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206-133
• • Image Project Well History File hover 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 - ~~~ Well History File Identifier Organizing (done) ^Two-sided III IIIIII II III II III ^ Rescan Needed RESCAN ^ Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: DIGI AL DATA Diskettes, No. p~. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: y~Q ^ Other:: BY: aria Date: 3~ (J u /s/ Project Proofing III II'lll IIIII II III BY: Maria Date: ~ 3~ f~ 0 /s/ Scanning Preparation ~_ x 30 = + =TOTAL PAGES v Q~ ount does not include cover sh ) BY: Maria Date: ~ 3 ~ 0 CJ lsl Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scannin Preparation: _~~ES NO BY: Maria Date: ~ ~ ~~ ,U g /s/ r VI 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 III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked -f= 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMI SION ' REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well r Plug Perforations r Perforate r Other p ESP to Gas Lift Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: - ConocoPhillips Alaska, Inc. Development 'r Exploratory r 206-133 • 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23321-60 . 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25662,ADL 380058 i f}S)1,00 1.6 Ci<0I 1J-182L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): E Kuparuk River Field/West Sak Oil Poo 11.Present Well Condition Summary: NOV Total Depth measured 17757 feet Plugs(measured) None #� true vertical 3271 feet Junk(measured) None AOC, Effective Depth measured 17752 feet Packer(measured) 0 true vertical 3271 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR IN 77 20 120 120 0 0 SURFACE 3631 13.375 3673 2151 0 0 INTERMEDIATE 9084 9.625 9121 3432 0 0 D-SAND LINER 8441 6.41 17754 3271 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 9373-10118,10159-17709 True Vertical Depth: 3360-3351,3352-3272 RECEIVED Tubing(size,grade,MD, and TVD) 4.5, L-80,8038 MD,3122 TVD SCANNED NOV 22 2013 Packers&SSSV(type,MD,and TVD) Packer=NONE AOGCC SSSV=NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 736 132 94 175 203 Subsequent to operation 760 398 129 652 221 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development i • Service r Stratigraphic r 16.Well Status after work: Oil p- • Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Bob Christensen/Darrell Humphrey Email n1139(c�conocophillips.com Printed Name Darrell R. Humphrey Title NSK Production Engineering Specialist Signature _`\ _ >\,- Phone:659-7535 Date / , 2. D • /`3 Ir'LF 4� RBDMS NOV 2 5 O Form 10-404 Revised 10/2012 /2/t eG G 3 Submit Original Only • • t 1J-182L1 ` DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/23/13 Open Well-Return to gas lifted production 10/21/13 (AC EVAL) MIT-OA PASSED TO 1200 PSI. 09/29/13 Pulled TTCESP f/Deployment Flange. JOB Complete. 09/28/13 ENGAGE AND PULL ESP PUMP AT 7987'CTMD. POOH, HANG ESP IN PANCAKE FLANGE AT SURFACE. PANCAKE LOCK DOWN SCREWS AT 5-1/2 TURNS EACH. READY FOR SLICKLINE. KUP PROD • 1J-182L1 ConocoP1MMMi s 0-:' Well Attributes Max Angle&MD TD • Alaska. Wellbore API/UWI Field Name Wellbore Status Inc!I°) MD OMB) Act Btm(ftKB) rlapc 500292332160 WEST SAK PROD 94.16 13,045.01 17,757.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1J-182L1,11/11/20136:29:56 PM SSSV:NONE 0 8/14/2012 Last WO: 7/7/2010 43.51 1107/2006 Venical schematic(actual) Annotation Depth(ftKB) End Date Annotation -Last Mod By End Date Last Tag: Rev Reason.GLV C/O lehallf 11/11/2013 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 1,TNGER;35.a j r D-SAND LINER 41/2 3476 9,313.5 17,754.0 3,271.3 11.60 L-80 ^ + Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inc!(°) Item Des Corn lin) 9,313.5 3,360.8 90.55 SLEEVE BAKER HR LINER SETTING SLEEVE 5.750 -- - - 9,371.2 3,359.8 91 24 XO BUSHING BTC CROSSOVER BUSHING 3.930 t Perforations&Slots Shot Dens ll Top(TVD) Btm(TVD) (shotslf Top(ftKB) Btm( KB) (ftKB) MKS) Zone Date t) Type Corn 4,829.0 4,913.0 2,416.9 2,435.2 WS B,1J- 10/2/2006 32,0 SLOTS ALL PERFS IN CONDUCTOR Insulated;43.0- 182L1 WELLBORE:Alternating 120.0 solid/slotted pipe- .,nv�� 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non ESP Mandrel;1,975.6 -slotted ends 9,373.0 10,118.0 3,359.8 3,351.0 WS D,1J- 11/6/2006 32.0 SLOTS 182L1 10,159.0 17,709.0 3,350.9 3,272.1 WS D,1J- 11/6/2006 32.0 SLOTS 182L1 Notes:General&Safety End Date Annotation 11/14/2006 NOTE:MULTI-LATERAL WELL: 1J-182(B-SAND),1J-182L1(D-SAND) /{{ 2/3/2009 'NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE;42.a-3,673.4 , CMT SHOE;2,673.0 SLOTS;4,829.0-4913.0 DISCHARGE;7,962.3 a r- ESP INTAKE;8,038.3 'Olio SEAL Upper;8,049.0 in ail SEAL Lower;8,055 9 Mt o ESP MOTOR;8.062.8 d SENSOR.8,088.2 I• Centralizer;8,090.3 D-SAND LINER HH;9,118.0- 9.358.D3 INTERMEDIATE;37.19.831.0 • • SLOTS;9,373.0-10.118.0 SLOTS;10.159.0-17,709.0 D-SAND LINER;9 313 5- 17,754 0 STATE OF ALASKA ALASKF~ AND GAS CONSERVATION COMMIS~J REPORT OF SUNDRY WELL OPERATIONS 1. operations Performed: Abandon ~ Repair w ell Rug Perforations ~""' Stimulate ~ Other "` Alter Casing ~"° Pull Tubing Perforate New Fbol ~ Waiver ~ Time Extension Change Approved Frogram Operat. Shutdown Perforate J"" Re-enter Suspended Well 2. Operator Name:. 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory J"° 206-133 3. Address: Stratigraphic Service .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23321-60 7. Property Qesignatict~: \ ~ ~ 8. Well Name and Number. ADL 25662, 380058 _ ~, , ` ' f (~ 1J-182L1 9. Field/Pool(s): ~, Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 17757 feet Plugs (measured) None true vertical 3271 feet Junk (measured) None Effective Depth measured 17752 feet Packer (measured) no packer true vertical 3271 feet (true vertucal) no SSSV Casing Length Size MD ND Burst Collapse CONDUCTOR IN 77 20 121 121 SURFACE 3630 13.375 3673 2151 INTERMEDIATE 9084 9.625 9831 3432 D-SAND LINER 8441 4.5 17754 3271 ~r '~) ~ :t3 1+`+~i~g,r t`a~~1s ~., ix ~ Perforation depth: Measured depth: 9373'-10118', 10159'-17709' ~:~ ~` ~' True Vertical Depth: 3360'-3351', 3352'-3272' ~~~~~~~D ~U~, U ~ 2010 Tubing (size, grade, MD, and TVD) 4.5, L-80, 8092 MD, 3135 TVD Alaska ('!!f ~ Ga: ~~er~. C~missifm Packers &SSSV (type, MD, and TVD) no packer ~gf,~~f.3~~ no SSSV 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 580 41 29 -- 201 Subsequent to operation 897 70 17 -- 201 13. Attachments 14. Well Class after proposed work: ~1 " Copies of Logs and Surveys run ~` Service Exploratory Developmeinfi ~ 15. Well Status after work: Oi Gas WDSPL Daily Report of Well Operations XXX GSTOR ~""'" WAG ~""` GASINJ ~ WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Erik Nelson ~ 263-4693 Printed Name ~c elso -4693 ~ Title Wells Engineer Signature `, Phone: 263-4693 Date,,, ~~ ~~~~ ~' / RBDMS AU6 ~ 6 2010 ~ d' G ~o Form 10-404 Revised 7/2009 ~ Submit Original Only -- ' - KUP - 1J-182L1 -'' ~l)t'lO~{~P~'11~~1~}~ ~, 'I Well Attributes ( wT,--- ___-_ tt _ IMax A ° I ngle 8 MD ,TD '' ~ }K:. Welllwre APVU WI Feltl Name Well Status lncl ( ) ACt Bim (ftKB) MD (ftK8) ~ 500292332160 WEST SAK ~~ ~ PROD 94.16 13.045.01 17,757.0 Comment H25 (PMn) Annotation End Date Date ~KB-Grd (fl) ~. Rig Release Da' SSSV NONE Il 0 a ( ( ( 7/10/2009 Last WO~ 7/7/2010 4351 ', 11/17/2006 _ w_en _ nttg ~JJ Tn1/2 -~ pp Actu ,n o1G toT SS al - Annotat r Depth (ftKB) End Dale Annotation ~ L tM d...End Date __ _. o ( ( Last Ta ( Rev Reason: WORKOVER Imosbor 7;11/201 --- _- Casing Stria s HANGER, 35-- --- --- - Casing Des 'pt on St g O .Str' g ID.. Top (ftKB( Set Depth (f .Set Depth (ND) . St mg Wt .Str g Stri g Top Thrd t- D SAND HH 4 1/2 4-000 9,118 0 9 358.0 3,360 1 11.60 L 80 ''' Casing Des r ption St g O Str ng ID . Top (ftK8) Set Depth (f... Set Depth (ND) . Stang Wt... Str g String Top Thrd - D SAND LINER 4 1/2 i 3-958 9,313.5 17 754.0 3,271 3 _ 11.60 L 80 __ _ Liner Details ___ __ Top Depth ', ', (ND) Top Incl Nom -"' Top (ftKB) (ftK8) (~) Item Description Comment ID (i 9,313 5 SLEEVE 3,36Q5~ 90.55 BAKER HR LINER SETTING SLEEVE 5.7 ' 9.371.2 3,359.5 90 43 XO BUSHING BTC CROSSOVER BUSHING 3.9 ' Perforations & Slots - - _ - __ _-- -- --_ ~~ ~ s ToP (TVDI Btm (NDI ~I 'i Den coNDUCroR ms~lalea. 63120 ESP Mantlret. 1 5]6 SURFACE,- a3-3,673 DISCHARGE, - ],962 10,1591 17 709 3,351.91 3,2721 WS D, NOTE: VIEW SCHEMATIC w/Alaska SchemaGc9.0 PERFS IN WELLBORE: ~nating solid/slotted pipe - S"x2.5" @ 4 circumferential cem rows, 3" centers staggered eg, 3' non-slotted ends PERFS IN WELLBORE: Hating solitllslotted pipe - 5"x2.5" @ 4 circumferential cent rows, 3" centers staggered eq, 3' non-slotted ends ESP INTAKE, 8,036- SEAL Upper, _ 8,049 ~- SEAL LOwer,_ 8,056 ~_ ESP MOTOR, 6,063 ~\ SENSOR, }r 6,086 @ t a _ Centralizer. 6.090 D-SANG HH. -- 9,116-9,358 I ' SLOTS, ' 9,3]3-10,118 ERMEDIATE, 37-9.631 1 Y SLOTS, _ 10,159-17,]09- e~..~e 0-SAND -~ LINER, 9,313-1],754 17.757 Valve Run Date I Com... 1J-182 Pre and Post Rig Summary • DATE SUMMARY 4/22/10 REPLACED 2000 PSI SHEAR VAL @ 2036' RKB. READY FOR CTU. 4/25/10 CLEAN OUT THICK CRUDE TO TOP OF SLIP STOP @ 7992' CTMD W/SLICK DIESEL & DIESEL GEL. NO SOILDS NOTICED IN RETURNS, IN PROGRESS. 4/26/10 PULL 4.5" SLIP STOP & PACK OFF @ 7992' CTMD. IN PROGRESS. 4/27/10 PULLED 48.65' FC 600 ESP FROM 8011 CTMD, WASHED PUMP WITH 50 BBLS DIESEL DOWN BACKSIDE, SET IN DEPLOYMENT FLANGE IN TREE. READY FOR S/L. 5/4/10 PULLED 48', 4-1/2 TTCESP PUMP IN DEPLOYMENT SUB IN TREE, SHOOK OFF NEW 47.88' OAL 4-1/2 TTCESP IN TBG @ 860' SLM, RDMO. READY FOR COIL. 5/5/10 INSTALLED 4-1/2 TTC ESP @ 8806 CTMD, RAN PACKOFF ASSEMBLY & SLIP STOP ON TOP OF PUMP. READY FOR S/L TO REPLACE SOV. 5/7/10 PULLED SOV @ 2036' RKB, " IT WAS NOT SHEARED", SET NEW 2000# SOV @ 2036' RKB, COMPLETE. 