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Home My WebLink About206-017• 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. ~Q ~ - ~ 1 Well History File Identifier Organizing (done> ^ Two-sided III II'lII II III II III ^ Rescan Needed III IIIIII II II III III RE AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ~iskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~., (~~ /s/ Project Proofing III IIIIIIIIII) IIIII BY: Maria Date: ~ $ /s/ Scanning Preparation ~_ x 30 = ~ + _~ =TOTAL PAGES_~ (Count does not include cover sheet) BY: Maria Date: D /s/ Production Scanning III IIIIIIIIIII IIIII Stage 1 Page Count from Scanned File: (!/ ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: M a, ~ V /s/ 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. III II ~I II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III IIlI III 10!6/2005 Well History File Cover Page.doc t x~ ~: ~ ~ ~~ ` -;~. .~ ~ ' ~ ~ ., ,w;. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Nlicrofilm_Marker.doc 0~ ' - d DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060170 Well Name/No. KUPARUK RIV U WSAK 1J-152L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23298-60-00 MD 13408 TVD 3424 Completion Date 4!22/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surv Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, CBL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 5720 13408 Open 6/27/2006 1 '~k~D C Lis 13991(,Jnduction/Resistivity 0 0 Open 7/19/2006 LIS GR, ROP +{D C A 13991 ~d ti /R i i i uc on sc es st v ty 0 0 Open 7/19/2006 TEXT GR, ROP pt 13991 LI S Verification 0 0 Open 7/19/2006 , / F,0 C Lis 15039 induction/Resistivity 2741 13408 Open 4/17/2007 LIS Veri, GR, FET, ROP w/Graphics CGM, EMF, i PDF Well Cores/Samples Information: Name Interval Start Stop Sample Set Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ICJ Chips Received? ~.~ Analysis ~`tid'~ Received? _ _ __ _ ___ Comments: Daily History Received? l: ~ N Formation Tops ~ N ___- _ _ _ --- - - -. --- _ - - -- -- - Compliance Reviewed By: _ _ _ _. __ _ __ Date __ ~ ~EC~iv~a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~g ~ ~ ~.dQ$ REPORT OF SUNDRY WELL OPERATION ~~ ~~~~., Commi~~~arR 1. Operations Pertormed: Abandon ^ Repair Well ^~ '" Plug Perforations ^ Stimulate ^ Other AfIC~88 Alter Casing ^ Pull Tubing Q ~ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Welt ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^~ Exploratory ^ 206-017 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23298-60 ' 7. KB Elevation (ft}: 9. Well Name and Number: RKB 28', 108' AMSL 1 J-152L1 0 8. Property Designation: - 10. Field/Pool(s): ADL 25661 ~& 25662 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13408' ~ feet true vertical 3424' feet Plugs (measured) Effective Depth measured 13372' feet Junk (measured) true vertical 3424' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2664' 10-3/4" 2773' 2198' PRODUCTION 6414' 7-5/8" 6523' 3638' LINER 7632' 4.5" 13374' 3424' Perforation depth: Measured depth: 5949'-6763', 7139'-8323', 8529'-10034', 10202'-1041 8', 10546'-13340' true vertical depth: 3515'-3490', 3512'-3476', 3481'-3456'. 3456'-3458', 3459'-3425' Tubing (size, grade, and measured depth) tubing in main wellbore, , Packers & SSSV (type & measured depth) ZXP liner pkr @ 5502' Camco'DB' nipple @ 504' 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 SI SI -- Subsequent to operation 1797 723 44 -- 200 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 Printed Name Brett Packer ~--, '" ~ Title Wells Group Engineer ~,~~~ ~ ~~~~- ~ Signature ~ Phone: 265-6845 Date / Pre ared b Sh n Allsu -Or k 263-4612 Form 10-404 Revised 04/2006 ~ ~ ~ ~~~^ ~.t~ ~ ~ ~~~~ ~~1~~ Submit Ori ' (~rjiv/~~~~ ,,r -.~ ~~ G~In~~'~i11~s -~aska, ~c. Heat Trace ` T~ (2o-2ss1, ---~ OD:0.500) ~ ~ ~~ XO Bushing (5383-5384, OD:5.990) HANGER (5399-5415, OD:5.460) PACKER (5502-5521, OD:6.540) CSR (5521-5541, OD:6.280) HANGER (5732-5742, oDS.7so> HANGER (5742-5759, OD:6.750) _ HANGER (5759-5766, OD:6.750) PACKER (5818-5841, OD:8.000) SLEEVE (5887-5900, OD:5.500) KRU 1J-152L1 - _ 1J-152L1 API: 500292329860 Well T e: PROD _ _ _ __ ~ An le TS: de SSSV Type: NIPPLE Orig Com letion: 4/22/2006 Angle @ TD: 91 deg @ 13408 Annular Fluid: Last W/O: 1/17/2008 Rev Reason: GLV C/O Reference Lo 28' RKB Ref Lo Date: Last U date: 1/30/2008 Last Ta TD: 13408 kKB Last Ta Date: Max Hole ~le_ 94 de -- 6503 -- -.. Casin Strin _- COMMON ~ S T_RING S - B-Sand slotted li ner has 8 constrictor ackers W Descri lion _ _ Size To Bottom ND V11t Grade Thread CONDUCTOR 20.000 0 108 108 62.60 H-40 WELD SURFACE 10.750 0 2773 2198 45.50 L-80 BTC PRODUCTION 7.625 0 6523 3495 29.70 L-80 BTCM WINDOW D-SAND 7.000 5403 5404 3443 0.00 WINDOW B-SAND 7.000 5747 5748 3507 0.00 B-SAND SLOTTED LINER Tubin Strin -`;TUBING Size Top _ 4.500 0 Perforations Summary _ Interval TVD 4.500 Bottom ~~,~~ Zone 5788 13374 3424_ _ 11.60 L-80 BTC TVD Wt Grade I Thread _ ~~-~>> 72c,o (~,o I~rn~ Status Ft SPF Date T e Comment 5949 - 6763 3515 - 3490 WS B 814 32 4/7/2006 Slots Alternatin slotted/solid i e 7139 - 8323 3512 - 3476 WS B 1184 32 4/7/2006 Slots Alternatin slotted/solid i e 8529 - 10034 3481 - 3456 WS B 1505 32 4/7/2006 Slots Alternatin slotted/solid i e 10202 - 10418 3456 - 3458 WS B 216 32 4/7/2006 Slots Alternatin slotted/solid i e 10546 - 13340 3459 - 3425 \~~S B Gas Lift MandrelslValves St MD ND Man Mfr Man Type 2794 _ 32 4!7/2006 Slots Alternating slotted solid plPe V Mfr V Type V OD Latch Port TR© Date Run Vlv Cmnt 1 3154 2403 CAMCO KBG-2-1R GLV 1.0 BK 0.125 1470 1/29/2008 I f I1. I bUti41 33b~IGAMGU~Kl3Ci-Z-1R1 I UV I lA I liK I U.31Z I U I1/1y/LUU2S1 I Other lu s, a ui ., etc. -COMPLETION De th ND T e Descri lion ID 20 20 Heat Trace TYCO DDH HEAT TRACE 0.000 25 25 HANGER TUBING HANGER 3.900 504 504 NIP CAMCO'DB' NIPPLE 3.875 5297 3419 NIP CAMCO'DB' NIPPLE 3.812 5298 3419 GAUGE BAKER POLARIS GUARDIAN GAUGE CARRIER w/GUARDIAN. 0.000 5363 3434 SBE D-SAND SEAL BORE EXTENSION 190-47 4.750 5383 3438 XO Bushing D-SAND LEM BAKER CROSSOVER BUSHING 3.950 5388 3439 HANGER D-SAND LEM BAKER ABOVE HOOK HANGER 3.690 5399 3442 HANGER D-SAND LEM BAKER BELOW HOOK HANGER 3.690 5485 3460 SEAL D-SAND LEM BAKER NON-LOCATING SEAL ASSEMBLY 3.880 Other lu s,_equ~ etc.Z- B-SAND LEM/LINER DETAIL De th ND T e Descri lion ID 5502 3463 PACKER B-SAND ZXP LINER TOP PACKER 4.970 5521 3467 CSR B-SAND LINER 109-47 CASING SEAL BORE RECEPTACLE 4.750 5541 3471 XO B-SAND LINER CROSSOVER BUSHING 4.750 5732 3504 HANGER B-SAND LINER LEM ABOVE HOOK HANGER 5.320 ~ i 'I -°1 3"I ~ ' ~ ~ ~ . , , _ -- ~ ~ - I _ ~ ~ . ~ 5818 3513 PACKER B-SAND LINER BAKER PAYZONE EXTERNAL CASING PACKER 7.625 5825 3514 NIP B-SAND LINER CAMCO 'DB-6' NIPPLE 3.563 5887 3515 SLEEVE B-SAND LINER BAKER'HR' LINER SETTING SLEEVE 0.000 5901 3515 SEAL B-SAND LINER BAKER SEAL ASSEMBLY 0.000 13373 3424 General Notes Date Note SHOE B-SAND LINER_ BAKER OPEN GUIDE SHOE 0.000 4/24/2006 NOTE: MULTI-LATERAL WELL: 1J-152 A-SAND , 1J-152L1 B-SAND , 1J-152L2 D-SAND 10/6/2007 NOTE: WAIVERED WELL T x IA COMMUNICATION - PACKERLESS WELL ,ESP FAILED 1/17/2008 NOTE: WORKOVER PULL ESP ASSY: NEW COMPLETION w/GLM/NIP/LEM i Ca-nocc~Phlips Time Log Summary Weltu7ew 4Yeb Rey°nfng Well Name: 1J-152 -- Job Type: RECOMPLETION - - --_ ___ - --- ___ Time Logs Daie __ Fror~To Dur S. De th E Depth<Pt~ase Code Subcode T COM 01/09/2008 16:00 00:00 .8.00 MIRU MOVE MOB P RD move rig from 2A-18 to 1J-152 01/10/2008 00:00 10:30 10.50 MIRU MOVE MOB P Continue moving rig & camp from 2A-18 to 1J-152. Arrived on location with rig @ 10.00 am. Arrived with Cam 12:30 m. 10:30 17:30 7.00 MIRU MOVE OTHR P While Pad Maint. removing Thermosiphon. Removed 11" BOPE from stump in cellar and replacing with 13 5/8". S of cam and level. 17:30 19:30 2.00 MIRU MOVE MOB P Move rig around pad to 1J-152 well, s of ri over well, level same. 19:30 20:30 1.00 MIRU MOVE RURD P Berm up cellar and spot rock washer building. Run hardline and tie in kill tank to rig. Rig accepted this day, the 10th of Jan 2008 1930 hours. 20:30 00:00 3.50 COMPZ WELC KLWL T Attempted to pull BPV, wellhead frozen. RU steam lines and bring in heater, apply heat to wellhead for thaw. 01/11/2008 00:00 03:00 3.00 COMPZ WELCT OTHR T Finish thawing wellhead, pull BPV, Attempt to circulate and kill well, kill lines froze. Work through system and thaw same. 03:00 07:00 4.00 COMPZ WELCT CIRC P P-test kill lines. Press at start 190 psi TBG, 200 psi IA, start pumping 6% KCL down tubing with IA open to kill tank. At 83 bbls away, IA pressure started dropping, Ramp pumps up to 5 bpm while venting gas. Achieved circulation @ last 188 bbls pumped. Pumped total 200 bbls 140 deg F 6% KCL down tbg. Swap lines, start pumping down IA w/ returns up tbg. Pump 90 bbls 140 deg 6% KCL, Chase with 110 bbls 120 deg 6% KCL. Had full returns up tubing throughout pumping procedure on lA. Pumped down IA @ 4 bpm. Swapped from kill tank back to pits and circulated another 60 bbls. to clean hole. Shut in, monitor well, IA='0' tb = '0'. 07:00 08:00 1.00 COMPZ WELCT NUND P B/D & R/D circ. lines 08:00 10:30 , 2.50 COMPZ WELCT NUND P N/D tree & hang in cellar. Set test lu 10:30 16:00 5.50 COMPZ WELCT NUND P N/U 13 5/8" BOPE. ~_ (' , rt,~ 1 nt Time Logs ~ -- Date____ _ .From To Dur 5 Depth E. De~h_ Phasz___ Code Subcode T _ COM 01/11/2008 16:00 17:00 1.00 COMPZ RPCOh RURD P Load empty ESP spool on floor w/ crane. 17:00 23:30 6.50 COMPZ WELCT NUND P Finish NU 13 5/8" 5M BOPE. 23:30 00:00 0.50 COMPZ WELCT BOPE P Testing BOPE 250 psi Low, 2500 psi Hi h. 01/12/2008 00:00 05:00 5.00 PROD1 WELCT BOPE P Testing BOPE to 250 psi low, 2500 si hi h. 05:00 08:00 3.00 PROD1 WELCT WOEQ NP Waiting on test jt for lower rams. Trouble locatin . 08:00 09:00 1.00 PROD1 WELCT BOPE P Test lower pipe rams 250/2500 psi. 09:00 10:00 1.00 PROD1 RPCO NUND P Pull blanking plug & BPV. Fill hole 25 bbls . 10:00 10:30 0.50 PROD1 RPCOh SFTY P PJSIVI on pulling ESP. 10:30 12:00 1.50 PROD1 RPCOh NUND P Screw into the tubing hanger with the landing jt. Mark pipe at the rotary table. BOLDSs on tubing hanger. Unland tubing hanger and pull to rig floor. Lay down hanger, attach ESP cable to spooler. Pulled 150 klbs to unseat, PU 95 klbs, SO 75 klbs, 12:00 14:30 2.50 PROD1 RPCOh OTHR P Load 170 jts 3 1/2" IF, Drill Pipe in shed 5o it can be warming up while ESP is being pulled. Strap & tally same. 14:30 20:30 6.00 PROD1 RPCOti PULD P POOH standing back the 4 1/2" tubing, removing all jewelry, and s oolin u the ESP cable. 20:30 23:00 2.50 PRODS RPCO PULD P Disconnect, Break-out and LD ESP. 23:00 00:00 1.00 PROD1 RPCOh OTHR P Shuffle components in pipe shed, clear /clean floor for next o eration. 01/13/2008 00:00 02:30 2.50 PROD1 RPCOti CIRC P Shuffle tubing in pipe-shed. MU Wash BHA and break circulation at surface. Ramp up rate to get baseline data on circulation parameters. Achieved 6 bpm (252 gpm) @ 2400 psi. Decision made to pull circulating subs, pick up and RIH open ended w/ BHA and 3 1/2" DP, circulate to flush out any debris in DP before attempting wash routine. 02:30 04:00 1.50 PROD1 RPCO PULD P Break out lateral and bottom wash subs, MU remainin BHA. 04:00 08:00 4.00 PROD1 RPCOh PULD P PU and RIH w! 3 1/2" IF DP workstring o en-ended. 08:00 08:30 0.50 PROD1 RPCOti CIRC P Pumped 40 bbls (DP vol) to clean out drill i e. 4 BPM w/180 si. 08:30 09:00 0.50 PROD1 RPCOti PULD P Pull and stand back 3 stnds. PU and run 9 ~ts. 09:00 09:30 0.50 PROD1 RPCOti CIRC P Pumped 50 bbls to clean out drill pipe. 5 BPM w/380 si. 09:30 12:00 2.50 PROD1 RPCOti PULD P POOH standing back drill pipe and drill collars. Time Logs - - --- 1 - _ _ __ _ Date From_ To Dur 5 Depth_ E De~th_ Phase Cod2___ S__ubcode T COM ~ 01/13/2008 12:00 15:00 3.00 PROD1 RPCOti PULD P Break out BHA and install wash nozzles and RIH to 650'. 15:00 15:30 0.50 PROD1 RPCOti CIRC P Pump to get baseline data on pumping parameters. Achieved 6 BPM @ 2460 si. 15:30 17:30 2.00 PROD1 RPCOh PULD P Continue to RIH with Wash BHA to 5303'. 17:30 18:00 0.50 PROD1 RPCOh OTHR P Put steam to Top Drive and lubricate. 18:00 20:00 2.00 PROD1 RPCOh CIRC P MU top drive, establish. pumping parameters, wash from 5332.5 - 5539.5 (ORKB) @ 5 bpm & 1850 psi. Reciprocate through hook area and SBE. Established circulation, able to um at 5 b m w/ 50% returns. 20:00 21:00 1.00 PROD1 RPCOh CIRC P Rack 1 stand and CBU @ 6 bpm & 2800 psi. Blow down top drive, monitor well, fluid ra idl dro in . 21:00 23:00 2.00 PROD1 RPCOh TRIP P TOH from 5497 - 459'. 23:00 00:00 1.00 PROD1 RPCO PULD P Break out and LD BHA #2. Inspect wash subs, OK. 01/14/2008 00:00 01:30 1.50 PROD1 RPCO PULD P LD wellbore wash BHA and remove from floor. 01:30 02:30 1.00 PROD1 RIGMN SVRG P S&C Drill line. 02:30 03:30 1.00 PROD1 RPCOh OTHR P Organize pipe shed and floor, ready all to ick u LEM ass . 03:30 06:30 3.00 PROD1 RPCOh PULD P Picking up LEM Assembly and runnin tools. 06:30 11:00 4.50 PROD1 RPCOh PULD P RIH with LEM Assembly on Drillpipe to 5351'. U wt. 110K Dwn wt 75K 11:00 11:30 0.50 PROD1 RPCOh PULD P Oriented LEM w/MWD. 11:30 14:00 2.50 PROD1 RPCOh HOSO P Lowered LEM down and engaged hook hanger @5398'. MWD showed LEM window @ 3 degrees left. Snapped out of hook hanger w/20K overpull. Repeat process 3 times to verify orientation of 3 degrees left. Picked up single and rigged up circulating lines. Dropped 1 3/4" ball. Snapped in and out 2 more times to verify engagement. Pressured up to 4000 psi set packer and released running tool. Tested packer to 2500 psi and charted. Broke lines off, pulled up and released running tool. New top of liner 5344'. 14:00 17:00 3.00 PROD1 RPCOti OTHR P Change out ESP spool and install I-wire control lines ool. 17:00 23:30 6.50 PROD1 RPCOti PULD P POOH laying down 4 1/2" drillpipe. 23:30 00:00 0.50 PROD1 RPCOti PULD P PJSM, LD LEM running BHA. .01/15/2008 00:00 01:30 1.50 PROD1 RPCOh PULD P PJSM, Finish break-out and LD BHA. f - 3oi5 Time Low Date From To Dur____ _S_ Depth E_ Depth Phase Code Subcodz T CQ(~9 - - _ 01/15l2008 01:30 02:30 1.00 PROD1 RPCOh PULD P Remove BHA tools from rig. Pull wear bushin ,clear floor. 