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Home My WebLink About205-184• • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~- ~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided III IIIIII II III II III ^ Rescan Needed III IIIIII II II III III R SCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: DIGITAL DATA Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria Date: ~ / o /s/ Protect Proofing III IIIIII IIIII IIIII BY: Maria Date: ~ D /sl ~~ Scanning Preparation d~ x 30 = d + I ~ =TOTAL PAGES (Count does not include cover sheet) , BY: Maria Date: / /s/ Production Scanning l III IIIIII IIII II III Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning /Preparation: ~ YES NO BY: Maria Date: ~/ f / (~ $ /s/ ~ p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I (I II I I III ReScanned II I II II II ~ I III I I III BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III IIII II 10/6/2005 Well History File Cover Page.doc • '~_ ..._,~-- ~j~ f~ .~~ ~ ~ ; 6 s ~~ " ..~~*i MICROFILMED 6/30/2010 DO NOT PLACE ~. ~ '"~ - .,,.w:' w.: ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm Marker.doc • • ~. STATE OF ALASKA ; ?~ cp Fw s~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~ ~l~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ~ ~ Plug Pertorations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^~ 'Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhIIIIPS Alaska, (11C. Development 0 Exploratory ^ 205-1841 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23286-61 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1 J-101 L2 - 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 11711' feet true vertical 3656' feet Plugs (measured) Effective Depth measured 11681' feet Junk (measured) true vertical 3653' 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' LINER 7478' 4.5" 11682' 3653' Perforation depth: Measured depth: x235'-8x31', soss'-11650' , ,~ Li t~(~> ~I~~ ; _ '~ i . + ~l' ~~ L~ j"; true vertIC81 depth: 3460'-3534', 3531'-3651' Tubing (size, grade, and measured depth) 4.5", L-80, 4146.7' MD . Packers & SSSV (type & measured depth) pkr @ 4141' 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 Wells Engineer /O ~~2 ~D ~ `~~~ Signature .~~f7~ ^-7 ~ ~ ~ Phone: 265-6845 Date '~", / i` Pre a Sharon Allsu Drake 263-4612 1 / ~~ ~ ~~ /~d e 2~'f'. Form 10-404 Revised 04/2006 '~c~ Submit'Ori l al Q~~rIy rc1~s'~CB' i d- `~ KUP Conc~oPh~lli~s ~ ~ _ __ / Well Attributes r~::.,,,`n:=t, it ~i: ~ ~ Wellbore APW WIField Name --- _- ---Well Stat SG0292328670 WEST SAK (PROD Commern X25 (ppm) Date HANGER. 23 NIPPLE. soa SURFACE. 9-2,199 GAS LIFT. 2.546 GAS LIFT, 3.768 NIPPLE, 4,091 - GAUGE, 4.093- LOCATOR. 4.142 SEAL ASSV. 4.143 JANU, OS 4,206 0.SAND. 304.320 EDIATE. 27-5,389 - SLOTS. 4.236-6,931 1J-101 L2 1n2oos .pan I Depth (itK6) 'End Date Annotation End Date tg: ~ I Rev Reason: GLV C/O - 9/24/20( 79 $tfl-_~ Descri tion .- __._._ 58 ._ g g .. '~Str3n ~r' __ _. _ To (ft29) p _ Set Depth (f._ Set Depth (TVD)... ISVing Wt... --_ String Gr._ String Top D-SAND - 9 412 4 I 11,650.7 3650.5 12.60 L-80 IBTM Des ton P__-_~ St 0... Strin ID ... 9 9 To (ftK8 P ) Set Depth (f... Set Depth (TV D) . St ng WI... Strng Gr... String Top D-SAND BTM ~ 4 7/2 ~ 3.958 4202.0 i ~. 11,680.2 3652.9 12.60 L-80 IBT D etails ToP Depth. _ _. ___- (TV D) Top i, ;g) (ftKB) Incl (')'~ Item Description Comment IC m (TVD) Dens (ftKB) Zone Date it lsh... 3,533.7 WS D, 1J-101L2 1/5/2006 32.C 2006 NOTE: MULTI-LATERAL WELL: 1J-101 (A2-SAND), 1J-101L1 2006 NOTE: "'NO ESP PUMP IN WELL -USING GLVs"' 6/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9-0 9/2008 NOTE: "' ID 3.75' DB NIPPLE CJ 4183' IN D-SAND LI Valve Latch SLOTS, 9.056-11.651 LINER ~0.5AND TOP, -- 4.130-11.651 LWER D-S4ND RTM. 4.202-11,680 11 711 Canment ALL SLOTS: AAernating slotted/slid pipe 0.125' x 2.5' x 32 spf ~ 4 Circumferential adjacent rows, 3' Centers staggered 18 deg., 3 ft. non-slotted ends iJ-101 L2 Comment Cnr'ao~oPhi~lips Time Log & Summary Weffview Web Reyvrtfng 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 24 hr summary Free2e 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 1 J-101, spot and level rig over well, set up handy berm. Acce ted 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. P~g~ 1 cif r~ a ~ Time Lomas _ ___-- _ _ -- ~ Date From To Dur S. De th E. Depth Phase _Code Subcode T Comment 13:00 16:00 3.00 COMPZ RPCOM OTHR P IA pressure = 315 psi. Pull 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 R!H 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 4330'. 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. page 2 z~f 8 Time Logs ___ _ _ Date From To Dur S. C~epih E. DeUth Phase Code Subcode T Comment _ 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. ~~ag~: 3 ref ~ Time Lo s Date From To Dur S_D~pth E. De th Ph se Code Subcode 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 WELCTL 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 just above of ZXP packer at 4,050' while fillip IA with char a um . ` ~'~a~ ~ taf ~ r~ Time Logs __ Date From To_ Dur 5 Depth 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. 2,911 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 WELCTI CIRC T Pump 30 bbls Hi-Vis pill down DP and 120 bb-s 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 strip . 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 Install dart valve and RIH tojust above of ZXP acker at 4,050' Pa~~ a of 8 r~ • 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 bbl 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 WELCTI 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 Hi-Vis volume. 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 stnds, 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. • Time Logs __ __ _ Date From 'To Dur S Depth E De th Phase Code Subcode T Comment __ 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 1/2" 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 running order. 2,020 bbls lost Uformation today, 9,482 bbls lost Uwell total. 9/15/2008 Located seal assembly, spotted corrosion inhibited sea water, spaced out, spliced and landed hanger, ahem 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 lift 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. r Time Logs _ _ __ Date __. From To Dur S Depth E D~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 psi for 30 min. Good test at 500 psi 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, pul led TWC and freeze protected well, RDMO, spotted rig over well 1J-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. fr~age $ of 8 1 J-101 Pre-Rig and Post-Rig Well Work DATE SUMMARY 7/23/08 PRE-RWO, T-POT (PASSED), -PPPOT (PASSED), IC-POT (PASSED), I~ 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 Continue w/ CCT FCO 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). 9/21/08 FCO 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. ~c~ DATA SUBMITTAL COMPLIANCE REPORT zizs~zoos Permit to Drill 2051840 Well Name/No. KUPARUK RIV U WSAK 1J-101 L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23286-61-00 MD 11711 TVD 3656 Completion Date 1/7/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR / RES, DEN / NEU Well Log Information: Log/ Electr Data Digital Dataset Ty,(~e Med/Frmt Number Name D D Asc Directional Survey il~D D Lis 13762 Induction/Resistivity f F`N` 13762 LIS Verification ~D C Lis 15359 Induction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y-/`AI? Chips Received? "4TN"'' Analysis 1'~Al---- Received? Comments: Daily History Received? t~J N Formation Tops ~/ N - Compliance Reviewed By: _ __ - _ _ Date: (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 0 11711 Open 4206 11653 Open 4/6/2006 GR EWR4 ABI ROP ACAL PWD GeoPilot 4206 11653 Open 4/6/2006 GR EWR4 ABI ROP ACAL PWD GeoPilot 2150 11711 Open 8/23/2007 LIS Veri, CALA, FET, ROP w/Graphics Sample Interval Set Start Stop Sent Received Number Comments 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 +L1+Ll PB1+L2: Digital Log Images: SO-029-23286-00, 60, 70, 61 Bas-~~a ~ r5 3s~ ~ os - I ~r3 ~ ~s33 "~- aos--~a # ~5-~~s 1 CD Rom gag-~i~su ~ X5-3 `s9 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. ~~ 8 Date: T, Signed: ~i~ka iii ~; (gas Cons. Commissioir ;~nchora9e r1 • 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 1 J-101 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Surrey: 4,132.88' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 11,711.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICHC«~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 ~ 4 Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) pus -~8Y 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 L2, AK-MW-4081380 1 LDWG formatted Disc with verification listing. API#: 50-029-23286-61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETI7RNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~ 6d G Signed: V ~~+~1~~~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 2p~~ WELL COMPLETION OR RECOMPLETION REPORT gI~DaLO~ 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended ^ .WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well C ass: 01#311, , Development Q Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, lnc. 5. Date Comp., Susp., orAband.: January 7, 2006 12. Permit to Drill Number: 205-184 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December~6' 2005 '' ~; 13. API Number: 50-029-23286-61 4a. Location of Well (Governmental Section): Surface: 2274' FSL, 2453' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: January 3, 2006 ~ 14. Well Name and Number: 1J-101 L2 1 At Top Productive Horizon: 3636' FSL, 1800' FEL, Sec. 35, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 562' FSL, 1822' FEL, Sec. 23, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 11681' MD / 3653' TVD West Sak Oil P001 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558754 ' y- 5946086 ' Zone- 4 10. Total Depth (MD + ND): 11711' MD / 3656' TVD 16. Property Designation: ADL 25661 & 25650 , TPI: x- 559394 y- 5947452 Zone- 4 Total Depth: x- 559307'' - 5954938 ' Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 468 18. Directional Survey: Yes 0 No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2950' MD 21. logs Run: "~~~_~ ~~Y ~f71i/~` s~ipl ~ 5/S'3 `TY~ GR/Res, Dens/Neu .D 3. r ~ G(v 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" x 34" 62.58# H-40 28' 108' 28' 108' 42" 292 sx AS 1 10.75" 45.5# L-80 28' 2199' 28' 2186' 13.5" 46o 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 4204' 11682' 3452' 3653' 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" tbf in main wellbore 3352' 4601' slotted liner from 4235'- 8931', 9055'-11650' 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 1J-101 and 1J-101 L1: 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. 540 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 2200 GAS-MCF 1881 WATER-BBL 1 OIL GRAVITY -API (corr) not availab-e 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". - NONE ~ - Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~ ,~ ~~~~ ~u~ 3, rt-chi 2s. zs. 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 L2 West Sak D Sand 4204' 3452' ~ Base West Sak D sand 11711' 3656' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. 1 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 Drilling Team Leader Signature ~<~ "-- Phone - Date 3 (3 ~f ~6 ,~ 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 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 Phase Code 12/5/2005 14:00 - 16:00 2.00 MOVE DMOB MOVE 16:00 - 17:00 1.00 MOVE MOVE MOVE 17:00 - 19:30 2.50 MOVE MOVE MOVE 19:30 - 23:00 3.50 MOVE MOB MOVE 23:00 - 00:00 1.00 MOVE MOB MOVE 12/6/2005 00:00 - 02:00 2.00 MOVE POSN MOVE 02:00 - 04:00 2.00 WELCT. NUND RIGUP 04:00 - 06:30 2.50 DRILL RIRD RIGUP 06:30 - 10:15 3.751 DRILL I PULD I RIGUP 10:15 - 11:15 I 1.00 DRILL I PULD I SURFAC 11:15 - 12:00 0.75 WELCT BOPE SURFAC 12:00 - 12:30 0.50 WELCT BOPE SURFAC 12:30 - 14:15 1.75 DRILL PULD SURFAC 14:15 - 14:45 0.50 DRILL REAM SURFAC 14:45 - 16:45 2.00 DRILL DRLG SURFAC 16:45 - 18:45 I 2.001 DRILL I PULD 1 SURFAC 18:45 - 00:00 I 5.251 DRILL DRLG I SURFAC 12/7/2005 00:00 - 04:30 4.50 DRILL. DRLG SURFAC 04:30 - 05:00 I 0.501 DRILL I CIRC I SURFAC Start: 12/6/2005 Rig Release: 1/7/2006 Rig Number: Page 1 of 22 Spud Date: 12/6/2005 End: 1/7/2006 Group: Description of Operations Blow down all steam lines, Prepare modules for move. Move pipe shed modules, rockwasher, boilers, motor complex, and pits away from location. Move Sub base from 1J - 164 to 1J- 101. Spot subbase on well. Lay all rig mats, and spot pits, motor complex, boilers, rockwasher, and pipe shed modules. Hook up all service lines, steam lines to pump room and pits. Continue work on Rig Acceptance checklist. Spot pipe shed tioga, berm & 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. PJSM with crew. Nipple up diverter riser and lines. Load shed with BHA and drill string. Change out Saver Sub, Bellguide, and Grabbers on Top Drive fors" DP. 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 derck. Make up 1 stand of 8" Non-Mag flex drill collars, and rack back in derrick. Pick up 1 stand 5" DP & RU to perform Diverter Test. Perform Diverter function test. Wintness of Test waived by AOGCC - John Crisp. 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'. Fill-string and conductor with mud. Perform Conductor test, and leak test. Test mud line to 3000 PSI. Wash & ream down to 108'. 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 = 50K, ROT WT = 47K. Torque on/off bottom =-1-2K. Pumps - 510 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 @ 34 / 82. POOH, rack back 2 stands of 5" HWDP. Continue MU BHA. MU 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'). 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. 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 = 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. Circulate bottoms up for Survey while reciprocate & rotate string. RU Printed: 2/7/2006 10:40:10 AM • • ConocoPhillips Alaska Page 2 of 22 Operations Summary Report Legal Well Name: 1J-101 Common W ell Name: 1J-101 Spud Date: 12/6/2005 Event Nam e: ROT -D RILLING Start: 12/6/2005 End: 1/7/2006 Contractor Name: n1334@ ppco.co m Rig Release: 1/7/2006 Group: Rig Name: Doyon 1 41 Rig Number. Date From - To Hours Code Sub Phase Description of Operations Code 12/7/2005 04:30 - 05:00 0.50 DRILL CIRC SURFAC Slickline unit. 05:00 - 05:30 0.50 DRILL SURV SURFAC WLIH with Multi -Shot Gyro to obtain surveys. WLOH, RD Slickliners. 05:30 - 12:00 6.50 DRILL DRLG SURFAC 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 12:00 - 18:00 6.00 DRILL DRLG SURFAC 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. 18:00 - 19:00 1.00 DRILL CIRC SURFAC Circulate bottoms up 3 times @ 177 SPM - 750 GPM's - 2350 PSI. RPM's - 80, Torque = 2.5K 19:00 - 20:45 1.75 DRILL TRIP SURFAC 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. 20:45 - 21:30 0.75 DRILL TRIP SURFAC Contiue POOH on elevators from 1086' - 245' (841'). Rack back 5" HWDP & Jars (913'), and 10 Stands. 21:30 - 23:00 1.50 DRILL PULD SURFAC 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 23:00 - 23:30 0.50 DRILL PULD SURFAC Clear & Clean Rig Floor area, send all tools out. 23:30 - 00:00 0.50 CASE RURD SURFAC Rig up 10 3/4" Casing Equipment. Make up Franks fill up tool. Check all equipment for casing run. Cement head, plugs etc.. 12/8/2005 00:00 - 01:30 1.50 CASE RURD SURFAC Rig up 10 3/4" Casing Equipment. Make up Franks fill up tool. Check all equipment for casing run. Cement head, plugs etc.. 01:30 - 04:15 2.75 CASE RUNC SURFAC Run 54 jts of 10 3/4", 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 locked 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. 