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C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-10-08_22194_KRU_1J-101_EVCamera_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 222194 KRU 1J-101 50-029-23286-00 EV Camera 08-Oct-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC **** This is a very large file and is broke down into the following: Attn: Natural Resources Technician 205182_1J-101_EVCamera_08-Oct-24 (main Upload with 23 images) 333 W. 7th Ave., Suite 100 205182_1J-101_EVCamera_Video 1-15 Anchorage, Ak. 99501-3539 205182_1J-101_EVCamera_Video 16-31 Delivered By: CPAI Sharefile 205182_1J-101_EVCamera_Video 32-47 205182_1J-101_EVCamera_Video 48-61 **** ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 205-182 T39677 10/21/2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.21 09:50:52 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-11-21_21139_KRU_1J-101_MemoryCamera_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21139 KRU 1J-101 50-029-23286-00 Memory Camera 21-Nov-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 205-182 T38195 12/1/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 13:34:07 -09'00' 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 #:________________Signature12/21/2021Wd͗ϮϬϱϭϴϮϬ Ͳ^Ğƚ͗ϯϲϭϰϰJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1H-11950029235910000 KRU WLIPROFFINAL FIELD24-Jun-211H-11750029236020000 KRU WLIPROFFINAL FIELD16-Jun-213H-31A50103202050100 KRU WLCUTTERFINAL FIELD31-Jul-213S-61150103207740000 KRU WLCUTTERFINAL FIELD11-Oct-211R-10150029214040300 KRU WLSAMPLINGFINAL FIELD30-Jun-213H-3750103208220000 KRU WLGLSFINAL FIELD29-May-213F-0450029214490000 KRU WLIPROFFINAL FIELD23-Feb-211J-10150029232860000 KRU WLPPROFFINAL FIELD2-Mar-211D-0250029204290000 KRU WLIPROFFINAL FIELD17-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD18-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD20-Feb-21MP-150029205730000 KRU WLSCMTFINAL FIELD28-Mar-211G-0250029208130000 KRU WLIPROFFINAL FIELD1-Apr-211C-19050029231360000 KRU WLIPROFFINAL FIELD30-Oct-212L-31850103206810000 KRU WLIPROFFINAL FIELD24-Jul-21 - - 11/10/08 ~~~~~~~~ Schlumberger -DCS n , 2525 Gambell Street, Suite 400 ~>'s.~ ~. +-~ L ,., u~ Anchorage, AK 99503-2838 ATTN: Beth • ~ ~.~ Well Job # Log Description N0.4957 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD iC-119 11978488 INJECTION PROFILE 10/16/08 1 1 1J-101 11978491 PRODUCTION PROFILE 10/19/08 1 1 3H-02 12080447 INJECTION PROFILE ~ - ~-- ~- 10/24/08 1 1 3K-24 11978500 SBHP 10/26/08 1 1 iJ-120 11978501 PRODUCTION PROFILE ~ _. 10/27/08 1 1 3H-24 12080454 INJECTION PROFILE 10/28/08 1 1 3S-15 11978491 SBHP SURVEY - 10/18/08 1 1 iH-08 12100434 INJECTION PROFILE - J 10/30/08 1 1 1H-09 12096560 INJECTION PROFILE,~zC tq3~~ 1~-('}~ 10/30/08 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. Page 1 of 4 ~ • Maunder, Thomas E (DOA) From: Crisp, John H (DOA) Sent: Wednesday, October 22, 2008 8:16 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) ~ v Subject: FW: Nordic 3 West Sak 1J-101 Kick and BOP Shut In: UPDATE 9-14-08 ~ i~ ~J ~O From: Jones, Jeffery B (DOA) Sent: Monday, September 15, 2008 6:04 AM To: DOA AOGCC Prudhoe Bay Subject: FW; Nordic 3 West Sak iJ-101 Kick and BOP Shut In: UPDATE 9-14-08 FYI From: Nordic 3 Company Man jmailto:n1433@conocophillips.com] Sent: Sunday, September 14, 2008 8:50 PM To: Jones, Jeffery B (DOA) Cc: Nezaticky, Peter Subject: FW: Nordic 3 West Sak 1J-101 Kick and BOP Shut In: UPDATE 9-14-08 Jeff, This is an update to the well control issues we have had on 1J-10~~~~,~~j~ ~~~~' ~. ~ ~~~~ 9/13/08 • 19:00: Shut in well and monitor while building 300 bbl of 4 Ib/per bbl flo-vis Hi-Vis pill . 21:30: Well on vac. Line up and pump 35 bbls 41b/per bbl flo-vis Hi-Vis pill down DP. Pump OOH from 4,050' up wt 85K, 12 stands to dart valve at 2,900'. Shut in and monitor well for 15 min, SICP built to 10 psi. 9114/08 • 00:00: Cont building Hi-Vis volume and monitoring well at 2,900', adding 100 bph down DP. Pump OOH at 5 bpm for 10 studs, from 2,900' to 1,925', 75K up wt, total pit volume at 650 bbls Hi-Vis fluid, 200 bbls to the hole. Shut in well and monitor while building volume, well on vac. • 04:00: Cont pumping OOH at 200 bph from 1,925' to 1,000', line up charge pump on kill line and POOH on elevators, LD MWD and Baker running tools. • 06:00 RU and test annular and rams as per AOGCC rag's at 250 and 2,500 psi on chart, RU floor to run 4 1/2" tubing. Witness of test waived by AOGCC Rep John Crisp on 9-14-08 at 5:45 am. • 07:00: Pumped 300 bbls and monitored well. MU seal assembly, RIH one stand, MU GLM with SOV and RIH to 4000' MD, up wt 74K, down wt 69K. • 09:30: MU TD and pump 344 bbls HI-Vis S/W @ 6bpm chased with 70 bbls of clear S/VV with 6% KCL, pumped 150 bbls down backside. • 11:00: RIH from 4000' to 4130', drop standing valve down tbg to nipple at 4183', R/U and chased valve with 37 bbls to seat, pressured up to and held 1000 psi, for 15 min, bled down to 0, and filled IA. 10/23/2008 Page 2 of 4 • ~ The 4-1/2" tubing was POOH, we are isolated from the formation with a full column of fluid in the casing above the standing valve. We are currently in the process of running the completion and do not anticipate any further we{I control issues. If you need anymore information or have any questions please contact myself or Rance. Regards, Peter Nezaticky (943-1253) / Rance Pederson (398-4847) ConocoPhillips, Workover Supervisors Nordic3 659-7446 From: Nordic 3 Company Man Sent: Saturday, September 13, 2008 7:02 PM To: 'jeff.jones@alaska.gov' Cc: Nordic 3 Company Man Subject: FW: Nordic 3 West Sak 1J-101 Kick and BOP Shut In: UPDATE 9-13-08 Jeff, Here is an update to the kicks that were taken on 1J-101: 9112108 • 19:00: Monitor well while building 300 bbl Hi-Vis pill, SICP at 470 psi., dart valve in string. • 20:30: Break circ and pump 100 bbls Hi-Vis pill down DP with choke open to kill tank, line up on kill line and pump 200 bbls Hi-Vis pill down FA with charge pump. • 21:30: Shut in and monitor well while building another 150 bbl Hi-Vis pill, SICP at 10 psi, dart valve in string. 2,911 bbls lost t/formation, 5,396 bbls lost t/well total. 9/13/08 • 02:00: Pump 30 bbls Hi-Vis pill down DP and 120 bbls down IA. • 02:30; Shut in well and monitor while building 300 bbl Hi-Vis pill for trip OOH, SICP at 0 psi, dart valve in string. . 04:30: Added 50 bbls Hi-Vis pill to IA with charge pump, POOH stand back DP, using 3 X pipe displacement on hole fills, 11 stands OOH (2,900') removed dart valve and had flow out of DP, made up top drive, shut in well and built to 240 psi SIDPP, SICP at 10 psi. • 06:00: Pumped 30 bbls Hi-Vis pill down drill pipe, 100 bbls Hi-Vis pill down IA, shut in and monitored pressure. SIDPP 30 psi, SICP 30 psi, lined up IA to kill tank and pumped 200 bbls down DP at 6 bpm. . 06:45: Shut in and monitor well, while building another 150 bbl pill. Performed a fluid shot on IA with echometer and determined top of fluid column is at 1,170'. • 08:30: SIDPP at 10 psi, SICP at 70 psi, pump 100 bbls HI-Vis pill down DP with open choke IA to kill tank, then lined up in kill line and pumped 200 bbls down DP @ 6 bpm. . 09:00: Install dart valve and RIH to just above of ZXP packer at 4,050' . 09:30: Shut in well and monitor while building 300 bbl of 4 Ib/per bbl flo-vis Hi-Vis pill & 40 bbl of 6 Ib/per bbl flavis hi-vis pill. Waiting on fluids and Flo-Vis product from Prudhoe. Mix and shear in pits. • 14:30: SICP = 270 psi, pump 40 bbls HI-Vis (6 Ib/bbl) pill chased with 60 bbls HI-Vis (4 Ib/bbl) down DP with open choke, IA to kill tank. Then lined up IA on kill line and pumped 200 bbls Hi-Vis (4 Lb/bbl) down backside @ 6 bpm. • 15:30: Shut in well and monitor while building 300 bbl of 4 Ib/per bbl flo-vis Hi-Vis pill • 19:00 SICP = 10 psi. The plan forward is to pump another 40 bbl HI-Vis pill, followed by an additional 250 bbl of Hi-Vis fluid. Monitor well. If the well is dead, POOH filling well with 100 bbl/hour plus 3 x displacement. Pressure test the annular BOP and the variable pipe rams for 4-1/2" pipe. RIH with 4-1/2" tubing and sting into the SBE at 4149'. Pump a 10/23/2008 Page 3 of 4 • • standing valve into the 3.75" nipple at 4183'. Pressure test the tubing to 1000 psi to confirm seat. Load the lA with fluid, POOH with the 4-1/2" tubing. Run the 4-1/2" completion with down hole gauge with tech wire and heat trace from 3000' up to surface. if you have any questions please contact us at: office 659-7446 or Nori3 doghouse 659-1760. Regards, Peter Nezaticky (943-1253) / Rance Pederson (398-4$47) ConocoPhillips, Workover Supervisors From: Nordic 3 Company Man Sent: Friday, September 12, 2008 7:57 PM To: jeff.jones@alaska.gov Subject: FW: Nordic 3 West Sak i)-101 Kick and BOP Shut In Jeff, Here is a summary of the kick and BOP shut in while recompleting 1J-101 West Sak producer: • 1J-101 West Sak tri-lateral producer, initially completed as an ESP producer. • Pulled the ESP completion, ran a wash string. • Set a lateral entry module (LEM) across the upper "D" sand lateral. • Set a packer at 4118', above the LEM, and pulled out of the packer. • 09:00 am: Took a kick at 2811'. Shut in the annular BOP and screw in the top drive. SIDPP = 350 psi, SICP = 50 psi. • 09: 25 am: SIDPP = 450 psi, SICP = 200 psi. Start pumping SW w/6% KCI (8.8 ppg) down the DP with the IA open to the kill tank. Pump strokes = 120 bbl, well on a vacuum fluid was being siphoned, actual volume 320 bbl, 2 x surface to surface volumes. • 10: 20 am: SIDPP = 0, SICP = 0. Monitor well @ 10:45 am SIDPP = 0, SICP = 140 psi. Loading fluids to the pits. • 11:30 am: 51DPP = 150 psi, SICP = 430 psi. Start pumping down the DP with the IA open to the kill tank. Pump strokes = 120 bbl, well on a vacuum fluid was being siphoned, actual volume 320 bbl, 2 x surface to surface volumes. . 12:15 pm: SIDPP = 0 psi, SICP = 0. Monitor well for 30 min. • 12:45 pm: SIDPP = 0 psi, SIGP = 0 psi. Open annular BOP. Pump 100 bbl down the IA and preparing to continue POOH. • 13:20 : Prior to pulling first stand took a kick. Screw top drive back into the DP and close pipe rams. SIDPP = 100 psi, SICP = 150 psi. • 13:30: Discussed plan forward. Loading fluids to the pits. Mixing Flo-Vis+ pill in pits. • 16:OO:SIDPP = 550 psi, SICP = 560 psi. Start pumping Flo-Vis+ down the DP with the IA choked to the kill tank. Pumped 100 bbl of Flo-Vis+ and displaced DP with 22 bbl of SW w/6% KCL. Final DP press 10 psi, choked iA press 340 psi. • 18:00: Leave IA choked open to kill tank and allow pill to settle, DP press = 0 psi, 1A press = 0 psi. Pump 200 bbls down backside. . 18:30: Install dart valve and RIH to the top of ZXP packer at 4050' while filling IA with charge pump. The plan is to continue to pump viscous pill until the welt stabilizes allowing us to POOH and RIH with the 4-1/2" 10/23/2008 Page 4 of 4 w • gas lift completion. The AOGCC will be notified if any further kicks are taken. If you have any question please call, it may be best to reach us on our cell phones. Regards, Peter Nezaticky (943-1253) / Rance Pederson (398-4847) ConocoPhillips, Workover Supervisors 10/23/2008 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Pertorations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^~ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, Inc. Development 0 Exploratory ^ 205-182 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23286-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1 J-101 ' 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25650 ~ Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11510' - feet true vertical 3817' , feet Plugs (measured) Effective Depth measured 11328' feet Junk (measured) true vertical 3805' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 2171' 10-3/4" 2199' 2186' INTERMEDIATE 5361' 7-5/8" 5389' 3681'~`:~ 1 ~~`~uu#`~~;k'.? h `~' ` "` ~ Z~Q~ , LINER 6729' 4.5" 11330' 3805' Perforation depth: Measured depth: 5366'-5428', 6381'-7247', 7526'-7900', 8303'-8798', 8920'-8950', 9137'-9565', 9686'-10029', 10306'-10773', 11114'-11297' true vertlC81 depth: 3674'-3685', 3700'-3702', 3728'-3728', 3719'-3728', 3734'-3734', 3724'-3732', 3732'-3756', 3787'-3805', 3802'-3814' Tubing (size, grade, and measured depth) 4.5", L-80, 4146.7' MD. Packers 8~ SSSV (type & measured depth) HRD ZXP liner top packer @ 4601' (A-sand), 4291' (B-sand), 4141' (D-sand) 3.875"'DB' nipple, 3.813"'DB' nipple, 3.75"'DB' nipple @ 503', 4091', 4183' 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 858 2031 25 -- 196 Subsequent to operation 2312 2748 13 - 228 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 Brett Packer @ 265-6845 Printed Name Brett Packer Title Welis Engineer l v ~ f~ ~ Signature ~F~ '~~.~ Phone: 265-6845 Date / _ Pre ared b Sharon Allsu Drak 263-4612 1r 3 .~ /0.2.0. k r ~ fj t„~. ,; 10~~ Form 10-404 Revised 04/2006 ~~~, ~'~1 1,.~ ~ Submit Original Only ~ (~~a~ K_UP 4, t CanC,~C©prli~~l~?S ~ weu AttributOB , r.:{ ,,. WNIborc APIIUWI Freld Name .. 500292328670 ~ WEST SAK _ - ,~ , Tubng Hanger, ~' CONDUCTOR, 6108 NIPPLE, 503 SURFACE,1 82,19911 GAS LIFT, - 2sas,°:--- --- GAS LIFT, NIPPLE, 4,091 ~IIIIII z7s,3e9 Slotc, 5,366-5,428 Sbts, s,3st-7, z47 sores, 7.s267,9gg Sbec, 8,3638,798 sores, 8,9268,950 Sties, 9,137-9,555 Sties, 9,68610,029 sores. 10,30610,773 slurs. 1-I, eia11, 297 LINER A-SAND, 4,fi07-11,330 TD (1J-101), ns1D LINER B-SAND, 4,50311, 619 LINER -D-SAND TOP, 4,13611,651 LINER D-SAND BTM, 4,202-11,fi80 1 I H I JL i1 ~ -" wen 6tatus IrlcbnaUOn (-) (PROD 95.75 1 J-101 MD (nne) iotat Depth tnhel 6,387.76 ~ 11,711.0 Comment H2S (ppm) Date Annotatlon End Date KB-0M (h) Rig Release Date SSSV: NIPPLE 30 711/2008 -Last WO: 9/16/2008 33.02 1I7Y2006 Annotation DepM (flKB) Entl Date Annotation Entl Date Last Tag: Rev Reason: WORKOVER 9/19/2008 Casing Strings '. ~ Casing Deacripdon jSMn... String I... Top (RKB) SN Depth (R.. SN Depth (TVD) (R.. String ... Strip... jStnng Top ThM I (SURFACE 10314 9.950 -9.0 2,199.1 2,186.4 45.50 L-SO j ]Casing Description SMn... String I... Top (hKB) SN Depth (tt.. SN Depth (TVD) (R.. String ... Strip... String Top ThN ;CONDUCTOR 20 0.0 108.0 108.0 I (Casing Description Strip... String 1... Top (RKB) Set Depth (R.. SN Depth (TVD) (R.. String ... Strip... String Top ThM I ] INTERMEDIATE 75/8 6.875 27.4 5,389.0 3,678.6 29.70 L-80 Buttress Thread Casing Description Strip... String I... Top (flKB) SN Depth (R.. SN DepM (TVD) (R.. String ... Strip... String Top Thrd i (LEM 0.SAND 41/2 3.958 4,130.3 ' . 4,320.0 3,479.5 12.60 L-80 IBTM Casing Description Strip... String 1... Top (RKB) ] Set Depth (R.. SN DepM (ND) (R.. String ... SMn... String Top Thrd WINDOW 0.SAND 9 4,205.0 I 4,206.0 3,452.5 i Casing DesMphon Strip... String I... Top (RKB) ] Set Depth (tt.. SN Depth (TVD) (tt.. String ... Shin... String Top ThM LEM B-SAND 41/2 4,291.4 ' 4,642.2 3,560.5 12.60 ~ L-80 IBT Casing Description Strip... String I... , Top (RKB) SN Depth (tt.. SN Depth (TVD) (R.. String ... ~ Strin... String Top ThM WINDOW B-SAND 9 4,507.0 4,508.0 3,526.0 Casing Description Strip... String I... Top (flKB) SN Depth (R.. Set Depth (ND) (R.. String ... i Strin... String Top Thrd LINER A LAND 4 112 3.958 14,601.1 11,330.0 ~ anR a +2.60 L-R(1 IBT Liner Details - __ _ Top (flKB) Kem ~cxr,yDOn Gonwa:nt ICJ (~nl 4,601.1 PACKER "HRD" ZXP Liner Top PACKER 4.790 4,6202 NIPPLE "RS" Packoff Seal Nipple 4.575 4,623.0 HANGER Flex Lock Liner Hanger I 4.853 4,632.5 CSR iCasing Seal Bore '; 4.750 4,651.9 XO BUSHING ;Cross Over Bushing ~ ; 3.930 Tubing Strings i b ray C~~s' Rion Slri I C~ Slrin~ IU T,~N (K 1 [~. yLli flk. Scl r)eplh IT:C,1 kHH ~ 1 VJt S Shiny toy in,n ~TUFIr.I~ -0 ,. _ _ 4 14n. I 1 _. L -1l If'~IId Completion Details ._.,._..., 24.9 ._....,___..,,..,... Hanger Joint ,..,,,,..._... jt. of 4.5" 12.6#, L-80, IBTM Tubing (30.30') Bore 3.900" ID ' ...,...r~ 3.958 I 502.8 NIPPLE 3.875"'DB' Nipple 3.875] 4,091.4 NIPPLE 3.813"'DB' XN Nipple 3.812' 4,093.0 GAUGE Baker Guardian Gauge 3.958' 4,141.9 LOCATOR Locator Sub 3.990 4,143.O Perfora Top (RKB) iSEAL ASSY tions lop Btm ITVOI ~ (RKB) (RKB) Bonded Seal Assembly wl Full Mule Shoe w13.75'space out 3.870 btm I Shot (ND) ~ Dens (RKB) j Type Zone (sho.-. Date Comment 5,366.0 5,428.0 3,674.4 ~ 3,684.7 ~ Slots WS A2, 1J-101 32.0 12/2112005 ALL SLOTS: Alternating slotted/solid 1 pipe 0.125"x2.5"x32 spT@ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 6,381.0 7,247.0 3,699.7 3,701) Slots WS A2, 1J-101 32.0 1 1 2121/2 0 0 5 7,526.0 7,900.0 3,727.8 3,728.4 Slots WS A2, 1J-101 32A 12/21@005 8,303.0 8,798.01 3,718.7 3,728.0 Slots WS A2, 1J-101 32A, 1 2121/2 0 0 5 8,920.0 8,950.0: 3,733.9 3,733.9 SIots WS A2, 7J-101 ~ 32.0 12121/2005 9,137.0 9,565.0 3,724.1 3,731.7 Slots WS A2, iJ-101 32.0 12/21/2005 9,686.0 10,029.0 3,731.8 3,755.9 Slots WS A2, 1J-101 32.0 12121/2005 ~ 110,306.0 10,773.0 3,787.2 3,8047 Slots WS A2, 1J-101 32.0 12121/2005 ~ i 11,114.011,297.0 3,801.6 3,813.9 Sbts IWSA2, 1J-101 32.012YL1I2005~ - _ .Notes: General & Safety. LnU care notation (1/8/2006 ~ NOTE: °' NO ESP PUMP INWELL- USING GLVS'"' ~; 1/8YL006 NOTE: MULTI-LATERAL WELL: 1J-101 (A2-SAND), iJ-tOtL1 (B-SAND), 1J-101 L2 (0.SAND) 19/16/2008 NOTE: VIEW SCHEMATIC wlAlaska Schematic9.0 '9/19/2008 ~- NOTE: "` ID 3.75" DB NIPPLE @ 4183' IN D-SAND LEM"" - I I I Mandrel Details -_ Set Depth Pert Top (TVD) Valve Latch Size TRO Run Stn (RKB) (RKB) Make Model OD (in) Type Type IiN (psi) Run Date Comment j 1 2,546.31 3,438.9 CAMCO KBG-2-1R 1 DMY BEK 0 0.0 9/1512008 2 3,767.8 3,438.9 CAMCO KBG-2-1R 1 DMY BK-5 I 0 0.0'9/15/2008 i 1 J-101 Pre-Rig and Post-Rig Well Work BATE SUMMARY 7/23/08 PRE-RWO, T-POT (PASSED~PPPOT (PASSED), IC-POT (PASSED), PPPOT (PASSED), FUNCTION TEST LDS'S 9/3/08 ENCOUNTERED HYDRATES @ 3' SLM. DISPLACED TBG WITH 45 BBLS HOT DIESEL. GAUGED TBG TO 3.79" TO 3273' SLM. SET SLIP STOP CATCHER @ 2911' RKB. PULLED OV @ 2832' RKB (CHECK VLV WASHED OUT). PULLED GLV @ 2349' RKB. REPLACED WITH DMY. JOB IN PROGRESS. 9/4/08 SET DMY VLV @ 2832' RKB. PULLED CATCHER SUB @ 2911' SLM. MEASURED APPOX 18 HOUR SHUT IN BHP @ 3275' RKB (705 PSI) NO PUMP AVAILABLE, LRS WILL RETURN TO PUMP DOWN IA. JOB COMPLETE. 9/5/08 PUMPED 60 BBLS OF DIESEL DOWN IA, 50 BBLS DOWN TBG WITH NO PROBLEMS. PUMP REPORT IN WORKING FILE. 9/17/08 Stage CCT unit at well, standby for Slickline and weather, (Wind 30+ mph). Begin rigging up for BOP test. 9/17/08 PULLED CAT STANDING VALVE FROM 4183' RKB. READY FOR CTU. 9/18/08 Continue w/ CCT FCO down to 5700' ctmd where coil stacked out weight, (medium- heavy sand in returns) uncovered a zone at this depth and started loosing well bore_ fluid along w/ having heavy pull weights. PUH into tubing and unload sand. (Job in progress). 9/19/08 ~9ntn~e w/ CCT~~O down to 7130' ctmd (little to no sand in returns. seeing what we beleave is Duovis) (Job in progress). 9/20/08 Continue w/ CCT FCO down to 8100' ctmd (little to no sand in returns Jetting what, appears to be thick gel off bottom. (Job in progress). 9121/08 F_CO COMPLETE TOTAL DEPTH ACHIEVED WAS 8150' CTMD, 5 BBLS SAND RECOVERED, (( COMPLETE)) 9/22/08 CLEARED ICE FROM HANGER. PULLED SHEARED SOV FROM 2546' RKB, REPLACED WITH DV. MIT IA 2500 PSI, GOOD. IN PROGRESS. 9/23/08 INSTALL OV AT 3786' RKB AND GLV AT 2531' RKB. DRAW DOWN IA 300# TO CONFIRM GOOD SET. JOB COMPLETE. ConocoPhi~lips Time Log & Summary E..;~~~ ~~~ R~p°~r,~g Report Well Name: 1J-101 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 9/9/2008 9:30:00 PM Rig Release: 9/16/2008 8:00:00 AM -- -- Time Logs Date From To Dur S. Depth E Depth Phase Code Subcode T Comment -- - - - -- - - - --- 9/09/2008 za hrsummarv Freeze protected well 1J-168, RDMO and moved over 1J-101, RU hardline and kill tank. 20:30 21:30 1.00 MIRU MOVE MOB P Back rig off 1J-168 and move to 1J-101, spot and level rig over well, set up handy berm. Nordic Ri 3 21:30 hrs. 21:30 23:00 1.50 MIRU RPCOM RURD P RU hard line & kill tank, spot tanks and mud shack, pulled BPV w/lubricator, 750 psi on tbg, 700 psi on IA, 450 si on OA. 23:00 00:00 1.00 MIRU RPCOM RURD P Load empty ESP spool on rig floor with crane, start loadin 3 1/2" DP. 9/10/2008 Pumped 150 bbls of hot SW w/6% KCL, Set BPV, ND tree , NU & test BOPE, started POOH with 4 1/2" ESP com letion. 00:00 01:00 1.00 COMPZ RPCOM RURD P Load pits with hot seawater, press tested hardline with air and water at 120 and 500 psi, cont loading 3 1/2" DP. 01:00 05:00 4.00 COMPZ RPCOM CIRC P Notified security and DSO, bled gas off tbg and IA. Pumped 100 bbls hot seawater down IA and 50 bbls down tbg at 6 bpm - 120 psi, well pressure increased to 80 psi on IA, pumped another 100 bbls down IA at 6 bpm - 120 psi and well pressure came up to 20 psi, pumped another 90 bbls down IA at 6 bpm - 120 psi and confirmed well is dead. Never had returns, blew down circ lines, installed BPV. 05:00 08:30 3.50 COMPZ RPCOM NUND P ND tree / NU BOPE. 08:30 13:00 4.50 COMPZ RPCOM SFEO P Test BOPE 250/2500 psi. Tested variables with 4-1/2" and 3-1/2" test joint. 24 hr notice given to the AOGCC 9-8-08 @ 18:30. John Crisp requested update for the following day. Update given 9-9-08 @ 18:00. John Cris waived test. page 1 of ~ l J Time Logs Date From To Dur S Depth E De th Phase Code_ __` Subcode T_ Comment 13:00 16:00 3.00 COMPZ RPCOM OTHR P IA pressure = 315 psi. Pul4 test dart. Open IA to kill tank, pump 60 bbl of SW w/6%KCL down the tubing throught the BVP at 2 bpm. IA pressure = 0 psi. Pull BPV, install landing joint, BOLD's. Un-land hanger with 215K#. Pull hanger to the floor with 82K#. 16:00 20:00 4.00 COMPZ RPCOM CIRC P Pumped hot SW w/ 6% KCL , 200 bbl down the IA, 90 bbl down the tubin to clean u strin . 20:00 00:00 4.00 3,350 994 COMPZ RPCOM TRIP P LD hanger and landing jnt, string esp cable through sheave, start POOH standing back 4 1/2" tubing from 3,350' MD to 994' MD. 9/11 /2008 PU RIH with 3 1/2" DP and clean out assembly, POOH to run LEM and ZXP 00:00 03:30 3.50 994 0 COMPZ RPCOM TRIP P Cont POOH with 4 1/2" esp completion from 994', break down motor assembly and box up, off load shed. 03:30 05:00 1.50 0 0 COMPZ RPCOM OTHR P Load cleanout tools and attempt to install wear ring. Backed out alignment pin and set wear ring, stra ed 3 1/2" IBTM tubin . 05:00 07:30 2.50 0 402 COMPZ RPCOM RURD P PU and MU cleanout BHA. 07:30 11:30 4.00 402 4,180 COMPZ RPCOM TRIP P PJSM. RIH with clean out BHA (bullnose and side jet nozzle) on 3-1/2" DP 11:30 13:30 2.00 4,180 4,290 COMPZ RPCOM FCO P RIH to with wash BHA to 4180'. Up wt = 90K, down wt = 80K. Pump down DP 3 bpm @ 120 psi. RIH washing down @ 3 bpm. Sit down at X30'. Reciprocate 40' across the hook hanger and into the SBR several times jetting at 3 bpm 180 psi. PUH to 4290' and bullhead 50 bbl down the IA at 5.5 b m 50 si. 13:30 18:30 5.00 4,290 0 COMPZ RPCOM TRIP P POOH and stand back 3-1/2" DP. La down wash BHA, clean ri floor. 18:30 21:30 3.00 0 0 COMPZ RPCOM PULD P Load LEM equipment, PU and MU LEM equipment, CO floor equipment to run DP. 21:30 23:00 1.50 0 299 COMPZ RPCOM TRIP P RIH 1 stand and attempt to shallow test MWD. 23:00 00:00 1.00 299 0 COMPZ RPCOM TRIP T Tool failed, POOH to CO MWD. 9/12/2008 PU RIH with LEM-ZXP assembly and set same, POOH with running tools, RU to run completion, PU and RIH with 4 1/2" as lift com letion. 00:00 01:30 1.50 0 299 COMPZ RPCOM TRIP T CO MWD on inner string, MU assembly and RIH 1 stand, shallow test tool. 01:30 04:30 3.00 299 4,175 COMPZ RPCOM TRIP P Cont RIH at 150E from 298' to 4,175', u wt 95K down wt 85K. gym. ~ ~ W ~a~e 2 €st ~ i Time Logs Date From To Dur S. ae th E. De th Phase Code Subcod_e T__Co_m_ment _ ~I 04:30 05:30 1.00 4,175 4,320 COMPZ RPCOM DHEQ P Break circ at 150 gpm, tool face at 73R (D lateral hook hanger at 20R), ease seals down through hook hanger, sit down 10K, orientation at 61 R, sit down to 12K and collet latched, tool oriented to 18L, pulled 20K and collet unlatched after few seconds hesitation. Break connection and dropped ball, pumped 30 bbls and saw pressure increase, pressured up to 2500 psi to activate pusher tool. Pressured up to 3500 psi, to neutralize the pusher tool. Bled off and PU 1' u wt 95K. 05:30 07:00 1.50 4,320 4,320 COMPZ RPCOM DHEQ P Fill IA with fluid close annular and ressure test IA to 2,500 si. 07:00 09:00 2.00 4,320 2,811 COMPZ RPCOM TRIP P Pull out of ZXP packer with 105K#. Pull out of seals, POOH standing back 3-1/2 DP and ZXP setting tool 98K#. Filling IA with 100 bbl per hour lus 3 x dis lacement. E~.~ . ..~.._._ ~~~ ~ ~f • • _ Time Lomas _ _ _ _ _ ___ ___ Date _ From To Dur S De th E. Depth Phase Code Subcod_e T Comment 09:00 13:30 4.50 2,811 2,811 COMPZ WELCTL CIRC T 09:00 am: Took a kick at 2,811'. Shut in the annular BOP and screw in the top drive. SIDPP = 350 psi, SICP = 50 psi. 09:25 am: SIDPP = 450 psi, SICP = 200 psi. Start pumping SW w/6% KCI (8.8 ppg) down the DP with the IA open to the kill tank. Pump strokes = 120 bbl, well on a vaccum fluid was being siphoned, actual volume 320 bbl, 2 x surface to surface volumes. 10:20 am: SIDPP = 0, SICP = 0. Monitor well @ 10:45 am SIDPP = 0, SICP = 140 psi. Loading fluids to the pits. 11:30 am: SIDPP = 150 psi, SICP = 430 psi. Start pumping down the DP with the IA open to the kill tank. Pump strokes = 120 bbl, well on a vacuum fluid was being siphoned, actual volume 320 bbl, 2 x surface to surface volumes. 12:15 pm: SIDPP = 0 psi, SICP = 0. Monitor well for 30 min. 12:45 pm: SIDPP = 0 psi, SICP = 0 psi. Open annular BOP. Pump 100 bbl down the IA and preparing to continue POOH. 13:20pm: Prior to pulling first stand_ took a kick. Screw top drive back into the DP and close pipe rams. SIDPP = 100 si, SICP = 150 si. 13:30 16:00 2.50 2,811 2,811 COMPZ WELCTL COND T Dicussed plan forward. Loading fluids to the pits. Mixing Flo-Vis+ pill in its. 16:00 18:30 2.50 2,811 2,811 COMPZ WELCTI CIRC T SIDPP = 550 psi, SICP = 560 psi. Start pumping Flo-Vis+ down the DP with the IA choked to the kill tank. Pumped 100 bbl of Flo-Vis+ and displaced DP with 22 bbl of SW w/6% KCL. Final DP press 10 psi, choked IA press 340 psi. Leave IA choked open to kill tank and allow pill to settle, DP press= 0, IA press = 0. Pump 200 bbls down backside. 18:30 19:00 0.50 2,811 4,050 COMPZ WELCTL TRIP T Install dart valve and RIH to lust above of ZXP oacker at 4.05Q while fillip IA with char a um . ~ ~~ _ [~~~~ ~ ref ~ r~ Time Lo~___ _ __ ___ Date From To Dur 5 De th E De th Phase_ Code _Subcode T Comment 19:00 20:30 1.50 4,050 4,050 COMPZ WELCTL OWFF T Monitor well while building 300 bbl Hi-Vis pill, SICP at 470 psi., dart valve in strin . 20:30 21:30 1.00 4,050 4,050 COMPZ WELCTL CIRC T Break circ and pump 100 bbls Hi-Vis pill down DP with choke open to kill tank, line up on kill line and pump 200 bbls Hi-Vis pill down IA with char a um . 21:30 00:00 2.50 4,050 4,050 COMPZ WELCTL OWFF T Shut in and monitor well while building another 150 bbl Hi-Vis pill, SICP at 10 psi, dart valve in string. 2, bbls lost t/formation today, 5,396 bbls lost t/well total. 9/13/2008 RIH to 4050' and killed well, built volume and monitored well, pumped OOH to 2,900', shut in and monitored well, killed well, cont buildin hi-vis volume while monitorin well. 00:00 00:30 0.50 4,050 4,050 COMPZ WELCTL CIRC T Pump 30 bbls Hi-Vis pill down DP and 120 bbls down IA. 00:30 02:00 1.50 4,050 4,050 COMPZ WELCTL OWFF T Shut in well and monitor while building 150 bbl Hi-Vis pill, SICP at 10 si, dart valve in strin . 02:00 02:30 0.50 4,050 4,050 COMPZ WELCTL CIRC T Pump 30 bbls Hi-Vis pill down DP and 120 bbls down IA. 02:30 04:30 2.00 4,050 4,050 COMPZ WELCTL OWFF T Shut in well and monitor while building 300 bbl Hi-Vis pill for trip OOH, SICP at 0 psi, dart valve in strin . 04:30 06:00 1.50 4,050 2,900 COMPZ WELCTL TRIP T Added 50 bbls Hi-Vis pill to IA with charge pump, POOH stand back DP, using 3 X pipe displacement on hole fills, 11 stands OOH (2,900') removed dart valve and had flow out of DP, made up top drive, shut in well and built to 240 psi SIDPP, SICP at 10 si. 06:00 08:30 2.50 2,900 2,900 COMPZ WELCTL CIRC T Pumped 30 bbls Hi-Vis pill down drill pipe, 100 bbls Hi-Vis pill down IA, shut in and monitored pressure. SIDPP 30 psi, SICP 30 psi, lined up IA to kill tank and pumped 200 bbls down DP at 6 bpm. 6:45 AM -Shut in and monitor well, while building another 150 bbl pill. Perfomed a fluid shot on IA with echometer and determined top of fluid column is at 1,170'. 08:30 09:00 0.50 2,900 2,900 COMPZ WELCTL CIRC T SIDPP at 10 psi, SICP at 70 psi, pump 100 bbls HI-Vis pill down DP with open choke IA to kill tank, then lined up in kill line and pumped 200 bbls down DP 6 b m. 09:00 09:30 0.50 2,900 4,050 COMPZ WELCTL TRIP T dart valve and RIH to 'ust above of ZXP acker at 4,050' C_`_ f~~~c~ ~ ref 3 • s Time Logs _ - _. -- -- Date From To Dur S De th E. De th Phase Code Subcode T Comment 09:30 14:30 5.00 4,050 4,050 COMPZ WELCTL OWFF __ T _ _ _ Shut in well and monitor while building 300 bbl of 4 Ib/per bbl flo-vis Hi-Vis pill & 40 bbl of 6 Ib/per bbl flo-vis hi-vis pill. Waiting on fluids and Flo-Vis product from Prudhoe. Mix and shear in its. 14:30 15:30 1.00 4,050 450 COMPZ WELCTL CIRC T SICP @ 270 pis, pump 40 bbls HI-Vis (6 Ib/bbl) pill chased with 60 bbls HI-Vis (4 Ib/bbl) down DP with open choke, IA to kill tank. Then lined up IA on kill line and pumped 200 bbls Hi-Vis (4 Lb/bbl) down backside 6 b m. 15:30 18:30 3.00 4,050 4,050 COMPZ WELCTL OWFF T Shut in well and monitor while building 300 bbl of 4 Ib/per bbl flo-vis Hi-Vis ill 18:30 19:30 1.00 4,050 4,050 COMPZ WELCTL CIRC T SICP @ 40 pis, pump 40 bbls HI-Vis (6 Ib/bbl) pill chased with 60 bbls HI-Vis (4 Ib/bbl) down DP with open choke, IA to kill tank. Then lined up IA on kill line and pumped 200 bbls Hi-Vis (4 Lb/bbl) down backside @ 6 b m. 19:30 21:30 2.00 4,050 4,050 COMPZ WELCTL OWFF T Shut in well and monitor while building 600 bb4 of 4 Ib/per bbl flo-vis Hi-Vis ill. 21:30 22:30 1.00 4,050 2,900 COMPZ WELCTL TRIP T Well on vac. Line up and pump 35 bbls 4 Ib/per bbl flo-vis Hi-Vis pill down DP. Pump OOH from 4,050' up wt 85K, 12 stands to dart valve at 2,900'. Shut in and monitor well for 15 min, SICP built to 10 si. 22:30 00:00 1.50 2,900 COMPZ WELCTL CIRC T Kelly up and pump 100 bbls down DP, line up and pump 200 bbls flo-vis Hi-Vis pill down IA. Cont building ' Vis.aroLumee 2,066 bbls lost t/formation'today, 7,462 bbls lost t/well total. 