02:30 18:00 15.50 PROD1 RPCOti WOEO NP Wait on equipment needed to assemble final completion string prior to RIH. While waiting on equipment crew continued to rig up sheeves for I wire and heat sensor. Along w/ 20 extra ~ts of 4.5 12.6# IBTM L-80 tb . 18:00 18:30 0.50 PROD1 RPCOh SFTY P Held PJSM w/ Rig crew and Third Part Contractors 18:30 21:00 2.50 0 357 PROD1 RPCOh PULD P Pick up & Rih w/ GBH-22 Locating Seal Assembly 1 jt of tbg and Polaris Guardian pressure / tempature gauges w/ 3.813" DS Nipple (used 3 SS bands). Rih w/ 7 jts of tbg w/single cannon clamps @ ea coupling, GLM #1 w/ SOV, 1 't 21:00 23:30 2.50. 357 2,389 PROD1 RPCOti Continue to Rih w/ tbg from derrick w/ single cannon clamps @ ea coupling to 2389'. 23;30 00:00 0.50 2,389 2,420 PROD1 RPCOti PJSM, Start Heat Trace and Rih to 2420' 01/16/2008 00:00 05:00 5.00 2,420 3,020 PROD1 RPCO RCST P Continue to Rih f/ 2420' installing heat trace, Tec wire and cannon clam s. 05:00 06:30 1.50 3,020 3,020 PROD1 RPCOh RCST P Shut down running to test cable and chan a out sheave for the I-wire. 06:30 12:00 5.50 3,020 4,077 PROD1 RPCOti RCST P Continue to RIHf/ 2420' U 4077'. Installing heat trace, Tec wire and cannon clamps. Crew Change. 75k u wt. 68k do wt. 12:00 20:00 8.00 4,077 5,382 PROD1 RPCOti RCST P PJSM, Continue to Rih f/ 4077' to 5349' and tag top of ZXP Tie back sleeve@ 5349'. Work into tie back sleeve w/ 1/2 turn, and Rih to 5384' bottom of seals and locator @ 5355'. Pressure test to 500 si. 20:00 22:30 2.50 5,382 5,330 PROD1 RPCOA HOSO P Space out to 5382' @ bottom of seal assy. PU and MU 2 space out pups (15'), 1 jt and hanger w/ MCA Landing 't. 22:30 00:00 1.50 5,330 PROD1 RPCOh OTHR P Install Penetrators and install splices in tech wire and heat trace. 01/17/2008 00:00 01:00 1.00 PROD1 RPCOh OTHR P Continue to Splice I Tech and Heat Trace and tie into Penetrator. 01:00 02:30 1.50 PROD1 RPCOh CIRC P pump 35 bbls corrosion inhibited sea water followed b 100 bbls sea water. 02:30 04:00 1.50 PROD1 RPCOh HOSO P Land Hanger and RILDS. RU to test IA 04:00 04:30 0.50 PROD1 RPCOh SFEO P Pump on IA attempting to work air from system prior to chart test and prematuraly shear out SOV @ 1150 si. 04:30 08:00 3.50 PROD1 RPCOh WOEO T Call for Slick line to change out 1500 psi SOV to 2000 psi SOV. RD heat trace sheave. --- ---- - -- _ I' ~ ~t ,} • Time Logs Date From To Dur 5 De th E. DEpth PhaseCode Subcode T COM ___ .01/17/2008 08:00 13:30 5.50 PROD1 RPG©h ©THR T PJSM on RU slick line. RU slickline and attempt to run plug in D8 nipple @ 5298'. Unable to get past 4500'.. Dropped Standing valve and attempted to push down with weight. Could not et ast 4500'. POOH with slickline. 13:30 15:30 2.00 PROD1 RPCOti DHEQ P RD slickline. RU hoses and pumped standing valve down on seat of DB nipple @ 5298'.. Pressured up on IA/tubing combination to 2500 psi and charted for 30 min. 15:30 16:00 0.50 PROD1 RPCOh NUND P Bled off pressure. Back out landing jt. and la ed down. Set two-wa check. 16:00 18:00 2.00 PROD1 RPCOh NUND P PJSM. ND BOPE 18:00 22:30 4.50 PROD1 RPCOh NUND P PJSM. NU Tree and test hanger void and Tree to 5,000 psi f! 10 min. Good test. 22:30 00:00 1.50 PROD1 RPCOh FRZP P RU LRS and pressure test circ. lines to 3,000 psi. Freeze protect w/ 87.5 bbls diesel. U tube tbg x IA. RD LRS set. HBPV. 2052 bbls KCL Seawater lost to well during workover. Release ri 23:59 hrs. F'-~r.. 5 ~f 5 o ~ ~ ~ ~ SARAH PALIN, GOVERNOR ~-7~ 0~ ~D t7[~7 333 W. 7th AVENUE, SUITE 100 C011T5F.1ZQ~-1•I011T COM1~iISSi01~ ANCHORAGE, ALASKA 99501-3539 -7sI a` -7 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-152L1 Sundry Number: 307-304 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager) . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Dan T. Seamount Commissioner DATED this ~ day of October, 2007 Encl. ao~,_~(~ ConocoPhiilips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 27, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: u(.~' ~ ~, ~~~~ ,•~~ Enclosed please find a 10-403 Sundry Notice variance request for ConocoPhillips Alaska, Inc., West Sak well 1J-152, 1J-152L1, and 1J-152L2 (PTD #'s 2060160, 2060170, 2060180). The variance request is for approval to temporarily use gaslift to produce the '" ESP completed well. Also attached is a discussion and well schematic. Please call MJ Loveland or myself at 907-659-7043, and 907-659-7224 respectively if you have any questions. Sincerely, Brent Rogers Problem Well Supervisor Attachments STATE OF ALASKA iQ~? {~° (•--i- ~- ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ?(~(;1 APPLICATION FOR SUNDRY APPROVAL ~i~ska-~i~ ~~;~ ~~,; , ~.~~;~;~ 20 AAC 25.280 Cs~.-~~,; . 1: Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved. program ^~ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2: Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ^ 206-017 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23298-60 '' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and. Number; where ownership or landownership changes: Spacing Exception Required? YeS ` ^ NO ^~ ~ 1J-152L1 9, Property Designation:. 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25661. & 25662. ALK 471 & 2177 RKB 109' Kuparuk River Field? West Sak Oil Pool - 12: PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured):. Junk (measured): 13408' 3424' , Casing Length Size MD TVD Burst Collapse CONDUCTOR.. 108' 20" 108' 108' SURFACE 2664' 10-3/4" 2773' 2198' PRODUCTION 6414' 7-5/8" 6523' 3637 WINDOW D-SAND 1' 7" 5404' 3443' - WINDOW 8-SAND 1' 7" 5748' 3507 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Zones FR 5949' - 13340' Zones FR 3425' - 3515' 4-1/2" L-80 4892' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV no SSSV 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development. ^~ Service. ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 3, 2007 Oil ^~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~'` Contact; M J Loveland / Perry Klein % Printed Name:. M J Loveland ~ Title: Problem Well Supervisor ~ Signature Phone 659-7224 Date 09/27/07 Commission Use Only: Sundry Number. Conditions of approval: Notify Commission so that a .representative may witness o?_ 3 Q Plug Integrity ^ SOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: S ~FP.-~ Obi ~ 2~Q~ Subsequent Form Re uired: ~~firJ •"~, ~ F; ~-• t'~+~t;~ APPROVED BY ~~Z ~ Approved by: THE COMMISSION Date: ,( Form 10-43 Revised 06/2006 l,f ~ j v ~ I y~ k Sub it in Duplicate ~ • • ConocoPhillips Alaska, Inc. West Sak Injection Well 1J-152 (PTD 2060160) & 1J-152L1 (PTD 2060170) & 1J-152L2 (PTD 2060180) SUNDRY NOTICE 10-403 VARIANCE REQUEST 09-27-07 The purpose of this Sundry Notice is for approval to produce dual lateral West Sak producer 1J- 152 via gas lift until the failed ESP is replaced. The well is completed as an ESP (electric submersible pump) producer and does not have a packer. 1J-152 was completed in April, 2006. The well produced via ESP until 09/11/07, at which time it was shut-in due to a downhole motor electrical failure. The A-well gauges (suction and temperature) flat lined starting August 22 as the ESP was ramped up after CPF 1 came back online post ESD test so we have no down hole telemetry during the failure. The failure mechanism will not be known until the ESP is pulled and torn down. A no-flow situation is suspected to have occurred, followed by the motor overheating or another form of electrical burnout. A no-flow condition or high motor temperature would have been caught by the down hole gauge readings had they been working. The tubing is configured with two gas lift mandrels at 3138' RKB (2395' TVD) and 4210' RKB (2986' TVD). A GLV was installed at 3138' and an orifice valve was installed at 4210'. Gas lift will be applied in the "standard" configuration; i.e., gas will be injected down the annulus and enter the tubing through the gaslift and orifice valves. Attached is a motherbore well diagram of the well. The following is a summary of the proposed plan: 1. The AOGCC approve this request for a time period not to exceed 24 months from the approval date; 2. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. • • KRU 1 J-152 "~ API: 500292329800 ,___ Well Type i PROD I Angle @ TS . deg_~_ ,~~ "~ e:'I NONE ' Orig Completion:' 4/22/2006 An le TD ' 88 de 1 C Annular Fluid: j Last W/O: j _ Rev Reason: ,NEW WELL _. i i Tn~ I ~ nn~z alto I I '. HANGER (5399-5415, OD:8.470) HANGER (5742-5766, OD:6.750) r r r r r I ^ e ' r I r r r r - 1 Last Tag Date: ; Max Hole Angle 94 deg @ 7511 Casin Strin -COMMON STRINGS A-Sand sl otted liner has 11 constrictor ackers Descri tion Size To ! Bottom TVD V1(t Grade Thread CONDUCTOR 20.000 0 108 108 62.50 ~ H-40 WELDED '; SURFACE 0 10.750 ! 2773 2198 45.50 L-80 BTC PRODUCTION _ ~ 7.625 ~ 0 6523 I 3637 29.70 L-80 I BTCM WINDOW D-SAND 8.000 5403 5404 3443 0.00 WINDOW B-SAND 8.000 5747 5748 3507 0.00 A-SAND SLOTTEDLINER 4.500 5862 9102 ~ 3633 11.60 L-80 BTC A-SAND SLOTTEDLINER 4.500 9102 9841 3621 12.60 L-80 IBTM Tu6in Strin '-...TUBING I Size To Bottom TVD Wt Grade ~ Thread 4.500 0 4892 I 3286 12.60 L-80 IBTM Perforations Summa Interval TVD Zone ' Status Ft ~ SPF Date T e Comment 6500 - 6885 3636 - 3633 WS A3,WS A2 i 385 32 3/29/2006 Slots Alternating solid/slotted pipe 7310 - 8075 3662 - 3639 WS A2 ! 765 32 3/29/2006 Slots Alternatin solid/slotted i e 8291 - 8421 3630 - 3623 WS A2 130 32 3!29/2006 Slots Alternatin solid/slotted i e 8630 - 8673 3630 - 3632 WS A2 ! 43 32 ~ 3/29/2006 Slots . Alternatin solidlslotted i e 8843 - 9102 3632 - 3633 WS A2 259 i 32 3/29/2006 Slots Alternatin solid/slotted i e 9104 - 9320 I 3632 - 3632 WS A2 ~ 216 32 3!29/2006 Slots Alternatin solid/slotted i e 9475 - 9808 3629 - 3621 WS A2 333 32 3!29/2006 Slots Alternating solid/slotted. i e I Gas Lift Mandrels/Valves _. - St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch ' I Port TRO !Date Run Viv Cmnt 1 3138 2395 CAMCO KBMG SOV 1.0 BEK-5 0.0 00 0 i 4/22/2006 i 2 4210 2986 CAMCO KBMG DMY 1.0 BK-5 0.000 0 ' 4/22/2006 Other. lu s a ui etc. '- COMPLETION JEWELRY De th TVD T e Descri tion ID 23 23 ' HANGER VETCO GRAY TUBING HANGER 4.500 4752 3227 DIS. SUB A-WELL DISCHARGE SUB ' 0.000 4830 3260 ! XO TTC CROSSOVER w/SCREEN INTAKE 0.000 4840 3264 SEAL TANDEM SEAL SECTION GSB 3 DB AB/HSN PFSA 0.000 4854 3270 MOTOR/ PUMP MOTOR 418 HP KMHFER 2610 / 98 "4 w/ PUMP INSTALLED IN MOTOR'* 0.000 4888 3284 ! GAUGE A-WELL PUMP GAUGE 0.000 4890 3285 Centralizer MOTOR CENTRALIZER ' 0.000 5399 3442 HANGER D-SAND BAKER MODEL B-1 HOOK HANGER INSIDE CASING 4.020 Other lu s ''e ui .,.etc . =A-SANDLINER'JEWELRY De th TVD T e Descri tion ID 5862 3527 PACKER HRD ZXP LINER TOP PACKER i 4.970 5880 3530 NIP 'RS' PACKOFF SEAL NIPPLE 4.875 5883 3530 HANGER FLEXLOCK LINER HANGER 4.853 5893 3532 ~ SBE 190-47 CASING SEAL BORE EXTENSION 4.750 I 5913 3535 XO CROSSOVER BUSHING 3.830 9840 3621 SHOE ROT WEATHERFORD GUIDE SHOE 3.500 ' Other lu s, equi ., etc . - B-SAND LEM. De th TVD T e Descri tion ID 5502 3463 PACKER ZXP LINER TOP PACKER 4.970 5521 3467 CSR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5541 3471 XO CROSSOVER BUSHING 3.830 5732 3504 ! HANGER LEM ABOVE HOOK HANGER ~ 5.320 5742 3506 HANGER j LEM INSIDE HOOK HANGER 5.320 ~ General Notes ___ - Date Note 4/24/2006 MULTI-LATERAL WELL: 1J-152 A-SAND , 1J-152L1 B-SAND , 1J-152L2 D-SAND I I I 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-152, PB1, PB2, Ll, L2 & L2 PBI, AK-MW-4263658 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-152, PBl, PB2, Ll, L2, L2 PBl: LIS & Digital Log Images: 50-029-23298-00, 70, 71, 60, 61, 72. FAQ ~ao~-ode ~ 1563 €~- - S ~~~ ~ , 5~3~ ~1 . ° ~~~.~ rye ~4a.~ ~aot~-or ~ ~ t5o~3 C~ April 16, 2007 1 CD Rom '~ ~b~ " Ol ~ ~ ! 5010 '~I~UVJ ~ • WELL LOG TRANSMITTAL To: State of Alaska June 22, 2006 Alaska Oil and Gas Conservation Co, Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-152, PB1, PB2, L1, L2, L2 PB1, AK-MW-4212091 1 LDWG formatted CD Rom with verification listing(s). API#: 50-029-23298-00, 70, 71, 60, 61, 72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date:_`~~~~ Signed: ~~o~ --6~~ , ~~~-vr'~~ X06 -~vr~ ~i 399 ~ • • 11-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-152 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,720.63' MD Window /Kickoff Survey: 13,365.44' MD (if applicable) Projected Survey: 13,408.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 i a Date o2 ? ~wn~~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 2n6-n, ~ ConocoPhillips May 24, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Randy Thomas Kuparuk Drilling Team Leader Drilling- & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Subject: Well Completion Reports for 1 J-152, 1 J-152L1 and 1 J-152L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1 J-152, 1 J-152L1, 1 J-152L2. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820.. Sincerely, R. Thomas . Kuparuk Drilling Team Leader CPAI Drilling RT/skad • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION - WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil O Gas Plugged ^ Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: April 22, 2006 12. Permit to Drill Number: 206-017 / • 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: „•n March2006 I,•~'~~' 13. API Number: S0-029-23298-60 4a. Location of Well (Governmental Section): Surface: 2191' FSL, 2582' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: `~ Apri12006 / ~.'L'~ 14. Well Name and Number: 1J-152L1 At Top Productive Horizon: 2025' FSL, 968' FWL, Sec. 35, T11 N, R10E 8. KB Elevation (ft): 28' RKB / 108' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 345' FNL, 1002' FWL, Sec. 11, T10N, R10E 9. Plug Back Depth (MD + ND): 13372' MD ! 3424' TVD West Sak Oil P001 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558625 y- 5946002 Zone- 4 10. Total Depth (MD + ND): • 13408' MD / 3424' TVD ' 16. Property Designation: ADL 25661 & 25662 TPI: x- 556897 y- 5945822 Zone- 4 Total Depth: x- 556999. - 5938174 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes Q No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2365' MD 21. Logs Run: T-/l~~i.fJ s -~y~ iaa, 3sa~ ~~ GR/Res, CBL ~l.