5/14/10 PULLED 4.5" SLIP STOP @ 7992' CTMD. PULLED 4.5" PACK OFF @ 7995' CTMD. NOTE: PULLED W/OUT JARRING; ELEMENT WAS NOT SET. JOB IN PROGRESS. 5/15/10 SET 4.5" PACK OFF (W/ 4' EXT PUP, DETAILS ABOVE) @ 8004' CTMD. PT TO 440 PSI, GOOD. SET 4.5" SLIP STOP ON PACK OFF @ 7991' CTMD. WELL STILL DIESEL PACKED. JOB COMPLETE. 6/20/10 PERFORM PASSING WEEKLY BOP TEST. TAG SLIP STOP @ 7991' CTMD, NO FILL APPARENT. WASH HEAVY CRUDE OUT OF TBG W/SLICK DIESEL & DIESEL GEL. IN PROGRESS. 6/21/10 PULL 4.5" SLIP STOP @ 7992' CTMD. PULL 4.5" PACKOFF @ 7996' CTMD. IN PROGRESS. 6/22/10 PULLED 48.65' TTC ESP FROM 8003 CTMD, SET IN DEPLOYMENT FLANGE IN TREE. READY FOR S/L. 6/25!10 PULLED 48' x 4-1/2"TTCESP f/ DEPLOYMENT FLANGE. SET CATCHER. PULLED SOV @ 2036' RKB, SET DV @ SAME. PULLED CATCHER. COMPLETE. 7/1/10 PRE RWO T-POT BONNET( FAILED), T-PPPOT BONNET (PASSED ), T-POT UPPER BODY PASSED ), T-PPPOT UPPER BODY..( PASSED ), T-POT LOWER BODY (PASSED ), T-PPPOT LOWER BODY (PASSED ), IC POTS PASSED, FT-LDS ALL NORMAL. 7/5/10 FISHED ~6' x 3' PIECE OF ABSORB @ 798' SLM. SET 4.5" ESP PUMP (OAL= 52') @ 312' SLM. SET D&D PACKOFF @ 260' SLM (TOP @ 252' SLM/ OAL= 8' 4"). TESTED PACKOFF TO 1000#. ***PASS***. SET 4.5" TBG STOP @ 252' SLM. JOB COMPLETE. 7/6/10 ""RIG JOB "", CHANGE OUT SV FROM IA X TUBING, TO 2000# TUBING X IA SV a ~~ Conoc©Phillips Time Log & Summary iNeflview Web Reporting Report Well Name: 1J-182 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 7/3/2010 2:30:00 PM Rig Release: 7/7/2010 8:00:00 AM Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 7/02/2010 24 hr Summary Completed 3B-14 Well. RDMO. Begin Rig move to next Location. 16:30 00:00 7.50 MIRU MOVE MOB P Start moving rig from 3B pad toward 1 J ad. 7/03/2010 Continue moving Rig to 1 J-Pad. MIRU. Rig up Lines. Pull BPV. Bullhead kill Well. 00:00 13:30 13.50 MIRU MOVE MOB P Continue moving Rig to 1J-Pad. Moving slower because DTH short handed and movin ri mats slow. 13:30 14:00 0.50 MIRU RPCOM RURD P Spot rig on double mats. Rig up containment (Handy Berm). Acccepted Nordic 3 rig @ 1400 hrs. 7-3-2010 14:00 18:30 4.50 MIRU RPCOM RURD P Set kill tank and hook up hard line. Set cuttings box and berm up containment. LRS heating fluids and loading pits with 160° SW w/6% KCL. Pull 4" Type H BPV. TP = 300 psi, IAP = 300 psi, OA = 100 si. 18:30 20:00 1.50 COMPZ RPCOM KLWL P Rig up Lines in Celler. Pressure test lines at 250/2,500 psi. Good. Continue to off-load fluids in Ri Pits. 20:00 22:00 2.00 COMPZ RPCOM KLWL T Waiting for third Vac Truck to arrive on location with remaining hot Sea Water. 22:00 00:00 2.00 COMPZ RPCOM CIRC P PJSM. Bullhead 125 bbls down the Tubing at 4.0 bpm/80 psi. Then Bullhead down the IA at 7.0 bpml500 si. 7/04/2010 ND Tree. NU BOPE. Test BOPE. Begin to POOH with 4 1/2" ESP Completion. 00:00 02:00 2.00 COMPZ RPCOM CIRC P Finish Bullhead killing IA. Monitor Well. However, had some gas at surface in tubing and then some on the IA. Shut in Well. Tbg = 120 psi IA = 220 psi. Line up to pump down the Tubing and route IA gas through the Choke to the Tiger Tank. Pump down the Tubing at 4.0 bpm/70 psi. Gas bled down to "0" psi in just a couple of minutes. Continue to pump a Tubing volume (125 bbls). Monitor Well. Both sides on a vacuum. 02:00 03:30 1.50 COMPZ RPCOM NUND P Set BPV. Nipple down Tree. Inspect top Hanger Threads. Good. Set Blanking Plug. Function all LDS. Page 1 of 4 Time Los Date From To Dur S. De tFi: E`. De the Phase Code Subcode T Comment 03:30 07:30 4.00 COMPZ RPCOM NUND P Nipple up BOPE. 07:30 12:00 4.50 COMPZ WELCTt ROPE P Function & Pressure Test BOPE and choke 250/2500 psi. Test good. the Stare's right to witness the test was waived b J. Jones. 12:00 14:00 2.00 COMPZ RPCOM NUND P Pull blanking plug, pull BPV. Pumped 100 bbls down tubing 7 BPM @ 90 psi, 100 bbls down IA 7 BPM 260 si 14:00 17:00 3.00 8,099 COMPZ RPCOM NUND P BOLDS. Unset tubing hanger with 200K. Pulled hanger to rig floor at 115K. Well on slight vacumm. Remove Penetrator. LD tubing han er, strin flat cable over sheave. 17:00 00:00 7.00 800 COMPZ RPCOM PULL P POOH with ESP Completion, standing back 41/2" tubing, removing cannon clamps and s oolin u flat cable. 7/05/2010 Complete POOH with 4 1/2" Completion. Pick up and service new ESP Completion Assembly. RIH with new 4 1/2" Com letion. 00:00 02:00 2.00 800 63 COMPZ RPCOM PULL P Finish POOH with 4 1/2" ESP Completion. Pull ESP Cable over Sheave. Wrap ESP Cable Reel and prep for crane lift. Recovered 231 Cannon clamps, 3 Protectors, 2 ea 6-ft Flat Guard. Recovered 5 SS Bands. Lost 7 in the hole. The entire Tubing String looked good. Pull samples off of ESP sections. Initial findings. Water in Motor. Burnt Oil. 02:00 04:00 2.00 63 0 COMPZ RPEQPI PULD P PJSM. Spot crane and pick used ESP Cable/Reel off of Rig floor. Lift new ESP Cable and set on Ri floor. 04:00 05:30 1.50 0 COMPZ RPCOM PULD P Continue breaking down and lay down ESP sections. Take oil sam les, LD & BD ESP. 05:30 07:30 2.00 COMPZ RPCOM PULD P Clean rig floor. Box up ESP equip. and move out of i e shed. 07:30 11:00 3.50 COMPZ RPCOM RCST P PJSM. PU& service motot section and PU motor. Centrilift Tech. using absorb for hole cover around split table. When lowering motor in hole pulled absorb downhole and absorb dropped down hole. Pulled motor section back out and stand back out of wa . 11:00 13:00 2.00 COMPZ RPCOM FISH T PJSM with slickline crew. RU slickline and RIH w/4 prong wire grab with 6" OD. Grabbed fish (absorb) @ 750' and POOH. Recovered all of absorb. RD slickline. Page 2 of 4 Time Los Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13:00 15:00 2.00 COMPZ RPCOM RCST P PJSM. PU motor centralizer, A-well 1-pump Sensor, and motor and place assembly in hole. Record breakaway & rotational shaft torque of the motor. PU the tandem seal section, check and record it's breakaway and rotational shaft torque. Assemble seal section to motor. Service the seal section and then check & record the shaft torque values of the entire assembl . 15:00 15:30 0.50 0 355 COMPZ RPCOM RCST P MU the first 2 jts of the 41/2" tbg to the handling pup. Install a Cannon cross-coupling cable clamp. Install the Unique discharge pressure sub and connect the discharge pressure capillary tubing and test. Continue RIH w/the ESP com letion to 335'. 15:30 19:30 4.00 355 355 COMPZ RPCOM RCST P PJSM. RU HES Slickline. RIH w/ESP pump w/gas separator. Set pump. Set packoff on top of pump and PT to 1000 psi. for 15 min. Set sli sto and RDMO HES slickline. 19:30 00:00 4.50 355 3,700 COMPZ RPCOM RCST P Continue RIH with ESP Assembly on 4 1/2" Tubing. Install Cannon Clamps. Perform electrical checks eve 1,000-ft. 7/06/2010 Complete ROH with 4 1/2" ESP Completion. ND BOPE. NU Tree and test. RU S-line. 00:00 04:30 4.50 3,700 7,500 COMPZ RPCOM RCST P Continue RIH ESP Assembly on 4 1/2" Tubing from 3,700-ft. Pick-up Camco 4 1/2" x 1" KBMG w/DCK-2 Shear Valve. Continue with 4 1/2" Tubing. Stop to splice in additional ESP Cable. 04:30 05:30 1.00 7,500 7,500 COMPZ RPCOM RCST P PJSM. Spot Crane. Prep to swap out ESP Reels. Pull empty ESP Reel off of floor. Pick-up Reel with additional ESP Cable a set in S ooler on Ri floor. 05:30 09:00 3.50 7,500 7,500 COMPZ RPCOM OTHR P Splice in additional length of ESP Cable and test - ood. 09:00 09:30 0.50 8,057 8,057 COMPZ RPCOM TRIP P RIH f/ 7,500' to 8,057' 09:30 10:00 0.50 8,057 8,057 COMPZ RPCOM OTHR P PU and MU hanger -prep for final s lice. 10:00 12:00 2.00 8,057 8,057 COMPZ RPCOM OTHR P Make final splice and connect to penetrators. Surface test guages (PI- 978 psig, DP -1,002 psig, IT - 60.1degrees) and ESP cable (P\P - 2.6, P\Grd - 1.0 thru enatrators. Page 3 of 4 Time Lo s Date From To Dur S. De th E. De th Phase Gode Subcode T Comment 12:00 13:30 1.50 8,057 8,092 COMPZ RPCOM HOSO P Land hanger (115k up wt ! 52k do wt) w/ tail @ 8,092', RILDS, and test upper and lower pack offs - 250/5,000 psig for 10 minutes. 230 - 4.5" X-cplg clamps 6 - SS Bands 3 - Protectrolizers 1 - 5.13" x 4 .5" X-cplg clamp 4 - 5.13" Cannon clam 13:30 14:00 0.50 8,092 36 COMPZ WELCTL MPSP P Back out landing jt and install BPV 14:00 16:00 2.00 36 0 COMPZ WELCTL NUND P Change UPR's f/ 4.5" to 3.5", ND BOPE - Test guages and ESP cable - ood test 16:00 18:00 2.00 0 0 COMPZ WELCTL NUND P Set test plug and NU Tree - 4.063" 5M Horizontal Producer. Test void @ 5,000 psi and Test tree @ 25015,000 si. Good test. 18:00 18:45 0.75 0 COMPZ WELCTL MPSP P Lubricate out TWC. Lay down same. 18:45 00:00 5.25 COMPZ RPEQPI SLKL T PJSM. Rig up HES Slick Llne Unit. RIH with Catcher Sub. Had problems setting Catcher Sub. RIH and pull DCK-2 Shear Valve from GLM at 1.975-ft. 7/07/2010 Ru S-Line and pull SOV. Lil' Red Freeze Protect Well. S-Line set SOV. 00:00 00:30 0.50 COMPZ RPEOPI T Recovered DCK-2 Valve from GLM at 1,975-ft. S-Line stand-b . 