04:15 - 04:45 0.50 CEMENT PULD SURFAC Pick up Vetco Gray casing hanger and land w/Shoe @ 2,199.12', Float collar @ 2,115.04'. 04:45 - 05:15 0.50 CEMEN CIRC SURFAC Circ btm's up w/frank's fill up tool at rate of 5 bpm @ 350 psi, Up 125K, . Dn 110K. 05:15 - 05:45 0.50 CEMENT PULD SURFAC Lay down frank's fill up tool, Pick up Dowell cement head. 05:45 - 07:30 1.75 CEMENT CIRC SURFAC Finish circ and cond mud for cementing, staged pump rate up to 7.0 bpm at 420 psi, reciprocating pipe 15' 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. rnncea: un~uw -iu:wu: iv.vrv~ • • ConocoPhillips Alaska Page 3 of 22 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 12/8/2005 ~ 07:30 - 09:30 ~ 2.00 ~ CEMENIj PUMP ~ SURFAC 09:30 - 10:00 I 0.501 CEMENTI DISP I SURFAC 10:00 - 12:00 2,00 WELCT NUND SURFAC 12:00 - 12:30 0.50 CMPLTN NUND SURFAC 12:30 - 15:00 I 2.501 CMPLTNI NUND I SURFAC 15:00 - 16:00 1.00 CMPLTNI NUND SURFAC 16:00 - 18:00 2.00 CMPLTN NUND SURFAC 18:00 - 20:15 2.25 WELCT NUND SURFAC 20:15 - 00:00 I 3.751 WELCTLI BOPE I SURFAC 12/9/2005 100:00 - 02:30 2.501 WELCTL~ BOPS I SURFAC 02:30 - 03:00 0.50 WELCT BOPE SURFAC 03:00 - 03:30 0.50 RIGMNT RSRV SURFAC 03:30- 06:00 2.50 DRILL PULD SURFAC 06:00 - 08:00 I 2.001 DRILL I PULD I SURFAC 08:00 - 08:30 i 0.501 DRILL I PULD I SURFAC Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number: Description of Operations Turned 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, Reciprocated casing 10' to 15' until 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 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, Had full returns thru ,out job with 42.7 bbls 10.7 ppg cement to surface, 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 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 testa 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, #10. All test to 250 PSI -low, 3500 PSI High. AOGCC 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 & 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 to rig floor. YflflteO: L//lLUUb lU:4U:lU AM ~ • ConocoPhillips Alaska Page 4 of 22 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 12/9/2005 ~ 08:30 - 09:15 ~ 0.75 ~ DRILL ~ PULD ~ SURFAC 09:15 - 10:00 0.75 DRILL PULD SURFAC 10:00 - 10:30 0.50 DRILL PULD SURFAC 10:30 - 11:30 1.00 DRILL TRIP SURFAC 11:30- 12:00 I 0.501 DRILL (TRIP (SURFAC 12:00 - 12:30 0.50 DRILL TRIP SURFAC 12:30 - 13:00 0.50 DRILL CIRC SURFAC 13:00 - 14:00 1.00 CASE DEOT SURFAC 14:00 - 15:30 1.501 CEMEN7~ DSHO SURFAC 15:30 - 16:00 0.50 DRILL CIRC SURFAC 16:00 - 17:00 1.00 DRILL LOT SURFAC 17:00 - 18:00 1.00 RIGMNT RGRP INTRMI 18:00 - 19:00 1.00 DRILL TRIP INTRM1 19:00 - 00:00 5.00 DRILL DRLG INTRM1 12/10/2005 00:00 - 10:30 10.501 DRILL I DRLG INTRMI 10:30 - 11:30 1.00 DRILL I OTHR INTRM1 Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number: 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 = 1.031SQ. 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'). Plug 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 & 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 @ ..738 PSI. Total pumped = 6 BBLS. Computer calculated 15.3 PPG EMW, @ 2199' MD, 2185' ND. 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. ND =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' ND, 23.68 DEG INC, 43.48 DEG AZ Continue Directional drill 9 7/8" Intermediate hole from 2685' - 3713 (1028') MD. ND = 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' ND, 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!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 12/10/2005 11:30 - 12:00 ~ 0.50 ~ DRILL ~ CIRC 12:00 - 15:00 3.00 I DRILL 15:00 - 15:30 I 0.501 DRILL 15:30 - 17:00 ~ 1.50 ~ DRILL 17:00 - 18:00 I 1.001 DRILL 18:00 - 18:30 0.50 DRILL 18:30 - 19:30 1.00 DRILL 19:30 - 22:00 2.50 DRILL 22:00 - 22:30 0.50 DRILL 22:30 - 00:00 1.50 DRILL 112/11/2005 100:00 - 00:15 I 0.251 DRILL 00:15 - 00:30 I 0.251 DRILL 00:30 - 01:00 0.50 RIGMNT 01:00 - 02:00 1.00 DRILL 02:00 - 10:30 I 8.50 {DRILL 10:30 -11:00 ~ 0.501 DRILL ~ 11:00- 12:00 1.00) DRILL J 12:00 - 13:00 I 1.00 I DRILL I 13:00 - 14:00 1.00 DRILL 14:00 - 14:30 I .0.501 DRILL 1 Phase INTRM1 TRIP INNTRMI TRIP INTRM1 TRIP INTRM1 TRIP INTRM1 DEQT INTRM1 i PULD INTRM1 'DEQT INTRM1 PULD INTRM1 TRIP INTRM1 TRIP INTRM1 OTHR INTRMI RSRV INTRM1 TRIP INTRM1 DRLG 11NTRM1 OTHR INTRM1 CIRC INTRMI TRIP INTRMI TRIP INTRM1 TRIP INTRM1 Page 5 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 Pump Hi Visc weighted sweep with nut plug. 5Ibs /BBL. Monitor well, static POOH on elevators observing 40K to 50K overpull, and swabbing. RU and BROOH from 3622' - 3062' @ drilling rates of 650 GPM's -2000 PSI. Observe gas cut mud @ 3062' Continue BROOH slowly from 3062' - 2698' allowing time for good bottoms up and observing 395 Max gas units. BROOH to shoe @ 2197'. BROOH total of 1519' Monitor well at the shoe -static. Pump dry job. Change elevators to 5" DP, 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 BHA. Inspect bit and gauge to 1 / 1 / WT / A / E / I / N / DTF. We will rerun bit. RIH, breakout & lay dowh 6 3/4" ACAL Assembly. (5.62') Plug in and down load MWD. Breakout, lay down all Smart Tools. Total length = 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, decision to RIH without ACAL tool Breakout & 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 9 7/8" Ghost Reamer. TIH from 81' - 1136' (1055') Continue TIH from 1136' - 2213'. PU 9 7/8" Ghost Reamer on top of HWDP. Perform Shallow Pulse test @ 2213'. Pumps @ 600 GPM's - 141 SPM - 1500 PSI. Good test. Service Top Drive, Recharge Actuator Cylinders. ,Continue Trip in hole from 2213' - 361 T (1404'). No issues on OH. '.Wash & ream last stand from 361 T - 3713' (96'), @ 141 SPM - 600 GPM'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 btm = 5K, Off bottom = 5K. Pumps - 650 GPM's - 2300 PSI. RPM's = 80. 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 @ 4132' 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 to gain communication. Pump 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' TVD Pump #1 , 30 SPM -210 PSI, 40 SPM - 290 PSI. Pump #2, 30 SPM -210 PSI, 40 SPM - 290 PSI. POOH on elevators, no issues, or overpull. After 5 stands pulled with correct 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. Rack 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: Z/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 12/11/2005 14:00 - 14:30 0.5C 14:30 - 15:00 0.5C 15:00 - 16:30 I 1.50 16:30 - 17:30 1.00 17:30 - 20:30 3.00 20:30 - 21:00 0.50 21:00 - 00:00 I 3.00 112/12/2005 00:00 - 12:00 12.00 12:00 - 14:00 2.00 14:00 - 14:30 0.50 14:30 - 15:30 1.00 15:30 - 18:00 2.50 18:00-19:30 1.50 19:30 - 20:00 0.50 20:00 - 23:D0 3.00 23:00 - 00:00 1.00 12/13/2005 00:00 - 00:15 0.25 Code DRILL TRIP INTRM1 DRILL OTHR INTRM1 I DRILL I PULD I INTRM1 DRILL OTHR INTRM1 DRILL TRIP INTRM1 DRILL. REAM INTRM1 DRILL DRLG INTRM1 DRILL DRLG INTRMI DRILL DRLG INTRMI DRILL CIRC INTRM1 DRILL CIRC INTRM1 DRILL TRIP INTRMI DRILL TRIP INTRMI DRILL TRIP INTRMI DRILL PULD INTRM1 DRILL PULD INTRMI DRILL PULD INTRM1 Start: 12/6/2005 Rig Release: 1/7/2006 Rig Number: Page 6 of 22 Spud Date: 12/6/2005 End: 1 /7/2006 Group: Description of Operations Asembly. Plug in and download MWD assembly. Observe short circuit in Gamma 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: TVD = 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. TVD = 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. W06 = 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 TVD, INC = 82.14 Deg, AZ = 358.13 Deg. Obtain SPR's at 4362' MD, 3486' TVD 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. TVD = 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' TVD. 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" Drill 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/E/I/WT/TD. 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 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 Sub Phase Code 12/13/2005 010:00 - 01:30 0.50 DRILL PULD I INTRM1 01:30 - 02:00 0.50 CASE OTHR INTRM1 02:00 - 03:00 1.00 CASE RURD INTRMI 03:00 - 03:45 0.75 RIGMNT RSRV INTRM1 03:45 - 04:00 .0.25 CASE SFTY INTRM1 04:00 - 07:30 3.501 CASE RUNC INTRM1 08:00 - 108:30 I 3.50 CASE RU C INTRMI 11:30 - 12:00 0.501 CEMENl1CIRC INTRM1 12:00 - 12:15 0.251 CEMENl1CIRC INTRM1 12:15 - 13:30 I 1.251 CEMENl~PULD INTRM1 13:30 - 15:00 1.50 CEMEN CIRC INTRM1 15:00 - 16:15 1.25 CEMEN CIRC INTRM1 16:30 - 18:45 2.25 CEMENI~PUMP INTRM1 Page 7 of 22 Spud Date: 12/6/2005 End: 1 /7/2006 Group: 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 Ft/Lbs. Seal rings in collars. Filling casing through Franks tool. Observe proper fill. Circulate bottoms up @ 4 BPM - 300 PSL 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, while reciprocate casing. 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. 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 with full returns 15' to 20'. 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 r • ConocoPhillips Alaska Page 8 of 22 Operations Summary Report Legal Well Name: 1 J-101 Common W ell Name: 1J-101 Spud Date: 12/6/2005 Event Nam e: ROT -D RILLING Start: 12/6/2005 End: 1/7/2006 Contractor Name: n1334@ ppco.co m Rig Release: 1/7/2006 Group:. Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 12/13/2005 18:45 - 19:15 0.50 CEMEN RURD INTRMI Rig down Cement head and blow down all lines 19:15 - 24:30 2.25 CMPLTN NUND INTRM1 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' 21:30 - 00:00 2.50 CMPLTN OTHR INTRM1 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 infectivity test. 12/14/2005 00:00 - 00:30 0.50 CMPLTN OTHR INTRM1 Continue test Packoff 10 min. to 3800 PSI. = 80 % burst pressure of casing. Rig up lines to annulus from mud pump for annular infectivity' test. 00:30 - 01:30 1.00 DRILL- LOT INTRM1 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 & strap 4" Drill pipe in shed. NOTE: Welder injured finger on left hand. 01:30 - 02:00 0.50 DRILL OTHR INTRM1 Install wear bushing. RILDS. ID of wear bushing = 9.25" 02:00 - 03:00 1.00 DRILL PULD INTRM1 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. 03:00 - 04:30 1.50 RIGMNT RSRV INTRM1 PJSM. Change out Saver Sub on Top Drive. SIMOPS: Complete installation of fitting and safety cable on top of standpipe for Anadrill MWD. 04:30 - 07:45 3.25 DRILL PULD INTRM1 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. 07:45 - 08:15 0.50 DRILL PULD INTRM1 PJSM with crew. Discuss safety issues, and procedure for installation of Super Sliders. RU air line & tools. 08:15 - 12:00 3.75 DRILL PULD INTRM1 POOH with 18 stands installing Super Sliders in the middle of each joint. Rack back in derrick. Installed 54 Super Sliders. Crew change. 12:00 - 14:15 2.25 DRILL PULD INTRM1 Continue POOH with 25 stands installing Super Sliders in the middle of each joint. Rack back in derrick. Installed 36 Super Sliders. 14:15 - 17:30 .3.25 DRILL PULD INTRM1 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 17:30 - 18:30 1.00 DRILL PULD INTRMI POOH, rack back Push Pipe stands. 18:30 - 20:30 2.00 DRILL PULD INTRM1 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. 20:30 - 22:00 1.50 DRILL PULD INTRM1 Pick up &RIH with 21 joints of 4" Slick Drill Pipe, rack back same in derrick. 22:00 - 23:00 1.00 DRILL PULD INTRMI 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. 23:00 - 00:00 1.00 DRILL PULD INTRM1 MU BHA #5, Bit #3. Make up Hycalog RSX711 M-AZ Bit w! 2x11, and 2 x 12 jets for a TFA of .407, on Anadrill Periscope drilling assembly. Crew change. 12/15/2005 00:00 - 00:30 0.50 DRILL PULD INTRM1 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 r~nnted: uii~uue ~u:au:iuam • ~ 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 12/15/2005 ~ 00:00 - 00:30 ~ 0.50 ~ DRILL ~ PULD ~ INTRMI 00:30 - 00:45 0.25 DRILL OTHR INTRM1 00:45 - 01:45 1.00 DRILL PULD INTRM1 01:45 - 05:15 I 3.501 DRILL (TRIP I INTRM1 05:15 - 05:45 ~ 0.50 ~ DRILL ~ TRIP INTRM1 05:45 - 09:00 I 3.251 RIGMNTI RSRV INTRM1 09:00-10:00 1.00 DRILL DEOT INTRM1 10:00- 12:00 I 2.001 CEMEN7DSH0 I INTRM1 12:00 - 13:00 I 1.001 CEMENTI DSHO I INTRM1 13:00 - 13:30 0.50 DRILL CIRC INTRM1 13:30 - 14:30 t.00 DRILL LOT PROD 14:30 - 16:30 I 2.001 DRILL I CIRC I PROD 16:30 - 00:00 I 7.501 DRILL I DRLG I PROD 112/16/2005 100:00 - 05:15 05:15 - 06:15 06:15 - 12:00 5.251 DRILL DRLG PROD 1.00 DRILL OTHR PROD 5.75 DRILL -DRLG PROD Start: 12/6/2005 Rig Release: 1/7/2006 Rig Number: Page 9 of 22 Spud Date: 12/6/2005 End: 1 /7/2006 Group: 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 & 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 ahalysis. 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 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, S0 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 @ 6745' MD, 3697 TVD. Pump #1 - 25 SPM - 380 PSI, 35 SPM - 520 PSI. Pump #2 - 25 SPM - 390 PSI, 35 SPM - 540 PSI. Printetl: Z/7/2006 '10:40:10 AM • ~ ConocoPhillips Alaska Page ~ o of 22 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 J-101 1 J-101 ROT -DRILLING n1334@ppco.com Doyon141 Date From - To Hours Code Sub Phase Code 112/16/2005 112:00- 00:00 12/17/2005 00:00 - 12:00 12:00 - 13:15 13:15 - 14:30 14:30 - 16:30 16:30 - 00:00 12.001 DRILL I DRLG I PROD 12.00 DRILL DRLH PROD 1.251 DRILL I DRLH I PROD 1.251 DRILL OTHR PROD 2.00 DRILL DRLH PROD 7.501 DRILL DRLH PROD 112/1812005 100:00 - 10:00 I 10.00 I DRILL I DRLH I PROD 10:00 - 12:00 ~ 2.001 DRILL ~ DRLH ~ PROD 12:00 - 00:00 ~ 12.00 ~ DRILL ~ DRLH ~ 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 Continue Drill 6 3/4" hole in the Undulating A Lateral from 6745' - 7787'(1042'). MD. TVD = 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. 'Stand back Drill pipe pulling back 8877 - 8599'. (278'). Circulate & reciprocate drill string while conference with town. Down link tool while cutting 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 8620' -8632' (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 = 7' 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 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 - 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' Prinrea: zuizucm 7U:4UaU HM • • ConocoPhillips Alaska Page ~ ~ of 22 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 12/18!2005 ~ 12:00 - 00:00 ~ 12.00 ~ DRILL ~ DRLH ~ PROD 112/19/2005 100:00 - 12:00 I 12.00 I DRILL I DRLH I PROD 12:00 - 00:00 I 12.001 DRILL I DRLH I PROD 112/20/2005 100:00 - 08:15 08:15 - 1.1:00 11:00 - 15:15 15:15 - 18:45 18:45 - 00:00 8.25 I DRILL I DRLH I PROD 2.75 DRILL CIRC PROD 4.25 DRILL WIPR I PROD 3.501 DRILL ICIRC (PROD 5.251 DRILL (TRIP (PROD 12/21/2005 00:00 - 00:30 0.50 DRILL TRIP PROD 00:30 - 02:00 1.50 DRILL PULD PROD 02:00 - 02:30 0.50 DRILL OTHR CMPLTN 02:30 - 03:30 1.00 DRILL OTHR CMPLTN 03:30 - 04:00 0.50 CASE RURD CMPLTN 04:00 - 09:00 5.00 CASE PULR CMPLTN Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number: Description of Operations (549') MD. TVD = 3720'. ART = 7.63 HRS, PU WT = 117K, SO WT = 62K, ROT WT = 92K. Torque on/off bottom = 4.5K. Pumps - 330 GPM's - 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, 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 PSI. Total K-Revs for sliders today = 123100 HRS. Continue Drill 6 3/4" hole in the Undulating A Lateral from 9253' - 10216' (963') MD. TVD = 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. 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 = 11 OK. Torque onloff 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. 