~ G•4 • a` 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" 62.58# H-40 28' 108' 28' 108' 42" 12o sx Class G 10.75" 45.5# L-80 28' 2774' 28' 2198' 13.5" 520 sx AS Lite, 184 sx DeepCRETE 7-5/8" 29.7# L-80 28' 6523' 28' 3638' 9-7/8" 375 sx DeepCrete 4.5" 11.6# L-80 5742' 13374' 3506' 3424' 6.75" slotted liner 23. Pertorations 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 tubing in main wellbore 4892' 5818' slotted liner: 13340'-10545', 10418'-10202', 10033'-8529' 8323'-7138', 6763'-5948' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production May 14, 2006 Method of Operation (Flowing, gas lift, etc.) ESP Oil -shares production with 1J-152 and 1J-152L2 Date of Test 5/16/2006 Hours Tested .5 hours Production for Test Period -> OIL-BBL 80 GAS-MCF 28 WATER-BBL 21 CHOKE SIZE 19% GAS-OIL RATIO 390 Flow Tubing press. 186 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 2837 GAS-MCF 1107 WATER-BBL 744 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~~ ~L,. ,IUN 0 ~ 2006 ~ ._~•Z2 NONE .__-~D . Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~~i~ 28. 29. 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". 1J-152L1 Top West Sak B 5747' 3507' Base West Sak B 13408' 3424' , N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed N e Ran a Title: Greater Kuoaruk Area Dril-ino Team Leader S~2 r~o~ , Signature P~ ___s Date ZG.r-G ~? 3 c INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12!2003 1J-152 Daily Operations Summary • DATE Summary operations 03/13/06 Move off well 1 J-159.... 03/14/06 RDMO of well 1 J-159 -Move North 160' on well row to 1 J-152 03/15/06 Drill, PU Dir BHA, resume drilling 03/16/06 Drilled from 1,173' to 1,816' MD. Tripped for bit. RIH and washed and reamed from 1,636' to 1,816'. Lost 5? of angle, inadvertently S/T @ 1,636'. Cont'd drilling from 1,816' to 1, 838'. . 03/17/06 Drilled 13.5" hole to TD @ 2787' MD / 2,205' TVD. BROOH from 2,787' to 2,048'. POOH and UD BHA. R/U to run 10.75" casing. Run casing to 1,496'. 03/18/06 Ran 10 3/4" casing to 2,774.8' and cemented same. Set casing on slips. Welded on flange and wrapped to cool. Sim-Ops C/O saver sub,. P/U 27 jts 4" DP. 03/19/06 P/U 4" DP and R/B. Tested BOPs. Run gyro on wireline. P/U 8HA #3. 03/20/06. RIH w/ BHA #3. Performed casing test to 3000 psi. Drilled out FC and FS and performed LOT to 14.2# EMW. Drilled from 3,193' to 4,096' MD / 2,925' TVD. 03/21/06 Drilled 9 7/8" intermediate from 4,096' to 5,614' MD / 3,483' TVD. 03/22/06 Drilled from 5,614' to TD @ 6,532' MD / 3,639' TVD. BROOH to 3,335'. 03/23/06 POOH and L/D BHA #3. R/U for 7 5/8" casing run and run to TD @ 6,522' MD / 3.638' TVD. Cemented as per detail. . 03/24/06 Set 7 5/8" casing, on slips. P/U DP and install 90 super sliders. M/U BHA #4 and singled in hole. RIH tagged cement, PU and CBU. Slipped and cut, serviced TD and DWS. Performed casing test. 03/25/06 Tested casing. to 3000 psi for 30 min. Drilled out shoe +20' new hole, performed LOT to : -,__. 13.5 EMW..Drilled intermediate from 6,552' to 7,646'. Pulled back for S/T (fault) @ 6,8.11' MD. Drilled from 6,811' to 7,085' MD. 03/26/06 Drilled "A" Lat from 7,085' to 9,024' MD. 03/27/06 Drilled from 9,024' to 9,343' MD. Decision made to S/T, pulled back to 8,425' MD. Drilled from 8,425' to 9,803' MD. 03/28/06 Drilled to TD of 10053' MD/ 3621' TVD. Pump hi visc sweeps. POOH to 7 5/8" shoe, RIH to TD. Went into old sidetracked hole twice. Made it to TD. POOH to 362' MD. 03/29/06 LD BHA #4. Run & set 4.5" liner and liner hanger. MU whipstock and mill assembly. Set whipstock. Displace from SFOBM to MOBM. 03/30/06 Mill window from 5747' to 5759'. Drill 5' gauge hole to 5774' MD. POOH and LD milling -~ assembly. RU and Test BOPEs. PU BHA #6. Slip & cut drill line, service TD, DWs, & saver sub. Drill from 5774' to 5828' MD / 3522' TVD. 03/31/06 Drilled B Lat from 5,828' to 7,962' MD / 3,492' TVD. 04/01/06 Drilled B lat from 7,962' to 10,079' ! 3452' TVD 04/02/06 Drilled B lat from 10,079' to 11,631' MD / 3,438' TVD. 04/03/06 Drilled B lat from 11,631' to TD at 13,408' MD / 3426' TVD. -• 04/04/06 BROOH to window. Circ sweep. TIH to TD, change over to SFOBM. 04/05/06 POOH, LDBHA, PU Whipstock retrieving tools, PJSM, RIH and pull whipstock. 04/06/06 LD Whipstock & retrieving tools. RIH with 4.5" liner. 04/07/06 POOH and PU flop and drop assembly to leave 4.5" liner. RIH with with liner and HR setting sleeve on drill pipe. Rotated liner down from 11,519' MD to TD at 13,374' MD. Set liner & POOH. LD running tools. 04/08/06 MU Hook Hanger assembly for the drop run. RIH and find liner. Set hook hanger. POOH and LD running tools. PU milling assembly. 04/09/06 MU Milling assembly. RIH and tagged up 23' early & mill plugged off. POOH and MU milling assembly with float sub. RIH, filling pipe every 10 stds. Tag RS nipple, cycle boot baskets. POOH and LD milling assembly. MU LEM assembly. 04/10/06 Set LEM & ZXP. POOH & LD running tools. MU Whipstock assembly. RIH & MAD pass. • 1J-152 Daily Operations Summary • 04/11/06 Set whipstock, drilled window from 5,403' to 5,415'. POOH, and L/D mills. Tested BOPE. M/U drilling BHA and SHT MWD. 04/12/06 Cut and slipped DL, serviced TD. Drilled "D" lat from 5,442' to 6,024' MD. Unable to get proper directional response, POOH. M/U BHA w/ motor and agitator. 04/13/06 Trough from 5,425-5,445' MD. S/T from 5,445' to 7,249' MD / 3,446' TVD. 04/14/06 Drilled from 7,249' to 7,572' w/ motor. POOH due to washout. UD motor and P/U Geo- pilot and assoc. BHA. RIH and drill from 7,572' to 7,967 MD. 04/15/06 Drilled from 7,967 to 9,775' MD w/geo-pilot. 04/16/06 Drilled from 9,775' MD to 11,30T w! geo-pilot. 04/17/06 Drilled from 11,307 MD to 13,112' TD w/geo-pilot. Began to BROOH. 04/18/06 BROOH to window, pumped sweep +2BU. Cut and slipped DL and serviced TD. RIH to TD circa sweep and disp. well to SFOBM. TOOH and began UD BHA. 04/19/06 UD BHA. Ran 4.5" slotted liner to 13,086' w/ top @ 5,603' and released. POOH w/ DP. RIH and retrieved whipstock. 04/20/06 RIH w/ hook hanger and ECP and set. Began L/D DP. 04/21/06 L/D DP. Singled in hole w/ completion tubing and S/B. Rigged up Centrilift and began R/U motor and ESP. 04/21/06 SET 46.01' X 3.80" OD ESP PUMP (W/CHECK) @ 86' SLM (TOP OF PUMP @ 40' SLM ). SET D&D PACKOFF ASSEMBLY, 5' SPACER, AND STINGER ASSEMBLY (94 3/4" OAL) AND SET ONTOP OF PUMP @ 40' SLM. TEST TBG. TO 1000 PSI FOR 10 MIN. (HELD SOLID ). SET 4 1/2 SLIP 04/22/06. Ran ESP and associated completion. - - • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. __ Date: 5/3/2006 Time: 14 00 35 e: 1 Yag Field: Kuparuk River Unit _ Co-ordiuate(NE) Reference: Well: 1 J-152, True North Site: Kuparuk 1J Pad Veilical (TVD) Refer ence: 1J-152L1: 109A Well: 1J-152 Section (VS) Reference: Well (O:OON,0.OOE,180.OOAzi) ~!V'ellpath: 1J-152L1 Survey Calculation M ethod: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre ~ A Sj ys Datum: Mean Sea Level Geomagnetic Model: bggm2005 li Well: 1 J-152 Slot Name: Well Position: +N/-S 83.97 ft Northing : 5946002.32 ft t Latitude: 70 15 47.084 N +E/-W -163.96 ft Easting : 558625.36 ft . Longitude: 149 31 33.778 W ': Position Uncertainty: 0.00 ft I, Wellpath: 1J-152L1 Drilled From: 1J-152P61 500292329860 Tie-on Depth: 5720.63 ft ~ Current Datum: 1 J-152L1: Height 109.00 ft Above System Datum: Mean Sea Level i j Magnetic Data: 3/10/2006 Declination: 24.16 deg Field Strength: 57565 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 _ - __- - - _ 0.00 - 0.00 _ 180.00 Survey Program for Definitive Wellpath Date: 5/3/2006 Validated: N o Version: 2 Actual From To Survey Toolcode Tool Name ft ft 90.00 537.00 1J-152P61 gyro (90.00- 537.00) CB-GYRO-SS Camera based gyro single shot 656.75 5720.63 1J-152PB1 (656.75-760 5.55) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5747.00 13365.44 1J-152L1 (5747.00-13365.44) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ____ ~~ID Incl Azim 'I'VD SysTVD N/S E/W (VTapN MapE Tool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 __ 28.00 ___ -81.00 0.00 0.00 5946002.32 558625.36 TIE LINE 90.00 0.31 153.79 90.00 -19.00 -0.15 0.07 5946002.17 558625.44 CB-GYRO-SS 169.00 0.33 240.18 169.00 60.00 -0.46 -0.03 5946001.86 558625.33 CB-GYRO-SS ~, 257.00 0.37 215.61 257.00 148.00 -0.81 -0.41 5946001.50 558624.95 CB-GYRO-SS 353.00 0.61 342.02 353.00 244.00 -0.58 -0.75 5946001.74 558624.61 CB-GYRO-SS 445.00 2.63 346.08 444.95 335.95 1.94 -1.41 5946004.25 558623.93 CB-GYRO-SS 537.00 4.04 349.64 536.80 427.80 7.17 -2.50 5946009.47 558622.80 CB-GYRO-SS 656.75 7.14 348.99 655.96 546.96 18.63 -4.68 5946020.91 558620.53 MWD+IFR-AK-CAZ-SC ~', j 747.98 11.14 348.52 746.02 637.02 32.84 -7.52 5946035.10 558617.58 MWD+IFR-AK-CAZ-SC ''j 839.68 13.86 349.80 835.53 726.53 52.33 -11.23 5946054.56 558613.72 MWD+IFR-AK-CAZ-SC 931.01 14.42 353.74 924.10 815.10 74.40 -14.41 5946076.60 558610.38 MWD+IFR-AK-CAZ-SC it 1020.87 16.90 354.31 1010.62 901.62 98.53 -16.92 5946100.70 558607.67 MWD+IFR-AK-CAZ-SC 1120.48 20.55 357.30 1104.94 995.94 130.41 -19.18 5946132.56 558605.17 MWD+IFR-AK-CAZ-SC 1213.13 22.43 356.92 1191.14 1082.14 164.31 -20.90 5946166.44 558603.19 MWD+IFR-AK-CAZ-SC ~ 1273.52 24.12 356.30 ~ 1246.62 1137.62 188.13 -22.31 5946190.25 558601.59 MWD+IFR-AK-CAZ-SC ~ 1306.74 26.79 355.67 1276.61 1167.61 202.37 -23.32 5946204.48 558600.47 MWD+IFR-AK-CAZ-SC 1397.20 33.70 353.74 1354.71 1245.71 247.70 -27.60 5946249.77 558595.84 MWD+IFR-AK-CAZ-SC 1491.41 39.81 355.12 1430.16 1321.16 303.78 -33.02 5946305.80 558589.98 MWD+IFR-AK-CAZ-SC 1584.09 46.04 357.97 1498.00 1389.00 366.75 -36.73 5946368.73 558585.78 MWD+IFR-AK-CAZ-SC 1677.37 44.16 357.94 1563.84 1454.84 432.77 -39.09 5946434.74 558582.91 MWD+IFR-AK-CAZ-SC 1769.27 43.33 359.13 1630.23 1521.23 496.29 -40.71 5946498.23 558580.79 MWD+IFR-AK-CAZ-SC j 1859.90 45.61 356.18 1694.91 1585.91 559.71 -43.34 5946561.62 558577.66 MWD+IFR-AK-CAZ-SC 1952.12 49.11 352.59 1757.38 1648.38 627.19 -50.04 5946629.04 558570.44 MWD+IFR-AK-CAZ-SC ', 2043.67 52.60 342.96 1815.24 1706.24 696.39 -65.18 5946698.11 558554.76 MWD+IFR-AK-CAZ-SC ', 2136.92 55.91 333.37 1869.79 1760.79 766.45 -93.40 5946767.94 558526.01 MWD+IFR-AK-CAZ-SC ', 2229.42 57.89 326.70 1920.35 1811.35 833.49 -132.11 5946834.68 558486.78 MWD+IFR-AK-CAZ-SC ~ ', 2323.46 61.30 323.86 1967.94 1858.94 900.11 -178.32 5946900.93 558440.06 MWD+IFR-AK-CAZ-SC 'i 2415.35 59.74 326.15 2013.17 1904.17 965.63 -224.20 5946966.08 558393.67 MWD+IFR-AK-CAZ-SC ', • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 5/3/2006 1'Fme: 14 :00:35 Yage: 2 Field: Ku paruk River Unit Co-ord inate(NE) Re ference: Well: 1J-152, True North Site: Ku paruk 1J Pad Vertica l(TVD) Refe rence: 1J-15 2L1: 109.0 - Well: 1J-152 Section (VS) Refere nce: Well ( O.OON,O.OOE, 180.OOAzi) Wetlpath: 1J-152L1 Survey Cakcula tion Alethod: Minimum Curvature Db: Oracle Survev MD Incl Azim 7ti'D Svs "ND N/S E/W b1apN IVIapE Tool ft deg deg ft ft ft ft ft, ft 2507.53 ~ 61.17 322.16 2058. 63 1949. 63 1030.60 271 .16 5947030 .68 558346.21 MWD+IFR-AK-CAZ-SC ' 2600.04 57.97 321.79 2105. 48 1996. 48 1093.43 -320 .29 5947093 .12 558296.60 MWD+IFR-AK-CAZ-SC ~, 2694.14 58.26 320.11 2155. 19 2046. 19 1155.48 -370 .62 5947154 .77 558245.79 MWD+IFR-AK-CAZ-SC ', 2737.89 57.29 318.61 2178. 52 2069. 52 1183.56 -394 .72 5947182 .66 558221.47 MWD+IFR-AK-CAZ-SC i 2824.65 56.33 316.70 2226. 02 2117. 02 1237.23 -443 .62 5947235 .94 558172.16 MWD+IFR-AK-CAZ-SC 2917.67 56,95 310.44 2277. 20 2168. 20 1290.72 -499 .88 5947288 .99 558115.50 MWD+IFR-AK-CAZ-SC 3010.82 58.11 305.21 2327. 23 2218. 23 1338.87 -561 .93 5947336 .65 558053.07 MWD+IFR-AK-CAZ-SC 3106.49 58.00 297.13 2377. 91 2268. 91 1380.84 -631 .30 5947378 .07 557983.39 MWD+IFR-AK-CAZ-SC ! 3199.84 57.91 291.80 2427. 47 2318. 47 1413.59 -703 .28 5947410 .25 557911.16 MWD+IFR-AK-CAZ-SC 3293.54 57.09 284.95 2477. 86 2368. 86 1438.50 -778 .20 5947434 .58 557836.06 MWD+IFR-AK-CAZ-SC 3386.38 56.42 278.35 2528. 79 2419. 79 1454.18 -854 .18 5947449 .66 557759.97 MWD+IFR-AK-CAZ-SC I 'I 3480.31 57.70 271.98 2579. 90 2470. 90 1461.24 -932 .62 5947456 .11 557681.48 MWD+IFR-AK-CAZ-SC II 3573.11 57.79 264.56 2629. 48 2520. 48 1458.87 -1010 .98 5947453 .13 557603.15 MWD+IFR-AK-CAZ-SC !, 3666.73 56.46 257.70 2680. 34 2571. 34 1446.79 -1088 .60 5947440 .45 557525.64 MWD+IFR-AK-CAZ-SC 3760.80 55.63 251.72 2732. 91 2623. 91 1426.25 -1163 .81 5947419 .33 557450.59 MWD+IFR-AK-CAZ-SC 3853.77 55.26 245.94 2785. 68 2676. 68 1398.63 -1235 .17 5947391 .15 557379.46 MWD+IFR-AK-CAZ-SC 3945.47 53.52 240.08 2839. 10 2730. 10 1364.85 -1301 .57 5947356 .87 557313.33 MWD+IFR-AK-CAZ-SC 4039.70 55.93 231.18 2893. 59 2784. 59 1321.43 -1364 .90 5947312 .95 557250.34 MWD+IFR-AK-CAZ-SC ', 4131.77 57.12 225.10 2944. 40 2835. 40 1270.20 -1422 .04 5947261 .29 557193.61 MWD+IFR-AK-CAZ-SC ', I 4225.31 58.72 218.73 2994. 12 2885. 12 1211.24 -1474 .91 5947201 .93 557141.20 MWD+IFR-AK-CAZ-SC ; I~ 4318.68 62.42 211.13 3040. 04 2931. 04 1144.60 -1521 .34 5947134 .93 557095.31 MWD+IFR-AK-CAZ-SC 'I ~, 4412.45 I 62.54 205.36 3083. 39 2974. 39 1071.39 -1560 .66 5947061 .42 557056.55 MWD+IFR-AK-CAZ-SC ! 4505.47 65.67 199.24 3124. 04 3015. 04 994.00 -1592 .34 5946983 .80 557025.48 MWD+IFR-AK-CAZ-SC !I 4599.02 64.31 198.33 3163. 59 3054. 59 913.74 -1619 .64 5946903 .34 556998.81 MWD+IFR-AK-CAZ-SC 4693.03 65.96 193.22 3203. 14 3094. 14 831.69 -1642 .79 5946821 .12 556976.30 MWD+IFR-AK-CAZ-SC 4784.50 65.62 191.43 3240. 66 3131. 66 750.20 -1660 .60 5946739 .49 556959.13 MWD+IFR-AK-CAZ-SC 4879.26 64.36 190.69 3280. 72 3171. 72 665.92 -1677 .08 5946655 .10 556943.31 MWD+IFR-AK-CAZ-SC 4974.57 67.36 187.23 3319. 70 3210. 70 580.03 -1690. 59 5946569 .11 556930.47 MWD+IFR-AK-CAZ-SC ! !, 5068.20 69.45 185.25 3354. 16 3245. 16 493.49 -1700 .04 5946482 .52 556921.69 MWD+IFR-AK-CAZ-SC 5161.20 72.44 182.54 3384. 53 3275. 