00:30 03:00 2.50 COMPZ RPCOM FRZP P PJSM to Freeze Protect Well. Lil' Red Pump down the Tubing with Diesel at 2.0 bpm/400 psi. Total Diesel pumped 215 bbls. RD Hot Oil Unit. 03:00 06:00 3.00 COMPZ RPEQPI SLKL T S-Line RIH and attempt to set SOV back in GLM at 1,975-ft. Having troubles locating pocket. Set SOV. PUII Catcher Sub. Ri down S-line. 06:00 07:00 1.00 COMPZ WELCTL MPSP P Set BPV and dress tree 07:00 07:30 0.50 COMPZ MOVE RURD P Move rig off well 07:30 08:00 0.50 COMPZ MOVE OTHR P Clean up well area and move matting. Sign off well to Production. Nordic Rig 3 released @ 08:00 hrs on 7-7-10. Page 4 of 4 s ~v ~'~ _. w ;. ~~ MICROFILMED 6/30/2010 DO NOT.PLACE ANY NEW MATE R1AL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc DATA SUBMITTAL COMPLIANCE REPORT 10/13/2008 Permit to Drill 2061330 Well Name/No. KUPARUK RIV U WSAK 1J-182L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23321-60-00 MD 17757 TVD 3271 Completion Date 11!17/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Type , Med/Frmt Number Name Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments ~,8~ D Asc I Directional Survey `I T~'D~ D Asc Directional Survey ~~D C Lis i 14518 Induction/Resistivity C L s 14518 Induction/Resistivity ~~A C 15903 Induction/Resistivity i ~~ED C 15904 Induction/Resistivity 12978 17757 Open 1/29/2007 9090 13487 Open 1/29/2007 PB 1 3638 17757 Open 3/16/2007 LIS Veri, GR, ROP, FET 3638 13487 Open 3/16/2007 P61 LIS Veri, GR, ROP, FET 2156 3721 Open 2/6/2008 MD and TVD of EWR and DGR in EMF, PDF and CGm graphics 2156 3306 Open 2/6/2008 P61 MD and TVD of EWR, DGR and ROP in EMF, PDF and CGm graphics Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORM/;~ION Well Cored? Y /r`N\~ Daily History Received? Chips Received? 'f-fiV~• Formation Tops ~N Analysis ~l, Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 10/13/2008 Permit to Drill 2061330 Well Name/No. KUPARUK RIV U WSAK 1J-182L1 Operator CONOCOPHILLIPS ALASKA INC MD 17757 TVD 3271 mpletion Date 11/17/2006 Completion Status 1-OIL Current Status 1-OIL - ------- Compliance Reviewed By: _ ~~ -_---_----..- _.___._ -- Date: API No. 50-029-23321-60-00 UIC N U ~` ,~ -~.. -~ ~ ~ , ~;~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-182+L1+L1PB1 ,,;. February 1, 2008` AK-MW-4665704 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-182+L1+L1PB1: Digital Log Images 50-029-23321-00,60,70 1 CD Rom 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~Blvdp, An lc'S° Date: ~"!~ ~~? r^ ~?~ f?~ ~~ -; 3a rS 9va Signed: ~o~-t33 1 s'Sv3 pat ~g`io~/ WELL LOG TRANSMITTAL To: State of Alaska February 09, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data: 1J-182, Ll PB1 & L1, AK-MW-4665704 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23321-00, 70 & 60 !~ ~ ~~~ ~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNL~'G AND RETL`RNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~ ; ~. ~ _~ Date: . ~~s^ _ ~ ~~~; -~ _vvs -' Signed: f ~~ r~ ~ 1 ~° ~~L--1~ ~o~-r3~ iLr~r`~f - - STATE OF ALASKA ~ ~A~ 1 ~G Q] ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPO'I~`ai~°~~€~~mmission ta. Well Status: Oil ^ _ Gas Plugged ^ Abandoned Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other 1 b. Well Class: "' Development ^/ ~ Exploratory ^ ^ StratigraphicTest^ Service 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: November 17, 2006 12. Permit to Drill Number: 206-133 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: -/~ V Z~ ZD~. /" _ ~. (»• 13. API Number: 07 50-029-23321-60 • 4a. Location of Well (Governmental Section): Surface: 1570' FSL, 2434' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: November 7, 2006 14. Well Name and Number: 1J-182L1 At Top Productive Horizon: 598' FNL, 1055' FWL, Sec. 11, T10N, R10E, UM 8. KB Elevation (ft): 40' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1350' FSL, 1167' FWL, Sec. 14, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 17752' MD / 3271' TVD West Sak Oil Po01 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558780 y- 5945382 Zone- 4 10. Total Depth (MD + ND): 17757' MD / 3271' ND 18. Property Designation: ADL 25662, 380058 TPI: x- 557054 y- 5937922 Zone- 4 Total Depth: x- 557242 - 5929313 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 2177, 4604 18. Directional Survey: Yes Q No^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3670' MD 21. Logs Run: ~ !,~ y/2/ /~9D 3 3S/ ~ Ti'•a -D i• iq.~7 GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE TI AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMEN NG RECORD PULLED 20" x 34" 62.6# H-40 40' 121' 40' 121' 42" 38o sx AS 1 13.375" 68# L-80 40' 3673' 40' 2151' 16" 72o sx ArcticSet Lite, 185 sx LiteCRETE 9-5/8" 40# L-80 40' 9831' 40' 3432' 12.25" 287 sx LiteCRETE 4.5" 11.6# L-80 9117' 17754' 3350' 3271' 6.75" slotted liner 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 8099' 9176' slotted liner from 17709'-10159', 10117'-9373', 9284'-9202' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production December 21, 2006 Method of Operation (Flowing, gas lift, etc.) ' ESP Lift Oil producer -shares production with 1J-182 Date of Test 1/4/2007 Hours Tested 22.5 hours Production for Test Period--> OIL-BBL 1546 GAS-MCF 1067 WATER-BBL 48 CHOKE SIZE 31% GAS-OIL RATIO 690 Flow Tubing press. 250 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1536 ~ GAS-MCF 964 WATER-BBL 46 OIL GRAVITY -API (corn) not available 27. CORE DATA Brief description of Iithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". NONE .._ ~ - Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~6 ~~ /-/9.0'7 za. zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1J-182L1 Top West Sak D 9120' 3351' Base West Sak D 17757' 3271' 1J-182L1 P61 TD 13487' 3306' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Casing Detail Sheets 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Nugent @ 265-6862 Printed Na RaAS o as Title: Greater Kuoaruk Area Drillino Team Leader (~S S r~ ~ ' w ° Signature --------~~,ne ° Date i--~-.- ~- 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 1212003 1J-182'D' Sand Liner Detail well: 1J-182 "~"'' y y 4 T/2" Slotted Liner Date: 11/6/2006 CL?~t3CE?~~~I~~~S Plop & Drop Ataska, tne. F/NAL DETAIL DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS Note: "D" lateral window to 9121'/ Bttm 9138.22' TOL 176' out in open hole 5" DP to Surtace ==> crossover 41/2 IF box x 3-1/2 IF pin Liner Runnin Tool 3-1/2" IF" Does not sta in hole 7.20 9306.72 51/2" Baker "HR" Liner Setting Sleeve (6.41" O.D. x 5.75" I.D.) 12.67 9313,92 51/2", 15.5 ppf, L-80, Hydril 521 Pup Jt (4.90" I.D.) 7.37 9326.59 5 1/2", 15.5 ppf L-80, Hydril 521 blank casing (4.91" I.D.) 37.68 9333.96 5-112" Hydril 521 x 4-112" BTC XO Bushing (3.93" I.D.) 1.40 9371.64 Jts 178 to 195 18 Jts ~»~*' ~~ ~ $~ ~~'~ ~~~ j~~ ~ <: . ; 744.51 9373.04 4-1/2" Hydril 521 box x 4-1/2" BTC in Crossover JT 41.50 10117.55 Jts 1 to 177 177 Jts 4-1/Z",11.6 f, L-80, BTC Slotted Casing 7550.34 10159.05 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.32 17709.39 4-112" Silver Bullet Shoe 1.29 17752.71 17754.00 Bttm of Tail =_> 17754.00 TD 6 3/4" hole 17757' MD/ 3271' TVD 91 Deg 3-1/2" Shoe 17752 MD?/ 3271' TVD (5' Rathole) Total Parts used: 194 stop rings 194 H draFORM Centralizers 41/2" x 6.13" Run 1 HydroForm per jt floating with a sto ring in center of each jt. f/ Jt 2 thru Jt 195 4.5" X 6.13") Coverage of Centralizers f/ 17670' to 9400' Ran total of 1 jts Blank= 28.80' and 196 jts Slotted= 8294.85' ,Slots are Up Wt ???K w! (32) 2.5" long x .125" 4 Circumferential adjacent rows, 3" Centers Dn Wt ???K staggered 18 deg., 3 ft. non-slotted ends Block Wt ??K Used Run-N-Seal thread com ound on all connections. Rot Wt ???K Drifted casing to 3.833" w/ teflon rabbit. Liner Wt ??k Torque Rings Installed in joints 78 Thru 177 Supervisors: Fred Herbert/ Granville Rizek Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12/21/2006 Time: 10:23:21 Page: t ' Field: Kuparuk River Unit Co -ordinate(NF.) Reference: Well: 1 J-182, Tru e North + ' Site: Kuparuk 1J Pad Vertical ("fVD) Re ference: 1J-182L1: 121:3 Well: 1J-182 Section (VS)Referencei Well (O.OON,O.OOE,180.OOAzi) V1'ellpath: 1 J-182L1 Survey Calculation Method: Minimum Curvat ure 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 System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 __ Well: 1J-182 Slot Name: ' ~; Well Position: +N/-S -537.96 ft Northing: 5945381.64 ft Latitude: 70 15 40.967 N +E/-W -14.46 ft Easting : 558779.69 ft Longitude: 149 31 29.427 W Position Uncertainty: 0.00 ft ~ ~ Wellpath: 1J-182L1 Drilled From: 1J-182L1P61 500292332170 Tie-on Depth: 12978.05 ft Current Datum: 1 J-182L1: Height 121.30 ft ~ Above System Datum: Mean Sea Level Magnetic Data: 10/4/2004 Declination: 24.63 deg Field Strength: 57562 nT Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.30 0.00 0.00 180.00 Survey Program for Definitive Wellpath -' Date; 12/21/2006 Validated: No Version: 6 ~~ Actual From To Survey Toolcode Tool Name ft ft 100.00 891.00 1J-182 gyro (100.00-891.00) (0 CB-GYRO-SS Camera based gyro single shot 965.65 9090.74 1J-182 (965.65-17809.76) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9121.00 12978.05 1J-182L1 PB1 (9121. 