418.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), BIMODAL ACOUSTIC TOOL (BAT), AND PRESSURE WHILE DRILLING (PWD). NO ACOUSTIC CALIPER (ACAL) DATA IS AVAILABLE FOR RUN 200 OWING TO TOOL MEMORY FAILURE. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL 2W-17 WITH API#: 50-029-23370-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7882'MD/6801'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (X- SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). CTFA = AVERAGE OF FAR NEUTRON DETECTOR COUNT RATE. CTNA = AVERAGE OF FAR NEUTRON DETECTOR COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED. (LOW COUNT RATE BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW COUNT-RATE BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION Page 2 ~ ~ 2w-17.tapx FACTOR. ALD SLIDE = NON-ROTATED INTERVALS REFLECTIONG ALD DEPTH. DTCP = SMOOTHED COMPRESSIONAL WAVE SLOWNESS - POST WELL PROCESSED. DTSP = SMOOTHED SHEAR WAVE SLOWNESS - POST WELL PROCESSED. VPVS = RATIO OF SHEAR TO COMPRESSIONAL VELOCITY. PARAMETERS USED IN POROSITY CALCULATIONS: HOLE SIZE: 8.9~~ - 6.2~~ FIXED SIZE MUD WEIGHT: 10.9-11.4 PPG MUD SALINITY: 250 - 150 PPM CHLORIDES FMTN WATER SALINITY: 22,000 - 14,545 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 Service Sub Level.Name... version Number. ........1.0.0 Date of Generation.......08/02/20 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 ROP 108.5 7882.0 GR 179.5 7816.0 DTC 2588.5 7748.5 RPX 2699.0 7823.0 PEF 2699.0 7803.0 FCNT 2699.0 7788.0 NPHI 2699.0 7788.0 RPD 2699.0 7823.0 RPM 2699.0 7823.0 RPS 2699.0 7823.0 NCNT 2699.0 7788.0 FET 2704.0 7823.0 DRHO 2704.0 7803.0 RHO6 2704.0 7803.0 DTSH 3295.5 7748.5 SCRA 3295.5 7748.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH Page 3 MERGED PBU MWD MWD MWD REMARKS 2W-17.tapx DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 108.5 2 2709.0 3 7425.0 MERGED MAIN PASS. MERGE BASE 2709.0 7425.0 7882.0 Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Di rection .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .liN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD FPH 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 NPHI MWD PU 4 1 68 32 9 FCNT MWD CP30 4 1 68 36 10 NCNT MWD CP30 4 1 68 40 11 RHOB MWD G/CC 4 1 68 44 12 DRHO MWD G/CC 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 DTC MWD USPF 4 1 68 56 15 DTSH MWD USPF 4 1 68 60 16 SCRA MWD NONE 4 1 68 64 17 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 108.5 7882 3995.25 15548 108.5 7882 ROP MWD FPH 0.34 523.42 144.392 15548 108.5 7882 GR MWD API 10.84 435.12 96.533 15274 179.5 7816 RPX MWD OHMM 0.42 783.57 4.63558 10165 2699 7823 RPS MWD OHMM 0.06 889.86 4.69752 10165 2699 7823 RPM MWD OHMM 0.84 2000 6.40239 10165 2699 7823 RPD MWD OHMM 0.91 2000 6.77495 10165 2699 7823 FET MWD HR 0.21 140.86 1.30778 10155 2704 7823 NPHI MWD Pu 11.12 51.23 36.9236 10011 2699 7788 FONT MWD CP30 202.9 2971.18 904.04 10011 2699 7788 NCNT MWD CP30 16486.4 191381 128585 10011 2699 7788 RHOB MWD G/cc 1.917 3.096 2.30896 10048 2704 7803 DRHO MWD G/CC -0.094 0.423 0.0432087 10048 2704 7803 PEF MWD B/E 1.77 16.61 3.29239 10072 2699 7803 DTC MWD USPF 82.282 171.197 112.899 10321 2588.5 7748.5 DTSH MWD USPF 139 283.608 211.763 8543 3295.5 7748.5 SCRA MWD NONE 1.418 2.523 1.93772 8543 3295.5 7748.5 Page 4 2W-17.tapx First Reading For Entire File..........108.5 Last Reading For Entire File...........7882 File Trailer service name... .......STSLI6.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/20 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header service name... .......STSL2B.