53 405.81 -1705 .99 5946394 .80 556916.43 MWD+IFR-AK-CAZ-SC !' 5254.29 77.35 182.62 3408. 78 3299. 78 316.06 -1710 .04 5946305 .02 556913.08 MWD+IFR-AK-CAZ-SC 5347.73 76.10 181.87 3430. 23 3321. 23 225.19 -1713 .60 5946214 .14 556910.22 MWD+IFR-AK-CAZ-SC ', 5441.59 77.86 182.13 3451. 38 3342. 38 133.80 -1716 .79 5946122 .74 556907.74 MWD+IFR-AK-CAZ-SC '' 5534.45 79.40 182.58 3469. 69 3360. 69 42.84 -1720 .53 5946031 .76 556904.71 MWD+IFR-AK-CAZ-SC I, 5627.15 80.41 182.99 3485. 93 3376. 93 -48.31 -1724 .97 5945940 .58 556900.99 MWD+IFR-AK-CAZ-SC ', 5720.63 79.48 181.58 3502. 26 3393. 26 -140.28 -1728 .64 5945848 .60 556898.03 MWD+IFR-AK-CAZ-SC 5747.00 79.52 182.01 3507. 06 3398. 06 -166.20 -1729 .45 5945822 .68 556897.42 MWD+IFR-AK-CAZ-SC I 5848.03 90.38 182.50 3515. 94 3406. 94 -266.61 -1733. 41 5945722 .25 556894.25 MWD+IFR-AK-CAZ-SC li 5941.66 91.00 182.94 3514. 81 3405. 81 -360.12 -1737. 85 5945628 .71 556890.53 MWD+IFR-AK-CAZ-SC 6035.88 93.34 183.39 3511. 25 3402. 25 -454.13 -1743. 05 5945534 .68 556886.07 MWD+IFR-AK-CAZ-SC !I 6128.81 91.37 181.17 3507. 43 3398. 43 -546.89 -1746. 74 5945441 .90 556883.10 MWD+IFR-AK-CAZ-SC ! 6222.52 91.93 179.30 3504. 73 3395. 73 -640.56 -1747. 13 5945348 .24 556883.44 MWD+IFR-AK-CAZ-SC ~~ 6315.83 89.70 177.05 3503. 40 3394. 40 -733.80 -1744 .15 5945255 .03 556887.14 MWD+IFR-AK-CAZ-SC 6409.74 92.54 179.71 3501. 57 3392. 57 -827.64 -1741 .50 5945161 .23 556890.52 MWD+IFR-AK-CAZ-SC ' 6502.99 94.46 179.81 3495. 87 3386. 87 -920.71 -1741 .11 5945068 .17 556891.64 MWD+IFR-AK-CAZ-SC ', 6597.44 92.60 178.01 3490. 06 3381. 06 -1014.95 -1739 .32 5944973 .95 556894.17 MWD+IFR-AK-CAZ-SC I 6689.21 89.00 182.34 3488. 78 3379. 78 -1106.68 -1739 .60 5944882 .24 556894.60 MWD+IFR-AK-CAZ-SC !, 6782.69 88.84 181.63 3490. 54 3381. 54 -1200.08 -1742 .83 5944788 .82 556892.09 MWD+IFR-AK-CAZ-SC I 6877.58 84.61 181.96 3495. 96 3386. 96 -1294.75 -1745 .80 5944694 .14 556889.86 MWD+IFR-AK-CAZ-SC I 6971.04 84.63 180.31 3504. 72 3395. 72 -1387.78 -1747. 64 5944601 .11 556888.74 I MWD+IFR-AK-CAZ-SC 7065.38 88.10 180.75 3510. 70 3401. 70 -1481.91 -1748. 52 5944506 .98 556888.60 MWD+IFR-AK-CAZ-SC I 7158.98 89.95 182.97 3512. 29 3403. 29 -1575.44 -1751. 55 5944413 .45 556886.29 MWD+IFR-AK-CAZ-SC • Halliburton Company; Survey Report Compam: ConocoPhillips Alaska Inc. Date: 5/3/2006 Tiroe: 14 :00:35 Page: 3 Field: Ku paruk River Unit Co-ordinate(NE) Reference: Welh 1 J-152, True North Site: Ku paruk 1J Pad Vertical (TVD) Reference: 1J-1521.1: 109 .0 Well: 1J- 152 Section (VS) Reference: Well (O.OON,O. OOE, 180.OOAzi) Wellpath: 1J-152t_1 Survey Calculation Method: Minimum Curv ature Db: Oracle Sur~ev - __ 117D Incl Azim TVD Sys TVll N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft ___ 7249.90 90. 49 181.76 3511 .95 3402. 95 -1666. 28 -1755 .30 5944322.59 556883. 25 MWD+IFR-AK-CAZ-SC I, 7345.89 91. 43 180.96 3510 .34 3401. 34 -1762. 22 -1757 .58 5944226.64 556881. 72 MWD+IFR-AK-CAZ-SC '. 7439.04 93. 03 180.53 3506 .71 3397. 71 -1855. 29 -1758 .79 5944133.57 556881. 23 MWD+IFR-AK-CAZ-SC 7532.14 93. 72 179.78 3501 .23 3392. 23 -1948. 23 -1759 .04 5944040.64 556881. 71 MWD+IFR-AK-CAZ-SC '. 7624.83 93. 03 179.25 3495 .78 3386. 78 -2040. 75 -1758 .26 5943948.13 556883. 21 MWD+IFR-AK-CAZ-SC 7717.53 92. 54 180.24 3491 .27 3382. 27 -2133. 34 -1757 .85 5943855.56 556884. 34 MWD+IFR-AK-CAZ-SC 7811.55 92. 79 181.42 3486 .90 3377. 90 -2227. 25 -1759 .21 5943761.66 556883. 71 MWD+IFR-AK-CAZ-SC 7903.26 91. 31 181.28 3483 .62 3374. 62 -2318. 87 -1761 .37 5943670.03 556882. 27 MWD+IFR-AK-CAZ-SC i 7996.10 89. 94 180.86 3482 .61 3373. 61 -2411. 69 -1763 .10 5943577.21 556881. 26 MWD+IFR-AK-CAZ-SC 8088.94 91. 24 176.87 3481 .65 3372. 65 -2504. 48 -1761 .26 5943484.44 556883. 82 MWD+IFR-AK-CAZ-SC 8184.10 91. 74 175.65 3479 .18 3370. 18 -2599. 41 -1755 .06 5943389.58 556890. 76 MWD+IFR-AK-CAZ-SC -. 8277.64 91. 62 177.53 3476 .43 3367 .43 -2692. 74 -1749 .50 5943296.30 556897. 05 MWD+IFR-AK-CAZ-SC '. 8370.32 89. 70 178.63 3475 .36 3366. 36 -2785. 35 -1746 .39 5943203.72 556900. 87 MWD+IFR-AK-CAZ-SC 8463.84 86. 06 179.99 3478 .82 3369. 82 -2878. 79 -1745 .27 5943110.31 556902. 73 MWD+IFR-AK-CAZ-SC 8556.31 89. 64 183.03 3482 .29 3373. 29 -2971. 13 -1747 .70 5943017.96 556901. 01 MWD+IFR-AK-CAZ-SC ', I 8650.01 91. 06 184.09 3481 .72 3372. 72 -3064. 65 -1753 .52 5942924.41 556895. 92 MWD+IFR-AK-CAZ-SC '. 8745.29 92. 24 181.76 3478 .98 3369. 98 -3159. 75 -1758 .38 5942829.28 556891. 80 MWD+IFR-AK-CAZ-SC 8837.96 91. 73 181.56 3475 .77 3366. 77 -3252. 33 -1761 .07 5942736.69 556889. 84 MWD+IFR-AK-CAZ-SC 8931.25 91. 12 180.11 3473 .45 3364. 45 -3345. 58 -1762 .42 5942643.44 556889. 21 MWD+IFR-AK-CAZ-SC 9025.65 90. 37 182.29 3472 .22 3363. 22 -3439. 94 -1764 .40 5942549.08 556887. 96 MWD+IFR-AK-CAZ-SC 9119.67 90. 50 181.42 3471 .51 3362. 51 -3533. 91 -1767 .44 5942455.10 556885. 65 MWD+IFR-AK-CAZ-SC '. 9212.61 90. 07 180.32 3471 .04 3362. 04 -3626. 84 -1768 .86 5942362.17 556884. 96 MWD+IFR-AK-CAZ-SC ' 9306.72 88. 47 177.58 3472 .24 3363. 24 -3720. 91 -1767 .13 5942268.12 556887. 42 MWD+IFR-AK-CAZ-SC 9400.40 90. 43 179.21 3473 .14 3364. 14 -3814. 54 -1764 .51 5942174.52 556890. 77 MWD+IFR-AK-CAZ-SC !. 9494.13 91. 55 177.32 3471 .52 3362. 52 -3908. 21 -1761 .67 5942080.89 556894. 34 MWD+IFR-AK-CAZ-SC 9583.35 90. 63 176.94 3469 .83 3360. 83 -3997. 30 -1757 .20 5941991.84 556899. 50 MWD+IFR-AK-CAZ-SC !. 9667.73 89. 95 179.53 3469 .40 3360. 40 -4081. 63 -1754 .61 5941907.54 556902. 75 MWD+IFR-AK-CAZ-SC '', 9765.22 91. 80 179.24 3467 .91 3358. 91 -4179. 10 -1753 .56 5941810.10 556904. 56 MWD+IFR-AK-CAZ-SC 9856.25 92. 72 178.56 3464 .32 3355 .32 -4270. 04 -1751 .81 5941719.18 556907. 01 MWD+IFR-AK-CAZ-SC I. 9946.09 93. 03 177.51 3459 .81 3350. 81 -4359. 71 -1748 .74 5941629.54 556910. 79 MWD+IFR-AK-CAZ-SC 10037.75 91. 31 179.28 3456 .34 3347. 34 -4451. 26 -1746 .17 5941538.02 556914. 06 MWD+IFR-AK-CAZ-SC 10125.29 90. 38 178.03 3455 .05 3346. 05 -4538. 77 -1744 .12 5941450.55 556916. 80 MWD+IFR-AK-CAZ-SC 10219.75 87. 60 179.58 3456 .72 3347. 72 -4633. 18 -1742 .15 5941356.16 556919. 50 MWD+IFR-AK-CAZ-SC 10305.62 90. 01 180.18 3458 .51 3349. 51 -4719. 03 -1741 .97 5941270.33 556920. 35 MWD+IFR-AK-CAZ-SC 10398.75 90. 94 179.81 3457 .74 3348. 74 -4812. 15 -1741 .96 5941177.22 556921. 08 MWD+IFR-AK-CAZ-SC i 10490.03 89. 58 179.73 3457 .32 3348. 32 -4903. 43 -1741 .59 5941085.95 556922. 16 MWD+IFR-AK-CAZ-SC 10580.40 86. 74 180.00 3460 .22 3351. 22 -4993. 74 -1741 .38 5940995.65 556923. 08 MWD+IFR-AK-CAZ-SC 10671.87 89. 39 180.83 3463 .31 3354. 31 -5085. 15 -1742 .04 5940904.25 556923. 13 MWD+IFR-AK-CAZ-SC ~ 10761.85 92. 23 182.94 3462 .04 3353. 04 -5175. 06 -1745 .00 5940814.33 556920. 87 MWD+IFR-AK-CAZ-SC '! 10853.97 91. 54 182.29 3459 .01 3350 .01 -5267. 03 -1749 .20 5940722.34 556917. 38 MWD+IFR-AK-CAZ-SC it 10943.70 92. 36 180.67 3455 .96 3346. 96 -5356. 67 -1751 .52 5940632.69 556915. 77 MWD+IFR-AK-CAZ-SC 11035.30 91. 55 179.32 3452 .83 3343. 83 -5448. 22 -1751 .51 5940541.16 556916. 49 MWD+IFR-AK-CAZ-SC 11124.89 92. 10 178.94 3449 .98 3340 .98 -5537. 75 -1750 .15 5940451.64 556918. 54 MWD+IFR-AK-CAZ-SC 11216.43 91. 37 177.22 3447 .21 3338. 21 -5629. 19 -1747 .09 5940360.24 556922. 32 MWD+IFR-AK-CAZ-SC 11310.29 90. 44 177.09 3445 .72 3336. 72 -5722. 92 -1742 .43 5940266.55 556927. 71 MWD+IFR-AK-CAZ-SC II 11403.36 92. 11 176.18 3443 .65 3334. 65 -5815. 81 -1736 .97 5940173.72 556933. 89 MWD+IFR-AK-CAZ-SC 11497.55 91. 43 178.69 3440 .74 3331. 74 -5909. 85 -1732 .75 5940079.73 556938. 84 MWD+IFR-AK-CAZ-SC '~ 11588.80 91. 06 177.04 3438 .76 3329. 76 -6001. 01 -1729 .36 5939988.60 556942. 94 MWD+IFR-AK-CAZ-SC it 11683.96 92. 79 179.54 3435 .56 3326. 56 -6096. 06 -1726 .52 5939893.58 556946. 52 MWD+IFR-AK-CAZ-SC 11776.55 92. 10 179.30 3431 .61 3322. 61 -6188. 56 -1725 .58 5939801.10 556948. 18 MWD+IFR-AK-CAZ-SC ', ~, 11870.07 92. 18 184.89 3428 .12 3319. 12 -6281. 92 -1729 .00 5939707.73 556945. 49 MWD+IFR-AK-CAZ-SC ' 11960.89 90. 68 185.33 3425 .85 3316 .85 -6372. 35 -1737 .08 5939617.25 556938. 11 MWD+IFR-AK-CAZ-SC 12056.53 90. 19 184.87 3425 .13 3316 .13 -6467. 61 -1745 .58 5939521.94 556930. 35 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. .Date: 5/3/2006 Time: 14:00:35 Page: d Field: Ku paruk River Unit Co-ord inate(NE) Re ference: Well: 1J-152, TrueNorth I Site: Ku paruk 1J Pad Vertical (TVD) Refe rence: 1J -152L1: 109.0 WeIL• 1J-152 Section (V5) Referen ce: Well (O.OON,O.OOE,1 80.OOAzi) W'ellpath: 1 J-152L1 Survey Calculation 1ltethod: Mi nimum Curvature llb: Oracle tiurvev __ Mb lncl __ Azim TVD Sys TVD N/S E/W ~lapN h1apF, 'Tool ' ft deg deg ft ft ft ft ft ft 12150.85 90.32 181.73 3424.71 3315.71 -6561.76 -1751.01 5939427.76 556925.66 MWD+IFR-AK-CAZ-SC it 12243.55 88.16 182.13 3425.93 3316.93 -6654.39 -1754.13 5939335.11 556923.26 MWD+IFR-AK-CAZ-SC j I 12337.36 88.47 180.52 3428.69 3319.69 -6748.13 -1756.30 5939241.37 556921.82 MWD+IFR-AK-CAZ-SC li 12430.14 90.57 180.83 3429.47 3320.47 -6840.90 -1757.39 5939148.61 556921.45 MWD+IFR-AK-CAZ-SC ~ 12524.54 90.81 180.24 3428.33 3319.33 -6935.29 -1758.28 5939054.22 556921.30 MWD+IFR-AK-CAZ-SC ! 12618.17 90.38 179.06 3427.36 3318.36 -7028.91 -1757.70 5938960.62 556922.60 MWD+IFR-AK-CAZ-SC 12711.71 90.94 178.50 3426.28 3317.28 -7122.42 -1755.71 5938867.13 556925.32 MWD+IFR-AK-CAZ-SC '' 12805.10 90.14 176.80 3425.40 3316.40 -7215.72 -1751.88 5938773.87 556929.88 MWD+IFR-AK-CAZ-SC 12898.87 90.81 176.42 3424.63 3315.63 -7309.32 -1746.34 5938680.32 556936.15 MWD+IFR-AK-CAZ-SC '. 12992.50 90.31 175.03 3423.71 3314.71 -7402.69 -1739.36 5938587.03 556943.85 MWD+IFR-AK-CAZ-SC '' 13085.95 89.70 173.88 3423.70 3314.70 -7495.70 -1730.33 5938494.10 556953.61 MWD+IFR-AK-CAZ-SC ' 13179.46 89.64 173.01 3424.24 3315.24 -7588.59 -1719.66 5938401.30 556965.00 MWD+IFR-AK-CAZ-SC i 13272.38 89.52 171.40 3424.92 3315.92 -7680.65 -1707.05 5938309.35 556978.32 MWD+IFR-AK-CAZ-SC 13365.44 90.87 172.05 3424.61 3315.61 -7772.74 -1693.66 5938217.38 556992.43 MWD+IFR-AK-CAZ-SC ' 13408.00 90.87 172.05 3423.96 3314.96 -7814.88 -1687.77 5938175.28 556998.64 PROJECTED to TD .~ ' ~"(~) r a ~ FRANK H. MURKOWSKI ~,~ _ ;~ ~ , ~ ~ ,GOVERNOR ~~ Ou.I oils/ ~ 333 W. T" AVENUE S UITE 100 CO1~T3ERQA~`IO1Q COMI-IISSIOI~T ~~ ANCHORAGE, ALASKA 99501-3539 Randy Thomas ~ PHONE (907) 279-1433 Greater Kuparuk Area Drilling Team Leader FAx (so7) 27s-7542 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River, 1J-152L1 ConocoPhillips Alaska, Inc. Permit No: 206-017 Surface Location: 2191' FSL, 2582' FEL, Sec. 35, Tl 1N, R10E, UM Bottomhole Location: 351' FNL, 955' FWL, Sec. 11, T10N, R10E Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager) . SincerelyQ r Cathy P. Foerster 5~-- Commissioner DATED this3~ day of January, 2006 cc: Department of Fish & 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 Ancbora~e 1a. Type of Work: DrillQ Redrill 1b. Current Well Class: Exploratory Development Oil r r..3t,r~julultiple Zone ^ Re-entry ^ --~e./ Stratigraphic Test ^ Service .`~ . 1j i ~ c `' Development Gas ^ ~ ~ ~~`~gle Zone ^/ 2. Operator Name: 5. Bond: ~ Blanket Single Well 11. Well Name and Number: ConocoPhillipsAlaska, Inc. Bond No. 59-52-180 1J-152L1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 13245' ~ TVD: 3423' ~ Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2191' FSL, 2582' FEL, Sec. 35, T11 N, R10E, UM ~ ADL 25661 & 25662 ~ West Sak Oil Pool ~ ' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2092' FSL, 962' FWL, Sec. 35, T11 N, R10E ~ ALK 471 & 2177 3/26/2006 Total Depth: 9. Acres in Property: 14. Distance to 351' FNL, 955' FWL, Sec. 11, T10N, R10E ~ 2560 Nearest Property: <3 miles ` 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 558625 ~ y- 5946002 ' Zone- 4 (Height above GL): 28' RKB / 108' AMSL Well within Pool: 1J-154L1 , 1211' @ 12E 16. Deviated wells: Kickoff depth: 5518 ~ ft. 17. Maximum Anticipated Pressures in psig (see 20 a4C 25.035) Maximum Hole Angle: 91.8° deg Downhole: 1576 psig ' Surface: 1191 psig ~ 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 2825' 28' 28' 2825' 2204' 530 sx AS Lite, 180 sx DeepCrete 9-7/8" 7-5/8" 29.7# L-80 BTCM 6353' 28' 28' 6353' 3639' 360 sx DeepCrete 6.75" 4.5" 12.6# L-80 IBTM 772T 5518' 3502' 13245' ' 3423' ~ slotted liner. 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (tt): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner - refer to 1 F-01A Perforation Depth MD (ft): r,, Perforation Depth TVD (ft): II~W 20. Attachments: Filing Fee ' BOP Sketch ^ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ( ~ Phone -~~~ ~~ ~ 3o Date t (Z 3 X06 -~ ~ P n All Dra e Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ~-~/(c3 "~,~ / ~ 50- ~~~`! ~ ~~~L1 `~ ^t~LJ te: ~ ~ for other requirements Conditions of approval : ~~O©p9l ~P.~s~ m.~ 1C1.1~;~ ~ Samples regLired Yes No Q Mud log required Yes ^ No Hydrogen sulfide measures Yes ^ No ~ Directional survey required Yes ~ No ^ Other: APPROVED BY Approved by: THE COMMISSION Date: f ~ 3 ~ ~L~ ~~ ~E~EIVE ~aN 2 6 Zot ~c3S~8 ~l~ $t ~8S ~0~~. ~Qf1'tf: l Form 10-401 Revised 06/2004 ~-~' ~ ~ -~ ~ 1 \t ~ Submit in Duplicate • Permit It -West Sak Well #1J-152 L1 ~~`~~ ~., +~i Application for Permit to Drill Document ~,;; ftt~WelI r~o.xin,~~~ Welf V414~ Table of Contents 1. Well Name .....................................................................................................................2 Requirements of 20 AAC 25.005 (f) .................................................................................................... 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)(70) ............................................................................................. 5 11. Seabed Condition Analysis ........................................................................................ 5 Requirements of 20 AAC 25.005 (c)(7 ~) ............................................................................................. 5 12. Evidence of Bonding .................................................................................................. 