9/14/2008 Cont adding 100 bph to hole while building Hi-Vis volume, pumped OOH to 2900', built volume while monitoring, pumped OOH to 2025', built volume while monitoring, pumped OOH to surface, LD BHA, RU and tested BOP's, RIH with seal assembl , 00:00 02:30 2.50 2,900 2,900 COMPZ RPCOM OWFF T Cont building Hi-Vis volume and monitoring well at 2,900', adding 100 b h down DP. 02:30 03:30 1.00 2,900 1,925 COMPZ RPCOM TRIP P Pump OOH at 5 bpm for 10 studs, from 2,900' to 1,925', 75K up wt, total pit volume at 650 bbls Hi-Vis fluid, 200 bbls to the hole. 03:30 04:00 0.50 1,925 1,925 COMPZ RPCOM OWFF T Shut in well and monitor while buildin volume, well on vac. 04:00 06:00 2.00 1,925 0 COMPZ RPCOM TRIP P Cont pumping OOH at 200 bph from 1,925' to 1,000', line up charge pump on kill line and POOH on elevators, LD MWD and Baker runnin tools. ~ ~~ ~ e F~~e ~ czf ~ l l ~ Time Logs _ Date From To bur S Depth E. De th Phase Gode Subcode T_ Comment __ I 06:00 07:00 1.00 0 0 COMPZ WELCTL BOPE T RU and test annular and rams as per AOGCC reg's at 250 and 2,500 psi on chart, RU floor to run 4 1/2" tubing. Witness of test waived by AOGCC Rep John Crisp on 9-14-08 at 5:45 am. 07:00 08:00 1.00 0 COMPZ RPCOM CIRC T Pumped 300 bbls and monitored well. 08:00 09:30 1.50 0 4,092 COMPZ RPCOM TRIP T MU seal assembly, RIH one stand, MU GLM with SOV and RIH to 4000' MD, u wt 74K, down wt 69K. 09:30 11:00 1.50 4,092 4,092 COMPZ RPCOM CIRC T MU TD and pump 344 bbls HI-Vis S/W @ 6bpm chased with 70 bbls of clear S/W with 6% KCL, pumped 150 bbls down backside. 11:00 12:00 1.00 4,092 4,130 COMPZ RPCOM TRIP T RIH from 4000' to 4130', drop standing valve down tbg, R/U and chased valve with 37 bbls to seat, pressured up to and held 1000 psi. for 15 min, bled down to 0, and filled IA. 12:00 13:30 1.50 4,130 4,130 COMPZ RPCOM RURD P Split stds in derrick for rig. move and to clear way for heat trace and tec wire a ui ment. 13:30 16:00 2.50 4,130 0 COMPZ RPCOM TRIP P POOH, LD 4 jts 4 1i2" tbg, racked back 43 stnds of 4 1/2" tb . 16:00 00:00 8.00 0 1,880 COMPZ RPCOM RCST P CO lower seal rubbers and RIH with 4 1/2" tbg, guardian gauge and 3.812" DB nipple to 1,880' as per .r~n..rnn~g~ order. ~.1_ . J,,.,....._. 2 020 b5 s lost t/formation today,~`°~y 9,482 bbls lost t/well total. 9/15/2008 Located seal assembly, spotted corrosion inhibited sea water, spaced out, spliced and landed hanger, attem ted to test cs x tb to 1,500 si but SOV sheared at 1,350 si, installed TWC and ND BOP. 00:00 09:30 9.50 1,880 4,100 COMPZ RPCOM RCST P Cont RIH with 4 1/2" gas -ift completion string, heat trace and tec wire from 1,880' to 4,100'. 09:30 12:00 2.50 4,100 4,146 COMPZ RPCOM HOSO P Set down 12' on jt 133, pressure up to 500 psi for 5 min, pull up 20', pressure drop as SBA pulled out of SBE, space out 3.75', up wt 80K - dwn 75K, LD 3 singles and PU pup 'oints. 12:00 15:30 3.50 4,146 4,146 COMPZ RPCOM WOEO T Vetco-Grey honing out wellhead enetrator ort. 15:30 18:30 3.00 4,146 4,146 COMPZ RPCOM PULD P MU hanger and landing joint, install penetrator, splice heat trace and tec wire. 18:30 20:00 1.50 4,146 4,146 COMPZ RPCOM CIRC P RU and pump 50 bbls SW with corrosion inhibitor followed by 60 bbls SW down tbg to spot corrosion inhibitor from top GLM at 2,546' to 4,146'. 20:00 21:30 1.50 4,146 4,146 COMPZ RPCOM OTHR P Drain stack, landed hanger and RILD's. Tested upper and lower body seals to 5,000 si. ~~ ~ ~ Page 7 of ~ L Time Logs Date From _ _ To Dur S. De th E. De th _ Phase Code Subcode T ____ ___ Comment _ 21:30 22:00 0.50 4,146 4,146 COMPZ RPCOM DHEO P __ RU and attempt to test 7 5/8" csg to 1.500 osi for 30 min. Good test at 500 si but SOV sheared at 1,350 si, RD test a ui ment. 22:00 00:00 2.00 4,146 4,146 COMPZ RPCOM NUND P LD landing jnt and installed TWC, ND 13 5/8" BOP. 9/16/2008 Tested tree, pulled TWC and freeze protected well, RDMO, spotted rig over well 1 J-120. 00:00 00:30 0.50 4,146 4,146 COMPZ RPCOM NUND P Cont ND BOP. 00:30 03:00 2.50 4,146 4,146 COMPZ RPCOM NUND P Meg heat trace and tec wire, NU tree. 03:00 04:00 1.00 4,146 4,146 COMPZ RPCOM DHEO P Test tbg hanger void and tree at 250 and 5,000 si for 10 min each. 04:00 08:00 4.00 4,146 4,146 COMPZ RPCOM FRZP P Pull TWC and RU LRS circ lines, press test lines to 1,500 psi, pump 100 bbls diesel down tbg and through open GLM at 2,546' taking returns to kill tank, ICP 1,050 psi, BD & RD lines, set BPV, SITP= 0, IAP = 0, OAP = 450 psi, clean pits and Release Nordic Ri 3 08:00 hrs. --- m® _a ~ P~L~~' $ tat $ • • • ConocoPh i l l ~ ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 ~~'.... ~ g`a... Anchorage, AK 99501 r -~ ~~~~ Dear Mr. Maunder: 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 August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6th,2008. 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, Perry Klei ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/6/2008 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 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1 J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1 J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1 J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1 J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1 J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1 J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1 J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1J-184 206-044 8" NA 8" NA 1.28 9/6/2008 ~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • Well Job # ~~~~~ JUN ~.:~ 200 Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnke~n 333 West 7th Ave, Suites 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1 F-04 11964615 INJECTION PROFILE +(~ ,~ ( 05/26/08 1 1 3F-10 11964609 PRODUCTION PROFILE - ~~ f D 05/23/08 1 1 1J-101 11970685 GLS < < 05/23/08 1 1 iJ-166 11970681 GLS / -"" 05/20/08 1 1 2N-306 11964608 INJECTION PROFILE ill U (-~- 05/22/08 1 1 3K-13 11970688 INJECTION PROFILE - ~ 05/26/08 1 1 iB-08A 11970686 INJECTION PROFILE e- i ~ ~I / 05/24/08 1 1 1Y-11 11964613 INJECTION PROFILE ( - /(B~L} 05/25/08 1 1 3K-19 11964616 INJECTION PROFILE U-^ 05/27/08 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. ~~~ DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2051820 Well Name/No. KUPARUK RIV U WSAK 1J-101 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23286-00-00 MD 11510 TVD 3817 Completion Date 1/7/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey t~~"`-- DATA INFORMATION Types Electric or Other Log s Run: GR / RES, DENS / NEU (data t aken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments v D Asc Directional Survey 0 11510 Open lED D Asc Directional Survey 0 8877 Open PB 1 ,!~B'~ D I~j,i 5 13759 InductionlResistivity 2163 5349 Open 4/6/2006 GR EWR4 ROP ACAL PWD /j I~jpi 13759 LIS Verification 2163 5349 Open 4/6/2006 GR EWR4 ROP ACAL G~ ' PWD / ~LE?'D C Lis 14011 Gamma Ray 0 0 Open 8/8/2006 ROP, GR, RPM w/Graphics Log 14011 InductionlResistivity 25 Blu 5396 11510 Open 8/8/2006 MDL Recorded Mode Final ~ Frint **REDO** 15-Dec- 2005 ~ ~ E,.~6g 14011 InductionlResistivity 25 Blu 5396 11510 Open 8/8/2006 TVDL Recorded Mode Final Frint **REDO** 15- Dec-2005 i C Lis 14012 Induction!Resistivity 5264 8875 Open 8/8/2006 PB 1 MDL Recorded Mode Final Report 1:600 & 1:240 Lo See Notes 1 Blu 1 44 3244 Case 11/13/2006 Gas Lift Survey, SPIN, Temp, Pres, Gradio 6-Nov- 2006 D C Lis 15356 Induction!Resistivity 2150 5396 Open 8/23/2007 LIS Veri, GR, FET, ROP w/Log Graphics in PDF ~ ___ . ---- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2051820 Well Name/No. KUPARUK RIV U WSAK 1J-101 Operator CONOCOPHILLIPS ALASKA INC MD 11510 TVD 3817 Completion Date 1/7/2006 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~/ N Chips Received? ~Y~`t~^ Formation Tops ~ N Analysis .~L-LAI--- Received? Comments: - ---- - - - _ -- ,(~ - .~ Compliance Reviewed By. __. _ - Date _ _~~ed _~ _~ '~ API No. 50-029-23286-00-00 UIC N WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-101 +L1+L1 PB1+L2 AK-MW-4081383 August 3, 2007 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 99518 1J-101 +Ll+Ll PB1+L2: Digital Log Images: 50-029-23286-00, 60, 70, 61 eas.~~a ~ r5 3S~ ~ as - I ~3 ~ rS33 '~- aoS-~~a # ~s-~~ 1 CD Rom gas its<< ~' ~ 5`3 ~9 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. A, ' - 8 I" ; . Date: .~ r. Signed: ;~as~a tJii ~ {ate C~cros. ~o~rmisstioir ,4nci~o+~o90 11/10/06 Se~berger Schlumberger -DCS 2525 Gambetl Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # - a ,awn a.alp a ~ ~~ ... 9o i-' _ 9'04 .. ~s'R9s ~, ._-- (^~~ /~ Log Description N0.4034 Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1R26 11416225 INJECTION PROFILE 10/23/06 1 1 R-22A 11416224 PROD PROFILE W/DEFT 10/22/06 1 2K-28 N/A INJECTION PROFILE 10/19/06 1 36-09 11415642 PROD PROFILE W/DEFT 10/24/06 1 3G~16 11416226 INJECTION PROFILE 10/24/06 1 2P-427 11415637 INJECTION PROFILE 10/20106 1 2P-429 11415640 INJECTION PROFILE 10/22/06 1 1J=101 11445123 GLS 11106/06 1 2R-432 11415644 INJECTION PROFILE 10/26/06 1 3G-09 11415645 PROD PROFILE W/DEFT 10127/06 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFILE W/DEFT 11/05/06 1 11?-19A 11416228 INJECTION PROFILE 10/27/06 1 3J=05 1141630 INJECTION PROFILE 10/28/06 1 1D-04 11445121 PROD PROFILE W/DEFT 11/04/06 1 30-07 11416222 INJECTION PROFILE 10/20/06 1 2N~305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GLS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1 2L•-313 11445119 FLOWING BHP SURVEY 11/02!06 1 2K.27 11416234 FLOWING BHP SURVEY 11/02/06 1 2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • r 11-Aug-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Redistribution due to missing data on original Re: Distribution of Survey Data for Well 1J-101 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,532.84' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 11,510.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date o~ ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 11-Aug-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Redistribution due to missing data on original Re: Distribution of Survey Data for Well 1J-101 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 28.00' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 8,877.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 _ /J / I v Date t Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) a,~j -~~~ RECEIVED • h ~ ~. ~'~ L ( R AUG o ~ 2006 08/01/06 Oil & Gas Cons. Coml[>isilOCt NO. 3899 ~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Field: Well Job # Log Description Date BL Color CD 1J-101 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 1 D-125A (REDO) 11213778 INJECTION PROFILE 07/17/06 1 2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1 1G-05 11249932 INJECTION PROFILE 07/28/06 1 3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1 iD-117 11216305 INJECTION PROFILE 07/08/06 1 3F-18 11235384 SBHP SURVEY 07/25106 1 3F-17 11235383 BHP SURVEY 07/25/06 1 1Y-32 11213707 SBHP LOG 07/25/06 1 3G-25X 11216313 PROD PROFILE W/DEFT 07/31/06 1 1Y-24A 11216315 GLS/FBHP SURVEY 08/01/06 1 1 R-36 11249931 LDL 07/27/06 1 2V-10 11216311 SBHP SURVEY 07/28/06 1 1 D-107 11216309 INJECTION PROFILE 07/12/06 1 1D-130 11249928 INJECTION PROFILE 07/09/06 1 31-03 11213788 PROD PROFILE W/DEFT 07/26/06 1 1Y-05 11216310 LDL 07/27106 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • RECEivE~ ~ ~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth y~~~ AUG p 8 2006 NO. 3895 8 ~ ~ ~ ~' ~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 07/25/06 3K-32 11213780 SBHP SURVEY 07/19/06 1 2K-28 11235380 INJECTION PROFILE 07/22/06 1 2K-24 11213781 INJECTION PROFILE 07/20/06 1 2U-15 11213782 PROD PROFILE WIDEFT 07/21/06 1 1Q-18 11213873 PROD PROFILE W/DEFT 07/22/06 1 1G-13 11213784 PROD PROFILE W/DEFT 07/23/08 1 1J-101 PB1 40012836 MD & TVD VISION RESISTIVITY 12/17/05 2 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • WELL LOG TRANSMITTAL To: State of Alaska March 17, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-101, AK-MW-4081380 1 LDWG formatted Disc with verification listing. API# : 50-029-23286-00 ~37s-~ 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: ~ G Si ned: S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~>~ MAR I d 2006 WELL COMPLETION OR RECOMPLETION REPORA~a~1~0~~,~Q r,,,~,,,. 1a. Well Status: Oil 0 Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: AACIIOC Q Development Q ~ic~foratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~ or,4band.: January 7, 2006 12. Permit to-Drill Number: 205-182 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December 6, 2005 13. API Number: 50-029-23286-00 4a. Location of Well (Governmental Section): Surface: 2274' FSL, 2453' FEL, Sec. 35, T11 N, R10E, UM 7. Date TD Reached: December 20, 2005 ~ 14. Well Name and Number: 1 J-101 At Top Productive Horizon: 477' FNL, 1845' FEL, Sec. 35, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKg 15. Field/Pool(s): Kuparuk River Field Total Depth: 337' FSL, 1846' FEL, Sec. 23, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 11328' MD / 3805' ND West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558754 ' y- 5946086 ' Zone- 4 10. Total Depth (MD + ND): 11510' MD / 381 T ND ~ 16. Property Designation: , ADL 25661 & 25650 TPI: x- 559340 y- 5948619 Zone- 4 Total Depth: x- 559285 ' - 5954712 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 468 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2950' MD 21. Logs Run: GR/Res, Dens/Neu 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 20"x34" 62.58# H-40 28' 108' 28' 108' 42" 282 sx AS 1 10.75" 45.5# L-80 28' 2199' 28' 2186' 13.5" 480 sx ASLite, 148 sx DeepCrete 7-5/8" 29.7# L-80 28' 5389' 28' 3681' 9-7/8" 31 o sx LiteCrete 4.5" 12.6# L-80 4601' 11330' 3550' 3805' 6.75" slotted liner 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 3352' 4601' slotted liner from 5366'-11297' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n!a 26. PRODUCTION TEST Date First Production February 26, 2006 Method of Operation (Flowing, gas lift, etc.) shares production with 1 J-101 L1 and 1J-101 L2: gas lift oil Date of Test 2!28!2006 Hours Tested 6 hours Production for Test Period --> OIL-BBL 553 GAS-MCF 462 WATER-BBL 0 CHOKE SIZE 64% GAS-OIL RATIO 855 Flow Tubing press. 430 psi Casing Pressure not available Calculated 2a-Hour Rate -> OIL-BBL 2200 GAS-MCF 1881 WATER-BBL 1 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ..'j' _ 7 ' ~'O.~'__ t k NONE .~ - -- Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~ ~ ~, d ~ I G i ~ A L ~~~ ~ ~o~~ ~~ -~~ ..:~ 3.5- ~T~~` 2s. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-101 West Sak A Sand 4660' 3565' ' West Sak A2 Sand 5396' 3680' Base West Sak A sand 11310' 3872' N/A 1J-101 PB1 TD 8877 3728' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Name Rand Thomas Title: Greater Kuoaruk Area Drillino Team Leader 3 ~~ /~~ "~ ` Si nature Phone -> Date 9 ~ 6, ~ E "~ 5 C'~ INSTRUCTIONS Prepared by 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. 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 elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ConocoPhillips Alaska Page" 1 of 22 Operations Summary Report Legal Well Name: 1 J-101 Common W ell Name: 1 J-101 Spud Date: 12/6/2005 Event Nam e: ROT -D RILLING Start: 12/6/2005 End: 1/7/2006 Contractor Name: n 1334@ ppco.co m Rig Release: 1/7/2006 Group: Rig Name: Doyon 1 41 Rig Number: Date From - To '' Hoclrs ' Code ~ Code Phase ' Description of Operations 12/5/2005 14:00 - 16:00 ' 2.00 MOVE DMOB MOVE ' Blow down all steam lines, Prepare modules for move. 16:00 - 17:00 1.00 MOVE MOVE MOVE Move pipe shed modules, rockwasher, boilers, motor complex, and pits away from location. ' 17:00 - 19:30 ' 2.50 MOVE MOVE MOVE Move Sub base from 1 J - 164 to 1 J- 101. Spot subbase on well. 19:30 - 23:00 3.50 MOVE , MOB MOVE Lay all rig mats, and spot pits, motor complex, boilers, rockwasher, and i pipe shed modules. ' 23:00 - 00:00 ~ 1.00 MOVE MOB MOVE ~ Hook up all service lines, steam lines to pump room and pits. 12/6/2005 00:00 - 02:00 2.00 MOVE POSN MOVE Continue work on Rig Acceptance checklist. Spot pipe shed tioga, berm i & trim herculite liner on rockwasher. Apply steam, glycol & air to lines. Set up pipe skate. Rig up mud pump lines, and install all drain plugs in centifugal pumps. Rig Accepted @ 0200 HRS. 02:00 - 04:00 2.00 WELCTL NUND RIGUP PJSM with crew. Nipple up dverer riser and lines. Load shed with BHA and drill string. 04:00 - 06:30 2.50 DRILL RIRD RIGUP Change out Saver Sub, Bellguide, and Grabbers on Top Drive for 5" DP. 06:30 - 10:15. 3.75 DRILL PULD RIGUP PJSM with crew -Discuss safety issues and procedure for picking up pipe from shed. Pick up 51 joints of 5" DP (17 stands), and 29 joints of 5" HWDP & Drilling jars, racking back in deriick. 10:15 - 11:15. 1.00 DRILL PULD ' SURFAC Make up 1 stand of 8" Non-Mag flex drill collars, and rack back in derrick. 11:15 - 12:00 0.75 WELCT BOPE SURFAC Pick up 1 stand 5" DP & RU to perform Diverter Test. 12:00 - 12:30 0.50 WELCT ROPE SURFAC Perform Diverter function tact. Wintnest; of Test by AOGCC - ~ John Crisp. 12:30 - 14:15 1.75 DRILL PULD SURFAC PJSM with crew. Pull BHA up to rig floor. MU 8" Sperry Drill Lobe 4/5 - 5.3 stage Motor (28.78') with 13 1/2" Hughes MXC1 bit (1.0'), 8" Integral ' ~ ' blade stabilizer (5.65'), Non-Mag crossover (1.65'), and 1 stand 5" HWDP. Total 37.08'. RIH Tag @ 96'. : 14:15 - 14:45 , 0.50 , DRILL REAM ; SURFAC Fill string and conductor with mud. Perform Conductor test, and leak test. Test mud line to 3000 PSI. Wash & ream down to 108'. 14:45 - 16:45 2.00 DRILL DRLG SURFAC Drill 13 1/2" surface hole from 108' - 221' MD (113'). TVD = 221'. ADT = 1.61 HRS, ART = 1.61 HRS, AST = 0 HRS. PU WT = 42K, SO WT = i 50K, ROT WT = 47K. Torque onloff bottom = 1-2K. Pumps - 510 i GPM's - 650 PSI. RPM's = 80. WOB = 4-10K. Note: 6" Liners in pumps. Output = .101 BBLS/ STK. Mud Wt = 8.90 PPG, Visc = 351, YP = 78, Gels @ 34182. 16:45 - 18:45 2.00 DRILL , PULD SURFAC POOH, rack back 2 stands of 5" HWDP. Continue MU BHA. MU i Non-Mag Pressure drop sub (1.63'), 8" DGWD 1200 System (25.12'), ' Non-Mag Float sub (2.75'), Non-Mag UBHO sub (3.31'). Orient and up load MWD Assembly. PU 1 stand Non MAg Flex Drill Collars (92.65') ~ and XO (2.48'). 18:45 - 00:00 ~ 5.25' DRILL DRLG ~ SURFAC Run back in hole, continue drilling 13 1/2" Surface hole from 221' - 573' (352') MD. TVD = 573'. ADT = 3.8 HRS, ART = 3.8 HRS, AST = 0 HRS. PU WT = 64K, SO WT = 74K, ROT WT = 70K. Torque on/off bottom = 1-2K. Pumps - 675 GPM's - 1600 PSI. RPM's = 80. WOB = 14-17K. ' Total ADT = 5.41 HRS Mud Wt = 8.90 PPG, Visc = 351, YP = 78, Gels @34/82. 12/7/2005 00:00 - 04:30 4.50 ' DRILL DRLG 'SURFAC Continue drilling 13 1/2" Surface hole from 573' - 1075' (502') MD. TVD = 1075'. ADT = 3.76 HRS, ART = 3.76 HRS, AST = 0 HRS. PU WT = 87K, SO WT = 95K, ROT WT = 93K. Torque on/off bottom = i ~ ~ 2.5K. Pumps - 680 GPM's - 2000 PSI. RPM's = 80. WOB = 15-18K. Total Bit HRS = 9.17 HRS. Mud Wt = 9.20 PPG, Visc = 300,YP = 51, Gels @ 22 / 55. j 04:30 - 05:00 j 0.50 ~ DRILL CIRC ;SURFAC Circulate bottoms up for Survey while reciprocate & rotate string. RU Printed: 2/7/2006 10:40:10 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 12/7/2005 04:30 - 05:00 05:00 - 05:30 05:30 - 12:00 1J-101 1 J-101 ROT -DRILLING n1334@ppco.com Doyon141 Hours Code 0.50 DRILL 0.50 DRILL 6.50 DRILL Sub Phase Code CIRC 'SURFAC SURV SURFAC DRLG SURFAC 12:00 - 18:00 6.00 DRILL DRLG i SURFAC I i i 18:00 - 19:00 I 1.00 DRILL CIRC SURFAC 19:00 - 20:45 1.75 DRILL ~ TRIP SURFAC 20:45 - 21:30 ~ 0.75 DRILL TRIP i SURFAC 21:30 - 23:00 1.501 DRILL PULD SURFAC 23:00 - 23:30 ' 0.50 ~ DRILL PULD SURFAC 23:30 - 00:00 0.50; CASE !RURD SURFAC 12/8/2005 100:00-01:30 01:30 - 04:15 04:15 - 04:45 04:45 - 05:15 05:15 - 05:45 05:45 - 07:30 1.501 CASE RURD ;SURFAC 2.751 CASE RUNC SURFAC 0.501CEMENIiPULD (SURFAC 0.501 CEMEN7CIRC (SURFAC 0.50 CEMEN~PULD SURFAC 1.751 CEMEN i CIRC SURFAC Spud Date: Start: 12/6/2005 End: Rig Release: 1/7/2006 Group: Rig Number: Description of Operations Page 2 of 22 12/6/2005 1 /7/2006 Slickline unit. WLlli with Multi.-Shot Gyro to obtain surveys. WL(1~1, RD81~4cliners. Continue drilling 13 1/2" Surface hole from 1075' - 1580' (505') MD. TVD = 1580'. ADT = 5.01 HRS, ART = 4.47 HRS, AST = .54 HRS. PU WT = 96K, SO WT = 101 K, ROT WT = 100K. Torque on/off bottom = 2.5K. Pumps - 680 GPM's - 2000 PSI. RPM's = 80. WOB = 15-18K. Total Bit HRS = 14.18 HRS. Total Jar HRS = 59.19. Mud Wt = 9.20 PPG, Visc = 300,YP = 51, Gels @ 22 / 55. Install 13 1/2" Ghost reamer at top of HWDP while drilling. Crew Change Continue drilling 13 1/2" Surface hole from 1580' - 2209' (629') MD. TVD = 2195'. ADT = 4.27 HRS, ART = 2.23 HRS, AST = 2.04 HRS. PU WT = 112K, SO WT = 112K, ROT WT = 111 K. Torque on btm = 3K, Off bottom = 1.5K. Pumps - 742 GPM's - 2450 PSI. RPM's = 80. WOB = 2-18K. Total Bit HRS = 18.45 HRS. Total Jar HRS = 63.46. Mud Wt = 9.0 PPG, Visc = 170,YP = 38, Gels @ 14 / 28. Circulate bottoms up 3 times @ 177 SPM - 750 GPM's - 2350 PSI. RPM's - 80, Torque = 2.5K BROOH from 2209' - 1086' (1123'), at drilling rate of 80 RPM's, Torque at 2-8K, 177 SPM -750 GPM's, and 2300 PSI. Lay down Ghost Reamer. Contiue POOH on elevators from 1086' - 245' (841'). Rack back 5" HWDP & Jars (913'), and 10 Stands. Continue POOH, Breakout & Lay down BHA #1. Lay down 8" Sperry Drill Lobe 4/5 - 5.3 stage Motor (28.78') with 13 1/2" Hughes MXC1 bit (1.0'), 8" Integral blade stabilizer (5.65'), Non-Mag crossover (1.65'), Non-Mag Pressure drop sub (1.63'), 8" DGWD 1200 System (25.12'), Non-Mag Float sub (2.75'), Non-Mag UBHO sub (3.31'). Plug in & down load MWD Assembly. Lay down 8" Non Mag Flex drill collars. Record gauge of Bit@5/5/WT/A/6/I/WT/TD Clear & Clean Rig Floor area, send all tools out. Rig up 10 3/4" Casing Equipment. Make up Franks fill up tool. Check all equipment for casing run. Cement head, plugs etc.. Rig up 10 3/4" Casing Equipment. Make up Franks fill up tool. Check all equipment for casing run. Cement head, plugs etc.. Run 54 jts of 10 314", 45.5#, L-80 BTC csg to 2,166' per well plan, MU 10 3/4 Weatherford Model 303 float shoe, 2 joints 45.5#, L-80, BTC csg and Weatherford model 402 FC, (1) joint 45.5#, L-80, BTC casing, baker Vocked btm 3 conn. and pumped thru checking float equipment, cont RIH with 10 3/4" csg to 2,166', Ran 19 bow spring centralizers on 1st 17jts (1-10' above Shoe, 1-10' above & below Float collar) ran 1 cent on jts. # 51 & 52 @ 20" conductor @ 106' & 146' (Total of 21 centralizers and 3 stops). No problems RIH, st wt up 125K, down wt 110K. Pick up Vetco Gray casing hanger and land w/Shoe @ 2,199.12', Float collar @ 2,115.04'. Circ btm's up w/ frank's fill up tool at rate of 5 bpm @ 350 psi, Up 125K, Dn 110K. Lay down frank's fill up tool, Pick up Dowell cement head. Finish circ and cond mud for cementing, staged pump rate up to 7.0 bpm at 420 psi, reciprocating pipe 't5' with 135K up wt and 107K do wt, circ and cond mud to 8.9 ppg and lowered PV to 20 and YP to 12, held PJSM on cement job with Dowell, ASRC and rig crew while circ and cond mud. Printed: 2!7/2006 10:40:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ,From - To 12/8/2005 07:30 - 09:30 09:30 - 10:00 10:00 - 12:00 12:00 - 12:30 12:30 - 15:00 15:00 - 16:00 16:00 - 18:00 18:00 - 20:15 20:15 - 00:00 12/9/2005 00:00 - 02:30 02:30 - 03:00 03:00 - 03:30 03:30 - 06:00 06:00 - 08:00 08:00 - 08:30 ConocoPhillips Alaska Operations Summary Report 1 J-101 1 J-101 ROT -DRILLING n1334@ppco.com Doyon141 Ho~lrs' Code Code' Phase 2.00' CEMEN~PUMP i i i 0.50 CEMENl(DISP 2.00; WELCT NUND SURFAC SURFAC SURFAC 0.501 CMPLTNI NUND 2.501 CMPLTNI NUND 1.001 CMPLTNI NUND 2.00; CMPLTN~NUND 2.251 WELCTIJ NUND 3.751 WELCTLI BOPE SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC 2.501 WELCTU BOPE SURFAC 0.50 WELCT BOPE SURFAC 0.50 RIGMNT RSRV SURFAC 2.50 DRILL PULD SURFAC 2.00 i DRILL PULD I SURFAC 0.501 DRILL 1 PULD ;SURFAC Start: 12/6/2005 Rig Release: 1/7/2006 Rig Number: Page 3 of 22 Spud Date: 12/6/2005 End: 1 /7/2006 Group: Description of Operations __ - jTurned over to Dowell and cemented 10 3/4" csg, Pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), Followed by 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm plug, began mixing and pumping Arcticset lead slurry, Pumped 368.0 bbls (460 sxs) of lead cement at 10.7 ppg and 4.49 yield with additives, ave 6.6 bpm at 275 psi, Followed with 65.4 bbls (148 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.47 yield with add., ave 4.8 bpm at 230 psi, shut down and dropped top plug, Kick plug out with 20 bbls fresh water, ted casing 10' to 15' untiF 135 bbls cement around shoe then. pipe became ~ tight and landed on hanger, Up 135K, Dn 107K.. !Turn over to rig and displace cement w/ 181.2 bbls (Total 201.2 bbls to bump) of 8.9 ppg mud, Displaced cement at 7.0 bpm, Initial pump j pressure 525 psi, max pressure at 7.0 bpm 700 psi, Observed red dye at shakers after pumping 13.7 bbls mud, Slowed rate down to 3 bpm @ 500 psi 10 bbls prior to bumping plug, Bumped plug w/ 1100 psi, Held 5 min, Check floats- OK, CIP @ 10:00 hrs 12/8/05, Hsi fwtt ~turr}s thru out job wfth 42.7 bbls 10.7 ppg t~rr-ent tosurfsce, Shoe @ 2,199.12', Float collar @ 2,115.04'. Test Float Equipment. Flush stack, Rig down all cement equipment, lay down landing joint. SIMOPS -Nipple down Diverter stack & lines. !Continue lay down all Casing equipment, & Franks tool, and ND I Diverter stack. SIMOPS -Move pipe shed modules, Change out ~ Drilling Line Spool on Sub base, respot Pipe shed modules. Continue ND Diverter stack and Riser. Lay down XO for Diverter & Conductor. Lay down Knife Valve. Position all equipment to rear of cellar for crane pick. Pull all Diverter stack equipment form rear of cellar using crane. Move & Set wellhead equipment in cellar. Nipple up wellhead as per Vetco Gray rep. Test same to 5000 PSI - 10 minutes. ,Nipple up BOP stack & all lines. Change out saver sub on Top Drive, 'grabbers and bell guide. Perform BOP test. Test 7 5/8" Lower rams, & Annular with 7 5/8" test ,joint. Test 6"x 3 1!2" VBR's in top set, and Annular with 5" test joint. Continue test 5" Dart Valve, Floor Valve, 4" Floor & Dart valves, and 3 1/2" x 6" VBR's with 4" test joint. Test HCR & Choke, and manual valves. Test Choke manifold valves #1, #12, #13, #14. Upper IBOP, Choke Manifold valves # 9, #11. Test Lower IBOP & choke manifold valves # 5, #8, #1t1.,Ak1 test to 250 PSt -law, 3500 PSI High. AO(3C~ rep, Jeff Jones waived witness of test at 1840 HRS. Continue test BOP's. Test Dart & Floor valve for 4" DP, Choke manifold valves # 4, #6, #7 & #2. Test HCR's Choke 8~ Manual valves, Annular. ': Perform Koomey test. Tets Blind rams, Choke manifold valves #3, & #4. Install wear bushing with Vetco Gray rep. RILDS. Re-Hang Bales on Top Drive and service T.D. PJSM, Pick up and RIH with 60 joints of 4" DP. POOH, rack back same. Contiue Pick up and RIH with 60 joints of 4" DP. POOH, rack back same for a total of 120 joints picked up. . Change out all handling equipment from 4" to 5" DP. Pull BHA tools up Ito rig floor. Printed: 2(7/2006 10:40:10 AM ConocoPhiilips Alaska Page 4 of 22 Operations Summary Report Legal Well Name: 1J-101 Common Well Name: 1J-101 Spud Date: 12/6/2005 Event Name: ROT -DRILLING Start: 12/6/2005 End: 1/7/2006 Contractor Name: n1334@ppco.com Rig Release: 1!7/2006 Group: Rig Name: Doyon 141 Rig Number: Date 12/9/2005 From - To 'Hours Code 'Sub ' Phase Code _-- - 08:30 - 09:15 ~ 0.75 ~ DRILL ~ PULD I~ SURFAC 09:15 - 10:00 10:00 - 10:30 10:30 - 11:30 11:30 - 12:00 12:00 - 12:30 12:30 - 13:00 13:00 - 14:00 14:00 - 15:30 15:30 - 16:00 0.75 DRILL PULD 0.50 DRILL PULD 1.00; DRILL (TRIP 0.501 DRILL (TRIP 0.501 DRILL (TRIP 0.501 DRILL CIRC 1.00 CASE ~DEQT 1.50 CEMEN DSHO 0.501 DRILL CIRC 16:00 - 17:00 1.00 DRILL LOT 17:00 - 18:00 1.00 RIGMNT RGRP 18:00 - 19:00 ; 1.00 DRILL TRIP 19:00 - 00:00 5.001 DRILL j DRLG SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC INTRM1 INTRM1 I NTRM 1 12/10/2005 100:00 - 10:30 10.501 DRILL I DRLG INTRM1 10:30 - 11:30 I 1.001 DRILL I OTHR i INTRMI Description of Operations PJSM with crew. Discuss safety issues, and procedure for MU BHA. Make up BHA #2. 9 7/8" Hughes MX-CX1 bit with 3 x 20, 1 x 12 jets (1.0') TFA = 1.031 SO. IN., 7" Sperry Drill Lobe 7/8 - 6.0 stage (25.45`), 6 3/4" Float sub (2.49'), 6 1!2" Welded Blade Stabilizer (5.72'), 6 3/4" DM Collar (9.21'), 6 3/4" Gamma/Res/PWD/HCIM (27.30'), 6 3/4" TM Collar (9.85'), 6 3/4" Acal (5.62'). Pfug in and Upload MWD assembly. Continue MU BHA picking up 3 Non-Mag Flex Drill Collars. Trip in hole from 172' - 900' (728'). Perform Shallow pulse test @ 600 GPM's - 1450 PSI. 144 SPM. Good test. Rack back 1 stand of 4" DP with crossover. Insert Corrosion Ring in top joint of 5" HWDP. TIH to 1191', make up 9.875" Ghost reamer. Crew Change Continue trip in hole from 1191' - 1940' (749'). Wash down to Float Collar @ 2115' @ 142 SPM - 1700 PSI, 602 GPM's. Tag Float Collar. Pull up to 2087', RU and circulate & condition mud @ 602 GPM's - 1700 PSI. Mud weight = 9.0 PPG. Rig up i;< test 10 3/4" Surface casing to 3000 PSI - 30 minutes. Record on chart. Rig down test equipment. RIH to 2115', re-tag Float collar. Drill out float collar and Shoe track and 20' of new hole from 2115' - 2229', (114'). UP WT = 102K, SO WT = 97K, ROT WT = 100K. 500 GPM's - 1350 PSI. 60 RPM's, with 3-4K torque. Circulate & displace well with 8.9 PPG conditioned LSND mud, @ 550 GPM's - 1550 PSI. Pull Back up into casing. Rig & perform LOT to observe break over @ 7318 PSd. Total pumped = 6 BBLS: Computer c~nlaul~ted 45;3 PPG EMW, @ 2199' MD, 2185' TVD. Mud wt = 8.8 PPG, 10 Min Gel - 15. Bleed back in 10 minutes to 330 PSI. Rig down, blow down lines. Repair broken bolts on Top Drive stand jump cylinder. POOH back to 5' DP (tapered string), Change out elevators, Pick up 1 stand of 5" DP, Run back in hole to 2229' Break circulation. Directional drill 9 7/8" Intermediate hole from 2229' - 2685' (456') MD. TVD = 2648'. ADT = 3.6 HRS, ART = 2.11 HRS, AST = 1.49 HRS. PU WT = 112K, SO WT = 104K, ROT WT = 108K. Torque on btm = 3K, Off bottom = 3.5K. Pumps - 650 GPM's - 19000 PSI. RPM's = 80. WOB = 2-10K. Total Bit HRS = 3.6 HRS. Total Jar HRS = 69.11. Mud Wt = 9.0 PPG, Visc = 68,YP = 26, Gels @ 10 / 17. Survey @ 2644' MD, 2608' TVD, 23.68 DEG INC, 43.48 DEG AZ Continue Directional drill 9 7!8" Intermediate hole from 2685' - 3713 (1028') MD. TVD = 3309'. ADT = 7.99 HRS, ART = 2.99 HRS, AST = 5.00 HRS. PU WT = 116K, SO WT = 100K, ROT WT = 105K. Torque on btm = 4K, Off bottom = 3.5K. Pumps - 650 GPM's - 2300 PSI. RPM's = 80. WOB = 2-18K. Total Bit HRS = 11.59 HRS. Total Jar HRS = 77.10 Mud Wt = 9.0 PPG, Visc = 54,YP = 25, Gels @ 9 / 13. Survey @ 3577' MD, 3247' TVD, 62.01 DEG INC, 23.96 DEG AZ Obtain SPR's at 3713' MD, 3309' ND Pump #1 , 30 SPM -210 PSI, 40 SPM - 280 PSI. Pump #2, 30 SPM -220 PSI, 40 SPM - 310 PSI. Lost MWD communication. Trouble shoot & attempt to communicate with MWD tools. Suspect plugged impellar. Attempt to unplug by working drill string and circulating @ 155 SPM - 2200 PSI. Increase pressure on mud pump pulsation dampeners to 750 PSI each. Failed to gain communication. Printed: 2/72006 10:40:10 AM ConocOPhillips Alaska Operations Summary Report Legal Well Name: 1J-101 Common Well Name: 1 J-101 Event Name: ROT -DRILLING Start: 12/6/2005 Contractor Name: n1334@ppco.com Rig Release: 1!7/2006 Rig Name: Doyon 141 Rig Number: Date From - To I Hours ~ Code ' Phase Code 12/10/2005 11:30 - 12:00 0.50 DRILL ~i CIRC INTRMI ~ 12:00- 15:00 ~ 3.00 ~ , DRILL ''TRIP INTRM1 i 15:00 - 15:30 0.50 DRILL ~! TRIP INTRM1 15:30 - 17:00 j 1.50 I 1 DRILL TRIP I INTRMI j 17:00 - 18:00 18:00 - 18:30 18:30 - 19:30 19:30 - 22:00 1.OOIDRILL (TRIP !INTRM1 0.501 DRILL •. DEOT INTRM1 1.00' DRILL PULD I INTRM1 2.50 DRILL DEOT IINTRM1 22:00 - 22:30 22:30 - 00:00 12/11/2005 00:00 - 00:15 00:15 - 00:30 0.50 DRILL .PULD INTRM1 1.50 DRILL STRIP INTRM1 0.251 DRILL (TRIP INTRM1 0.251 DRILL I OTHR I INTRMI 00:30 - 01:00 0.50 RIGMNT RSRV !INTRMI 01:00 - 02:00 1.00 DRILL TRIP i INTRM1 02:00 - 10:30 I 8.501 DRILL DRLG I INTRMI 10:30 - 11:00 ~ 0.501 DRILL OTHR ! INTRM1 11:00 - 12:00 1.00 DRILL CIRC I INTRM1 12:00 - 13:00 I 1.001 DRILL ITRIP i INTRM1 13:00 - 14:00 I 1.001 DRILL ITRIP I INTRMI 14:00- 14:30 I 0.501 DRILL ITRIP IINTRM1 Page 5 of 22 Spud Date: 12/6/2005 End: 1 /7/2006 Group: Description of Operations 'ump Hi Visc weighted sweep with nut plug. 5Ibs /BBL. Monitor well, static. 