00-13453.19) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 13045.00 17720.94 1J-182L1 (13045.00-17720.94) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ;bID Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg .deg ft ft ft ft ft ft ' 40.30 0.00 0.00 40.30 -81.00 0.00 0.00 5945381.64 558779.69 TIE LINE 100.00 0.46 219.18 100.00 -21.30 -0.19 -0.15 5945381.45 558779.54 CB-GYRO-SS 200.00 1.28 161.70 199.99 78.69 -1.56 -0.05 5945380.08 558779.65 CB-GYRO-SS 300.00 3.71 160.11 299.89 178.59 -5.66 1.40 5945375.99 558781.13 CB-GYRO-SS 400.00 5.02 173.55 399.60 278.30 -13.05 2.99 5945368.61 558782.78 CB-GYRO-SS 496.00 4.32 196.16 495.29 373.99 -20.70 2.46 5945360.96 558782.31 CB-GYRO-SS 515.00 4.27 202.60 514.23 392.93 -22.04 1.98 5945359.62 558781.85 CB-GYRO-SS 604.00 6.22 210.98 602.86 481.56 -29.23 -1.77 5945352.40 558778.15 CB-GYRO-SS 696.00 9.33 212.56 694.00 572.70 -39.79 -8.35 5945341.79 558771.65 CB-GYRO-SS 796.00 11.10 214.50 792.41 671.11 -54.56 -18.17 5945326.95 558761.95 CB-GYRO-SS 891.00 13.12 207.22 885.30 764.00 -71.69 -28.28 5945309.74 558751.97 CB-GYRO-SS 965.65 17.65 204.41 957.25 835.95 -89.54 -36.84 5945291.83 558743.56 MWD+IFR-AK-CAZ-SC ~ 1059.65 23.06 203.22 1045.35 924.05 -119.45 -49.99 5945261.81 558730.63 MWD+IFR-AK-CAZ-SC 1155.97 25.75 204.96 1133.06 1011.76 -155.76 -66.26 5945225.38 558714.65 MWD+IFR-AK-CAZ-SC 1250.69 28.41 205.71 1217.39 1096.09 -194.73 -84.73 5945186.28 558696.50 MWD+IFR-AK-CAZ-SC 1346.86 33.42 206.63 1299.87 1178.57 -239.04 -106.54 5945141.80 558675.03 MWD+IFR-AK-CAZ-SC 1441.92 39.62 206.72 1376.23 1254.93 -289.57 -131.92 5945091.08 558650.05 MWD+IFR-AK-CAZ-SC 1536.64 44.17 205.50 1446.72 I 1325.42 -346.36 -159.72 5945034.08 558622.69 MWD+IFR-AK-CAZ-SC I 1631.87 48.85 206.13 1512.24 1390.94 -408.53 -189.81 5944971.68 558593.09 i MWD+IFR-AK-CAZ-SC 1726.65 51.15 206.14 1573.16 1451.86 -473.71 -221.79 5944906.26 558561.62 MWD+IFR-AK-CAZ-SC 1821.56 57.81 204.82 1628.27 1506.97 -543.42 -254.97 5944836.30 558528.99 MWD+IFR-AK-CAZ-SC 1916.82 62.86 202.74 1675.41 1554.11 -619.15 -288.30 5944760.32 558496.26 MWD+IFR-AK-CAZ-SC 2012.04 66.37 201.40 1716.22 1594.92 -698.86 -320.60 5944680.37 558464.58 MWD+IFR-AK-CAZ-SC 2108.02 70.76 197.96 1751.30 1630.00 -782.96 -350.64 5944596.04 558435.20 MWD+IFR-AK-CAZ-SC 2202.30 73.96 195.11 1779.87 1658.57 -869.08 -376.19 5944509.74 558410.34 MWD+IFR-AK-CAZ-SC 2297.82 74.95 193.03 1805.47 1684.17 -958.34 -398.55 5944420.32 558388.67 MWD+IFR-AK-CAZ-SC i 2392.80 74.79 191.54 1830.26 1708.96 -1047.92 -418.06 5944330.59 558369.86 MWD+IFR-AK-CAZ-SC I~ Halliburton Company Survey Report __ __ _ --- Company; ConocoPhillips Alaska Inc. Date: 12/21/2006 'l'ime: 10:23:21 Page: 2 I' Field: Kuparuk River Unit Co-ordinate(NE)Reference: Welt 1J-182, True North ',' Site: Kuparuk 1J Pad V""ertical(TVD)Refcrcnce: 1J-182L1: 121.3 Nell: 1J-182 Section (VS}Reference: Well (O.OON,O.OOE,180:OOAzi) I' Wellpath: 1J-182L1 Survey Calculation Mcthod: Minimum Curvature Db: Oracte Snrvcv 111D Incl :1zim T1'D Sys T1'D ~!S E/W )<1apN D4apE Tool ft deg deg ft ft ft ft ft ft 2488.25 74.98 191.95 1855.15 1733.85 -1138.14 -436.82 5944240.24 558351.81 MWD+IFR-AK-CAZ-SC 2583.30 73.42 192.50 1881.03 1759.73 -1227.52 -456.18 5944150.71 558333.15 MWD+IFR-AK-CAZ-SC 2677.40 75.11 190.79 1906.55 1785.25 -1316.22 -474.46 5944061.88 558315.57 MWD+IFR-AK-CAZ-SC 2773.73 75.91 190.11 1930.65 1809.35 -1407.94 -491.37 5943970.04 558299.37 MWD+IFR-AK-CAZ-SC 2868.62 76.05 191.13 1953.64 1832.34 -1498.43 -508.34 5943879.43 558283.11 MWD+IFR-AK-CAZ-SC 2964.60 74.05 189.95 1978.40 1857.10 -1589.59 -525.31 5943788.15 558266.86 MWD+IFR-AK-CAZ-SC 3060.06 74.55 188.86 2004.23 1882.93 -1680.25 -540.32 5943697.39 558252.55 MWD+IFR-AK-CAZ-SC 3153.82 75.48 190.85 2028.48 1907.18 -1769.48 -555.83 5943608.05 558237.75 MWD+IFR-AK-CAZ-SC ~ 3250.26 79.82 193.03 2049.10 1927.80 -1861.62 -575.32 5943515.77 558218.97 MWD+IFR-AK-CAZ-SC i 3343.91 77.81 193.02 2067.27 1945.97 -1951.12 -596.03 5943426.12 558198.97 MWD+IFR-AK-CAZ-SC 3439.43 75.29 193.97 2089.49 1968.19 -2041.45 -617.70 5943335.63 558178.00 MWD+IFR-AK-CAZ-SC 3534.69 73.75 193.01 2114.91 1993.61 -2130.71 -639.12 5943246.21 558157.28 MWD+IFR-AK-CAZ-SC 3627.32 75.85 192.86 2139.20 2017.90 -2217.83 -659.13 5943158.95 558137.96 MWD+IFR-AK-CAZ-SC 3674.33 73.59 192.99 2151.58 2030.28 -2262.03 -669.27 5943114.68 558128.16 MWD+IFR-AK-CAZ-SC 3728.38 73.03 193.90 2167.11 2045.81 -2312.38 -681.31 5943064.24 558116.52 MWD+IFR-AK-CAZ-SC 3767.32 74.03 195.01 2178.15 2056.85 -2348.54 -690.63 5943028.01 558107.48 MWD+IFR-AK-CAZ-SC 3814.35 75.20 195.04 2190.62 2069.32 -2392.33 -702.38 5942984.13 558096.07 MWD+IFR-AK-CAZ-SC 3862.80 76.55 195.54 2202.45 2081.15 -2437.65 -714.77 5942938.72 558084.03 MWD+IFR-AK-CAZ-SC 3957.65 75.95 195.37 2224.99 2103.69 -2526.45 -739.33 5942849.74 558060.18 MWD+IFR-AK-CAZ-SC 4051.61 76.29 195.25 2247.53 2126.23 -2614.43 -763.41 5942761.58 558036.78 MWD+IFR-AK-CAZ-SC 4146.61 77.59 195.02 2269.00 2147.70 -2703.76 -787.57 5942672.07 558013.32 MWD+IFR-AK-CAZ-SC 4193.74 77.89 195.13 2279.01 2157.71 -2748.23 -799.55 5942627.51 558001.69 MWD+IFR-AK-CAZ-SC 4242.12 75.85 195.08 2290.00 2168.70 -2793.72 -811.83 5942581.94 557989.77 MWD+IFR-AK-CAZ-SC 4338.69 76.70 195.04 2312.91 2191.61 -2884.31 -836.20 5942491.17 557966.11 MWD+IFR-AK-CAZ-SC 4432.61 78.83 194.61 2332.81 2211.51 -2973.03 -859.68 5942402.27 557943.32 MWD+IFR-AK-CAZ-SC 4528.23 77.20 194.15 2352.67 2231.37 -3063.63 -882.91 5942311.50 557920.80 MWD+IFR-AK-CAZ-SC 4623.98 77.65 191.67 2373.52 2252.22 -3154.72 -903.79 5942220.27 557900.64 MWD+IFR-AK-CAZ-SC 4719.02 78.38 189.93 2393.25 2271.95 -3246.04 -921.21 5942128.82 557883.93 MWD+IFR-AK-CAZ-SC 4813.42 76.99 192.60 2413.39 2292.09 -3336.48 -939.22 5942038.25 557866.63 MWD+IFR-AK-CAZ-SC ~ 4908.79 77.71 191.02 2434.28 2312.98 -3427.56 -958.26 5941947.04 557848.30 MWD+IFR-AK-CAZ-SC 5004.18 77.33 190.46 2454.89 2333.59 -3519.06 -975.62 5941855.41 557831.66 MWD+IFR-AK-CAZ-SC 5100.11 77.80 192.08 2475.55 2354.25 -3610.93 -993.92 5941763.41 557814.08 MWD+IFR-AK-CAZ-SC 5194.97 78.19 191.09 2495.28 2373.98 -3701.83 -1012.56 5941672.38 557796.15 MWD+IFR-AK-CAZ-SC 5245.05 76.50 191.04 2506.25 2384.95 -3749.78 -1021.93 5941624.36 557787.15 MWD+IFR-AK-CAZ-SC 5289.86 76.35 191.57 2516.77 2395.47 -3792.49 -1030.47 5941581.59 557778.95 MWD+IFR-AK-CAZ-SC 5383.69 76.38 189.94 2538.89 2417.59 -3882.07 -1047.49 5941491.88 557762.63 MWD+IFR-AK-CAZ-SC 5480.30 76.88 192.49 2561.23 2439.93 -3974.26 -1065.77 5941399.56 557745.07 MWD+IFR-AK-CAZ-SC 5575.36 77.14 193.16 2582.60 2461.30 -4064.58 -1086.33 5941309.10 557725.22 MWD+IFR-AK-CAZ-SC 5670.51 76.90 195.02 2603.97 2482.67 -4154.50 -1108.90 5941219.01 557703.36 MWD+IFR-AK-CAZ-SC 5765.44 77.68 195.42 2624.86 2503.56 -4243.86 -1133.21 5941129.48 557679.75 MWD+IFR-AK-CAZ-SC 5853.39 77.20 194.23 2643.99 2522.69 -4326.84 -1155.18 5941046.33 557658.43 MWD+IFR-AK-CAZ-SC 5955.75 77.69 193.94 2666.24 2544.94 -4423.75 -1179.49 5940949.24 557634.88 MWD+IFR-AK-CAZ-SC 6050.97 78.73 191.38 2685.70 2564.40 -4514.69 -1199.91 5940858.16 557615.17 MWD+IFR-AK-CAZ-SC ~i 6146.72 78.04 192.62 2704.97 2583.67 -4606.42 -1219.41 5940766.28 557596.39 MWD+IFR-AK-CAZ-SC 6242.35 78.50 193.52 2724.42 2603.12 -4697.63 -1240.59 5940674.92 557575.93 MWD+IFR-AK-CAZ-SC ~I 6336.27 78.57 193.82 2743.08 2621.78 -4787.07 -1262.34 5940585.33 557554.87 MWD+IFR-AK-CAZ-SC 6431.97 78.50 192.15 2762.11 2640.81 -4878.46 -1283.41 5940493.78 557534.52 MWD+IFR-AK-CAZ-SC 6524.99 77.16 190.37 2781.72 2660.42 -4967.63 -1301.17 5940404.48 557517.46 MWD+IFR-AK-CAZ-SC 6621.26 76.62 189.01 2803.56 2682.26 -5060.05 -1316.95 5940311.95 557502.40 MWD+IFR-AK-CAZ-SC 6716.43 74.40 190.42 2827.37 2706.07 -5150.86 -1332.50 5940221.03 557487.57 MWD+IFR-AK-CAZ-SC 6811.74 77.45 192.82 2850.55 2729.25 -5241.40 -1351.13 5940130.36 557469.65 MWD+IFR-AK-CAZ-SC 6904.44 76.02 192.77 2871.82 2750.52 -5329.38 -1371.11 5940042.23 557450.35 MWD+IFR-AK-CAZ-SC 6997.68 76.41 193.79 2894.03 2772.73 -5417.51 -1391.91 5939953.95 557430.24 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Inc. Date: 12/21/2006 Time: 10:23:21 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeII: 1 J-182, True North Site: KuparuklJPad Vertical (TVD)Reference: 1J-182L1:121.3 Well: 1J-182 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi} Wellpath: 1J-182L1 Survey Cakalation ~7ethod: Minimum Curvature Db: Oracfe Surr°cy -~ 111D Lul 9zim TVD Sys TVn 1\/S E/~i' MapN 111apE Tool ft deg deg ft ft ft ft ft ft 7093.73 75.76 193.05 2917.13 2795.83 -5508.20 -1413.55 5939863.11 557409.31 MWD+IFR-AK-CAZ-SC 7189.72 78.20 193.38 2938.76 2817.46 -5599.23 -1434.93 5939771.91 557388.65 MWD+IFR-AK-CAZ-SC I 7285.02 77.69 194.25 2958.66 2837.36 -5689.74 -1457.18 5939681.25 557367.10 MWD+IFR-AK-CAZ-SC 7379.64 78.08 193.35 2978.52 2857.22 -5779.58 -1479.25 5939591.25 557345.74 MWD+IFR-AK-CAZ-SC 7428.90 77.88 193.93 2988.78 2867.48 -5826.40 -1490.61 5939544.35 557334.75 MWD+IFR-AK-CAZ-SC j 7475.83 77.03 193.04 2998.97 2877.67 -5870.94 -1501.29 5939499.72 557324.41 MWD+IFR-AK-CAZ-SC 7570.60 77.46 193.06 3019.89 2898.59 -5960.99 -1522.16 5939409.53 557304.25 MWD+IFR-AK-CAZ-SC 7665.02 79.31 195.11 3038.91 2917.61 -6050.68 -1544.67 5939319.67 557282.44 MWD+IFR-AK-CAZ-SC 7759.52 78.16 193.79 3057.37 2936.07 -6140.43 -1567.80 5939229.75 557260.01 MWD+IFR-AK-CAZ-SC 7854.47 76.57 194.10 3078.14 2956.84 -6230.34 -1590.13 5939139.67 557238.39 MWD+IFR-AK-CAZ-SC 7949.97 75.79 194.98 3100,95 2979.65 -6320.11 -1613.41 5939049.74 557215.82 MWD+IFR-AK-CAZ-SC 8044.86 76.40 194.48 3123.75 3002.45 -6409.19 -1636.83 5938960.49 557193.10 MWD+IFR-AK-CAZ-SC 8140.30 76.82 194.35 3145.85 3024.55 -6499.11 -1659.94 5938870.40 557170.69 MWD+IFR-AK-CAZ-SC 8234.16 76.58 192.88 3167.45 3046.15 -6587.88 -1681.44 5938781.47 557149.88 MWD+IFR-AK-CAZ-SC 8328.34 76.86 191.83 3189.08 3067.78 -6677.42 -1701.05 5938691.79 557130.97 MWD+IFR-AK-CAZ-SC 8424.91 76.83 189.84 3211.06 3089.76 -6769.78 -1718.73 5938599.31 557114.02 MWD+IFR-AK-CAZ-SC 8519.95 75.60 190.23 3233.71 3112.41 -6860.66 -1734.81 5938508.30 557098.65 MWD+IFR-AK-CAZ-SC 8615.82 76.46 187.81 3256.85 3135.55 -6952.54 -1749.39 5938416.33 557084.78 MWD+IFR-AK-CAZ-SC 8710.90 75.76 187.09 3279.68 3158.38 -7044.06 -1761.36 5938324.72 557073.53 MWD+IFR-AK-CAZ-SC 8806.01 76.27 184.22 3302.67 3181.37 -7135.89 -1770.45 5938232.83 557065.16 MWD+IFR-AK-CAZ-SC 8901.29 81.57 183.62 3320.97 3199.67 -7229.14 -1776.84 5938139.54 557059.50 MWD+IFR-AK-CAZ-SC 8996.39 81.78 182.06 3334.74 3213.44 -7323.12 -1781.50 5938045.54 557055.57 MWD+IFR-AK-CAZ-SC 9090.74 82.65 180.59 3347.52 3226.22 -7416.57 -1783.66 5937952.08 557054.14 MWD+IFR-AK-CAZ-SC / 9121.00 82.47 180.41 3351.44 - 3230.14 -7446.58 -1783.92 5937922.08 557054.12 MWD+IFR-AK-CAZ-SC 9199.25 86.54 180.79 3358.93 3237.63 -7524.45 -1784.74 5937844.22 557053.91 MWD+IFR-AK-CAZ-SC 