5 .................. Requirements of 20 AAC 25.005 (c)(12) ................................................ ........................... 5 (not done) 1J-152L1 PERMlT IT Page 1 of 6 Printed: 23-Jan-06 App~n for Permit to Drill, Well 1J-152 L1 Revision No.O Saved: 23-Jan-06 ~~ r~~ f~ ! • App~n for Permit to Drill, Well 1J-152 L1 Revision No.O Saved: 23-Jan-45 13. Proposed Drilling Program .........................................................................................5 Requirements of 20 AAC 25.005 (c)(93) ............................................................................................. 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 we//must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a we// with multiple we11 branches, each branch must Simi/ar/y be identified by a unique name and API number by adding a suffix to the name designated far the well by the operator and to the number assigned to the wet/ by the commission. The well for which this Application is submitted will be designated as iJ-152 Ll. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item a/ready an file with the commission and identified in the app/ication: (2) a p/at identifying the property and the property's owners and showing (AJthe coordinates of the proposed /ocation of the we// at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed /ocation of the we// at the surface, referenced to the state plane coordinate system for this state as maintained by the Nationa/ Geodetic Survey in the Nationa/ Oceanic and Atmospheric Administration,- (C) the proposed depth of the we// at the top of each objective formation and at Iota/ depth; Location at Surface 2,191' FSL, 2,582' FEL, Section 35, T11N, R10E ASPZone 4NAD27Coordinates RKB Elevation 108.0' AMSL Northings; 5,946,002 Eastings: 558,625 Pad Elevation 80.0' AMSL Location at Top of Productive Interval 2,092' FSL, 962' FWL, Section 35, T11N, R10E West Sak "B" Sand ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 5,518 Northings: 5,945,889 Eastings.• 556,890 Total l/ertical De th, RKB: 3,502 Total vertical De th, SS.• 3,393 Location at Total De th 351' FNL 955' FWL, Section 11, T10N R10E - ASPZone 4 NAD 27 Coordinates Measured De th, RKB: 13, 245 ' Northings: 5,938,168 Eastings- 556,952 Total Vertical De th, RKB: 3,423 Total ~ertica/ Depth, SS.' 3,314 and (D) other information required by 20 AAC Z5.050(b),~ (not done) 1J-152L1 PERMIT !T Page 2 of 6 Printed: 23-Jan-06 t Ap~n for Permit to Drill, Well 1J-152 L1 Revision No.O Saved: 23-Jan-06 Requirements of 20 AAC 25.050(b) Ifa we/1 is to be intentional/y deviated, the application For a Permit to Ori// (Form 10-401) must (1) inc/ude a p/at, drawn to a suitable sca/e, showing the path of the proposed we//bore, including a//adjacent we/!bores within 200 Feet of any portion of the proposed we/% Please see Attachment 1: Directional Plan and (2) For a// we%(s within 200 feet of the proposed wel/bore (A) Jist the names of the operators of those we//s, to the extent that those names are known or discoverab/e in pub/ic records, and show that each named operator has been furnished a copy of the app/ication 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 25.005(c)(3) An app/ication for a Permit to Ori/l must be accompanied by each of the following items, except for an item a/realy on file with the. commission and identified In the application.~ (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, ZO AAC 25.036, or 20 AAC 25.037, as app/icable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well iJ-152 Ll. 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 for a Permit to Ori/l must be accompanied by each ofthe following items, except for an item a/ready on file with the comm/ssion and identified in the app/ication: (4) information on drilling hazards, inc/udinq (AJ the maximum downho% pressure that may be 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 ~~B" sand formation is 1,191 psi, calculated thusly: MPSP =(3,502 ft TVD)(0.45 - 0.11 psi/ft) =1,191 psi (BJ data on potential gas zones,- The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of ho% problems such as abnorma//y geo pressured strata, lost circulation zones, and zones that have a propensity for differentia/ sticking;- Please see Attachment 2: 1J-152 Ll 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//must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the app/ication.- (5) adescription of the procedure For conducting formation integrity tests, as required under 20 AAC 25.030(t); The parent wellbore, 1J-152, 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. ~~~ (not done) 1J-152L1 PERMIT tT Page 3 of 6 Printed: 23-Jan-06 • Ap~n for Permit to Drill, Well 1 J-152 L1 Revision No.O Saved: 23-Jan-46 6. Casing and Cementing Program Requirements of 20 AAC 25A05(c}(6) An application for a Permit to Dri//must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the app/ication: (6J a comp/ete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted 1ine~ pre- perforated liner, or screen to be instal/ed,- Casin and Cementin Pro ram Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD 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 4,270 5,618 / 3,520 9,888 / 3,632 Slotted- no cement Slotted Lateral (1J-152) 4-1/2 6-3/4" s sand .12.6 t-$0 IBTM .7,727 5,518) 3,502 13,245 / .3,423. slotted- no cement Slotted Lateral (iJ-152 L1) 4-1/2 6-3/4" D sand 12.6 L-80 IBTM 7,708 5,232/ 3,437 12,940 / 3,347 slotted- no cement Slotted Lateral (i1-152 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c}(7) An application for a Permit to DriJ/must be accompanied by each of the fol%wing items, except for an item a/ready on fi/e with the commission and identified in the application.• (7) a diagram and description of the diverter system as required by 20 AAC 25.03s, unless this requirement is waived by the commission under ZO AAC 25.035(hJ(2); No diverter system will be utilized during operations on 1J-152 Ll. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/ication for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on fi/e with the commission and identified in the app/icatioir. (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Density (ppg) 8.6 Plastic Viscostiy 15-25 (Ib/900 sf) Yield Point 18.28 (cP) HTHP Fluid loss (ml/30 min <4 0 200psi & . 150° Oil /Water 70 / 30 Ratio Electrical 650-900 Stability i 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. ~~ (nof done) 7J-152L1 PERMlT IT Page 4 of & ~"~ Printed: 23-Jan-06 ~~ ~~ • App~n for Permit to Drill, Well 1J-152 L1 Revision No.O Saved: 23-Jan-06 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Diil/ must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application.• (9) for an exp/oratory or stratigraphic test i•veli, a tabu/ation setting out the depths of predicted abnorma//y geo pressured strata as required by 20 AAC 2s.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(90) An app/ication for a Permit to Dii/l must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the app/icatio~~ • (X 0) for an erp/oratory or stratigraphic test wel% a seismic refraction or reflection ana/ysis as required by 20 AAC 25.061(aJ; 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 app/ication for a Permit to Dri//must be accampanied by each of the fo/%wing items, except for an item already on fi/e with the commission and identified in the app/ication: (YI) for awet/drilled from an offshore p/atform, mobile bottom-founded structure, jack-up rig, or floating dri//ing vess% an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(92) An app/ication for a Permit to Dri/l must be accampanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application: (12J evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met,' Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(93) An app/ication for a Permit to Dri/l must be accampanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the app/ication: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-152 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 5,518' MD / 3,502' TVD, the top of the B 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 B sand lateral at 13,245' MD / 3,423' 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. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. (not done) 7J-152L1 PERMIT IT Page 5 of 8 ~ ~ Printed:23-Jan-06 , a ? ~ r~ • Ap~n for Permit to Drill, Well 1 J-152 L1 Revision No.O Saved: 23-Jan-46 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 11. POOH and prepare to drill the "D" sand lateral 1J-152 L2. 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// mustc be accompanied by each of the following items, except for an item a/ready on fi/e with the commission and identified in the app/ication: (14) a genera/ description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the we/%; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J 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 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 WeII Schematic (nof done) 1J-152L1 PERM1717 Page fi of S ~ ~ ~ ~, , Printed: 23-Jan-08 ~.~' • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-152 -Slot 1J-152 1J-152 L1 Plan: 1J-152 L1 (wp05) Proposal Report 17 January, 2006 ~~ ~r~1in ~rvi+a~es C ~ NMN~ N C - min N ~ O O a0 ~ y f0 ~~ J y ~ Oa o AAm ~ o r ~ M ~ N ._-' ~ '~/ / _- o •- d ~ N N ~- ~ J Q !- NUmQ ~ m v' > » M N Vl N N • C C LM m N ~ J m 'a c - MAO fV E~ ~, S= ~ ~ ~ ~ / ' ~. ~ p ~ ~ ~ Y Y ~~ W o omM~ u.mFYFM~-»7x333 Q 2~n V. ~ ~ p : ~ H a~ h 3 L~ r J ~ lC ~ N O F- L OI IONMY1NOD iGNN V7 10NDD V71?h~pMAYINA W ~ ~ MO~f 1~ ~ W c G ~ ~ N ~I ~A. GC's O. L ~ 3 3~~ Y O - amdOd u~oui~ccuqi u7 ~ bmt+~i aD p)N~OND Ib`1Q u'~'i ~'nn NNMO V N N Z ~ N ~~ O ~ N ~ - _ ;`'' r" O O Y a O~ ~r .. .. 1 Q s L00000000000 „00000000000 ~ a OD V7N NAM ~ ~ aU ~ N N d ~ (~.~. d ~ Ny d~ ~ ~ ~ C~u°iicdot~m~i eNno~no ~~:°-~NNMMM ~M U OoDDO >oao Z ~ ~ ~o; p oa ' ~ Imo 4iG J a Z ~NM O NIO t~OD Oi ~~ N~~ NMM -. 3 : J a JQ in ~ Q. U N J ~ J .. ~ o ~ O C ZEN M (n ~ ~ ~ ~ a GM J LL ~~~ C ^ 3 ~ O W N Ur W c0 O O ~ ~ I' 3 N ~ H ~M Z I N `r' Z~ N O ~ ~ Q r ~ ~ ~ - m 2" 3 Q ~ ~ ~ ~ ~ ~ ~ ~ ~ I MMM ~ rn ~ ~ _ o o z H M 3 c v o M O ~ ~ I' _ J N o ~ "' ~~ °o M ~ ~ ~ _ J ~ p ~ ~ In ~ ~ m N F _ O _ 1~ ~ C p I O ~ ~ N .~c ~ (~ ~ ~ O ~\ Ud i ~ _ ~ N ~ C7 ~ ~ ~ ~: 0Y @~ O O ~ m ~ a ~ .~ i (O \ ~ , ; 1 ~ ~ O r- a~ n o ~ c a i i ~ _ ~~ ~ i ~ U S a - O ~ ~ ~ ~ ~ ~ O ° ~ ~i ~ 0~8 ~ ~ o ~ ~ i :~ ~ : c°h io Z ~ ~ i~~i '. ~~ ~ ~ \' --- p F- O ~ \ U ~ „ ` ~ \ ' N m ~ 1 m ~ _ ~ \ \ U J J `` ~ ~\ ~ \ 1 ` 00 ~ ~ ~ ` N ~ N \ ~ ' \ ~ O 4'S \: : :~ ~ O J ~ o~Q ~ 1!] ~ lL \ 1 r `~ . ~: ~ : N O ` :\ ' 1 ~: O N ~ ~~ ~ ~ ~ ~ O 0 O \~ " 2 0 "C ~ h \ H \ ~ \ \ N ~ d Y ~ C In H J o~ O O N o3( ~ o q~ r p~ °~! i 0 O ~ fl.~ v c7 ° 009 o i i ~ m ~ o j ~I ~I I ~. o O N +0 V ~ ~ i ~ i O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O N O ~ O O lA N ~ O In In O ~~!~ ~ 000 L1 e~;daQ O ~ ~e~~an anr~ O In M M O ~ ~ ~ O ~, U'J L1 : Top of Window - 2092ft FSL 8 962ft FW L -Sec 35 - T11 N - R tOE, 5518ft MD, 3502ft ND 0 1500 ~ °o, 1000 270° 500 - ` L1 : 8ttm of W indow - Dnll 30' Raihole, 5530ft MD, 3504ft TVD ~ `\ ~, ~ 184° 0 ~ .. , ~ .I7 5/8"~ - "~i -- ` 1 1 Project: Kuparuk River Unit Site: Kuparuk 1J Pad '1o 3/a°i Well: Plan 1J-152 Wellbore: 1J-152 L1 Plan: 1J-152 L1 (wp05) s- ConocoPhillips \ 33~ Alaska L1 : Build @ 5°/100ft , 5560ft MD, 3509ft TVD - ` L1 : Continue Geosteer in B-Sand, 6236ft MD, 3494ft TVD -' 182° ____, 1~0. 180° ~L1 : Sail @ 93.1°, 5784ft MD, 3518ft TVD IJ t ,:_ 1. t ? i , :~.1~05~ 180° 180° Drillers Target - defines a corridor with allowable deviation from plan of +/- 50fit wirhile in productian zone 3500 I I I -4000 ~ ~_ O O -4500 ~ 1J-152 (wp05) @ 9888' MDR,' - - _ - - - L O -5000 Z t 7 O N -5500 -soon 1J-152 L2 (wp05) - 12940'MD -6500 -~oo0 1J-152 L1 (wp05) @ 13245'MD ---- -7500 ~ -8000 1so° NfELLDETAILS: PIan1J-152 Ground Level: 81.00 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5946002.32 .558625.36 70°15'47.084N149`31'33.778W 1J-152 180° _ _ _ _ _ 1J-152 Lt T3 (wp05) 180° .~1J-152 L1 T4 (wp05~ i ~1st1° r M gnetic Norlh: 24.54° A~lagnetic Field Strength. 57578.6nT Dip Angle: 80.72° Date 11/23/2004 lelodel. BGGM2004 . ;~' A~~~£:7T~i Sp~trry Grilling Satrvicos CASING DETAILS 1J-1s2 a rs (typos No TVD MD Name Size 1 2204.00 2825.33 10 314" 10-3/4 2 3502.48 5517.94 7 5!8" 7-5/8 3 3423.0013244.76 4112" 4-112 4 1/2' L1 : BHL @ 351ft FNL & 955ft FW L -Sec 11 - T10N - R10E, 13245ft t°1D, 342 3ft1 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 500 1000 1500 2000 2500 ~-' ~ Hatliburton Energy Services t-~a~~rBUATON ~"~!~~~~~~$ Planning Report -Geographic -e. f~<~tik3 ~pe+'r!