'OOH on elevators observing 40K to 50K overpull, and swabbing. RU and BROOH from 3622' - 3062' @ drilling rates of 650 GPM's - 2000 'SI. Observe gas cut mud @ 3062' Continue BROOH slowly from 3062' - 2698' allowing time for good bottoms up and observing 395 Max 3as units. BROOH to shoe @ 2197'. BROOH total of 1519' Monitor well at the shoe -static. Pump dry job. Change elevators to 5" JP, and blow down equipment. continue POOH on elevators observing hole taking calculated fill, standing back all 5" HWDP. Stand back all Non-Mag Flex Drill Collars. Pull assembly up to bit. Drain 3HA. Inspect bit and gauge to 1 / 1 / WT / A / E / I / N /DTF. We will ~erun bit. RIH, breakout i~ lay down 6 3/4" ACAL Assembly. (5.62') 'lug in and down load MWD. Breakout, lay down all Smart Tools. Total ength = 46.36' Make up Back up set of Smart tools. (46') plug in up load MWD assembly. Attempt to read ACAL tool without success. No communication with tool. Discuss options with town, iecision to RIH without ACAL tool. 3reakout & lay down ACAL assembly. Download resistivity tool. Make up remaining BHA #3, with re-run bit, Run Non -Mag Flex drill collars (91.32'), 5" HWDP with Jars (642.08'), Continue TIH picking up 3 7/8" Ghost Reamer. TIH from 81' - 1136' (1055') continue TIH from 1136' - 2213'. PU 9 7/8" Ghost Reamer on top of iWDP. 'erform Shallow Pulse test @ 2213'. Pumps @ 600 GPM's - 141 SPM - 1500 PSI. Good test. iervice Top Drive, Recharge Actuator Cylinders. continue Trip in hole from 2213' - 3617' (1404'). No issues on OH. Nash & ream last stand from 3617' - 3713' (96'), @ 141 SPM - 600 3PM's - 1900 PSI. PU WT = 110K, SO WT = 90K, ROT WT = 100K. continue Directional drill 9 7/8" Intermediate hole from 3713' - 4178' '465') MD. TVD = 3446'. ADT = 6.59 HRS, ART = 2.87 HRS, AST = 3.72 HRS. PU WT = 110K, SO WT = 94K, ROT WT = 100K. Torque on ~tm = 5K, Off bottom = 5K. Pumps - 650 GPM's - 2300 PSI. RPM's = 30. WOB = 5-20K. Total Bit HRS = 18.18 HRS. Total Jar HRS = 83.69 Mud Wt = 9.2 PPG, Visc = 54,YP = 25, Gels @ 9 / 13. Survey @ X132' MD, 3435' TVD, 76.39 DEG INC, 4.04 DEG AZ. Max gas units = 136, ECD =9.57 PPG. observe lost communication with MWD assembly. Troubleshoot. Failed o gain communication. 'ump Hi Visc weighted sweep with SAP & nut plug. 5 Ibs /BBL, while reciprocate & rotate drill string. Observe 20 % increase in cuttings when across shakers. Monitor well, static. Obtain SPR's at 3800' MD, 3334' fVD Pump #1 , 30 SPM -210 PSI, 40 SPM - 290 PSI. Pump #2, 30 iPM -210 PSI, 40 SPM - 290 PSI. 'OOH on elevators, no issues, or overpull. After 5 stands pulled with ;orrect hole fill, pump dry job, and continue POOH to shoe at 2178'. change out to 5" handling equipment, and POOH, racking back 5" DP ~ HWDP. Zack back Non-Mag Flex Drill Collars, Pull up to inspect & grade bit @ 1 / 1 / WT / A / 0 / 1 / NO /DTF. Drain mud motor & Smart tool Printed: 2/7/2006 10:40:10 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-101 Common Well Name: 1J-101 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To ~ Hours Code ' Sub ', Phase '! '..Code . ---_- ___ - _-- Page 6 of 22 Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number: Description of Operations 12/11/2005 14:00 - 14:30 0.50 DRILL TRIP INTRM1 Asembly. 14:30 - 15:00 0.50 DRILL OTHR INTRM1 i Plug in and download MWD assembly. Observe short circuit in Gamma 15:00 - 16:30 1.50 I 16:30 - 17:30 I 1.00 17:30 - 20:30 3.00 20:30 - 21:00 0.50 21:00 - 00:00 3.00 12!12/2005 100:00 - 12:00 12:00 - 14:00 12.00 2.00 14:00 - 14:30 0.50 14:30 - 15:30 1.00 I 15:30 - 18:00 ~ i 2.50 18:00 - 19:30 ~ 1.50 19:30 - 20:00 0.50 20:00 - 23:00 3.00 23:00 - 00:00 12/13/2005 00:00 - 00:15 1.00 0.25 DRILL PULD i INTRM1 i I DRILL OTHR INTRM1 DRILL TRIP INTRM1 DRILL REAM INTRM1 DRILL I DRLG INTRM1 DRILL I DRLG DRILL I DRLG INTRM1 INTRM1 DRILL CIRC INTRM1 DRILL jCIRC ~INTRM1 DRILL TRIP INTRM1 DRILL TRIP INTRMI DRILL TRIP INTRMI DRILL ~ PULD INTRM1 DRILL ~ PULD ~ INTRM1 DRILL i PULD i INTRM1 Assembly. Breakout & lay down Smart Tools. Lay down 6 3/4" DM Collar (9.21'), 6 3/4" Gamma/Res/PWD/HCIM (27.30'), 6 3/4" TM Collar (9.85'), Total 46.36'. Make up Back up Smart Tool Assembly, 6 3/4" DM Collar (9.18), 6 3/4" Gamma/Res/PWD/HCIM (27.37'), 6 3/4" TM Collar (9.85'), Total 46.40' Plug in and upload MWD assembly. MU remaining BHA #4, TIH with 5" x 4" tapered string, filling pipe & perform Shallow pulse test at shoe. Good Test. Wash & ream last stand from 4084' - 4177' (92'). Observe bad joint of 4" DP. Breakout, lay dn, and PU new joint. Continue Directional drill 9 7/8" Intermediate hole from 4178' - 4297' (119') MD. ND = 3473'. ADT = 2.13 HRS, ART = .82 HRS, AST = 1.31 HRS. PU WT = 110K, SO WT = 90K, ROT WT = 100K. Torque on btm = 5K, Off bottom = 5K. Pumps - 650 GPM's - 2300 PSI. RPM's = 80. WOB = 5-20K. Total Bit HRS = 20.31 HRS. Total Jar HRS = 85.82 Mud Wt = 9.25 PPG, Visc = 57,YP = 25, Gels @ 10 / 16. Max gas units = 158, ECD =9.68 PPG. Observe drilling through concretions @ 4273' -4293' (20'). Continue Directional drill 9 7/8" Intermediate hole from 4297' - 5247' (950') MD. ND = 3654'. ADT = 9.04 HRS, ART = 6.81.82 HRS, AST = 2.59 HRS. PU WT = 109K, SO WT = 85K, ROT WT = 94K. Torque on btm = 6K, Off bottom = 6K. Pumps - 650 GPM's - 2600 PSI. RPM's = 80. WOB = 5-20K. Total Bit HRS = 29.71 HRS. Total Jar HRS = 95.22 Mud Wt = 9.2 PPG, Visc = 54,YP = 26, Gels @ 10 / 16. Max gas units = 392, ECD =9.90 PPG. Survey @ 5161' MD, 3643 ND, INC = 82.14 Deg, AZ = 358.13 Deg. Obtain SPR's at 4362' MD, 3486' ND Pump #1 , 30 SPM -220 PSI, 40 SPM - 290 PSI. Pump #2, 30 SPM -250 PSI, 40 SPM - 310 PSI. Drill through concretion @ 5119' - 5129' (10'). Continue Directional drill 9 7/8" Intermediate hole from 5247' - 5396' (149') MD. ND = 3680'. ADT = 1.78 HRS, ART = 1.44 HRS, AST = 1.44 HRS. PU WT = 109K, SO WT = 85K, ROT WT = 94K. Torque on btm = 6K, Off bottom = 6K. Pumps - 650 GPM's - 2600 PSI. RPM's = 80. WOB = 5-20K. Total Bit HRS = 31.49 HRS. Total Jar HRS = 97.0 Mud Wt = 9.25 PPG, Visc = 53,YP = 27, Gels @ 15 / 24. Max gas units = 392, ECD =9.92 PPG. Circulate bottoms up for Geologist sample. Pumps @ 650 GPM's - 2600 PSI. GEO called TD at 5396' MD. 3680' ND. Contiue Circulate Hi Visc weighted sweep @ 650 GPM's - 2600 PSI, while reciprocate & rotate drill string. BROOH at drilling rates of 650 GPM's-2200 PSI from 5396' -3991' (1405'). Pull last 300' slowly to allow for a good bottoms up. Continue POOH on elevators from 3991' - 2199' (1792'), to casing shoe. Monitor well -static. Rig up 5" handling equipment. Continue POOH lay down 51 joints 5" Drilt Pipe & 29 joints of 5" HWDP. RIH with 6 stands from derrick, POOH, lay down same. Breakout & lay down BHA. RU & download MWD assembly Continue break out & lay down BHA #4. Flush & drain mud motor & breakout bit. Gauge bit to 2/2/CT/G/EJI/WT/TD. Printed: 2/7/2006 10:40:10 AM ConocoPhillips Alaska Operations Summary'''Report Legal Weil Name: Common Well Name Event Name: Contractor Name: Rig Name: 1J-101 1J-101 ROT -DRILLING n1334@ppco.com Doyon 1 ~1 Date From - To 'Hours Code Code' Phase 12/13/2005 00:15 - 01:00 01:00 - 01:30 i 01:30 - 02:00 02:00 - 03:00 03:00 - 03:45 .03:45 - 04:00 04:00 - 07:30 07:30 - 08:00 08:00 - 11:30 11:30 - 12:00 12:00 - 12:15 12:15 - 13:30 13:30 - 15:00 15:00 - 16:15 16:15 - 16:30 16:30 - 18:45 0.75 DRILL OTHR 0.50, DRILL PULD 0.50 CASE OTHR 1.00 CASE RURD 0.75 ~ RIGMNT RSRV 0.25 CASE SFTY 3.50 CASE RUNC 0.50 CASE CIRC 3.501 CASE RUNC I 0.501 CEMEN CIRC 0.25 ~ CEMEN CIRC 1.25 i CEMEN PULD 1.50 CEMEN CIRC 1.25 CEMEN CIRC I 0.25 i GEMEN CIRC 2.25 ~ CEMENlf PUMP INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRMI Page 7 of 22 Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number: Description of Operations Plug in and download MWD assembly Lay down all remaining BHA. Lay down Smart Tool Assembly, 6 3/4" DM Collar (9.18), 6 3/4" Gamma/Res/PWD/HCIM (27.37'), 6 3/4" TM Collar (9.85'), Total 46.40' 'Rig up and BOLDS. Pull Wear bushing. Rig up all 7 5/8" casing running equipment. Visually Inspect & Service Top Drive PJSM with crew and casing hand. Discuss safety issues and procedure to run casing as per detail. Discuss all pinch points, and overhead loads. Make up 7 5/8" Shoe joint, and flaot collar joints. Continue RIH picking up casing. Make up torque @ 9000 FULbs. Seal rings in collars. Filling casing through Franks tool. Observe proper fill. 'Circulate bottoms up @ 4 BPM - 300 PSI. Monitor well -static. Continue RIH with 7 5/8" Casing from 2180' - 5391' (3211'). Tag bottom @ 5391'. Attempt to wash down to TD at 5396'. Solid bottom @ 5391' _ 7' high of TD. We ran a total of 125 joint of casing, 4 pups for window 'space out, with tandem rise centralizers on each joint for depths of 5390'-2777'. Circulate & condition mud @ 6 BPM - 600 PSI, whiff reeiprocttfe easing ,string. PU WT = 160K, SO WT = 102K. Mud properties = 9.5 PPG,Visc = 62, PV = 13, YP = 27, Gels @ 13 / 24. Note: SIMOPS: RU Dowell Schlumberger cementing crew, and trucks. Continue Circulate & condition mud @ 6 BPM - 600 PSI, while reciprocate casing string. PU WT = 160K, SO WT = 102K. Condition mud to pre-cement @ 9.1 PPG, PV = 10, YP = 15, Gels @ 6 / 8. Rig down Franks fill up tool. Blow down Top Drive. RU 7 5/8" Casing cement head & lines. i Circulate & condition mud staging up to 8 BPM - 450 PSI. ~ RU & pump 210 BBLS - 42 Sacks of Alpine Co-Polymer Drill Beads (Fine Size), @ 6.25 BPM - 350 PSI, adding beads on the fly. Chase with 240 BBLS of conditioned mud to spot in the annulus to shoe @ 2199'. PU WT = 160K, SO WT = 112K. We observed no significant change in Up & Down parameters. Fill both Mud pumps & lines with MOBM Turn Rig over to Dowell lines. Dowell pumped 10 bbls CW 100 at 8.3 ;ppg at rate of 4.7 bpm @ 230 psi, Pressure tested lines to 3,500 psi, Then pumped 40 add. bbls of CW 100 at rate of 4.5 bpm @ 170 psi, Pumped 50 bbls of MudPush at 11.0 ppg at rate of 4.7 bpm @ 215 psi, Dropped btm plug then pumped 124 bbls, (310 sxs - 10% over caliper) of DeepCrete cmt at 12.5 ppg, 2.25 yield with additives, avg 5.6 bpm at 275 psi, Reciprocated pipe wi#h full returns 15` td 2t)`. Drop top plug and Dowell kicked top plug out with 10 bbls fresh water, @5 BPM -200 PSI. Rig displaced cement with 9.1 ppg OBM, Bumped plug after pumping 240.8 bbls MOBM (96% pump eff.) 2396 Strokes, avg 6.8 bpm while displacing cmt, Observed lift pressure f! 500 psi to 800 psi prior to slowing pump rate to 3 bpm, Slowed pump rate to 3 bpm @ 500 psi with 10 bbls left to pump and bumped plug to 1185 psi, ck floats and held. CIP at 1830 hrs, 12-13-05. Reciprocated pipe 15' to 20' until MudPUSH at shoe, then recip. 10' until Cmt at shoe, then recip. 10' until last 30 bbls, then recip. 5' until last 10 bbls then stopped pipe, Landed csg with Shoe @ 5389', Float Collar @ 5300', Calc TOC @ 2440', Had full returns thru out job. Well static after shut down. Printed: 2!7/2006 10:40:10 AM ConocoPhiilips Alaska Operations Summary Report Legal Well Name: 1J-101 Common Well Name: 1J-101 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours ' Code Code ', Phase __ ___ ~_ - 12/13/2005 18:45 - 19:15 0.50 CEMENTRURD INTRM1 19:15 - 21:30 2.25 CMPLTN~ NUND INTRM1 21:30 - 00:00 I 12/14/2005 00:00 - 00:30 00:30 - 01:30 01:30 - 02:00 02:00 - 03:00 i 03:00 - 04:30 04:30 - 07:45 07:45 - 08:15 08:15 - 12:00 12:00 - 14:15 14:15 - 17:30 17:30 - 18:30 18:30 - 20:30 20:30 - 22:00 22:00 - 23:00 23:00 - 00:00 2.50 i CMPLTNI OTHR I INTRM1 0.501 CMPLTNI OTHR INTRM1 1.001 DRILL !LOT I INTRMI 0.50 DRILL OTHR INTRMI 1.00 DRILL PULD INTRM1 1.501 RIGMNTI RSRV I INTRM1 3.25 I DRILL I PULD I INTRM1 0.501 DRILL PULD INTRM1 3.75 DRILL PULD ~ INTRM1 2.25 DRILL PULD INTRM1 3.25 DRILL • I PULD INTRM1 1.00' DRILL PULD INTRM1 2.00 DRILL PULD INTRM1 1.50 DRILL PULD ~ INTRMI 1.00 DRILL PULD INTRM1 1.001, DRILL !PULD INTRM1 12/15/2005 ! 00:00 - 00:30 I 0.501 DRILL I PULD i INTRM1 Page 8 of 22 Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number: Description of Operations Rig down Cement head and blow down all lines Nipple down BOP stack, and raise for installation of emergency slips. Set slips with 160K pulled on casing. Shoe @ 5389'. RU and suck out MOBM from inside of 7 5/8"joint to below well head level. Rig up WACHS pneumatic cutter and cut casing as per Vetco Gray reps. Pull and lay do Cut off joint. # 125 Cut off length = 22.41' Dress top of casing stump, install 7 5/8" casing Packoff. Nipple up BOP stack. RILDS. Test Packoff to 3800 PSI. = 80 % burst pressure of casing. Rig up lines to annulus from mud pump for annular injectivity test. Continue test Packoff 10 min. to 3800 PSI. = 80 % burst pressure of casing. Rig up lines to annulus from mud pump for annular injectivity test. RU & perform LOT on 10 3/4" x 7 5/8" Casing. Observe pressure to Equivalent Mud wt of 10.4 PPG. 10 minute shut in bled to 380 PSI. Continue pump 30 BBLS water down anulus staging up to 3 BPM - 900 PSI. SIMOPS :Weld fitting on top of standpipe for Anadrill MWD. Load i;< strap 4" Drill pipe in shed. NOTE: Welder injured finger on left hand. Install wear bushing. RILDS. ID of wear bushing = 9.25" PJSM with crew. Discuss safety issues and procedure for picking up 4" DP. Change out Bales. Pick up 4" DP from skate. Continue Load & strap DP in shed: PJSM. Change out Saver Sub on Top Drive. SIMOPS: Complete installation of fitting and safety cable on top of standpipe for Anadrill MWD. Continue pick up and RIH with 129 joints of 4" DP. SIMOPS: RU Little Red Services and pump 80 BBLS of H2O flush with rig, & 80 BBLS of Freeze protect diesel down 10 3/4" x 7 5/8" Annulus @ 3 BPM - 925 PSI. Shut in. Bleed & blow down lines. RD Little Red Services. PJSM with crew. Discuss safety issues, and procedure for installation of Super Sliders. RU air line & tools. POOH with 18 stands installing Super Sliders in the middle of each joint. Rack back in derrick. Installed 54 Super Sliders. Crew change. Continue POOH with 25 stands installing Super Sliders in the middle of each joint. Rack back in derrick. Installed 36 Super Sliders. Pick up &RIH with Hybrid Push pipe from shed. (2 joints of 4 3/4" drill collars & 1 joint of 4" HWDP). 15 stands total POOH, rack back Push Pipe stands. RIH with 13 stands of 4" Drill pipe from derrick. POOH, racking back, while installing remaming Super Sliders in the middle of each joint. Installed 39 Sliders. Pick up &RIH with 21 joints of 4" Slick Dri11 Pipe, rack back same in derrick. Clean & clear rig floor area. Pull tools to floor. Calibrate Schlumberger Block height. PJSM with crew &Anadrill hands.Discuss Safety Issues and procedure for making up BHA. MU BHA #5, Bit #3. Make up Hycalog RSX711M-A2 Bit w/ 2x11, and 2 x 12 jets for a TFA of .407, on Anadrill Periscope drilling assembly. Crew change. Continue MU BHA #5. MU 4 3/4" Bias Unit w 22/restrictor (2.96'), 4 15/16" Control Collar (10.34'), 4 13/16" x 5" PD XO (1.31'), 5 x 4 13/16" Receiver (4.92'), 4 3/4" Flex XO (2.38'), 4 11/16" Periscope (24.98'), 4 3/4" Impulse MWD tool (35.0'), 4 3/4" VPWD (16.35'), 5 1/4" Bypass Printed: 2/7/2006 10:40:10 AM ConocOPhillips Alaska Page 9 of 22 Operations Summary Report Legal Well Name: 1 J-101 Common W ell Name: 1 J-101 Event Nam e: ROT -D RILLING Contractor Name: n 1334@ ppco.co m Rig Name: Doyon 1 41 Date From - To ' Hours ' Code ' Sub ', Phase ' Code 12/15/2005 00:00 - 00:30 0.50 DRILL `PULD INTRMI 00:30 - 00:45 0.25 DRILL OTHR INTRM1 j 00:45 - 01:45 1.00 j I DRILL PULD INTRM1 i 01:45 - 05:15 i I 3.50! DRILL TRIP INTRM1 1 05:15 - 05:45 j 4 0.50f DRILL ~ TRIP INTRM1 05:45 - 09:00 3.25 I RIGMNT ~ RSRV ~ i INTRM1 09:00 - 10:00 1.00 DRILL i DEOT ~ INTRM1 10:00 - 12:00 2.00 CEMEN DSHO INTRM1 12:00 - 13:00 1.00 CEMEN DSHO INTRM1 13:00 - 13:30 0.50 DRILL CIRC INTRM1 13:30 - 14:30 1.00 DRILL LOT PROD 14:30 - 16:30 I 2.00 ~ DRILL I CIRC PROD ~~ 16:30 - 00:00 ~ 7.50 ~ I DRILL ~ DRLG i PROD 12/16/2005 00:00 - 05:15 5.25 DRILL DRLG PROD 05:15 - 06:15 1.00 DRILL OTHR PROD ~ 06:15 - 12:00 i 5.75 II DRILL DRLG ~ i PROD Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number: ~~ Description of Operations Flaot Valve (2.33'), 3 - NM Flex Drill Collars (93.45'), XO sub (1.65'), 3 Jnts 4" HWDP (90.89'), 4 3/4" Drilling Jars (28.88'), 2 Jnts 4" HWDP (60.57'. Total BHA = 376.59' Perform Shallow pulse test, & test Power Drive @ 67 SPM - 990 PSI. Continue MU 5 1/4" Bypass Flaot Valve (2.33'), 3 - NM Flex Drill Collars (93.45'), XO sub (1.65'), 3 Jnts 4" HWDP (90.89'), 4 3/4" Drilling Jars (28.88'), 2 Jnts 4" HWDP (60.57'. Total BHA = 376.59' Trip in hole picking up 63 joints of 4" Drill Pipe from shed. Continue RIH with DP from derrick to tag cement @ 5278' DPM. Circulate DP Volume. Clean i;< clear rig floor area while finish up circulating @ 70 SPM -1300 PSI. PU WT = 94K, SO WT = 76K. PJSM with crew. Discuss Safety Issues and procedure to slip & cut drilling Line from new spool. Perform Hazrd Recognition analysis. Slip and cut 1600' of drilling line. Rig Up and perform 7 5/8" casing test to 3000 PSI. record on chart 30 minutes. Drill cement stringers form 5278' -5302' (24'). Tag 7 drill out Float collar ! @ 5302, and continue to wash & ream down to 5329'. Crew Change !Continue wash & ream down to Float Shoe 5391'. Drill Flaot shoe and ~! 20' of new hole to 5416'. Circulate & condition mud for LOT until balanced at 8.9 PPG IN /OUT. ~', Stand 1 stand back. Perform LOT to 15.3 PPG EMW @ 5416 MD, 3684' TVD. 8.9 PPG, YP 18, VISC = 83 Downlink Periscope tool -establish baseline ECD @ 9.94 PPG with 310 GPM's -120 RPM's, 9.96 PPG with 140 RPM's. Obtain Slow pump rates @ 25 SPM - 330 PSI, 35 SPM - 480 PSI. 5422 MD 3684 TVD. Attempt to down link tool, tool not responding, repeated attempts to observe tool respond. Drill 6 3/4" hole in the A Lateral from 5419' - 6077' (658'). MD. TVD = 3709'. ART = 4.51 HRS, PU WT = 103K, SO WT = 73K, ROT WT = 85K. Torque on/off bottom = 2.5K. Pumps - 315 GPM's - 2300 PSI. RPM's = 100-150. WOB = 2-15K. Total Bit HRS = 4.51 HRS. Total Jar ',HRS = 72.41. Mud Wt = 8.9 PPG, Visc = 83,YP = 18, Gels @ 21 / 28. 'Survey @ 6011' MD, 3712' TVD, 91.92 Deg INC, 358.02 Deg AZ ii Continue Drill 6 3/4" hole in the Undulating A Lateral from 6077 - 6391' !! (315'). MD. TVD = 3700'. ART = 3.17 HRS, PU WT = 98K, SO WT = 75K, ROT WT = 86K. Torque on/off bottom = 3K. Pumps - 315 GPM's - 2400 PSI. RPM's = 100-150. WOB = 2-10K. Mud Wt = 8.9 PPG, Visc = 83,YP = 18, Gels @ 21 ! 28. Survey @ 6387' MD, 3698' TVD, 95.67 Deg INC, 2.34 Deg AZ Stop Drilling for Geology Conference call. Continue Drill 6 3/4" hole in the Undulating A Lateral from 6391' - 6745' (354'). MD. TVD = 3697'. ART = 5.95 HRS, PU WT = 98K, SO WT = 75K, ROT WT = 86K. Torque on/off bottom = 3K. Pumps - 315 GPM's - 2400 PSI. RPM's = 100-150. WOB = 2-10K. Total Bit HRS = 10.56 HRS. Total Jar HRS = 78.36. Mud Wt = 8.85 PPG, Visc = 74,YP = 18, Gels @ 21 / 28. Survey @ 6666' MD, 3696' TVD, 89.49 Deg INC, 3.08 Deg AZ. ECD = 10.30 PPG, Max gas = 132 Units. Observed drilling through concretions from 6238' -6241' (3'), 6317'-6321'(4'), 6371'-6373' '~ (2'), 6471'-6476' (5'), and 6501'-6503' (2'). Obtain Slow pump rates @ 1.6745' MD, 3697 TVD. Pump #1 - 25 SPM - 380 PSI, 35 SPM - 520 PSI. ;Pump #2 - 25 SPM - 390 PSI, 35 SPM - 540 PSI. Printed: 2(7/2006 10:40:10 AM ConocoPhillips Alaska .Operations Summary Report Legal Well Name: 1J-101 Common Well Name: 1J-101 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Date 12/16/2005 12/17/2005 Doyon 141 From - To ', Hours '~ Code 'Code Phase 12:00 - 00:00 ~ 12.00 ~ DRILL ~ DRLG ~ PROD 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 13:15 1.25 DRILL ~ ~ DRLH ~ I, PROD 13:15 - 14:30 i L25~ DRILL OTHR PROD 14:30 - 16:30 2.00 DRILL DRLH PROD 16:30 - 00:00 i 7.50! i DRILL DRLH i PROD 12/18/2005 00:00 - 10:00 I, j 10.00 I DRILL DRLH PROD , 10:00 - 12:00 2.00 DRILL ! DRLH ,PROD 12:00 - 00:00 12.00 DRILL DRLH PROD Start: 12/6/2005 Rig Release: 1/7/2006 Rig Number: Page 10 of 22 Spud Date: 12/6/2005 End: 1/7/2006 Group: ', Description of Operations Continue Drill 6 3/4" hole in the Undulating A Lateral from 6745' - 7787'(1042'). MD. ND = 3763'. ART = 6.34 HRS, PU WT = 110K, SO ' WT = 70K, ROT WT = 89K. Torque on/off bottom = 3.5K. Pumps - 315 GPM's - 2700 PSI. RPM's = 100-150. WOB = 2-10K. Total Bit HRS = 16.90 HRS. Total Jar HRS = 84.70. Mud Wt = 8.8 PPG, Visc = 74,YP = 18, Gels @ 21 / 28. Survey @ 7600' MD, 3734' TVD, 84.78 Deg INC, 2.18 Deg AZ. ECD = 10.59 PPG, Max gas = 119 Units. Observed ;drilling through concretions from 6714'-6717' (3'), and 6867'-6873' (5'). 'Obtain Slow pump rates @ 7568' MD, 3729 TVD. Pump #1 - 25 SPM - 410 PSI, 35 SPM - 610 PSI. Pump #2 - 25 SPM - 420 PSI, 35 SPM - 570 PSI. Total K-Revs for day (Sliders) = 63310 Continue Drill 6 3/4" hole in the Undulating A Lateral from 7787'- 8803' (1016'). MD. TVD = 3722'. ART = 6.92 HRS, PU WT = 108K, SO WT = 70K, ROT WT = 86K. Torque on/off bottom = 3.5K. Pumps - 320 GPM's - 2500 PSI. RPM's = 100-150. WOB = 4-7K. Total Bit HRS = 23.82 HRS. Total Jar HRS = 91.62. Mud Wt = 8.8 PPG, Visc = 71,YP = 18, Gels @ 17 / 26. Survey @ 8719' MD, 3721' TVD, 89.31 Deg INC, 357.75 Deg AZ. ECD = 10.77 PPG, Max gas = 136 Units. Observed drilling through concretions from 8362'-8370' (8'), 8376'-8385' (9'), and 8494'-8498' (5'). Obtain Slow pump rates @ 8690' MD, 3721 TVD. Pump #1 - 20 SPM - 360 PSI, 30 SPM - 520 PSI. Pump #2 - 20 SPM - 380 PSI, 30 SPM - 530 PSI. Continue drilling from 8803' - 8877' MD. TVD =3727. ADT =.69 HRS., and same parameters as above. Observed a dogleg of 16.4 Degrees. 0~ lC~ ~ Stand back Drill pipe pulling back-887T - 8599'. (278'). Circulate & ~`~ reciprocate drill string while conference with town. `.~ Down link tool while cutti~ trough from 8600' -8620'.. Toolface @ 161 degrees at 100%. Pumps @ 275 GPM's - 2100 PSI. 130 RPM's w/ 3.5K torque. WOB = 0-1 K. Perform Open hole sidetrack from>a620' $2' {12'). AVG ROP = 1-3 FT / HR. ADT = 6.36 HRS. Time drill for 1' - 1 HR. 4' -2 HRS. 7' -3 HRS. PU WT = 115K, SO WT = 65K, ROT WT = 92K. 130 RPM's. ECD's @ 10.70 PPG. Max Gas = 105 Units. Total Jar HRS = 100.8. Total Bit HRS = 30.87. Pumps @ 275 GPM's - 77 SPM - 2100 PSI. 'Observe inclination slightly dropping from 89.45 Degrees to 89.35 ', Degrees. NOTE:Inclination = T behind bit. Total K-Revs for sliders = 77709 Continue Perform Open hole sidetrack from 8636' - 8690' (54'). ADT = 9.8 HRS. Control Drill @ 3 FT/HR from 8636' -8678', 20 FT / HR from 8678' - 8690'. PU WT = 115K, SO WT = 65K, ROT WT = 92K. 130 RPM's. ECD's @ 10.62 PPG. Max Gas = 84 Units. 316 GPM's - 77 SPM - 2600 PSI. Observe inclination dropping from 89.45 Degrees to 87.37 indicating getting sidetracked. NOTE:Inclination = 7' behind bit. Continue Drill 6 3/4" hole in the Undulating A Lateral from 8690' -8704' (14') MD. TVD = 3722'. ART = 1.14 HRS. ART = 10.94 Total HRS, PU i WT = 108K, SO WT = 70K, ROT WT = 87K. Torque on/off bottom = 4K. Pumps - 316 GPM's - 2600 PSI. RPM's = 100-160. WOB = 1-5K. Total Bit HRS = 41.81 HRS. Total Jar HRS = 109.27 Mud Wt = 8.85 PPG, Visc = 72,YP = 18, Gels @ 18 / 28. ECD = 10.66 PPG, Max gas = 46 Units. Obtain Slow pump rates @ 8690' MD, 3722 TVD. Pump #1 I - 20 SPM - 350 PSI, 30 SPM - 500 PSI. Pump #2 - 20 SPM - 360 PSI, 30 SPM - 490 PSI. Continue Drill 6 3/4" hole in the Undulating A Lateral from. 8704'-9253' Printed: 2!7/2006 10:40:10 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-101 Common Well Name: 1J-101 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To ' Hours ' Code ' `Sub ~_ - ~ -Code'. 12/18/2005 12:00 - 00:00 j 12.00 DRILL DRLH 12/19/2005 12/20/2005 12/21 /2005 00:00 - 12:00 12:00 - 00:00 00:00 - 08:15 08:15 - 11:00 11:00 - 15:15 15:15 - 18:45 18:45 - 00:00 00:00 - 00:30 00:30 - 02:00 12.001 DRILL I DRLH 12.001 DRILL i DRLH 8.251 DRILL DRLH 2.75 DRILL CIRC 4.25, DRILL ' WIPR 3.50 DRILL ( CIRC 5.251 DRILL TRIP 0.50; DRILL TRIP 1.50 i DRILL PULD 02:00 - 02:30 0.50 ~ DRILL OTHR 02:30 - 03:30 , 1.00 ~ DRILL OTHR 03:30 - 04:00 0.50 CASE 1 RURD 04:00 - 09:00 5.001 CASE ~ PULR Start: 12/6/2005 Rig Re{ease: 1/7/2006 Rig Number: Page 11 of 22 Spud Date: 12/6/2005 End: 1 /7/2006 Group: Phase Description of Operations PROD (549') MD. ND = 3720'. ART = 7.63 HRS, PU WT = 117K, SO WT = 62K, ROT WT = 92K. Torque on/off bottom = 4.5K. Pumps - 330 GPM's j- 3000 PSI. RPM's = 100-150. WOB = 2-10K. Total Bit HRS = 49.44 HRS. Total Jar HRS = 110.60. Mud Wt = 8.85 PPG, Visc = 72,YP = 18, Gels @ 18 / 29. Survey @ 9187 MD, 3720' TVD, 90.34 Deg INC, i 1.71 Deg AZ. ECD = 11.09 PPG, Max gas = 84 Units. Obtain Slow pump rates @ 9250' MD, 3720 TVD. Pump #1 - 20 SPM - 350 PSI, 30 SPM - 500 PSI. Pump #2 - 20 SPM - 360 PSI, 30 SPM - 490 PS1. Total K-Revs for sliders today = 123100 HRS. PROD 1 Continue Drill 6 3/4" hole in the Undulating A Lateral from 9253' - 10216' (963') MD. ND = 3777'. ADT = 5.83 HRS, PU WT = 125K, SO WT = 60K, ROT WT = 86K. Torque on/off bottom = 4.5K. Pumps - 323 GPM's - 2900 PSI. RPM's = 100-150. WOB = 3-6K. Total Bit HRS = 55.27 HRS. Total Jar HRS = 116.43. Mud Wt = 8.85 PPG, Visc = 70,YP = 18, Gels @ 18 / 28. Survey @ 10026' MD, 3756' TVD, 84.64 ~ Deg INC, 352.16 Deg AZ. ECD = 11.24 PPG, Max gas = 226 Units. Obtain Slow pump rates @ 10091' MD, 3759 TVD. Pump #1 - 20 SPM - 400 PSI, 30 SPM - 550 PSI. Pump #2 - 20 SPM - 400 PSI, 30 SPM - 570 PSI. PROD Continue Drill 6 3/4" hole in the Undulating A Lateral from 10216' - 11020' (804') MD. TVD = 3807'. ADT = 7.73 HRS, PU WT = 155K, SO WT = 60K, ROT WT = 110K. Torque on/off bottom = 5.5K. Pumps - 310 GPM's - 3250 PSI. RPM's = 100-150. WOB = 2-10K. Total Bit HRS = 63.00 HRS. Total Jar HRS = 124.16 Mud Wt = 8.85 PPG, Visc = 70,YP = 18, Gels @ 18 ! 28. Survey @ 10935' MD, 3806' TVD, 91.47 Deg INC, 1.48 Deg AZ. ECD = 11.24 PPG, Max gas = 126 Units. Obtain Slow pump rates @ 10980' MD, 3807 TVD. Pump #1 - 25 SPM - 620 PSI, 35 SPM - 730 PSI. Pump #2 - 25 SPM - 590 PSI, 35 SPM - 780 PSI. Total K-Revs for sliders today = 134632 HRS. PROD .Continue Drill 6 3/4" hole in the Undulating A Lateral from 11020' - 11510' (490') MD. TVD = 3817'. ADT = 4.0 HRS, PU WT = 160K, SO WT = 70K, ROT WT = 105K. Torque on/off bottom = 6000/5000 fUlb. ',Pumps - 323 GPM's - 3800 PSI. RPM's = 135, WOB = 3-6K. ECD = ,11.26 PPG, Max gas = 76 Units. Total K-Revs for sliders today = 90742 HRS. PROD ,Pump Weighted Hi-vis sweep &circ hole clean at rate of 323 gpm @ 3800 psi and 160 RPM, Had 40% Increase w/ sweep, Monitor well. PROD i POOH on elevators f/ 11510' to 8600' with no problems, RIH to 11510'- ~~ OK. PROD ~ Pump Weighted Hi-vis sweep &circ btm's up at rate of 320 gpm @ 13900 psi and 160 RPM, Change over to SFOBM. PROD 1~ Monitor well, Drop 1.9" rabbit, POOH on elevators with no problems f/ 11510' to 3180' at midnight. PROD ~ Continue to POOH to BHA. PROD Lay down Schlumberger BHA, Flex DC's, Float sub, MWD, Periscope, 'Bit. CMPLTN 'Clear & Clean rig floor. CMPLTN Rig down Schlumberger sensor's on stand pipe, Drawworks, ect. CMPLTN Rig to run 4-1/2" liner. CMPLTN Pick up 4 1/2" L80, 12.6# IBT slotted !blank liner assembly and RIH. Make up torque =3000 FUlbs. Run liner as per detail. MU Blank joint with ROT Silver Bullet Guide shoe and pup. Continue with blanks and slots space out as per engineer, Run 215 Jnts = 6672.65', with 17 Printed: 2/7/2006 10:40:10 AM ConocoPhillips Alaska ~perations'Summary Report Legal Well Name: 1J-101 Common Well Name: 1J-101 Event Name: ROT -DRILLING Start: 12/6/2005 Contractor Name: n1334@ppco.com Rig Release: 1/7/2006 Rig Name: Doyon 141 Rig Number: Page 12 of 22 Spud Date: 12/6/2005 End: 1 /7/2006 Group: Date 'From - To ~ Hours ' Cade ' Sub ~' Phase I' Description of Operations _ _ Code 12/21/2005 04:00 - 09:00 ~ 5.00' CASE ~ PULR ~ CMPLTN ~ constrictor packers and Spiral glider centralizers floating on each jnt except the Constrictor packer jnts. (174 total) 09:00 - 09:45 0.75 CASE PULR CMPLTN Make up XO Bushing, Casing Seal Bore Ext, Flexlock Liner Hanger, RS I Packoff Seal nipple, and HRD ZXP Liner Top PKR, with BOT running 'tools. Total 8HA length of liner assembly = 6728.88'. PU WT = 95K, SO WT = 55K. 09:45 - 13:30 3.75: CASE RUNL CMPLTN ~ Continue RIH with Liner on Drill Pipe from 6728' - 11259' with no problems. 13:30 - 14:45 1.25 CASE DEQT CMPLTN Wash down f/ 11259' to 11335', Up 150K, Dn 82K, Drop 1 1/2" ball, Position liner w/ shoe @ 11330' & top of liner @ 4601.12', Circ ball i down w/ 500 stks and pressure up to 1500 PSI. Set down 55K to set slips as per BOT rep, continue pressure up to 4000 PSI, to complete setting PKR. Bleed pressure, Rig up and pressure test down annulus to ~ test PKR at 1000 PSI - 10 Minutes. Blow down Top Drive and Kill Line. I 'Monitor well -Static. 