9226.60 88.03 180.92 3360.23 3238.93 -7551.76 -1785.14 5937816.90 557053.71 MWD+IFR-AK-CAZ-SC 9265.23 89.80 181.11 3360.96 3239.66 -7590.38 -1785.83 5937778.28 557053.33 MWD+IFR-AK-CAZ-SC 9363.69 91.34 181.59 3359.98 3238.68 -7688.80 -1788.15 5937679.85 557051.78 MWD+IFR-AK-CAZ-SC 9458.42 90.03 181.47 3358.85 3237.55 -7783.49 -1790.68 5937585.16 557049.99 MWD+IFR-AK-CAZ-SC 9553.34 89.60 181.64 3359.16 3237.86 -7878.37 -1793.25 5937490.27 557048.16 MWD+IFR-AK-CAZ-SC 9648.91 91.22 185.22 3358.47 3237.17 -7973.75 -1798.97 5937394.86 557043.18 MWD+IFR-AK-CAZ-SC ' 9743.74 91.09 185.61 3356.56 3235.26 -8068.14 -1807.92 5937300.41 557034.97 MWD+IFR-AK-CAZ-SC 9838.73 90.84 184.25 3354.96 3233.66 -8162.76 -1816.08 5937205.74 557027.55 MWD+IFR-AK-CAZ-SC 9934.00 90.78 181.85 3353.61 3232.31 -8257.88 -1821.15 5937110.59 557023.23 MWD+IFR-AK-CAZ-SC ~~ 10029.29 91.15 179.58 3352.01 3230.71 -8353.14 -1822.34 5937015.33 557022.78 MWD+IFR-AK-CAZ-SC 10123.91 90.03 179.56 3351.03 3229.73 -8447.75 -1821.63 5936920.74 557024.23 MWD+IFR-AK-CAZ-SC 10218.99 91.09 178.28 3350.10 3228.80 -8542.81 -1819.83 5936825.71 557026.76 MWD+IFR-AK-CAZ-SC 10315.29 90.03 177.53 3349.16 3227.86 -8639.04 -1816.31 5936729.52 557031.04 MWD+IFR-AK-CAZ-SC 10409.39 91.28 181.36 3348.09 3226.79 -8733.11 -1815.40 5936635.47 557032.68 MWD+IFR-AK-CAZ-SC 10504.72 91.08 182.52 3346.12 3224.82 -8828.36 -1818.63 5936540.20 557030.20 MWD+IFR-AK-CAZ-SC 10572.02 90.90 181.98 3344.96 3223.66 -8895.60 -1821.27 5936472.95 557028.08 MWD+IFR-AK-CAZ-SC 10599.96 90.90 181.44 3344.52 3223.22 -8923.52 -1822.10 5936445.02 557027.47 MWD+IFR-AK-CAZ-SC 10694.88 90.28 179.80 3343.54 3222.24 -9018.43 -1823.13 5936350.12 557027.18 MWD+IFR-AK-CAZ-SC 10790.08 89.85 176.69 3343.44 3222.14 -9113.57 -1820.22 5936255.01 557030.84 MWD+IFR-AK-CAZ-SC ', 10885.65 89.98 171.16 3343.58 3222.28 -9208.57 -1810.11 5936160.11 557041.69 MWD+IFR-AK-CAZ-SC 10980.54 88.89 166.35 3344.52 3223.22 -9301.60 -1791.61 5936067.23 557060.91 MWD+IFR-AK-CAZ-SC 11075.99 86.88 168.67 3348.04 3226.74 -9394.72 -1770.98 5935974.29 557082.26 MWD+IFR-AK-CAZ-SC 11170.57 85.65 173.73 3354.20 3232.90 -9487.96 -1756.54 5935881.18 557097.42 MWD+IFR-AK-CAZ-SC 11266.57 88.88 177.53 3358.78 3237.48 -9583.54 -1749.24 5935785.66 557105.47 MWD+IFR-AK-CAZ-SC i 11361.89 92.53 181.55 3357.61 3236.31 -9678.81 -1748.48 5935690.41 557106.98 MWD+IFR-AK-CAZ-SC 11456.83 92.70 183.21 3353.28 3231.98 -9773.57 -1752.42 5935595.63 557103.78 MWD+IFR-AK-CAZ-SC 11552.24 91.39 183.52 3349.88 3228.58 -9868.75 =1758.01 5935500.42 557098.93 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 1J Pad Nell: 1J-182 Wellpath: 1 J-182L1 Sunev Date: 12/21/2006 ' Time: 10:23:21 Page: A Co-ordinate(NE) Reference: WeIL 1J-182, True North Vertical (TVD) Reference: 1 J-182L1: 121.3 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Survey Calculation Method: Minimum Curvature Db: Oracle VID Incl Azim TVD - -- Sys TVD N/S __ E/1V MapN - -- b1apE Tool ft deg deg ' ft ft ft ft ft ft 11647. 80 90. 96 184 .07 3347. 92 3226 .62 -9964. 08 -1764 .34 5935405. 05 557093. 35 MWD+IFR-AK-CAZ-SC 11742. 80 90. 59 184. 28 3346. 63 3225. 33 -10058. 82 -1771 .25 5935310. 27 557087. 17 MWD+IFR-AK-CAZ-SC 11837. 54 90. 66 183. 89 3345. 60 3224. 30 -10153. 31 -1778 .00 5935215. 73 557081. 16 MWD+IFR-AK-CAZ-SC ~ 11932. 67 90. 90 183. 74 3344. 30 3223. 00 -10248. 22 -1784 .33 5935120. 79 557075. 58 MWD+IFR-AK-CAZ-SC 12027. 61 90. 90 181 .88 3342. 81 3221. 51 -10343. 03 -1788 .98 5935025. 95 557071. 66 MWD+IFR-AK-CAZ-SC ~ 12121. 52 91. 03 179 .04 3341. 23 3219. 93 -10436. 92 -1789 .74 5934932. 07 557071. 64 MWD+IFR-AK-CAZ-SC 12212. 67 90. 65 175 .36 3339. 89 3218. 59 -10527. 93 -1785 .29 5934841. 11 557076. 80 MWD+IFR-AK-CAZ-SC 12311. 69 90. 41 171 .99 3338. 98 3217 .68 -10626. 33 -1774 .38 5934742. 80 557088. 48 MWD+IFR-AK-CAZ-SC 12406. 96 90. 16 169 .52 3338. 50 3217 .20 -10720. 35 -1759 .07 5934648. 91 557104. 51 MWD+IFR-AK-CAZ-SC 12502. 14 89. 60 167 .55 3338. 70 3217 .40 -10813. 63 -1740 .16 5934555. 80 557124. 16 MWD+IFR-AK-CAZ-SC 12597. 38 89. 92 167 .49 3339. 10 3217 .80 -10906. 62 -1719 .58 5934462. 98 557145. 46 MWD+IFR-AK-CAZ-SC 12692. 74 90. 10 168 .99 3339. 08 3217 .78 -10999. 97 -1700 .14 5934369. 79 557165. 62 MWD+IFR-AK-CAZ-SC 12787. 87 90. 41 171 .53 3338. 66 3217 .36 -11093. 72 -1684 .05 5934276. 17 557182. 44 MWD+IFR-AK-CAZ-SC ~, 12882. 53 90. 28 172 .73 3338. 09 3216 .79 -11187. 49 -1671 .09 5934182. 52 557196. 13 MWD+IFR-AK-CAZ-SC 12978. 05 90. 78 174 .45 3337. 21 3215. 91 -11282. 40 -1660 .42 5934087. 70 557207. 54 MWD+IFR-AK-CAZ-SC 13045. 00 94. 16 175 .15 3334. 32 3213 .02 -11349. 01 -1654 .36 5934021. 16 557214. 12 MWD+IFR-AK-CAZ-SC 13073. 17 88. 42 176 .35 3333. 69 3212 .39 -11377. 08 -1652 .28 5933993. 10 557216. 42 MWD+IFR-AK-CAZ-SC 13168. 28 88. 68 178 .70 3336. 09 3214 .79 -11472. 06 -1648 .17 5933898. 16 557221. 27 MWD+IFR-AK-CAZ-SC 13263. 17 87. 50 180 .87 3339. 26 3217 .96 -11566. 89 -1647 .81 5933803. 35 557222. 37 MWD+IFR-AK-CAZ-SC 13358. 10 89. 25 181 .96 3341. 95 3220 .65 -11661. 75 -1650 .16 5933708. 48 557220. 76 MWD+IFR-AK-CAZ-SC 13452. 83 92. 53 183 .00 3340. 48 3219 .18 -11756. 37 -1654 .26 5933613. 85 557217. 40 MWD+IFR-AK-CAZ-SC 13548. 00 92. 82 183 .25 3336. 04 3214 .74 -11851. 29 -1659 .44 5933518. 90 557212. 96 MWD+IFR-AK-CAZ-SC 13642. 84 93. 63 180 .94 3330. 70 3209 .40 -11945. 91 -1662 .90 5933424. 26 557210. 24 MWD+fFR-AK-CAZ-SC 13737. 96 91. 14 180 .22 3326. 74 3205 .44 -12040. 94 -1663 .86 5933329. 24 557210. 02 MWD+IFR-AK-CAZ-SC 13832. 14 93. 69 179 .67 3322. 77 3201 .47 -12135. 02 -1663 .77 5933235. 17 557210. 85 MWD+IFR-AK-CAZ-SC ~ 13928. 04 91. 32 179 .72 3318. 58 3197 .28 -12230. 82 -1663 .26 5933139. 38 557212. 10 MWD+IFR-AK-CAZ-SC 14023. 19 91. 33 179 .74 3316. 38 3195 .08 -12325. 95 -1662 .81 5933044. 27 557213. 29 MWD+IFR-AK-CAZ-SC 14118. 34 90. 84 178 .56 3314. 58 3193 .28 -12421. 07 -1661 .40 5932949. 18 557215. 45 MWD+IFR-AK-CAZ-SC 'I 14213. 79 90. 47 179 .43 3313. 49 3192 .19 -12516. 50 -1659 .73 5932853. 77 557217. 87 MWD+IFR-AK-CAZ-SC 14308. 78 90. 66 181 .97 3312. 55 3191 .25 -12611. 47 -1660 .89 5932758. 81 557217. 45 MWD+IFR-AK-CAZ-SC ~i 14403. 75. 90. 34 182 .81 3311. 72 3190 .42 -12706. 35 -1664 .85 5932663. 90 557214. 23 MWD+IFR-AK-CAZ-SC 14498. 89 90. 53 183 .16 3311. 00 3189 .70 -12801. 36 -1669 .80 5932568. 87 557210. 02 MWD+IFR-AK-CAZ-SC 14594. 58 90. 41 180 .28 3310. 22 3188 .92 -12896. 99 -1672 .67 5932473. 23 557207. 89 MWD+IFR-AK-CAZ-SC 14688. 16 90. 97 179 .93 3309. 09 3187 .79 -12990. 56 -1672 .85 5932379. 66 557208. 45 MWD+IFR-AK-CAZ-SC 14784. 04 90. 53 179 .76 3307. 84 3186 .54 -13086. 43 -1672 .59 5932283. 81 557209. 46 MWD+IFR-AK-CAZ-SC 14879. 44 90. 16 180 .37 3307. 26 3185 .96 -13181. 83 -1672 .69 5932188. 42 557210. 09 MWD+IFR-AK-CAZ-SC 14975. 08 90. 60 183 .00 3306. 63 3185 .33 -13277. 42 -1675 .51 5932092. 82 557208. 03 MWD+IFR-AK-CAZ-SC ~, 15069. 63 91. 16 181 .49 3305. 17 3183 .87 -13371. 88 -1679 .21 5931998. 34 557205. 06 MWD+IFR-AK-CAZ-SC 15165. 10 91. 34 178 .02 3303. 09 3181 .79 -13467. 32 -1678 .80 5931902. 93 557206. 22 MWD+IFR-AK-CAZ-SC 15259. 59 90. 03 174 .52 3301. 96 3180 .66 -13561. 58 -1672 .66 5931808. 72 557213. 10 MWD+IFR-AK-CAZ-SC 15353. 23 90. 22 176 .45 3301. 76 3180 .46 -13654. 93 -1665 .28 5931715. 44 557221. 19 MWD+IFR-AK-CAZ-SC 15448. 29 90. 04 178 .65 3301. 54 3180 .24 -13749. 89 -1661 .22 5931620. 52 557226. 00 MWD+IFR-AK-CAZ-SC 15543. 85 90. 35 179 .65 3301. 22 3179 .92 -13845. 44 -1659 .80 5931525. 00 557228. 16 MWD+IFR-AK-CAZ-SC 15637. 31 90. 72 180 .45 3300. 34 3179 .04 -13938. 90 -1659 .89 5931431. 55 557228. 81 MWD+IFR-AK-CAZ-SC ~i 15732. 74 90. 22 178 .77 3299. 56 3178 .26 -14034. 32 -1659 .24 5931336. 15 557230. 20 MWD+IFR-AK-CAZ-SC 15827. 58 90. 60 180 .28 3298. 88 3177 .58 -14129. 15 -1658 .45 5931241. 34 557231. 73 MWD+IFR-AK-CAZ-SC ' 15922. 61 90. 59 182 .39 3297. 89 3176 .59 -14224. 14 -1660 .66 5931146. 34 557230. 26 MWD+IFR-AK-CAZ-SC 16017. 32 90. 72 182 .70 3296. 81 3175 .51 -14318. 75 -1664 .87 5931051. 71 557226. 79 MWD+IFR-AK-CAZ-SC 16112. 59 90. 72 181 .14 3295. 61 3174 .31 -14413. 96 -1668 .06 5930956. 49 557224. 34 MWD+IFR-AK-CAZ-SC 16207. 81 91. 59 179 .03 3293. 69 3172 .39 -14509. 15 -1668 .20 5930861. 30 557224. 95 MWD+IFR-AK-CAZ-SC 16303. 33 92. 82 175 .34 3290. 02 3168 .72 -14604. 47 -1663 .52 5930766. 04 557230. 37 MWD+IFR-AK-CAZ-SC 16398. 69 87. 66 175 .37 3289. 62 3168 .32 -14699. 48 -1655 .80 5930671. 09 557238. 83 MWD+IFR-AK-CAZ-SC 16494. 17 89. 99 177 .18 3291. 58 3170 .28 -14794. 73 -1649 .60 5930575 .91 557245. 