- Drfliing Saar~rices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB C~ 109.OOft (Doyon 141 (28+81 J) Project: Kuparuk River Unit MD Reference: Planned RKB Cu 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-152 Survey Calculation Method: Minimum Curvature Wellbore: 1J-152 L1 Design: 1J-152 L1 (wp05) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Leiiel Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well _ _ Plan 1J-152 -Slot 1J-152. - - ___ Well Position +N/y^ 0.00 ft Northing: 5,946,002.32ft +E/-W O.OOft Easting: 55$,1i25.36ft Position Uncertainty O.OOft Wellhead Elevation: ft Latitude: Longitude: Ground Level: 70° 15' 47.084" N 149° 31' 33.778" W 81.OOft - I Wellbore 1J-152 L1 ---- _ Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2004 11(23/2004 24.54 80.72 57,579 Design 1J-152 L1 (wp05 ) Audit Notes: Version: Phase: PLAN Tie On Depth: 5,517.93 I Vertical Section: Depth From (TYD) +N/-S +E/-W Direction I (ft) (ft) (ft) (°) 28.00 0.00 0.00 180.00 1/17/2006 9:38:23AM Page 2 of 8 COMPASS 2003.11 Baild 48 ~~~ r•' ~ Halliburton Energy Services HALLIBtJFlTORt C4C1!C~CC3~'i1~~1p5 Planning Report -Geographic - A{s;ka Dr! i~ 5e Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-152 Wellbore: 1J-152 L1 Design: 1J-152 L1 (wp05) ~~rry 1 ng rvfces Local Ca-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 TVD Reference: Planned RKB ~ 109.OOft (Doyon 141 (28+81)1 MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)1 North Reference: True Survey Calculation Method: Minimum Curvature Ptan Summary Measured Vertical Dogleg Build Turn Depth Inclination .Azimuth Depth +N(-S +E/-W Rate Rate Ra#e TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°1100ft) (°) 5,517.93 80.00 182.00 3,502.48 -99.63 -1,735.72 0.00 0.00 0.00 0.00 5,529.93 81.91 182.00 3,504.36 -111.47 -1,736.14 15.90 15.90 0.00 0.00 5,559.93 81.91 182.00 3,508.59 -141.15 -1,737.17 0.00 0.00 0.00 0.00 5,756.17 91.72 182.00 3,519.48 -336.73 -1,744.00 5.00 5.00 0.00 360.00 5,784.10 93.10 182.22 3,518.31 -364.62 -1,745.03 5.00 4.94 0.78 9.00 6,235.71 93.10 182.22 3,493.89 -815.22 -1,762.49 0.00 0.00 0.00 0.00 6,292.40 91.72 179.74 3,491.50 -871.86 -1,763.45 5.00 -2.43 -4.37 -119.06 6,542.40 91.72 179.74 3,484.00 -1,121.74 -1,762.32 0.00 0.00 0.00 0.00 6,730.01 86.09 179.68 3,487.58 -1,309.23 -1,761.36 3.00 -3.00 -0.03 -179.34 6,969.77 86.09 179.68 3,503.92 -1,548.44 -1,760.01 0.00 0.00 0.00 0.00 7,143.71 91.31 179.75 3,507.86 -1,722.27 -1,759.14 3.00 3.00 0.04 0.82 8,143.71 91.31 179.75 3,485.00 -2,722.00 -1,754.77 0.00 0.00 0.00 0.00 8,292.52 86.85 179.80 3,487.39 -2,870.75 -1,754.20 3.00 -3.00 0.04 179.30 8,516.51 86.85 179.80 3,499.72 -3,094.40 -1,753.43 0.00 0.00 0.00 0.00 8,644.66 90.69 179.73 3,502.47 -3,222.50 -1,752.91 3.00 3.00 -0.06 -1.12 10,344.66 90.69 179.73 3,482.00 -4,922.36 -1,744.90 0.00 0.00 0.00 0.00 10,390.21 91.60 179.73 3,481.09 -4,967.89 -1,744.69 2.00 2.00 0.00 0.00 11,145.11 91.60 179.73 3,460.00 -5,722.49 -1,741.13 0.00 0.00 0.00 0.00 11,175.21 91.01 179.82 3,459.32 -5,752.58 -1,741.01 2.00 -1.98 0.30 171.50 13,244.76 91.01 179.82 3,423.00 -7,821.81 -1,734.47 0.00 0.00 0.00 0.00 1/1712006 9:38:23AM Page 3 of 8 COMPASS 2003. ? 1 Build 48 r.-` Halliburton Ene rgy Serv ices HA LLIBIJA`1"t31V ~'~'~'~~~~~~' Planning Report -Geographic ~ ~ --..__ Alaska rr5- tyr~h~ng 75ttevf~ss Database: EDM 2003.11 Sin gle User Db Local Co-ordinate Reference: Well Plan 1J- 152 -Slot 1J-152 Company: ConocoPhillips Al aska (Kuparu k) ND Reference: Planned RKB ~: 109.OOft (D oyon 141 (2 8+81)) Project: Kuparuk River Un it MD Reference: Planned RKB @ 1 U9.OOft (D oyon 141 (2 8+81)) Site: Kuparuk 1J Pad North Reference : True Well: Plan 1J-152 Survey Calculation Method: Minimum Curvature Wellbore: 1J-152 L1 Design: 1J-152 L1 (wp05) _. _ Planned Survey 1J-152 L1 (wp05) _ _ _ _ ~ Map Map MD Inclination Azimuth TVD SSND +N/-S +E/_yy Northing Fasting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ftj {ft) ' 5,517.93 80.00 182.00 3,502.48 3,393.48 -99.63 -1,735.72 5,945,889.19 556,890.63 0.00 99.63 L1 : Top of Window - 2092ft FSL & 962ft FWL -Sec 35 - T11 N - R 10E, 5518ft MD, 3502ft ND - 7 5!8" 5,529.93 81.91 182.00 3,504.36 3,395.36 -111.47 -1,736.14 5,945,877.35 856,890.31 15.90 111.47 L1 : Bttm of Window -Drill 30' Rathole, 5530ft MD, 3504ft ND 5,555.76 81.91 182.00 3,508.00 3,399.00 -137.02 -1,737.03 5,945,851.79 556,8$9.62 0.00 137.02 5,559.93 81.91 182.00 3,508.59 3,399.59 -141.15 -1,737.17 5,945,847.66 556,889.51 0.00 141.15 L1 : Build @ 5°1100ft , 5560ft MD, 3509ft ND 5,600.00 83.91 182.00 3,513.53 3,404.53 -180.89 -1,738.56 5,945,807.92 556,888.43 5.00 180.89 5,700.00 88.91 182.00 3,519.79 3,410.79 -280.60 -1,742.04 5,945,708.19 556,885.72 5.00 280.60 5,756.17 91.72 182.00 3,519.48 3,410.48 -336.73 -1,744.00 5,945,652.05 556,884.20 5.00 336.73 5,784.10 93.10 182.22 3,518.31 3,409.31 -364.62 -1,745.03 5,945,624,16 556,883.39 5.00 364.62 L1 : Sail @ 93.1 °, 5784ft MD, 3518ft ND 5,800.00 93.10 182.22 3,517.45 3,408.45 -380.48 -1,745.64 5,945,608.30 556,882.90 0.00 380.48 5,900.00 93.10 182.22 3,512.04 3,403.04 -480.26 -1,749.51 5,945,508.50 556,879.81 0.00 480.26 6,000.00 93.10 182.22 3,506.63 3,397.63 -580.04 -1,753.37 5,945,408.70 556,876.72 0.00 5$0.04 6,100.00 93.10 182.22 3,501.23 3,392.23 -679.82 -1,757.24 5,945,308.91 556,873.63 0.00 679.82 6,200.00 93.10 182.22 3,495.82 3,386.82 -779.60 -1,761.11 5,945,209.11 556,870.55 0.00 779.60 6,235.71 93.10 182.22 3,493.89 3,384.89 -815.22 -1,762.49 5,945,173.48 556,869.44 0.00 815.22 L1 : Continue Geosteer in B-Sand, 6236ft MD, 3494ft ND 6,292.40 91.72 179.74 3,491.50 3,382.50 -871.86 -1,763.45 5,945,116.85 556,868.92 5.00 871.86 6,300.00 91.72 179.74 3,491.28 3,382.28 -879.45 -1,763.42 5,945,109.25 556,869.01 0.00 879.45 6,400.00 91.72 179.74 3,488.27 3,379.27 -979.41 -1,762.97 5,945,009.31 556,870.24 0.00 979.41 6,500.00 91.72 179.74 3,485.27 3,376.27 -1,079.36 -1,762.51 5,944,909.38 556,871.47 0.00 1,079.36 6,542.40 91.72 179.74 3,484.00 3,375.00 -1,121.74 -1,762.32 5,944,867.00 556,872.00 0.00 1,121.74 1J-152 L1 T1 (wp05) 6,600.00 89.99 179.72 3,483.14 3,374.14 -1,179.33 -1,762.05 5,944,809.42 556,872.72 3.00 1,179.33 6,700.00 86.99 179.69 3,485.77 3,376.77 -1,279.28 -1,761.53 5,944,709.48 556,874.01 3.00 1,279.28 6,730.01 86.09 179.68 3,487.58 3,378.58 -1,309.23 -1,761.36 5,944,679.54 556,874.41 3.00 1,309.23 6,800.00 86.09 179.68 3,492.35 3,383.35 -1,379.06 -1,760.97 5,944,609.72 556,875.35 0.00 1,379.06 6,900.00 86.09 179.68 3,499.17 3,390.17 -1,478.83 -1,760.40 5,944,509.97 556,876.69 0.00 1,478.83 6,969.77 86.09 179.68 3,503.92 3,394.92 -1,548.44 -1,760.01 5,944,440.38 556,877.63 0.00 1,548.44 7,000.00 87.00 179.69 3,505.74 3,396.74 -1,578.61 -1,759.84 5,944,410.21 556,878.03 3.00 1,578.61 7,100.00 90.00 179.73 3,508.36 3,399.36 -1,678.56 -1,759.33 5,944,310.27 556,879.32 3.00 1,678.56 7,143.71 91.31 179.75 3,507.86 3,398.86 -1,722.27 -1,759.14 5,944,266.57 556,879.86 3.00 1,722.27 7,200.00 91.31 179.75 3,506.58 3,397.58 -1,778.54 -1,758.89 5,944,210.31 556,880.54 0.00 1,778.54 7,300.00 91.31 179.75 3,504.29 3,395.29 -1,878.52 -1,758.45 5,944,110.35 556,881.75 0.00 1,878.52 7,400.00 91.31 179.75 3,502.00 3,393.00 -1,978.49 -1,758.02 5,944,010.39 556,882.97 0.00 1,978.49 7,500.00 91.31 179.75 3,499.72 3,390.72 -2,078.46 -1,757.58 5,943,910.44 556,884.18 0.00 2,078.46 7,600.00 91.31 179.75 3,497.43 3,388.43 -2,178.44 -1,757.15 5,943,810.48 556,885.40 0.00 2,178.44 7,700.00 91.31 179.75 3,495.14 3,386.14 -2,278.41 -1,756.71 5,943,710.52 556,886.61 0.00 2,278.41 7,800.00 91.31 179.75 3,492.86 3,383.86 -2,378.38 -1,756.27 5,943,610.57 556,887.83 0.00 2,378.38 7,900.00 91.31 179.75 3,490.57 3,381.57 -2,478.35 -1,755.84 5,943,510.61 556,889.04 0.00 2,478.35 8,000.00 91.31 179.75 3,488.29 3,379.29 -2,578.33 -1,755.40 5,943,410.65 556,890.25 0.00 2,578.33 8,100.00 91.31 179.75 3,486.00 3,377.00 -2,678.30 -1,754.96 5,943,310.70 556,891.47 0.00 2,678.30 i/17/2006 9:38:23AM Page 4 of 8 COMPASS 2003. ? 1 Build 48 ~~~,.~ ~- . r-° ~ ~ Hallibulrrton Energy Services H,4LL~euAT'ofw' ~~'~~~~~~ Planning Report -Geographic - ~- ~--~- ~~--~---- Rt~~ska ~sOnY tleillln~ Saavi~e~ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-152 - 51ot 1J-152 Company: ConocoPhillips Alaska (Kuparu k) TVD Reference: Planned RKB @ 109-OOft (Doyon 141 (28+81 j) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True WeII: Plan 1J-152 Survey Calculation Method: Minimum Curvature Wellbore: 1J-152 L1 Design: 1J-152 L1 (wp05) Planned Survey 1J-152 L1 (wp05) MD Inclination Azimuth 8,143.71 91.31 179.75 1J-152 L1 T2 (wp05} 8,200.00 89.62 179.17 8,292.52 86.85 179.80 8,300.00 86.85 179.80 8,400.00 86.85 179.80 8,500.00 86.85 179.80 8,516.51 86.85 179.80 8,600.00 89.35 179.76 8,644.66 90.69 179.73 8,700.00 90.69 179.73 8,800.00 90.69 179.73 8,900.00 90.69 179.73 9,000.00 90.69 179.73 9,100.00 90.69 179.73 9,200.00 90.69 179.73 9,300.00 90.69 179.73 9,400.00 90.69 179.73 9,500.00 90.69 179.73 9,600.00 90.69 179.73 9,700.00 90.69 179.73 9,800.00 90.69 179.73 9,900.00 90.69 179.73 10,000.00 90.69 179.73 10,100.00 90.69 179.73 10,200.00 90.69 179.73 10,300.00 90.69 179.73 10,344.66 90.69 179.73 1J-152 L1 T3 (wp05} 10, 390.21 91.60 179.73 10,400.00 91.60 179.73 10,500.00 91.60 179.73 10,600.00 91.60 179.73 10,700.00 91.60 179.73 10,800.00 91.60 179.73 10,900.00 91.60 179.73 11,000.00 91.60 179.73 11,100.00 91.60 179.73 11,145.11 91.60 179.73 1J-152 L1 T4 (wp05} 11,175.21 91.01 179.82 11,200.00 91.01 179.82 11,300.00 91.01 179.82 11,400.00 91.01 179.82 11,500.00 91.01 179.82 11,600.00 91.01 179.82 11,700.00 91.01 179.82 11,800.00 91.01 179.82 11,900.00 91.01 179.82 Map Map SSTVD +N/-S +E/_yy Northing Fasting DLSEV Vert Section (ft) (ft) (ft) (ft) (ft) (°/100ft) {ft) 3,376.00 -2,722.00 -1,754.77 5,943,267.00 556,892.00 0.00 2,722.00 TVD (ft) 3,485.00 3,484.54 3,375.54 -2,778.28 -1,754.54 5,943,210.73 556,892.67 3.00 2,778.28 3,487.39 3,378.39 -2,870.75 -1,754.20 5,943,118.27 556,893.74 3.00 2,870.75 3,487.81 3,378.81 -2,878.22 -1,754.17. 5,943,110.81 556,893.82 0.00 2,878.22 3,493.31 3,384.31 -2,978.07 -1,753.83 5,943,010.98 556,894.94 0.00 2,978.07 3,498.81 3,389.81 -3,077.91 -1,753.49 5,942,911.14 556,896.05 0.00 3,077.91 3,499.72 3,390.72 -3,094.40 -1,753.43 5,942,894.66 556,896.24 0.00 3,094.40 3,502.49 3,393.49 -3,177.84 -1,753.11 5,942,811.24 556,897.21 3.00 3,177.84 3,502.47 3,393.47 -3,222.50 -1,752.91 5,942,766.58 556,897.76 3.00 3,222.50 3,501.81 3,392.81 -3,277.83 -1,752.65 5,942,711.26 556,898.45 0.00 3,277.83 3,500.60 3,391.60 -3,377.82 -1,752.18 5,942,611.28 556,899.70 0.00 3,377.82 3,499.40 3,390.40 -3,477.81 -1,751.71 5,942,511.31 556,900.95 0.00 3,477.81 3,498.19 3,389.19 -3,577.81 -1,751.24 5,942,411.33 556,902.20 0.00 3,577.81 3,496.99 3,387.99 -3,677.80 -1,750.77 5,942,311.36 556,903.45 0.00 3,677.80 3,495.78 3,386.78 -3,777.79 -1,750.30 5,942,211.38 556,904.70 0.00 3,777.79 3,494.58 3,385.58 -3,877.78 -1,749.83 5,942,111.41 556,905.95 0.00 3,877.78 3,493.38 3,384.38 -3,977.77 -1,749.35 5,942,011.43 556,907.20 0.00 3,977.77 3,492.17 3,383.17 -4,077.76 -1,748.88 5,941,911.46 556,908.44 0.00 4,077.76 3,490.97 3,381.97 -4,177.76 -1,748.41 5,941,811.48 556,909.69 0.00 4,177.76 3,489.76 3,380.76 -4,277.75 -1,747.94 5,941,711.51 556,910.94 0.00 4,277.75 3,488.56 3,379.56 -4,377.74 -1,747.47 5,941,611.53 556,912.19 0.00 4,377.74 3,487.35 3,378.35 -4,477.73 -1,747.00 5,941,511.56 556,913.44 0.00 4,477.73 3,486.15 3,377.15 -4,577.72 -1,746.53 5,941,411.58 556,914.69 0.00 4,577.72 3,484.95 3,375.95 -4,677.71 -1,746.06 5,941,311.60 556,915.94 0.00 4,677.71 3,483.74 3,374.74 -4,777.70 -1,745.58 5,941,211.63 556,917.19 0.00 4,777.70 3,482.54 3,373.54 -4,877.70 -1,745.11 5,941,111.65 556,918.44 0.00 4,877.70 3,482.00 3,373.00 -4,922.36 -1,744.90 5,941,067.00 556,919.00 0.00 4,922.36 3,481.09 3,372.09 -4,967.89 -1,744.69 5,941,021.47 556,919.57 2.00 4,967.89 3,480.82 3,371.82 -4,977.68 -1,744.64 5,941,011.69 556,919.69 0.00 4,977.68 3,478.02 3,369.02 -5,077.64 -1,744.17 5,940,911.74 556,920.94 0.00 5,077.64 3,475.23 3,366.23 -5,177.60 -1,743.70 5,940,811.80 556,922.19 0.00 5,177.60 3,472.43 3,363.43 -5,277.56 -1,743.23 5,940,711.86 556,923.44 0.00 5,277.56 3,469.64 3,360.64 -5,377.52 -1,742.76 5,940,611.91 556,924.69 0.00 5,377.52 3,466.85 3,357.85 -5,477.48 -1,742.29 5,940,511.97 556,925.94 0.00 5,477.48 3,464.05 3,355.05 -5,577.44 -1,741.82 5,940,412.03 556,927.19 0.00 5,577.44 3,461.26 3,352.26 -5,677.40 -1,741.34 5,940,312.08 556,928.44 0.00 5,677.40 3,460.00 3,351.00 -5,722.49 -1,741.13 5,940,267.00 556,929.00 0.00 5,722.49 3,459.32 3,350.32 -5,752.58 -1,741.01 5,940,236.91 556,929.35 2.00 5,752.58 3,458.88 3,349.88 -5,777.37 -1,740.94 5,940,212.13 556,929.62 0.00 5,777.37 3,457.13 3,348.13 -5,877.35 -1,740.62 5,940,112.16 556,930.72 0.00 5,877.35 3,455.37 3,346.37 -5,977.34 -1,740.30 5,940,012.19 556,931.81 0.00 5,977.34 3,453.62 3,344.62 -6,077.32 -1,739.99 5,939,912.22 556,932.91 0.00 6,077.32 3,451.86 3,342.86 -6,177.30 -1,739.67 5,939,812.25 556,934.00 0.00 6,177.30 3,450.11 3,341.11 -6,27729 -1,739.36 5,939,712.28 556,935.10 0.00 6,277.29 3,448.35 3,339.35 -6,377.27 -1,739.04 5,939,612.31 556,936.19 0.00 6,377.27 3,446.60 3,337.60 -6,477.26 -1,738.72 5,939,512.35 556,937.28 0.00 6,477.26 1/17/2006 9:38:23AM Page 5 of 8 COMPASS 2003.118ui1d 48 n~r~~~ r•' ~ Halliburton Energy Services HpLLIC~U1~TCiN ~~~~~~~~~- Planning Report-Geographic ~~~~~~~~ ~~~~°° Ali sxa SpierTy Cirt111eI~g avi~es Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-15~' -Slot 1J-152 Company: ConocoPhillips Alaska (Kuparu k) TVD Reference: Planned RKB C~ 109.OOft (Doyon 141 (28+81)i Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-152 Survey Calculation Method: Minimum Curvature Wellbore: 1J-152 L1 Design: 1J-152 L1 (wp05) Planned Survey 1J-152 L1 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E!-W Northing Fasting DLSEV Vert Section Ift) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) {°/100ft) {ft} 12,000.00 91.01 179.82 3,444.84 3,335.84 -6,577.24 -1,738.41 5,939,412.38 556,938.38 0.00 6,577.24 12,100.00 91.01 179.82 3,443.09 3,334.09 -6,677.22 -1,738.09 5,939,312.41 556,939.47 0.00 6,677.22 12,200.00 91.01 179.82 3,441.33 3,332.33 -6,777.21 -1,737.78 5,939,212.44 556,940.57 0.00 6,777.21 12,300.00 91.01 179.82 3,439.58 3,330.58 -6,877.19 -1,737.46 5,939,112.47 556,941.66 0.00 6,877.19 12,400.00 91.01 179.82 3,437.82 3,328.82 -6,977.18 -1,737.14 5,939,012.50 556,942.76 0.00 6,977.18 12,500.00 91.01 179.82 3,436.07 3,327.07 -7,077.16 -1,736.83 5,938,912.53 556,943.85 0.00 7,077.16 12,600.00 91.01 179.82 3,434.31 3,325.31 -7,177.15 -1,736.51 5,938,812.56 556,944.94 0.00 7,177.15 12,700.00 91.01 179.82 3,432.56 3,323.56 -7,277.13 -1,736.20 5,938,712.59 556,946.04 0.00 7,277.13 12,800.00 91.01 179.82 3,430.80 3,321.80 -7,377.11 -1,735.88 5,938,612.62 556,947.13 0.00 7,377.11 12,900.00 91.01 179.82 3,429.05 3,320.05 -7,477.10 -1,735.56 5,938,512.66 556,948.23. 