14:45 - 17:30 2.75 DRILL TRIP CMPLTN POOH & Lay down liner running tools. 17:30 - 18:00 0.50 DRILL OTHR CMPLTN Clear & clean rig floor, Pull wear bushing. 18:00 - 00:00 ~ 6.00' WELCT I BOPE CMPLTN ~ Rig & test BOPS to 250 psi low & 3500 psi high, Rig down test equip., Set wear bushing, I~OGCC Jahn Crisp witnessed t®st. 12/22/2005 00:00 - 01:45 1.75 RIGMNT RSRV CMPLTN Service top drive, Change out saver sub. 01:45 - 04:00 2.25 ~ WINDO ULD PROD2 ,Pick up whipstock tools to floor, Thaw & make up same, Pick up MWD 04:00 - 05:00 05:00 - 06:00 06:00 - 08:30 08:30 - 09:00 09:00 - 09:30 09:30 - 10:15 10:15 - 10:30 ~,Q~3Q - 12:00 12:00 - 15:30 15:30 - 16:30 ~ 16:30 - 19:00 19:00 - 20:45 i 20:45 - 23:00 23:00 - 00:00 12/23/2005 ' 00:00 - 00:45 00:45 - 01:30 01:30 - 03:30 03:30 - 04:30 04:30 - 04:45 04:45 - 10:15 10:15 - 10:45 10:45 - 13:30 1.00 1.00, 2.50 ~ 0.50 0.50 ~ 0.75 0.25 1.50 WINDO WINDO WINDOV~ WINDO WINDOW WINDO WINDO WINDO ULD IRC ITRIP ~ THR CIRC RIP ETW IRC PROD2 PROD2 PROD2 ' PROD2 PROD2 PROD2 ' PROD2 PROD2 & Orient same to slide. Plug in & program MWD. Pick up DC's, Surface test MWD tools. RIH to 3,452', Filled pipe @ 2998' 280 gpm @ 1500 psi. MWD Detection problems. MADD pass K-13 f/ 3,452' to 3,550'. ~, n Continue RIH to 4,601'. Orient whipstock to 8 degrees left of highside, Shear off bolt. , ~" Circ & Chan a over to 8.7 MOBM. 3.50 WINDO TWP ~ PROD2 ' Mill window f/ 4507' to 4519', 16' of new hole f/ 4519' to 4535' with 5' of guage hole, WOB 2/5K, 65 to 105 RPM, 275 gpm @ 1850 psi. 1.00 WINDO IRC PROD2 Work thru window several times, Pump sweep &Circ hole clean at rate I ~, of 320 gpm @ 2500 psi. 2.50 WINDOV ~TRIP PROD2 Observe well, Pump dry job, POOH to BHA. 1.75 WINDO ULD PROD2 Down load MWD, Lay down BHA & Mills (6-3l4" mill in guage), Note; ,Found pieces of wood on top MWD. 2.25 DRILL OTHR PROD2 ; Clear & Clean rig floor, Pull wear bushing, Make up flushing tool & flush stack, Install wear bushing, Clear floor. 1.00, DRILL ~ PULD PROD2 Pick up Sperry-Sun mud motor & adjust to 1.76 deg, Make up bit. 0.75 DRILL PULD PROD2 .Plug in and program MWD tools. 0.75 DRILL PULD PROD2 Continue to pick up BHA, NMDC's, HWDP, Jars. 2.00 I DRILL TRIP PROD2 RIH removing 51 supersliders f/ 17 stands, Pick up 4- 4" test Lo-Tad's, i Fill pipe & test MWD. 1.00 DRILL TRIP PROD2 ' RIH to 4494', Fill pipe, Test MWD, Orient to 8 deg. left. 0.25 DRILL REAM PROD2 Go thru window @ 4507' to 4519' with no problem, Wash & ream f/ 4522' to 4535'. 5.50 DRILL DRLH PROD2 ' Drill 6-3/4" w/mud motor w/ 1.76 deg AKO f/ 4535' to 4653' MD 3536' TVD (118), ADT= 3.78 hrs, ART= 1.74 hrs, AST= 2.04 hrs, WOB 5-20K, 50 RPM, 291 gpm @ 2250 psi, Up 92K, Du 80K, Rot 85K, TO I on/off 4/3K, ECD 9.74 ppg, Max gas 72 units. 0.50 DRILL CIRC PROD2 Circ btm's up. 2.75 ~ DRILL ; TRIP I PROD2 Monitor well, Pump dry job, POOH to MWD. Printed: 2/72006 10:40:10 AM - ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-101 Common Well Name: 1J-101 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date 12/23/2005 From = To I Hours I Code i Code ' Phase 13:30 - 14:00 j 0.501 DRILL OTHR 14:00 - 15:00 1.00 DRILL PULD 15:00 - 16:15 ' 1.25 DRILL PULD 16:15 - 17:15 1.00 DRILL OTHR 17:15 - 18:30 1.25 DRILL ~ PULD 18:30 - 20:15 I 1.75 DRILL ! TRIP 20:15 - 21:30 1.25 RIGMNT RSRV 21:30 - 21:45 0.25 DRILL TRIP 21:45 - 22:30 , 0.75 DRILL ' REAM 22:30 - 00:00 ~ 1.50 { DRILL DRLH 12/24/2005 100:00 - 12:00 I 12.001 DRILL I DRLH 12:00 - 00:00 12.00 DRILL I DRLH 12/25/2005 100:00 - 12:00. 12.00 i DRILL I DRLH 12:00 - 16:45 16:45 - 17:30 17:30 - 00:00 12/26/2005 100:00 - 01:30 4.751 DRILL I DRLH 0.751 DRILL CIRC 6.50 i DRILL DRLH PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 1.50 ! DRILL !DRLH I PROD2 Page 13 of 22 Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number: Description of Operations Down load MWD. Lay down MWD, Motor & bit. Make up bit, GeoPilot, MWD tools. Change out GR/RES, Porgram MWD tools. Continue to pick up BHA, Float sub, Stab, NMDC's, Surface test MWD tools. RIH to 4472'. Slip & Cut drilling line 70', Service top drive. RIH to 4600'. MADD Pass f/ 4600' to 4653' 300 gpm @ 1975 psi. Drill 6-314" hole w/ GeoPilot f/ 4653' to 4719' MD 3522' TVD (66'), ADT= .72 hrs, WOB 5-15, 75 RPM, 300 gpm @ 2025 psi, Up 92K, Dn 80K, Rot 86K, TO on/off 2l2.5K. Directional drill 6 3/4" hole in 'B' sand lateral with Geo-pilot assembly from 4,719' to 6,056' MD/3,568' ND (1,337') ADT 8.7 hrs, 2-15K wob, 140 rpm's, 89 spm, 316 gpm @ 2400 psi, on btm torque 3.OK ft-Ibs, off btm 2.OK ft-Ibs, Up wt 95K, Dn wt 75K, Rot wt 86K, 8.85 ppg MOBM, ave ECD 10.1 ppg, ave BGG 35 units, max gas 112 units, drilled concretions f/ 4846' to 4855', 4903' to 4919', 5477' to 5480'. Directional drill 6 3!4" hole in 'B' sand lateral with Geo-pilot assembly from 6,056' to 7,560' MD/3,557' TVD (1,504') ADT 8.02 hrs, 4-15K wob, 140 rpm's, 92 spm, 327 gpm @ 2700 psi, on btm torque 4.5K ft-Ibs, off btm 4.OK ft-Ibs, Up wt 104K, Dn wt 65K, Rot wt 85K, 8.85 ppg MOBM, ave ECD 10.44 ppg, ave BGG 45 units, max gas 127 units, drilled concretions f/ 6164' to 6166', 6489' to 6495', 6541' to 6545', 6611' to 6612', 6658' to 6664', 6930' to 6935', 7111' to 7112', 7119' to 7121', 7153' to 7163', 7546' to 7553'. Directional drill 6 3/4" hole in 'B' sand lateral with Geo-pilot assembly from 7,560' to 8,788' MD/3,597' TVD (1,228') ADT 8.29 hrs, 3-6K wob, 140 rpm's, 93 spm, 330 gpm @ 2900 psi, on btm torque 5.OK ft-Ibs, off btm 4.OK ft-Ibs, Up wt 110K, Dn wt 60K, Rot wt 86K, 8.85 ppg MOBM, ave ECD 10.85 ppg, ave BGG 45 units, max gas 123 units, drilled concretions f/ 8177'-80', 8427'-29', 8435'-41'. Directional drill 6 3!4" hole in 'B' sand lateral with Geo-pilot assembly from 8,788' to 9,260' MD/3,595' TVD (472') ADT 3.85 hrs, 5-15K wob, 140 rpm's, 92 spm, 327 gpm @ 2950 psi, on btm torque 6.OK ft-Ibs, off btm 4.OK ft-Ibs, Up wt 120K, Dn wt 55K, Rot wt 85K, 8.85 ppg MOBM, ave ECD 10.9 ppg, ave BGG 45 units, max gas 123 units, drilled concretions f/ 8833'-55', 8905'-10', 8949'-58', 9162'-63', 9176'-79', 9195'-98', 9207'-10', 9233'-36'. Rack back 1 stand drill pipe, Circ for Geology at rate of 327 gpm @ 3000 psi, 140 RPM, TO 5000 ft/Ib. Directional drill 6 3/4" hole in 'B' sand lateral with Geo-pilot assembly from 9,260' to 9,816' MD/3,605' TVD (556') ADT 4.63 hrs, 5-15K wob, 140 rpm's, 92 spm, 327 gpm @ 3025 psi, on btm torque 6.OK ft-Ibs, off btm 5.5K ft-Ibs, Up wt 122K, Dn wt 48K, Rot wt 85K, 8.80 ppg MOBM, ave ECD 11.13 ppg, ave BGG 45 units, max gas 126 units, drilled concretions f/ 9358'-70', 9439'-50', 9528'-30', 9540'-42', 9621'-22', 9678'-87'. Directional drill 6 3/4" hole in 'B' sand lateral with Geo-pilot assembly from 9,816' to 10,047' MD/3,621' TVD (231') ADT 1.36 hrs, 10-15K wob, 140 rpm's, 92 spm, 327 gpm @ 3050 psi, on btm torque 6/9.OK ft-Ibs, off btm 6.OK ft-Ibs, Up wt 130K, Dn wt 45K, Rot wt 86K, 8.80 ppg Printed: 2f//2006 10:40:10 AM ConocoPhillips`Alaska Opera#ions Summary Report Legal Well Name: 1J-101 Common Well Name: 1J-101 Event Name: ROT -DRILLING Start: 12/6/2005 Contractor Name: n1334@ppco.com Rig Release: 1/7/2006 Rig Name: Doyon 141 Rig Number: Date ~ From - To 'Hours ' Code ' Phase Code L 12/26/2005 00:00 - 01:30 1.50 DRILL DRLH PROD2 01:30 - 01:45 i 0.25 DRILL ~ CIRC PROD2 01:45 - 05:45 4.00; DRILL DRLH PROD2 ; I 05:45 - 06:45 1.00 DRILL 'CIRC PROD2 06:45 - 07:15 0.50 DRILL ,TRIP PROD2 07:15 - 08:30 1.25.. DRILL REAM PROD2 08:30 - 10:30 2.00 DRILL 'DRLH PROD2 10:30 - 13:45 3.25 DRILL ~ DRLH I PROD2 i 13:45 - 00:00 ' 10.25 DRILL DRLH ' PROD2 12/27/2005 I 00:00 - 02:30 i 2.50 DRILL DRLH ~ I PROD2 i I 02:30 - 02:45 0.251 DRILL SURV ~ PROD2 02:45 - 04:15 ~ 1.50 DRILL CIRC ; PROD2 ~ 04:15 - 04:30 0.25 DRILL SURV PROD2 04:30 - 12:00 7.50: DRILL WIPR PROD2 i 12:00 - 16:00 i 4.00 DRILL ~ WIPR PROD2 ~i 16:00 - 17:15 1.25 DRILL i CIRC , i PROD2 Page 14 of 22 Spud Date: 12/6/2005 End: 1 /7/2006 Group: Description of Operations MOBM, ave ECD 11.13 ppg, ave BGG 45 units, max gas 126 units, 'drilled concretions f/ 9955'-5T. Circ for Geology at rate of 327 gpm @ 3200 psi, 140 RPM. Directional drill 6 3/4" hole in 'B' sand lateral with Geo-pilot assembly from 10,047 to 90,415' MD/3,612' TVD (368') ADT 2.96 hrs, 5-15K wob, ;140 rpm's, 92 spm, 327 gpm @ 3300 psi, on btm torque 7.OK ft-Ibs, off btm 6.OK ft-Ibs, Up wt 125K, Dn wt 45K, Rot wt 87K, 8.85 ppg MOBM, ave ECD 11.10 ppg, ave BGG 45 units, max gas 125 units, drilled ~~- ' concretions f/ 10048'-61', 10072'-80', 10176'-91'. Rack back 1 stand drill pipe, Circ for Geology at rate of 327 gpm @ '3300 psi, 140 RPM. Back ream out to 10,099' for sidetrack. !,Trough f/ 10,099' to 10,115' at rate of 327 gpm @ 3300 psi, 140 RPM to sidetrack well. (Time drill f/ 1®,'t15'to 10,134' MD/3622' TVD (19'), ADT 1.87 hrs, 313 'gpm @ 2900 psi, 140 RPM. Directional drill 6 3/4" hole in 'B' sand lateral with Geo-pilot assembly from 10,134' to 10,415' MD/3,630' TVD (281') ADT 2.27 hrs, 5-15K wob, 140 rpm's, 92 spm, 327 gpm @ 3150 psi, on btm torque 6.5K ft-Ibs, off btm 5.5K ft-Ibs, Up wt 135K, Dn wt OK, Rot wt 90K, 8.80 ppg MOBM, ave ECD 11.27 ppg, ave BGG 45 units, max gas 125 units, drilled concretions ff 10260'-63', 10274'-77'. Directional drill 6 3/4" hole in 'B' sand lateral with Geo-pilot assembly from 10,415' to 11,366' MD/3,682' TVD (951') ADT 8.77 hrs, 4-12K wob, 140 rpm's, 93 spm, 330 gpm @ 3700 psi, on btm torque 7.OK ft-Ibs, off btm 7.OK ft-Ibs, Up wt 155K, Dn wt 48K, Rot wt 102K, 8.85 ppg MOBM, ,ave ECD 11.5 ppg, ave BGG 45 units, max gas 126 units, drilled concretions f/ 10465'-78', 10528'-48', 10585'-94', 10603'-07', 10681'-10700, 10812'-16'. K-rev's 15963. Directional drill 6 3/4" hole in 'B' sand lateral with Geo-pilot assembly .from 11,366' MDto 11,645' MD/3,703' TVD (279') ADT 2.17 hrs, 3-12K wob, 140 rpm's, 93 spm, 330 gpm @ 4000 psi, on btm torque 8.OK ft-Ibs, off btm 7.OK ft-Ibs, Up wt 165K, Dn wt 55K, Rot wt 110K, 8.85 ppg MOBM, ave ECD 11.71 ppg, max gas 82 units, drilled concretions f! 11,400'-10', 11,446'-60', ' 11,638'-45'. MWD detection trouble. No survey @ TD garnered. Try again after sweep. Pumped weighted hi-vis sweep w/ 93 stk/min (330 GPM), 4000 psi, and ~ 140 rpm. Garnered survey at TD. SPR @ TD, checked flow (static). BROOH from 11,645' to 7,850'. 'Tried to POOH w/ 40-50K overpull, cont'd to BROOH. PUW=165K SOW=55K ROT=85K TO=7K @ 100 rpm. SPR #1=20stk/580psi, 30stk/700psi SPR #2=20stkf590psi, 30stk/710psi @ 11,645' MD/3,702' TVD 8.8#MW • BROOH from 7,850' to 6,157 w/ 93 spm (330 gpm), 140 rpm, TQ=4K. (Attempted to pull on elevators w/ 15-20K overpull and swabbing. Cont'd to BROOH to 4,590'. Pulled to 4,476'. Pumped 30 bbl weighted hi-vis sweep @ 4,476' w/ 93 spm (330 gpm), 2300 psi, 140 rpm, TO=3K PUW=93K SOW=76K ROT=85K Observed 50% increase in cuttings. ~h L~.. l Printed: 2f7/2006 10:40:10 AM ConocoPhillips Alaska 'Page 15'of 22 Operations Summary Report Legal Well Name: 1 J-101 Common W ell Name: 1 J-101 Spud Date: 12/6/2005 Event Nam e: ROT -DRILLING Start: 12/6/2005 End: 1/7/2006 Contractor Name: n 1334@ppco.co m Rig Release: 1/7/2006 Group: Rig Name: Doyon 141 Rig Number: ' ~' ' sub ' Date From - To Hours ~ Code I ! Code Phase Description of Operations 12/27/2005 17:15 - 20:15 3.00 DRILL WIPR PROD2 TIH from 4,476' to 9,686'. No slack off weight @ 9,686'. ~ 20:15 - 23:00 2.75 DRILL : WIPR PROD2 ,Washed and reamed from 9,686' to 11,645' w/ 75 spm (266 gpm), 140 i 'rpm, TO=5.5K. 23:00 - 00:00 1.00, DRILL CIRC PROD2 Pumped 30 bbls weighted hi-vis sweep w/ 89 spm (316 gpm), 140 rpm, ! ' 3900 psi, TO=7K. Krevs=85389. 12/28/2005 00:00 - 01:30 1.50 ~ DRILL CIRC PROD2 Cont'd circ. sweep and 3 B/Us for total 12,000 stks w/ 92 spm, 4000 ~ ~ ' psi. 01:30 - 02:45 1.25 DRILL CIRC PROD2 Displace well to SFOBM w! 92 spm, 4100 psi, 140 rpm. 02:45 - 03:15 0.50 DRILL TRIP PROD2 i Garnered SPRs, checked flow (static), B/D top drive, and drop 1-7/8" rabbit. ~ SPR #1=20stk/440psi, 30 stk/670psi 'SPR #2=20stk/440psi, 30 stk/660psi @ 11,645' MD/ 3,702' TVD 8.8MW 03:15 - 09:15 6.00 DRILL TRIP PROD2 POOH from 11,645' to window @ 4,507' w! 10-20K overpull. Pulled ,,from window to BHA @ 369'. PUW=165K SOW=50K 09:15 - 09:30 0.251 DRILL ; PULD PROD2 ,Rack back HWDP, jars, NM DCs. UD stab, float sub. 09:30 - 10:30 1.00 DRILL OTHR , PROD2 'Plugged in and downloaded MWD. 10:30 - 11:30 1.00 DRILL PULD PROD2 UD TM HOC, PWD, Slimphase 4 w/ DGR, smart stab, DM HOC, NM ' .pony collar, Geo-Pilot and bit. 11:30 - 12:00 0.50 DRILL PULD ~ CMPLT2 Cleared and cleaned rig floor. 12:00 - 12:45 0.75 WINDO ULD CMPLT2 P/U and M/U whipstock retrieval BHA w/ 1jt HWDP, bumper, oil jars, 12:45 - 15:00 2.25 WINDOV~ ITRIP XO, 3 stds hybrid DP. CMPLT2 TIH from 329' to 4,497. PUW=120K SOW=105 15:00 - 15:30 ~ 0.50 WINDOV~ ITRIP CMPLT2 Turn 1/4 turn 7 times to engage fish. Wash slot, hook slot. Pulled ' ! 200K to fire jars; fish freed. Pulled up to 4,413' w/ PUW=126K. 15:30 - 16:00 ! 0.50 WINDO IRC CMPLT2 ~ Circa BU w/ 85 spm (302 gpm), 1900 psi. 16:00 - 18:45 2.75 WINDO RIP CMPLT2 POOH from 4,413' to 298' (Fill actual=44, Calculated=43). ~ Dropped 1.75" drift. 18:45 - 20:15 1.50 WINDOV~ IPULD CMPLT2 ' UD XO, jars, bumper, 1 jt 3.5" HWDP, hook, whipstock, debris sub, drain sub, shear disconnect, B/T anchor, blank sub, 2 jts 3.5" DP, unloader sub and seals. Removed BHA from rig floor. 20:15 - 20:45 0.50 CASE I RURD CMPLT2 R/U to run 4.5" liner. 20:45 - 00:00 ~ 3.25 CASE RUNC , CMPLT2 Held PJSM. Ran 4.5" liner to jt #115 as per detail. PUW=68K SOW= 69K. 12!29!2005 00:00 - 03:00 3.00 CMPLTN RUNT CMPLT2 Cont'd to run 4.5" liner from jt #115 to TD @ jt #228. Tagged lower "A" 'lateral XO bushing @ 4,650' w/ jt #150. Pulled up and re-oriented, bent sub through window @ 4,507 on 2nd try. Ran total of 31 jts blank pipe ~ (957.4'), and 197 jts slotted liner (6,095.4'). 03:00 - 04:30 1.50, CMPLTN, RUNT CMPLT2 PJSM. Discuss safety issues and procedure for making up Slim Hole ! ~ MWD assmy. Make up Baker Model B1 FHH Hook Hanger assembly, ,pups, with crossover joint, Casing Swivel, running and setting tools. Make up Ball seat shear sub and Slimhole MWD assembly, oriented 180 DEG from Hook on hanger. 04:30 - 05:00 0.50 CMPLTN! RUNT CMPLT2 M/U 1 std 4" DP @ 7,225'. Pulse tested MWD w/ 110 gpm @ 550 psi. Blew down TD. 05:00 - 08:30 3.50 ~ CMPLTN, TRIP CMPLT2 '~ Cont'd to run liner in hole on DP from 7,225' to 11,618'. ! 08:30 - 09:45 ! ~ 1.25 CMPLTN OTHR PUW=185K SOW=60K CMPLT2 ,Orient to 8 Degrees left of high side, slack off to liner depth at 11.619'. Hook window, MWD @ 19 degrees right of high side. PU and re-hook to check orientation still 19 degrees right. Picked up and orient 180 i j degrees out and slack off to RIH past bottom of window to liner depth of Printed: 2!7/2006 10:40:10 AM ConocOPhiNips Alaska, - Page 1 s of 22 Operations Summary Report Legal Well Name: 1J-101 Common Well Name: 1J-101 Spud Date: 12/6/2005 Event Name: ROT -DRILLING Start: 12/6/2005 End: 1/7/2006 Contractor Name: n1334@ppco.com Rig Release: 1/7/2006 Group: Rig Name: Doyon 141 Rig Number: Date 12/29/2005 12/30/2005 From'- To Hours ' Code I, Sub ',. Phase ~~~ Code 08:30 - 09:45 ~I 1.25 CMPLTN OTHR CMPLT2 09:45 - 10:00 ~ 0.25 ~ CMPLT ~ CIRC CMPLT2 10:00 - 10:15 0.25 WELCT OTHR CMPLT2 10:15 - 12:00 1.75 CMPL' 12:00 - 12:30 0.50 CMPL' 12:30 - 13:30 1.00 CMPL 13:30 - 14:00 0.50 CMPL 14:00 - 15:00 I 1.00 CMPL' TRIP CMPLT2 TRIP CMPLT2 TRIP CMPLT2 RURD CMPLT2 PULD CMPLT2 15:00 - 16:45 I 1.751 CMPLTNI TRIP I CMPLT2 16:45 - 17:30 I 0.751 CMPLTN!TRIP I CMPLT2 17:30 - 17:45 I 0.25 CMPLTN PCKR CMPLT2 17:45 - 18:15 'i 0.50. CMPLTN PCKR CMPLT2 18:15 - 18:45 ~ 0.50 CMPL' 18:45 - 20:30 ' 1.75 CMPL' 20:30 - 21:00 0.50 CMPL 21:00 - 00:00 I 3.00 i WINDS ', 00:00 - 01:00 01:00 - 01:15 01:15 - 01:30 01:30 - 03:45 03:45 - 04:15 04:15 - 04:30 04:30 - 05:00 CIRC :,CMPLT2 TRIP ~ CMPLT2 PULD CMPLT2 PULD PROD3 1.00 WINDOTHR i PROD3 0.25; WINDO ULD ~PROD3 0.25 ~ WINDO THR PROD3 2.25 WINDOWTRIP PROD3 0.50 WINDOWTRIP PROD3 0.25 WINDOVIITRIP PROD3 0.50 WINDOWSETW PROD3 - i.v~ vvnwvvv~inv rrwva 06:00 - 12:00 6.00 WINDOWSCML PROD3 Description of Operations 11,629'. Pull Back up, reorient to 8 degrees left of high side and land Hook Hanger on bottom of window @ 4520' and 19 degrees right of hih side. Set down 30K. Drop 1 3/4" ball. Top of hook hanger @ 4503.14'. PUW=123K SOW=70K Circa @ 110 gpm w/ 380 psi. Garnered SPR, blew down TD. SPR #2=20stk/280psi, 30stk/380psi. POOH from 4503' to 2162'. POOH from 2162' to 46'. UD running tool and MWD. R/U casing tools for LEM run. I Held PJSM. M/U LEM to 363'. Baker Seal assembly (3.26'), ~ Crossover joint IBT x STL (43.04'), 4 1/2" IBT pup (31.04'), Camco "DB" Nipple 3.563" ID (1.55'), 4 1!2" IBT JNT (28.2'), 4 1/2" IBT pups (7.89), LEM assembly (35..00'), 5 - JNTs of 4 1/2" IBT (154.13'), 4 1/2" IBT pup (3.80'), Baker Casing Swivel (2.77'), XO Bushing (1.43'), 109-47 Casing Seal Bore receptacle (19.65'), ZXP Liner Top Packer (19.05'). Total tools to stay in hole 350.81'. PUW=38K SOW=41 K TIH from 363' to 4,640'. PUW=118K SOW=108K Landed LEM @ 4,642'. Pulled up 130K and set down 60K. Dropped 1.75" ball and seated w/ 25 spm @ 425psi Set packer and pressured ~, up to 2000/3000!4000 psi. Released from LEM. ',Attempted to test ZXP Packer twice. Tests unsuccessful. Pulled up and mechanically set packer. Tested packer to 1000 psi for 5 mins. Good test. Top of ZXP packer @ 4291.36'. Pulled up to 4,480' and CBU @ 90 spm and 1800 psi. ~I Checked flow, static. POOH from 4,480' to 3T. UD running tool. Make up D Lateral whipstock assembly. Make up Whipstock assembly & space out pipe. MU Seal Assembly with Stop Sub (1.95'), 4 5/8" Unloader Sub (5.19'), 1 jnt 3 1/2 DP (31.19'), 2 pup-jnts 3 1/2 DP (10.0', 9.76'), Blanking Sub (1.23'), Bottom Trip Anchor (3.22'), Safety Disconnect (2.69'), Ported Drain Sub (1.12'), Debris Barrier sub w/ Cup (1.95'), & 5/8" Whipstock slide (15.45'). 6.156" Starting Mill (1.13'), 6.3125" Lower Mill (5.49'), 6.750" Upper mill (5.81'), 1-jnt 3 1i2" HWDP (29.81'), 4 3/4" NM Float sub (2.41'), MWD (44.0'), 4 3/4" Bumper jars ', (7.86')Crossover IF x XT39 (1.65'), 3 stands 4 3/4" Hybrid Push pipe(271.T). Total BHA = 455.1' Plugged in and programmed MWD. 'Changed elevators, M/U XO, 3 stds, hybrid DP. Pulsed tested MWD @ 80 spm, 930 psi. TIH from 455' to 3,720' MD. Filled pipe 2,251' w/ 80 spm and 1225 psi. Made MADD pass from 3,479' to 3,801'. Cont'd to TIH from 3,801' to 4,290'. Oriented and set whipstock. Set @ 12 degrees left, with top of t whipstock @ 4,206'. ~~~ Dis laced well to MOBM 80 s m, 2000 si. ~~"~C Milling from 4,206' to 4,248'. Milled w/ 80 spm, 1900 psi, 100 rpm. .TOW=4,206' BOW=4,218' PUW=110K SOW=97K ROT=105K TO=2K ~ L Printed: 2/7/2006 10:40:10 AM ConocoPhillips_Alaska Page 17 of 22 Operations Summary Report Legal Well Name: 1J-101 Common Well Name: 1J-101 Spud Date: 12/6/2005 Event Name: ROT -DRILLING Start: 12/6/2005 End: 1/7/2006 Contractor Name: n1334@ppco.com Rig Release: 1/7/2006 Group: Rig Name: Doyon 141 Rig Number: Date !From - To Hours.'! Code Sub Code - _ _ - _ -- 12/30/2005 i 06:00 - 12:00 6.00 WINDOWSCML 12:00 - 13:00 1.00 WINDOV~ICIRC 12!3112005 13:00 - 14:45 ! 1.75 ~ WINDO RIP 14:45 - 16:15 ~ I 1.50; i WINDO ULD 16:15 - 16:45 I 0.501 WELLS EQRP 16:45 - 19:45 3.00 WELCT BOPS 19:45 - 20:00 0.25 WELLS EQRP 20:00 - 22:30 2.50 DRILL PULD 22:30 - 00:00 ' 1.501 DRILL 'TRIP 00:00 - 00:30 I 0.50 DRILL STRIP 00:30 - 01:45 I 1.25 WELLS EQRP 01:45 - 02:00 ! ; 0.25 ~ i DRILL TRIP 02:00 - 12:00 i 10.001 DRILL I DRLH 12:00 - 00:00 12.00 DRILL I DRLH 1/1/2006 ! 00:00 - 12:00 ! 12.00 i, DRILL DRLH 12:00 - 00:00 I 12.001 DRILL I DRLH Phase ', Description of Operations PROD3 Hit concretion @ 4,242'-4,245' spent 1.5 hours milling through. SPR#1=20stk/230psi, 30stk/340psi SPR#2=20stk/240psi, 30stk/340psi @ 4,248'MD / 3,462'TVD 8.8 MW Krevs=253 PROD3 Pumped 30 bbl hi-vis weighted sweep @ 4,218' w/ 80 spm, 1825 psi, 70 rpm. Pulled up/down with rotary, and up/down w/ no rotary w/ no pumps. Noted clean cut window. PROD3 I Flow checked, static. POOH from 4,218' to 97'. PROD3 i VD mill, XO, bumper sub, downloaded MWD, TM, MWD, DM, F/S, 1 jt 3.5" HWDP, window mill, lower and upper mill (upper mill in gauge). I Removed mill and BHA from rig floor. PROD3 ;Drained and flushed stack after milling operations. Pulled wear bushing. PROD3 R/U and test BOP stark, HCR's & manual valves. Test Choke mainfold valves, upper & lower IBOP valves, floor safety valve & dart valve.Alt tests 250 PSI Low / 3500 PSI High. Recorded on chart. J8M'Jtints with AO~C waived of tit. Tegtad gas alarms and PVT and high flow alarms. R!D test equipment. PROD3 Installed wear bushing. PROD3 P/U and M/U BHA #11 including: bit, geo-pilot, pony collar, DM, smart stab, slimphase, PWD, TM, NM F/S, stab. Uploaded MWD. Cont'd M/U NM flex DCs, XO, 1 std HWDP, jars, 2 std HWDP. Broke in ,geo-pilot bearings and SHT MWD w/ 77spm, 1100 psi. PROD3 ~I TIH from 369' to 2,985'. PROD3 ;Cont'd TIH to 4,107. PROD3 ;Slipped and cut drilling line and serviced top drive. PROD3 (Trip through window @ 4,206 w/ no problems. TIH to 4,238' and ream to 4,248' w/ 72 spm, 260 gpm, 1450 psi, 50 rpm. PUW=90K SOW=80K TO=2K. PROD3 Drilled 6.75" D lateral from 4,248' to 5,318' MD / 3,486' TVD ADT=6.8. PUW=94K SOW=74K ROT=83K TOon/off=3K/2.5K ECD=10.18 Max Gas=141 Units Jar hrs=197.18 hrs SPR#1=25spm/350psi, 35spm/490psi SPR#2=25spm/340psi, 35spm/490psi Concretion depths: 4300-4335' PROD3 Drilled 6.75" D lateral from 5,318' to 6,501' / 3,493' TVD ADT=9.77. PUW=100K SOW=65K ROT=82K TOon/off=5K/3.5K ECD=10.23 Max Gas=185 Units Jar hrs=206.95 hrs !SPR#1=20spm/330psi, 30spml480psi SPR#2=20spm/340psi, 30spm/490psi Concretion depths/length: 5368/2', 5563/9', 5655!3', 5918!4', 5938/2', 5948/2', 5967/6', 6266/6', 6301/6', 6323/3', 6329/13', 6346/7', 6376/12', 6390/13', 6417/30', 6493/12' PROD3 Drilled 6.75" D lateral from 6,501' to 8,056' MD / 3,516' TVD ADT=8.81. PUW=110K SOW=57K ROT=84K TOon/off=5.5K/5K ECD=10.63 Max Gas=151 Units Jar hrs=215.76 hrs SPR#1=20spm/400psi, 30spm/560psi SPR#2=20spm/430psi, 30spm/560psi @ 7,467' MD/3,512' TVD 8.8 MW Concretion depths: 6493-6505', 7630-7646', 7651-7671', 7679-7699', 7718-7735', 7736-7742'. PROD3 Drilled 6.75" D lateral from 8,056' to 9,231' MD / 3,537 TVD ADT=9.67. Printed: 2/7/2006 10:40:10 AM ConocoPhiflips Alaska Page,18 of22 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1J-101 1 J-101 Spud Date: 12/6/2005 ROT -DRILLING Start: 12/6/2005 End: 1/7/2006 n1334@ppco.com Rig Release: 1/7/2006 Group: Doyon 141 Rig Number: Code ;Sub ''I Phase-' Code Date From - To '-Hours 111 /2006 ~ 12:00 - 00:00 1 /2/2006 100:00 - 12:00 12:00 - 00:00 12.001 DRILL ~ DRLH ~ PROD3 12.001 DRILL 12.001 DRILL 1/3/2006 00:00 - 02:00 2.00 i DRILL 02:00 - 04:15 ~ 2.25 ~ DRILL 04:15 - 05:15 1.00 DRILL ' 05:15 - 12:00 i 6.75 DRILL 12:00 - 15:00 , 3.00' DRILL ,15:00 - 16:00 ; 1.001 DRILL DRLH I PROD3 DRLH I PROD3 DRLG PROD3 CIRC PROD3 WIPR ~PROD3 WIPR !PROD3 i WIPR PROD3 CIRC , PROD3 16:00 - 18:45 I 2.751 DRILL i WIPR I PROD3 Description of Operations PUW=116K SOW=50K ROT=83K TOon/off=7.5K/5K ECD=11.87 Max Gas=98 Units Jar hrs=225.43 hrs SPR#1=20spm/420psi, 30spm/590psi SPR#2=20spm/430psi, 30spm/590psi Concretion depths: 8170-8177',8198-8191', 8260-8264', 8279-8281', 8329-8330', 8533-8539', 8593-8610', 8610-8622', 8642-8652', 8654-8678', 8679-8702', 8705-8716', 8853-8856', 8858-8860', 8862-8864', 9102-9105', 9149-9153', 9173-9182'. Drilled 6.75" D lateral from 9,231' to 10,383' MD / 3,579' TVD ADT=8.47. PUW=130K SOW=40K ROT=86K TOon/off=7K/7K ECD=11.22 Max Gas=95 Units Jar hrs=233.90 hrs SPR#1=20spm/420psi, 30spm/570psi SPR#2=20spm/430psi, 30spm/6000psi @ 9,349' MD / 3,542' TVD 8.8MW Concretion depths:9247-9250, 9254-9255', 9268-9270', 9290-9299', 9336-9354', 9631-9636', 9781-9783', 9805-9811', 9813-9818', 9820-9823', 9863-9867', 9883-9887', 10009-100015', 100035-100042', 100083-10089', 10100-10102', 10270-10275'. Drilled 6.75" D lateral from 10,383' to 11,456' MD ! 3,640' TVD ADT=8.84. PUW=163K SOW=OK ROT=105K TQon/off=8K/8K ECD=11.43 Max Gas=102 Units Jar hrs=242.74 hrs SPR#1=20spm/570psi, 30spm/730psi SPR#2=20spm/580psi, 30spm/750psi @ 11,456' MD / 3,640' TVD Concretion depths: 10384-10388', 10418-10420', 10459-10461', 10741-10472', 11272-11274', 11280-11290', 11294-11307', 11338-11340', 11365-11374', 11385-11402', 11420-11430', 11438-11444', 11448-11459'. Krevs=150,947 Drilled 6.75" D lateral from 11,456' - 11711' MD (255') 3,655' TVD ADT=1.92 HRS. PUW=173K SOW=35K ROT=90K TO on/off=8.5K, 9K ECD=11.47 Max Gas=90 Units Jar hrs=244.66 hrs SPR#1=20spm - 610psi, 30spm - 770psi SPR#2=20spm - 570psi, 30spm - 720psi @ 11,711' MD / 3,655' TVD Pump Hi Visc Weighted sweep and 3 bottoms up @ 93 SPM - 330 GPM - 3950 PSI. RPM's -125 - 135 Torque = 7K, While Reciprocate & rotate drill string. Observed 10°l° increase in cuttings when sweep across shakers. Monitor well, static. POOH on elevators from 11711' - 11187' (524'), 6 stands total, observed hole not taking proper hole fill. BROOH from 11187' - 7003' (4184'). Back ream at drilling rate, 93 SPM - 330 GPM's - 3500 PSI. Torque = 8K, at 125 RPM's. Continue BROOH from 7003' - 4294' (2709'). Back ream at drilling rate, 93 SPM - 330 GPM's - 3500 PSI., Torque = 8K, at 125 RPM's. POOH on elevators to 4185'. Pump Hi Visc Weighted sweep plus 3 bottoms up @ 93 SPM - 330 GPM - 3950 PSI. RPM's -125 - 135 Torque = 7K, While Reciprocate & rotate drill string. PU WT = 90K, SO WT = 81 K. Observed 10°l° increase in cuttings when sweep across shakers. Monitor well -static. Trip back in hole from 4185' - 8940' (4755'), until Printed: 2f7/2006 10:40:10 AM ConocoPhillips Alaska Legal Well Name: 1J-101 Operations Summary Report Page 19 of 22 Common Well Name: 1J-101 Spud Date: 12/6/2005 Event Name: ROT -DRILLING Start: 12/6/2005 End: 1/7/2006 Contractor Name: n1334@ppco.com Rig Release: 1/7/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours ' Code Sub ~ Phase Description'of Operations ,Code , 1/3/2006 ~ 16:00 - 18:45 j 2.751 DRILL WIPR PROD3 18:45 - 22:15 ~ 3.50 ~ DRILL ..WIPR PROD3 22:15 - 00:00 1.75 1/4/2006 00:00 - 00:45 0.75 00:45 - 02:15 1.50 DRILL 'CIRC ' PROD3 DRILL CIRC PROD3 DRILL !,CIRC ~ PROD3 02:15 - 02:30 I 0.251 DRILL ! OBSV I PROD3 02:30 - 08:30 6.00 08:30 - 10:00 1.50 10:00 - 10:45 0.75 10:45 - 12:00 i 1.25 DRILL (TRIP DRILL i PULD DRILL OTHR DRILL PULD 12:00 - 12:30 I 0.50 WINDOVVIPUL[ 12:30 - 14:00 1.50 ~ WINDO~RIP 14:00 - 14:15 i 0.25 WINDOWOTHI 14:15 - 14:45 0.50 14:45 - 17:00 2.25 17:00 - 19:00 , 2.00 RC P PROD3 PROD3 PROD3 PROD3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 we observed run out of downweight. Wash & ream in hole from 8940' - 11711' (2771') @ 75 GPM's - 89 SPM - 266 GPM - 2100 PSI. PU WT = 173K, SO WT = 35K. ROT WT = 109K with 9K torque. Pump 30 BBL Hi Visc Weighted sweep @ 89 SPM - 316 GPM - 3900 PSI. RPM's -125. Torque = 8.5K, While Reciprocate & rotate drill string. PU WT = 173K, SO WT = 35K, ROT WT 90K. Observed 10% increase in cuttings when sweep across shakers. K-REV total = 72088. Continue circulate 3 bottoms up after sweep returned, ensuring hole clean @ 93 SPM, 330 GPM's, 4150 PSI rotating & reciprocating drill string at 125 RPM's with 8.5K torque. PJSM with entire crew & truck drivers. Discuss Safety issues and Spill prevention procedures. Designate Spill Champion for displacement. Displace well from 8.8 PPG MOBM to 8.8 PPG SFMOBM (490 BBLS) at 88 SPM , 315 GPM's, 3950 PSI, 100 RPM's and 8K torque. NO spill issues. Obtain SPR's. Monitor well -static. Drop 1 3/4" drift in drill string. Pump #1 - 20 SPM -510 PSI 30 SPM - 720 PSI Pump #2 - 20 SPM - 500 PSI 30 SPM - 680 PSI. PU WT = 174K, SO WT = 35K, ROT WT = 110K. ECD = 11.54 PPG, Max gas = 36 BTU's @ 11711' MD, 3655' TVD. MW = 8.8+ PPG. POOH on elevators observing well taking proper hole fill. Breakout & lay down BHA. Lay down Non Mag Float sub (2.41'), 4 3!4" Integral Blade Stabilizer (4.58'), 3 -Non Mag Flex Drill Collars (92.46'), Crossover sub (1.65'), 3 jnts - 4" HWDP (90.89'), 4 3/4" Drilling jars (28.88'), and 2 jnts - 4" HWDP (60.57'). Plug in and download MWD assembly. Breakout & lay down BHA. Lay down 6.750" Security FMF2641Z PDC bit (1.27'), 5200 Geo-Pilot 027 (16.19'), GP NonMag Pony Collar (11.53'), DM HOC (8.56'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/ DGR RES (24.36'), PWD tool (10.86'), TM HOC (11.28'). Gauge & record bit gauge @ 3 / 1 ! CT / N / X / I / WT / TD. Total BHA = 369.08' Clean floor area. Send tools out: PJSM. Make up Whipstock retrieving hook assembly. Make up Retrieving Hook (7.50'), 1 -Jnt of 3 1/2" HWDP (29.82'), 4 3/4" Float sub (2.41'), 4 3/4" Bumperjar (7.86'), 4 3!4" Oil Jar (11.13'), Crossover (1.65'), and 3 -stands of 4" Hybrid push pipe (271.70'). Total BHA = 332.07' Trip in hole from 332' -4212' (3880'). PU WT = 115K, SO WT = 105K. Tagged whipstock 2 times attemting to hook slot. Rotate 1/4 turn, no catch, Pull up rotate 1/3 turn to observe Hooking whipstock slot @ 4211' DPM. Pull to 160K to fire jars, recock jars, pull up to 200K, fire jars, observe whipstock assembly sheared and free. New up weight = 122K. Pull up to 4123' Circulate bottoms up @ 85 SPM -302 GPM's - 1700 PSI. No gas or fluid loss. Monitor well -static. POOH from 4123' - 415' (3708'). Observe no swabbing and hole taking proper hole fil{. Breakout & lay down Whipstock retrieving assembly with slide and space out assembly. Layed down Retrieving Hook (7.50'), 1 -Jnt of 3 1/2" HWDP (29.82'), 4 3/4" Float sub (2.41'), 4 3/4" Bumperjar (7.86'), Printed: 2/7/2006 10:40:10 AM ConocoPhillips Alaska Operations' Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 J-101 1 J-101 ROT -DRILLING n 1334@ppco.com Doyon141 Date From - To Hours Code Sub ,Phase Code _ i -_ 1 /4/2006 1 /5/2006 17:00 - 19:00 19:00 - 19:30 19:30 - 22:30 22:30 - 00:00 00:00 - 02:30 02:30 - 03:45 03:45 - 04:00 04:00 - 06:30 06:30 - 07:30 07:30 - 08:00 08:00 - 08:30 2.001 WINDOVVPULD ICMPLT3 0.50. CASE ! RURD .CMPLT3 3.001 CASE I RUNC ICMPLT3 1.50 CASE RUNC ICMPLT3 2.501 CASE I RUNC ICMPLT3 1.25 I CASE I RUNC ICMPLT3 0.25; CASE IOTHR ICMPLT3 2.50 CASE RUNL CMPLT3 1.00 ~ CASE J RUNL ~ CMPLT3 0.501 CASE I OTHR ICMPLT3 0.501 CASE I CIRC ICMPLT3 08:30 - 11:00 ! 