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 ft/Ib. 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. Pump Weighted Hi-vis sweep &circ hole clean at rate of 323 gpm @ 3800 psi and 160 RPM, Had 40°lo Increase w! sweep, Monitor well. POOH on elevators f/ 11510' to 8600' with no problems, RIH to 11510'- OK. Pump Weighted Hi-vis sweep &circ btm's up at rate of 320 gpm @ 3900 psi and 160 RPM, Change over to SFOBM. Monitor well, Drop 1.9" rabbit, POOH on elevators with no problems f/ 11510' to 3180' at midnight. Continue to POOH to BHA. Lay down Schlumberger BHA, Flex DC's, Float sub, MWD, Periscope, Bit. Clear & Clean rig floor. Rig down Schlumberger sensor's on stand pipe, Drawworks, est. Rig to run 4-1/2" lines Pick up 4 1/2" L80, 12.6# IBT slotted /blank liner assembly and RIH. Make up torque =3000 Ft/Ibs. 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!!/2006 10:40:10 AM • • ConocoPhillips Alaska Page ~2 of 22 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 Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number: Date From - To Hours Code Code Phase 12/21/2005 104:00 - 09:00 I 5.00 CASE IPULRCMPLTN 09:00 - 09:45 I 0.751 CASE IPULR I CMPLTN 09:45 - 13:30 I 3.751 CASE I RUNL I CMPLTN 13:30 - 14:45 ~ .1.25 ~ CASE ~ DEQT ~ CMPLTN 14:45 - 17:30 .2.75 DRILL TRIP CMPLTN 17:30 - 18:00 0.50 DRILL OTHR CMPLTN 18:00 - 00:00 6.00 WELCT BOPE CMPLTN 12/22/2005 00:00 - 01:45 1.75 RIGMNT~ RSRV CMPLTN 01:45 - 04:00 2.25 WINDO ULD PROD2 04:00 - 05:00 1.00 WINDOW PULD PROD2 05:00 - 06:00 1.00 WINDO IRC PROD2 06:00 - 08:30 2.50 WINDO RIP PROD2 08:30 - 09:00 0.50 WINDO THR PROD2 09:00 - 09:30 0.50 WINDO IRC PROD2 09:30 - 10:15 0.75 WINDO RIP PROD2 10:15 - 10:30 0.25 WINDO ETW PROD2 10:30 - 12:00 1.50 WINDO IRC PROD2 12:00 - 15:30 3.50 WINDO TWP PROD2 15:30 - 16:30 I 1.001 WINDOWCIRC I PROD2 16:30 - 19:00 2.50 WINDOV~ITRIP PROD2 19:00 - 20:45 1.75 WINDO ULD PROD2PROD2 20:45 - 23:00 I 2.251 DRILL I OTHR I PROD2 23:00 - 00:00 1.00 DRILL PULD PROD2 12/23/2005 00:00 - 00:45 0.75 DRILL PULD PROD2 00:45 - 01:30 0.75 DRILL PULD PROD2 01:30 - 03:30 2.00 DRILL TRIP PROD2 04:30 - 04:45 0.25 DRILL I REAM PROD2 04:45 - 10:15 5.50 DRILL DRLH PROD2 10:15 - 10:45 0.50 DRILL CIRC PROD2 10:45 - 13:30 2.75 DRILL TRIP i PROD2 Description of Operations constrictor packers and Spiral glider centralizers floating on each jnt except the Constrictor packer jnts. (174 total) Make up XO Bushing, Casing Seal Bore Ext, Flexlock Liner Hanger, RS Packoff Seal nipple, and HRD ZXP Liner Top PKR, with BOT running tools. Total BHA length of liner assembly = 6728.88'. PU WT = 95K, SO WT = 55K. Continue RIH with Liner on Drill Pipe from 6728' - 11259' with no problems. 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 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. Monitor well -Static. POOH & Lay down liner running tools. Clear & clean rig floor, Pull wear bushing. Rig & test BOPE to 250 psi low & 3500 psi high, Rig down test equip., Set wear bushing, AOGCC John Crisp witnessed test. Service top drive, Change out saver sub. Pick up whipstock tools to floor, Thaw & make up same, Pick up MWD & 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'. Continue RIH to 4,601'. Orient whipstock to 8 degrees left of highside, Shear off bolt. Circ & change over to 8.7 ppg MOBM. 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. Work thru window several times, Pump sweep & circ hole clean at rate of 320 gpm @ 2500 psi. Observe well, Pump dry job, POOH to BHA. Down load MWD, Lay down BHA & Mills (6-3/4" mill in guage), Note; Found pieces of wood on top MWD: 'Clear 8~ Clean rig floor, Pull wear bushing, Make up flushing tool & flush stack, Install wear bushing, Clear floor Pick up Sperry-Sun mud motor & adjust to 1.76 deg, Make up bit. Plug in and program MWD tools. Continue to pick up BHA, NMDC's, HWDP, Jars. RIH removing 51 supersliders f/ 17 stands, Pick up 4- 4" test Lo-Tad's, Fill pipe & test MWD. RIH to 4494', Fill pipe, Test MWD, Orient to 8 deg: left.. Go thru window @ 4507' to 4519' with no problem, Wash & ream f/ 4522' to 4535'. 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 on/off 4/3K, ECD 9.74 ppg, Max gas 72 units. Circ btm's up. Monitor well, Pump dry job, POOH to MWD. Printed: 2!7!2006 10:40:10 AM ConocoPhillips Alaska Page 13 of 22 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 Frcr7~ - To Hours Code Sub Phase Code 12/23/2005 13:30 - 14:00 0.50 DRILL OTHR PROD2 14:00 - 15:00 1.00 DRILL PULD PROD2 15:00 - 16:15 .1.25 DRILL PULD PROD2 16:15 - 17:15 1.00 DRILL OTHR PROD2 17:15 - 18:30 1.25 DRILL PULD PROD2 18:30 - 20:15 1.75 DRILL TRIP PROD2 20:15 - 21:30 1.25 RIGMNT RSRV PROD2 21:30 - 21:45 0.25 DRILL TRIP PROD2 21:45 - 22:30 0.75 DRILL REAM PROD2 22:30 - 00:00 1.50 DRILL DRLH PROD2 112/24/2005 100:00 - 12:00 1 12.001 DRILL DRLH PROD2 12:00 - 00:00 I 12.00 DRILL DRLH PROD2 12/25/2005 100:00 - 12:00 I 12.00 I DRILL I DRLH I PROD2 12:00 - 16:45 I 4.751 DRILL DRLH PROD2 16:45 - 17:30 0.751 DRILL I CIRC PROD2 17:30 - 00:00. 6.50 I DRILL DRLH PROD2 12!26/2005 100:00 - 01:30 ! 1.50 I DRILL I DRLH I PROD2 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 6-3/4" 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 2/2.5K. 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 wf 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' ND (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: 2!T/2006 10:40:10 AM • • ConocoPhillips Alaska Page 14 of 22 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 12/26/2005 00:00 - 01:30 01:30 - 01:45 01:45 - 05:45 05:45 - 06:45 06:45 - 07:15 07:15 - 08:30 08:30 - 10:30 10:30 - 13:45 1.50 I DRILL DRLH ~ PROD2 0.25 DRILL CIRC PROD2 4.00 DRILL DRLH PROD2 1.001 DRILL I CIRC I PROD2 0.50 DRILL TRIP PROD2 1.25 DRILL REAM PROD2 2.001 DRILL I DRLH I PROD2 3.25 I DRILL I DRLH I PROD2 13:45- 00:00 10.251 DRILL DRLH PROD2 112!27/2005 100:00 - 02:30 02:30 - 02:45 02:45 - 04:15 04:15 - 04:30 04:30 - 12:00 12:00 - 16:00 16:00 - 17:15 2.501 DRILL I DRLH I PROD2 0.251 DRILL I SURV I PROD2 1.501 DRILL (CIRC IPROD2 0.25 DRILL SURV PROD2 7.50 DRILL WIPR PROD2 4.001 DRILL WIPR I PROD2 1.251 DRILL 1CIRC IPROD2 Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number: Description of Operations MOBM, ave ECD 11.13 ppg, ave BGG 45 units, max gas 126 units, drilled concretions f/ 9955'-57'. 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 10,415' 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 we4L" Time drill f/ 10,115' 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' ND (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 f/ 10260'-63', 10274'-7T. 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' MD to 11,645' MD/3,703' ND (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 TQ=7K @ 100 rpm. SPR #1=20stk/580psi, 30stk/700psi SPR #2=20stk/590psi, 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, TO=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. rnncea: unzutro lU:4UaU HM • • ConocoPhillips Alaska Page 15 of 22 Operations Summary Report Legal Well Name: 1J-101 Common W ell Name: 1J-101 Event Nam e: ROT -D RILLING Contractor Name: n1334@ ppco.co m Rig Name: Doyon 1 41 Date From - To Hours Code Phase Code ',12/27/2005 17:15 - 20:15 3.00 DRILL VVIPR PROD2 20:15 - 23:00 2.75 DRILL WIPR PROD2 23:00 - 00:00 1.00 DRILL CIRC PROD2 12/28/2005 00:00 - 01:30 1.50 DRILL CIRC PROD2 01:30 - 02:45 1.25 DRILL CIRC PROD2 02:45 - 03:15 0.50 DRILL TRIP PROD2 03:15 - 09:15 6.00 DRILL TRIP PROD2 09:15 - 09:30 0.25 DRILL PULD PROD2 09:30 - 10:30 1.00 DRILL OTHR PROD2 10:30 - 11:30 1.00 DRILL PULD PROD2 11:30 - 12:00 0.50 DRILL PULD CMPLT2 12:00 - 12:45 0.75 WINDO ULD CMPLT2 12:45 - 15:00 2.25 WINDO RIP CMPLT2 I 15:00 - 15:30 0.50 WINDOV ~f'RIP CMPLT2 15:30 - 16:00 0.50 WINDO ~IRC CMPLT2 16:00 - 18:45 2.75 WINDO RIP CMPLT2 18:45 - 20:15 1.50 WINDO ULD CMPLT2 20:15 - 20:45 0.50 CASE RURD CMPLT2 20:45 - 00:00 3.25 CASE RUNC CMPLT2 12/29/2005 00:00 - 03:00 3.00 CMPLTN RUNT CMPLT2 03:00 - 04:30 1.50 CMPLTN RUNT CMPL~'2 04:30 - 05:00 0.50 CMPLTN RUNT CMPLT2 05:00 - 08:30 3.50 CMPLTN TRIP CMPLT2 08:30 - 09:45 1.25 CMPLTN OTHR CMPLT2 Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number. Description of Operations TIH from 4,476' to 9,686'. No slack off weight @ 9,686'. Washed and reamed from 9,686' to 11,645' w/ 75 spm (266 gpm), 140 rpm, TO=5.5K. Pumped 30 bbls weighted hi-vis sweep w/ 89 spm (316 gpm), 140 rpm, 3900 psi, TQ=7K. Krevs=85389. Cont'd circ. sweep and 3 B/Us for total 12,000 stks w/ 92 spm, 4000 psi. Displace well to SFOBM w/ 92 spm, 4100 psi, 140 rpm. 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 POOH from 11,645' to window @ 4,507' w/ 10-20K overpull. Pulled from window to BHA @ 369'. PUW=165K SOW=50K Rack back HWDP, jars, NM DCs. UD stab, float sub. Plugged in and downloaded MWD: UD TM HOC, PWD, Slimphase 4 w/ DGR, smart stab, DM HOC, NM pony collar, Geo-Pilot and bit. Cleared and cleaned rig floor. P/U and M/U whipstock retrieval BHA w/ 1jt HWDP, bumper, oil jars, XO, 3 stds hybrid DP. TIH from 329' to 4,497'. PUW=120K SOW=105 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. Circa BU w/ 85 spm (302 gpm), 1900 psi. POOH from 4,413' to 298' (Fill actual=44, Calculated=43). Dropped 1.75" drift. 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. R/U to run 4.5" liner. Held PJSM. Ran 4.5" liner to jt #115 as per detail. PUW=68K SOW= 69K. 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'). PJSM. Discuss safety issues and procedure for making up Slim Hole MWD assmy. Make up Baker Model 61 FHH Hook Hanger assembly, pups, with crossoverjoint, Casing Swivel, running and setting tools. Make up Ball seat shear sub and Slimhole MWD assembly, oriented 180 DEG from Hook on hanger. M/U 1 std 4" DP @ 7,225'. Pulse tested MWD w/ 110 gpm @ 550 psi. Blew down TD. Cont'd to run liner in hole on DP from 7,225' to 11,618'. PUW=185K SOW=60K 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 degrees out and slack off to RIH past bottom of window to liner depth of Printed: 2/7/2006 10:40:10 AM • ConocoPhillips Alaska Page 16 of 22 Operations Summary Report Legal Well Name: 1J-101 Common Weil Name: 1J-101 Event Name: ROT -DRILLING Contractor Name:. n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number: Description of Operations 12/29/2005 08:30 - 09:45 1.25 CMPLTN OTHR CMPLT2 11,629'. Pull Back up, reorient to $ 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 1 314" ball. Top of hook hanger @ 4503.14'. PUW=123K SOW=70K 09:45 - 10:00 0.25 CMPLTN CIRC CMPLT2 Circ'd @ 110 gpm w/ 380 psi. 10:00 - 10:15 ~ 0.25 ~ WELCTL OTHR I CMPLT2 10:15 - 12:00 1.75 CMPLTN TRIP CMPLT2 12:00 - 12:30 0.50 CMPLTN TRIP CMPLT2 12:30 - 13:30 1.00 CMPLTN TRIP CMPLT2 13:30 - 14:00 0.50 CMPLTN RURD CMPLT2 14:00 - 15:00 1.00 CMPLTN PULD CMPLT2 15:00 - 16:45 I 1.751 CMPLTN( TRIP (CMPLT2 16:45 - 17:30 0.75 CMPLTN( TRIP CMPLT2 17:30 - 17:45 0.25 CMPLTN PCKR CMPLT2 17:45 - 18:15 0.50_ CMPLTN PCKR CMPLT2 18:15 - 18:45 0.50 CMPLTN CIRC CMPLT2 18:45 - 20:30 1.75 CMPLTN TRIP CMPLT2 20:30 - 21:00 0.50 CMPLTN PULD CMPLT2 21:00 - 00:00 3.00 WINDO ULD PROD3 12/30/2005 00:00 - 01:00 1.00 WINDOW OTHR PROD3 01:00 - 01:15- 0.25 WINDO ULD PROD3 01:15 - 01:30 0.25 WINDO THR PROD3 01:30 - 03:45 2.25 WINDOV' ITRIP PROD3 03:45 - 04:15 0.50 WINDO RIP PROD3 04:15 - 04:30 0.25 WINDOV~ RIP PROD3 04:30 - 05:00 0.50 WINDOW SETW PROD3 05:00 - 06:00 1.00 WINDOWCIRC PROD3 06:00 - 12:00 6.00 WINDOIIVSCML PROD3 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. Held PJSM. M/U LEM to 363'. Baker Seal assembly (3.26'), Crossoverjoint IBT x STL (43.04'),4 1/2" IBT pup (31.04'), Camco "DB" Nipple 3.563" tD (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 (2.7T), 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.. Checked flow, static. POOH from 4,480' to 37'. 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 1/2" 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(271.7'). 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 whipstock @ 4,206'. Displaced well to MOBM @ 80 spm, 2000 psi. 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 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 Code Phase Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1!7/2006 Group: Rig Number: Description of Operations 112/30!2005 106:00 - 12:00 I 6.001 WINDOWSCML I PRODS 12:00 - 13:00 I 1.001 WINDOWCIRC I PRODS 13:00 - 14:45 1.75 WINDOV~/T'RIP PRODS 14:45 - 16:15 1.50 WINDO ULD PRODS 16:15 - 16:45 I 0.501 WELLSI~ EORP PRODS 16:45 - 19:45 3.00 WELCT BOPE PRODS 19:45 - 20:00 0.25 WELLS EORP PRODS 20:00 - 22:30 2.50 DRILL PULD PRODS 22:30-00:00 1.50 DRILL. TRIP PRODS 12!3112005 00:00 - 00:30 0.50 DRILL TRIP PRODS 00:30 - 01:45 1.25 WELLS EQRP PRODS 01:45 - 02:00 0.25 DRILL TRIP PRODS 02:00 - 12:00 10.00 DRILL I DRLH PRODS 12:00 - 00:00 I 12.001 DRILL I DRLH I PRODS 1/1/2006 100:00 - 12:00 12.00 DRILL ~ DRLH PRODS 12:00 - 00:00 ~ 12.00 ~ DRILL ~ DRLH ~ PRODS 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 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. Flow checked, static. POOH from 4,218' to 97'. L/D mill, XO, bumper sub, downloaded MWD, TM, MWD, DM, F/S, 1 jt 3.5" HWDP, window mill, Tower and upper mill (upper mill in gauge). Removed mill and BHA from rig floor. Drained and flushed stack after milling operations. Pulled wear bushing. R/U and test BOP stack, HCR's & manual valves. Test Choke mainfold valves, upper & lower IBOP valves, floor safety valve & dart valve.All tests 250 PSI Low / 3500 PSI High. Recorded on chart. Jeff Jones with AOGCC waived witness of test. Tested gas alarms and PVT and high flow alarms. R/D test equipment. Installed wear bushing. 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. TIH from 369' to 2,985'. Cont'd TIH to 4,107. Slipped and cut drilling line and serviced top drive. 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 TQ=2K. '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' 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, 30spm/480psi 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' 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'. Drilled 6.75" D lateral from 8,056' to 9,231' MD / 3,537' TVD ADT=9.67. Printed: 2r!/2006 10:40:10 AM • ConocoPhillips Alaska Page 18 of 22 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 1/1/2006 (12:00 - 00:00 I 12.00 I DRILL DRLH PROD3 1/2/2006 00:00 - 12:00 12.00 DRILL DRLH PROD3 12:00 - 00:00 12.00 DRILL DRLH PROD3 11/3/2006 100:00 - 02:00 I 2.001 DRILL I DRLG I PROD3 Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number. 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, 30spml590psi 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' ND ADT=8.47. PUW=130K SOW=40K ROT=86K TOoh/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 TOon/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 02:00 - 04:15 2.251 DRILL CIRC PROD3 04:15 - 05:15 1 1:00 I DRILL I WIPR I PROD3 05:15 - 12:00 I 6.751 DRILL !WIPR I PROD3 12:00 - 15:00 ~ 3.00 ~ DRILL ~ WIPR ~ PROD3 15:00 - 16:00 I 1.001 DRILL i CIRC I PROD3 16:00 - 18:45 ~ 2.75 ~ DRILL ~ WIPR I PROD3 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% 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 PSIa 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% increase in cuttings when sweep across shakers. Monitor well -static. Trip back in hole from 4185' - 8940' (4755'), until Printed: 2/7/2006 10:40:10 AM • • ConocoPhillips Alaska Page 19 of 22 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 Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number. Description of Operations 1/3/2006 16:00 - 18:45 2.75 DRILL WIPR PROD3 18:45 - 22:15 3.50 DRILL WIPR PROD3 22:15 - 00:00 I 1.751 DRILL I CIRC I PROD3 11/4/2006 ~ 00:00 - 00:45 ~ 0.751 DRILL ~ CIRC ~ PROD3 00:45 - 02:15 I 1.501 DRILL I CIRC 1 PROD3 02:15 - 02:30 0.251 DRILL OBSV PROD3 02:30 - 08:30 6.00 DRILL TRIP PROD3 08:30 - 10:00 1.50 DRILL PULD PROD3 10:00 - 10:45 0.75 DRILL OTHR PROD3 10:45 - 12:00 1.25 DRILL PULD PROD3 12:00 - 12:30 0.50 WINDO ULD CMPLT3 12:30-14:00 1.50 WINDO RIP CMPLT3 14:00 - 14:15 0.25 WINDO THR CMPLT3 14:15 - 14:45 0.50 WINDOW CIRC CMPLT3 14:45 - 17:00 2.25 WINDOVI /fRIP CMPLT3 17:00 - 19:00 2.00 WINDOW PULD 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 8~ 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' ND. 