0.00 7,477.10 13,000.00 91.01 179.82 3,427.29 3,318.29 -7,577.08 -1,735.25 5,938,412.69 556,949.32 0.00 7,577.08 13,1.00.00 91.01 179.82 3,425.54 3,316.54 -7,677.07 -1,734.93 5,938,312.72 556,950.42 0.00 7,677.07 13,200.00 91.01 179.82 3,423.79 3,314.79 -7,777.05 -1,734.62 5,938,212.75 556,951.51 0.00 7,777.05 13,244.76 91.01 179.82 3,423.00 3,314.00 -7,821.81 -1,734.47 5,938,168.00 556,952.00 0.00 7,821.81 L1 : BHL @ 351ft FNL & 955ft FW L -Sec 11 - T10N - R10E, 13245ft MD, 3423ft - 41/2" -1J-152 L1 T5 (wp05) 1/17/2006 9:38:23AM Page 6 of 8 COMPASS 2003.1? Build 48 ~~~~~" ti-' ~ ~ Halliburton Energy Services HALLIBt.li~TOfV ~~'~~~~~~~~~ Planning Report -Geographic _ ~~ } Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-152 Wellbore: 1J-152 L1 Design: 1J-152 L1 (wp05) Geologic Targets 1J-152 L1 Sprerry D~1111ng `srtrvi~es Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 TVD Reference: Planned RKB C 10J.OOft (Doyon 141 (28+81)) MD Reference: Planned RKB C: 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature ND Target Name +N!-S +E/-W (ft) -Shape ft ft 3,460.00 1J-152 L1 T4 (wp05) -5,722.49 -1,741.13 - Point 3,485.00 1J-152 L1 TZ {wp05) -2,722.00 -1,754.77 - Point 3,482.00 1J-152 L1 T3 {wp05) -4,922.36 -1,744.90 - Point 3,484.00 1J-152 L1 T1 {wp05) -1,121.74 -1,762.32 - Point 3,423.00 1J-152 L1 T5 (wp05) -7,821.81 -1,734.47 - Point 3,502.48 1J-152 L1 DD Poly (wp05) -99.63 -1,735.72 - Polygon Point 1 -50.00 0.00 5,945,888.80 556,840.64 Point 2 -58.28 -236.72 5,945,652.05 556,834.20 Point 3 -76.77 -715.20 5,945,173.48 556,819.44 Point 4 -76.60 -1,021.72 5,944,867.00 556,822.00 Point 5 -69.06 -2,621.99 5,943,267.00 556,842.00 Point 6 -59.18 -4,822.34 5,941,067.00 556,869.00 Point 7 -55.41 -5,622.47 5,940,267.00 556,879.00 Point 8 -48.76 -7,721.79 5,938,168.00 556,902.00 Point 9 51.25 -7,722.57 5,938,168.00 557,002.00 Point 10 44.59 -5,623.25 5,940,267.00 556,979.00 Point 11 40.82 -4,823.12 5,941,067.00 556,969.00 Point 12 30.95 -2,622.76 5,943,267.00 .556,942.00 Point 13 23.41 -1,022.50 5,944,867.00 556,922.00 Point 14 23.23 -716.28 5,945,173.18 556,919.44 Point 15 41.72 -237.50 5,945,652.05 556,934.20 Point 16 50.00 0.00 5,945,889.58 556,940.63 Northing (ft) 5;940,267.00 5;943,267.00 5;941,067.00 5;944,867.00 5;938,168.00 5,945,889.19 Fasting (ft) 556,929.00 556,892.00 556,919.00 556,872.00 556,952.00 556,890.63 Prognosed Casing Points Measured Depth (ft) 2,825.33 5, 517.94 13,244.76 Vertical Casing Hole Depth Diameter Diameter 2, 204.00 10-3/4 13-112 3,502.48 7-518 9-718 3,423.00 4112 6-314 1/17/2006 9:38:23AM Page 7 of 8 COMPASS 2003.118ui1d 48 a t y S~ ,.~ • ti-' ~"~'~~~~~' Hailiburton Energy Services H~-~uBUaYOnr hi Pl i R t G ann ng epor - eograp c ~~ska r-Y Dr9lfing ~eevlces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 Company: ConocoPhillips Alaska (Kuparu k} TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81 j) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-152 Survey Calculation Method: Minimum Curvature Wellbore: 1J-152 L1 Design: 1J-152 L1 (w p05) Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N!-E (ft) (°) (°) lft) (ft) 1,689.59 47.14 355.00 1,541.00 513.51 1,870.86 52.87 349.56 1,659.00 649.83 2,368.62 55.59 324.44 1,942.00 1,028.03 2,825.33 53.89 299.80 2,204.00 1,281.77 3,950.55 53.45 230.74 2,869.00 1,217.22 4,275.65 57.66 211.66 3,054.00 1,016.32 4,427.38 60.55 203.48 3,132.00 901.01 4,820.76 65.24 193.58 3,306.00 562.84 5,260.55 76.00 184.00 3,444.00 150.46 5,405.22 76.00 184.00 3,479.00 10.43 5,555.76 81.91 182.00 3,508.00 -137.02 +E(-W (ft) Name -44.93 Base of Perm -62.23 T3 -209.22 K15 -480.10 T3 + 554 -1,331.81 Ugnu C -1,506.16 Ugnu B -1,566.21 Ugnu A -1,664.61 K13 -1,720.15 West Sak D -1,729.94 West Sak C -1,737.03 West Sak B 1/17/2006 9:38:23AM Page 8 of 8 COMPASS 2003.11 Bulld 48 ~ • ConocoPhillps Alaska GonocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-152 1J-152 L1 Anticollision Summary 17 January, 2006 ~-erry r°i~ir~+ ~~~~~ ~~:~~,~ ~.. 3 , ~ rx~ ~ ~,~ SGRVF,Y PROGk43i Uafe: 2006.01-17TOU:00:00 Validated: 1'es Version: Uepth From llepth To Sur.ey/Plan Twd 28At7 799.00 ('B-ClR0-55 800.OU 5517.93 N\\D+I}'R-AK-C.4ZSC 5517.93 13244.76 1J-152 Ll (..p05) \(\\'U+IFIt-AK-CAZSC NAD 27 ASP Zane 4 : WELL DETAILS: Plan iJ-152 ANTI-COLLISION SETTINGS Ground Level: 81.00 Interpolation Method: MD Interval: SOStations +N/-S +EI-W Northing Easting Latittude Longitude Depth Range From: 5517.93 To 13244.7628704813 0.00 0.00 5946002.32 558825.38 70°15'47.084N 149°31'33.778W Mauimum Range:1521.67626704813 Reference: Plan: 7J-152 L7 (wp05) 330 z7o so From Colour To MD 0 5500 5500 5750 5750 6000 6000 6250 6250 6500 6500 6750 s7so 7000 180 7000 7250 7250 --- 7500 7500 ""' ""'"'"' 7750 7750 8000 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [150 tt/in] 6000 a5oo 8500 9000 9000 10000 10000 10500 10500 11000 11000 11500 11500 12000 12000 12500 REFERENCE INFORMATION 12500 13000 Coordinate (N/E) Reference: Well Plan 1J-152 -Slot 1J-152, True North 13000 13250 Vertical (ND) Reference: Planned RKB @ 709.00(1 (Doyon 141 (28+87)) Section (VS) Reference: Slat -1J-752(O.OON, O,OOE) Measured Depth Reference: Planned RKB @ 109.DOft (Doyon 141 (28+81)) Calculation Method: Minimum Curvature 30 ConocoPhillips Alaska (Kuparuk) Drilling 8 Wells Slot West Sak iJ-152 Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder N°rth Error Surface: Elliptical Conic Warning Method: Rules Based 3 30 1\ 1 I / 240 120 20 25 210 150 30 180 Tra\•elling Cylinder Azimuth (TFQ+AZI) [°~ vs Cen[re to Centre Separation [15 ft/in] 90 1 SECTION DETAILS Sec MD Inc Azi ND +NIS +E/-W DLeg TFace VSec Target 1 5517.93 80.00 182.00 3502.48 -99.63 -1735.72 0.00 0.00 99.63 2 5529.93 81.91 182.00 3504.36 -111.47 -1736.14 15.90 0.00 711.47 3 5559.93 87.91 182.00 3508.59 -141.75 -1737.17 0.00 0.00 747.15 4 5756.17 91.72 182.00 3519.48 -336.73 -1744.00 5.00 360.00 336.73 5 5784.10 93.10 182.22 3518.31 -364.62 -1745.03 5.00 9.00 364.62 6 6235.71 93.10 782.22 3493.89 -815.22 -7762.49 0.00 0.00 815.22 7 6292.40 97.72 179.74 3491.50 $77.86 -7783.45 5.00 -119.06 877.86 8 6542.40 91.72 179.74 3464.00 -1727.74 -7762.32 0.00 0.00 1127.74 1J-752 Li T1 (wp05) 9 8730.01 86.09 179.68 3487.56 -1309.23 -7761.36 3.OD -179.34 1309.23 10 6989.77 86.09 179.68 3503.92 -1548.44 -1760.07 0.00 0.00 1548.44 11 7143.71 91.31 179.75 3507.88 -1722.27 -1759.14 3.00 0.82 7722.27 12 8143.71 91.31 179.75 3485.00 -2722.00 -1754.77 0.00 0.00 2722.00 iJ-152 Li T2 (wp05) 13 8292.52 88.85 179.80 3487.39 -2870.75 -1754.20 3.00 179.30 2870.75 14 8518.51 86.85 779.80 3499.72 -3094.40 -1753.43 0.00 0.00 3094.40 15 8844.66 90.69 779.73 3502.47 -3222.50 -1752.91 3.00 -7.12 3222.50 16 10344.66 90.69 179.73 3482.00 -0922.36 -1744.90 0.00 0.00 4922.36 iJ-752 L1 T3 (wpD5) 171039011 97.60 779.73 3481.09 4967.89 -174469 2.00 0.00 4967.39 18 111-05.71 91.b0 779.73 34b0.00 -5722.49 -1747.13 0.00 0.00 5722.44 1J-152 Lt T4 (wp05} 19 11775.21 91.07 179.82 3459.32 -5752.58 -1747.01 z.DD 171.50 5752.59 20 13244.76 91.01 179.82 3423.00 -7827.81 -1734.47 0.00 0.00 7821.81 1J-152 L7 T5 (wp05) • • ti-' ~ Halliburton Energy Services ~Cri~t3Ct~P~I~1p5~ Anticollision Report f~~c~iKi~. Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-152 Well Error: O.OOft Reference Wellbore 1J-152 L1 Reference Design: 1J-152 L1 (wp05) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HALLIBURTON ~pierry, Drilling ;~crvices. Well Plan 1J-152 -Slot 1J-152 Planned RKB @ 109.OOft (Doyon 141 (28+81)1 Planned RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Reference Datum Reference 1J-152 L1 (wp05) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referf Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: 5,517.93 to 13,244.76ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,521.68ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 1/17/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 799.00 1J-152 (wp05) (1J-152) CB-GYRO-SS Camera based gyro single shot 800.00 5,517.93 1J-152 {wp05) (1J-152) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5,517.93 13,244.76 1J-152 L1 (wp05) (1J-152 L1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, 5F -min separation factor, ES -min ellipse separation 1/17/2006 10:35:34AM Page 2 of 3 COMPASS 2003.11 Build 48 r ~ ~ ~ ~ ~ ~ ~1~{~Phi~~1~~ Alaska Halliburton Energy Services Ha~.~iBUR-ror Anticollision Report ,~r.ry Drinieg 5erv;o~s Company: ConocoPhillips Alaska (Kupar uk) Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 Project: Kuparuk River Unit ND Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Reference Site: Kuparuk 1J Pad MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81 )) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-152 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbore 1J-152 L1 Database: EDM 2003.11 Single User Db Reference Design: 1J-152 L1 (wp05) Offset ND Reference: Reference Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre .Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad 1J-154 - 1J-154 - 1J-154 Rig 11,027.51 9,063.00 1,242.65 223.69 1,018.96 Pass -Major Risk 1J-154 - 1J-154 L1 - 1J-154 L1 12,917.43 10,950.00 1,211.49 284.41 927.08 Pass -Major Risk 1J-154 - 1J-154 L2 - 1J-154 L2 12,952.65 10,964.00 1,258.16 286.96 971.21 Pass -Major Risk Plan 1 J-102 - 1 J-102 - 1 J-102 (wp04) Out of range Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp03) Out of range Plan 1 J-102 - 1 J-102 L2 - 1 J-102 L2 {wp03) Out of range Plan 1J-103 -Plan 1J-103 - 1J-103 (wp01) BHI Out of range Plan 1J-105 -Plan 1J-105 - 1J-105 {wp01) BHI Out of range Plan 1J-107 -Plan 1J-107 - 1J-107 {wp01) BHI Out of range Plan 1J-109 -Plan 1J-109 - 1J-109 (wp04) Out of range Plan 1J-111 -Plan 1J-111 - 1J-111 (wp02) Out of range Plan 1J-123 Kuparuk Prelim - 1J-23 E Lat - 1J-23 6,303.32 4,499.98 380.19 104.09 276.10 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 Pilot - 1J-23 F 6,303.32 4,499.98 380.19 104.09 276.10 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 W Lat- 1J-23 6,303.32 4,499.98 380.19 104.09 276.10 Pass -Major Risk Plan 1J-152 - 1J-152 - 1J-152 (wp05) 5,549.98 5,550.00 0.87 2.54 -1.67 FAIL - No Errors Plan 1J-152 - 1J-152 L2 - 1J-152 L2 (wp05) 5,548.47 5,550.00 51.45 51.43 0.02 Pass - No Errors Plan 1J-156 - 1J-156 L1 - 1J-156 L1 (wp02) 5,855.81 3,899.98 964.60 99.95 864.65 Pass -Major Risk Plan 1J-156 - 1J-156 L2 - 1J-156 L2 (wp02) 5,855.81 3,899.98 964.60 99.95 864.65 Pass -Major Risk Plan 1J-156 -Plan 1J-156 - 1J-156 (wp02) 5,855.81 3,899.98 964.60 99.95 864.65 Pass -Major Risk Plan 1J-158 - 1J-158 - 1J-158 (wp2A) BHI Out of range Plan 1J-159 - 1J-159 - 1J-159 (wp06) Out of range Plan 1J-159 - 1J-159 L1 - 1J-159 L1 (wp06) Out of range Plan 1J-159 - 1J-159 L2 - 1J-159 L2 (wp06) Out of range Plan 1J-160 -Plan 1J-160 - 1J-160 (wp01) BHI Out of range Plan 1 J-162 - 1 J-162 -1 J-162 (wp03.1-North Heel Out of range Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp3.1) Out of range Plan 1 J-162 - 1 J-162 L2 - 1 J-162 L2 {wp3.1) Out of range Plan 1J-166 - 1J-166 - 1J-166 5,562.63 3,200.00 965.56 78.93 886.63 Pass -Major Risk Plan 1J-166 - 1J-166 L1 - 1J-166 L1 (wp07) 5,537.06 3,250.00 947.59 79.02 868.57 Pass -Major Risk Plan 1J-166 - 1J-166 L1 - 1J-166 L1 Rig 5,562.63 3,200.00 965.56 78.93 886.63 Pass -Major Risk Plan 1J-166 - 1J-166 L2 - 1J-166 L2 (wp07) 5,537.06 3,250.00 947.59 79.02 868.57 Pass -Major Risk Ptan 1J-170 -Plan 1J-170 - 1J-170 (wp02) 6,931.63 4,050.00 1,113.14 103.57 1,009.57 Pass -Major Risk Plan 1J-170 -Plan 1J-170 L1 - 1J-170 L1 (wp02) 6,931.63 4,050.00 1,113.14 103.58 1,009.56 Pass -Major Risk Plan 1J-170 -Plan 1J-170 L2 - 1J-170 L2 (wp02) 6,931.63 4,050.00 1,113.14 103.58 1,009.56 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 E Lateral - 1J-73 E L 6,599.97 4,350.00 398.59 102.69 295.89 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 Kuparuk - 1J-73 W L 6,599.97 4,350.00 398.59 102.69 295.89 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 Pilot- 1J-173 Pilot (v 6,599.97 4,350.00 398.59 102.69 295.89 Pass -Major Risk Plan 1J-178 -Plan 1J-178 - 1J-178 (wp01) 10,253.35 6,000.00 1,417.28 155.43 1,261.85 Pass -Major Risk Plan 1J-180 -Plan 1J-180 - 1J-180 (wp01) 12,669.17 8,200.00 881.07 241.35 639.72 Pass -Major Risk Plan 1J-182 - 1J-182 - 1J-182 (wp05) 13,205.60 8,750.00 150.60 32.52 118.08 Pass -Minor 11200 Plan 1J-182 - 1J-182 L1 - 1J-182 L1 (wp05) 13,205.60 8,750.00 150.60 0.51 150.09 Pass -Minor 1!200 Plan 1J-184 - 1J-184 - 1J-184 (wp09) 13,231.16 8,599.97 1,391.80 312.24 1,079.56 Pass -Major Risk Plan 1J-184 - 1J-184 L1 - 1J-184 L1 (wp09) 13,231.16 8,599.97 1,391.80 312.29 1,079.51 Pass -Major Risk WSP-1 S -WSP-1 S -WSP-1 S Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/17/2006 40:35:34AM Page 3 of 3 COMPASS 2003.19 Build 48 ~~~~~~ .~ iJ-152L1~rillinq H mm (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Oaen 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-152L1 Drilling Hazards Summary ~ z ~ ~ ~ } ~ r-- ~~ prepared by Mike Greener 1/23/2006 7:14 AM "\.i / ~~ n ~(. ~. ms w `~ r/J T '' ~ ~ ~ rt 3 R _ y =, rt C C '' O 'o 2 R ~- ~ ~ c ;~ ... N Wellhead /Tubing Head /Tree, 10-3/4" x Inntlated Conductor Casing, 20", 94#, K55 x 34", 0.312" WT L,: +;- gU' MD Tuburg String: 4-1;2" 12.6 #, L-SQ, IBTh7 (2) Gas Lift Mattdrels, CAMCO 4-I/2" x I" Model KMBG w/dummy wakes, one ~; ] OU` MD & mre C~. 150` MD, both are both dotvtrhole recombination 10-aid", 68#, L-8Q, BTC, R3 C-. 2,825 ` b1D ; 2,204' TVD _~ ~~ 53.9 degrees TD 13-1 ~" hole Top oC Ugnu C ~' 3,900' MI) / 2,839"1'VI) ~ Top of Wes[ Sak B (a _ _ ~ 5,518' Aill 13,502' TVD literal Entry Module #1 (LEM). Baker, with seal bore and ZXP packer abot•e. ~ 15211 ' nt ow (at 5,578' MD / 3,502' TVD 80 degees "B"Liner, 4d;2", 12.8#, L80, IBTM, R3 (0.125" x 2.5" slots, 32 per Coot, S.9°~~ open area) ke a g ~F is ~~:n~ a c '~+' Tubing, 4-! ~' IBTM, from LEM to -- A2 Later, wi[It seal nem and CAMCO 3.562" "DB" nipple. -, Seal bore and ZXP packer for A2 later +'. 90' below "B" window Top of West Sak A ~•. 6,353' D1D 13,530' TVD -~ 7-5/8", 40#, L-80, BTC M, R3 C'sg C 6,353' MD / 3,530' TVD C'. 85 degees TD 9.7/8" hole A2 Sand Liner, 3'f'2°PP.B~#, L8 ,~ IBTM, R3 4i slotted and ';5 blank, ronsn~inas for iaolainn LI-152 Ll: ~-.