2.50 ~ CMPLTNi TRIP 'CMPLT3 11:00 - 12:00 1.00 CMPLTN TRIP CMPLT3 12:00 - 22:45 10.75 CMPLTN TRIP CMPLT3 Page 20 of 22 Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number: Description of Operations - _ _ ___ 4 3/4" Oil Jar (11.13'), Crossover (1.65'), and 3 -stands of 4" Hybrid push pipe (271.70'). Total BHA = 332.07 and layed down Seal Assembly with Stop Sub (1.95'), 4 5/8" Unloader Sub (5.19'), 1 jnt 3 112 DP (31.19'), 2 pup-jnts 3 1/2 DP (10.0', 9.76'), Blanking Sub (1.23'), Bottom Trip Anchor (3.22'), Safety Disconnect (2.69'), Ported Drain Sub (1.12'), Debris Barrier sub w/Cup (1.95'), & 5/8" Whipstock slide (15.45'). 6.156" Starting Mill (1.13'), 6.3125" Lower Mill (5.49'), 6.750" Upper mill (5.81'), 1-jnt 3 1/2" HWDP (29.81'), 4 3/4" NM Float sub ~! (2.41'), MWD (44.0'), 4 3/4" Bumperjars (7.86')Crossover IF x X739 (1.65'), 3 stands 4 314" Hybrid Push pipe(271.7'). Total BHA = 455.1' Rig up 4 1/2" liner running equipment. Check Pipe shed for correct order of liner. PJSM with entire crew & BOT rep. Discuss Safety issues and running procedure of 4 1/2" liner. Make up 3 1/2" Bent joint with Guide shoe and crossover sub, continue make up and RIH with 4 1.2" Slotted liner to tag crossover in B Lateral LEM at 4330'. Make up torque = 3000 ft/Ibs. Pull 1 stand and 2 joints back to rotate and orient guide shoe to pass through window at 4218'. Repeat attempts 7 times before observing guide shoe through window and out into open hole. PU WT = 75k. SO WT = 70K. Total K-revs for day = 10801 'Work guide shoe through window @ 4218', continue run into open hole to 7447' MD. Rig up and make up 3 1/4" SlimHole MWD assembly and ball catcher 'sub on bottom of Hook Hanger. PU WT = 80K, SO WT = 60K Perform Shallow pulse test on MWD assembly @ 31 SPM - 110 GPM - 600 PSI. Good test. Continue run 4 1.4" slotted liner on DP from 7447' - 11680' (4233'). 'Observe good hole condition and no issues, with hole taking proper hole fill. PU WT = 170K, SO WT = 60K. Pick up 2 jnts of 4" DP and orient Hook Hanger to 4 degrees left of HS. Locate & set Hook on bottom of window @ 4220', wait and observe new toolface of 20 Degrees right of HS. Tagged bottom of window 2.75' lower @ 4220.75'. Pick up 30' and observe toolface back to 1 degree left of HS,set down to see new toolface of 20 Degrees right of HS. PU 30', orient to 175 Degrees right, slack off 10' past the bottom of the window with no issues. Pull back up. Re-orient Hook to 4 degrees left of HS and set Hook on bottom of window once again at 4220', observing corrected toolface at 20 Degrees right of HS. Guide shoe depth = 11682.92' MD. Top of Hook Hanger @ 4204'. PU WT = 170K, SO WT = 60K Drop 29!32" ball down drill string pumping it down at 27 SPM -96 GPM- 800 PSI. Observed ball landed with 362 strokes pumped. Continue pumping pressuring up 3300 PSI, releasing from Hook Hanger. Bleed pressures and pull up to observe UP WT = 120K. Lay down 2 joint of 4" DP. Circulate bottoms up @ 93 SPM - 330 GPM - 2100 PSI. No gas or fluid loss. Monitor well -static. POOH breakout, lay down & inspect running tool, and MWD assembly. Clean & clear floor area. Remove all running tools and equipment. Rig up to lay down entire drill string. PJSM with crew. Discuss safety issues, pinch points and procedure for laying down drill string from mousehole. LAy down 312 jnts of 4" DP, 36 joints of 4" HWDP, & 30 joints of 4" x 4 3/4" Hybrid Push Pipe. Remove 4 Lo-tads. Inspect Super ,Sliders and leave on Drill Pipe. Printed: 2/7/2006 10:40:10 AM ConocoPhiNips Alaska Opera#ions Surnrnary,Report Legal Well Name: 1J-101 Common Well Name: 1J-101 Event Name: ROT -DRILLING Start: 12/6/2005 Contractor Name: n1334@ppco.com Rig Release: 1/7/2006 Rig Name: Doyon 141 Rig Number: Date From - To Hours 1 /5/2006 22:45 - 00:00 1.25 1 /6/2006 00:00 - 00:30 0.50 00:30 - 03:00 2.50 03:00 - 03:45 03:45 - 05:30 05:30 - 06:00 06:00 - 06:45 06:45 - 07:45 07:45 - 12:00 12:00 - 12:30 ' 0.50 12:30 - 19:00 6.50 19:00 - 19:15 I 0.25 19:15 - 20:45 i 20:45 - 22:30 i 22:30 - 00:00 1 /7/2006 00:00 - 00:30 00:30 - 00:45 Page 21 of 22 Spud Date: 12/6/2005 End: 1 /7/2006 Group: Code !Phase Code Description of Operations RIGMNT~ RSRV ~ CMPLT3 Slip & cut 68' of drilling line, and service Top Drive. CMPLTN PULD CMPLT3 Continue Rig up completion running equipment. CMPLTN PULD CMPLT3 PJSM with entire crew. Discuss safety issues, and procedure for ~ picking up and racking back 4 1/2" 12.6# Completion string. Pick up and RIH with 102 joints of 4 1/2" tubing. MAke up torque = 3000 FT/LBS. CMPLTN PULD ' CMPLT3 :, Rig down 7 5/8" Eckel tongs, and Rig up Double stack tongs for completion. CMPLTN PULD CMPLT3 POOH, rack back 34 stands of 4 112" completion string, for running 'ESP completion. CMPLTN OTHR CMPLT3 Rig up and BOLDS, pull wear bushing. CMPLTN RURD ; CMPLT3 Clear & Clean floor area. Pull all Centrilift equipment to rig floor. Pull all Clamps and bands to floor. CMPLTN, RURD CMPLT3 PJSM. Discuss safety issues and procedure and safety for hanging :ESP cable and sheave in derrick. Pull ESP tine & sheave to rig floor. Hang sheave in Derrick, ensure tied off as not to fall. CMPLTN RUNT CMPLT3 PJSM with entire crew and Centrilift rep. Discuss Safety issues and procedure for handling and picking up ESP equipment. Make up Baker Centrilift 5.62" OD 418 HP KMHFER 2610 Motor (33.85'), with 4.60" A-Well pump gauge (2.11') and 6" OD centralizer (1.95'). MU 5.13" Tandem Seal Section GSB 3 DB AB/HSN PFSA (13.78'),5.13" OD TTC Crossover w/ Screen Intake with 4-1/2" IBT pup (20.40'). Install oil, and CPAI witness free rotation of motor, utilizing CPAI checklist for 'installation of ESP assembly. CMPLTN RUNT ~ CMPLT3 Continue MU ESP assembly attaching ESP cable, and testing same as ,per Centrilift Rep. CMPLTN RUNT CMPLT3 RIH with 4 1/2" L80 12.6# IBT tubing from derrick installing Cannon Clamps every other collar, protectolizers, Flat guards as per Centrilift rep. RIH to 3297'. Test ESP cable every 1000' while RIH. Run total of 102 joints of 4-1/2" tubing and 4-Camco GLMS KMBG 4 1/2" x 1" w/ Dummy valves (BK -5 Latch) spaced out in string to depths of #1 GLM = 2832' MD 2773' TVD @ 32.53 DEG INC. #2 GLM = 2348' MD 2328' TVD @ 17 DEG INC. #3 GLM = 142' MD 142' TVD @ .44 DEG INC. #4 -GLM = 92' MD 92' TVD .36 DEG INC. CMPLTN RUNT CMPLT3 Make up Vetco Gray 11" x 4 1/2" Hanger w/ 4.909" MCA top Connection, and full joint (32.53'),with landing joint. NOTE: BPV installed in hanger. 0.75 1.75 0.50 0.75 1.00 4.25 1.50: CMPLTN OTHR CMPLT3 Position hanger at floor, and install Penetrator as per Vetco Gray rep. Test Penetrator and ESP line again. Measure & cut ESP line for splice and Pigtail Hookup. Splice ESP line as per Centrilift Rep. 1.75' CMPLTN OTHR ~ CMPLT3 Trouble shoot splice connection as the Meter indicated a faulty connection. Check splice with 2 more meters, and the a third to verify good connection and splice. Observed faulty meter, remove from ,service. All tests good. 1.50 CMPLTN OTHR CMPLT3 Continue with splicing Pigtail to ESP line, wrapping & securing ESP i cable. Total Cannon Clamps run = 61, Total Flat Guards run = 2 ,Total Protectolizers run = 3 NOTE: SIMOPS -Change out Liners to 6" in Mud Pump #1. 0.50 ~ CMPLTN OTHR ~ CMPLTN ~ Continue with splicing Pigtail to ESP line, wrapping & securing ESP cable. Make up Pigtail to hanger and secure same. Total Cannon ~ Clamps run = 61, Total Flat Guards run = 2 ,Total Protectolizers run = 3 NOTE: SIMOPS -Change out Liners to 6" in Mud Pump #1 & 2. 0.25 CMPLTN OTHR ~ CMPLT3 Rig up and test ESP cable again after make up to hanger. Good test Printed: 2/7/2006 10:40:10 AM ConocoPhiilips Alaska Page 22 of 22 Operatiolns Summary Report Legal Well Name: 1J-101 Common Well Name: 1J-101 Spud Date: 12/6/2005 Event Name: ROT -DRILLING Start: 1 2/612 0 0 5 End: 1/7/2006 Contractor Name: n1334@ppco.com Rig Release: 1!7/2006 Group: Rig Name: Doyon 141 Rig Number: bate !From - To .Hours ; Code I Code Phase ~ Description of Operations 1/7/2006 ~ 00:45 - 01:15 , ~ 0.501 CMPLTN RUNT CMPLT3 Land tubing hanger as per Vetco Rep. Observe good set down into wellhead. PU WT =78K, SO WT = 78K. NOTE: BPV installed in hanger before RIH. Clear Rig Floor area. j 01:15 - 02:00 ~ 0.75 CMPLTN RUNT CMPLT3 RILDS. Verify all made up correctly, and measure. Rig up & test upper i and lower Hanger seals to 5000 PSI for 10 minutes each. Good test. Backout & lay down landing joint. ' 02:00 - 03:00; 1.00 WELCTI NUND CMPLT3 Nipple down BOP stack & lines. 03:00 - 06:00 ~ 3.00 CMPLTN NUND CMPLT3 Nipple up Vetco Gray Tree as per Vetco Rep. Test "void" on tree to i 5000 PSI - 15 minutes. Perform final test on ESP Cable on Penetrator through tree as per Centrilift Rep. Good test. Rig up and test tree to 250 ~ / 5000 PSI Low /High test - 10 minutes each. No leaks. Good test. Rig i up and pull BPV. 06:00 - 08:00 ' 2.00! CMPLTN FRZP CMPLT3 PJSM with crew and Little Red Hot Oil reps. Discuss safety issues and procedures for spill prevention. Rig up Little Red Services. Pump Freeze protect Diesel down annulus, returns through tubing @ 4 BPM. ~ 600 PSI. Total pumped = 140 BBLS of Diesel. SIMOPS :Rig up scaffolding in cellar for installing BPV. 08:00 - 09:00 1.00 CMPLTN FRZP CMPLT3 Rig down Little Red. No issues while displacing. Clean pits, and change ~ ; out saver sub on Top Drive. 09:00 - 10:00 1.00 CMPLTN OTHR ~ CMPLT3 ' Make up Lubricator, and install BPV as per Vetco Gray Rep. Shut in & ~ secure well. 10:00 - 12:00 2.00 ~ MOVE DMOB CMPLT3 ~ Use Super Sucker to clean out cellar box, Rig down Lubricator and all scaffolding. Prepare Pipe shed and modules for rig move. Remove Tioga heater, blow down all water, steam, and Glycol lines. ~ j Rig Released @ 1200 HRS 1/7/2006. Printed: Z7/2006 10:40:10 AM ~Iallburton Company Global Report ~ ; ~ E '~s --- ('~+nil~ain. n PI':illil ` ',I;asFa li~~;. I~irl+l: I':'_.o ui~. Ei`~~'i Ur~lt U:uc 1 ~~ll~iii"i„ l i+n~: ',1 :_ + - Page: ('++-+n~Jiua(c(\LI krG~rcn~+•: ,'Je!L 1J 1 ~ I, True North Dili: I.!ip3rak.1J~'a_i t'crtic;il(I~~DjRcfcr cucc; 1J-101 1i~~90" 11c11: 1~'~-1 _TI tirc(inu (1~1 Rel~~rru rc: Well(O.UUN 0`.OOE ,O.OOAzi) ~~ ~~cllhaU+: 1J-101 ~urce~e~alculau~n+~ lcilu+l: MinimumCurvature Dba Oracfie Survey: T Start Date: Company: Engineer: Tool: Tied-to: 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 Syste m: Well Cehtre + Sys Datums Mean Sea Level Geomagnetic Mo del: bggm2005 Site: Kuparuk 1J Pad Site Position: Northing: 5945919.64 ft Latitude: 70 15 46.258 N From: Map Easting: 558789.95 ft Longitude: 149 31 29.007 W Position Uncertainty: 0.00 ft North Reference: True i Ground Level: 0.00 ft Grid Convergenc e: 0.45 deg __ __ Well: 1 J-101 Slot Name: Welt Position: +N!-S 166.80 ft Northing: 5946086.15 ft " Lat-tude: __ _ 70 15 47..898 N +E/-W -34.32 ft Easting : 558754.33 ft Longitude:-"~ 149 31 30.005 W Position Uncertainty: 0.00 ft ~ _ Wellpath: 1 J-101 Drilled From: 1 J-101 L1 PB1 j 500292328600 Tie-on Depth: 8532.84 ft Current Datum: 1J-101 H eight 109.00 ft Above System Da tum: Mean Sea Level Magnetic Data: 12/18/2005 Declination: 24.24 deg Field Strength: 57564 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 1/23/2006 Validated: No Version: 10 Actual From To Survey Toolcode Tool Name I ft ft 100.00 843.00 1J-101 gyro (100.00-843.00) CB-GYRO-SS Camera based gyro single shot 933.26 5348.51 1J-101 (933.26-5348.51) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5446.54 8532.84 1J-101PB1 A nadrill (5446 .54-88 MWD+IFR-AK-CAZ-SC MWD+IFR AK GAZ SCC 8626.58 11447.53 1J-101 Anadr ill (8626.58-11447 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey - >, ~ll) I+ +r ~~ l> ti l .."I~~l~ _ \ti I'~~ -- - f1~ap~ MapF, - Tool l ; a ~f J ft it ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5946086.15 558754.33 -TIE LINE 100.00 0.41 315.04 100.00 -9.00 0.18 -0.18 5946086.33 558754.15 CB-GYRO-SS , 200:00 0.52 347.22 200.00 91.00 0.88 -0.54 5946087.02 558753.79 CB-GYRO-SS 300.00 0.66 342.49 299.99.. 190.99 1.87 -0.81 5946088.01 558753.51 CB-GYRO-SS 400.00 0.75 345.17 399.98 290.98 3.05 -1.15 5946089.19 558753.16 CB-GYRO-SS 500.00 1.13 351.65 499.97 390.97 4.66 -1.46 5946090.80 558752.83 CB-GYRO-SS 600.00 1.41 355.45 599.95 490.95 6.86 -1.70 5946093.00 558752.58 CB-GYRO-SS I 662.00 1.34 355.45 661.93 552.93 8.35 -1.82 5946094.48 558752.45 CB-GYRO-SS I 752.00 1.60 0.61 751.90 642.90 10.65 -1.89 5946096.78 558752.36 CB-GYRO-SS 843.00 1.74 8.06 842.86 733.86 13.29 -1.68 5946099.42 558752.54 CB-GYRO-SS 933.26 2.14 28.78 933.07 824.07 16.12 -0.68 5946102.27 558753.53 MWD+IFR-AK-CAZ-SC ~ i 1025.28 2.46 39.48 1025.01 916.01 19.15 1.40 5946105.31 558755.58 MWD+IFR-AK-CAZ-SC 1124.64 2.48 36.34 1124.28 1015.28 22.53 4.03 5946108.71 558758.19 MWD+IFR-AK-CAZ-SC 35 2.40 46.26 1217 1216.91 1107.91 25.49 6.62 5946111.69 558760.76 MWD+IFR-AK-CAZ-SC ! . 1308.28 2.69 45.39 1307.75 1198.75 28.30 9.52 5946114.52 558763.63 MWD+IFR-AK-CAZ-SC I 1402.35 2.84 42.40 1401.71 1292.71 31.57 12.66 5946117.82 558766.74 MWD+IFR-AK-CAZ-SC ~Halliburton Company i • Global Report ~ ~,,,,,~,;,,,, ~ ~~n -- r ~, Ilia . - ~-{aska Inc Dater ` 1/24/2006 N Times 10.29 52 True Well 1J 101 c e Page: 2 l Nofth ~ Iiclil: i.i_~~~ ~ 3~uF. ~~:~, i i.,~ _~~ ~ El Kcf ( n-nrrlinate( nce: r 1J 10 , 109 0 1' tii~r; i.l:h .sir l,,' F~I ~I ~ ~~r(iea Src~i~ui l I I ~ D1 li~l~ r ~~ti1 Rrl~rcn . rn<<: c~.: ~nlPII ;OAON,<J OOE 0 OOAzi) ~~rll; 1.J-1 11 ~in,~ec talcula~wn ~ Ic(hod I~.' nim um Curvature Db: Oracle ~~~~~Ili~:~ih: !-1 ~?i 5ur~r~ _ _~ -_ SID lucl Mini IUD ~c, l~~l) A,S I. AA' ~lah,A' ~I.il C { TooF tl aeq e~~ it ft ff tt ft f 1495.88 2.50 43.81 1495.14 1386.14 34.76 15.64 5946121.02 558769.69 08 558773 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC ' 1589.49 3.84 39.66 1588.60 1479.60 38.64 19.05 74 24 5946124.94 80 5946130 . . 558778.72 MWD+IFR-AK-CAZ-SC 1682.18 6.25 47.26 1680.93 1571.93 94 1663 44.46 52 34 . 40 33 . 5946138.74 558787.32 MWD+IFR-AK-CAZ-SC 1774.94 8.26 48.06 1772.94 . . . 2 6 77 9 90 44 1864 57 1755.57 62.37 43.92 5946148.86 558797.76 MWD+IFR-AK-CAZ-SC 7.7 18 04 1961 . 22 12 . 06 43 . 1956.17 1847.17 75.20 56.25 5946161.78 558809.99 MWD+IFR-AK-CAZ-SG . 2054.22 . 15.21 . 40.29 2046.69 1937.69 91.73 70.89 5946178.42 33 558824.50 05 55$841 MWD+IFR-AK-CAZ-SG MWD+IFR-AK-CAZ-SG ~ 2147.04 16.21 42.92 2136.04 2027.04 110.51 87.59 69 112 5946197. 71 5946223 . 558865:94 , MWD+IFR-AK-CAZ-SC 2270.88 17.86 44.57 2254.44 2145.44 136.69 . . 2363.84 17.00 43.26 2343.13 2234.13 156.75 132.01 5946243.91 558885.10 25 558903 MWD+IFR-AK-CAZ-SC ~ MWD+IFR-AK-CAZ-SC 2457.01 16.37 43.11 2432.38 2323.38 77 12 176.25 73 196 150.31 19 171 5946263.55 5946284.19 . 558923.96 MWD+IFR-AK-CAZ-SC 2551.08 19.88 47.57 2521.77 . 24 37 2499 . 03 221 . 79 195 5946308.68 b58948.37 MWD+fFR-AK-CAZ-SC 2644.35 23.68 43.48 2608.37 11 691 . 11 2582 . 96 251 . 222.12 5946339.81 558974.45 MWD+IFR-AK-CAZ-SC 2736.56 28.67 37.82 . 2 . . . 2830.94 32..48 33.99 2772.37 2663.37 290.88 250.18 5946378.94 4 559002.21 30 559030 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC 2924.19 37.30 30:72 2848::84 2739.84 335.95 278.63 53 307 5946424.2 65 5946476 . 559058.79 MWD+IFR-AK-CAZ-SG '_ 3016.39 43.42 27,43 16 28 2919.07 65 2984 2810.07 65 2875 388.15 448.67 . 339.45 . 5946537.41 559090.24 MWD+IFR-AK-CAZ=SG 3111.21 49.01 . 1 . 52 3042 . 52 2933 512.16 372.31 5946601.15 559122.60 MWD+IFR-AK-CAZ-SC 3203.20 53.02 26.6 . . 3297.32 54.45 27.67 3098.19 2989.19 579.69 406.93 5946668.94 7 559156.69 75 559190 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SG 3391.15 54.17 26.32 3152.93 3043.93 647.59 441.52 31 476 .10 594673 17 5946808 . 559224.97 MWD+IFR-AK-CAZ-SC ; 3484.69 60.93 26.02 3203.09 6 3094.09 63 3138 718.39 64 792 . 91 510 . 5946882.67 559258.99 MWD+IFR-AK-CAZ-SC i 3577.93 62.01 23.96 3247. 3 286 60 . 60 3177 . 96 866 . 540.26 5946957,22 559287.76 MWD+IFR-AK-CAZ-SC 3666.88 66.03 19.22 . 3 . . 3759.55 64.62 18.29 3325.29 3216.29 946.70 567.34 5947037,1.5 559314.21 92 559339 .MWD+IFR-AK-CAZ-SC `'. MWD+IFR-AK-CAZ-SC 3850.67 70.00 18.24 3360.43 3251.43 1026.50 36 1113 593.67 10 619 5947117.15 5947204.20 . 559364.67 MWD+IFR-AK-CAZ-SG j 3945.82 74.20 14.44 3389:68 3280.68 50 3304 . 72 1201 . 65 637 5947292.69 559382.53 MWD+IFR-AK-CAZ-SC I 4039.23 76.27 9.30 3413.50 64 3435 . 64 3326 . 07 1292 . 648.22 5947383.11 559392.38 MWD+IFR-AK-CAZ-SG 4132,88 76.39 4.04 . : . 4228.44 77.05 358.70 3457:61 3348.61 1385.01 650.44 5947476.06 559393.88 89 559389 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC 4319.41 75.33 357.02 3479.32 3370.32 1473.28 82 1563 647.14 01 641 5947564.29 5947654,78 . 559383.05 MWD+IFR-AK-CAZ-SG 4413.12 75.83 355.23 9 3502.66 23 3525 3393.66 23 3416 . 1652.27 . 633.05 5947743.15 559374.41 MWD+IFR-AK-CAZ-SC 4504.75 75.65 354.4 . . 09 3441 25 1744 85 623 5947835.04 559364.49 MWD+IFR-AK-CAZ-SG 4600.47 74.25 354,08 3550.09 . . . 66 4691 77.89 357.19 3572.04 3463.04 1832.47 617.13 5947923.21 559357.09 58 559353 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC . 4787.41 80.46 359.42 3590.02 3481.02 1926.46 14 2018 614.36 61 613 5948017.16 5948108.82 . 559352.11 MWD+IFR-AK-CAZ-SC 4880.13 82.40 359.64 3603.84 3494.84 55 3507 . 85 2110 . 01 613 5948201.52 559350.79 MWD+IFR-AK-CAZ-SC 4973.71 81.99 359.62 3616.55 2 . 76 3520 . 83 2201 . 75 611 5948292.47 559348.83 MWD+IFR-AK-CAZ-SG 5065.65 81.49 358.80 9.76 36 . . . 00 5161 82.14 358.13 3643.33 3534.33 2296.17 609.23 5948386.79 559345.56 11 559343 MWD+IFR-AK-CAZ-SC -MWD+IFR-AK-CAZ-SC . 5255.29 80.37 359.75 3657.67 3548.67 2389.34 607.50 606 50 5948479.93 84 5948571 . 559341.40 MWD+IFR-AK-CAZ-SC 5348.51 80.61 359.01 3673.07 3564.07 2481.28 22 2578 . 97 602 . 5948668.74 559337.11 MWD+IFR-AK-CAZ-SC 5446.54 82.90 356.82 3687.13 23 3697 3578.13 23 3588 . 91 2675 . 598.84 5948766.39 559332.22 .MWD+IFR-AK-CAZ-SC 5544.85 85.31 358.34 . . . 5637.98 84.24 356.95 3705.71 3596.71 2768.57 595.03 5948859.01 81 5948951 559327.69 76 559322 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC 5731.15 88.07 357.86 3711.95 3602.95 2861.42 590.83 52 588 , 17 5949045 . 559319.72 MWD+IFR-AK-CAZ-SC 5824.58 90.28 359.31 3713.30 3604.30 33 3604 2954.80 78 3048 . 586.08 . 5949139.12 559316.54 MWD+IFR-AK-CAZ-SC 5918.60 89.68 357.71 3713.33 . 04 3603 . 10 3141 582.07 5949231.40 559311.82 MWD+IFR-AK-CAZ-SC 6011.02 .91.92 357.32 3712.04 . . 6104 95 91.64 358.33 3709.12 3600.12 3234.92 578.51 5949325.17 559307.52 19 559304 MWD+IFR-AK-CAZ-SC I MWD+IFR-AK-CAZ-SC . 6198.84 89.48 358.49 3708.21 3599.21 3328.76 575.90 5949418.98 . i a 7 35 3512034 42 576 5949607.54 559303.23 MWD+IFR-AK-CAZ SC ~R7 77 5 95. 2.22 3698.94 3589..94 . . ~Ialliburton Company Global Report Cnnihaii~_ ~_CII 'Flil~~ll ~'~nl Ins tint: u;_~=~n_!R 1J Fe'_I \1cll: I-1 i1 I \\rlln;ith ' '-1 '1 ~urcrc Alil (nil Viui 6478. 92 89. 30 2.86 6572. 82 89. 43 1.97 6666. 04 89. 46 2.88 6760. 14 90. 09 0.35 6852. 83 89. 29 359.65 6945. 63 89. 54 357.96 7040. 09 89. 50 356.49 ' 7132. 04 89. 80 357.85 ~ 7226. 46 86. 82 359.08 7319. 31 84. 32 359.87 7413. 16 85. 53 0.58 7506. 55 84. 93 1.45 7600. 24 84 .70 1.17 7691. 92 90 .76 0.61 7784. 59 93 .69 4.74 7878. 41 92 .61 - 4.65 7972. 18 92 .45 4.47 8065. 32 92 .08 5.44 8158. 53 90 .27 5.39 8253. 30 90 .46 5.64 8345. 91 90 .29 2.62 8439.08 89.95 1.12 8532.84 88.88 1.40 8626.58 88.79 358.85 8721.97 87.22 2.35 .8814.74 87.44 5.92 8908.70 87.67 6.77 9001.83 92.89 5.57 9095.12 94.96 3.36 9187.89 90.32 1.57 9278.79 86.10 0.25 9372.85 86.35 0.69 9467.30 90.45 0.88 9559.12 91.46 0.09 9651.87 87.53 359.28 9747.59 85.10 357.28 9839.54 87.44 355.85 9934.18 86.17 353.39 10026.81 84.62 351.57 10119.00 83.19 354.26 10216.59 83.69 354.69 10302.43 84.94 352.68 10393.13 85.16 352.69 10484.54 86.99 353.01 10575.67 88.86 353.11 10665.86 89.30 356.79 - 11ato_ 1 ~-1`~n~,,, Cin~e: 1029:52 Page; 3 ('i~-unlin:uc(\ll Kcfrr~rnu:` Well. 1J-101,TfUeNorth ~ \crtic.il fll"I)I Rcl~~rcnce; 1J 101 10:9.0' 5cctinn 1A S) Rcl~icu~c: Well (O.OON,O:OOE,O-OOAzi) ~~~~,~~ ~ alculation Jlethod_ Minimum Curvature Rb: Oracle ~ . 1 \ U ~ ' ~ ~ ~ FI~~' lIapA -- Ma~E - - I T~oof ~ _ ft ~ ft ft ft- fC 3585.93 3608.26 580. 45 5949698. 48 559306. 55 MWD+IFR-AK-CAZ-SC 3586.97 3702.07 584. 41 5949792. 31 559309. 78 MWD+IFR-AK-CAZ-SC ~ 3587 87 3795.20 588. 35 5949885. 46 559312. 99 MWD+IFR-AK-CAZ-SC ' . 3588.24 3889.25 591. 00 5949979. 52 559314. 91 MWD+fFR-AK-CAZ-SC 3588.75 3981.94 591. 00 5950072. 20 559314. 19 MWD+IFR-AK-CAZ-SC 3589.69 4074.71 589. 07 5950164. 94 559311. 53 MWD+IFR-AK-CAZ-SC 3590 48 4169.06 584. 49 5950259. 24 559306. 22 MWD+IFR-AK-CAZ-SC ! . 3591.05 4260.89 579. 95 5950351. 03 559300. 97 MWD+IFR-AK-CAZ-SC ~ 3593.83 4355.22 577. 43 5950445. 33 559297. 70 MWD+IFR-AK-CAZ-SC 3601.00 4447.78 576. 58 5950537. 87 559296. 13 MWD+IFR-AK-CAZ-SC 3609.30 4541.26 576. 94 5950631. 34 559295. 77 MWD+IFR-AK-CAZ-SC ~ 3617.07 4634.31 578. 59 5950724. 39 559296. 69 MWD+IFR-AK-CAZ-SC ' 3625 54 4727.60 580. 73 5950817. 68 559298. 09 MWD+IFR-AK-CAZ-SC . 3629 17 4819.15 582. 15 5950909. 23 559298. 80 MWD+IFR-AK-CAZ-SC . 57 3625 4911.62 586. 46 5951001. 72 559302. 40 MWD+IFR-AK-CAZ-SC ~ . 3620.41 5004.98 594 .13 5951095. 13 559309. 33 MWD+IFR-AK-CAZ-SC 3616:27 5098.36 601. 58 5951188. 56 559316. 05 MWD+IFR-AK-CAZ-SC ~ 3612 59 5191.08 609 .62 5951281. 33 559323 .37 ~ MWD+iFR-AK-CAZ-SC . 3610 68 5283.85 618 .41 5951374. 16 559331 .44 MWD+IFR-AK-CAZ-SC . 3610 08 5378.18 627 .52 5951468. 55 559339 .81 MWD+IFR-AK-CAZ-SC ; . 3609.47 5470.54 634 .19 5951560. 94 559345 .75 MWD+IFR-AK-CAZ-SC 3609 27 5563.66 637. 23 5951654. 07 559348 .07 MWD+IFR-AK-CAZ-SC ~ . 23 3610 5657.39 639 .29 5951747. 81 559349 .40 MWD+IFR-AK-CAZ-SC . 14 3612 5751.10 639 .49 5951841. 51 559348 .87 MWD+IFR-AK-CAZ-SC . . 46 3615 5846.41 640 .49 5951936. 82 559349 .12 MWD+IFR-AK-CAZ-SC i . 3619.78 5938:82 647 .17 5952029. 27 559355 .08 MWD+IFR-AK-CAZ-SC 79 3623 6032.12 657 .55 5952122. 64 559364 .73 MWD+IFR-AK-CAZ-SC . 34 3623 6124.68 667 .55 5952215. 26 559374 .01 MWD+IFR-AK-CAZ-SC . 3616.95 6217.45 674 .80 5952308. 08 559380 .53 MWD+IFR-AK-CAZ-SC 68 3612 6310.01 678 .78 5952400. 66 559383 .79 MWD+IFR-AK-CAZ-SC . 3615.52 6400.83 680 .23 5952491. 48 559384 .53 MWD+IFR-AK-CAZ-SC 3621 71 6494.68 681 .00 5952585. 33 559384 .56 MWD+IFR-AK-CAZ-SC I . 3624,35 6589.07 682 .29 5952679. 71 559385 .12 MWD+IFR-AK-CAZ-SC I 3622 82 6680.87 683 .07 5952771. 50 559385 .18 MWD+IFR-AK-CAZ-SC ~ . 3623 63 6773.60 682 .56 5952864. 21 559383 .95 MWD+IFR-AK-CAZ-SC . 3629.79 6869.06 679 .69 5952959. 65 559380 .34 MWD+IFR-AK-CAZ-SC ~ 3635.77 6960.64 674 .19 5953051. 17 559374 .13 MWD+IFR-AK-CAZ-SC ' 04 3641 7054.71 665 .34 5953145. 16 559364 .54 MWD+IFR-AK-CAZ-SC . 48 3648 7146.24 653 .25 5953236. 59 559351 :74 MWD+IFR-AK-CAZ-SC j . 27 3658 7237.20 641 .95 5953327. 44 559339 .73 MWD+IFR-AK-CAZ-SC . 3669.42 7333.70 632 .61 5953423. 86 559329 .64 MWD+IFR-AK-CAZ-SC 3677 92 7418.59 623 .22 5953508. 67 559319 .58 MWD+IFR-AK-CAZ-SC . 3685 75 7508.22 611 .71 5953598. 19 559307 .38 MWD+IFR-AK-CAZ-SC ~ . 3692 01 7598.70 600 .36 5953688. 58 559295 .32 MWD+IFR-AK-CAZ-SC ` . 31 3695 7689.10 589 .36 5953778. 88 559283 .62 ~ MWD+IFR-AK-CAZ-SC . 3696.75 7778.91 581 .42 5953868. 62 559274 .98 MWD+IFR-AK-CAZ-SC 93 3697 7870.84 579 .06 5953960. 51 559271 .91 MWD+IFR-AK-CAZ-SC ' . 3699 17 7959.51 578 .54 5954049. 17 559270 .70 MWD+IFR-AK-CAZ-SC . 3698 68 8048.43 578 .89 5954138. 07 559270 .35 MWD+IFR-AK-CAZ-SC ~ . 82 3694 8135.50 579 .77 5954225 .14 559270 .55 MWD+IFR-AK-CAZ-SC . 3692.61 8227.72 581 .59 5954317 .37 559271 .65 MWD+IFR-AK-CAZ-SC 3694.20 8319.84 586 .05 5954409 .51 559275 .38 MWD+IFR-AK-CAZ-SC I \ I~ tt 3694.93 3695.97 3696.87 3697.24 3697.75 3698.69 3699.48 3700.05 3702.83 3710.00 3718.30 3726.07 3734.54 3738.17 3734.57 3729.41 3725.27 3721.59 3719.68 3719.08 3718.47 3718.27 3719.23 3721.14 3724.46 3728.78 3732.79 3732.34 3725.95 3721.68 3724.52 3730.71 3733.35 3731.82 3732.63 3738.79 3744.77 3750.04 3757.48 3767.27 3778.42 3786.92 3794.75 3801.01 3804.31 3805.75 10757.84 89. 23 0.27 3806. 93 10846.52. 89. 17 359.06 3808. 17 10935.45 91. 46 1.39 3807. 68 11022.62 93. 62 359.76 3803. 82 11114.92 89. 12 2.50 3801. 61 11207.16 88 .91 3.04 3803. 20 ~Halliburton Company. Global Report c'„ni~~;iii~ on ~~F'hilln ,las~~~ In~.~ (?~,-~,~; r.l!uaiur, ?i~dci Ji~it 5f~~~ ~ ~aruk 1J Pad Tell::. 1J-`1! 1 I ~~ellpaih: 1J-`t~~ 1 1-~ Sar.ec ~ll~ lucl Azini ft deq deg - 11296.94 89.55 2.77 11387.18 88.31 1.75 11447.53 83.87 1.57 ~' 11510.00 83.87 1.57 ~ _ - I ~~I) tike I~~U ft ft 3804.41 3695.41 3806.09 3697.09 3810.21 3701.21 3816.88 ~ 3707.88 Date: 1/24/2006 Time: 10'29'52 Page: 4 Co-oi-dinate(NE) Reference: Well 1J-101, True North Vertical (TVll) Reference: 1J-101 109.0 i Section (VS) Reference- Well (O.OON,O.OOE,O.OOAzi) Survc} Calculation Atefhod: Minimum Curvature Db: Orae{e _ - - _ - - A ti I, ~~ n7apN _' A1apI~; Thal ~I ~t it ft ft _ - - _ 8409.50 590.59 5954499.19 559279.23 MWD+IFR-AK-CAZ-SC 8499.65 594.15 5954589.36 559282.09 MWD+IFR-AK-CAZ-SC 8559.82 595.90 5954649.53 559283.36 MWD+IFR-AK-CAZ-SC 8621.91 597.60 5954711.63 559284.58 PROJECTED to TD Halliburton Company Global Report ~JEFII~:ITIVE 1 uuil~ ins: '~~51 ~ F'hi it .:~;F,~ ~lr llat~ _ ~ il; Iinir 12 ' ~ P I'irl~l: r i ur F;I i ' ~ni[ ' (o-ur~lm rt i,AI I R~ lcrrnci~: ^ - i~ 1 I 1111 T~ .ipe: u~ Ilo!1h ~ilr: I ui f _i ~. 1J ~., _l ~'crl u',tl 1 f 11)1 I r fc rcnrc: ~ J-10~ ~ F 1' 109 a ' ~\~~II: IJ- ~ I " ~ccuun IA ti~ I ~I~ r i ruiv: vveii ~U vuN O.OOE,O.OOAZI) I \v rllh:uh~ 1J-~~ Ii~~'~ i Sur~~~ t:~li~ulatinn ~luli,d: Minimum Curvat ure Db: Oracle Survey: Start Date: - -- -~ Company: Engineer: Tool: Tied-to: Fields Kuparuk RiverUnit North Slope Alaska United States i Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sys tem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 - __ - Site: Kuparuk 1J Pad Site Position: Northing: 5945919.64 ft Latitude: 70 15 46.258 N From: Map Easting: 558789.95 ft Longitude: 149 31 29.007 W Position Uncertainty: 0.00 ft North Referenc e: True Ground Level: 0.00 ft Grid Convergence: 0.45 deg Well: 1 J-101 Slot Name: Well Position: +N/-S 166.80 ft Northing : 5946086.15 ft Latitude:. 70 15 47.898 N ' +E/-W -34.32- ft Easting : 558754.33 ft Longitude: 149 31 30.005 W Position Uncertainty: 0.00 ft -- Wellpath: 1J-101 PB1 Drilled From: 1J-101 500292328670 Tie-on Depth: 5348.51. ft ! Current Datum: 1J-101PB1: Height 109.00 ft Above System D atum: Mean Sea Level ; Magnetic Data: 1/23/2006 Declination: 24.20 deg i Field Strength: 57564 nT Mag Dip Angle: 80.77 deg ~ Vertical Section: Depth From (TVl) ) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpa th Date: 1/23/2006 Validated: No Version: 4 Actual From To Surve Y Toolcode Tool Name ft ft 100.00 843.00 1J-101 gyro (100.00-843 .00) (0 CB-GYRO-SS Camera based gyro single shot 933.26 5396.00 1J-101 (933.26-5396.00) (0) MWD+IFR-AK-CAZ-SCMWD+IFR AK CAZ SCC 5446.54 8813.61 1J-101PB1 Anad~ill (5446.54-88 MWD+IFR-AK-CAZ -SCMWD+IFR AK CAZ SCC Survey r _ ~IU lu~l \iiui I\ I) - ti~v t'\I) \ti C;AV` - -- 11a1iA ~I.ilil T.riol ~, 8 ~ ,~ leg it ff ft ft ft „1l 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5946086.15 558754.33 TIE LINE 100.00 0.41 315.04 100.00 -9.00 0.18 -0.18 5946086.33 558754.15 CB-GYRO-SS 200.00 0.52 347:22 200.00 91.00 0.88 -0.54 5946087.02 558753.79 CB-GYRO-SS I 300.00 0.66 342.49 299.99 190.99 1.87 -0.81 5946088.01 558753.51 CB-GYRO-SS 400.00 0.75 345.17 399.98 290.98 3.05 -1.15 5946089.19 558753.16 CB-GYRO-SS i 500.00 1.13 351.65 499.97 390.97 4.66 -1.46 5946090.80 558752.83 CB-GYRO-SS 600.00 1.41 355.45 599.95 490.95 6.86 -1.70 5946093.00. 558752.58 CB-GYRO-SS 662.00 1.34 355.45 661.93 552.93 8.35 -1.82 5946094.48 558752.45 CB-GYRO-SS 752.00 1.60 0.61 751.90 642..90 10.65 -1.89 5946096.78 558752.36. CB-GYRO-SS 843.00 1.74 8.06 842.86 733.86 13.29 -1.68 5946099.42 558752.54 CB-GYRO-SS 933.26. 2.14 28.78 933.07 824.07 16.12 -0.68 5946102.27 558753.53 MWD+IFR-AK-CAZ-SC 1025.28 2.46 39.48 1025.01 916.01 19.15 1.40 5946105.31 558755.58 MWD+IFR-AK-CAZ-SC 1124.64 2.48 36.34 1124.28 1015.28 22.53 4.03 5946108.71 558758.19 MWD+IFR-AK-CAZ-SC 1.217.35 2.40 46.26 1216.91 1107.91 25.49 6.62 5946111.69 558760.76 MWD+IFR-AK-CAZ-SC 1308.28 2.69 45.39 1307.75 1198.75 28.30 9.52 5946114.52 558763.63 MWD+IFR-AK-CAZ-SC 1402.35 2.84 42.40 1401.71 1292.71 31.57 12.66 5946117.82 558766.74 MWD+IFR-AK-CAZ-SC 1495.88 2.50 43.81 1495.14 1386.14 34.76 15.64 5946121.02 .558769.69 MWD+IFR-AK-CAZ-SC ~Hallburton Company Global Report Cnnili.un: ~_n~ ~PLiih~ I~~F~~In~ U,ut: ~i~3i~wo Pmr. 16:'1826 Page: 1 - Iicl~l_ r.uF a~u~ f~i ~ i ~_!nit Co-ord inate(NE)lieference: W ell: iJ-101, True North ;ii~~: r `.u, ~~ru~. l r' _;ri Aw riva l ~ I ~U) 12c fcici~~c 1J 101PB1: 1-09.0 l1~~11: 1J 1~_~1 ~cc~inn I~ ~) R~~f~ r rnc~; Well (0 OON,O.OOE 0 OOAzi) ~ ~~clll,a~h: -"~~1('G1 >uncc (1il~~nlaui~u ~le~h~~t1: Mi nirri'umCurvatur -- -- - e nb Oracle Sinci~ \II~ lu~l ~ ~~i~~ I ~ I ~ ~_~ ~ Il 11 \ ~ L ~1' T flap\`' -- ~tapG -- Tool ft ft i[ (~ ft ft - 1589.49 3.84 39.66 - 1588.60 1479.60 38.64 19.05 - 5946124.94 - 558773.08 MWD+IFR-AK-CAZ-SC 1682.18 6.25 47.26 1680.93 1571.93 44.46. 24.74 5946130.80 558778.72 MWD+IFR-AK-CAZ-SC ; 1774.94 8.26 48.06 1772.94 1663.94 52.34 33.40 5946138.74 558787.32 MWD+IFR-AK-CAZ-SC 1867.72 9.77 44.90 1864.57 1755.57 62.37 43.92 5946148:86 .558797.76 MWD+IFR-AK-CAZ-SC 1961.04 12.22 43.06 1956.17. 1847.17 75.20 56.25 5946161.78 558809.99 MWD+IFR-AK-CAZ-SC 2054.22 15.21 40.29 2046.69 1937.69 91.73 70.89 5946178.42 558824.50 MWD+IFR-AK-CAZ-SC 2147.04 16.21 42.92 2136.04 2027.04 110.51 87.59 5946197.33 558841:05 MWD+IFR-AK-CAZ-SC 2270.88 17.86 44.57 2254.44 2145.44 136.69 112.69 5946223.71 558865.94 MWD+IFR-AK-CAZ-SC 2363.84 17.00 43.26 2343.13 2234.13 156.75 132.01 5946243.91 558885.10 MWD+IFR-AK-CAZ-SC 2457.01 16.37 43.11 2432.38 2323.38 176.25 150.31 5946263.55 558903.25 MWD+IFR-AK-CAZ-SC 2551.08 19.88 47.57 2521.77 2412.77 196.73 171.19 5946284.19 558923.96 MWD+IFR-AK-CAZ-SC 2644.35 23.68 43.48 2608.37 2499.37 221.03 195.79 5946308.68 558948.37 MWD+IFR-AK-CAZ-SC ' 2736.56 28.67 37.82 2691.11 2582.11 .251.96 222.12 5946339.81 558974.45 MWD+tFR-AK-CAZ-SC 2830.94 32.48 33.99 2772.37 2663.37 290.88 250.18 5946378.94 559002.21 MWD+IFR-AK-CAZ-SC 2924.19 37.30 30.72 2848.84 2739.84 335.95 278.63 5946424.24 559030.30 MWD+IFR-AK-CAZ-SC 3016.39 . .43.42 27.43 .2919.07 2810..07 388.15 307.53 5946476.65 559058.79 MWD+IFR-AK-CAZ-SC 3111.21 49.01 28.16 2984.65 2875.65 - 448.67 339.45 5946537.41 559090.24 MWD+IFR-AK-CAZ-SC 3203.20 53.02 26.61 3042.52 .2933.52 _ 512.16 372.31 5946601.15 559122,60 MWD+IFR-AK-CAZ-SC 3297.32 54.45 27.67 3098.19 2989.19 579.69 406.93 5946668.94 559156.69 MWD+IFR-AK-CAZ-SC 3391.15 54.17 26.32 .3152.93 3043.93 647.59 441.52 5946737.10 559190.75 MWD+IFR-AK-CAZ-SC 3484.69 60.93 26.02 3203.09 3094.09 718.39 476.31 5946808.17 559224.97 MWD+IFR-AK-CAZ-SC 3577.93 62.01 23.96 3247.63 3138.63 792.64 510.91 5946882.67 559258.99 MWD+tFR-AK-CAZ-SC 3666.88 66.03 19.22 3286.60 3177.60 866.96 540.26 5946957.22 559287.76 MWD+IFR-AK-CAZ-SC 3759.55 64:62 18.29 3325.29 3216.29 946.70 567.34 5947037.15 559314.21 MWD+IFR-AK-CAZ-SC 3850.67 70.00 18.24 3360.43 3251.43 1026.50 593.67 5947117.15 559339.92 MWD+IFR-AK-CAZ-SC i 3945.82 74.20 14.44 3389.68 3280.68 1113.36 619.10 5947204.20. 