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/20 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......ST5LI6,001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 108.5 2709.0 $R 179.5 2664.5 LOG HEADER DATA DATE LOGGED: 19-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 2709.0 TOP LOG INTERVAL (FT): 108.0 BOTTOM LOG INTERVAL (FT): 2709.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: 45.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132477 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 Page 5 DRILLER'S CASING DEPTH (FT): 2W-17.tapx BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) 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 ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 L~ .0 Native/spud Mud 9.20 300.0 9.8 300 .0 .000 .0 .000 75.2 .000 .0 .000 .0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 GR MWDO10 API 4 1 68 8 3 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 108.5 2709 1408.75 5202 108.5 2709 ROP MWDO10 FT/H 11.49 523.42 178.483 5202 108.5 2709 GR MWDO10 API 10.84 110.98 65.5767 4971 179.5 2664.5 First Reading For Entire File..........108.5 Last Reading For Entire File...........2709 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/20 Maximum Physical Record..65535 File Type ................LO Page 6 . ~ • 2W-17.tapx 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.......08/02/20 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log he ader data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DTC 2588.5 7303.0 GR 2665.0 7378.5 RPD 2699.0 7371.0 RPX 2699.0 7371.0 RPS 2699.0 7371.0 RPM 2699.0 7371.0 NPHI 2699.0 7328.5 FONT 2699.0 7328.5 PEF 2699.0 7342.0 NCNT 2699.0 7328.5 FET 2704.0 7371.0 DRHO 2704.0 7342.0 RHOB 2704.0 7342.0 ROP 2709.5 7425.0 SCRA 3295.5 7303.0 TSH 3295.5 7303.0 $ LOG HEADER DATA DATE LOGGED: 28-NOV-07 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7425.0 TOP LOG INTERVAL (FT): 2709.0 BOTTOM LOG INTERVAL (FT): 7425.0 BIT ROTATING SPEE D (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25.3 MAXIMUM ANGLE: 54.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132478 EWR4 ELECTROMAG. RESIS. 4 96540 CTN COMP THERMAL NEUTRON 231173 BAT BIMODAL ACOUSTIC 90144363 Page 7 R • 2w-17.tapx ALD AZIMUTHAL LITHO-DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) 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 Loging DireCtion .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 i 728188 8.750 2704.0 Lignosulfanate 10.90 60.0 9.8 250 .0 3.000 70.0 1.613 136.0 2.200 70.0 3.500 70.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MwD020 API 4 1 68 8 3 RPX MwD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MwD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MwD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-5 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MwD020 G/cM 4 1 68 48 13 PEF MwD020 BARN 4 1 68 52 14 DTC MWD020 USPF 4 1 68 56 15 DTSH MwD020 USPF 4 1 68 60 16 scRA MwD020 NONE 4 1 68 64 17 Page 8 • 2w-17.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2588.5 7425 5006.75 9674 2588.5 7425 ROP MWD020 FT/H 0.34 432.03 132.986 9432 2709.5 7425 GR MWD020 API 21.19 435.12 113.19 9428 2665 7378.5 RPX MWD020 OHMM 0.42 45.02 4.4788 9345 2699 7371 RPS MWD020 OHMM 0.06 45.04 4.5527 9345 2699 7371 RPM MWD020 OHMM 0.84 1663.7 4.84612 9345 2699 7371 RPD MWD020 OHMM 0.91 2000 5.98239 9345 2699 7371 FET MwD020 HOUR 0.21 140.86 1.00502 9335 2704 7371 NPHI MwD020 Pu-s 11.12 51.23 37.2583 9260 2699 7328.5 FCNT MWD020 CNTS 630.51 2971.18 946.593 9260 2699 7328.5 NCNT MWD020 CNTS 116580 191381 137020 9260 2699 7328.5 RHOB MwD020 G/CM 1.917 3.096 2.29948 9277 2704 7342 DRHO MWD020 G/CM -0.076 0.272 0.0440714 9277 2704 7342 PEF MWD020 BARN 1.77 14.29 