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 f X f 1 / 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 fill 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 Page 20 of 22 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 1/4/2006 117:00 - 19:00 ~ 2.OO WINDOWPULD ICMPLT3 19:00 - 19:30 I 0.501 CASE I RURD ICMPLT3 119:30 - 22:30 I 3.00 I CASE I RUNC ICMPLT3 22:30 - 00:00 I 1.50 f CASE I RUNC ICMPLT3 I 1 /5/2006 00:00 - 02:30 2.50 CASE RUNC ICMPLT3 02:30 - 03:45 I 1.251 CASE I RUNC ICMPLT3 03:45 - 04:00 ~ 0.25 CASE OTHR CMPLT3 04:00 - 06:30 2.50 CASE RUNL CMPLT3 06:30 - 07:30 I 1.001 CASE I RUNL ICMPLT3 07:30 - 08:00 I 0.501 CASE J OTHR ICMPLT3 08:00 - 08:30 0.50 CASE I CIRC ICMPLT3 08:30 - 11:00 2.50 CMPLTN TRIP CMPLT3 11:00 - 12:00 1.00 CMPLTN TRIP CMPLT3 12:00 - 22:45 10.75 CMPLTN TRIP CMPLT3 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 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 1/2" HWDP (29.81'), 4 3/4" NM Float sub (2.41'), MWD (44.0'), 4 3/4" Bumperjars (7.86')Crossover IF xXT39 (1.65'), 3 stands 4 3/4" 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 3 172" 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 welt -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 • • ConocoPhillips Alaska Page 21 of 22 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 Spud Date: 12/6/2005 Start: 12/6/2005 End: 1/7/2006 Rig Release: 1/7/2006 Group: Rig Number: Description of Operations 1/5/2006 22:45 - 00:00 1.25 RIGMNT RSRV CMPLT3 Slip & cut 68' of drilling line, and service Top Drive. 1/6/2006 00:00 - 00:30 0.50 CMPLTN PULD CMPLT3 Continue Rig up completion running equipment. 00:30 - 03:00 2.50 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. 03:00 - 03:45 0.75 CMPLTN PULD CMPLT3 Rig down 7 5/8" Eckel tongs, and Rig up Double stack tongs for completion. 03:45 - 05:30 1.75 CMPLTN PULD CMPLT3 POOH, rack back 34 stands of 4 1/2" completion string, for running ESP completion. 05:30 - 06:00 0.50 CMPLTN OTHR CMPLT3- Rig up and BOLDS, pull wear bushing. 06:00 - 06:45 0.75 CMPLTN RURD CMPLT3 Clear & Clean floor area. Pull all Centrilift equipment to rig floor. Pull all Clamps and bands to floor. 06:45 - 07:45 1.00 CMPLTN RURD CMPLT3 PJSM. Discuss safety issues and procedure and safety for hanging ESP cable and sheave in derrick: Pufl ESP line & sheave to rig floor. Hang sheave in Derrick, ensure tied off as not to fall. 07:45 - 12:00 4.25 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. 12:00 - 12:30 0.50 CMPLTN RUNT CMPLT3 Continue MU ESP assembly attaching ESP cable, and testing same as per Centrilift Rep. 12:30 -.19:00 6.50 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-Cameo 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' ND .36 DEG INC. 19:00 - 19:15 0.25 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. 19:15 - 20:45 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. 20:45 - 22:30 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. 22:30 - 00:00 1.50 CMPLTN OTHR CMPLT3 Continue with splicing Pigtail to ESP line, wrapping & securing ESP cable. Total Cannon Clamps run = 61, Total Flat Guards run = 2 ,Total Protectolizers run = 3 NOTE: SIMOPS -Change out Liners to 6" in 1 Mud Pump #1. 1/7/2006. 00:00 - 00:30 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. 00:30 - 00:45 0.251 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 • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-101 Common Well Name: 1 J-101 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phass Start: 12/6/2005 Rig Release: 1/7/2006 Rig Number: Page 22 of 22 Spud Date: 12/6/2005 End: 1/7/2006 Group: Description of Operations 1/7/2006 00:45 - 01:15 0.50 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. 01:15 - 02:00 0.75 CMPLTN RUNT CMPLT3 RILDS. Verify all made up correctly, and measure. Rig up & test upper and lower Hanger seals to 5000 PSI for 10 minutes each. Good test. Backout & lay down landing joint. 02:00 - 03:00 .1.00 WELCT 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 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 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 CMPLT 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. Rig Released @ 1200 HRS 1R/2006. Printed: 2/7/2006 10:40:10 AM .. ~; ~' Halliburton Company Global Report. ~~~mlr.un: ~~eophdlip~,Ia~kalnr. " hater r~~~Y2006 Time: 1:0'5727 Page: 1; Firl~l: f ~,i 3 it F i.~i i lni! ~ ~~~~~ li~~.ir~•i A'E) Reference: Nell: 1J 101 True Nadh ~ilr F. ~ A crux ~I i I Fl~i P.~ference: , 1J 101L2 109.0. V1 rll. I 1 1 ~ ~~~,ii .n i~ ~ti~ I ~Irience: Well (O.OON 0 OOE,O OOAzi) I ~~ rupath: a~ ~u~ LL S^rve}° Calculation ltethud: Minimum Curvature Db: Oracle j Sw-vey: 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 System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Kuparuk 1 J 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 Ground Level: 0.00 ft Grid Convergence: 0.45 deg Well: 1J-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 L2 Drilled From: 1J-101 500292328661 Tie-on Depth: 4132.88 ft Current Datum: 1 J-101 L2: Height 109.00 ft Above System Datum:. Mean Sea Level Magnetic Data: 11/3/2005 Declination: 24.29 deg Field Strength: 57563 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E!-W Direction ft ft ft deg 25.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath -~ Date: 1/13/2006 Validated: No Version: 1 Actual From To Survey 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 4132.88 1J-101 (933.26-5348.51) (0) MWD+IFR-AK-CAZ-SC MIND+IFR AK CAZ SCC j 4206.00 11676.21 1J-101 L2 (4206.00-11676.21) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey " b1D Incl Azirn ft -_-- deg:. - deg -- 28.00 0.00 0.00 100.00 0.41 315.04 200.00 0.52 347.22 300.00 0.66 342.49 400.00 0.75 345.17 500.00 1.13 351.65 600.00 1.41 355.45 662.00 1.34 355.45 .752.00 1.60 0.61 843.00 1.74 8.06. 933.26 2.14 28.78 1025.28 2.46 39.48 1124.64 2.48 36.34 1217.35 2.40 46.26 1308.28 2.69 45.39 1402.35 2.84 42.40 1495.88 2.50 43.81 V D Sys T~!I) V/S E/W MapN ft ft ft ft ft 28.00 -81.00 0.00 0.00 5946086.15 100.00 -9.00 0.18 -0.18 5946086.33 200.00 91.00 0.88 -0.54 5946087.02 299.99 190.99 1.87 -0.81 5946088:01 399.98 290.98 3.05 -1.15 5946089.19 499.97 390.97 4.66 -1.46 5946090.80 599.95 490.95 6.86 -1.70 5946093.00 661.93 552.93 8.35 -1.82. 5946094.48 751.90 642.90 10.65 -1.89 5946096.78 842.86 733.86 13.29 -1.68 5946099.42 933.07 824.07 16.12 -0.68 5946102.27 025.01 916.01 19.15 1.40 5946105.31 124.28 1015.28 22.53 4.03 5946108.71 216.91 1107.91 25.49 6.62 5946111.69 307.75 1198.75 28.30 9.52 5946114.52 401.71 1292.71 31.57 12.66 .5946117.82 495.14 1386.14 34.76 15.64 5946121.02 i!'Ia p E Tool.. ft 558754.33 TIE LINE 558754.15 C6-GYRO-SS 558753.79 CB-GYRO-SS 558753.51 CB-GYRO-SS 558753.16 CB-GYRO-SS 558752.83 CB-GYRO-SS 558752.58 CB-GYRO-SS 558752.45 CB-GYRO-SS 558752.36 CB-GYRO-SS 558752.54 CB-GYRO-SS 558753.53 MWD+IFR-AK-CAZ-SC 558755.58 MWD+IFR-AK-CAZ-SC ~ 558758.19 MWD+IFR-AK-CAZ-SC 558760.76 MWD+IFR-AK-CAZ-SC 558763.63 MWD+IFR-AK-CAZ-SC 558766.74 MWD+IFR-AK-CAZ-SC 558769.69 MWD+IFR-AK-CAZ-SC I ~" 1. ~' Ha l~burton Company Global Report I~1~1~I: E n ~ri.~ i L!nit ~~ilr: r it ii i.~' 1 ~i~ ~~~Ilp.ith:' ~J-1~! IL2 Stir ~ rc (~~-u~lwifclAI II'rli~irnie~ II 1.1 l~il Tn f,arth ~ crru.il; 1111 6eli~rcuce: t~-tOILG. IUy:U Vc<~ti~m ~~til Rctc rc nr e: Well (OOON,O.OOE;O,OOAzi) tini~~~~ r ,Irulation Dlcthodi Minimum Curvature Db: OracLe ill) Inrl \iiui l ~ U tip. ll I~ 1589.49 3.84 39.66 1588.60 1479.60 1682.18 6.25 47.26 1680.93 1571.93 1774.94 8.26 48.06 1772.94 1663.94 1867.72 9.77 44.90 1864.57 1755.57 1961.04 12.22 43.06 1956.17 1847.17 2054.22 15.21 40.29 2046.69 1937.69 2147.04. 16.21 42.92 2136.04 2027.04 2270.88 17.86 44.57 2254.44 2145.44 2363.84 17.00 43.26 2343,13 2234.13 2457.01 16.37 43.11 2432.38 2323.38 2551.08 19.88 47.57 2521.77 2412.77 2644.35 23.68 43.48 2608.37 2499.37 2736.56 28.67 37.82 2691.11 2582.11 2830.94 32.48 33.99 2772.37 2663.37 2924.19 37.30 30.72 2848.84 2739.84 3016.39 43.42 27.43 2919.07 2810.07 3111.21 49.01 28.16 2984.65 2875.65 3203.20 53.02 26.61 3042.52 2933.52 3297.32 54.45 27.67 3098.19 2989.19 3391.15 54.17 26.32 3152.93 3043.93 3484.69 60.93 26.02 3203.09 3094.09 3577.93 62.01 23.96 3247.63 3138.63 3666.88 66.03 19.22 3286.60 3177.60 3759.55 -64.62 18.29 3325.29 3216.29 3850.67 70.00 18.24 3360.43 3251.43 3945.82 74.20 14.44 3389.68 3280.68 4039.23 76.27 9.30 3413.50 3304.50 4132.88 76.39 4.04 3435.64 3326.64 4206.00 76.89 359.95 3452.54 - 3343.54 4346.17 82.41 7.67 3477.75 3368.75 4443.08 84.09 5.83 3489.15 3380.15 4535.72 89.25 6.50 3494.53 3385.53 4629.65 94.50 5.09 3491.45 3382.45 4722.47 92.60 4.60 3485.71 3376.71 4815.63 90.69 3.71 3483.03 3374.03 4909.09 88.71 359.63 3483.52 3374.52 4999.85 89.40 359.24 3485.02 3376.02 5093.81 90.02 359.65 3485.49 3376.49 5189.31 89.71 359.40 3485.72 3376.72 5281.04 89.65 358.60 3486.23 3377.23 5377.52 88.53 356.55 3487.76 3378.76 5470.58 88.78 353.34 3489.95 3380.95 5563.30 89.03 353.74 3491.72 3382.72 5657.07 90.89 357.02 3491.79 3382.79 5750.73 89.95 357.72 3491.10 3382.10 5844.14 89.46 358.68 3491.58 .3382.58 5938.06 88.59 359.95 3493.18 3384.18 6031.00 89.34 2.04 3494.86 3385.86 6124.82 89.59 3.44 3495.73 3386.73 6217.60 91.88 5.64 3494.54 3385.54 6310.92 90.57 1.90 3492.55 3383.55 6404.61 89.83 358.47. 3492.22 3383.22 6497.45 87.72 353.37 3494.21 3385.21 ~ ~ C;~~ VahA ~ ~ ~ 1LapG - TpoF it ft I; ft - 38.64 19.05 5946124.94 558773.08 . MWD+IFR-AK-CAZ-SC 44.46 24.74 5946130.80 558778.72 MWD+IFR-AK-CAZ-SC ~ 52.34 33.40 5946138.74 558787.32 MWD+IFR-AK-CAZ-SC j 62.37 43.92 5946148.86 558797.76 MWD+IFR-AK-CAZ-SC (` 75.20 56.25 5946161.78 558809.99 MWD+IFR-AK-CAZ-SC ' 91.73 70.89 5946178.42 558824.50 MWD+iFR-AK-CAZ-SC 110.51 87.59 5946197.33 558841.05 MWD+IFR-AK-CAZ-SC 136.69 112.69 5946223.71 558865.94 MWD+IFR-AK-CAZ-SC 156.75 132.01 5946243.91 55$885.10 MWD+IFR-AK-CAZ-SC 176.25 150.31 5946263.55 558903.25 MWD+IFR-AK-CAZ-SC 196.73 171.19 5946284.19 558923.96 MWD+IFR-AK-CAZ-SG 221.03 195.79 5946308.68 558948.37 MWD+IFR-AK-CAZ-SC 251.96 222.12 5946339.81. 558974.45 MWD+fFR-AK-CAZ-SC i 290.88 250.18 5946378.94 559002.21 MWD+IFR-AK-CAZ-SC 335.95 278.63 5946424.24 559030:30 MWD+fFR-AK-CAZ-SC 388.15 307.53 5946476.65 559058.79 MWD+IFR-AK-CAZ-SG 448.67 339.45 5946537.41 559090.24 MWD+IFR-AK-CAZ-SC 512.16 372.31 5946601,15 559122.60 MWD+IFR-AK-CAZ-SC 579.69 406.93 5946668.94 559156.69 MWD+IFR-AK-CAZ-SC 647.59 441.52 5946737.10 559190.75 MWD+IFR-AK-CAZ-SC ; 718.39 476.31 5946808.17 559224.97 MWD+IFR-AK-CAZ-SC i 792.64 510.91 5946$82.67 559258.99 MWD+IFR-AK-CAZ-SC 866.96 540.26 5946957.22 559287.76 MWD+IFR-AK-CAZ-SC i 946.70 567.34 5947037.15 55931421 MWD+IFR-AK-CAZ-SC 1026.50 593.67 5947117.15 559339.92 MWD+IFR-AK-CAZ-SC 1113.36 619.10 5947204.20 .559364.67 MWD+IFR-AK-CAZ-SC 1201.72 637.65 5947292.69 559382.53 MWD+IFR-AK-CAZ-SC 1292.07 648.22 5947383.11 559392.38 MWD+IFR-AK-CAZ-SC j 1363.15 650.69 5947454.20 559394.30 MWD+IFR-AK-CAZ-SC 1500.56 659.92 5947591,67 559402.46 MWD+IFR-AK-CAZ-SC 1596.13 671.23 5947687.31 559413.02 MWD+IFR-AK-CAZ-SC 1688.04 681.16 5947779.29 559422.24 MWD+IFR-AK-CAZ-SC 1781.41 690.64 5947872.72 559430.98 MWD+IFR-AK-CAZ-SC ' 1873.71 698.46 5947965.08 559438.09 MWD+IFR-AK-CAZ-SC 1966.59 705.21 5948057.99 559444.11 MWD+IFR-AK-CAZ-SC 2059.98 707.93 5948151.39 559446.10 MWD+IFR-AK-CAZ-SC 2150.72 707.04 5948242.12 559444.50 MWD+IFR-AK-CAZ-SC 2244.68 706.13 .5948336.05 559442.85 MWD+IFR-AK-CAZ-SC 2340.17 705.34 5948431.53 559441.32 MWD+IFR-AK-CAZ-SC ~ 2431.89 703.74 5948523.22 559439.00 MWD+IFR-AK-CAZ-SC 2528.26 699.65 5948619.55 559434.17 MWD+IFR-AK-CAZ-SC 2620.92 691.46 5948712.13 559425.25 MWD+IFR-AK-CAZ-SC ~ 2713.04 681.03 5948804.16 559414.10 MWD+IFR-AK-CAZ-SC 2806.48 673.48 5948897.53 559405.82. MWD+IFR-AK-CAZ-SC 2900.04 669.18 5948991.05 559400.80 MWD+IFR-AK-CAZ-SC 2993.40 666.25 5949084.37 559397.13 MWD+IFR-AK-CAZ-SC 3087.30 665.12 5949178.25 559395.28 MWD+IFR-AK-CAZ-SC 3180.20 666.74 5949271.15 559396.17 MWD+IFR-AK-CAZ-SC 3273.91 671.22 5949364.88 559399.92 MWD+IFR-AK-CAZ-SC i 3366.38 678.56 5949457.40 559406.54 MWD+IFR-AK-CAZ-SC 3459.46 .684.70 5949550.51 559411.95 MWD+IFR-AK-CAZ-SC 3553.13 685.00 5949644.18 559411.52 MWD+IFR-AK-CAZ-SC 3645.68 678.40 5949736.66 559404.20 MWD+IFR-AK-CAZ-SC •'' Halliburton Company Global Report r ~,nilr in,,._ r„~,,,,-~ph~il ~~ pla~vq ins Tlafe- r~.94i2n~F < Cimc: 10.'57:27 Page; 3 IirIJ: } iq ~;ruh 'l!iiit (~~-or~l uiarcjAI:I P.c l~~renee: '' We11; 1J 101',7rueNorth ~ilc: ~ up ~;i i.!P. ',I >' ~i~i ~crdra l ~l AUi Rel~c rrnee: 1J 10't'L2. 109:0 ~1~~II: 1- 1,i1 ~cr~i~~u i~~~Kel~rt ure; Well(OOON,O.OOEO.OOAzi) ~Vellp~th:' ` 1J 1 01L2 Sunny C?~Icnlation Alethod; Mi nimum Curvatu re II4: Orade Su rvcy D1D irrcl Ariw I ~ I) I'Vn Sys cA~S F.. W 1t1apN ~ ~IapE Tool ft deg deg ft ~ ! ft it ft ft ft -- 6590.55 86.31 353.67 3499.05 3390.05 3738.06 667.91 5949828.95 559392.98 MWD+IFR-AK-CAZ-SC i 6684.93 89.29 354.30 3502.68 3393.68 3831.84 658.02 5949922.64 559382.37 MWD+IFR-AK-CAZ-SC 6777.62 90.15 354.33 3503.13 3394.13 3924.07 ~ 648.84 59500'14.79 559372.47 MWD+IFR-AK-CAZ-SC 6871.22 87.90 353.26 3504.72 3395.72 4017.10 638.73 5950107.73 559361.63 MWD+IFR-AK-CAZ-SC 6964.80 89.22 352.78 3507.07 3398.07 4109.96 627.36 5950200.48 559349.54 MWD+IFR-AK-CAZ-SC 7055.11 89.90 353.30 3507.77 3398.77 4199.60 616.42 5950290.02 559337.90 MWD+IFR-AK-CAZ-SC i 7151.54 88.65 353.29 3508.99 3399.99 4295.36 605.16 5950385.69 559325.90 MWD+IFR-AK-CAZ-SC 7244.91 89,16 355.75 3510.77 3401.77 4388.28 596.25 5950478.52 559316.26 -MWD+IFR-AK-CAZ-SC I 7336.49 89.53 359.08 3511.82 3402.82 4479.74 592.12 5950569.95 559311.42 MWD+IFR-AK-CAZ-SC 7429.86 89.96 2.63 3512.24 3403.24 4573.09 593.51 5950663.29 559312:08 MWD+IFR-AK-CAZ-SC 7525.93 90.76 1.97 3511.63 3402.63 4669.08 597.36 5950759.30 559315.19 MWD+IFR-AK-CAZ-SC 7618.54 91.69 1.25 3509.65 3400.65 4761:63 599.97 5950851.86 559317.07 MWD+IFR-AK-CAZ-SC 7714.02 87.90 357.25 3509.99 3400.99 4857.06 598.72 5950947,27 559315.07 MWD+IFR-AK-CAZ-SC 7810.37 88.23 356.05 3513.25 3404.25 4953.19 593.09 5951043.34 559308.70 MWD+IFR-AK-CAZ-SC 7909.19 88.41 358.01 3516.14 3407.14 5051.83 587.97 5951141.93 559302.81 MWD+IFR-AK-CAZ-SC .8005.70 90.28 358.50 3517.25 3408.25 5148.29 585.03 5951238.35 559299.12 MWD+IFR-AK-CAZ-SC 8100.38 89.27 358.05 3517.62 3408.62 5242.92 582.18 5951332:95 559295.53 MWD+IFR-AK-CAZ-SC 8193.62 88.10 357.45 3519.76 3410.76 5336.06 578.52 5951426.05 559291.15 MWD+IFR-AK-CAZ-SC 8287.00 88.60 356.84 3522.45 3413.45 5429.29 573.88 5951519.23 559285.77 MWD+IFR-AK-CAZ-SC 8380.14 88.29 359.58 3524.98 3415.98 5522.34 570.97 5951612.24 559282.14 MWD+IFR-AK-CAZ-SC 8472.84 88.29 4.21 3527.74 3418.74 5614.92 574.03 5951704.84 559284.48 MWD+IFR-AK-CAZ-SC 8566.65 89.53 3.86 3529.53 3420.53 5708.48 580.63 5951798.44 559290.35 MWD+IFR-AK-CAZ-SC 8661.06 87.91 1.48 3531.64 3422.64 5802.75 585.03 5951892.73 559294.01 MWD+IFR-AK-CAZ-SC 8754.04 90.34 0.37 3533.06 3424.06 5895.70 586.53 5951985.68 559294.78 MWD+IFR-AK-CAZ-SC 8846.88 88.96 2.51 3533.62 3424.62 5988.50 588.86 5952078.49 559296:39 MWD+IFR-AK-CAZ-SC I 51 8940 91.14 3.92 3533.54 3424.54 6081.98 594.11 5952171.99 559300.91 MWD+IFR-AK-CAZ-SC . 