559364.67 MWD+IFR-AK-CAZ-SC i 4039.23 76.27 9.30 3413.50 3304.50 1201.72 637.65 5947292.69 559382.53 MWD+IFR-AK-CAZ-SC 4132.88 76.39 4.04 3435.64 3326.64 1292.07 648.22 5947383.11 559392.38 MWD+IFR-AK-CAZ-SC 4228.44 77.05 358.70 3457.61 3348.61 1385.01 650.44 5947476.06 559393.88 MWD+IFR-AK-CAZ-SC 4319.41 75.33 357.02 3479.32 3370.32 1473.28 647.14 5947564.29 559389.89. MWD+IFR-AK-CAZ-SC 4413.12 75.83 355.23 3502.66 3393.66 1563.82 641.01 5947654.78 559383.05 MWD+IFR-AK-CAZ-SC 4504.75 75.65 354.49 3525.23 3416.23 1652.27 633.05 5947743.15 559374.41 MWD+IFR-AK-CAZ-SC 4600.47 74.25 354.08 3550.09 3441.09 1744.25 623.85 5947835.04 559364.49 MWD+IFR-AK-CAZ-SC ! 4691.66 77.89 357.19 3572.04 3463.04 1832.47 617.13 5947923.21 559357.09 MWD+tFR-AK-CAZ-SC 4787.41 80.46 359.42 3590.02 3481.02. 1926.46 614.36 5948017.16 559353.58 MWD+IFR-AK-CAZ-SC 4880.13 82.40 359.64 3603.84 3494.84 2018.14 613.61 5948108.82 559352.11 MWD+IFR-AK-CAZ-SC 4973.71 81.99 359.62 3616.55 3507.55 2110.85 613.01 5948201.52 559350.79 MWD+{FR-AK-CAZ-SC ' 5065.65 81.49 358.80 3629.76 3520.76 2201.83 611.75 5948292.47 559348.83 MWD+IFR-AK-CAZ-SC 5161.00 82.14 358.13 3643.33 3534.33 2296.17 609.23 5948386.79 559345.56 MWD+tFR-AK-CAZ-SC 5255.29 80.37 359.75 3657.67 3548.67 2389.34 607.50 5948479.93 559343.11 MWD+IFR-AK-CAZ-SC 5348.51 80.61 359.01 3673.07 3564.07 2481.28 606.50 5948571.84 559341.40 MWD+IFR-AK-CAZ-SC 5446.54 82.90 356.82 3687.13 3578.13 2578.22 602.97 5948668.74 559337.11 MWD+IFR-AK-CAZ-SC ~ 5544.85 85.31 358.34 3697.23 3588.23 2675.91 598.84 5948766.39 559332.22 MWD+IFR-AK-CAZ-SC 5637.98 84.24 356.95 3705.71 3596.71 2768.57 595.03 5948859.01 - 559327.69 MWD+IFR-AK-CAZ-SC 5731.15 88.07 357.86 3711.95 3602.95 2861.42 590.83 5948951.81 559322.76 MWD+IFR-AK-CAZ-SC 5824.58 90.28 359.31 3713.30 3604.30 2954.80 588.52 5949045.17 559319.72 MWD+IFR-AK-CAZ-SC 5918.60 89.68 357.71. 3713.33 3604.33 3048.78 586.08 5949139.12 559316.54 MWD+IFR-AK-CAZ-SC 6011.02 91.92 357.32 3712.04 3603.04 3141.10 582.07 5949231.40 559311.82 MWD+IFR-AK-CAZ-SC 6104.95 91.64 358.33 3709.12 3600.12 3234,92 578.51 5949325.17 559307.52 MWD+fFR-AK-CAZ-SC 6198.84 89.48 358.49 3708.21 3599.21 3328.76 575.90 5949418.98 559304.19 MWD+IFR-AK-CAZ-SC 6292.17 92.97 .359.94 3706.21 3597.21 3422.05 574:62 5949512.25 559302.18 MWD+IFR-AK-CAZ-SC 6387.77 95.75 2.22 3698.94 3589.94 3517.34 576.42 5949607.54 559303.23 MWD+IFR-AK-CAZ-SC , 6478.92 89.30 2.86. 3694.93 3585.93 3608.26 580.45 5949698.48 559306.55 MWD+IFR-AK-CAZ-SC ~Halliburton Company Global Report ~~ni~run _'~'006 line. lu1 ~_ Page: 3 f. ~I, CI I ll;f ~~I~-lll (~I I I.I Li'I~I ~ ~l l' It'I't'll l'f': .. t' ~. ~~ ~~~, TfJ" IILI~h 1ilr: i'. ~_ l 'iU'r: 1J ~z'.~; ~'crlical (1~1~1)) Itcli~ rcncr: 1 101E 1. 109.0 ~1cll: 1 J 1 it tiecUn^ 1 ~~) 12~fcicn ~~~: .~ c ll iJ ii ail 0.00E O.QOAZI) ~~ cll~~.ul~: ~ ! I ~ 1 FG 1 ~ur~ c~~ ~ 'alculati~ui 1IcUu~~l: 'ain rm.im Curvature _ D6: Oracle ~urtr~ _ \Ifl Licl \~ini l~~ll ~}. ll ll V?ti L;11 AI;ipA JLi~ih Togl - ~'.eq sly%1 ff (t ft ft Tt {r 72.82 65 89.43 1.97 3695.97 3586.97 3702.07 584.41 5949792.31 559309.78 MWD+IFR-AK-CAZ-SC I 6666.04 89.46 2.88 3696.87 3587.87 3795.20 588.35 5949885.46 559312.99 MWD+IFR-AK-CAZ-SC 6760.14 90.09 .0.35 3697.24 3588.24 388925 591.00 5949979.52 559314.91 MWD+IfR-AK-CAZ-SC 6852.83 89.29 359.65 3697.75 3588.75 3981.94 591.00. 5950072:20 559314.19 MWD+IFR-AK-CAZ-SC 6945.63 89.54 357.96 3698.69 3589.69 4074.71 589.07 5950164.94 559311.53 MWD+IFR-AK-CAZ-SC 09 7040 89.50 356.49 3699.48 3590.48 4169.06 584.49 5950259.24 559306.22 MWD+IFR-AK-CAZ-SC . 04 7132 89.80 357.85 3700.05 3591.05. 4260.89 579.95 5950351.03 559300.97 MWD+IFR-AK-CAZ-SC . 46 7226 86.82 359.08 3702.83 3593.83 4355.22 577.43 5950445.33. 559297.70 MWD+IFR-AK-CAZ-SC . 31 7319 84.32 359.87 3710.00 3601.00 4447.78 576.58 5950537.87 559296.13 MWD+IFR-AK-CAZ-SC . 7413.16 85.53 0.58 3718.30 3609.30 4541.26 576.94 5950631.34 559295.77 MWD+IFR-AK-CAZ-SC 55 7506 84.93 1.45 3726.07 3617.07 4634.31 578.59 5950724.39 559296.69 MWD+IFR-AK-CAZ-SC . 7600.24 84.70 1.17 3734.54 3625.54 4727.60 580.73 5950817.68 559298.09 MWD+IFR-AK-CAZ-SC I 92 7691 90.76 0.61 3738.17 3629.17 4819.15 582.15 5950909.23 559298.80 MWD+IFR-AK-CAZ-SC . 59 7784 93.69 4.74 3734.57 3625.57 4911.62 586.46 5951001.72 559302.40 MWD+IFR-AK-CAZ-SC . 7878.41 92.61 4.65 3729.41 3620.41 5004.98 594.13 5951095.13 559309.33 MWD+IFR-AK-CAZ-SC 18 7972 92.45 - 4.47 3725.27 3616.27 5098:36 601.58 5951188.56 559316.05 MWD+IFR-AK-CAZ-SC . 32 8065 92.08 5.44 3721.59 3612.59 5191.08 609.62 5951281.33 559323.37 MWD+IFR-AK-CAZ-SC . 53 8158 90.27 5.39 3719.68 3610.68 5283.85 618.41 5951374.16 559331.44 MWD+IFR-AK-CAZ-SC . 30 8253 90.46 5.64 3719:08 3610:08 5378.18 627.52 5951468.55 559339.81 MWD+IFR-AK-CAZ-SC . 91 8345 90.29 2.62 3718.47 3609.47 5470.54 634.19 5951560.94 559345.75 MWD+IFR-AK-CAZ-SC . 08 8439 89.95 1.12 3718.27 3609.27 5563.66 637.23 5951654.07 559348.07 MWD+IFR-AK-CAZ-SG . 84 8532 88.88 1.40 3719.23 3610.23 5657.39 639.29 5951747.81 559349.40 MWD+IFR-AK-GAZ-SC . 07 8627 89.31 0.48 3720.72 3611.72 5751.59 640.84 5951842.01 559350.21 MWD+IFR-AK-CAZ-SC , ` . 74 8719 89.31 357.90 3721.84 3612.84 5844.24 639.53 5951934.64 559348.17 MWD+IFR-AK-CAZ-SC . 8778.57 88.24 355.30- 3723.09 3614.09 5902.94 636.04 5951993.31 559344.23 MWD+IFR-AK-CAZ-SC 61 8813 86.60 349.73 3724.67 3615.67 5937.64 631.48 5952027.96 559339.40 MWD+IFR-AK-CAZ-SC . .8877.00 86.60 349.73 3728.43 3619.43 5999.90 620.20 5952090.13 559327.64 PROJECTED to TD • ConocoPhillips March 3, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-101, 1 J-101 L1, 1 J-101 L2 Dear Commissioner: P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1 J-101, 1 J-101 L1, 1 J- 101 L2. if you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells RT/skad • • AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-101 B1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,348.51' MD Window /Kickoff Survey: 8,813.61' MD (if applicable) Projected Survey: 8,877.00' MD 05-Feb-06 a05-1~2- PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~2-'r'7 L~~ Signed ~' ~ ~ ~~ ! ~ t Please call me at 273-3545 if you a any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • 05-Feb-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 J-101 Dear Dear Sir/Madam: Enclosed is one disk with the .PTT and *.PDF files. Tie-on Survey: 8,532.84' MD Window /Kickoff Survey: 11,447.53' MD (if applicable) Projected Survey: 11,510.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~~ Date ~~' r'7~C~(~ Signed ~ -~,). _' %; Please call me at 273-3545 if you have any questions or oncerns. Regards, Carl Ulrich Survey Manager Attachment{s} J$J 5 1 J z~ ' s = ~~ ~ 1~, ~ ~ ~ ~. ~ ~ ~ j ~°',~ ;,'~~~~ (, ~ ~ , °~ ~ ~ ~ ~ FRANK H. MURKOWSKI, GOVERNOR ~~a~ ~~_~~~+g~ ~7~ OI~ ~ ~ ~~ 333 W. 7"' AVENUE, SUITE 100 CO1~T5ERQA7`IOI•T COD'II~'IISSIOI~T ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: West Sak 1J-101 ConocoPhillips Alaska, Inc. Permit No: 205-182 Surface Location: 2247' FSL, 2453' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 346' FSL, 1846' FEL, SEC. 23, T11N, R10E, 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 conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24} hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907} 659- 3607 (pager). DATED this day of November, 2005 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.ThomasC~conocophillips.com November 10, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 • ~E~~~ ~'~ NOV 15 z~ ~I~tki Oil & G>s~ C~~~~. ~:,~~~,.,~,~~.~~ Anlchor~pa Re: Applications for Permit to Drill, West Sak Producer, 1J-101, 1J-101 Ll, iJ-101 L2 Dear Commissioners: ~,. ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a trilateral '' horizontal well in the West Sak ~~A2", ~~B"and ~~D" sands. The main bore of the well will be designated 1J- 101, and the lateral bores of the well will be designated 1J-101L1 and 1J-101L2. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1J-101 is November 23, 2005. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RE~~IVE~ Nav 1 ~ 200 L,l- Alaska Oii & Gas Cons. Commissidn Anchorage 1a. Type of Work: Drill / Redrill Re-entry ^ 1b. Current Well Class: Exploratory Development Oil / Multiple Zone ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone 0 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 1J-101 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 11518' TVD: 3861' ' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface:,2N247~FSL, 2453' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Property Designation: ADL 25661 & 25650 ~ West Sak Oil Pool ` Top of Productive Horizon`. ^ ` ~ ~jJt ~ ~ y~.;~ 422' FNL, 1840'-F~PdC~Sec. 35, T11 N, R10E, UM 8. Land Use Permit: ALK 471 & 468 13. Approximate Spud Date: 11123!2005 Total Depth: ~ 346' FSL, 1846' FEL, Sec. 23, T11N, R10E, UM 9. Acres in Property: 2560 14. Distance to > 7ooe, r fL 1,,1. S~'.JC Nearest Properly: 2247' ~~ ~""'~ ~~ /~~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558754 ~ y- 5946086 ~ Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: 1 D-132 , 1224' @ 11518' 16. Deviated wells: Kickoff depth: 1550 " ft. Maximum Hole Angle: 92.5° deg 17. Maximum Anticipated Pressures in psig (see 2Q AAC 25.035) Downhole: 1737 psig Surface: 1313 psig ' 18. Casing Program ifi S ti Setting Depth Quantity of Cement Size pec ca ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' ~ 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 2181' 28' 28' 2209' - 2199' 460 sx ASLite, 140 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 5462' 28' 28' 5490' " 3712' 310 sx DeepCRETE 6.75" 4.5" 12.6# L-80 BTCM 6026' 5490' 3712' 11516' ' 3856' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Pertoration Depth MD (ft): Pertoration Depth TVD (ft): 20. Attachments: Filing Fee ^/ BOP Sketch Drilling Program ^/ Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 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 Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~~Y ` Phone ~ ~- ~~ 3~ Date t l ll ~f~o 5- P b r n All k Commission Use Only Permit to Drill Number: ~~,~ -' l~~ API Number: 50- ~-~~~ "" 2 ~~ ~ ~ r ~~~-~ Permit Approval Date: See cover letter for other requirements Conditions of approval S p s required Yes ^ No ~ Mud log required Yes ^ No y ogen sulfide measures Yes ^ No ~` Directional survey required Yes ~ No ^ Other: 3 °` ~~cs~ ca~.Q-lc~b`1~F o lZo.~ c~.cc-e~.~C~.~- ~ae~~~~c .~o AR~~.S 035 ~h1 APPROVED BY Approved by: ~~~ THE COMMISSION Date: / ~/ (/ . t ~ S'~6, ~) Form 10-401 Rev ed 06/2004 ~ ~ ~) ~~ r~ ~ Submit in Duplicate • ~ation for Permit to Drill, Well 1J-101 Revision No.0 Saved: 9-Nov-05 Permit It -West Sak Well #1J-101 Application for Permit to Drill Document M d x i m i x~ WWII ~'v1Ue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (~ • ....................................................................................•-•---............ 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.D05 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling-Fluid Program .............................................................................................4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (LSND) ............................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals ........................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 1J-101 PERMIT IT Page 1 of 8 Panted: 9-Nov-05 • ~ation for Permit to Drill, Well 1J-101 Revision No.O Saved: 9-Nov-05 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) .:.............................................................................................. 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan ......................................................~-~--.................................................... 8 Attachment 2 Drilling Hazards Summary .............................................................................................. 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 5 % Mile Radius Effect for Injector ..................................... Error! Bookmark not defined. Attachment 6 BOP Configuration ........................................................................................................... 8 1. Well Name Requirements of 20 AAC 25.005 (fl Each we!! must be identified 6y a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a well with mu/tip/e we//branches, each branch must similarly be identified by a unique name andAPl number by adding a suffix to the name designated for the well by the operator and to the number assigned to the we/1 by the commission. The well for which this Application is submitted will be designated as 1J-101. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An app/ication far a Permit to ®ril/ must be accompanied by each of the following items, except for an item afready on file with the commission and identified in the application; (2) a plat identifying the property and the property`s owners and showing (A)che coordinates of the proposed lacation of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmenta/section lines. (B) the coordinates of the proposed location of the we/I at the sun`ace, referenced to the state plane coordinate system far this state as maintained 6y the National Geodetic Survey in the Natr"ona/ Oceanic and Atmospheric Administration; (C) the proposed depth ofthe we/I at the top ofeach objective formation and at Iota/ depth; Location at Surface 2 'FSL, 2,453' FEL, Section 35, T11N 810E ASP zone 4 /VAD 27 Coordinates ~" ~ RKB Elevation 109.0' AM S L Northings: 5,946,086 'Eastings: 558,754 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "A2" Sand ~~ c. ~~' r~~~ ~~ ~~~~' 422' FNL, 1,840'~L, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates MeaSUred De th, RKB,' 5,463 Northings: 5,948,674 Eastings: 559,344 Total l/ertica/ De th, RKB: 3,692 Total t/ertica/De th, SS.' 3,583 Location at Total De th 346' FSL, 1 846' FEL, Section 23, T11N, R10E ASP Zone 4 NAD 27 Coordinates MeaSU/'ed De th, RKB.' 11,518 Northings.' 5,954,721 Eastings: 559,285 Total ~ertica/De th RKB: 3,861 Total I/ertical De th, SS.' 3,752 1J-101 PERMIT IT Page 2 of 8 Printed: 9-Nov-05 and (D) other information required by 20 AAC ZS.OSD(b); ~ation for Permit to Drill, Well 1J-101 Revision No.O Saved: 9-Nov-05 Requirements of 20 AAC 25.050(b) If a we/! is to be intentionally deviated, the app/ication far a Permit to Drill (Form 10-401) must (I) inc/ude a p/at, drawn to a suitab/e scale, showing the path of the proposed we//bore, inc/ud/ng a//adjacent we//bores within 200 feet of any portion of the proposed wel% Please see Attachment 1: Directional Plan and (2) for a// we//s within 200 feet of the proposed wel/bore (A) list the names of the operators of those we//s, to the extent that those names are known or drscoverab/e in public records, and show that each named operator has been furnished a copy of the application by certifred mail; or (B) state that the app//cant is the on/y affected owner. The Applicant is the only affected owner 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 fol%wing items,. except for an item already on fi/e with the commission and identified in the app/ication; (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC ZS 035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete the well. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 7-5/8"rams in the lowermost cavity. See attached diagram entitled "Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). Immediately prior to running the intermediate string of 7-5/8" casing, a test plug will be set below the lowermost rams, and those rams will be closed and tested to 3,000 psi on a 7-5/8" OD. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An apply"catr"on for a Permit to Dri/1 must be accompanied by each of the fo/%wing items, except far an item already an fr/e wr"th the commission and identified in the app/ication.• (4) information on dri/Gng hazards, Inc/uding (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potentia/surface pressure based on a methane gradient, The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). These pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,281 psi, calculated thusly: MPSP =(3,861 ft TVD)(0.45 - 0.11 psi/ft) =1,313 psi % (B) data on potential gas zones,• The well bore is not expected to penetrate any gas zones. ~~ and (C) data concerning potentia/ causes ofho% prob/ems such as abnorma//y geo pressured strata, /ost circulation zones, and zones that have a propensity for differentia! sticking; Please see Attachment 2: Drilling Hazards Summary. 1J-101 PERMIT lT Page 3 of 8 Printed: 9-Nov-05 ORIGINAL • ration for Permit to Drill, We{I 1J-101 Revision No.O Saved: 9-Nov-05 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item a/ready an fi/e with the commission and identified in the application: (5} a description of the procedure for conducting formation integrity tests, as required under 20 AAC25.030(f}; 7-5/8" intermediate casing will be landed at the top of the West Sak A2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except far an item a/ready on fi/e with the commission and identified in the application,• (6} a camp/ete proposed casing and cementing program as required by 20 AAC 25.03f1, and a description of any slotted liner, pre- perfarated liner, ar screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm CsglTbg Size Weigh Length MDITVD MD/TVD OD in in t lb/ft Grade Connection ft ft ft Cement Pro ram 20 x 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 2,181 28 / 28 2,209 /2,199 460 sx ASLite Lead, drift 140 sx DeepCRETE Tail Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 5,462 28 / 28 5,490 / 3,712 2.476' MD / 2,497' TVD. Cemented w/ 310 sx Dee CRETE 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 6,026 5,490 / 3,712 11,516 / 3,855 Slotted- no cement Slotted Lateral (1J-164) 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 7,113 4,540/ 3,533 11,653 / 3,696 Slotted- no cement slotted Lateral (1J-164 Ll) 4-1/2 6-3/4" D Sand 12.6 L-80 IBTM 7,521 4,197/ 3,459 11,718 / 3,639 Slotted- no cement slotted Lateral (1J-164 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An app/icatian far a Permit to Dri/l must be accompanied by each of the fa//awing items, except far an item already an file wr"th the commission and identified in the application: (7} a diagram and description of the diverter system as required by 24 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2}; A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1J-164. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 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 fa//ow/ng items, except far an item a/ready an file with the commission and identified in the application: (8} a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-101 PERMIT IT Page 4 of 8 Printed: 9-Nov-05 ~R1~1~AL • Surface Hole Mud Program (extended bentonite) ~ation for Permit to Drill, Well 1 J-101 Revision No.0 Saved: 9-Nov-05 Spud to Base of Permafrost Sase of Permafrost to 10-3j4" Casin Point Initial Value Final Value Initial Value Final Value Density (pPg) 8.9 9.2 9.5 9.6 Funnel Viscosity 150 250 200 300 seconds yield Point 50 70 30 50 cP Plastic Viscostiy 20 45 15 20 Ib/100 s pH 8.5 9.0 8.5 9.0 API Filtrate NC 8 0 5 0 7 0 cc / 30 min . . . *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) 10-3/4"Cs Shoe to 7-5/8"Cs Point Value Density (ppg) 9.0 - 9.1 Funnel Viscosity 45 - 60 (seconds) Plastic Viscostiy 12 - 18 (Ib/100 sf) Yield Point 26 - 35 (cP API Filtrate 4 - 6 (cc / 30 min Chlorides (mg/I) <S00 pH 9.0 - 9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals Value Densit pg 8.6 Plastic Viscostiy Ib/100 s 15 - 25 Yield Point 18 - 28 cP HTHP Fluid loss (ml/30 min @ 200psi & <4.0 150° Oil I Water Ratio 70 / 30 Electrical >600 Stabilit Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Dri1/ must be accompanied by each of the following items, except for an item a/ready on fr/e with the commission and identified in the app/ication, (9) for an exploratory or stratigraphic test we/% a tabulation setting out the depths afpredicted abnormafiy geo pressured strata as required by 20 AAC25.033(~ Not applicable: Application is not for an exploratory or stratigraphic test well 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication far a Permit to Ori// must be accompanied by each of the fo//awing items,. except for an item already on file with the commission and identified m the applicatian; (10) for an explanatory or stratigraphic test we/% a seismic refraction ar retJection analysis as required by 20 ,4AC 25, 061(a); Not applicable:. Application is not for an exploratory or stratigraphic test well. 1J-101 PERMIT IT Page 5 of 8 Panted: 9-Nov-05 ORIGINAL /~tion for Permit to Drill, Well 1J-101 Revision No.0 Saved: 9-Nov-05 11. Seabed Condition Ana{ysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the fallowing items, except for an item already on file with the commission and identified in the application: (11) for a well dril/ed from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vesset, an analysis ofseabed conditions as required by 2I1 AAC25.061(b); Not applicable: 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 Dri!l must be accompanied by each of the fallowing items, except for an item already on file with the commission and identified in the application; (12) eNdence showing that the requirements of20 AAC 25.1125 {Sonding}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 app/ication for a Permit to ®ri/l must be accompanied by each of the lot/awing items, except for an item a/ready on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. ` Install landing ring on conductor. 2. Move in /rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 2,209' MD / 2,199' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8" bit and 6-1/4"drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 5,490 MD / 3,695' TVD, the prognosed top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 2,976' MD / 2,866' TVD if Ugnu B is uppermost oil bearing formation. Top of cement to be 500 feet (MD) above shallowest oil bearing sand.). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. li. Flush 10-3/4" x 7-5/8"annulus with water, followed by diesel 12. PU 6-3/4" PDC Bit and 4-3/4" drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (expected ECD's in 6-3/4" lateral modeled to be less than 12.0 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 11,516' MD / 3,856' TVD as per directional plan.. 1J-101 PERMIT lT Page 6 of 8 j"~ t ~ ~ A t /~ ~ Printed: 9-Nov-05 C, ~ation for Permit to Drill, Well 1J-101 Revision No.O Saved: 9-Nov-05 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 16. Run USIT log for cement bond if the well is an injector. ~r~1 S ~~cc `~'`~ 17. PU and run 4-1/2" slotted liner. 18. Land liner, set liner hanger @ +/- 4,630' MD. POOH. Note: .Remaining operations are covered under the 1]-164L1 Application for Permit to Drill, and are provided here for information only. ~.p5-~~s3 19. Run and set Baker WindowMaster whipstock system, at window point of 4,540' MD / 3,533' TVD, the top of the B sand. 20. Mill 6-3/4" window. POOH. 21. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 22. Drill to TD of B sand lateral at 11,653' MD / 3,696' TVD, as per directional plan. 23. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 25. PU and run 4-1/2"slotted liner. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool., POOH. 28. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the iJ-164L2 Application for Permit to Drill, and are provided here for information only. ass- ~~ ~ 29. Run and set Baker WindowMaster whipstock system, at window point of 4,197' MD / 3,459' TVD, the top of the D sand. 30. Mill 6-3/4" window.. POOH. 31. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 32. Drill to TD of D sand lateral at 11,718' MD / 3,639' TVD, as per directional plan. 33. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 34. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 35. PU and run 4-1/2" slotted liner. 36. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 37. Release hanger running tool. 38. POOH and lay down drill pipe. 39. RU and run a 4 1/2" ESP completion with backup gaslift. 40. Space out tubing and land tubing in tubinghead. 41. Nipple down BOPE, nipple up tree and test, change over the hole to diesel 42. Set BPV and RDMO Doyon 141. 1J-101 PERMITlT Page 7 of 8 Printed: 9-Nov-05 ORIGINAL L~ 43. Rig up wire line unit. Pull BPV. 44. Circulate out well with diesel through the ESP. ~tion for Permit to Drill, Well 1J-101 Revision No.O Saved: 9-Nov-05 45. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 46. Replace gas lift valves with blank dummy valves. 47. Place well on production with ESP. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the app/ication; (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under ZO AAC 25.080 For an annu/ar disposal operation in the we/l.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1] Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 BOP Configuration Attachment 5 Schematic 1J-101 PERMIT /T Page 8 of 8 j`> ~"'~j ~ /""~ ~ ~ } ~ ~ Printed: 9-Nov-05 • • Conoco hiilips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-101 Plan: 1J-101 (wp04) Proposal Report 19 October, 2005 !-!~-,LLI E3!! R"T~L7lV p~err ~r~1in~ rv-~+~s oQiGINAL COCIOCOP~'1l~~[~35 Alaska LEGEND $ Plan 1J-101, Plan 1J-101 L1, 1J-101 L1 (wp04) $ Plan 1J-101, Plan 1J-101 L2, 1J-101 L2 (wp04) $ 1J-101 (wD041 Sail @ 30° Inc : 2617ft MD, 2571ft ND p ~20,~ ~ ~ Continue Build @ 5°I100ft , 2717ft MD, 2658ft ND ~', ~ ~ Begin Pump Tangent - Sait @ 55°Inc & 28°Azi : 3244ft MD, 3044ft TV~ 0 ~ Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-101 Wellbore: Plan 1J-101 Plan: 1J-101 (wp04) SHL @ 2274ft FSL & 2453ft FEL- Sec 35 - T11 N - R10 KOP @ 1550ft MD, 1550ft ND -Build @ 2.5°/100ft ~' rContinue Build @ 3°I100ft , 1950ft MD, 1948ft N i ~ i ' i i 10 314" CSG : 2209ft MD, 2199ft ND i ~ ~ FORMATION TOP DETAILS N3.VDPath MDPath Formation 1 1540.001540.00 Permafrost 2 1645.001645.03 T3 3 1935.00 1936.83 K15 4 2198.00 2207.73 T3~550 5 2926.00 3058.02 Ugnu C 6 3177.00 3476.47 Ugnu B 7 3254.00 3619.89 Ugnu A 8 3298.00 3710.91 K73 9 3460.00 4201.84 D @ 77° 10 3504.00 4397.44 West Sak C 113536.00 d554.23 B @ 80° 12 3575.00 4778.82 West Sak A4 133618.00 5026.45 West Sak A3 14 3692.00 5463.09 A2 @ 84° I CASING DETAILS 1 No TVD MD Name Size 1 108.00 108.00 20" 20 2 2199.00 2208.78 10 3l4" 10-3/4 3 3695.11 5490.40 7 5/8" 7-5/8 4 3861.40 11518.14 4 1l2" 4-1 /2 - i i _ '~i pemlafrosC, End Pump Tangent -Continue BuildlTurn @ 5°NOOft , 3464ft MD, 3170ft ND 1000 ,' ~~ , -' ~ ~ T3 ' - - 1500 ........ -... 0` , 2000 4000 4500 K15! , . ~ Geosteer Across Fault -Reacquire Lower Lobe: 8736ft MD, 3724ft TVD i _ ~~ ~~ . ..... ..............._....._ 1. ~ __ - 10° ~ Continue GeoSteering in A2 Lateral, 8780ft MD, 3725ft ND T3+550' 20° _~.-emu ~ 3Q , ~ Sail @ 77° Inc : 4133ft MD, 3445ft N r i ~ ;Ugnu g Np ° , - ~~Sail @ 80° Inc : 4540ft MD, 3534ft ND ~ BHL @ 346ft FSL 8 1846ft FEL -Sec 23 - T11N - R10~ i .' tlnuA'. ~h~ '~ ,,-'~ Build@3°I100ft1080°Inc-4440ftMD,3514ft ND ~ ,~ ~ ,~ _ i K ,~ 13 - _-- ~ 4 1/2" __ - .-_-- --~- r. - - - - ,' ~ . .. ................ .................. .................. ......... .................... .........•- . ........... . .s. ~.~....._-~.-v. ....................... ....... .-. .... ~ 1 --. -. •- - ... _ - y...t..~~`. ...- ~ --.-.- ....f-~ _ --- - .-.- _ ,~ ~ , ~ 8 @ 8t}' ~ 1J-101 Ti - Dtop (wp04)'I ~ ~ ~ ~ ~ ~ ~ ~ ~ West Sak A4 ~, ~ ~ ~ ~ ~ ~~ ~ ~~ I1J-101 T11 (wp04)j i . ~. ~ ~ ~ ~ ~ ~ , ~ ~~ i Wast Sak A3 ~ ~~\ ~\ ~\ ~ ~\ ~ ~ ~ i 1J-101 T10 (wp04) ~ ` ~ ~ ' ~ ` ~ '~,~~`I ~ ~~ ~~ ~` ~~ ~~ ~~ `~~ 1J-101 T9(wp04) Build @ 4°1100ft to 80°Inc - 5390ft MD, 3681ft N ~ ~ ~ ~ ~i ~ `~ ~ ~ ~ 1J-101 T8 (wp04) '~ ~ ~ , ~ ~ 1J-101 T3 -Peak 1 (wp04) ~ 1J-101 TS -Peak 2 (wp04) ~~ 1J-101 T7 (wp04) Build @ 0.7°I100ft Inc - 5836ft MD, 3724ft ND -Begin Undulatio s ~ ~ '.7 5/8" CSG : 5490ft MD, 3695[1 ND~. 1J-101 T2 `Trough 1 (wp04) ~~ 1J-101 T4 -Trough 2 (wp04) 1J-101 T6 (wp04) )0 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 Vertical Section at 0.00° (1000 ft/in) 1"' Ct~nc~c©Phillips Alaska 11 IBHL@346ftFSL81846kFEL-Sec 23-T11N-R1D~ ~ ~~~~~- CASING DETAILS No TVD MD Name Size 1 108.00 108.00 20" 20 2 2199.00 2208.78 10 3/4" 10-314 3 3695.11 5490.40 7 5/8" 7-5/8 4 3861.40 11518.14 4 1l2" 4-1Y1 T M agnelic North: 24.32° Magnetic Field Strength. 57561.1 nT Dip Angle: 80.76° Date: 10/5/2005 Model: BGGM2005 4.1/2" __`\ ~_ ---_--1 __ _ _ \.... _. -..-_..L__ -~_ -_ -_ ___ '~ - - - - 1 J-101 T11 (wp04~ 1J-101 T6 (wp04 Continue GeoSteering in A2 Lateral, 8780ft MD, 3725ft ND ,Geosteer Across Fault -Reacquire Lower Lobe: 87360 MD, 3724ft NDI 1250 ~ -1 c_ 0 N r Z guild @ 4°/1000 Inc - 5690ft MD, 3716ft TVD -Begin Undulations L 7 0 to a ~f`. FN '. if.44h « ~ f 11M11 - ~ ,tE 549Cf' bi D- 3695n Build @ 4°/t00ft to 80° Inc - 53908 MD, 3681ft ND 360° 1J-101 T10 (wp04 360° 1J-101 T9 (wp04 ~~- - - - - ' - ' - - 1J-001 TB (wp04 360° 1J-101 T 360' _ _ ^ _ ^ _ _ .