78 MWD+IFR-AK-CAZ-SC ' ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12/21/2006 'l'ime: 10:23:21 Pager 5 Field: Ku paruk River Unit Co-or dinate(NE) Reference: Well: 1J-182, Tru e North Site: Ku paruk 1J Pad Vertical (TVD) Reference: 1J-182L1: 121.3 ' Nell: 1J -182 Section (VS)Reference: Well (O.OON,O.OO E,180.OOAzi} Wellpath: 1J -182L1 Survey Calculati on Method: Minimum Curvature Db: Oracle Surccy -- - - MD Incl Azim TVD Sys TVD hIS E1N' MapN MapE Tool ft deg deg ft ft ft ft ft ft 16589.34 91.53 178.49 3290.31 3169.01 -14889.82 -1646.00 5930480.86 557250.11 MWD+IFR-AK-CAZ-SC 16684.19 90.90 179.32 3288.30 3167.00 -14984.63 -1644.19 5930386.07 557252.67 MWD+IFR-AK-CAZ-SC 16778.83 91.71 181.54 3286.15 3164.85 -15079.23 -1644.90 5930291.47 557252.70 MWD+IFR-AK-CAZ-SC 16872.54 90.65 180.17 3284.22 3162.92 -15172.91 -1646.30 5930197.80 557252.03 MWD+IFR-AK-CAZ-SC 16967.93 91.53 181.44 3282.40 3161.10 -15268.27 -1647.64 5930102.44 557251.43 MWD+IFR-AK-CAZ-SC II 17063.83 91.52 180.32 3279.85 3158.55 -15364.12 -1649.11 5930006.59 557250.71 I MWD+IFR-AK-CAZ-SC 17158.66 89.72 179.36 3278.83 3157.53 -15458.94 -1648.84 5929911.78 557251.71 MWD+IFR-AK-CAZ-SC 17254.02 90.91 180.28 3278.30 3157.00 -15554.30 -1648.54 5929816.44 557252.76 MWD+IFR-AK-CAZ-SC 17349.24 89.10 180.39 3278.29 3156.99 -15649.51 -1649.10 5929721.24 557252.94 MWD+IFR-AK-CAZ-SC 17444.33 90.66 181.24 3278.49 3157.19 -15744.59 -1650.45 5929626.16 557252.33 MWD+IFR-AK-CAZ-SC i 17539.02 91.96 182.76 3276.33 3155.03 -15839.19 -1653.76 5929531.54 557249.77 MWD+IFR-AK-CAZ-SC 17634.20 91.27 183.15 3273.64 3152.34 -15934.21 -1658.66 5929436.50 557245.61 MWD+IFR-AK-CAZ-SC 17720.94 91.02 181.70 3271.91 3150.61 -16020.85 -1662.33 5929349.84 557242.62 MWD+IFR-AK-CAZ-SC ,17757.00 91.02 181.70 3271.27 3149.97 -16056.89 -1663.40 5929313.80 557241.83- PROJECTED to TD Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc . __ Date: 12/21/2006 Time: 10:01:49 __ Page: I Field: Kuparuk River Unit Co -ordinate(NE) Reference: WeII: 1 J-182, T rue North Sitc: Kuparuk iJ Pad Ve rtical (TVD)Rc fcrcncc: 1J-182L1P61: 121.3 ~~'ell: 1J-182 Section (VS) Reference: Wetl (0.OON,O.OOE,180.OOAzi) Wellpath: 1J-182L1PB1 __ Survey Calculation ~lcthod: 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 Sy stem: Well Centre I Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 j Well: 1 J-182 Slot Name: i Well Position: +N/-S -537.96 ~ ft Nort hing: 59453 81.64 ft Latitude: 70 15 40.967 N ~ +E/-W -14.46 ft Easti ng : 558779.69 ft Longitude: 149 31 29.427 W Position Uncertainty: _ 0_00 ft _ _ Wellpath: 1J-182L1P61 Drilled From: 1J-182 500292332170 Tie-on Depth: 9090.74 ft Current Datum: 1 J-182L1 P61: Height 121.30 ft Above System Datum: Mean Sea Level Magnetic Data: 10/4/2006 Declination: 23.77 deg Field Strength: 57611 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ~ ft ft ft deg 40.30 _ 0.00 0.00 180.00 Survey Program for Definitive Wellpath DI ate: 12/21/2006 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft 100.00 891.00 1J-182 gyro (100.00-891.00) (0 CB-GYRO-SS Camera based gyro single shot 965.65 9090.74 1J-182 (965.65-17809.76) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9121.00 13453.19 1J-182L1 PB1 (9121 .00-13453.19) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey 111D Incl Azim fVD Sys TVD I~/S E/W 11apN MapF. "fool ft deg deg ft ft ft ft ft ft 40.30 0.00 0.00 40.30 -81.00 0.00 0.00 5945381.64 558779.69 TIE LINE ~ 100.00 0.46 219.18 100.00 -21.30 -0.19 -0.15 5945381.45 558779.54 CB-GYRO-SS 200.00 1.28 161.70 199.99 78.69 -1.56 -0.05 5945380.08 558779.65 CB-GYRO-SS 300.00 3.71 160.11 299.89 178.59 -5.66 1.40 5945375.99 558781.13 CB-GYRO-SS 400.00 5.02 173.55 399.60 278.30 -13.05 2.99 5945368.61 558782.78 CB-GYRO-SS 496.00 4.32 196.16 495.29 373.99 -20.70 2.46 5945360.96 558782.31 CB-GYRO-SS 515.00 4.27 202.60 514.23 392.93 -22.04 1.98 5945359.62 558781.85 CB-GYRO-SS 604.00 6.22 210.98 602.86 481.56 -29.23 -1.77 5945352.40 558778.15 CB-GYRO-SS 696.00 9.33 212.56 694.00 572.70 -39.79 -8.35 5945341.79 558771.65 CB-GYRO-SS 796.00 11.10 214.50 792.41 671.11 -54.56 -18.17 5945326.95 558761.95 CB-GYRO-SS 891.00 13.12 207.22 885.30 764.00 -71.69 -28.28 5945309.74 558751.97 CB-GYRO-SS 965.65 17.65 204.41 957.25 835.95 -89.54 -36.84 5945291.83 558743.56 MWD+IFR-AK-CAZ-SC 1059.65 23.06 203.22 1045.35 924.05 -119.45 -49.99 5945261.81 558730.63 MWD+IFR-AK-CAZ-SC 1155.97 25.75 204.96 1133.06 1011.76 -155.76 -66.26 5945225.38 558714.65 MWD+IFR-AK-CAZ-SC 1250.69 28.41 205.71 1217.39 1096.09 -194.73 -84.73 5945186.28 558696.50 MWD+IFR-AK-CAZ-SC 1346.86 33.42 206.63 1299.87 1178.57 -239.04 -106.54 5945141.80 558675.03 MWD+IFR-AK-CAZ-SC 1441.92 39.62 206.72 1376.23 1254.93 -289.57 -131.92 5945091.08 558650.05 MWD+IFR-AK-CAZ-SC ~ ~ 1536.64 44.17 205.50 1446.72 1325.42 -346.36 -159.72 5945034.08 558622.69 MWD+IFR-AK-CAZ-SC 1631.87 48.85 206.13 1512.24 1390.94 -408.53 -189.81 5944971.68 558593.09 MWD+IFR-AK-CAZ-SC 1726.65 51.15 206.14 1573.16 1451.86 -473.71 -221.79 5944906.26 558561.62 MWD+IFR-AK-CAZ-SC 1821.56 57.81 204.82 1628.27 1506.97 -543.42 -254.97 5944836.30 558528.99 MWD+IFR-AK-CAZ-SC 1916.82 62.86 202.74 1675.41 1554.11 -619.15 -288.30 5944760.32 558496.26 MWD+IFR-AK-CAZ-SC 2012.04 66.37 201.40 1716.22 1594.92 -698.86 -320.60 5944680.37 558464.58 MWD+IFR-AK-CAZ-SC 2108.02 70.76 197.96 1751.30 1630.00 -782.96 -350.64 5944596.04 558435.20 MWD+IFR-AK-CAZ-SC 2202.30 73.96 195.11 1779.87 1658.57 -869.08 -376.19 5944509.74 558410.34 MWD+IFR-AK-CAZ-SC i~ 2297.82 74.95 193.03 1805.47 1684.17 -958.34 -398.55 5944420.32 558388.67 MWD+IFR-AK-CAZ-SC 2392.80 74.79 191.54 1830.26 1708.96 -1047.92 -418.06 5944330.59 558369.86 MWD+IFR-AK-CAZ-SC 2488.25 74.98 191.95 1855.15 1733.85 -1138.14 -436.82 5944240.24 558351.81 MWD+IFR-AK-CAZ-SC ,~ Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Inc. 1}ate: 12/21/2006 Time: 10:01:49 Page: 2 I Field: Kuparuk River Unit Co-ordinate(NE) Reference: r Well: 1J-182, True North I' Site: Kuparuk 1J Pad ~'ertical(T~'D) Reference: 1J-182L1PB1:121.3 ~~' ~Ve0: 1J-182 Section (VS)Reference: Well (O.OON,O.OOE,180.OOAzi) Weltpath: 1J-182L1PB1 Survey Calculation Method: Minimum Curvature Db: Oracle __ _ __ Sun'ev D1D Incl azim TVD Sys T~'D N/S E/1i' AIapN ?11apE Tool ft deg deg ft ft ft ft ft ft 2583.30 73.42 192.50 1881.03 1759.73 -1227.52 -456.18 5944150.71 558333.15 MWD+IFR-AK-CAZ-SC 2677.40 75.11 190.79 1906.55 1785.25 -1316.22 -474.46 5944061.88 558315.57 MWD+IFR-AK-CAZ-SC 2773.73 75.91 190.11 1930.65 1809.35 -1407.94 -491.37 5943970.04 558299.37 MWD+IFR-AK-CAZ-SC 2868.62 76.05 191.13 1953.64 1832.34 -1498.43 -508.34 5943879.43 558283.11 MWD+IFR-AK-CAZ-SC ~ 2964.60 74.05 189.95 1978.40 1857.10 -1589.59 -525.31 5943788.15 558266.86 MWD+IFR-AK-CAZ-SC 3060.06 74.55 188.86 2004.23 1882.93 -1680.25 -540.32 5943697.39 558252.55 MWD+IFR-AK-CAZ-SC 3153.82 75.48 190.85 2028.48 1907.18 -1769.48 -555.83 5943608.05 558237.75 MWD+IFR-AK-CAZ-SC 3250.26 79.82 193.03 2049.10 1927.80 -1861.62 -575.32 5943515.77 558218.97 MWD+IFR-AK-CAZ-SC 3343.91 77.81 193.02 2067.27 1945.97 -1951.12 -596.03 5943426.12 558198.97 MWD+IFR-AK-CAZ-SC j 3439.43 75.29 193.97 2089.49 1968.19 -2041.45 -617.70 5943335.63 558178.00 MWD+IFR-AK-CAZ-SC 3534.69 73.75 193.01 2114.91 1993.61 -2130.71 -639.12 5943246.21 558157.28 MWD+IFR-AK-CAZ-SC 3627.32 75.85 192.86 2139.20 2017.90 -2217.83 -659.13 5943158.95 558137.96 MWD+IFR-AK-CAZ-SC 3674.33 73.59 192.99 2151.58 2030.28 -2262.03 -669.27 5943114.68 558128.16 MWD+IFR-AK-CAZ-SC 3728.38 73.03 193.90 2167.11 2045.81 -2312.38 -681.31 5943064.24 558116.52 MWD+IFR-AK-CAZ-SC 3767.32 74.03 195.01 2178.15 2056.85 -2348.54 -690.63 5943028.01 558107.48 MWD+IFR-AK-CAZ-SC 3814.35 75.20 195.04 2190.62 2069.32 -2392.33 -702.38 5942984.13 558096.07 MWD+IFR-AK-CAZ-SC I, 3862.80 76.55 195.54 2202.45 2081.15 -2437.65 -714.77 5942938.72 558084.03 MWD+IFR-AK-CAZ-SC I 3957.65 75.95 195.37 2224.99 2103.69 -2526.45 -739.33 5942849.74 558060.18 MWD+IFR-AK-CAZ-SC 4051.61 76.29 195.25 2247.53 2126.23 -2614.43 -763.41 5942761.58 558036.78 MWD+IFR-AK-CAZ-SC 4146.61 77.59 195.02 2269.00 2147.70 -2703.76 -787.57 5942672.07 558013.32 MWD+IFR-AK-CAZ-SC 4193.74 77.89 195.13 2279.01 2157.71 -2748.23 -799.55 5942627.51 558001.69 MWD+IFR-AK-CAZ-SC 4242.12 75.85 195.08 2290.00 2168.70 -2793.72 -811.83 5942581.94 557989.77 MWD+IFR-AK-CAZ-SC i 4338.69 76.70 195.04 2312.91 2191.61 -2884.31 -836.20 5942491.17 557966.11 MWD+IFR-AK-CAZ-SC 4432.61 78.83 194.61 2332.81 2211.51 -2973.03 -859.68 5942402.27 557943.32 MWD+IFR-AK-CAZ-SC 4528.23 77.20 194.15 2352.67 2231.37 -3063.63 -882.91 5942311.50 557920.80 MWD+IFR-AK-CAZ-SC 4623.98 77.65 191.67 2373.52 2252.22 -3154.72 -903.79 5942220.27 557900.64 MWD+IFR-AK-CAZ-SC 4719.02 78.38 189.93 2393.25 2271.95 -3246.04 -921.21 5942128.82 557883.93 MWD+IFR-AK-CAZ-SC 4813.42 76.99 192.60 2413.39 2292.09 -3336.48 -939.22 5942038.25 557866.63 MWD+IFR-AK-CAZ-SC 4908.79 77.71 191.02 2434.28 2312.98 -3427.56 -958.26 5941947.04 557848.30 MWD+tFR-AK-CAZ-SC 5004.18 77.33 190.46 2454.89 2333.59 -3519.06 -975.62 5941855.41 557831.66 MWD+IFR-AK-CAZ-SC 5100.11 77.80 192.08 2475.55 2354.25 -3610.93 -993.92 5941763.41 557814.08 MWD+IFR-AK-CAZ-SC 5194.97 78.19 191.09 2495.28 2373.98 -3701.83 -1012.56 5941672.38 557796.15 MWD+IFR-AK-CAZ-SC ', 5245.05 76.50 191.04 2506.25 2384.95 -3749.78 -1021.93 5941624.36 557787.15 MWD+IFR-AK-CAZ-SC 5289.86 76.35 191.57 2516.77 2395.47 -3792.49 -1030.47 5941581.59 557778.95 MWD+IFR-AK-CAZ-SC 5383.69 76.38 189.94 2538.89 2417.59 -3882.07 -1047.49 5941491.88 557762.63 MWD+IFR-AK-CAZ-SC 5480.30 76.88 192.49 2561.23 2439.93 -3974.26 -1065.77 5941399.56 557745.07 MWD+IFR-AK-CAZ-SC 5575.36 77.14 193.16 2582.60 2461.30 -4064.58 -1086.33 5941309.10 557725.22 MWD+IFR-AK-CAZ-SC 5670.51 76.90 195.02 2603.97 2482.67 -4154.50 -1108.90 5941219.01 557703.36 MWD+IFR-AK-CAZ-SC 5765.44 77.68 195.42 2624.86 2503.56 -4243.86 -1133.21 5941129.48 557679.75 MWD+IFR-AK-CAZ-SC 5853.39 77.20 194.23 2643.99 2522.69 -4326.84 -1155.18 5941046.33 557658.43 MWD+IFR-AK-CAZ-SC 5955.75 77.69 193.94 2666.24 2544.94 -4423.75 -1179.49 5940949.24 557634.88 MWD+IFR-AK-CAZ-SC 6050.97 78.73 191.38 2685.70 2564.40 -4514.69 -1199.91 5940858.16 557615.17 MWD+IFR-AK-CAZ-SC 6146.72 78.04 192.62 2704.97 2583.67 -4606.42 -1219.41 5940766.28 557596.39 MWD+IFR-AK-CAZ-SC 6242.35 78.50 193.52 2724.42 2603.12 -4697.63 -1240.59 5940674.92 557575.93 MWD+IFR-AK-CAZ-SC 6336.27 78.57 193.82 2743.08 2621.78 -4787.07 -1262.34 5940585.33 557554.87 MWD+IFR-AK-CAZ-SC 6431.97 78.50 192.15 2762.11 2640.81 -4878.46 -1283.41 5940493.78 557534.52 MWD+IFR-AK-CAZ-SC 6524.99 77.16 190.37 2781.72 2660.42 -4967.63 -1301.17 5940404.48 557517.46 MWD+IFR-AK-CAZ-SC 6621.26 76.62 189.01 2803.56 2682.26 -5060.05 -1316.95 5940311.95 557502.40 MWD+IFR-AK-CAZ-SC 