9033.96 91.19 3.76 3531.64 3422.64 6175.20 600.37. 5952265.25 559306.44 MWD+IFR-AK-CAZ-SC 9127.54 88.52 0.46 3531.88 3422.88 6268.69 603.81 5952358.76 559309.15 MWD+IFR-AK-CAZ-SC ' 9219.70 87.54 356.06 3535.05 3426.05 6360.73 601.02 5952450.77 559305.64 MWD+IFR-AK-CAZ-SC 9313.37 87.42 354.42 3539.17 3430.17 6453.99 593.25 5952543.95 559297.15 MWD+IFR-AK-CAZ-SC 9407.10 86.93 355.29 3543.79 3434.79 6547.22 584.86. 5952637.11 559288.03 MWD+IFR-AK-CAZ-SC 9500.87 88.85 359.21 3547.24 3438.24 6640.80 580.36 5952730.64 559282.81 MWD+IFR-AK-CAZ-SC ' 9594.65 88.66 0.40 3549.28 3440.28 6734.56 580.05 5952824.38 559281.75 MWD+IFR-AK-CAZ-SC 9688.49 87.92 1.12 3552.08 3443.08 6828.34 581.29 5952918.17 559282.27 MWD+IFR-AK-CAZ-SC 9775.63 88.29 358.36 3554.96 3445.96 6915.43 580.89 5953005.23 559281.19 MWD+IFR-AK-CAZ-SC 9874.15 87.60 1.74 3558.49 3449.49 7013.87 580.98 5953103.66 559280.51 MWD+IFR-AK-CAZ-SC 9966.97 88.48 2.96 3561.67 3452.67 7106.55 584.78 5953196.37 559283.59 MWD+IFR-AK-CAZ-SC 10061.30 87.91 2.47 3564.64 3455.64 7200.73 589.25 5953290.57 559287.32 MWD+IFR-AK-CAZ-SC 10152.26 87.42 0.53 3568.35 3459.35 7291.58 591.63 5953381.42 559288.99 MWD+IFR-AK-CAZ-SC 10241.22 88.54 358.55 3571.48 3462.48 7380.47 590.91 5953470.30 559287.58 MWD+IFR-AK-CAZ-SC 10333.14 86.54 1.54 3575.43 3466.43 7472.29 590.98 5953562.11 559286.94 MWD+IFR-AK-CAZ-SC 10425.62 87.49 359.92 3580.25 3471.25 7564.64 592.16 5953654.45 559287.39 MWD+IFR-AK-CAZ-SC 10516.22 86.06 0.91 3585.34 3476.34 7655.09 592.81 5953744.90 559287.34 MWD+IFR-AK-CAZ-SC 10607.32 86.44 1.74 3591.30 3482.30 7745.97 594.92 5953835.78 559288.73 MWD+.IFR-AK-CAZ-SC 10698.05 86.31 0.92 3597.04 3488.04 7836.49 597.02 5953926.31 559290.13 MWD+IFR-AK-CAZ-SC 10789.28 86.43 3.78 3602.81 3493.81 7927.45 600.75 5954017.29 .559293.15 MWD+IFR-AK-CAZ-SC 10878.99 87.24 0.85 3607.77 3498.77 8016.94 604.37 5954106.79 559296.07 MWD+IFR-AK-CAZ-SC 10969.42 85.87 2.60 3613.20 3504.20 8107.16 607.08 5954197.02 559298.08 MWD+IFR-AK-CAZ-SC 11060.00 88.12 5.45 3617.95 3508.95 8197.38. 613.44 5954287.28 559303.73 MWD+IFR-AK-CAZ-SC I 11148.20 87.67 0.78 3621.19 3512.19 8285.36 618.22 5954375.29 559307.83 MWD+IFR-AK-CAZ-SC 11240.60 88.23 3.39 3624.50 3515.50 8377.64 621.58 5954467.58 559310.47 MWD+IFR-AK-CAZ-SC 11330.83 86.17 359.92 3628.91 3519.91 8467.70 624.19 5954557.65 559312.37 MWD+IFR-AK-CAZ-SC Halhburton Company Global Report r ~' ` 1 ~mil~an~: i ~-fi I ~ ~.I i~F:~7 liar, I):u~~ i ?1J ~il~, l inu~ I ~ . , _ Nape: Iirl~l: F iil iF ~ i ~~r~,~,t (o-i~~~ini.urfA1 i I'rf~~rrncc: II IJ I True North <iir: E ui ~ru;-. I f _~, rl ~rru~.il iIVI)I I.cfcrcncc: i ~ 1~1F-'L: 109.0 ~1~~11: (I- lul >cc~ion ~~~~~ t~cferrucc: '.' III (O.OON,O:OQE,O.OOAzi) ~~ ~~IIp;iU,_ I i . _~ 1l % ~~~~,~~~ ~ ~alrulati~w ~Ic~h~~~l: Miri~iiurn Curvature D6: Qfacle Sure ~ ~ - \II~ - Intl liini - - IlI) ~~s~l~\ll _ _ -- VAS I~,~1 ~la~iA <,~1fapE Togl "` ~-'.1 '~5~.1 rl ft if It ?t -.. ~ - - _ __ ~ 11421.29 86.75 0.27 3634.49 3525.49 8557.99 624.34 5954647.93. 559311.81 MWD+IFR-AK-CAZ-SC 11511.22 85.50 359.31 3640.57 3531.57 8647.71 624.01 5954737.63 559310.79 MWD+IFR-AK-CAZ-SC 4 11599.93 86.38 359.19 3646.85 3537.85 8736.19 622.85 5954826.09 559308.94 MWD+IFR-AK-CAZ-SC 11676.21 85.07 359.17 3652.54 3543.54 8812.25 621.76 5954902.13 559307.26 MWD+IFR-AK-CAZ-SC 11711.00 85.07 359.17 3655.53 - 3546.53 8846.90 621.26 5954936.78 559306.48 MWD , • 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 L2 Dear Dear Sir/Madam: Enclosed is one disk with the `.PTT and *.PDF files. Tie-on Survey: 4,132.88' MD Window I Kickoff Survey: 11,676.21 ' MD (if applicable) Projected Survey: 11,711.00' MD ao5- ~ ~1- 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 C~~ ~ r? i~(~ Si ned j .i Please cal{ me at 273-3545 if you e any questions or concerns. Regards, Carl lJlrich Survey Manager Attachment(s) r ~~ ~~ J ~ ~ ~ ~ ~ a~ I ~ j ~ 3~ 1 1 ~ x~ i o~ ~ dy ~rss~i~7 ~' i+t~ ~~ ~ + ~ ,(~ d ~ ~ y~~ i 9~ ~ ~, ~ y ~, ~, ~ FRANK H. MURKOWSKI, GOVERNOR 5.,i ~~ ~~ ~~ ~~r+ ,~ t~~ ~ ~ ~+ fib, L~llt).-7~ O~ D/.sJV ~ 333 W. 7"' AVENUE, SUITE 100 COI~TSLRVATIOI~T COMA'IISSIOI~T ;~, ANCHORAGE, ALASKA 99501-3539 .J PHONE (907) 279-1433 Randy Thomas FAx (so7> 27s-75x2 Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: West Sak 1J-lO1Ll2 ConocoPhillips Alaska, Inc. Permit No: 205-184 Surface Location: 2247' FSL, 2453' FEL, SEC. 35, T11N, RlOE, UM Bottomhole Location: 566' FSL, 1844' FEL, SEC. 23, T11N, RlOE, 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. The permit is for a new wellbore segment of existing well KRU 1J-101 Permit No 205-182, API 50-029-23286-00. Production should continue to be reported as a function of the original API number stated above. 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 required test. Contact the Commission's petroleum field inspecto;07) 9- 607 (pager). J DATED this` day of November, 2005 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 NOV 1 ~ 2ao5 Alaska Oil & Gas Cons. CommissiontS~ Anrhnrana 1 a. Type of Work: Drill / Redrill Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil / Multiple Zone ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone Q 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-101 L2 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 11718' TVD: 3642' '~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2247 FSL, 2453' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Property Designation: ADL 25661 & 25650 < West Sak Oil Pool ° Top of Productive Horizon: 1665' FNL, 1841' FEL, Sec. 35, T11N, R10E, UM ~ 8. Land Use Permit: ALK471 &468 13. Approximate Spud Date: 11/23/2005 Total Depth: 566' FSL, 1844' FEL, Sec. 23, T11 N, R10E, UM / 9. Acres in Properly: 2560 ' 14. Distance to ~ 7u-x. ,+~ nv, %~< ~ Nearest Property: 2247 ~fF ~~~ •i < 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: WSP-155 , 1025' @ 11717 16. Deviated wells: Kickoff depth: 4197 ~ ft. Maximum Hole Angle: 93° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1639 psig Surface: 1238 psig ~ 18. Casing Program ifi ti S 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) 40" 20" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 3527' 28' 28' 3555' 2118' 640 sx ASLite, 180 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 8181' 28' 28' 8209' 3481' 480 sx DeepCRETE 6.75" 4.5" 12.6# L-80 BTCM 7521' 4197' 3459' 11718' 3639' 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 Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee rJ BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program 0 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 Pef Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~,~,~ ~ Phone -Z~~ ~~~~ Date Lt,l~yfmS """' P h I Commission Use Only Permit to Drill Number. ~~% ~ J ` j API Number: 50- ~~--~ ~-~ ~--C? /G' -' l~' / Permit Approval Date: • ~` . S See cover letter for other requirements Conditions of approval Sa ples re wired Yes ^ No ~ Mud log required Yes ^ No droge ulfide measures Yes ^ Noi~ Directional survey required Yes ~ No `^ Other: ~~~ ~, ~ ~ C~-Cr () K3.rr~ ~ : ~` ~C ~ ~ `C Q t`~, C?~'q~-1 !r~~'~ ~~ ~ \"Q-C~ `G.~O ~~ APPROVED BY ~ _ J ~~ Approve THE COMMISSION Date: ~~ ry . v -~/ r , Form 10-401 Revised 06/2004 ~ ~ ~\~ Submit in Duplicate Ap~n for Permit to Drill, Well 1J-101 L2 Revision No.0 Saved: 9-Nov-05 Permit It -West Sak Well #1J-101 L2 •~°# r.^ App/ication for Perrrlit to Dril/ Documen +'x t; 1~1t~'I~f~ll M~ x i m i x~ WWII Vplue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (i) ....................................................................................................... 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 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 3 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 Lateral Mud Program (Ml VersaPro Mineral Oil Base) ........................................................................... 4 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 ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12 . Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 e~isiNn~ 1J-101L2 PERMIT lT Page 1 of 6 Printed: 9-Nov-05 r: Ap~n for Perrnit to Drill, Well 1J-101 L2 Revision No.0 Saved: 9-Nov-05 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) .......:........................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (t) Each well must be identifred by a unique name designated by the operator and a unique API number assigned by the commission under 2t7 AAC25.1140(6J. For a well with mu/tip/e well branches, each branch must similar/y be identifred by a unique name andAPl number by adding a suffix to the name designated for the we/i by the operator and to the number assigned to the we// by the commission. The well for which this Application is submitted will be designated as 1J-101 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An app/ication for a Permit to Dri/1 must be accompanied by each of the fo!/owing items, except for an item afready on file with the commission and identifred rn the app/ication: (2) a plat identifying the property and the property's owners and showing (A)fhe coordinates of the proposed location of the we/1 at the surface, at the top of each objective formation, and at tote! depth, referenced to governmental section lines (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained 6y the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the we// at the tap of each objective formation and at tote! depth; Location at Surface 2,24T FSL 2 453' FEL, Section 35, T11N, R10E ASPZone 4 NAD 27 coordinates RKB Elevation 109.0' AMSL Northings: 5,946,086 Eastings: 558,754 Pad Eievation 81.0' AMSL Location at Top of Productive Interval West Sak ~~D" Sand 1,665' FNL, 1,841' FEL, Section 35, T11N, R10E ' ASP Zone 4 NAD 27 Coordinates Measured De th, RKB,• 4 197 Northings: 5,947,430 Eastings.• 559,353 Tote/ t/ertica/De th, RKB.• 3 459 Total Vertical De th, SS.• 3 350 Location at Total De th 566' FSL 1844' FEL, Section 23, Ti1N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 11,718 " Northings 5,954,941 Eastings.• 559,285 Total ~erticalDe th, RKB.• 3,642 Total ~ertica/ De th, SS.• 3 532 and. (DJ other information required by 20 AAC25.050(b); 1J-101L2 PERMIT IT Page 2 of 6 /'~ ~ ~ Printed: 9-Nov-05 App~n for Permit to Drill, Well 1J-101 L2 Revision No.O Saved: 9-Nov-05 Requirements of 20 AAC 25.050(b) df a weif is to be intentionally deviated, the application far a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed we/Ibore, inc/uding all adjacent we//bores within 2D0 feet afany portion of the proposed wet/; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed we!/bore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in pub/ic records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the on/y affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.D05(c)(3) An application for a Permit to Drill must be accompanied by each of the fo/lowing items, except Far an item a/ready on File with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 2.~ 035, 20 AAC 25.035, or 20 AAC 25.037, as applicab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete the well. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app/ication far a Permit to Drift must be accompanied by each of the fo/lowing items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, inc/uding (A) the maximum downhote pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the iJ area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). 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 °D" sand formation is 1,214 psi, calculated thusly: ~ MPSP =(3,642 ft TVD)(0.45 - 0.11 psi/ft) =1,238 psi (B) data on potentra/gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differentia! sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dri/1 must be accompanied by each of the Following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); The parent wellbore, 1J-101, will be completed with 7-5/8" intermediate casing landed in the West Sak A- 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. 1J-101L2 PERMIT lT Page 3 of 6 Printed: 9-Nov-05 ~~ Ap~n for Permit to Drill, Well 1J-101 L2 Revision No.O Saved: 9-Nov-05 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 following items, except for an item already on file with the commission and identified in the application; (6) a complete proposed casing and cementing program as required by 20 AAC Zs.03C1, and a description of any slotted liner, pre- perforated liner, or screen to be Installed; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top Btm Csg/Tbg Size Weigh Length MDITVD MDITVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 6,026 5,490 / 3,712 11,516 / 3,856 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 10 a ateral 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) Diverter System Information Requirements of 20 AAG 25.005(c)(7) An applicat/on for aPerm/t to Dir// must be accompanied by each of the fol%wing items, except for an item already on file wr`th the commission and identified in the app/ication: (7) a diagram and descr/pt/on of the diverter system as required by 20 AAC25.03s, unless this requirement is waived by the commission under 2D AAC 25.0~5(h)(2); No diverter system will be utilized during operations on 1J-101 L2. 8. Drilling Fluid Program Requirements of 20 AAC 25A05(c)(8) An app/ication for a Permit to Dri// must be accompanied by each of the fol%wing /terns, except for an item a/ready on fr/e with the commission and identified in the application: (8J a drilling fluid program, including a diagram and description of the drilling fluid system, as required by ZD AAC 2s. D33; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit pp) 8.6 Plastic Viscostiy 15 - 25 lb/100 s fl Yield Point 18 - 28 (cP) HTHP Fluid loss (ml/30 min <4.0 @ 200psi & 150° Oil l Water Ratio 70 / 30 Electrical 650-900 Stabilit 1J-101L2 PERMIT lT Page 4 of 6 Printed: 9-Nov-05 • Ap~n for Permit to Drill, Well 1J-101 L2 Revision No.O Saved: 9-Nov-05 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 Dri/I must be accompanied by each of the following items, except far an item a/ready an file with the commission and identified in the applicatian: (9) for an exploratory or stratigraphic test weU, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 2C1 AAC 25.033(1); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Dri// must be accompanied by each ofthe fo!/owing items, except for an item already on fi/e with the commission and identified in the application: (10) for an expioratory ar stratigraphic test we11, a seismic refraction ar rel7ectian analysis as required by ~©AAC 25, 061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on fr/e with the commission and identified in the application; (11) for a we/1 drilled from an offshore platform, mobi/e bottom-founded structure, jack-up rig, or floating drilling vessel, an anafysis of seabed conditions as required by 20 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 Driil must be accompanied by each of the foflowing items, except far an item already on file with the commission and identified in the application; (12) evidence showing that the requirements of20AAC25.025 {&onding}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 Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Atta hment 3, Well Schematic. Note: Previous operations are covered under the 1J-Application for Permit to Drill. .i'" 1. Run and set Baker WindowMaster whipstock system, at window point of 4,197' MD / 3,459' TVD, the top of the D sand. 2. Mill 6-3/4" window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of D sand lateral at 11,718' MD / 3,639' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 1 J-101 L2 PERMIT IT Page 5 of 6 ,{~ ~ ~ ~ Printed: 9-Nov-05 • Ap~n for Permit to Drill, Well 1J-101 L2 Revision No.0 Saved: 9-Nov-05 8. RIH, until liner hanger is just above window. Orient hanger to window and .land hanger 9. Release hanger running tool. 10. POOH and lay down drill pipe. 11. RU and run a 4 1/2" ESP completion with backup gaslift. 