-~1J-101 TS -Peak 2 (wp04i 1J-101 T4 -Tough 2 (wrp04 1J-101 T3 -Peak 1 (wp04 1J-101 T2 -Trough 1 (wp0~ 0° Sail @ 80° Inc : 4540ft MD, 3534ft ND ~~ _ _ _ _ 0° Build @ 3°/100ft to 80° Inc - 4440fl MD, 3514ft ND - -- - -- _. -- Sail @ 77° Inc : 4133ft MD, 34458 ND _ _ _ _ _ _ _ 3~ ------------- n° Ii II 1J-101 T1 - Dtop (wp04 ~/, , EtidPump Tangs-Continua BuiWlfpm @ 5°MQOft , 3464fF M4, 3170k II Continue Build @ 5°/100fl , 2717ft MD, 2658ft ND ,- __ _ - - - I' _ _ _ _ _ . - 3~° ' , _ , _ - _- -, - . (Sail @ 30 Inc : 2617ft MD, 2571ft ND -_--_.._z_ __ _ . ''sue. *~.. -~______---- SHL @ 2274tt FSL 8 2453ft FEL- Sec 35 T11 N - R10~ ° ~ i i ~. i ~ Continue Build @ 3°/t00ft , 1950ft MD, 1948fl ND r KOP @ 1550ft MD, 1550fl ND -Build @ 2.5°/100ft 25 -2500 -1875 -1250 1250 1875 2500 3125 3750 4375 fUin) n-' ~~~~~~~~- Halliburton Company Pl i R rt G hi HaL~~BUATC~N -~------°- - _ ~~-~~ ann ng - eograp c epo A{~s~a Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-101 Company: ConocoPhillips Alaska {Kuparuk) TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) Site: Kuparuk 1J Pad North Reference: True Wetl: Plan 1J-101 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-101 Design: 1J-101 (wp04) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-101 Well Position +Ni-S 0.00 ft Northing: 5,946,086.15 ft Latitude: 70° 15' 47.898" N +E/-W 0.00 ft Easting: 558,754.33 ft Longitude: 149° 31' 30.005" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore Plan 1J-101 Magnetics Model Name Sample Date Declination (°) BGGM2005 10/5!2005 24.32 Design 1J-101 (wp04) Audit Notes: Version: Vertical Section 10/19/2005 3:52:44PM Phase: Depth From (TVD) (ft) 28.00 • PLAN +N/-S (ft) 0.00 • Dip Angle Field Strength (°) (nT) 80.76 57,561 Tie On Depth: +El-W Direction (ft) (°) 0.00 0.00 Page 2 of 90 Q~IGINAL 28.00 COMPASS 2003.11 Buiid 48 r.-' +~~na-~+~~aili[ps Aiask~ Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad WeII: Plan 1J-101 Wellbore: Plan iJ-101 Design: 1J-101 (wp04) Halliburton Com an P Y l-1ALLIBIJRTON Planning Report -Geographic - - - sperry bf=illing Services Local Co-ordinate Reference: Well Plan 1J-101 TVD Reference: Plan RKB @, 109.OOft (Doyon 141 (81 + 28)) MD Reference: Plan RKB ~ 109.OOft (Doyon 141 (81 + 28)) North Reference: True Survey Calculation Method: Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N(-S +E/_yy Rate Rate Rate TFO (ft) (°} (°) (ft) (ft) (ft) (°/100ft) (°l100ft) (°/100ft) (°) 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 1,550.00 0.00 0.00 1,550.00 0.00 0.00 0.00 0.00 0.00 0.00 1,950.00 10.00 40.50 1,947.97 26.48 22.61 2.50 2.50 0.00 40.50 2,616.67 30.00 40.50 2,571.26 198.98 169.94 3.00 3.00 0.00 0.00 2,716.67 30.00 40.50 2,657.86 237.00 202.42 0.00 0.00 0.00 0.00 3,243.93 55.08 28.00 3,043.92 533.34 392.88 5.00 4.76 -2.37 336.44 3,463.93 55.08 28.00 3,169.85 692.62 477.57 0.00 0.00 0.00 0.00 4,133.30 77.00 360.00 3,444.58 1,277.76 610.19 5.00 3.27 -4.18 -56.04 4,197.40 77.00 360.00 3,459.00 1,340.22 610.19 0.00 0.00 0.00 0.00 4,440.40 77.00 360.00 3,513.66 1,576.99 610.19 0.00 0.00 0.00 0.00 4,540.40 80.00 0.00 3,533.60 1,674.97 610.19 3.00 3.00 0.00 0.00 5,390.40 80.00 0.00 3,681.20 2,512.06 610.19 0.00 0.00 0.00 0.00 5,490.40 ~ 84.00 0.00 3,695.11 2,611.06 610.19 4.00 4.00 0.00 0.00 5,690.40 84.00 0.00 3,716.02 2,809.97 610.19 0.00 0.00 0.00 0.00 5,836.15 89.83 359.95 3,723.86 2,955.45 610.13 4.00 4.00 -0.03 -0.49 6,222.15 92.53 359.95 3,715.90 3,341.33 609.79 0.70 0.70 0.00 0.00 6,417.15 92.53 359.95 3,707.29 3,536.14 609.62 0.00 0.00 0.00 0.00 6,802.22 89.43 359.95 3,700.68 3,921.11 609.29 0.80 -0.80 0.00 -180.00 7,188.22 87.50 359.95 3,711.00 4,306.95 608.95 0.50 -0.50 0.00 180.00 7,383.22 87.50 359.95 3,719.49 4,501.76 608.78 0.00 0.00 0.00 0.00 7,769.26 89.48 359.95 3,729.63 4,887.65 608.45 0.51 0.51 0.00 0.00 8,155.26 91.03 359.95 3,727.91 5,273.63 608.11 0.40 0.40 0.00 0.00 8,350.26 91.03 359.95 3,724.41 5,468.60 607.94 0.00 0.00 0.00 0.00 8,736.26 89.10 359.95 3,723.98 5,854.58 607.60 0.50 -0.50 0.00 -180.00 8,779.58 88.35 359.52 3,724.95 5,897.90 607.40 2.00 -1.74 -0.99 -150.21 9,127.77 88.35 359.52 3,735.00 6,245.92 604.48 0.00 0.00 0.00 0.00 9,201.47 89.75 359.98 3,736.23 6,319.62 604.16 2.00 1.90 0.63 18.22 9,827.88 89.75 359.98 3,739.00 6,946.02 603.94 0.00 0.00 0.00 0.00 9,872.58 88.41 359.86 3,739.72 6,990.71 603.88 3.00 -2.99 -0.27 -174.75 10,026.97 88.41 359.86 3,744.00 7,145.05 603.50 0.00 0.00 0.00 0.00 10,084.29 86.70 360.00 3,746.45 7,202.31 603.42 3.00 -2.99 0.24 175.36 10,527.83 86.70 360.00 3,772.00 7,645.11 603.40 0.00 0.00 0.00 0.00 10,542.83 86.27 359.87 3,772.92 7,660.08 603.38 3.00 -2.88 -0.85 -163.60 10,728.28 86.27 359.87 3,785.00 7,845.14 602.96 0.00 0.00 0.00 0.00 10,791.83 84.37 359.64 3,790.19 7,908.47 602.69 3.00 -2.98 -0.37 -173.00 11,518.15 84.37 359.64 3,861.40 8,631.28 598.09 0.00 0.00 0.00 0.00 10119/2005 3:52:44PM Page 3 of 10 COMPASS 2003.11 Build 48 C~C1ACa~"fi~~l~5 ~~ Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-101 Wellbore: Plan 1J-101 Design: 1J-101 (wp04) Planned Survey 1J-101 (wp04) Halliburton Company t-~A~ai~uaronr Pianning Report -Geographic - °~w - --- Sp~erry Dvllitng Servtces Local Co-ordinate Reference: Well Plan 1J-101 TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) MD Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) North Reference: True ~ Survey Calculation Method: Minimum Curvature MD Inclination Azimuth TVD SSTVD 1ft) (°) l°) (ft) (ft1 .28.00 0.00 0.00 28.00 -81.00 SHL @ 2274ft FSL & 2453ft FEL-Sec 35 - T11 N - R10E ~" 100.00 0.00 0.00 100.00 -9.00 108.00 0.00 0.00 108.00 -1.00 20" Map Map +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (ft) ~~) (ft) (°l100ft) (ft) 0.00 0.00 5,946,086.15' 558,754.33 - 0.00 0.00 0.00 0.00 5,946,086.15 558,754.33 0.00 0.00 0.00 0.00 5,946,086.15 558,754.33 0.00 0.00 200.00 0.00 0.00 200.00 91.00 0.00 0.00 5,946,086.15 300.00 0.00 0.00 300.00 191.00 0.00 0.00 5,946,086.15 400.00 0.00 0.00 400.00 291.00 0.00 0.00 5,946,086.15 500.00 0.00 0.00 500.00 391.00 0.00 0.00 5,946,086.15 600.00 0.00 0.00 600.00 491.00 0.00 0.00 5,946,086.15 700.00 0.00 0.00 700.00 591.00 0.00 0.00 5,946,086.15 800.00 0.00 0.00 800.00 691.00 0.00 0.00 5,946,086.15 900.00 0.00 0.00 900.00 791.00 0.00 0.00 5,946,086.15 1,000.00 0.00 0.00 1,000.00 891.00 0.00 0.00 5,946,086.15 1,100.00 0.00 0.00 1,100.00 991.00 0.00 0.00 5,946,086.15 1,200.00 0.00 0.00 1,200.00 1,091.00 0.00 0.00 5,946,086.15 1,300.00 0.00 0.00 1,300.00 1,191.00 0.00 0.00 5,946,086.15 1,400.00 0.00 0.00 1,400.00 1,291.00 0.00 0.00 5,946,086.15 1,500.00 0.00 0.00 1,500.00 1,391.00 0.00 0.00 5,946,086.15 1,540.00 0.00 0.00 1,540.00 1,431.00 0.00 0.00 5,946,086.15 Permafrost 1,550.00 0.00 0.00 1,550.00 1,441.00 0.00 0.00 5,946,086.15 KOP @ 1550ft MD, 1550ft TVD -Build @ 2.5°l1 00ft ~' 1,600.00 1.25 40.50 1,600.00 1,491.00 0.41 0.35 5,946,086.57 1,645.03 2.38 40.50 1,645.00 1,536.00 1.50 1.28 5,946,087.66 T3 1,700.00 3.75 40.50 1,699.89 1,590.89 3.73 3.19 5,946,089.91 1,800.00 6.25 40.50 1,799.50 1,690.50 10.36 8.85 5,946,096.58 1,900.00 8.75 40.50 1,898.64 1,789.64 20.28 17.32 5,946,106.57 1,936.83 9.67 40.50 1,935.00 1,826.00 24.77 21.15 5,946,111.08 K15 1,950.00 10.00 40.50 1,947.97 1,838.97 26.48 22.61 5,946,112.80 Continue Bu ild @ 3°l1 00ft , 1950ft MD,1948ft TVD 2,000.00 11.50 40.50 1,997.09 1,888.09 33.57 28.67 5,946,119.94 2,100.00 14.50 40.50 2, 094.52 1, 985.52 50.67 43.28 5, 946,137.15 2,200.00 17.50 40.50 2,190.63 2,081.63 71.63 61.18 5,946,158.25 2,207.73 17.73 40.50 2,198.00 2,089.00 73.41 62.70 5,946,160.04 T3+550 2,208.78 17.76 40.50 2,199.00 2,090.00 73.65 62.90 5,946,160.28 10 3t4" CSG @ 2348ft FSL & 2390Pt FEL -Sec 35 - T11N - R 10E : 2209ft MD, 2199ft TVD -10 3!4" 2,300.00 20.50 40.50 2,285.18 2,176.18 96.38 82.32 5,946,183.16 2,400.00 23.50 40.50 2,377.88 2,268.88 124.86 106.64 5,946,211.83 2,500.00 26.50 40.50 2,468.50 2,359.50 157.00 134.09 5,946,244.17 2,600.00 29.50 40.50 2,556.79 2,447.79 192.69 164.57 5,946,280.10 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.33 0.00 0.00 558,754.68 2.50 0.41 558,755.60 2.50 1.50 558,757.49 2.50 3.73 558,763.09 2.50 10.36 558,771.49 2,50 20.28 558,775.29 2.50 24.77 558,776.73 2.50 26.48 558,782.73 3.00 33.57 558,797.21 3.00 50.67 558,814.94 3.00 71.63 558,816.44 3.00 73.41 558,816.65 3.00 73.65 558,835.89 3.00 96.38 558,859.99 3.00 124.86 558,887.18 3.00 157.00 558,917.38 3.00 192.69 10/?9/2005 3:52:44PM page 4 of 10 ORIGINAL COMPASS 2003.?? Build 48 t~tltKt~~"li~~l~S Aiasl~~ Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska {Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-101 Wellbore: Plan 1J-101 Design: 1J-101 {wp04) Planned Survey 1J-101 (wp04) • Halliburton Company H~-c.uBUATON Planning Report -Geographic -~- ~ ~~ Sperry Drilling Services Local Coordinate Reference: Well Plan 1J-101 TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) MD Reference: Plan RKB @ 109.OOft {Doyon 141 {81 + 28)) North Reference: True Survey Calculation Method: Minimum Curvature Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) 2,616.67 30.00 40.50 2,571.26 2,462.26 198.98 169.94 5,946,286.43 Sail @ 30° Inc : 2617ft MD, 2571ft TVD 2,700.00 30.00 40.50 2,643.43 2,534.43 230.66 197.01 5,946,318.32 2,716.67 30.00 40.50 2,657.86 2,548.86 237.00 202.42 5,946,324.70 Continue Build @ 5°i100ft , 2717ft MD, 2658ft TVD 2,800.00 33.86 37.51 2,728.58 2,619.58 271.27 230.09 5,946,359.18 2,900.00 38.56 34.64 2,809.25 2,700.25 319.04 264.79 5,946,407.22 3,000.00 43.32 32.30 2,884.77 2,775.77 373.71 300.86 5,946,462.16 3,058.02 46.10 31.13 2,926.00 2,817.00 408.44 322.31 5,946,497.05 Ugnu C 3,100.00 48.12 30.35 2,954.57 2,845.57 434.87 338.03 5,946,523.61 3,200.00 52.95 28.67 3,018.11 2,909.11 502.06 376.01 5,946,591.08 3,243.93 55.08 28.00 3,043.92 2,934.92 533.34 392.88 5,946,622.49 Begin Pump Tangent -Sail @ 55° Inc & 28°Azi : 3244ft MD, 3044ft TVD 3,300.00 55.08 28.00 3,076.01 2,967.01 573.94 414.46 5,946,663.25 3,400.00 55.08 28.00 3,133.26 3,024.26 646.33 452.96 5,946,735.94 3,463.93 55.08 28.00 3,169.85 3,060.85 692.62 477.57 5,946,782.40 End Pump Tangent -Co ntinue BuildRurn @ 5°/100ft , 3464ft MD, 3170ft TVD 3,476.47 55.43 27.37 3,177.00 3,068.00 701.74 482.36 5,946,791.57 Ugnu B 3,500.00 56.10 26.20 3,190.24 3,081.24 719.11 491.12 5,946,809.00 3,600.00 59.06 21.42 3,243.87 3,134.87 796.32 525.13 5,946,886.47 3,619.89 59.67 20.51 3,254.00 3,145.00 812.30 531.25 5,946,902.49 Ugnu A 3,700.00 62.18 16.94 3,292.94 3,183.94 878.60 553.69 5,946,968.96 3,710.91 62.53 16.47 3,298.00 3,189.00 887.86 556.47 5,946,978.24 K13 3,800.00 65.44 12.71 3,337.08 3,228.08 965.32 576.60 5,947,055.84 3,900.00 68.81 8.71 3,375.95 3,266.95 1,055.82 593.68 5,947,146.47 4,000.00 72.28 4.88 3,409.26 3,300.26 1,149.42 604.79 5,947,240.14 4,100.00 75.81 1.20 3,436.75 3,327.75 1,245.40 609.86 5,947,336.15 4,133.30 77.00 360.00 3,444.58 3,335.58 1,277.76 610.19 5,947,368.51 Saii @ 77° In c : 4133ft MD, 3445ft TVD 4,197.40 77.00 360.00 3,459.00 3,350.00 1,340.22 610.19 5,947,430.96 13-101 T1 - Dtop (wp04) 4,200.00 77.00 360.00 3,459.59 3,350.59 1,342.75 610.19 5,947,433.49 4,201.84 77.00 360.00 3,460.00 3,351.00 1,344.55 610.19 5,947,435.29 D@77° 4,300.00 77.00 360.00 3,482.08 3,373.08 1,440.19 610.19 5,947,530.92 4,397.44 77,00 360.00 3,504.00 3,395.00 1,535.13 610.19 5,947,625.85 West Sak C 4,400.00 77.00 360.00 3,504.58 3,395.58 1,537.63 610.19 5,947,628.34 Map Fasting DLSEV Vert Section (ft) (°h QOft) (ft) 558,922.70 3.00 198.98 558,949.51 0.00 230.66 558,954.87 0.00 237.00 558,982.28 5.00 271.27 559,016.60 5.00 319.04 559,052.24 5.00 373.71 559,073.42 5.00 408.44 559,088.93 5.00 434.87 559,126.38 5.00 502.06 559,143.00 5.00 533.34 559,164.26 0.00 573.94 559,202.19 0.00 646.33 559,226.43 0.00 692.62 559,231.15 5.00 701.74 i 559,239.78 5.00 t 719.11 559,273.18 5.00 796.32 559,279.17 5.00 812.30 I 559,301.10 5.00 878.60 I 559,303.80 5.01 887.86 559,323.32 5.00 965.32 559,339.69 5.00 1,055.82 559,350.07 5.00 1,149.42 559,354.39 5.00 1,245.40 559,354.48. 5.00 1,277.76 559,353.99 0.00 1,340.22 559,353.97 0.00 1,342.75 559,353.96 0.00 1,344.55 559,353.21 0.00 1,440.19 559,352.47 0.00 1,535.13 559,352.45 0.00 1,537.63 10/19/2005 3:52:44PM Page 5 of 10 COMPASS 2003.11 Build 48 ~~~~ ~ J ~+~-' Halliburton Company t~!C'id+~t)1~~1~3~ Planning Report -Geographic r"Jaska Database: EDM 2003.11 Single User Db Local Coordinate Reference: Company: ConocoPhiliips Alaska (Kuparuk) TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-101 Survey Calculation Method: Wellbore: Plan 1J-101 Design: 1J-101 (wp04) ' Planned Survey 1J-101 (wp04) HAGL.I~iUATlt71N Sperry Drillliing Services Well Plan 1J-101 Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) True Minimum Curvature Map MD Inclination Azimuth ND SSND +N/-S +E/-W Northing (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) 4,440.40 77.00 360.00 3,513.66 3,404.66 1,576.99 610.19 5,947,667.70 Build @ 3°/100ft to 80 ° Inc - 4440ft MD, 3514ft ND 4,500.00 78.79 360.00 3,526.16 3,417.16 1,635.26 610.19 5,947,725.97 4,540.40 80.00 0.00 3,533.60 3,424.60 1,674.97 610.19 5,947,765.67 Sail @ 80° Inc : 454pft MD, 3534ft ND 4,554.23 80.00 0.00 3,536.00 3,427.00 1,688.59 610.19 5,947,779.29 B @ 80° 4,600.00 80.00 0.00 3,543.95 3,434.95 1,733.67 610.19 5,947,824.36 4,700.00 80.00 0.00 3,561.31 3,452.31 1,832.15 610.19 5,947,922.83 4,778.82 80.00 0.00 3,575.00 3,466.00 1,909.77 610.19 5,948,000.44 West Sak A4 4,800.00 80.00 0.00 3,578.68 3,469.68 1,930.63 610.19 5,948,021.30 4,900.00 80.00 0.00 3,596.04 3,487.04 2,029.11 610.19 5,948,119.76 5,000.00 80.00 0.00 3,613.41 3,504.41 2,127.59 610.19 5,948,218.23 5,026.45 80.00 0.00 3,618.00 3,509.00 2,153.64 610.19 5,948,244.28 West Sak A3 5,100.00 80.00 0.00 3,630.77 3,521.77 2,226.07 610.19 5,948,316.70 5,200.00 80.00 0.00 3,648.14 3,539.14 2,324.55 610.19 5,94$,415.17 5,300.00 80.00 0.00 3,665.50 3,556.50 2,423.03 610.19 5,94$,513.64 5,390.40 80.00 0.00 3,681.20 3,572.20 2,512.06 610.19 5,948,602.65 Build @ 4°/100ft to 80 ° Inc - 5390ft MD, 3681ft ND 5,400.00 80.38 0.00 3,682.83 3,573.83 2,521.52 610.19 5,948,612.11 5,463.09 82.91 0.00 3,692.00 3,583.00 2,583.93 610.19 5,948,674.52 A2 @ 84° 5,490.40 84.00 0.00 3,695.11 ' 3,586.11 2,611.06 610.19 5,948,701.64 7 518" CSG @ 395ft FNL & 1840ft FEL -Sec 35 - T11N - R 10E : 5490ft MD, 3695ft ND - 75!8" 5,500.00 84.00 0.00 3,696.12 3,587.12 2,620.61 610.19 5,948,711.19 5,600.00 84.00 0.00 3,706.57 3,597.57 2,720.07 610.19 5,948,810.63 5,690.40 84.00 0.00 3,716.02 3,607.02 2,809.97 610.19 5,948,900.52 Build @ 4°/100ft Inc - 5690ft MD , 3716ft ND - Begin Undulations 5,700.00 84.38 360.00 3,716.99 3,607.99 2,819.52 610.19 5,948,910.08 5,800.00 88.38 359.96 3,723.30 3,614.30 2,919.30 610.16 5,949,009.84 5,836.15 89.83 359.95 3,723.86 3,614.86 2,955.45 610.13 5,949,045.99 Build @ 0.7°/100ft, 58 36ft MD, 3724ft ND -1J-101 T2 -Trough 1 (wp04) 5,900.00 90.28 359.95 3,723.80 3,614.80 3,019.30 610.08 5,949,109.83 6,000.00 90.98 359.95 3,722.71 3,613.71 3,119.29 609.99 5,949,209.81 6,100.00 91.68 359.95 3,720.39 3,611.39 3,219.26 609.90 5,949,309.76 6,200.00 92.38 359.95 3,716.85 3,607.85 3,319.20 609.81 5,949,409.69 6,222.15 92.53 359.95 3,715.90 3;606.90 3,341.33 609.79 5,949,431.82 Sail @ 92.53° Inc : 6222ft MD, 3716ft ND 6,300.00 92.53 359.95 3,712.47 3,603.47 3,419.10 609.73 5,949,509.58 6,400.00 92.53 359.95 3,708.05 3,599.05 3,519.01 609.64 5,949,609.47 6,417.15 92.53 359.95 3,707.29 3,598.29 3,536.14 609.62 5,949,626.60 Drop @ 0.8°l100ft, 6417ft MD, 3707ft ND Map Fasting DLSEV Vert Section (ft) (°7100ft) (ft) 559,352.14 0.00 1,576.99 559,351.69 3.00 1,635.26 559,351.38 3.00 1,674.97 559,351.27 0.00 1,688.59 559,350.92 0.00 1,733.67 559,350.15 0.00 1,832.15 559,349.55 0.00 1,909.77 559,349.38 0.00 1,930.63 559,348.62 0.00 2,029.11 559,347.85 0.00 2,127.59 559,347.64 0.00 2,153.64 559,347.08 0.00 2,226.07 559,346.31 0.00 2,324.55 559,345.54 0.00 2,423.03 559,344.85 0.00 2,512.06 559,344.77 3.99 2,521.52 559,344.29 4.00 2,583.93 559,344.07 4.00 2,611.06 559,344.00 0.00 2,620.61 559,343.22 0.00 2,720.07 559,342.52 0.00 2,809.97 559,342.45 3.99 2,819.52 559,341.63 4.00 2,919.30 559,341.32 4.00 2,955.45 559,340.77 0.70 3,019.30 559,339.90 0.70 3,119.29 559,339.04 0.70 3,21926 559,338.17 0.70 3,319.20 559,337.98 0.70 3,341.33 559,337.30 0.00 3,419.10 559,336.43 0.00 3,519.01 559,336.29 0.00 3,536.14 10119/2005 3:52:44PM Page 6 of 10 OR161NAL COMPASS 2003.11 Build 48 • ~C~CIt~CC}P~1~~I ~JJS A ~~sk~ Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project; Kuparuk River Unit Site; Kuparuk 1J Pad Well: Plan 1J-101 Wellbore: Plan 1J-101 Design: 1J-101 (wp04) Planned Survey 1J-101 (wp04) Map MD Inclination Azimuth ND SSND +N/-S +EI-W Northing 6,500.00 91.87 359.95 3,704.11 3,595.11 3,618.93 609.55 5,949,709.38 6,600.00 91.06 359.95 3,701.56 3,592.56 3,718.89 609.47 5,949,809.33 6,700.00 90.26 359.95 3,700.41 3,591.41 3,818.89 609.38 5,949,909.31 6,800.00 89.45 359.95 3,700.66 3,591.66 3,918.89 609.29 5,950,009.29 6,802.22 89.43 359.95 3,700.68 3,591.68 3,921.11 609.29 5,950,011.51 Drop @ 0.5°l100ft : 68 02ft MD, 3701ft ND -1J -101 T3 -Peak 1 (wp04) 6,900.00 88.95 359.95 3,702.07 3,593.07 4,018.87 609.20 5,950,10927 7,000.00 88.45 359.95 3,704.34 3,595.34 4,118.85 609.12 5,950,209.23 7,100.00 87.95 359.95 3,707.49 3,598.49 4,218.80 609.03 5,950,309.17 7,185.22 87.50 359.95 3,711.00 3,602.00 4,306.95 608.95 5,950,397.31 Sail @ 87.50° Inc : 7188ft MD, 371 1ft TVD 7,200.00 87.50 359.95 3,711.51 3,602.51 4,318.72 608.94 5,950,409.07 7,300.00 87.50 359.95 3,715.86 3,606.86 4,418.62 608.85 5,950,508.96 7,383.22 87.50 359.95 3,719.49 3,610.49 4,501.76 608.78 5,950,592.10 Build @ 0.5°1100ft - 7383ft MD, 3719ft ND 7,400.00 87.59 359.95 3,720.21 3,61121 4,518.53 608.77 5,950,608.86 7,500.00 88.10 359.95 3,723.96 3,614.96 4,618.46 608.68 5,950,708.77 7,600.00 88.62 359.95 3,726.83 3,617.83 4,718.42 608.59. 5,950,808.72 7,700.00 89.13 359.95 3,728.79 3,619.79 4,818.40 608.51 5,950,908.68 7,769.26 89.48 359.95 3,729.63 3,620.63 4,887.65 608.45 5,950,977.93 Build @ O.d°l100ft - 7769ft MD, 3 730ft ND -1 J-101 T4 -Tough 2 (wp04) 7,800.00 89.61 359.95 3,729.88 3,620.88 4,918.39 608.42 5,951,008.67 7,900.00 90.01 359.95 3,730.21 3,621.21 5,018.39 608.33 5,951,108.65 8,000.00 90.41 359.95 3,729.85 3,620.55 5,118.39 608.24 5,951,208.64 8,100.00 90.81 359.95 3,728.79 3,619.79 5,218.38 608.16 5,951,308.62 8,155.26 91.03 359.95 3,727.91 3,618.91 5,273.63 608.11 5,951,363.86 Sail @ 91° Inc : 8155ft MD, 3728ft ND 8,200.00 91.03 359.95 3,727.11 3,618.11 5,318.37 608.07 5,951,408.59 8,300.00 91.03 359.95 3,725.31 3,616.31 5,418.35 607.98 5,951,508.56 8,350.26 91.03 359.95 3,724.41 3,615.41 5,468.60 607.94 5,951,558.80 Drop @ 0.5°I100ft : 8350ft MD, 37 24ft 7VD 8,400.00 90.78 359.95 3,723.62 3,614.62 5,518.34 607.89 5,951,608.53 8,500.00 90.28 359.95 3,722.70 3,613.70 5,618.33 607.81 5,951,708.51 8,600.00 89.78 359.95 3,722.65 3,613.65 5,718.33 607.72 5,951,808.50 8,700.00 89.28 359.95 3,723.47 3,614.47 5,818.33 607.63 5,951,908.48 8,736.26 89.10 359.95 3,723.98 3,614.98 5,854.58 607.60 5,951,944.73 Geosteer Across Fauft -Reacquire Lower Lobe: 8736ft MD, 3724ft ND -1J-101 T5 -Peak 2 (wp04) 8,779.58 88.35 359.52 3,724.95 3,615.95 5,897.90 607.40 5,951,988.04 Continue GeoSteering in A2 Late ral, 8780ft MD, 3725ft ND 8,800.00 88.35 359.52 3,725.54 3,616.54 5,918.30 607.23 5,952,008.44 8,900.00 88.35 359.52 3,728.43 3,619.43 6,018.26 606.39 5,952,108.38 9,000.00 88.35 359.52 3,731.31 3,622.31 6,118.21 605.55 5,952,208.31 9,100.00 88.35 359.52 3,734.20 3,625.20 6,218.17 604.71 5,952,308.25 9,127.77 88.35 359.52 3,735.00 3,626.00 6,245.92 604.48 5,952,336.00 1J-101 T6 (wp04) 9,200.00 89.72 359.97 3,736.22 3,627.22 6,318.14 604.16 5,952,408.21 559,309.12 2.00 6,318.14 • Haiiiburton Company ria~t~suAroro Planning Report -Geographic -~-~---~ - - - rry felling ~®rvice~ Local Co-ordinate Reference: Well Plan 1J-101 ND Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) MD Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) North Reference: True Survey Calculation Method: Minimum Curvature Map Fasting DLSEV Vert Section (ft) (°/100ft) (ft) 559,335.57 0.80 3,618.93 559,334.70 0.80 3,718.89 559,333.83 0.80 3,818.89 559,332.97 0.80 3,918.89 559,332.95 0.80 3,921.11 559,332.10 0.50 4,018.87 559,331.23 0.50 4,118.85 559,330.36 0.50 4,218.80 559,329.60 0.50 4,306.95 559,329.50 0.00 4,318.72 559,328.63 0.00 4,418.62 559,327.91 0.00 4,501.76 559,327.76 0.51 4,518.53 559,326.90 0.51 4,618.46 559,326.03 0.51 4,718.42 559,325.16 0.51 4,818.40 559,324.56 0.51 4,887.65 559,324.30 0.40 4,918.39 559,323.43 0.40 5,018.39 559,322.56 0.40 5,118.39 559,321.69 0.40 5,218.38 559,321.21 0.40 5,273.63 559,320.83 0.00 5,318.37 559,319.96 0.00 5,418.35 559,319.52 0.00 5,468.60 559,319.09 0.50 5,518.34 559,318.22 0.50 5,618.33 559,317.36 0.50 5,718.33 559,316.49 0.50 5,818.33 559,316.17 0.50 5,854.58 559,315.63 2.00 5,897.90 559,315.30 0,00 5,918.30 559,313.69 0.00 6,018.26 559,312.07 0.00 6,118.21 559,310.45 0.00 6,218.17 559,310.00 0.00 6,245.92 10/13/2005 3:52:44PM Page 7 of 10 COMPASS 2003.118ui1d 48 + i-18SK~ Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-101 Wetlbore: Plan 1J-101 Design: 1J-101 (wp041 HaNiburton Company HALLtBU#~TOlrl Planning Report -Geographic - Sperry Llrfiling ~e*rvices Local Co-ordinate Reference: Well Plan 'IJ-101 TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) MD Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) North Reference: True Survey Calculation Method: Minimum Curvature !,Planned Survey 1J-101 (wp04) __ _ _ _ _ __ Map Map MD Inclination Azimuth TVD SSTVD +NI-S +Ej-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°MOOft) (ft) 9,201.47 89.75 359.98 3,736.23 3,627.23 6,319.62 604.16 5,952,409.68 559,309.10 2.00 6,319.62 9,300.00 89.75 359.98 3,736.66 3,627.66 6,418.14 604.13 5,952,508.19 559,308.30 0.00 6,418.14 9,400.00 89.75 359.98 3,737.11 3,628.11 6,518.14 604.09 5,952,608.18 559,307.49 0.00 6,518.14 9,500.00 89.75 359.98 3,737.55 3,628.55 6,618.14 604.06 5,952,708.17 559,306.67 0.00 6,618.14 9,600.00 89.75 359.98 3,737.99 3,628.99 6,718.14 604.02 5,952,808.15 559,305.86 0.00 6,718.14 9,700.00 89.75 359.98 3,738.43 3,629.43 6,818.14 603.99 5,952,908.14 559,305.04 0.00 6,818.14 9,800.00 . 89.75 359.98 3,738.88 3,629.88 6,918.14 603.95 5,953,008.12 559,304.23 0.00 6,918.14 9,827.88 89.75 359.98 3,739.00 3,630.00 6,946.02 603.94 5,953,036.00 559,304.00 0.00. 6,946.02 1J-101 T7 (wp04) 9,872.58 88.41 359.86 3,739.72 3,630.72 6,990.71 603.88 5,953,080.69 559,303.59 3.00 6,990.71 9,900.00 88.41 359.86 3,740.48 3,631.48 7,015.12 603.81 5,953,108.09 559,303.31 0.00 7,018.12 10,000.00 88.41 359.86 3,743.25 3,634.25 7,118.08 603.56 5,953,208.04 559,302.28 0.00 7,118.08 10,026.97 88.41 359.86 3,744.00 3,635.00 7,145.05 603.50 5,953,235.00 559,302.00 0.00 7,145.05 1J-101 T8 (wp04) 10,084.29 86.70 360.00 3,746.45 3,637.45 7,202.31 603.42 5,953,292.26 559,301.48 3.00 7,202.31 10,100.00 86.70 360.00 3,747.35 3,638.35 7,217.99 603.42 5,953,307.94 559,301.36 0.00 7,217.99 10,200.00 86.70 360.00 3,753.11 3,644.11 7,317.82 603.42 5,953,407.76 559,300.57 0.00 7,317.82 10,300.00 86.70 360.00 3,758.87 3,649.87 7,417.66 603.41 5,953,507.58 559,299.79 0.00 7,417.66 10,400.00 86.70 360.00 3,764.64 3,655.64 7,517.49 603.41 5,953,607.40 559,299.00 0.00 7,517.49 10,500.00 86.70 360.00 3,770.40 3,661.40 7,617.33 603.40 5,953,707.22 559,298.22 0.00 7,617.33 10,527.83 86.70 360.00 3,772.00 3,663.00 7,645.11 603.40 5,953,735.00 559,298.00 0.00 7,645.11 1J-101 T9 (wp04) 10,542.83 86.27 359.87 3,772.92 3,663.92 7,660.08 603.38 5,953,749.97 559,297.87 3.00 7,660.08 10,600.00 86.27 359.87 3,776.64 3,667.64 7,717.13 603.25 5,953,807.01 559,297.29 0.00 7,717.13 10,700.00 86.27 359.87 3,783.16 3,674.16 7,816.92 603.02 5,953,906.78 559,296.28 0.00 7,816.92 10,728.28 86.27 359.87 3,785.00 3,676.00 7,845.14 602.96 5,953,935.00 559,296.00 0.00 7,845.14 1J-101 T10 (wp04) 10,791.83 84.37 359.64 3,790.19 3,681.19 7,908.47 602.69 5,953,998.32 559,295.23 3.00 7,908.47 10,800.00 84.37 359.64 3,790.99 3,681.99 7,916.60 602.63 5,954,006.45 559,295.12 0.00 7,916.60 10,900.00 84.37 359.64 3,800.79 3,691.79 8,016.12 602.00 5,954,105.95 559,293.71 0.00 8,016.12 11,000.00 84.37 359.64 3,810.60 3,701.60 8,115.63 601.37 5,954,205.45 559,292.30 0.00 8,115.63 11,100.00 84.37 359.64 3,820.40 3,711.40 8,215.15 600.74 5,954,304.95 559,290.89 0.00 8,215.15 11,200.00 84.37 359.64 3,830.21 3,721.21 8,314.67 600.10 5,954,404.45 559,289.48 0.00 8,314.67 11,300.00 84.37 359.64 3,840.01 3,731.01 8,414.18 599.47 5,954,503.95 559,288.07 0.00 8,414.18 11,400.00 84.37 359.64 3,849.82 3,740.82 8,513.70 598.84 5,954,603.44 559,286.66 0.00 8,513.70 11,500.00 84.37 359.64 3,859.62 3,750.62 8,613.21 598.21 5,954,702.94 559,285.26 0.00 8,613.21 i 11,518.15 84.37 359.64 3,861.40 3,752.40 8,631.28 598.09 5,954,721.00 559,285.00 0.00. 8,631.28 r BHL @ 346ft FSL R 1846ft FEL -Sec 23 - T11 N - R10E - 41 /2" -1J-101 T11 (wp04) 10/19/2005 3:52:44PM Page 8 of 10 .COMPASS 2003.11 Build 48 ~ r' Halliburton Com an p Y " ~~t'1ACtJl~~1 i Pl R rt G hi HALLIE~ ~~~- - Llia TON - ~ - - -~ ann ng epo - eograp c Alaska s!TY D~ill! (ng Srarvices Database: EDM 2003.11 Single User Db Local Co-ordinate R eference: Well Plan 1J-101 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-101 Survey Calculation Method: Minim um Curvatur e Wellbore: Plan 1J-101 Design: 1J-101 (wp04j Geologic Targets Plan 1J-101 - __ TVD Target Name +N/-S +E!-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,772.00 1J-101 T9 (wp04) 7,645.11 603.40 5,953,735.00 559,298.00 - Point 3,739.00 1J-101 T7 (wp04) 6,946.02 603.94 5,953,036.00 559,304.00 - Point 3,723.98 1J-101 T5 -Peak 2 (wp04} 5,854.58 607.60 5,951,944.73 559,316.17 - Point 3,723.86 1J-101 T2 -Trough 1 (wp04} 2,955.45 610.13 5,949,045.99 559,341.32 - Point 3,744.00 1J-101 T8 (wp04) 7,145.05 603.50 5,953,235.00 559,302.00 - Point 3,459.00 1J-101 T1 - Dtop (wp04) 1,340.22 610.19 5,947,430.96 559,353.99 - Point 3,700.68 1J-101 T3 -Peak 1 (wp04} 3,921.11 609.29 5,950,011.51 559,332.95 - Point 3,729.63 1J-101 T4 -Tough 2 (wp04) 4,887.65 608.45 5,950,977.93 559,324.56 - Point 3,735.00 1J-101 T6 (wp04) 6,245.92 604.48 5,952,336.00 559,310.00 - Point 3,785.00 1J-101 T10 (wp04} 7,845.14 602.96 5,953,935.00 559,296.00 - Point 3,861.40 1J-101 T11 (wp04} 8,631.28 598.09 5,954,721.00 559,285.00 - Point -- - ~ - _ Prognosed Casing _ Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 108.00 108.00 20 26 2,205.78 2,199.00 10-3/4 13-1/2 5,490.40 3,695.11 7-5/8 9-718 11,518.14 3,861.40 4-1/2 63f4 10/19/2005 3:52:44PM Page 9 of 10 COMPASS 2003.118ui1d 48 ~~~ri t~ ~ r-' Halliburton C ompany C)M'1C3C0 1~~i~ Planning Report -Geographic A1<~ ~~a Database: EDM 2003.11 S ingle User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kupar uk) ND Reference: Project: Kuparuk River U nit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-101 Survey Calculation Method: Wellbore: Plan 1J-101 Design: 1J-101 (wpG~i Prognosed Form ation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +FJ-W eft) ~°) (°) eft) eft) (ft) 1,540.00 0.00 0.00 1,540.00 0.00 0.00 1,645.03 2.38 40.50 1,645.00 1.50 1.28 1,936.83 9.67 40.50 1,935.00 24.77 21.15 2,207.73 17.73 40.50 2,198.00 73.41 62.70 3,058.02 46.10 31.13 2,926.00 408.44 322.31 3,476.47 55.43 27.37 3,177.00 701.74 482.36 3,619.89 59.67 20.51 3,254.00 812.30 531.25 3,710.91 62.53 16.47 3,298.00 887.86 556.47 4,201.84 77.00 360.00 3,460.00 1,344.55 610.19 4,397.44 77.00 360.00 3,504.00 1,535.13 610.19 4,554.23 80.00 0.00 3,536.00 1,688.59 610.19 4,778.82 80.00 0.00 3,575.00 1,909.77 610.19 5,026.45 80.00 0.00 3,618.00 2,153.64 610.19 5,463.09 82.91 0.00 3,692.00 2,583.93 610.19 M HALL(BtJpTON _ _ _ ~ _.. Sperry Driilliing 5erwices Well Plan 1J-101 Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) True Minimum Curvature Name Permafrost T3 K15 T3+550 Ugnu C Ugnu B Ugnu A K13 D @ 77° West Sak C B @ $0° West Sak A4 West Sak A3 A2 @ 84° 10/19/2005 3:52:44PM Page~~10ryryof 10 COMPASS 2003.11 Build 48 V~r~~ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-101 Anticollision Summary 19 October, 2005 • HA1.1..l~tJ~T~N ~rer~y ci~~t~ ~erw~c~ ~~'!61NAL SCR1"EY PRUGIta?1 NAD 27 ASP Zone 4: WELL DETAILS: Plan 7J-101 ConocoPhillips Alaska (KUparuk) -- - --- -- --- - - ---- - ANTI-COLLISION SETTINGS Date: :005-10-03700:00:00 1~elidatrd: Srs ~~rrsion: Ground Level: 81.00 Drilling 8 Wells Interpolation Method: MD Interval: SOStations +NIS +FJ-W Northing Easting Latittude Longitude Slot Wast Sak Depth From Depth To Sun ey/Plan Tool Depth Range From: 28.00 To 11518.15 O.OD 0.00 5946088.15 558754.33 70°75'47.898N 149°31'30.OD5W 28.00 800.110 1J-101 P~pOJ) CD-GIRO-58 Maximum Range:1239.50412311175 Calculation Method: Minimum Curvature BIX1.UU 1J 518.15 1.1-I(II (xpOJ) 1187)+IFR-AK-CA7 SC Reference: Plan: iJ-101 (wp04) Emor System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic 330 blaming Method: Rules Based Plan 1J-152 (M5) 1 J-09 I - ~ ~ ~5 2 30 300 60 Plan 1J-50 (Ugnu Disposal) 1 1 ~) 1 Plan 1J-102 ~ so. ' 1 Plan 1J-154 ~ X/ - 1 Plan 1J-103 yr,~i[,,~- ~ ire 2 k/ i \ _ \ICffl„ ~ ~ / •~ Plan 1J-105 270 Plan 1J-164 ,• y ~\. ' -~ / / .>(~ ,~~- - - i' .. \.. }~ ~ Plan 1J-12_ _ _~ 1 ~ '~~,.,~, /~ ~• ~ 1J-03 `1 - '~ `w, .i ~ I ~~ ~ '~ ~ /~ _ 1 ,. vo -- `-~,- .~ t ~ --- "-iG%-` so _ Plan 1J-107 - I ~, ~~ '_': v i _'" 1 - WSP15 ~ 240 120 ` ~"J1~ '+~ I~~' "!, F '~ _ _ PI na 1J-109 ~ ~ `t\\ -~' ~ r ~Ian1J-158(M3) ~ ~~5~` '?"~~"'`<"~, WSPISJ - + y 217 ~ - ~ - ~ Plan 1J-111 (M12) ~ lan 1J_156 (M4) - \ `~s ~,~,~ .rqr ~jv" ~ ~ .,r,_s,/',i _ _ k,D _ - ~ 150 Plan 1J-1 2a \ t . ` - _ Plan 1J-115 (L9)', 210 WSP-02 X, ~s~'' .><'' ,z1o'~~~~~, 15o ~.a , From Colour To MD WSP-1S 6 -, _._~. 