6716.43 74.40 190.42 2827.37 2706.07 -5150.86 -1332.50 5940221.03 557487.57 MWD+IFR-AK-CAZ-SC 6811.74 77.45 192.82 2850.55 2729.25 -5241.40 -1351.13 5940130.36 557469.65 MWD+IFR-AK-CAZ-SC 6904.44 76.02 192.77 2871.82 2750.52 -5329.38 -1371.11 5940042.23 557450.35 MWD+IFR-AK-CAZ-SC 6997.68 76.41 193.79 2894.03 2772.73 -5417.51 -1391.91 5939953.95 557430.24 MWD+IFR-AK-CAZ-SC I Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Ua[r. 12/21/2006 Time: 10:01:49 Page: 3 ' Field: Kuparuk River Unit Co-ordinate(NE)Reference: Well: 1J-182, True North Sitr. Kuparuk 1J Pad Vertical(TVD)Reference: 1J-182L1PB1:121.3 Well: 1J-1 $2 Section (VS) 12eference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1 J-182L1 PB1 Survey Calculation Method: Minimum Curvature Db: Oraete ____ Survev __ - _ _ -- _ MD Iucl Azim T1'D Sys TVD N/S E/W Aiap~ MapE Tool ft deg ..deg ft ft ft ft ft ft 7093.73 75.76 193.05 2917.13 2795.83 -5508.20 -1413.55 5939863.11 557409.31 MWD+IFR-AK-CAZ-SC 7189.72 78.20 193.38 2938.76 2817.46 -5599.23 -1434.93 5939771.91 557388.65 MWD+IFR-AK-CAZ-SC 7285.02 77.69 194.25 2958.66 2837.36 -5689.74 -1457.18 5939681.25 557367.10 MWD+tFR-AK-CAZ-SC ~' 7379.64 78.08 193.35 2978.52 2857.22 -5779.58 -1479.25 5939591.25 557345.74 MWD+IFR-AK-CAZ-SC 7428.90 77.88 193.93 2988.78 2867.48 -5826.40 -1490.61 5939544.35 557334.75 MWD+IFR-AK-CAZ-SC i 7475.83 77.03 193.04 2998.97 2877.67 -5870.94 -1501.29 5939499.72 557324.41 MWD+IFR-AK-CAZ-SC 7570.60 77.46 193.06 3019.89 2898.59 -5960.99 -1522.16 5939409.53 557304.25 MWD+IFR-AK-CAZ-SC ~ 7665.02 79.31 195.11 3038.91 2917.61 -6050.68 -1544.67 5939319.67 557282.44 MWD+IFR-AK-CAZ-SC 7759.52 78.16 193.79 3057.37 2936.07 -6140.43 -1567.80 5939229.75 557260.01 MWD+IFR-AK-CAZ-SC 7854.47 76.57 194.10 3078.14 2956.84 -6230.34 -1590.13 5939139.67 557238.39 MWD+IFR-AK-CAZ-SC 7949.97 75.79 194.98 3100.95 2979.65 -6320.11 -1613.41 5939049.74 557215.82 MWD+IFR-AK-CAZ-SC 8044.86 76.40 194.48 3123.75 3002.45 -6409.19 -1636.83 5938960.49 557193.10 MWD+IFR-AK-CAZ-SC 8140.30 76.82 194.35 3145.85 3024.55 -6499.11 -1659.94 5938870.40 557170.69 MWD+IFR-AK-CAZ-SC 8[34.16 76.58 192.88 3167.45 3046.15 -6587.88 -1681.44 5938781.47 557149.88 MWD+IFR-AK-CAZ-SC 8328.34 76.86 191.83 3189.08 3067.78 -6677.42 -1701.05 5938691.79 557130.97 MWD+IFR-AK-CAZ-SC I 8424.91 76.83 189.84 3211.06 3089.76 -6769.78 -1718.73 5938599.31 557114.02 MWD+IFR-AK-CAZ-SC 8519.95 75.60 190.23 3233.71 3112.41 -6860.66 -1734.81 5938508.30 557098.65 MWD+IFR-AK-CAZ-SC 8615.82 76.46 187.81 3256.85 3135.55 -6952.54 -1749.39 5938416.33 557084.78 MWD+IFR-AK-CAZ-SC 8710.90 75.76 187.09 3279.68 3158.38 -7044.06 -1761.36 5938324.72 557073.53 MWD+IFR-AK-CAZ-SC 8806.01 76.27 184.22 3302.67 3181.37 -7135.89 -1770.45 5938232.83 557065.16 MWD+IFR-AK-CAZ-SC i 8901.29 81.57 183.62 3320.97 3199.67 -7229.14 -1776.84 5938139.54 557059.50 MWD+IFR-AK-CAZ-SC 8996.39 81.78 182.06 3334.74 3213.44 -7323.12 -1781.50 5938045.54 557055.57 MWD+IFR-AK-CAZ-SC 9090.74 82.65 180.59 3347.52 3226.22 -7416.57 -1783.66 5937952.08 557054.14 MWD+IFR-AK-CAZ-SC 9121.00 82.47 180.41 3351.44 3230.14 -7446.58 -1783.92 5937922.08 557054.12 MWD+IFR-AK-CAZ-SC 9199.25 86.54 180.79 3358.93 3237.63 -7524.45 -1784.74 5937844.22 557053.91 MWD+IFR-AK-CAZ-SC 9226.60 88.03 180.92 3360.23 3238.93 -7551.76 -1785.14 5937816.90 557053.71 MWD+IFR-AK-CAZ-SC 9265.23 89.80 181.11 3360.96 3239.66 -7590.38 -1785.83 5937778.28 557053.33 MWD+IFR-AK-CAZ-SC 9363.69 91.34 181.59 3359.98 3238.68 -7688.80 -1788.15 5937679.85 557051.78 MWD+IFR-AK-CAZ-SC 9458.42 90.03 181.47 3358.85 3237.55 -7783.49 -1790.68 5937585.16 557049.99 MWD+IFR-AK-CAZ-SC 9553.34 89.60 181.64 3359.16 3237.86 -7878.37 -1793.25 5937490.27 557048.16 MWD+IFR-AK-CAZ-SC 9648.91 91.22 185.22 3358.47 3237.17 -7973.75 -1798.97 5937394.86 557043.18 MWD+IFR-AK-CAZ-SC 9743.74 91.09 185.61 3356.56 3235.26 -8068.14 -1807.92 5937300.41 557034.97 MWD+IFR-AK-CAZ-SC 9838.73 90.84 184.25 3354.96 3233.66 -8162.76 -1816.08 5937205.74 557027.55 MWD+IFR-AK-CAZ-SC 9934.00 90.78 181.85 3353.61 3232.31 -8257.88 -1821.15 5937110.59 557023.23 MWD+IFR-AK-CAZ-SC 10029.29 91.15 179.58 3352.01 3230.71 -8353.14 -1822.34 5937015.33 557022.78 MWD+IFR-AK-CAZ-SC 10123.91 90.03 179.56 3351.03 3229.73 -8447.75 -1821.63 5936920.74 557024.23 MWD+IFR-AK-CAZ-SC 10218.99 91.09 178.28 3350.10 3228.80 -8542.81 -1819.83 5936825.71 557026.76 MWD+IFR-AK-CAZ-SC 10315.29 90.03 177.53 3349.16 3227.86 -8639.04 -1816.31 5936729.52 557031.04 MWD+IFR-AK-CAZ-SC 10409.39 91.28 181.36 3348.09 3226.79 -8733.11 -1815.40 5936635.47 557032.68 MWD+IFR-AK-CAZ-SC 10504.72 91.08 182.52 3346.12 3224.82 -8828.36 -1818.63 5936540.20 557030.20 MWD+IFR-AK-CAZ-SC 10572.02 90.90 181.98 3344.96 3223.66 -8895.60 -1821.27 5936472.95 557028.08 MWD+IFR-AK-CAZ-SC '. 10599.96 90.90 181.44 3344.52 3223.22 -8923.52 -1822.10 5936445.02 557027.47 MWD+IFR-AK-CAZ-SC 10694.88 90.28 179.80 3343.54 3222.24 -9018.43 -1823.13 5936350.12 557027.18 MWD+IFR-AK-CAZ-SC 10790.08 89.85 176.69 3343.44 3222.14 -9113.57 -1820.22 5936255.01 557030.84 MWD+IFR-AK-CAZ-SC 10885.65 89.98 171.16 3343.58 3222.28 -9208.57 -1810.11 5936160.11 557041.69 MWD+IFR-AK-CAZ-SC 10980.54 88.89 166.35 3344.52 3223.22 -9301.60 -1791.61 5936067.23 557060.91 MWD+IFR-AK-CAZ-SC 11075.99 86.88 168.67 3348:04 3226.74 -9394.72 -1770.98 5935974.29 557082.26 MWD+IFR-AK-CAZ-SC 11170.57 85.65 173.73 3354.20 3232.90 -9487.96 -1756.54 5935881.18 557097.42 MWD+IFR-AK-CAZ-SC 11266.57 88.88 177.53 3358.78 3237.48 -9583.54 -1749.24 5935785.66 557105.47 MWD+IFR-AK-CAZ-SC 11361.89 92.53 181.55 3357.61 3236.31 -9678.81 -1748.48 5935690.41 557106.98 MWD+IFR-AK-CAZ-SC 11456.83 92.70 183.21 3353.28 3231.98 -9773.57 -1752.42 5935595.63 557103.78 MWD+IFR-AK-CAZ-SC 11552.24 91.39 183.52 3349.88 3228.58 -9868.75 -1758.01 5935500.42 557098.93 MWD+IFR-AK-CAZ-SC 11647.80 90.96 184.07 3347.92 3226.62 -9964.08 -1764.34 5935405.05 557093.35 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska tne. Date: 12121/2006 'Time. 10:01:49 Page: 4 Field: Ku paruk Rive r Unit Co-ordinate(NF,) Reference: WeN: 1J-182, T rue North Site: Ku paruk 1J P ad Verti cal (1'~'D) Reference: 1J-182L1P61: 121.3 Well: 1J -182 Section (VS) Reference: Well (O.OON,O. OOE,180.OOAzi) Wellpath: 1J-182L1PB1 Survey Calculation Method: Minimum Curv ature Db: Oracle __ Sun cv 1tD Incl Azim "I'VD Sys TVD \/S - E/W -- 11fnpN NtapE Tool ft deg deg ft ft ft ft ft ft 11742.80 90.59 184.28 3346.63 3225.33 -10058.82 -1771.25 5935310.27 557087.17 MWD+IFR-AK-CAZ-SC 11837.54 90.66 183.89 3345.60 3224.30 -10153.31 -1778.00 5935215.73 557081.16 MWD+IFR-AK-CAZ-SC 11932.67 90.90 183.74 3344.30 3223.00 -10248.22 -1784.33 5935120.79 557075.58 MWD+IFR-AK-CAZ-SC ~ 12027.61 90.90 181.88 3342.81 3221.51 -10343.03 -1788.98 5935025.95 557071.66 MWD+IFR-AK-CAZ-SC 12121.52 91.03 179.04 3341.23 3219.93 -10436.92 -1789.74 5934932.07 557071.64 MWD+IFR-AK-CAZ-SC 12212.67 90.65 175.36 3339.89 3218.59 -10527.93 -1785.29 5934841.11 557076.80 MWD+IFR-AK-CAZ-SC 12311.69 90.41 171.99 3338.98 3217.68 -10626.33 -1774.38 5934742.80 557088.48 MWD+IFR-AK-CAZ-SC 12406.96 90.16 169.52 3338.50 3217.20 -10720.35 -1759.07 5934648.91 557104.51 MWD+IFR-AK-CAZ-SC 12502.14 89.60 167.55 3338.70 3217.40 -10813.63 -1740.16 5934555.80 557124.16 MWD+IFR-AK-CAZ-SC ~ 12597.38 89.92 167.49 3339.10 3217.80 -10906.62 -1719.58 5934462.98 557145.46 MWD+IFR-AK-CAZ-SC I 12692.74 90.10 168.99 3339.08 3217.78 -10999.97 -1700.14 5934369.79 557165.62 MWD+IFR-AK-CAZ-SC 12787.87 90.41 171.53 3338.66 3217.36 -11093.72 -1684.05 5934276.17 557182.44 MWD+IFR-AK-CAZ-SC 12882.53 90.28 172.73 3338.09 3216.79 -11187.49 -1671.09 5934182.52 557196.13 MWD+IFR-AK-CAZ-SC 12978.05 90.78 174.45 3337.21 3215.91 -11282.40 -1660.42 5934087.70 557207.54 MWD+IFR-AK-CAZ-SC 13072.83 95.56 175.44 3331.97 3210.67 -11376.64 -1652.09 5933993.54 557216.61 MWD+IFR-AK-CAZ-SC i 13168.07 93.66 174.70 3324.31 3203.01 -11471.22 -1643.93 5933899.04 557225.51 MWD+IFR-AK-CAZ-SC 13262.94 92.44 175.59 3319.26 3197.96 -11565.61 -1635.91 5933804.72 557234.26 MWD+IFR-AK-CAZ-SC 13358.58 93.06 176.59 3314.68 3193.38 -11660.92 -1629.40 5933709.48 557241.52 MWD+IFR-AK-CAZ-SC SC T 13487.00 94.24 177.79 3306.15 3184.85 -11788.91 -1623.47 5933581.55 557248.44 ED to D P O EC Tirne Logs Date__ From _ _To Dur S. Depth_ E__Depth Phase Code__ Subcode T COM 11/01/2006 23:15 00:00 0.75 5,030 5,506 PROD2 STK TRIP P Continue trip in hole f/ 5030' to 5506' (stand #56 in hole. Checking torque and inspecting super sliders. Fluid lost to hole f/ 1800 hrs to midnight = 5 bbls Total fluid lost to hole today = 26 bbls. Total fluid lost to "B" lateral = 687.5 bbls. 11/02/2006 00:00 03:45 3.75 5,506 8,167 PROD2 STK TRIP P Continue trip in hole f/ 5506' to 58167'. Checking torque and inspecting super sliders. Fill i e eve 20 stands. 03:45 04:15 0.50 8,167 8,548 PROD2 STK TRIP P Continue RIH w/ 5"drill pipe w/o super sliders f/ 8167' to 8548' 04:15 05:15 1.00 8,548 8,605 PROD2 STK CIRC P Establish circ and MADD pass log f/ 8548' to 8605' no go depth. Logging de th 8385' to 8442'. 05:15 05:30 0.25 8,605 9,118 PROD2 STK TRIP P Continue RIH f/ 8605' to 9118'. 05:30 06:00 0.50 9,118 9,118 PROD2 STK CIRC P Break circ @ 9118'. Orient whipstock to 12 deg left. Pumping 505 gpm w/ 2000 psi. Fluid lost to well f/midnight to 0600 hrs = 7 bbls Total fluid lost on trip in w/ whi stock = 12 bbls. 06:00 07:00 1.00 9,118 9,224 PROD2 STK TRIP P Continue to work string down to top of "B" lateral @ 9224'. Tag up, set anchor, attempt to shear off of whi stock, unsucessful. 07:00 07:30 0.50 9,224 9,224 PROD2 STK OTHR P PJSM on displacement f/ SFOBM to OBM. 07:30 09:00 1.50 9,224 9,224 PROD2 STK CIRC P Start displacement from 8.8 ppg SFOBM to 8.8 ppg OBM. Working string up to 220k and Down to block wt w/ 10k ft Ib torque. Finally broke ` .