1Z Space out tubing and land tubing in tubinghead, 13. Nipple down BOPE, nipple up tree and test, change over the hole to diesel. 14. Set BPV and RDMO Doyon 141. 15. Rig up wire line unit. Pull BPV. 16. Circulate out well with diesel through the ESP. 17. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 18. Replace gas lift valves with blank dummy valves. 19. 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 app/ication for a Permit to Dri// music be accompanied by each of the fo/lowing items, except far an iterrr already on file with the commission and identified in the application: (14) a genera/ description of how the operator pans to dispose of dri/ling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.05'0 for an annular dispose! operation in the wedl.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on iJ 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 1J 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 7 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-101!_2 PERMIT lT Page 6 of 6 Prinfed: 9-Nov-05 a~ • • ConocaPhillips Alaska ConocoPhiltips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1 J Pad Plan 1J-101 L2 Plan: 1J-101 L2 (wp04) Proposal Report 20 October, 2005 HALLfURTf.~IV p+~~ ~~1~ryrg ~rvi~es ORIGINAL _1 1 ConocoPh~lli~s Alaska L2 - TO W 0 Project: KuparuK ttlver unlt Site: Kuparuk 1J Pad L E G E N D Well: Plan 1J-101 Wellbore: Plan 1J-101 L2 ~ Plan 1J-101, Plan 1J-101 L1, 1J-101 L1 (wp04) Plan: 1J-101 L2 (wp04) $ plan 1J-101, Plan 1J-101, 1J-101 (wp04) VO ~- 1J-101 L2 (wD04) FORMATION TOP DETAILS NbVDPath MOPath Formation 1 1540.00 1540.00 Permafrost 2 1645.00 1645.03 T3 3 1935.001936.83 K75 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 K13 9 3460.00 4207.97 D @ 77° 4197ft MD 3459ft TVD - 1665ft FNL & 1841ft FEL -Sec 35 - T11N - R10 i ~ L2 -BOW , 4209ft MD, 3467ft TVD -Drill 30' Rathole ~ ~ ~ L2 -Build @ 5.50°l100ft to 91.6° Inc - 4239ft MD, 3467ft TVD i ~ ~ T i ~ ~ ,' L2 -Sail @ 91.6` Inc : 4472ft MD, 3486ft TVD i i CASING DETAILS No TVD MD Name Size 1 2199.00 2208.78 10 314" 10-314 2 3459.00 4197.41 7 518" 7-518 3 3641.9011717.67 4112" 4-1 /2 i I~ i i ~ / ~ ~ L2 -Flatten Out @ 4`/100ft to 89.6 Inc : 4753ft MD, 3475ft TVD i 1000 x/500 -- ---...... - ~0` D -----... q0° 2000 --- --°-----•° ........... ..20 i ~ i ~ i ~ ~ ~ _. ~ ~ L2 - BHL. u ' 1718'i paU. 3%~1<'ft 1VD : 56(ift FSL R 1A44f¢ FE~_ ~ '-r- 2 ; ~ 1 N - R'~:1E. ~ , , i 3~ ~ ~ ~' N~ O ~ ..- ...~ i i h~ ~ ~ ° i O ~ i i ...................................................... ....Ip ° ~ O ~o '° o ............................................................ 1 / / / ~ p~ O) N °p ~ o . ~ .~.........4 .................................... ~...................m...................p1-......... 3500 ~ -D @ 77° -- - -- L2 -Continue Geeosteer @ 15' Below Top : 4805ft MD, 3478ft ,~ ,' ~ ~ ,' i ~~ , , ~ ~ i ~ i 1J-101 L2 T1 (wp04) ~ ~ ~ 1 J-101 L2 T3 (wp04) i iJ-101 L2 T2 (wp04) ~ ; , z i i , ~ , ~ , i ~ i ~ , i , i , ~ ~ i , i ~ , ~ ~ 1J-101 L2 TS (wp04) ~ ~ i ~ i ~ ~ , 11J-101 L2 T6 (wp04)il i 1J-101 L2 T4 (wp04) i 1J-101 L2 T7(Tce}(wp04) -1000 -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 fUin) ConotoPhillips AI8SI49 110E 81 360° 1 ._---_-- 1J-101 L2 T4(wp04~ 360`\~ L2 - BHL @ t1718k MD, 3642ft TVD : 566ft FSL & 1844ft FEL • Sec 23 - T11N - Rt E __- -~ -'----- -'-1J-101 L2 T3 (wp04 1 J-101 L2 T2 (wp04 360° c O V7 (V L 'C O Z t O 4 1!2" 1 J-101 L2 T7(Toe)(wp04 ~_ ' . --~-~ 358° - -- - - _- - _ _ 1J-101 L2 T6 (w~ 2° -~(}.- -____-_---------1J-101 L2 T5 (wp04 ~-_-------~------- 1J-00111 T1(wp04 ~2 -Continue Geeosteer @ 15' Below Top : 4805k MD, 3478ft T1/p 360° C~ -Flatten Out @ 4°/100k to 89.6°Inc : 4753ft MD, 3474k T1~~ , IL2_ Sail @91.6° Inc : 4472ft MD, 3486k T1l~ ' ~ , ` L2 - Build Q 5.50°I100ft to 91.6° Inc - 4234ft MD, 3467ft ~ ' ~ , - - - - - _ - - ~ 359' L2 BOW , 4209ft MD, 3467ft TVD - Dri1130' Rathol~ - - - - - - - - - -- - - - - - C----- - - _ __~° _2-TOW@4197ft MD, 3459ft TVD-1665ft FNL-R ?947ft FFL-.Sec 35_T11N`R1~~-_ _-____ .-- --- / i/ 8° / %~ 9p° 0 314" T M agnelic Nodh: 24.33° CASING DETAILS Magnetic Field Strength: 57560.9nT No TVD MD Name Size Dip Angle: 80.76° 1 2199.00 2208.78 10 3/4" 10-3/4 Date: 9127/2005 2 3459.00 4197.41 7 5/8" 7-5/S Model: BGGM2005 67 4112" 17 4-1/2 3 . 3641.90117 I I l I t i -4375 -3750 -3125 -2500 -1875 -1250 4625` ° 0 ° ~ 625 ~ 1250 1875 2500 3125 3750 ~ • ~-' Halliburton Company r~~n-I,.t.~~3up-r`t5au ~~~~~~~~~~~ Planning Report -Geographic ------~ __~ AIaSt« Sp~r~ ~rllling s®rvic~es 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 Well: Plan 1J-101 Survey Calculation Method: Minimum Curvature , Wellbore: Plan 1J-101 L2 Design: 1J-101 L2(wp04) Project Kupan~k 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 +W-S 0.00 ft Northing: 5,946,0$6.15 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 L2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 9!27/2005 24.33 80.76 57,561 Design 1J-101 L2 (wp04) Audit Notes: Version: Phase: PLAN Tie On Depth: 4,197.40 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 0.00 10/20/2005 11:36:08AM Page 2 of 7 ~~ g~ 1 c ~ ~ 0 ~ ~...,.. COMPASS 2003.11 Build 48 • ~t)C'~C)~t'I~P`~'1I ~ ~! p5 ~asiea 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 L2 Design: 1J-101 L2 (wp04) • Halliburton Company HALLIE~>l.lp'TGN Planning Report -Geographic - -----~ ---~---~~ ~-- Sperry Df-illing Services Local Co-ordinate Reference: Well Plan 1J-101 TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) M D 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 +t_/_vy Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft} (°/100ft) (°/100ft) (°/100ft) (°) 4,197.40 77.00 360.00 3,459.00 1,340.22 610.19 0.00 0.00 0.00 0.00 4,209.40 78.91 360.00 3,461.51 1,351.96 610.19 15.90 15.90 0.00 0.00 4,239.40 78.91 360.00 3,467.28 1,381.39 610.19 0.00 0.00 0.00 0.00 4,433.80 89.60 359.95 3,486.71 1,574.54 610.11 5.50 5.50 -0.03 359.73 4,471.89 91.58 359.26 3,486.32 1,612.63 609.85 5.50 5.19 -1.82 -19.33 4,752.51 91.58 359.26 3,478.60 1,893.12 606.21 0.00 0.00 0.00 0.00 4,805.23 89.60 359.99 3,478.06 1,945.83 605.86 4.00 -3.75 1.39 159.64 7,805.23 89.60 359.99 3,499.00 4,945.75 605.34 0.00 0.00 0.00 0.00 7,809.09 89.48 359.99 3,499.03 4,949.61 605.34 3.00 -3.00 -0.07 -178.61 8,805.40 89.48 359.99 3,508.00 5,945.88 605.11 0.00 0.00 0.00 0.00 8,932.06 93.28 359.84 3,504.94 6,072.49 604.93 3.00 3.00 -0.11 -2.16 9,105.79 93.28 359.84 3,495.00 6,245.93 604.45 0.00 0.00 0.00 0.00 9,380.73 85.03 359.99 3,499.04 6,520.60 604.04 3.00 -3.00 0.05 179.01 9,807.75 85.03 359.99 3,536.00 6,946.02 603.94 0.00 0.00 0.00 0.00 9,887.77 87.43 359.95 3,541.25 7,025.86 603.90 3.00 3.00 -0.04 -0.79 10,507.64 87.43 359.95 3,569.00 7,645.11 603.40 0.00 0.00 0.00 0.00 10,638.08 83.92 1.68 3,578.83 7,775.14 605.25 3.00 -2.69 1.32 153.95 11,064.59 83.92 1.68 3,624.00 8,199.07 617.69 0.00 0.00 0.00 0.00 11,287.82 89.36 357.76 3,637.09 8,421.78 616.58 3.00 2.44 -1.75 -35.86 11,717.68 89.36 357.76 3,641.90 8,851.29 599.81 0.00 0.00 0.00 0.00 10/20/2005 19: 36: 09AM oaisin~~ COMPASS 2003.11 Build 48 Cvr~~cra!li~ AiaS~:a • Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kupanik) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-101 Wellbore: Plan 1J-101 L2 Design: 1J-101 L2 (wp04) r~J Halliburton Company H14LLI~U~iTON Planning Report -Geographic ----~ __._. -- -- -~ ~t~~` drilling 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 Planned Survey 1J-101 L2 {wp04) Map Map MD Inclination Azimuth TVD SSTVD +N(-S +E/-W Northing Easting OLSEV Vert Section (ft! ~°) ~°) 1ft) (ft) 1ft) (ft) eft) eft) (°/100ft) (ft) 4,197.40 77.00 360.00 3,459.00 3,350.00 1,340.22 610.19 5,947,430.96 559,353.99 0.00 1,34022 LZ -TOW @ 4197ft MD, 34598 TV D -1665ft FNL & 1841ft FEL -Sec 35 - T11N - 810E - 7 5/8" 4,200.00 77.41 360.00 3,459.58 3,350.58 1,342.76 610.19 5,947,433.50 559,353.97 15.80 1,342.76 4,201.97 77.73 360.00 3,460.00 3,351.00 1,344.68 610.19 5,947,435.42 559,353.96 16.04 1,344.68 D @ 77° 4,209.40 78.91 360.00 3,461.51 3,352.51 1,351.96 610.19 5,947,442.70 559,353.90 15.90 1,351.96 L2 -BOW , 4209ft MD, 3467ft TVD -Drill 30' Rathole 4,239.40 78.91 360.00 3,467.28 3,358.28 1,381.39 610.19 5,947,472.13 559,353.67 0.00 1,381.39 L2 -Build @ 5.50°/100ft to 91.8° In c - 4239ft MD, 3467ft TVD 4,300.00 82.24 359.98 3,477.20 3,368.20 1,441.17 610.19 5,947,531.90 559,353.19 5.50 1,441.17 4,400.00 87.74 359.96 3,485.93 3,376.93 1,540.75 610.14 5,947,631.46 559,352.37 5.50 1,540.75 4,433.80 89.60 359.95 3,486.71 3,377.71 1,574.54 610.11 5,947,665.25 559,352.08 5.50 1,574.54 4,471.89 91.58 359.26 3,486.32 3,377.32 1,612.63 609.85 5,947,703.33 559,351.52 5.50 1,612.63 L2 -Sail @ 91.6° Inc : 4472ft MD, 3486ft TVD 4,500.00 91.58 359.26 3,485.55 3,376.55 1,640.72 609.48 5,947,731.42 559,350.93 0.00 1,640.72 4,600.00 91.58 359.26 3,482.79 3,373.79 1,740.67 608.18 5,947,831.35 559,348.86 0.00 1,740.67 4,700.00 91.58 359.26 3,480.04 3,371.04 1,840.63 606.89 5,947,931.28 559,346.78 0.00 1,840.63 4,752.51 91.58 359.26 3,478.60 3,369.60 1,893.12 606.21 5,947,983.76 559,345.69 0.00 1,893.12 L2 -Flatten Out @ 4°/100ft to 89.6°Inc : 4753ft M D, 34798 TVD 4,800.00 89.80 359.92 3,478.03 3,369.03 1,940.60 605.86 5,948,031.23 559,344.98 4.00 1,940.60 4,805.23 89.60 359.99 3,478.06 3,369.06 1,945.83 605.86 5,948,036.46 559,344.93 4.00 1,945.83 L2 -Continue Geeosteer @ 15' Be low Top : 4805ft MD, 3478ft TVD 4,900.00 89.60 359.99 3,478.72 3,369.72 2,040.59 605.84 5,948,131.21 559,344.17 0.00 2,040.59 5,000.00 89.60 359.99 3,479.42 3,370.42 2,140.59 605.83 5,948,231.20 559,343.38 0.00 2,140.59 5,100.00 89.60 359.99 3,480.11 3,371.11 2,240.59 605.81 5,948,331.18 559,342.58 0.00 2,240.59 5,200.00 89.60 359.99 3,480.81 3,371.81 2,340.59 605.79 5,948,431.17 559,341.78 0.00 2,340.59 5,300.00 89.60 359.99 3,481.51 3,372.51 2,440.58 605.77 5,948,531.15 559,340.98 0.00 2,440.58 5,400.00 89.60 359.99 3,482.21 3,373.21 2,540.58 605.76 5,948,631.14 559,340.19 0.00 2,540.58 5,500.00 89.60 359.99 3,482.91 3,373.91 2,640.58 605.74 5,948,731.12 559,339.39 0.00 2,640.58 5,600.00 89.60 359.99 3,483.60 3,374.60 2,740.58 605.72 5,948,831.11 559,338.59 0.00 2,740.58 5,700.00 89.60 359.99 3,484.30 3,375.30 2,840.57 605.70 5,948,931.09 559,337.79 0.00 2,840.57 5,800.00 89.60 359.99 3,485.00 3,376.00 2,940.57 605.69 5,949,031.08 559,337.00 0.00 2,940.57 5,900.00 89.60 359.99 3,485.70 3,376.70 3,040.57 605.67 5,949,131.06 559,336.20 0.00 3,040.57 6,000.00 89.60 359.99 3,486.40 3,377.40 3,140.57 605.65 5,949,231.04 559,335.40 0.00 3,140.57 6,100.00 89.60 359.99 3,487.10 3,378.10 3,240.56 605.63 5,949,331.03 559,334.60 0.00 3,240.56 6,200.00 89.60 359.99 3,487.79 3,378.79 3,340.56 605.62 5,949,431.01 559,333.80 0.00 3,340.56 6,300.00 89.60 359.99 3,488.49 3,379.49 3,440.56 605.60 5,949,531.00 559,333.01 0.00 3,440.56 6,400.00 89.60 359.99 3,489.19 3,380.19 3,540.56 605.58 5,949,630.98 559,332.21 0.00 3,540.56 6,500.00 89.60 359.99 3,489.89 3,380.89 3,640.55 605.56 5,949,730.97 559,331.41 0.00 3,640.55 6,600.00 89.60 359.99 3,490.59 3,381.59 3,740.55 605.55 5,949,830.95 559,330.61 .0.00 3,740.55 6,700.00 89.60 359.99 3,491.28 3,382.28 3,840.55 605.53 5,949,930.94 559,329.82 0.00 3,840.55 6,800.00 89.60 359.99 3,491.98 3,382.98 3,940.55 605.51 5,950,030.92 559,329.02 0.00 3,940.55 6,900.00 89.60 359.99 3,492.68 3,383.68 4,040.54 605.49 5,950,130.91 559,328.22 0.00 4,040.54 7,000.00 89.60 359.99 3,493.38 3,384.38 4,140.54 605.48 5,950,230.89 559,327.42 0.00 4,140.54 7,100.00 89.60 359.99 3,494.08 3,385.08 4,240.54 605.46 5,950,330.88 559,326.63 0.00 4,240.54 7,200.00 89.60 359.99 3,494.77 3,385.77 4,340.54 605.44 5,950,430.86 559,325.83 0.00 4,340.54 7,300.00 89.60 359.99 3,495.47 3,386.47 4,440.53 605.42 5,950,530.85 559,325.03 0.00 4,440.53 10/20/2005 11:36:09AM Page 4 of 7 COMPASS 2003.118ui1d 48 j ~ ti-- ~~~~~~~~~~~~~ Halliburton Company Pl i R rt hi G MA1.1,.1BUgTGN -- -- ~- -- ann ng epo - eograp c A105k3 $pA~ ~11'll~1rig 5i@WIfC@S 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 Well: Plan 1J-101 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-101 L2 Design: 1J-101 L2 (wp04) Planned Survey 1J-101 L2 (wp04) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°t100ft) (ft) 7,400.00 89.60 359.99 3,496.17 3,387.17 4,540.53 605.41 5,950,630.83 559,324.23 0.00 4,540.53 7,500.00 89.60 359.99 3,496.87 3,387.87 4,640.53 605.39 5,950,730.82 559,323.43 0.00 4,640.53 7,600.00 89.60 359.99 3,497.57 3,388.57 4,740.53 605.37 5,950,830.80 559,322.64 0.00 4,740.53 7,700.00 89.60 359.99 3,498.27 3,389.27 4,840.53 605.35 5,950,930.79 559,321.84 0.00 4,840.53 7,800.00 89.60 359.99 3,498.96 3,389.96 4,940.52 605.34 5,951,030.77 559,321.04 0.00 4,940.52 7,805.23 89.60 359.99 3,499.00 3,390.00 4,945.75 605.34 5,951,036.00 559,321.00 0.00 4,945.75 1J•101 L2 T1 (wp04) 7,809.09 89.48 359.99 3,499.03 3,390.03 4,949.61 605.34 5,951,039.86 559,320.97 3.00 4,949.61 7,900.00 89.48 359.99 3,499.85 3,390.85 5,040.52 605.32 5,951,130.75 559,32024 0.00 5,040.52 8,000.00 89.48 359.99 3,500.75 3,391.75 5,140.51 605.29 5,951,230.74 559,319.44 0.00 5,140.51 8,100.00 89.48 359.99 3,501.65 3,392.65 5,240.51 605.27 5,951,330.72 559,318.63 0.00 5,240.51 8,200.00 89.48 359.99 3,502.55 3,393.55 5,340.51 605.25 5,951,430.70 559,317.83 0.00 5,340.51 8,300.00 89.48 359.99 3,503.45 3,394.45 5,440.50 605.23 5,951,530.69 559,317.03 0.00 5,440.50 8,400.00 89.48 359.99 3,504.35 3,395.35 5,540.50 605.20 5,951,630.67 559,316.23 0.00 5,540.50 8,500.00 89.48 359.99 3,505.25 3,39625 5,640.49 605.18 5,951,730.65 559,315.42 0.00 5,640.49 8,600.00 89.48 359.99 3,506.15 3,397.15 5,740.49 605.16 5,951,830.64 559,314.62 0.00 5,740.49 8,700.00 89.48 359.99 3,507.05 3,398.05 5,840.49 605.14 5,951,930.62 559,313.82 0.00 5,840.49 8,800.00 89.48 359.99 3,507.95 3,398.95 5,940.48 605.11 5,952,030.60 559,313.02 0.00 5,940.48 8,805.40 89.48 359.99 3,508.00 3,399.00 5,945.88 605.11 5,952,036.00 559,312.97 0.00 5,945.88 1J-101 LZ T2 (wp04) 8,900.00 92.32 359.88 3,506.51 3,397.51 6,040.46 605.00 5,952,130.57 559,312.13 3.00 6,040.46 8,932.06 93.28 359.84 3,504.94 3,395.94 6,072.49 604.93 5,952,162.59 559,311.80 3.00 6,072.49 9,000.00 93.28 359.84 3,501.06 3,392.06 6,140.31 604.74 5,952,230.40 559,311.08 0.00 6,140.31 9,100.00 93.28 359.84 3,495.33 3,386.33 6,240.15 604.47 5,952,330.22 559,310.03 0.00 6,240.15 9,105.79 93.28 359.84 3,495.00 3,386.00 6,245.93 604.45 5,952,336.00 559,309.97 0.00 6,245.93 1J-101 L2 T3 (wp04) 9,200.00 90.46 359.89 3,491.93 3,382.93 6,340.08 604.24 5,952,430.14 559,309.02 3.00 6,340.08 9,300.00 87.46 359.94 3,493.75 3,384.75 6,440.05 604.09 5,952,530.10 559,308.10 3.00 6,440.05 9,380.73 85.03 359.99 3,499.04 3,390.04 6,520.60 604.04 5,952,610.64 559,307.42 3.00 6,520.60 9,400.00 85.03 359.99 3,500.71 3,391.71 6,539.80 604.04 5,952,629.83 559,30727 0.00 6,539.80 9,500.00 85.03 359.99 3,509.36 3,400.36 6,639.42 604.02 5,952,729.44 559,306.47 0.00 6,639.42 9,600.00 85.03 359.99 3,518.02 3,409.02 6,739.05 603.99 5,952,829.06 559,305.66 0.00 6,739.05 9,700.00 85.03 359.99 3,526.67 3,417.67 6,838.67 603.97 5,952,928.67 559,304.86 0.00 6,838.67 9,800.00 85.03 359.99 3,535.33 3,426.33 6,938.30 603.95 5,953,028.28 559,304.06 0.00 6,938.30 9,807.75 85.03 359.99 3,536.00 3,427.00 6,946.02 603.94 5,953,036.00 559,304.00 0.00 6,946.02 1J-101 L2 T4 {wp04) 9,887.77 87.43 359.95 3,541.25 3,432.25 7,025.86 603.90 5,953,115.83 559,303.34 3.00 7,025.86 9,900.00 87.43 359.95 3,541.80 3,432.80 7,038.08 603.89 5,953,128.05 559,303.23 0.00 7,038.08 10,000.00 87.43 359.95 3,546.28 3,437.28 7,137.98 603.81 5,953,227.93 559,302.37 0.00 7,137.98 10,100.00 87.43 359.95 3,550.75 3,441.75 7,237.87 603.73 5,953,327.82 559,301.51 0.00 7,237.87 10,200.00 87.43 359.95 3,555.23 3,446.23 7,337.77 603.65 5,953,427.71 559,300.65 0.00 7,337.77 10,300.00 87.43 359.95 3,559.71 3,450.71 7,437.67 603.57 5,953,527.59 559,299.79 0.00 7,437.67 10,400.00 87.43 359.95 3,564.18 3,455.18 7,537.57 603.49 5,953,627.48 559,298.93 0.00 7,537.57 10,500.00 87.43 359.95 3,568.66 3,459.66 7,637.47 603.40 5,953,727.37 559,298.07 0.00 7,637.47 10,507.64 87.43 359.95 3,569.00 3,460.00 7,645.11 603.40 5,953,735.00 559,298.00 0.00 7,645.11 1J-101 L2 T5 (wp04) 10,600.00 84.95 1.17 3,575.14 3,466.14 7,73725 604.30 5,953,827.13 559,298.19 3.00 7,737.25 10,638.08 83.92 1.68 3,578.83 3,469.83 7,775.14 605.25 5,953,865.03 559,298.83 3.00 7,775.14 10/20/200511:36:09AM Page 5 of 7 COMPASS 2003.11 Build 48 a~ r•' • Halliburton Company ~t~ncaF~hlt~ s ~-ra~.