~ ' sandsand lateral TD 13,245' MD i 3T'3'T~ Angle 91.01 degrees IJ-152: 6-314 A2 sand lateral TD 9,888' MD i 3,632' TVD Angle 90.97 degees (1) Gas Lift Mvtdrel, CAMCO 4-1;Y' z 1" Model KMBG w.' dummy wake ~:~, one (1) set ( 2,400' MD, 1959' TVD. - (1) Gas Lift Mandrel CAMCO 4-I 2" z 1" Model KMBG w' dummy wake, ~ <72 deg, 5,000' MD, 3,373' TVD. Electric Submersible Pump, Centrilift 418 HP motoq with FC6000 wireline deployed pump. Bottom at 6,193' MD, 3,620' TVD 1 S2 L2 "D" Sand Window C 5 X32' MD i 3,43 T T V D 76 degees "D" Liner, 4.1/Y', 12.8#, L80, 1BTM, R3 1J-152 L2: (0. ]25" x 2.5" slots, 32 per foot, 5.9° a open area) 6-3J4" D sand lateral TD 12,940' MD; 3,347 TVD Angle 91.24 degees ~`` `~ :7 • • TRANSMITTAL LETTER CHECKLIST WELL NAME /~~~'L~C. ~ ~/-~~'~~- ~-- PTD# ~-~~' ~ ~ ~ I/ N~Development aervice Exploratory Stratigraphic Test Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new we llbore segment of existing _ well ~~.i~'C{` % 6~. - /~ Z V~` (If last two digits in permit No. 2C>G~ ~--c'~ /~, API No. 50- ~C-`~ - Z~ Z~T~ - ~ . API number are between 60-69) production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be SAMPLE in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 1!05/06 C:\jody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKOlL-490150 _ _Well Name: KUPARUK RIV U WSAK iJ-152L1 Program DEV _._ Well bore seg [~ PTD#:2060170 Company CONOCOPHILLIPS ALASKA INC _ Initial ClasslType DEV I PEND GeoArea 890 Unit 11160 On1Off Shore On Annular Disposal Administration i 1 Permitfee attached- - _ - NA_ West Sak B Sand multilateral well branch; fee waived per 20 AAC 25.005(e)._ j 2 Lease number appropriate__.-_ _________________ ____________ ___ Yes_ --- ___ __ 3 Unique weltname and number _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ - - _ - . - - - - - .. _ . Yes - _ - _ _ - -Lateral well branch; top_productive interval.in ADL 025661- antl TD_in ADL 025662. _ . _ _ _ _ _ _ _ _ , - , _ - - - _ _ 4 Well located in a-defined_pool_ - - . - Yes KRUWestSakOil Pool,governetl-by Conseruation_Order_No.4066_ - _ _ _ ~ 5 Well located proper distance_ from drilling unit_boundary- - - - - - - - - - - - -- - - - - - - Yes - CQ 4066, Rr,le 3; no restrictions as-to well spacing except that no_pay shall be opened in a well closer - 6 Well located proper distance_ from other wells_ - _ - Yes - - - _ than 50.0 feet to_a_n external-property line where ownership-or landownership changes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 Sufficient acreageayail_ableind_ril_lingunit-_-______-.-_- ____-.-. -_---_ Yes. -______-.-_ - -- 8 If deviated, is_wellbore plat_included - _ _ _ _ _ _ - . - _ _ _ - - - - - . - Yes _ _ _ _ _ -- 9 Operatoronlyaff_ectedparty------------------ --.------ Yes- -:------- 10 Operator has.appropriate-bond in force -- -- -- -- -- - - Yes- -- - --- ---- - - - --- -- ------- - -- -- - -- --- 11 Permit_canbeissuedwithoutconservationorder______ _____________________ Yes- -.---__ _ .---__-_--.-.---__--__-__-__---.-.---___--.-.-_-_-__--__---- Appr Date 12 Permit-can be issued without administrative_appr_oyal-------- ---------------- Yes_ ____....._ -_.--___-- ---..----_.-__ __----___-.------- __.....-..-__-__- SFD 1!31!2006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authorized by_Injection Order# (put_1O# in-comments)_(For, NA_ Per Mike Greener, CPAt: this will be a production well branch. SFD 1131/2006 15 Allwellswithin1l4_milearea_ofreyiewidentified(Forserviicewel_lonly)_--____-.-.--- NA__ ____________________.---...--.-_--_.._-_.---..--_.__..--.-_.._---_---_- 16 Pre-produced injector: duration of preproduction Less than.3 mgnths_(For service well only) NA_ - - - .. _ . AC_M_P_Finding of Consistency_h_as been issued_forthis pro]ect_ NA_ - - - - Engineering 18 Conductor string-provided______________.-. __--__._-___-__-..- NA__ ___-..Conductorsetinmotherbore,_1_J-152(206-016).____________---_-.__-------..-.-__--__- 19 Surface casing_protectsall_known_USDWs--------- ------_..---__--_. NA__ ______Allaquifersexempted40CFR147.102~b)(3).-__--____________---________._--..-.-.__. 20 CMT_vol_ adequate_to circ_ul_ate.on conductor_& surf_csg - - NA_ - . - - _ Surface eosin set in_ motherbore. 8- - 21 _C_MT_vol_ adequate_to tie-in long string to-surf csg_ - NA- - - Production_casingset in_motherbore- - - - - - - - - - - - - - 22 CMT_will coverall know_nproductive horizon_s_ _ _ - - - No_ Slatted liner completion planned, . - _ - ~ 23 Casing designs adequate for C, T, B &_ permaf[ost_ - . - NA_ - Motherbore tubulars meet tlesi n criteria.- NA for slotted-liner, g ~ 24 Adequate tankage-or reserve pit - - - - - .. - - Yes - - Rig is_equipped with steel-pits. No reserue_pitplanned. All waste to_apprgued annulus or disposal wells. . 25 If a_re-drill, has_a 1.0-403 for abandonment been approved _ - NA_ - - 26 Adequate wellboreseporation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - . Proximity analysis performed, Nearest well branch is A sand lateral X18' - 200' tud below. _ _ - _ _ _ _ . _ . - _ - - . 27 Ifdiverterrequired,doesitmeetregulations_____________ _________________ NA__ _-- ._BOPStackwillalready_beinplace,-___________ ____---______._--..--.--__--___- Appr Date 28 Drilling fluid_ program schematic & e ui listade uate_ . 0.p 0. Yes Maximum expected formation pressure 8,7.EMW._ M_W_ planned $.6 ppg or as needed. - . - _ _ - - - . - TEM 1!31206 29 BOPES,dotheymeetregulation__-______---------------- -- Yes- ---.------.---------.---.----------------------------- ------------.- --- 30 BQPE.p_ress rating appropriate; test to.(put prig in comments)_ Yes MASP calculated at 1191 psi. 3K st_ack arrangement planned, wltpipe_ram.. 3000psi BO_P_test planned.. _ - - - - ~31 Choke,manifoldcomplies.w/APl_RP-53 (May84)_____ --------------- Yes- - ---------------------- ------------------------------------------------- '32 Work will occur without operation shutdow_n____________ ________---.-__ _ Yes_ _.-______---_______.-..------___-_-_.---..-..__ -_---_-...--------- j 33 Is presence_of H2S gas probable. - - - _ . - ... - - - _ - . - . - No_ H2S is not known_ in WS. Rig is equipped with sensors and_alarms---- - - - - - - - - -- - - _ - _ - - 34 Mechanical condition of wells withinAORyerifed(For_s_ervicewellonly)____---______ NA-- -- --- --------------------- --------- -----___-_-_. ..-..---_.-_- -_---. ------ Geology 35 - Permit_canbeissuedwlo.hydr_ogen_sulfidemeasures__________________________ Yes- - -___ __ -_-___..-- -----_-.--.---.--..--.__--__- --.-.-.__-__- 36 _D_ata_presented on_potential overpressure zones - Yes _ Expected res.pre_ssure is ~8.7ppg EMW; will be drilled with 8 6 ppgoil-based-mud, Mud weight will be - - ... - - Appr Date 37 Seismic analysis of shallow gas.zones_ NA_ - - - adjusted as needed. -...-- SFD 1!31!2006 138 Seabed condition survey,(ifoff-shore) NA 39 neforweekly_p_rogressreports(exploratoryonly]_ _______________ C ontactnamelpho NA_- . ___ ___---_____--....-__-__.--.--.... --.-_--___ .-___ --------------- e _ _ _ Geo .c Date: Engineering Date Public Date West Sak 8 sand production lateral well branch. Change in current well class from injector to producer as noted on the 10- Gdmm~ r. Commissionfr: / Commissioner 401 form made by SFD following a telephone conversation with Mike Greener, CPAI. SFD 1/3112006 +n i ~~ ~ ', • • J` • • Well History File APPENDIX Information of detailed nature that is nat particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made io chronologically organize this category of information. ao~ ~ o ~t~- '~ - 399 ~ Sperry-Sun Dr ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jun 21 09:25:40 2006 Reel Header Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF • Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-152 L1 API NUMBER: 500292329860 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 21-JUN-06 JOB DATA MWD RUN 3 MWD RUN 7 MWD RUN 8 JOB NUMBER: W-0004263658 W-0004263658 W-0004263658 LOGGING ENGINEER: T. GALVIN P. ORTH P. ORTH OPERATOR WITNESS: D. GLADDEN M. THORNTON M. THORNTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2191 FEL: 2582 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2774.0. 2ND STRING 6.750 7.875 5747.0 3RD STRING PRODUCTION STRING REMARKS: ~ • 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 EFFECTED BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS POSITIONED AT 5747'MD/3507'TVD WITHIN THE RUN 3 INTERVAL OF THE 1J-152 PB1 WELLBORE. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3,8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 8 ALSO INCLUDED AT-BIT INCLINATION (ABI) THE WHIPSTOCK WAS POSITIONED, THE WINDOW MILLED, AND 15' OF NEW HOLE WERE DRILLED DURING MWD RUN 7. ONLY SROP DATA ARE PRESENTED FOR RUN 7. MWD DATA OVER THE RUN 7 INTERVAL WERE ACQUIRED WHILE RIH FOR RUN 8. 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 1-3,7,8 REPRESENT WELL 1J-152 L1 WITH API#: 50-029-23298-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13408'MD/3424'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 (DEEP SPACING). 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.......06/06/21 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. • DEPTH INCREMENT: .500 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 274.1.5 13347.0 FET 2760.0 13354.0 RPD 2760.0 13354.0 RPS 2760.0 13354.0 RPM 2760.0 13354.0 RPX 2760.0 13354.0 ROP 2787.5 13408.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 2741.5 5747.0 MWD 7 5747.5 5774.0 MWD 8 5774.0 13408.5 REMARKS: MERGED MAIN PASS. 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 .12N 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 MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2741.5 13408.5 8075 21335 2741.5 13408.5 RPD MWD OHMM 1.71 2000 49.5063 21189 2760 13354 RPM MWD OHMM 2.2 2000 45.9371 21189 2760 13354 RPS MWD OHMM 2.5 2000 47.261 21189 2760 13354 RPX MWD ~ OHMM 3.05 2000 45.0572 21189 2760 13354 FET MWD HOUR 0.12 212.59 1.21984 21189 2760 13354 GR MWD API 26.27 131.95 69.4333 21212 2741.5 13347 ROP MWD FT/H 0.14 653.26 168.015 21243 2787.5 13408.5 First Reading For Entire File..........2741.5 Last Reading For Entire File...........13408.5 • • File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 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.......06/06/21 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2741.5 5747.0 FET 2760.0 5747.0 RPX 2760.0 5747.0 RPS 2760.0 5747.0 RPM 2760.0 5747.0 RPD 2760.0 5747.0 ROP 2787.5 5747.0 LOG HEADER DATA DATE LOGGED: 23-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT}: BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 53.5 MAXIMUM ANGLE: 84.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 105242 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2774.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) • 9.00 • MUD VISCOSITY (S) 60.0 MUD PH: 9.9 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.800 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.880 100.0 MUD FILTRATE AT MT: 2.350 65.0 MUD CAKE AT MT: 2.700 65.0 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 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 2741.5 5747 4244.25 6012 2741.5 5747 RPD MWD030 OHMM 1.71 2000 22.2618 5975 2760 5747 RPM MWD030 OHMM 2.2 1597.77 15.3824 5975 2760 5747 RPS MWD030 OHMM 2.5 1922.05 14.5915 5975 2760 5747 RPX MWD030 OHMM 3.05 1353.33 13.0474 5975 2760 5747 FET MWD030 HOUR 0.12 68.15 1.46117 5975 2760 5747 GR MWD030 API 26.27 125.3 69.1958 6012 2741.5 5747 ROP MWD030 FT/H 0.14 653.26 143.364 5920 2787.5 5747 First Reading For Entire File..........2741.5 Last Reading For Entire File...........5747 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ..............~O Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 I?ate of Generation.......06/06/21 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: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 5747.5 5774.0 LOG HEADER DATA DATE LOGGED: 30-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .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) 5747.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 69.0 MUD PH: .0 MUD CHLORIDES (PPM): 111000 FLUID LOSS (C3) 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 71.6 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 MWD070 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5747.5 5774 5760.75 54 5747.5 5774 ROP MWD070 FT/H 2.24 23.52 9.77648 54 5747.5 5774 First Reading For Entire File..........5747.5 Last Reading For Entire File...........5774 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 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.......06/06/21 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: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5747.5 13354.0 RPD 5747 13354.0 GR 5747.5 13347.0 RPM 5747.5 13354.0 FET 5747.5 13354.0 RPS 5747.5 13354.0 ROP 5774.5 13408.5 LOG HEADER DATA DATE LOGGED: 03-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.6 MAXIMUM ANGLE: 94.5 TOOL STRING (TOP TO BOTTOM) • VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5747.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 73.0 MUD PH: .0 MUD CHLORIDES (PPM): 18000 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 118.0 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 ~ l Name Service Order Units e Nsam Rep Code Offset C hanne DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWDO80 OHMM 4 1 68 16 5 FET MWDO80 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 Fi rst Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5747.5 13408.5 9578 15323 5747.5 13408.5 RPD MWD080 OHMM 5.49 2000 60.206 15214 5747.5 13354 RPM MWD080 OHMM 5.18 2000 57.9369 15214 5747.5 13354 RPS MWD080 OHMM 5.04 2000 60.0913 15214 5747.5 13354 RPX MWD080 OHMM 4.8 2000 57.6284 15214 5747.5 13354 FET MWD080 HOUR 0.21 212.59 1.12506 15214 5747.5 13354 GR MWD080 API 34.31 131.95 69.5273 15200 5747.5 13347 ROP MWD080 FT/H 1.71 494.55 178.132 15269 5774.5 13408.5 First Reading For Entire File..........5747.5 Last Reading For Entire File...........13408.5 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/06/21 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