50 28 250 WSP-04180 ~ ~ 250 500 _ WSP-OS ~ __~ WSP-03 Plan 1J-159 (M7)' 500 750 , , 15 WSP ~ 750 1000 - - 1000 1250 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separ ation (25Q~,fin~ 1500 1500 1750 1750 2000 REFERENCE INFORMATION 2000 3000 Coordinate (N/E) Reference: Well Plan 1J-101, True NoRh 3000 4000 Vertical (ND) Reference: Pion RKB @ 109.OOh (Doyon 741 (87 +28)) 4000 5000 Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: Plan RKB @ 109.OOft (Doyon 747 (87 + 28)) 5000 6000 Calculation Method: Minimum Curvature 6000 7000 7000 8000 8000 9000 sooo loooo 10000 11000 11000 12000 12000 12500 SECTION DETAILS Sec MD Inc Azi ND +N/S +EI-W DLeg TFace VSec Target 7 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 2 7550.00 0.00 0.00 1550.00 0.00 0.00 0.00 0.00 0.00 3 1950.00 10.00 40.50 1947.97 26.48 22.61 2.50 40.50 26.48 4 2616.67 30.00 40.50 2571.26 198.98 189.94 3.00 0.00 198.98 5 2716.67 30.00 40.50 2657.86 237.00 202.42 0.00 0.00 237.00 6 3243.93 55.08 28.00 3043.92 533.34 392.88 5.00 336.44 533.34 7 3463.93 55.08 28.00 3169.85 692.62 477.57 0.00 0.00 692.82 8 4133.30 77.00 360.00 3444.58 1277.76 810.19 5.00 56.04 1277.76 9 4197.40 77.00 360.00 3459.00 1340.22 810.19 0.00 0.00 1340.22 7J-101 T7 - Dtop (wp04) 10 4440.40 77.00 360.00 3513.68 1578.99 610.19 0.00 0.00 7576.99 it 4540.40 80.00 0.00 3533.80 1674.97 610.19 3.00 0.00 1674.97 12 5390.40 80.00 0.00 3681.20 2512.06 610.19 0.00 0.00 2512.06 13 5490.40 84.00 0.00 3895.11 2611.08 810.19 4.00 0.00 2611.06 74 5890.40 84.00 0.00 3718.02 2809.97 610.19 0.00 0.00 2809.97 15 5836.75 89.83 359.95 3723.86 2955.45 870.13 4.00 -0.49 2955.45 1J-101 T2 - Trough t (wp04) i6 6222.15 92.53 359.95 3775.90 3341.33 809.79 0.70 O.DO 3341.33 17 6417.75 92.53 359.95 3707.29 3536.14 609.62 0.00 O.OD 3536.14 18 6802.22 89.43 359.95 3700.68 3921.11 809.29 0.80 -180.00 3927.17 1J•101 T3 - Peak t (wp04) 79 7188.22 87.50 359.95 3771.00 4306.95 808.95 0.50 180.00 4306.95 20 7383.22 87.50 359.95 3719.49 4501.76 808.78 0.00 0.00 4501.76 21 7769.26 89.48 359.95 3729.83 4887.65 808.45 0.51 0.00 4887.65 iJ-707 T4-Tough2(wp04) 22 8155.26 97.03 359.95 3727.91 5273.63 808.71 0.40 0.00 5273.63 23 8350.26 97.03 359.95 3724.41 5468.60 807.94 O.OD 0.00 5468.60 24 8736.28 89.70 359.95 3723.98 5854.58 607.80 0.50 -180.00 5854.58 iJ-101 TS -Peak 2 (wp04) 25 8779.58 88.35 359.52 3724.95 5897.90 807.40 2.00 -150.21 5897.90 28 9127.77 88.35 359.52 3735.00 6245.92 804.48 0.00 0.00 6245.92 1J-101 T8 (wp04) 27 9201.47 89.75 359.98 3736.23 6319.62 604.76 2.00 18.22 6319.82 28 9827.88 89.75 359.98 3739.00 6946.02 603.94 0.00 0.00 8948.02 iJ-101 T7 (wp04) 29 9872.58 88.41 359.86 3739.72 6990.71 803.88 3.00 -174.75 8990.71 30 10026.97 88.41 359.86 3744.00 7145.05 803.50 0.00 0.00 7145.05 iJ-101 TS (wp04) 31 10084.29 86.70 360.00 3746.45 7202.37 803.42 3.00 175.36 7202.37 32 70527.83 88.70 380.00 3772.00 7645.11 803.40 0.00 0.00 7845.11 1J-701 T9 (wp04) 33 10542.83 88.27 359.67 3772.92 7860.08 803.38 3.00 -183.80 7860.06 34 10728.26 86.27 359.87 3785.00 7845.14 602.96 0.00 0.00 7845.14 iJ-101 710 (wp04) 35 10797.83 84.37 359.64 3790.19 7908.47 802.89 3.00 -173.00 7908.47 36 11578.15 84.37 359.64 3881.40 8631.28 598.09 0.00 0.00 8631.28 1J-107 Tit (wp04) ~J ~+tt?C~~'11~~1~15 Ai2i:>iSc Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-101 Well Error: O.OOft Reference Wellbore Plan 1J-101 Reference Design: 1J-101 (wp04) Haliiburton Company Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HALLf~3URTON Sperry Dr#11-rng Services w. Well Plan 1 J-101 Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) Plan RKB @ 109.OOft (Doyon 141 {81 + 28)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Reference 1J-101 (wp04) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,239.50ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma __ ___ Survey Tool Program Date 10/19/2005 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 800.00 1J-101 (wp04) (Plan 1J-101) CB-GYRO-SS Camera based gyro single shot 800.00 11,518.15 1J-101 {wp04) (Plan 1J-101) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 10/19/2005 4:22:19PM Page 2 of 3 COMPASS 2003.11 Build 48 ORIGINAL Halllburton Com an ~~~~~~~~~~ ~ p Y HALLIBUgTON' Anticollision Report ~~ -~- - -- t~l~~ek~ Spen'Y Driilling 5c~rv1U",e~~ Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Well Plan 1J-101 Project: Kuparuk River Unit ND Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)} Reference Site: Kuparuk 1 J Pad MD Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-101 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 1.00 sigma Reference Wellbore Plan 1J-101 Database: EDM 2003.11 Single User Db Reference Design: 1J-101 (wp04) Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1 D Pad 1 D-42 - 1 D-42 - 1 D-42 Out of range 1 D-42 - 1 D-42L1 - 1 D-42L1 Out of range 1 D-42 - 1 D-42L1 PB1 - 1 D-42L1 PB1 Out of range Kuparuk 1J Pad 1J-03 - 1J-03 - 1J-03 641.39 650.00 169.09 11.91 157.18 Pass -.Major Risk 1J-09 - 1J-09 - 1J-09 984.42 1,000.00 151.02 18.73 132.28 Pass -Major Risk Plan 1J-102 - 1J-102 - 1J-102 (wp03) 800.63 800.00 29.10 17.23 11.87 Pass -Major Risk Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp03) 800.63 800.00 29.10 17.14 11.96 Pass -Major Risk Plan 1J-102 - 1J-102 L2 - 1J-102 L2 (wp03) 800.63 800.00 29.10 17.14 11.96 Pass -Major Risk Plan 1J-103 -Plan 1J-103 - 1J-103 (wp01) BHI 749.77 750.00 47.13 16.07 31.05 Pass -Major Risk Plan 1J-105 -Plan 1J-105 - 1J-105 (wp01) BHI 749.04 750.00 86.81 16.09 70.72 Pass -Major Risk Plan 1J-107 -Plan 1J-107 - 1J-107 (wp01) BHI 500.35 500.00 131.25 10.60 120.65 Pass -Major Risk Plan 1 J-109 -Plan 1 J-109 - 1 J-109 (wp01) BHI 437.47 450.00 191.79 9.64 182.14 Pass -Major Risk Plan 1J-111 (M12) -Plan 1J-M12 Lat A -Plan 1J-I 450.73 450.00 231.34 8.61 222.72 Pass -Major Risk Plan 1J-115 (L9) -Plan 1J-L9 Lat A -Plan 1J-L9 L 750.29 750.00 312.52 14.22 298.30 Pass -Major Risk Plan 1J-12 -Plan 1J-12 (K2 Prelim} - 1J-12 (K2 Pr 2,210.82 2,299.99 202.66 42.18 160.47 Pass -Major Risk Plan 1J-127 (L8) -Plan 1J-L8 LatA -Plan 1J-L8 L< 1,986.54 2,050.00 502.75 35.98 466.77 Pass -Major Risk Plan 1J-152 (M5) - 1J-152 - 1J-152 (wp04) 793.72 800.00 142.29 17.52 124.77 Pass -Major Risk Plan 1J-152 (M5) - 1J-152 L1 - 1J-152 L1 (wp04) 793.72 800.00 142.29 17.52 124.77 Pass -Major Risk Plan 1J-152 (M5) - 1J-152 L2 - 1J-152 L2 (wp04) 793.72 800.00 142.29 17.52 124.77 Pass -Major Risk Plan 1J-154 - 1J-154 - 1J-154 Rig 1,093.36 1,100.00 159.70 22.32 137.38 Pass -Major Risk Plan 1J-154 - 1J-154 L1 - 1J-154 L1 (wp06) 1,143.32 1,150.00 175.27 23.29 151.99 Pass -Major Risk Plan 1J-154 - 1J-154 L2 - 1J-154 L2 (wp06) 1,142.63 1,150.00 175.25 23.27 151.98 Pass -Major Risk Plan 1J-156 (M4) -Plan 1 J-M4 A Lat -Plan 1 J-M4 450.99 450.00 209.85 8.63 201.22 Pass -Major Risk Plan 1J-158 (M3) -1J-M3 A Lateral - 1J-M3 A LatE 350.92 350.00 240.89 6.59 234.30 Pass -Major Risk Plan 1J-159 (M7) - 1J-159 - 1J-159 (wp04) 1,049.99 1,050.00 256.60 21.50 235.11 Pass -Major Risk Plan 1J-164 - 1J-164 - 1J-164 (wp07) 1,638.04 1,699.99 82.71 32.60 50.10 Pass -Major Risk Plan 1J-164 - 1J-164 L1 - 1J-164 L1 (wp07) 1,638.04 1,699.99 82.71 32.61 50.10 Pass -Major Risk Plan 1J-164 - 1J-164 L2 -1J-164 L2 (wp07) 1,638.04 1,699.99 82.71 32.61 50.10 Pass -Major Risk Plan 1J-50 (Ugnu Disposal) -Plan 1J-UgnuDispos 400.95 400.00 147.22 7.68 139.54 Pass -Major Risk WSP-02 -WSP-02 -WSP-02 2,059.63 2,100.00 226.80 41.70 185.10 Pass -Major Risk WSP-03 -WSP-03 -WSP-03 1,450.31 1,450.00 269.62 34.24 235.38 Pass -Major Risk WSP-04 -WSP-04 -WSP-04 1,588.98 1,600.00 337.15 32.28 304.87 Pass -Major Risk WSP-05 -WSP-05 -WSP-05 2,110.22 2,200.00 381.96 40.50 341.46 Pass -Major Risk WSP-15 -WSP-15 -WSP-15 2,467.19 2,500.00 78.43 61.94 16.49 Pass -Major Risk WSP-1S -WSP-1S -WSP-1S 1,838.02 1,850.00 95.39 74.55 20.84 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 10119/2005 4:22:19PM Page 3 of 3 COMPASS 2003.11 Build 48 ORIGINAL 1]-101 ~illinQ_Hazards ~I.~mma (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Oaen Hole / 10-3/4" Casina Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate ~` Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 9-7/8" Open Hole / 7-5/8" Casina Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates mud rheolo LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets ,_pum in out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low , Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo ,LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin 3 ~l ~ ~ "; ~~ 1J-101 Drilling Hazards Summary .~ 11/9/2005 12:29 PM 1 CemCADE Preliminary Job Design 7-5/8" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 11/4/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 2631.207 Mobile: (907) 748-6900 email: martin13@slb.com 'f Previous Csg. < 10 3/4", 45.5# casing at 2,209' MD < Top of Tail at 2,976' MD < 7 5/8", 29.7# casing in 9 7/8'° OH TD at 5,490' MD (3,695' TVD) Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 2514' MD annular length. Tail Slurrv Minimum thickening time: 160 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 2514' x 1.25 (25% excess) = 675.0 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 675.0 ft3 + 20.6 ft3 = 695.6 ft3 695.6 ft3/ 2.25 ft3/sk = 309.2 sks Round up to 310 sks BHST = 86°F, Estimated BHCT = 74°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) Ibbll (min) tminl CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 MUDPUSH II 5.0 50.0 10.0 30.0 Drop bottom plug 0.0 0.0 5.0 35.0 DeepCRETE 5.0 123.9 24.8 59.8 Drop top plug 0.0 0.0 10.0 69.8 Mud 6.0 238.0 39.7 109.5 Slow & bump plug 3.0 10.4 3.5 113.0 MUD REMOVAL Recommended Mud Properties: 9 ppg, Pv < 15, TY < 20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH* II, Pv ? 21-24, TY ? 35-40 Centralizers: Tandem Rise Centralizers 3000 - 3730 @ 1 per joint 4130 - 5410 @ 3 per 2 joints 5410 - 5480 @ 2 per joint ORIGINAL CemCADE Preliminary Job Design 10 3/4" 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: 11/3/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263.4207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 108' MD < Base of Permafrost at 1,540' MD (1,540' TVD) Schlumherger 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 1,609' MD. Lead Slurry Minimum pump time: 190 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x (108') x 1.00 (no excess) = 147.4 ft3 0.3637 ft3/ft x (1540' - 108') x 3.50 (250% excess) = 1822.9 ft3 0.3637 ft3/ft x (1609' - 1540') x 1.35 (35% excess) = 33.9 ft3 147.4 ft3 + 1822.9 ft3+ 33.9 ft3 = 2004.2 ft3 2004.2 ft3 / 4.45 ft3/sk = 450.4 sks Round up to 460 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 140 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3637 ft3/ft x (2209' - 1609') x 1.35 (35% excess) = 294.6 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 294.6 ft3 + 43.2 ft3 = 337.8 ft3 337.8 ft3/ 2.47 ft3/sk = 136.8 sks Round up to 140 sks BHST = 47°F, Estimated BHCT = 64°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) < Top of Tail at 1,609' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 2,209' MD (2,199' TVD) Mark of Schlumberger CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 50.0 10.0 35.0 ASL 7.0 357.0 51.0 86.0 DeepCRETE 5.0 60.2 12.0 98.0 Drop top plug 0.0 0.0 5.0 103.0 Water 5.0 20.0 4.0 107.0 Switch to rig 0.0 0.0 5.0 117.0 Mud 7.0 175.0 25.0 142.0 Slow & bump plug 3.0 9.8 3.3 145.3 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, TY < 20 or 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 'h per joint throughout tail slurry ORIGINAL Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Annular ~ -- To be tested to 250 psi and 1,500 psi at initial installation and every 14 days thereafter. 13-5 Double Ram Upper Rams: 3-'/2' to 6" variables To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves F-- To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Single Ram Rams to fit Intermediate Casing: 7-518" or 9-5/8" ~ To be tested to 250 psi and 3,000 psi only before running casing. ~ Wellhead Valves tested to 3,000 psi upon assembly Doyon 141 West Sak 3 ksi 13-580P3Kdiagram.vsd ~C)C1©CO~"1~~1~?S Sheet 1 of 1 BOP Configuration prepared by-Steve 8 111/2004 /~aSka *Vetco Gray 11" x 4-1/2"Hanger with 4.909" MCA top connection Tubing String 4-1 /2" 12.6#, L-80, IBTM / 3.958" ID, 3.833" Drift GLM, Camco 4-1 /2" X 1" KBG-2 GLM, Camco 4.1/2" X 1" KBG-2 GLM, Camco 4-1/2" X 1" KBG-2 10.3/4" Casing Shoe, set @ 2209' MD, 2199' TVD Bottom of Motor Centralizer Centralift 478 HP KMHFER 2610 / 98 D-sand Window at 4197' MD, ~ ~ 3459' TVD ~ ~~ ~~ "~x, v -'- ! ' ~y . 4-1/2" X 7-S18" Model'B' HOOK Hanger 5-1/2" X 7.5/8" ZX P L1ner Top Packer w ith Hold Downs Lateral Entrv Module (LEM) Assembly ~. ~.-- 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID ) Tubing Swivel, 4.1/2" Orienting Profile Automatic Alignment of LEM ` Positive Latching Collet dicates Correct Location Seal Bore for Lateral Isolation - 3.68" ID Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID Casing Sealbore Receptacle 4.75" ID 4112" X 7-518" Model'B' HOOK Hancer Seal Bore 3.66"ID 4-112" 12.6# Liner Hanger I Packer Assembly at +/- 4650' MD 4-1 /2" Liner Shoe, 12.6#, L-80 IBTM Set @ 11718' MD, 3639' TVD Lateral Entry Module(LEM) Orienting Profile B-sand Window / at 4540' MD, 3533' TVD 'B' Sand Lateral ~~~ NCR ~ Baker Oil Tools Lateral Entry Module (LEMI With Diverter s and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installed Installed (3.00" Latera l Dria) (2.50" ID Mainbore Ddtt) 'GS' Profile for f-Coil Connector Running/Retrieving ~ ~ f t (1.00' Length) '~ ' ~I ` i ~ Snap InlBnap Out i I r Back Pressure Valve -- /POSitive LocaOngti ~-i! , L i (1.60' Length) ~ Collet ~ Flow-Thru Swivel ~~ Lateral Isolation ~~ S l ~ I . ' (1.25'Length) ea s i i 1 ~ '. / Lateral Diverter ' / Hydraulic Ramp I ~ Disconnect IsolatioN Mainbore (1.50' Length) ` 0 19~/ GS Spear i li ~ Diverter Sleeve ~~ ~ t (1.50' Length) Lateral Isolation Seals 6.85 ft Approx. DAL" ~ ,:. I 'Jars may be required in highly tleviated 18.5' Diverter Length 18.5' Sleeve Length ~~ or deep applications (6' approx length). T 4-1/2" 12.6# L-80 Slotted , Liner Every Joint / 3-1i2" Bent Joint 1(l - .i/,,,,„„~ ,.,,.,,.~_ 3-1/2" Guide Shoe _ ~ : ~,.~„r"'u;a ~ .,;_-. ,,, 4.1/2" Liner Shoe, 12.6#, L-80 IBTM Set @ 11653' MD, 3696' TVD 3.562" DB Packer Downs \ , 5.112" X 7-518" Flex Lock \ L Hanger Casing Sealbore Receptacle, 4.75"ID Eauipment Specifications 4-1 /2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, w/diverter, no LEM: 3.88" _ Lateral/Mainbore Diverter OD: 6.75" ~~~ 5 ~~~` ~.. 4-1/2" Lateral Entry Module ' Mainbore Drift: 3.65" _ ~ ~. ^ Mainb Drift, wl isolation sleeve: 2.50" Seal Assembly C~)^, Late Drift, w/ coil diverter. 3.00" 4.75" Seal OD OD o 'verter and Sleeve: +l- 3.89" 3.875"ID 'A' Sand Undulating Lateral Divertera Sleeve Length:+l-18.5' 4-1/2" 12.6# L-80 Slotted Llner Every Joint 4112" Eccentric ~Gulde Shoe "" 1 4-112" Casing Shoe, 12.6#, L-80 I TM ~~_. ~ ~~"~'+""^"~~ ~ _, Set @ 11516' MD, 3856 TVD Shoe, Set at @ ® Baker Hughes 2005. Thla tloeument may not be reproducetl or distnbuled, In whole or in part, In any Corm or 5490' M D, 3695' T , deg inc °r'p r't"~ by any means elacbonlc or mechanical, Including photocopying, recording, or by any Iniorma6on storage 4005 West Sak 7-5/9" Trl-lateral Comple acct and retrieval system now known or hereafter Invented, without written permlaalon from Baker Hughes Inc. Novem y~ Marc D. Kuck R"NSion No.: 0 CO~C1t)C[) I'1~5 West Sak 7-5/8" Producer 1J-101 Tri-Lateral Completion 'D' Sand Lateral 41/2" 12.6# L•80 Slotted Liner Every Joint ~ 3-112" Bent Joint 3-1/2" Guide Shoe • • `~ l ~D-732 ConacoF'hh111ips M AI3Sk2 • agnetic North: 24.32° Magnetic Field Strength: 57561.1 nT Dip Angle: 80.76° Date: 10/5/2005 ~ ~ Model: BGGM2005 ~ 1 J-101 Heel 1 /4 (wp04) I ~ -~~- '~ __~1J-1G1L2(wp04j~ ----~~ ~~~ ----------- ------- 1J_101L1(wp04) l`` `-~_----- ~~1J-164 L1(wp07) - ------------------ - ----- . - - 360° ~ 8 31 1 360° i \ o° ~ I1J-101 L2 1/4 Mile radius @ Heel .__--- 360°_ - _.------- 0 _~` -s2s Closest Well In Pool wsa,ts~ 1J-101 (A2 Lateral) : 1D-132:1224' @ 11518' M 1J-101 L1 (B-Lateral) : 1D-132:1133' @ 11653' D -1250 1J-101 L2 (D-Lateral WSP-15:1025' @ 4197'Mp 1J-164 L2 (wp07) 1J-164 (wp07) ~__- _ _1 360° Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-101 Wellbore: Plan 1J-101 Plan: 1J-101 (wp04) c 0 u7 N t L O Z s 7 0 -4375 -3750 -3125 -2500 -1875 -1250 -62~ ] ~0~ ~"j ~E~~ 250 1875 2500 3125 3750 4375 ~ono~tiF'h~IlEp~s Alaska 1 /4 Mile Kadius - 1 J-1 U1 (wpU4) '~-D view portraying 3 closest wells it rnnl Plan 1J-164, 1J-164 L1, 1J-164 L1 (wp07) VO _--_ `"` --_-~e~- Plan 1J-164, 1J-164 L2, 1J-164 L2 (wp07) VO ""-'-~ Plan 1J-164, 1J-164, 1J-164 (wp07) VO ~. ~ - ~ .; \ ~. i - ~ ~~ i ~~ 0 ~ ,~ WSP-15, WSP-15, WSP-15 V1 ,, 0 '` ~ 0 !, ~,,. ~0~ ~, ~, ~- 0 ~ --- ~ ---------- ~1D ~_ F ~~ _ - -- ~ ~~~ , _- ~ ~~ _ - ~ _..~ -~ _/' ~ ~ r - ~~ 1J-101 (wp04) ~ ` ~ ~~ Plan 1J-101, Plan 1J-101 L2, 1J-101 L2 (wpOY~ ~~ , O -- O ~~O O Plan 1J-101, Plan 1J-101 L1, 1J-101 L1 (wp04) VO ~-"`~ ~ ~ O ' ~.. OO O - - 90 O ,--J" s _~, ~, O !_-. O O ~- ~ O ,--- `o ~ ~ ;. - ~ ~~-' o O ~ O 0 ~~- SHARON K. A P-DRAKE ,. _ ~, CONOCOPHILLIPS Ar0 y sao 1117 700 G ST. ANCHORAGE AI< 99501 ~~j _ DATE OtJ~ IiGCJ] '4 v ~ ORD 70 THE ~~Tl I ~ Q 62-74 ER OF /3Y 1 ` ~ 1L- ;,,5,~~ ~CC ~1~ a ~~ ~ ~i. C~~~~ Chase Manhattan Bank USA, LAR$ ~ ;"°'"^'~a~M ~ J Valid U G 200 White ClayDenterDr„Newark, DE197~~ pTo50 t ~`""~'a°" 00 Dollars 2 MEMO ~ ~:0 3 1 10 - --- w; y~ ~~ __ _- ,, 0 14 4 ~. 2 i 8 -- 'v'~ ' ~, Z~:- 47L9079276n~ ------ • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTEg/pARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /~1~ ~'~ ~ ~J ! ~G~ PTD# 7C-, -~,J'. lC ~~ " " CHECK WHAT ADD-ONS CLUE APPLIES (OPTIONS) ment of llb ore seg ermit is for a new we The ~ MULTI p LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as ' last two (2) digits a function of .the original API number stated are between 60-69) above. i I all 005(f) C 25 ! PILOT HOLE , . In accordance with 20 AA ta and logs acquired for the pilot d d (per ; ~ a s, recor hole must be clearly differentiated in both name (name on permit plus PH) ~ and API number (50 - ' ~ ~ 70/80) from records, data and logs acquired ~ for well (name on permit). ~ t to full b SPACING jec j The permit is approved su I ~ ; EXCEPTION ~ compliance with 20 AAC 25.055. Approval to ~ ~ perforate and Rroduce/infect is contingent I j upon issuance of a conservation order approving a spacing exception. ~ ~ ~ (Comnany Name) assumes ~ ~ the liability of any protest to the spacing I exception that may occur. submitted to the t l ~ DRY DITCH s e se All dry ditch samp SAMPLE Commission must be in no greater than 30' ~ ~ sample intervals from below the permafrost ~, ' or from where samples are first caught and ~ j 10' sample intervals through target zones. ' - ~ Rev: 04/01/05 C\jody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKOIL-490150 Well Name: KUPARUK RIV U WSAK 1J-101 Program DEV Well bore seg ^ PTD#:2051820 Company CONOCOPHILLIPS ALASKA INC Initial Classlfype DEV I PEND GeoArea 890 Unit 11160 On/off Shore On Annular Disposal ^ Administration 1 Pe[mit_feeattached_________ ___________.____.__,.____ .----__Yes- ________________--_--_...__ ----------------------------------------------- 2 Lease number appropriat_e_ _ Yes - - - - ...Surface Location and top- productive interval in ADL 025661;_ TD in ADL_025650-- - - - - - - - - -- - 3 Uniquewell_nameandnumber-- -- ----- --- --- -- -- Yes- ---- ----- -------- -- --- ------ ------- --- -------- --- ---- 4 Well located ina_defined_pool ________________ _____________ ____ ___Yes. _-_-._KRUWest_Sak_O_il Pool,governed_byConservation-OrderN_o,4066_________,_,-_--_--___ _____ 5 Well located proper distance- from drilling unit_boundary_ Yes - . _ _ - - _ Well is more- than 500 feet from an external property line. _ - - - .. . 6 Well locatedp[operdistance-from other wells______________________ ________Yes_ ____ _NOrestrictionsas_towel!spacinginCO.4.O6B._,__-_---.-__-,___-_-____________---_- 7 Sufficient acreage available in_dril_linq unit Yes - - - - - .. No restrictions as_to well spacing except that no_pay shall be opened in a well closer - - - - - - - - - - - - - 8 If_deviated,is_wellboreplat_included__________________________ ________ Yes_ --__--than 500 feetto_a_nextemal_propertyline.__----.,--____________-_._ -- --- 9 Operator only affected party__-____-------------------- -- - Yes- --------.--- - - - - 10 Operator has.appropriate-bond inforce--------------- ----- - - --Yes- ---- ------ -- ....--- -- ---------- ~---._ .------ -- -- --- ------ -- 11 Permit_canbeisSUedwithoutconserya_tionorder____________________ ________Yes- __-_--__-______________--_--_____-.__--_---__---_--------_-___--__ -_. Appr Date 12 Pe[mitcan be issued without administrative_approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes -- - - - SFD 11115/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorizedby_InjectionOrder#(putJO#in_comments)_(For-NA-_ _--_.,_____________-----___-__-__ __--_--___________________-_-_--- 15 All wells within 1/4_mile area_of review identified (Forserviee well only)_ _ _ _ _ _ _ _ __ _ _ _ _ _ NA_ - _ _ _ _ _ - _ _ - _ _ - 16 Pre-produced injector: duration of pre production Less than- 3 months (For_service well only) - _ NA_ _ _ . - _ _ -- -- -- - 17 ACMP-F-indjng of Consistency-has been issued-for_this project_ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ ACMP determination.no_longer_affects AOGGG approval_of permit to drill.- _ - . _ Engineering 18 Conductor string-Provided - - - - - - - - - - - - - - Yes - - - - - - - - 19 Surface casing-protects all known USDWs._--__-__.-___-__-___ ________ NA_ ___--Allaquifers exempted,4DCFR_147.1Q2(b)-(3)_________________________________- 20 C_MT_vol adequate_to circul_ate_on conductor & surf_csg _ _ _ _ _ _ _ _ _ _ . _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -- - 21 CMT-vol adeguate_to tie-in long string tosurf csg- _ _ - . _ - . _ _ - - N_o_ All hydrocarbon zones_planned_to be covered.- - - _ - . - - - - -- 22 CMT_will coyer all known.productiye horizons- - _ _ No_ - _ _ _ Slotted linercom _letion lanned._ P P -- 23 CasingdesgnsadequateforG,.T,B&_permafrost__-____----------- --------Yes_ ____________-___-__-._________,__.____---.-__--__--_____-._____ 24 Adequate tankage_or reserve pit Yes - - - ... Rig is_equippedwith steel_pits. -No reserve_pitplanned. All waste to approved annulus.or disposal well. 25 Ifa_re-dill,has-a:10-403 for abandonment beenapp_raved____________ ________ NA__ ______--_--_-,_ 26 Adequate wellbore separation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - . - - _ _ _ Proximity analysis performed: Traveling cylinder path calculated, Gyros possible shallow.- _ _ _ _ _ _ _ _ _ _ - . _ _ 27 If djvertertequired,doesjt meet regulations------------------___ __._____ Yes_ ___-_-__--_--_- Appr Date 28 Drilling tlu)d-program Schematic & equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Maximum expected fo[mation pressure 8J. EMW.- MW planned up 9.9 at_casing point & 8,6 ± ppg in West Sak._ _ TEM 1111 !2005 29 BOPEs, do they meet- regulation _ Yes - - .. CPAlproposes to have 1 PR for DP_and 1 PR for casing. This is acceptable-with MASP_43000 psi.- _ , - _ _ - - 30 BOPS-press rating appropriate; testto_(put prig in comments)- _ _ .. _ _ . _ . - Yes _ _ . _ MASP calculated at 1313psi, 3000-psi-BOP testplanned, _ - _ _ - - _ - . _ _ 31 _C_hoke_manjfoldcompliesw/API_I2P-53~May84)____ ________________ _______Yes- __-.__..-.____________--.-_--_____ 32 Work willoccucwithoutoperationshutdo_wn_____________________ ________Yes- __--__.._.__________ 33 Is presence of H2S gas probable- .. - . _ - Yes - .. - .. - Minor(510 ppm) H2S has been repo[ted_in nearby wells. _Mud_should preclude H2$, Rig_has sensors and alarms 34 Mechanical condition of wells withinAORyerified(Forse[vicewellgnly)______ ________ NA__ _________--_--____--__-._-__--------________--___-__-_--_----_____--_-. Geology 35 Permit.can be issued wlo hyd[ogen-sulfide measures - - - - . - - - - Yes . - - - - - Nearby well bores in pool,_1_D-134 &-1 D-131 ~ measur_ed 510 ppm H2S_ in 8/2004. - _ - _ _ - _ _ - , _ 36 Data_presented on_ pote_ntial overpressure zones - - - . -Yes _ _ _ - _ _ .None expected;_estimated reservoirpressure is 8,7_ppg EMW; well will be drilled with_8.6 - 9.6 ppg_mud, _ - _ _ Appr Date 37 Seismic.analysis ofshallow gas_zones_ - _ _ _ - _ _ - - -- - - NA_ Gas hydrates may be encountered; mitigation discussed-in Drilling_Hazards section, -- SFD 11!15!2005 38 Seabed condition survey_(if off-shore) _ - . _ NA - -- -- - 39 Contact namelphone for_weekly progress_reports [exploratory only]- NA- _ _ _ - _ - - . Geologic Engineering P ' Date Date: ' Date Commissioner: sinner: Com, Co issio r !~ • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dri ing Services LIS Scan Utility ` ~ $Revision: 3 $ LisLib $Revision: 4 $ Tue Mar 14 16:27:10 2006 Reel Header Service name .............LISTPE Date .....................06/03/14 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/03/14 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW-000408138 T. GALVIN M. THORTON • rC.P ~~ Scientific Technical Services Scientific Technical Services 1J-101 500292328600 ConocoPhillips Alaska, Inc. Sperry Drilling Services 14-MAR-06 MWD RUN 3 MWD RUN 4 MW-000408138 MW-000408138 P. ORTH P. ORTH M. THORNTON M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 35 11N l0E 2274 2453 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 2209.0 • REMARKS: U 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 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 2 ALSO INCLUDED RECORDED-ONLY ACOUSTIC CALIPER (ACAL). 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 1-4 REPRESENT WELL 1J-101 WITH API#:50-029-23286-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5396'MD/3681'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.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 GALA 2150.0 3632.0 GR 2163.5 5349.5 FET 2185.0 5342.0 RPS 2185.0 5342.0 RPM 2185.0 5342.0 RPD 2185.0 5342.0 RPX 2185.0 5342.0 ROP 2209.5 5396.0 S • • BASELINE CURVE FOR SHIFTS: C`JRVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2150.0 3714.0 3714.0 4179.0 4179.0 5396.5 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 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD INCH 4 1 68 4 2 RPD MWD OHMM 4 1 68 8 3 RPM MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPX MWD OHMM 4 1 68 20 6 FET MWD HOUR 4 1 68 24 7 GR MWD API 4 1 68 28 8 ROP MWD FT/H 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2150 5396 3773 6493 2150 5396 CALA MWD INCH 8.28 13.56 10.1851 2878 2150 3632 RPD MWD OHMM 4.02 2000 26.8548 6315 2185 5342 RPM MWD OHMM 3.45 1571.19 16.6024 6315 2185 5342 RPS MWD OHMM 3.22 1527.39 14.4002 6315 2185 5342 RPX MWD OHMM 2.86 1426.08 12.721 6315 2185 5342 FET MWD HOUR 0.21 49.43 1.59548 6315 2185 5342 GR MWD API 25.28 110.17 71.0402 6373 2163.5 5349.5 ROP MWD FT/H 2.7 486.36 138.584 6374 2209.5 5396 First Reading For Entire File..........2150 Last Reading For Entire File...........5396 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 • • Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CALA 2150.0 3632.0 GR 2163.5 3667.5 FET 2185.0 3658.5 RPX 2185.0 3658.5 RPS 2185.0 3658.5 RPM 2185.0 365$.5 RPD 2185.0 3658.5 ROP 2209.5 3714.0 LOG HEADER DATA DATE LOGGED: 10-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3714.0 TOP LOG INTERVAL (FT) 2209.0 BOTTOM LOG INTERVAL (FT) 3714.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 16.4 MAXIMUM ANGLE: 62.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S) 61.0 MUD PH: 10.1 MUD CHLORIDES (PPM): 100 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.900 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.020 103.4 MUD FILTRATE AT MT • MUD CAKE AT MT: ' NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 3.400 3.000 Name Service Order Units Size Nsam Rep Code Offset Channel • 70.0 70.0 DEPT FT 4 1 68 0 1 GALA MWD020 INCH 4 1 68 4 2 RPD MWD020 OHMM 4 1 68 8 3 RPM MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPX MWD020 OHMM 4 1 68 20 6 FET MWD020 HOUR 4 1 68 24 7 GR MWD020 API 4 1 68 28 8 ROP MWD020 FT/H 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2150 3714 2932 3129 2150 3714 GALA MWD020 INCH 8.28 13.56 10.1851 2878 2150 3632 RPD MWD020 OHMM 4.02 2000 33.5118 2948 2185 3658.5 RPM MWD020 OHMM 3.45 1571.19 14.7065 2948 2185 3658.5 RPS MWD020 OHMM 3.22 1527.39 12.4807 2948 2185 3658.5 RPX MWD020 OHMM 2.86 1426.08 11.7456 2948 2185 3658.5 FET MWD020 HOUR 0.21 49.43 1.49219 2948 2185 3658.5 GR MWD020 API 25.28 109.68 61.8889 3009 2163.5 3667.5 ROP MWD020 FT/H 15.64 486.36 162.867 3010 2209.5 3714 First Reading For Entire File..........2150 Last Reading For Entire File...........3714 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF • File Header Service name .............STSLIB.003 ' Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 • Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 3659.0 4124.0 FET 3659.0 4124.0 RPX 3659.0 4124.0 RPM 3659.0 4124.0 RPD 3659.0 4124.0 GR 3668.0 4132.0 ROP 3714.5 4179.0 LOG HEADER DATA DATE LOGGED: 11-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4179.0 TOP LOG INTERVAL (FT) 3714.0 BOTTOM LOG INTERVAL (FT) 4179.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 64.6 MAXIMUM ANGLE: 76.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 9.875 Other 9,10 55.0 9.0 150 4.5 2.900 70.0 2.060 101.2 3.400 70.0 3.000 70.0 NEUTRON TOOL MATRIX: .MATRIX DENSITY: • HOLE CORRECTION (IN): TOOL. STANDOFF (IN) EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel u DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3659 4179 3919 1041 3659 4179 RPD MWD030 OHMM 7.01 54.53 12.1276 931 3659 4124 RPM MWD030 OHMM 6.37 49.17 11.2953 931 3659 4124 RPS MWD030 OHMM 6.1 41.73 10.7629 931 3659 4124 RPX MWD030 OHMM 5.37 39.32 10.1926 931 3659 4124 FET MWD030 HOUR 0.46 16.37 2.8448 931 3659 4124 GR MWD030 API 41.6 106.87 80.5131 929 3668 4132 ROP MWD030 FT/H 2.7 244.2 89.779 930 3714.5 4179 First Reading For Entire File..........3659 Last Reading For Entire File...........4179 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/14 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.......06/03/14 Maximum Physical Record..65535 . File Type ............... Previous File Name.......STSLIB.003 Comment Record FILE HEADER • FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 4124.5 5342.0 RPX 4124.5 5342.0 RPD 4124.5 5342.0 RPS 4124.5 5342.0 FET 4124.5 5342.0 GR 4132.5 5349.5 ROP 4179.5 5396.5 LOG HEADER DATA DATE LOGGED: 12-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5396.0 TOP LOG INTERVAL (FT) 4179.0 BOTTOM LOG INTERVAL (FT) 5396.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 74.3 MAXIMUM ANGLE: 82.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 97054 EWR4 ELECTROMAG. RESIS. 4 216787 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 9.875 Other 9.10 57.0 9.7 150 4.3 2.900 70.0 1.830 114.8 3.400 70.0 3.000 70.0 REMARKS: S • Data Format Specification Record ' Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4124.5 5396.5 4760.5 2545 4124.5 5396.5 RPD MWD040 OHMM 6.05 1640.61 24.4271 2436 4124.5 5342 RPM MWD040 OHMM 5.11 235.48 20.925 2436 4124.5 5342 RPS MWD040 OHMM 4.75 95.17 18.1133 2436 4124.5 5342 RPX MWD040 OHMM 4.37 72.4 14.8677 2436 4124.5 5342 FET MWD040 HOUR 0.3 12.06 1.24301 2436 4124.5 5342 GR MWD040 API 48.15 110.17 78.7346 2435 4132.5 5349.5 ROP MWD040 FT/H 3.96 326.49 127.156 2435 4179.5 5396.5 First Reading For Entire File..........4124.5 Last Reading For Entire File...........5396.5 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/14 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/03/14 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/03/14 Origin ...................STS Reel Name ................~OWN Continuation Number......01 Next Reel Name...........UNKNOWN Comrnents .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