~i®tu~arr3r~ Planning Report -Geographic - --- - - - --- Riaska .Sperry ~1i11-rig Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-101 Company: ConocoPhillips Ataska (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: Minimum Curvature Wellbore: Plan 1J-101 L2 Design: 1J-101 L2 (wp04) Planned Survey 1J-101 L2 (wp04) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 10,700.00 83.92 1.68 3,585.39 3,476.39 7,836.68 607.05 5,953,926.58 559,300.16 0.00 7,836.68 10,800.00 83.92 1.68 3,595.98 3,486.98 7,936.08 609.97 5,954,025.98 559,302.30 0.00 7,936.08 10,900.00 83.92 1.68 3,606.57 3,497.57 8,035.47 612.89 5,954,125.39 559,304.44 0.00 8,035.47 11,000.00 83.92 1.68 3,617.16 3,508.16 8,134.87 615.80 5,954,224.79 559,306.58 0.00 8,134.87 11,064.59 83.92 1.68 3,624.00 3,515.00 8,199.07 617.69 5,954,289.00 559,307.96 0.00 8,199.07 1J•101 LZ T6 (wp04) 11,100.00 84.78 1.06 3,627.48 3,518.48 8,234.29 618.53 5,954,324.23 559,308.53 3.00 8,234.29 11,200.00 87.22 359.30 3,634.46 3,525.46 8,334.04 618.83 5,954,423.96 559,308.06 3.00 8,334.04 11,287.82 89.36 357.76 3,637.09 3,528.09 8,421.78 616.58 5,954,511.67 559,305.12 3.00 8,421.78 11,300.00 89.36 357.76 3,637.22 3,528.22 8,433.95 616.11 5,954,523.84 559,304.55 0.00 8,433.95 11,400.00 89.36 357.76 3,638.34 3,529.34 8,533.87 612.21 5,954,623.72 559,299.87 0.00 8,533.87 11,500.00 89.36 357.76 3,639.46 3,530.46 8,633.79 608.30 5,954,723.59 559,295.19 0.00 8,633.79 11,600.00 89.36 357.76 3,640.58 3,531.58 8,733.70 604.40 5,954,823.47 559,290.51 0.00 8,733.70 11,700.00 89.36 357.76 3,641.70 3,532.70 8,833.62 600.50 5,954,923.34 559,285.83 0.00 8,833.62 11,717.68 89.36 357.76 3,641.90 3,532.90 8,851.29 599.81 5,954,941.00 559,285.00 0.00 8,851.29 L2 - BHL @ 11718ft MD, 3642ft TVD : 566ft FSL & 1844ft FE L -Sec 23 - T11 N - R10E - 41/2" - -- Geologic Targets _ -- - Plan 1J-101 L2 TVD Target Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft} (ft) 3,495.00 1J-101 L2 T3 (wp04) 6,245.93 604.45 5,952,336.00 559,309.97 - Point 3,624.00 1J-101 L2 T6 (wp04) 8,199.07 617.69 5,954,289.00 559,307.96 - Point 3,508.00 1J-101 L2 T2 (wp04) 5,945.88 605.11 5,952,036.00 559,312.97 - Point 3,569.00 1J-101 L2 TS (wp04) 7,645.11 603.40 5,953,735.00 559,298.00 - Pant 3,536.00 1J-101 L2 T4 (wp04} 6,946.02 603.94 5,953,036.00 559,304.00 - Point 3,499.00 1J-101 L2 T1 (wp04) 4,945.75 605.34 5,951,036.00 559,321.00 - Point 3,641.90 1J-101 L2 T7(Toe)(wp04) 8,851.29 599.81 5,954,941.00 559,285.00 - Point 10/20/2005 11:36:09AM Page 6 of 7 COMPASS 2003.11 Build 48 4~ 't'"~ 4 `'~`` e ~ ~ '~t E y{ ~ t res+ } ~k ~I A .. .. • ~k7C1+t,~~`11~~1 ~5 Alaska 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 L2 Design: 1J-101 L2 (wp04) LJ Halliburton Company Mp~~~~~p-r~N Planning Report -Geographic ___._.__.__~: _ _ ._.___ Sperry drilling 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 Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter 1ft) eft) (~~) ~") 2,208.78 2,199.00 10-3/4 13-1/2 4,197.41 3,459.00 7-518 9-7/8 11,717.67 3,641.90 4-1/2 6-3l4 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W {fty (°) (o) (ft) (ft) (ftI Name 1,540.00 0.00 0.00 1,540.00 0.00 0.00 Permafrost 1,645.03 2.38 40.50 1,645.00 1.50 1.28 T3 1,936.83 9.67 40.50 1,935.00 24.77 21.15 K15 2,207.73 17.73 40.50 2,198.00 73.41 62.70 T3+550 3,058.02 46.10 31.13 2,926.00 408.44 322.31 Ugnu C 3,476.47 55.43 27.37 3,177.00 701.74 482.36 Ugnu B 3,619.89 59.67 20.51 3,254.00 812.30 531.25 Ugnu A 3,710.91 62.53 16.47 3,298.00 887.86 556.47 K13 4,201.97 77.73 360.00 3,460.00 1,344.68 610.19 D @ 77° 10/20/2005 11:36:09AM Page 7 of 7 COMPASS 2003.11 Build 48 .~} • ConocoPhillips aas~a ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-101 L2 Anticollision Summary 20 October, 2005 ~~ HLLII~RTt'~N terry ~ri~~~~ +~~+~~ ~, ~~; ~~~~~ Sl'IiPp1' PROGRA\I NAD 27 ASP Zone 4: WELL DETAILS: Plan 1J-tOt ConocoPhillips Alaska (Kuparuk) -- - - ----- -- i 1 00 1' lid t d l' V 00 ANTI-COLLISION SETTINGS Ground Level: 81.00 Drilling & Wells on: e : es ers Ua1e: 200SIOAJTl 0: : a a Interpolation Method: MD Interval: 50Stations +N/-S +E/-W Northing Easting Latittude Longitude Slot ° ' West Sak Uepth prom Uepih To Sun er~Plan Tool Depth Range From: 4250.4 To 11653.43 3t 30.OOSW 0.00 0.00 5946088.15 558754.33 70°15'47.898N 149 Calculation Method: Minimum Curvature 28,110 800.00 CD-GIRO-SS ' ' ' Maximum Rangea239.50412311175 Ertor System: ISCWSA .4ZSC U+IFR-AIC-C 800.00 J197.J0 ]f11 Reference: Plan: iJ-101 L2 (wp04) Scan Method: Trav. Cylinder North J197A0 11717.68 IJ-101 L2 (wpOJ) ]iRD+IFR-AK•CAZ.SC Error Surface: Elliptical Conic Warning Method: Rules Based 3 330 2 270 90 300 1 5 1 1 240 20 25 210 150 60 120 180 Travelling Cylinder Azimuth (TFC}+AZI) [°] vs Cenh~e to Cen[re Separation (15 ldin SECTION DETAILS From Colour To MD 180 0 4000 4000 5000 sooo sooo Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation X250 ftlitl] Travellin g 6000 7000 7000 8000 8000 9000 9000 10000 10000 11000 11000 12000 12000 0 REFERENCE INFORMATION Cacrdinate (N/E) Reference: Weil Plan 1J-101, True North Vertical (ND) Reference: Plan RKB @ 109.OOft (Doyen ibt (81 +28)) Sedian (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: Plan RKB Ld 109.OOft (Doyon 141 (81 + 28)) Calculation Method: Minimum Curvature Sec MD Inc Azi ND +N/-S +E/-W DLeg TFace VSec Target 1 4197.40 77.00 360.00 3459.00 1340.22 610.19 0.00 0.00 1340.22 2 4209.40 78.91 360.00 3461.51 1351.96 610.19 15.90 0.00 1351.96 3 4239.40 78.91 360.00 3467.28 1381.39 610.19 0.00 0.01) 1381.39 4 4433.80 89.60 359.95 3486.71 1574.54 610.11 5.50 359.73 1574.54 5 4471.89 91.58 359.26 3486.32 1612.63 609.85 5.50 -19.33 1612.63 6 4752.51 91.58 359.26 3476.60 1893.12 606.21 0.00 0.00 1893.12 7 4805.23 89.60 359.99 3478.06 1945.83 605.86 4.00 159.64 1945.83 8 7805.23 89.60 359.99 3499.00 4945.75 605.34 0.00 0.00 4945.75 1J-101 L2 T1 (wp04) 9 7809.09 89.48 359.99 3499.03 4949.61 605.34 3.00.176.61 4949.61 10 6605.40 89.48 359.99 3508.00 5945.88 605.11 0.00 0.00 5945.88 1J-101 L2 T2 (wp04) 118932.06 93.28 359.64 3504.94 6072.49 604.93 3.00 -2.16 6072.49 129105.79 93.28 359.84 3495.00 6245.93 604.45 0.00 0.00 6245.93 1J-101 LZ T3 (wp04) 139380.73 85.03 359.99 3499.04 6520.60 604.04 3.00 179.01 6520.60 149807.75 85.03 359.99 3536.00 6946.02 603.94 0.00 0.00 6946.02 1J-101 L2 T4 (wp04) 159887.77 87.43 359.95 3541.25 7025.66 603.90 3.00 -0.79 7025.66 190507.64 87.43 359.95 3569.00 7645.11 603.40 0.00 0.00 7645.11 1J-101 L2 TS(wp04) 1T 0638.08 83.92 1.68 3578.83 7775.14 605.25 3.00 153.95 7775.14 191064.59 63.92 1.68 3624.00 8199.07 617.69 0.00 0.00 8199.07 1J-101 L2 T6 (wp04) 191287.82 89.36 357.76 3637.09 8421.78 616.58 3.00 -35.86 8421.78 2tl 1717.66 89.36 357.76 3641.90 8851.29 599.81 0.00 0.00 8851.29 1J-101 L2 T7(Toe)(wp0 • / Halliburton Company ~~~~~,~~~~ Anticollision Report Ai~~l 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 L2 Reference Design: 1J-101 L2 (wp04) Reference 1J-101 L2 (wp04) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 50.OOft Error Model: Depth Range: 4,250.40 to 11,653.43ft Scan Method: Results Limited by: Maximum center-center distance of 1,239.50ft Error Surface: Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 10/20/2005 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 4,197.401J-101(wp04)(PIan1J-101) MWD+IFR-AK-CAZ-SC MWD+IFR AKCAZSCC 4,197.40 11,717.68 1J-101 L2 (wp04) (Plan 1J-101 L2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: • MALLIBURTON` Sperry Drilling Seerr3~c.es Well Plan 1 J-101 Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) Plan RKB @ 109.OOft (Doyon 141 (81 + 28)) Tnie Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datwn ISCWSA Trav. Cylinder North Elliptical Conic Summary Site Name Offset Well - Wellbore -Design Kuparuk 1 D Pad 1 D-42 - 1 D-42 - 1 D-42 1D-42- 1D-42L1 -1D-42L1 1D-42- 1D-42L1PB1 -1D-42L1P61 Kuparuk 1J Pad 1J-03- 1J-03- 1J-03 1J-09- 1J-09- 1J-09 Plan 1J-115 (L9) -Plan 1J-L9 Lat A -Plan 1J-L9 La' Plan 1J-12 -Plan 1J-12 (K2 Prelim) - 1J-12 (K2 Pre Plan 1J-127 {L8) -Plan 1J-L8 LatA -Plan 1J-L8 Lat Plan 1J-164 - 1J-164 -1J-164 (wp07) Plan 1J-164 - 1J-164 L1 - 1J-164 L1 (wp07) Plan 1J-164 - 1J-164 L2 - 1J-164 L2 (wp07) Reference Offset Centre to Measured Measured Centre Depth Depth Distance (ft) (ft) (ft) Out of range Out of range Out of range 4,268.91 4,499.98 1,199.49 10, 599.96 10, 599.96 1, 235.38 11, 561.19 11, 485.6 0 1, 232.12 11, 590.22 11, 507.42 1, 233.10 Nato Allowable Distance Deviation Warning (ft) from Plan (ft) Out of range Out of range Out of range 97.68 1,101.81 Pass -Major Risk Out of range 279.53 955.85 Pass -Major Risk 339.41 892.71 Pass -Major Risk 343.06 890.04 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 10/20/2005 11:49;37AM Page 2 of 2 COMPASS 2003.11 Build 48 [ Yt~11 1J-101L~rillin (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 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 1J-101L2 Drilling Hazards Summary 11/9/2005 12:33 PM *Vetco Gray 11" x 4-1/2" Hanger with 4.909" MCA top connection Tubing String C-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 Ct7-t"t~3CCa~l[Iip~ West Sak 7-5/8" Producer 1J-101 Tri-Lateral Completion Bott of Motor Cen ra C tralift 418 HP KMHFE D-sand Window R 2610 / 98 w ©~~ ) at4197'MD, 3459' TVD !. _ / ~, ,,,:`?'""'"~ 'D' Sand Lateral 41/2" 12.6# L-80 Slotted Liner Every Joint 3 1/2" Bent Joint ~ ~ 3.1/2" Guide Shoe ~`""'"~~( ~ 4-1 /2" Liner Shoe, 4-1/2" X 7-S18" Model'B' HOOK Hancer 5.112" X /8" ZXP ~ Liner Top Pa er with Hold Dow Lateral Entrv Module (LEMI , Assembly `'..----- 5.1/2" X 7.5/8" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID - Tubing Swivel, 4-112" - Orienting Profile Automatic Alignment of LEM - Positive Latching Collet Indicates 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 Sealbare Receptacle 4.75" ID 4.112" X 7.518" Model'B' HOOK Hancer Seal Borr 3.68"ID 4-112" 12.fi# Profile BO IB7M rvD B-sand Window 'g' Sand Lateral at 4540' MD, 3533' TVD 4-1/2" 12.6# L$0 Slotted p~~~.^ ~iaR sees Lateral Entry Module (LEMI With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool Siring Installed Installed (3.00" Lateral Drift) (2.50" ID Mainbore Drift) 'GS' Profile for Coil Connector f RunninglRetrieving ~ (1.00' Length) ~ Snap In/Snap Out I r8ack Pressure Valve ,{~ d Positive Locatingti (1.60' Length) ~ "`'~~~". Collet i Lateral IsolaBOn ~~ / Flow-7hre Swivel i ~~ Seals i i ~',. (1.25' Length) / Lateral Diverter i ~ ~' I ';~/ Hydraulic ~ Ramp [ ', I Disconnect Isolation/Mainbore ~~ (1.50'Length) \ ~ Diverter Sleeve i _,el;., -: ~/ GS Spear y • (7.50'Length) Lateral Isolation ~~ Seals i E 6.85 ft Approx. OAL' ~ ,~i 'Jan may be required in highly deviated 18.5' Diverter Length 18.5' Sleeve Length ' '. or deep applications (8' approx length). Liner Every Joint ~ 3-112" Bent Joint ~- ..... ........-¢.,t ,vim 3-112" Guide Shoe ~~ 1 I i ,w~a cs 4.1/2" Liner Shoe, 12.6#, L-80 IBTM ice"` Set @ 11653' MD, 3696' TVD 3.562" DB Nipple 5.112" X 7-SIB" ZXP ` \,,\o Liner Top Packer , ~~`-: Seal Assembly with Hold Downs / 4.75" Seal OD 3.875" ID 5.1/2" X 7.518" Liner Hanger /Packer Assembly at Flex Lock +/-4650' MD Liner Hanger Casing ~'- Sealbare /~'^~-.- Receptacle, ,{li`'~,-„_, " 4.75" ID 'A' Sand Undulating Lateral Diverter and Sleeve Length:+/-18.5' 4-112" 12.6# L-80 Slotted Liner EVery Joint 4.1/2"Eccentric 1 Guide Shoe ~ / ~""'f~II_} ~ " 4-1/2" Casing Shoe, 12.6#, L-80 IBTM /!w!~••. I--;.: ~ Set @ 11516' MD, 3856 TVD 7-5/8"Casing Shoe, Set at @ © Baker Hughes 2005. This document may not be reproduc¢d or distdbuted, In whole or In pert, In any (orm or 549D' M D, 3695' TVD, 84 deg inc owa nn.: by any means electronle or meehenleal, Including photocopying, reeortling, or by any information storage 2005 West Sak 7-518" Trl-lateral Completion -Producer and retrieval system now known or hereaft¢r invented, without wnlten permission from Baker Hughes Ina eats. November 9, 2005 Dnwn ay: RaNeion N".: Marc D. Kuck 0 Equipment Slaecifications 4-1 /2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drlff, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, w/ coil diverter: 3.00" OD of Diverter and Sleeve: +/- 3.89" • • `~ f` ~ ~~~-132) T { y ~y /~ag{<a • ~ Magnetic North: 24.32° Magnetic Field SVength: 57561.1 nT Dip Angle: 80.76° Date: 10/5/2005 Model: BGGM2005 1J-101 Heel 1/4 (wp04)I / \~~ % 8125 ~ 1 J-164 L2 (wp0~ ' 7500 1J-164 (wp07) ~- - -- 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 1= O Z r 0 I 3125 1 _625 Closest Well In Pool 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'Mb \ . _ _ _ 1J-101 L2 IWP~ ------------ ------- 1J_101L1(wp04) ---- --- ---- 1J-101(wp04) .60° ~/ 1360° 360° 360° 0° ~ ~J-101 L2 1/4 Mile radius @ Heel ---_ ----- 360° _ .. _. -- - ~`` ~SP-15 -4375 -3750 -3125 -2500 -1875 -1250~~ ~ ~„ ~ ~ ~ ~ ~6~5„ 1250 1875 2500 3125 3750 4375 COt"IOCOPI'~1~~1~35 Alaska Y!-~.. '~ I .0 ~`~-- ~ o ~ ~o ~ ~ 1 0 '~ ~, WSP-15, WSP-15, WSP-15 V1 I ~OO ,~ ~~~ ~~~, ~ ~-- 1 /4 Mile Kad~us - 1 J-1 U1 (wpU4) 3-D view portraying 3 closest wells in poal. Plan 1J-164, 1J-164 L1, 1J-164 L1 (wp07) VO Plan 1J-164, 1J-164 L2, 1J-164 L2 (wp07) VO ~_...--- ~,-_~' _ _.~-- i _ _ ~ , Plan 1J-164, 1J-164, 1J-164 (wp07) VO ~ - ~ ~ \ ~ i ~~ ~ ~ ~ ~ ~ ~ ~. L -,_ /" _`-` " /~ ______________1D-132, 1D-132,1D-132 V2 __, - ~ _/ ~ _ '~/ '"" ~_~''~~~ 1J-101 (wp04) ~ >~~ / Q~~ ~'"~ r Plan 1J-101, Plan 1J-101 L2, 1J-101 L2 (wp04) VO / SO ~---~~, -..--° ~0 O o Plan 1J-101, Plan 1J-101 L1, 1J-101 L1 (wp04) VO ~~"'~ ~ Q~ O .ter 9 ~ .~ - ~ s ~~ 0~0 O .~ --~ DO ,,/~ ~ J OO ~' ~. _ -. ~ O ~O 1 ~- 0 ~ • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME K~`'e ~"'~ ~~~ ~ PTD# 2 ~' ~ ~~ 1~~:~. ~, CHECK WHAT I. ADD-ONS "CLUE" APPLIES ~ (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well ~~~~ /'T ~~ ~ / Permit No~'5=15'~-API No. ~'.