3.06587 9287 2699 7342 DTC MwD020 USPF 85.165 171.197 114.551 9430 2588.5 7303 DTSH MWD020 USPF 139 283.608 214.723 7872 3295.5 7303 SCRA MWD020 NONE 1.418 2.523 1.94915 7872 3295.5 7303 First Reading For Entire File..........2588 Last Reading For Entire File...........7425 File Trailer Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/20 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/02/20 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY .5000 VENDOR TOOL CODE START DEPTH DTC 7303.5 GR 7379.0 PEF 7411.0 NPHI 7413.0 FCNT 7413.0 header data for each bit run in separate files. 3 STOP DEPTH 7748.5 7816.0 7803.0 7788.0 7788.0 Page 9 2w-17.tapx DTSH 7413.0 7748.5 SCRA 7413.0 7748.5 NCNT 7413.0 7788.0 FET 7413.5 7823.0 RPM 7413.5 7823.0 RPD 7413.5 7823.0 RPx 7413.5 7823.0 RPS 7413.5 7823.0 RHO6 7418.0 7803.0 DRHO 7418.0 7803.0 ROP 7427.5 7882.0 LOG HEADER DATA DATE LOGGED: 03-DEC-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7882.0 TOP LOG INTERVAL (FT): 7425.0 BOTTOM LOG INTERVAL (FT): 7882.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 19.7 MAXIMUM ANGLE: 24.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 CTN COMP THERMAL NEUTRON 10508998 BAT BIMODAL ACOU STIC 148321 EWR4 ELECTROMAG. RESIS. 4 228502 ALD AZIMUTHAL LITHO-DEN 102630 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 7418.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 11.40 MUD VISCOSITY (S): 47.0 MUD PH: 11.3 MUD CHLORIDES (PPM): 150 FLUID LO55 (C3): .0 RESISTIVITY (OHMM) AT TEMPERAT URE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.000 70.0 MUD AT MAX CIRCULATING TERM PERATURE: 1.735 126.0 MUD FILTRATE AT MT: 2.200 70.0 MUD CAKE AT MT: 3.500 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 10 • 2w-17.tapx Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Di rection .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MwD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MwD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MwD030 Pu-s 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MwD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 DTC MWD030 USPF 4 1 68 56 15 DTSH MwD030 usPF 4 1 68 60 16 SCRA MWD030 NONE 4 1 68 64 17 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7303.5 7882 7592.75 1158 7303.5 7882 ROP MWD030 FT/H 9.31 127.42 68.212 910 7427.5 7882 GR MWD030 API 37.9 130.96 92.9195 875 7379 7816 RPx MWD030 oHMM 1.64 783.57 6.42224 820 7413.5 7823 RPS MWD030 OHMM 1.64 889.86 6.34795 820 7413.5 7823 RPM MwD030 OHMM 1.63 2000 24.1381 820 7413.5 7823 RPD MwD030 OHMM 1.69 1637.19 15.8073 820 7413.5 7823 FET MwD030 HOUR 0.77 111.22 4.75443 820 7413.5 7823 NPHI MWD030 Pu-S 21.5 45.01 32.7975 751 7413 7788 FCNT MWD030 CNTS 202.9 765.34 379.354 751 7413 7788 NCNT MWD030 CNTS 16486.4 33698.1 24581.5 751 7413 7788 RHOB MwD030 G/CM 2.164 2.895 2.42301 771 7418 7803 DRHO MWD030 G/CM -0.094 0.423 0.0328288 771 7418 7803 PEF MwD030 BARN 3.4 16.61 5.97228 785 7411 7803 DTC MWD030 USPF 82.282 110.701 95.4084 891 7303.5 7748.5 DTSH MwD030 USPF 147.654 205.9 177.033 671 7413 7748.5 SCRA MWD030 NONE 1.573 2.094 1.80359 671 7413 7748.5 First Reading For Entire File..........7303.5 Last Reading For Entire File...........7882 File Trailer Service name... .......STSLIB.004 Service Sub Level~Name.,. version Number.........,.1.0.0 Page 11 ~. - • 2w-17.tapx gate of Generation.......08/02/20 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE gate . ...................08/02/20 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE gate . ...................08/02/20 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File • scientific Technical services scientific Technical services Page 12