^~`"~^~'" 1~ (If API number I Production should continue to be reported as 'last two (Z) digits I a function of .the original API number stated 4 are between 60-69) {above. PILOT HOLE ~ In accordance with ZO AAC ZSA05(f), all (ply I records, data and logs acquired for the pilot 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). SPACING i The permit is approved subject to full EXCEPTION j compliance with ZO AAC 25.055. Approval to ~~ perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company _Name) assumes I the liability of any protest to the spacing j exception that may occur. DRY DITCH ~ All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' j sample intervals from below the permafrost ' or from where samples are first caught and 10' sample intervals through target zones. UC} Rev: 04/01/05 C\jody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 - Well Name: KUPARUK RIV U WSAK 1J-101 L2 Program DEV Well bore seg ~~ PTD#:2051840 Company CONOCOPHILLIPS ALASKA INC Initial ClassRype DEV! PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Pe(mit_fee attached- _ _ - - _ - - NA- West Sak D Sand multilateral well segment; fee-waived per 20 AAC 25.005(e)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 Lease number appropriatee_ - , Yes - _ _ _ - -Multilateral: top- productive interval in ADL 025661 and TD in ADL 025650., - 3 Uni_quewell_nameandnumber-..---__-____________ ____________ ____Yes__-__- -__---,______- ------------------------------------------------------- 4 Well located in a_defnedpool_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - _ _ Yes - - _ _ _ - - KRU West_Sak Oil Pool, governed-by Conservation-OMer-No, 4066- _ - _ , - - _ _ _ _ _ _ - - - - _ _ _ _ _ _ _ _ 5 Well located proper distance-from drilling unit_boundary_ _ . . _ - -Yes Well is more_than_ 500 feet from an external property line. _ - - ... _ _ - - 6 Well located properdistance_f[o_motherwells__________________________ _..Yes_----_ _No[estnctionsas-to well spacing in CO-4.066.----____--_--_---,__-_-.-_-___----.----__ I 7 Sufficient acreage available in.drilling unit- - _ - - - Yes - - _ _ . tJo 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 feet to-an external-property line.-_____-__-________.._-_--__._----__--_--__ 9 Operator only affected party - - Yes - - - - - - - - 10 Operator has_appropriate_bondinforce- ----------- -- ----------- ---Yes-- --- ----- -- --- -- -- ---------------------------- --- --- --- -..._ 11 Pe[mit_canbeissuedwithoutconservationorder-__-_ _-__---_______- -_--Yes___._ _____________________________________________________________________ Appr Date 12 Permit_canbeisSuedwithoutadministrative_approval_____________________ ____Yes--____ ____.._-.-____-__--__.__._--__---__--_ SFD 11115l2D05' 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by-InjgctionOrder#(ps~tlp#in_comments}-(For- NA_______ _______________ ______________________________________-___._----_--_ 15 All wells_within 114_mil_e area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ __ NA_ _ _ _ _ _ _ _ _ _ . - _ --------------------------------------------------------------- 16 Pre-produced injector;dur_ationofpre-production less than_3months-(Forseruicewello nly)-.NA_______ _ _____________--_-._.-__-______--____________---._____--__-____-- 17 ACMP-FindjngofConsistency-hasbee_nissued_for_thisproject________________ _____N_A-_---__ - ______-__--_-.__---_________-__--___-__-___--__- _________-_ Engineering 18 Conductor string_provided _ - - _ _ - - - - - - NA_ - _ _ - - Gon_ductorsetin motherbore,-1J-101 {295-182)._ - _ _ -- - 19 Surface casing-protects all known U$DWs_-_____.__-_------------ ----NA___.-- -Allaquifers exempted, 40CFR.147.102_(b)(3)._________-__--_-____ __..-_--__--_--_ 20 CMT-u_oladeguate-tocircul_ate-on conductor_&surf_csg____________________ ____ NA____--- -Surface casing setin_motherbore._-__----_____-_--_________-.--_ 21 CMT_u_oladeguate_totle-in long string t_o surfcsg- - - - - - - - - - - - - NA_ - - - - - - Production_casin set in-motherbore. 9- -- 22 _C_MT-will coverall knownproductive horizon_s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No- - - _ _ _ _ _ Slotted liner completion planned.- _ _ _ _ _ .. - - - - _ - 23 Casing desyns adequate for C, T, B &-permafrost- - - - - _ - _ - . _ - NA- - _ _ - - Motherbore tubnlars meetdesign requirements.- NA for slotted liner.- _ _ - - - 24 Adequate iankage_or reserve pit _ . - - - - - _ - - - - _ - .Yes Rig is-equipped with steel-pits. No reserve-pitplanned. All waste to approved annulus or disposal wells. - - - - - 25 Ifa_re-drill,has-a-1.0-403forabandonment beenapp_roved------------------ ----NA___--- .-.----_______-.-,--__--____-_--_--_________--_--_- __---,--__-___ _ 26 Adequate wellbore separationproposed- - - - - - - --- - - - - - - - ----- - - - - - - - - - - -Yes - - _ . - - _ Proximity analysis performed, Traveling cylinder path calculated, B sand branch is_~70' Nd_ below, - .... - _ _ _ 27 Ifdiverterrequired,doesitmeetregulations___________________--__._- ____ NA___--- _BOPStack_willalready_beinplaee,_--_-__---__________..--._- __-...--_.-_--_ Appr Date 28 Drilling fluid-program schematic & equip lisiadequate_ _ _ Yes - _ _ .. - -Maximum expected formatiort prQSSUre 8,7_ EMW._ MW palnned 8.6 ±-ppg in West Sak, _ - TEM 11l1812005~ 29 BOPES,dotheymeetreulation.-- 9 -- Yes______ ___________________________________________________________-__._-.-- (~;, ~,{~ 30 BOPE-press rating appropriate; test to_(put prig in comments)- - - - - _ - - - Yes _ . _ .. . MASP calculated at 1238 psi. 3000-psi_BOP testproposed._ - _ . - - - - - ~ 11/,"_~ 31 Choke-manifold complieswlAPI-RP-53(May84}------------------------ ----Yes_____. -..._..--___ 32 Work willoccur-withoutoperationshutdown_-_------------ ------- -- ----Yes___ _-___-.---__-__- - - - - 33 Is presence of H2S gas probable. _ - _ _ - - - _ -Yes Minor-(<10-ppm} H2S reported in nearby wells, Mus should_preclude H2S._ Rig has sensors and alarms..... - _ 34 Mechanical condition of wells withinAORyerified[For_servicewellonlyj__________ _____N_A___-_-_ -------______-----__---_-__-_-_-._ Geology 35 Permit-can be issued 1wlo hydrogen_sulfide measrares Yes Nearby well bores in pool,- 1 D-134 &-1 t)-131, measured 510 ppm H2S in 812004- - - - - - - - - - - - - - - - - - - - - 36 Data-presented on potential overpressure zones - - - - - - - - - - - --- - - - - Yes _ None expected.- Estimated reservoir pressure is 8.7 ppg EMW; will be drilled with_~8,6_ppg mineral oil-based- _ - _ Appr Date i37 Seismic analysisofshallowgas-zones_______________________-_-._- .___ NA____-.- -mud.---__-_____ - - SFD 1111512005 '38 Seabed condition survey-(ifoff_-shore}______________________________ ____ NA----. 39 Contact namelphonefor weekly progress_reports (exploratory only]- - _ - - - - NA- - _ - Geologic Engineering Public Commissioner: Date; Commissioner: Date Com ne Date C~.~~-~- l~~z~ ~ ~~ z~ d • • 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 Tending 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 $ Wed Mar 15 16:27:12 2006 Reel Header Service name .............LISTPE Date .....................06/03/15 Origin ...................ST5 Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/03/15 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF • ~13~~~ Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-101 L2 API NUMBER: 500292328661 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 15-MAR-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: MW0004081383 MW0004081383 MW0004081383 LOGGING ENGINEER: T. CALVIN P. ORTH P. ORTH OPERATOR WITNESS: M. THORTON M. THORTON M. THORTON MWD RUN 10 MWD RUN 11 JOB NUMBER: MW0004081383 MW0004081383 LOGGING ENGINEER: T. CALVIN T. CALVIN OPERATOR WITNESS: M. THORTON M. THORTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2274 FEL: 2453 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS ~ s - r~~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT S~ (IN) 9.875 6.750 SIZE (IN) DEPTH (FT) 10.750 2209.0 7.875 5391.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS PLACED AT 4206'MD/3453'TVD, WITHIN THE RUN 4 INTERVAL OF 1J-101. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-4,11 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 INCLUDED RECORDED- ONLY ACOUSTIC CALIPER (ACAL) THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING RUN 10 - ONLY SROP DATA ARE PRESENTED FOR THIS RUN. MWD RUN 11 ALSO INCLUDED AT-BIT INCLINATION (ABI) AND GEO-PILOT ROTARY STEERABLE BHA (GP). 6. 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. 7. MWD RUNS 1-4,10,11 REPRESENT WELL 1J-101 L2 WITH API#:50-029-23286-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11711'MD/3656'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.......06/03/15 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; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GALA 2150.0 GR 2163.5 FET 2185.0 RPS 2185.0 RPM 2185.0 RPD 2185.0 RPX 2185.0 ROP 2209.5 all bit runs merged. STOP DEPTH 3632.0 11653.5 11660.5 11660.5 11660.5 11660.5 11660.5 11711.0 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 2 2150.0 3 3714.0 4 4179.0 10 4206.5 11 4248.0 REMARKS: MERGED MAIN PASS. MERGE BASE 3714.0 4179.0 4206.0 4248.0 11711.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 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 11711 6930.5 19123 2150 11711 CALA MWD INCH 8.28 13.56 10.1851 2878 2150 3632 RPD MWD OHMM 4.02 2000 64.7502 18952 2185 11660.5 RPM MWD OHMM 3.4~ 2000 RPS MWD OHMM 3.22 2000 RPX MWD OHMM 2.86 2000 FET MWD HOUR 0.18 460.61 GR MWD API 25.28 117.8 ROP MWD FT/H 1.08 486.36 First Reading For Entire File..........2150 Last Reading For Entire File...........11711 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/15 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.......06/03/15 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 BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY ~ 58.1597 18952 2185 11660.5 55.4251 18952 2185 11660.5 57.3029 18952 2185 11660.5 1.55867 18952 2185 11660.5 64.6283 18981 2163.5 11653.5 189.892 19004 2209.5 11711 for each bit run in separate files. VENDOR TOOL CODE START DEPTH CALA 2150.0 GR 2163.5 FET 2185.0 RPX 2185.0 RPS 2185.0 RPM 2185.0 RPD 2185.0 ROP 2209.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 3632.0 3667.5 3658.5 3658.5 3658.5 3658.5 3658.5 3714.0 10-DEC-05 Incite 66.37 Memory 3714.0 2209.0 3714.0 16.4 62.0 ~ TOOL STRING (TOP TO BOTTO VENDOR TOOL CODE TOOL TYPE TOOL NUMB ER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 121079 ACAL Acoustic Caliper 143792 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2209.0 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) 5.0 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: 3.400 70.0 MUD CAKE AT MT: 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 DEPT FT 4 1 68 0 1 CALA 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 CALA 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 GR MWD020 API 25.28 109.68 61.8889 3009 2163.5 ROP MWD020 FT/H 15.64 486.36 162.867 3010 2209.5 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.......06/03/15 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.......06/03/15 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 RPM 3659.0 4124.0 RPD 3659.0 4124.0 RPX 3659.0 4124.0 FET 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 3658.5 3667.5 3714 ~ • $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2209.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 55.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 150 FLUID LOSS (C3) 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.900 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.060 101.2 MUD FILTRATE AT MT: 3.400 70.0 MUD CAKE AT MT: 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 DEPT FT 4 l 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.......06/03/15 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.......06/03/15 Maximum Physical Record..65535 File Type ................LO 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 RPX 4124.5 4206.0 FET 4124.5 4206.0 RPS 4124.5 4206.0 RPM 4124.5 4206.0 RPD 4124.5 4206.0 GR 4132.5 4206.0 ROP 4179.5 4206.0 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) 4206.0 TOP LOG INTERVAL (FT) 4179.0 BOTTOM LOG INTERVAL (FT) 4206.0 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): 9.875 DRILLER'S CASING DEPTH (FT) 2209.0 BOREHOLE CONDITIONS • MUD TYPE: Other MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 57.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 150 FLUID LOSS (C3) 4.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.900 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.830 114.8 MUD FILTRATE AT MT: 3.400 70.0 MUD CAKE AT MT: 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 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 4206 4165.25 164 4124.5 4206 RPD MWD040 OHMM 10.01 13.46 11.2382 164 4124.5 4206 RPM MWD040 OHMM 8.96 12.34 10.3222 164 4124.5 4206 RPS MWD040 OHMM 8.29 11.82 9.72024 164 4124.5 4206 RPX MWD040 OHMM 7.47 11.13 8.9675 164 4124.5 4206 FET MWD040 HOUR 0.63 12.06 8.44073 164 4124.5 4206 GR MWD040 API 83.73 105.79 95.2329 148 4132.5 4206 ROP MWD040 FT/H 10.98 79.55 47.848 54 4179.5 4206 First Reading For Entire File..........4124.5 Last Reading For Entire File...........4206 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/15 Maximum Physical Record.~535 • File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/15 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4206.5 4248.0 LOG HEADER DATA DATE LOGGED: 30-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4248.0 TOP LOG INTERVAL (FT) 4206.0 BOTTOM LOG INTERVAL (FT) 4248.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2209.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S): 66.0 MUD PH: .0 MUD CHLORIDES (PPM): 56000 FLUID LOSS (C3) 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 79.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 lr~J u First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4206.5 4248 4227.25 84 4206.5 4248 ROP MWD100 FT/H 1.21 18.22 8.7569 84 4206.5 4248 First Reading For Entire File..........4206.5 Last Reading For Entire File...........4248 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/15 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER; 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH . • RPS 4206 11660.5 FET 4206.5 11660.5 RPD 4206.5 11660.5 RPM 4206.5 11660.5 GR 4206.5 11653.5 RPX 4206.5 11660.5 ROP 4248.5 11711.0 LOG HEADER DATA DATE LOGGED: 03-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11711.0 TOP LOG INTERVAL (FT) 4248.0 BOTTOM LOG INTERVAL (FT) 11711.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.4 MAXIMUM ANGLE: 94.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 59475 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2209.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LBJG) 8.80 MUD VISCOSITY (S) 71.0 MUD PH: .0 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 123.8 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 DEPT FT 4 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MWD110 OHMM 4 1 68 16 5 FET MWD110 HOUR 4 1 68 20 6 GR MWD110 API 4 1 68 24 7 ROP MWD110 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4206.5 11711 7958.75 15010 4206.5 11711 RPD MWD110 OHMM 7.78 2000 74.8017 14909 4206.5 11660.5 RPM MWD110 OHMM 8.85 2000 70.2045 14909 4206.5 11660.5 RPS MWD110 OHMM 8.69 2000 67.2084 14909 4206.5 11660.5 RPX MWD110 OHMM 7.91 2000 69.7846 14909 4206.5 11660.5 FET MWD110 HOUR 0.18 4 60.61 1.4158 14909 4206.5 11660.5 GR MWD110 API 41.48 117.8 63.8868 14895 4206.5 11653.5 ROP MWD110 FT/H 1.08 3 12.49 203.113 14926 4248.5 11711 First Reading For Entire File..........4206.5 Last Reading For Entire File...........11711 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/03/15 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/03/15 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Scientific Technical Services Scientific Technical Services Physical EOF • • End Of LIS File