- ` ~:.. shear bolt. 35k down to shear. Rotate ~, t~ a © UGC` ~ ~ ~ ~C..~ ~~ `v \ ~ ~°~-~ ~7 @ 50 rpm after sheared. Stop rotation. Finish displacement of 600 bbls um ed 400 m w/ 1390 si. 09:00 12:45 3.75 9,121 9,139 PROD2 STK WPST P Start milling @ 9121' to 9138'. Rotate 80-90 rpm w/ 12-13k ft Ib torque. Max torque of 17k when upper mill @ top of window. Pumping 400 gpm w/ 1390 psi. Milled to 9139'. Rotating wt 135k, PU wt 220k, SO wt 100k. WOB 2-10k. ` ` ~ Pumped @ 34 bbls hi vis weighted swee while millin 9130'. Paq~ 46 ref ~~ ~; Time Logs - _ Date From To Dur S Depth E. De th Phase Code Subcode T COM 11/02/2006 _ 12:45 _ _ 14:30 1.75 9,139 9,161 PROD2 STK WPST _ P _ __ Continue milling w/upper mill @ top of window, to bottom of window @ pilot mill depth of 9158.48', then continue milling to 9161' pilot mill depth. Upper mill 8-1/2" OD is 3' below bottom of window. Pumping 400 gpm w/ 1350 psi. Rotating 90 rpm w/ 10-17k ft Ib torque. Ream through window, then pass through with out rotation. Rotating weight 135k. PU wt 220k, SO wt 100k. WOB 2-6k. 14:30 16:00 1.50 9,161 9,161 PROD2 STK CIRC P Pump a 30 bbl hi vis weighted sweep. Work mill through window while pumping 400 gpm w/ 1350 psi. Rotate 120 rpm w/ 12k ft Ib torque. Circulate a total of 720 bbls. 16:00 16:15 0.25 9,161 9,161 PROD2 STK OWFF P Monitor well. Static. 16:15 18:00 1.75 9,161 5,307 PROD2 STK TRIP P Blow down top drive, then pull out of hole w/milling assembly f/ 9161' to 5307'. SPR@9161':#1 @20 spm=230 psi, 30 spm = 300 psi. #2@20 spm= 230 si, 30 s m = 300 si. 18:00 20:30 2.50 5,307 647 PROD2 STK TRIP P Continue POOH w/milling assembly f/ 5307' to 647' 20:30 21:00 0.50 647 647 PROD2 RIGMN SVRG P PJSM on slipping and cutting drilling line. 21:00 22:30 1.50 647 647 PROD2 RIGMN SVRG P Slip and cut 115' of 1-3l8" drilling line. 22:30 00:00 1.50 647 0 PROD2 STK TRIP P Finish POOH w/milling assembly. Guage mills. Upper mill 8-1/2", middle mill 8", lower mill 7-5/8". Trip out calc 81 bbls, actual 98 bbls. Fluid lost total today = 24 bbls Total Fluid lost to well = 711.5 bbls. 11/03/2006 00:00 00:45 0.75 0 0 PROD2 STK PULD P Break and laydown Baker mills. 00:45 01:00 0.25 0 0 PROD2 STK OTHR P Clean and clear rig floor. 01:00 02:00 1.00 0 0 PROD2 STK OTHR P PU/MU stack washing tool, wash stack to remove any iron f/ milling f/ ram cavities. Lay down tool. Blow down to drive. 02:00 03:45 1.75 0 0 PROD2 RIGMN SVRG NP Remove cement hose and standpipe from off driller's derrick leg to extend stand i e. Pag€~ 47 Gf fi4 d ~~ Time Logs Date From To Dur S.. D_e~thTE. De th Pha Code _ Subcode T COM _ 11/03/2006 03:45 06:45 3.00 0 372 PROD2 DRILL PULD P PU/MU BHA #8: 6-3/4" Security FMF3641Z ser no. 10891692 w/ a restrictor and (3) 21/32" nozzles, Sperry Sun 5200 series geopilot (ser no. TL-034), geopilot flex collar, DM HOC, 6.625" Smart stabilizer, Gamma/Res, PWD, TM HOC, nm float sub, 6.437" welded blade stabilizer, (3) 4-3/4" nm flex drill ocllars, x-o, (1) 4" HWDP, Daily jars (ser no. 140-01019). (4) 4" HWDP. Total = 372.24'. Uploaded MWD @ 94', shallow pulse tested @ 280' w/ 320 gpm and 1450 psi, roated slow (25 rpm) to break in seals on eo ilot. 06:45 07:00 0.25 372 372 PROD2 DRILL OTHR P Blow down top drive, choke manifold and kill line. 07:00 07:15 0.25 372 372 PROD2 DRILL SFTY P PJSM on picking up 15 joints of 4"drill i e f/ i e shed. 07:15 08:00 0.75 372 840 PROD2 DRILL PULD P Rabbit to 2.25" and PU/MU/RIH 15 joints of 4" Weatherford S-135 15.7 ppf drill i e. 08:00 08:30 0.50 840 840 PROD2 DRILL OTHR P Clear and clean rig floor. 08:30 13:00 4.50 840 8,814 PROD2 DRILL TRIP P RIH w/ 4"drill pipe f/derrick f/ 840' to 8814.97'. Added crossover to 5". 13:00 13:15 0.25 8,814 8,814 PROD2 DRILL TRIP P Change elevators f/ 4" to 5". Fill pipe. 13:15 14:00 0.75 8,814 9,161 PROD2 DRILL TRIP P RIH w/ 5" drill pipe, install Centurian ball catcher and circ sub one joint above x-o, continue to and through window @ 9121' to 9161'. Did not see an thin while oin throu h window. 14:00 14:15 0.25 9,161 9,161 PROD2 DRILL CIRC P Circulate @ 300 gpm w/ 2580 psi. Rotate @ 40 rpm w/ 8-9k ft Ib torque. ECD's 9.36 ppg Baseline estimated ECD's w/ 8.8 ppg mud in hole, circ 300 gpm : If no hole made 9.38 ppg, 200 ft/hr=10.49 ppg, 250 ft/hr= 10.78 ppg, 300 ft/hr= 11.07 e ~~ge 4~ of ~~ ~~ Time Lo s Date From To Dur S De th E. De th Phase Code Subc e T COM 11/03/2006 14:15 18:00 3.75 9,161 9,493 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 9161' to 9493' (326') (3356' TVD) Bit hours= 2.08, Jar (#140-01019) hours= 99.05, ART= 2.08 hrs, WO6= 5-7k, 40-90 rpm, 300 gpm @ 2580 psi on bottom and 2570 psi off bottom. Torque = 8-9k ft-Ibs on botttom and 8-10k ft-Ibs off bottom. ECD= 9.31-9.52 ppg. Avg gas 35 units. Max gas 138 units. P/U = 175-170k, S/O = 100k, Rot= 130k w/pumps off. Baseline estimated ECD's @ 9298' w/ 8.8 ppg mud in hole, circ 300 gpm If no hole made 9.38 ppg, 200ft/hr=10.49 ppg, 250 ft/hr= 10.78 300 ft/hr= 11.07 18:00 00:00 6.00 9,493 10,471 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 9493' to 10471' (978') (3346' TVD) Bit hours= 5.53, Jar (#140-01019) hours= 102.5, ART= 3.45 hrs, WO6= 2-8k, 90-120 rpm, 300-340 gpm @ 2580-3210 psi on bottom and 2570-2980 psi off bottom. Torque = 8-10k ft-Ibs on botttom and 9-10k ft-Ibs off bottom. ECD= 9.66-10.1 ppg. Avg gas 35 units. Max gas 138 units. P/U = 170-190 k, S/O = 100-95 k, Rot= 130 k w/ um s off. 11/04/2006 00:00 04:30 4.50 10,471 11,181 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 10471' to 11181' (710') (3355' TVD) Bit hours= 8.11, Jar (#140-01019) hours= 105.08, ART= 2.58 hrs, WO6= 2-6k, 110-120 rpm, 340-330 gpm @ 3210-3090 psi on bottom and 3180-3050 psi off bottom. Torque = 9-10k ft-Ibs on botttom and 8-10k ft-Ibs off bottom. ECD= 10.1-10.3 ppg. Max gas 199 units. P/U = 1190-200 k, S/O = 95 k, Rot= 130 k w/ um s off. 04:30 05:15 0.75 11,181 11,014 PROD2 DRILL CIRC P Backream out of hole f/ 11181' to 11014' pumping 330 gpm w/ 3050 psi, rotate 120 rpm w/ 9k ft Ib torque. PU wt 200k, SO wt 95k, Rot wt 130k. 05:15 05:30 0.25 11,014 11,181 PROD2 DRILL TRIP P RIH f/ 11014' to 11209'. 05:30 06:00 0.50 11,181 11,209 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 11181' to 11209' (28') (3357' TVD) Bit hours= 8.33, Jar (#140-01019) hours= 105.30, ART= .22 hrs, WOB= 2-6k, 120 rpm, 330 gpm @ 3090 psi on bottom and 3050 psi off bottom. Torque = 10k ft-Ibs on botttom and 8-9k ft-Ibs off bottom. ECD= 10.2 ppg. P/U = 200 k, S/O = 95 k, Rot= 130 k w/ um s off. P~c~e 49 taf ~ Time Logs __ _ _ Date From To Dur S De th E. De th Phase Code Subcode T COM 11/04/2006 06:00 12:00 -- 6.00 11,209 11,966 PROD2 DRILL - DDRL _ P _ _. Drilling 6-3/4" production "D" lateral f/ 11209' to 11966' (757') (3340' TVD) Bit hours= 12.49, Jar (#140-01019) hours= 109.46, ART= 4.16 hrs, WOB= 2-10k, 100-120 rpm, 330-295 gpm @ 3090-2460 psi on bottom and 3050-2400 psi off bottom. Torque = 10-12 k ft-Ibs on botttom and 10-12k ft-Ibs off bottom. ECD= 10.03-10.30 ppg. Avg gas 150 units. Max gas 365 units. P/U = 195-210 k, S/O = 95-90 k, Rot= 130-135 k w/ pumps off. 12:00 18:00 6.00 11,966 12,822 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 11966' to 12822' (856') (3338' TVD) Bit hours= 15.42, Jar (#140-01019) hours= 112.39, ART= 2.93 hrs, W06= 4-8k, 80-90 rpm, 260-283 gpm @ 2000-2390 psi on bottom and 1960-2350 psi off bottom. Torque = 11-13 k ft-Ibs on botttom and 12-13k ft-Ibs off bottom. ECD= 10.09-10.29 ppg. Avg gas 109 units. Max gas 405 units. P/U = 205-215 k, S/O = 88-83 k, Rot= 130-140 k w/ pumps off. 18:00 19:30 1.50 12,822 13,045 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 12822' to 13045' (223') (3334' TVD) Bit hours= 16.39, Jar (#140-01019) hours= 113.36, ART= .97 hrs, WOB= 4-8k, 90 rpm, 270-260 gpm @ 22250-2180 psi on bottom and 2100-2130 psi off bottom. Torque = 13-14 k ft-Ibs on botttom and 14 k ft-Ibs off bottom. ECD= 10.35 ppg. Avg gas 109 units. Max gas 405 units. P/U = 215-220 k, S/O = 80 k, Rot= 140-135 k w/ pumps off. Pump a 9.8 ppg hi weight (9.8 ppg) hi vis sweep @ 12900', slight increase in cuttin s. 19:30 22:30 3.00 13,045 13,487 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 13045' to 13487' (442') (3338' TVD) Bit hours= 17.92, Jar (#140-01019) hours= 114.89, ART= 1.53 hrs, W06= 2-10k, 70-100 rpm, 320 gpm @ 3070-3120 psi on bottom and 3100 psi off bottom. Torque = 12-13 k ft-Ibs on botttom and 14-13k ft-Ibs off bottom. ECD= 10.39-10.8 ppg. Avg gas 109 units. Max gas 405 units. P/U = 220 k, S/O = 80 k, Rot= 135 k w/ pumps off. Note: Decision was made to Sidetrack for Geolo 22:30 23:30 1.00 13,487 13,005 PROD2 STK CIRC T Backream out of hole for sidetrack . Backream f/ 13487' to 13005'. Pumping 330 gpm w/ 3200 psi, rotate 120 r m w/ 12k ft Ib for ue. ,~ Time Logs Date From To Dur S De th E. De th ode T COM Phase Code Subc 11/04/2006 23:30 00:00 _ 0.50 13,005 13,012 PROD2 DRILL _ DDRL T Trough f/ 13005' to 13012'. Pumping 330 gpm w/ 3200 psi. Rotate 95 rpm w/ 11 k ft Ib for ue. 11/05/2006 00:00 00:30 0.50 13,012 13,045 PROD2 DRILL DDRL T Trough f/ 13012' to 13045'. Pumping 330 gpm w/ 3200 psi. Rotate 95 rpm w/ 11 k ft Ib for ue. 00:30 02:45 2.25 13,045 13,297 PROD2 DRILL DDRL T Drilling 6-3/4" production "D" lateral f/ 13045' to 13297' (252') (3340' TVD) Bit hours= 19.28, Jar (#140-01019) hours= 116.25, ART= 1.36 hrs, t~ , C~ ~~ `~ ~ W06= 2-10k, 100 rpm, 320 gpm @ 1 ~ 3120-3080 psi on bottom and 1,~© _ '' 1~1~ ~ 3010-3080 psi off bottom. Torque = 11-12 k ft-Ibs on botttom and 8-10k ft-Ibs off bottom. ECD= 10.5 ppg. 143 units. P/U = 210 k, S/O = 85 k, Rot= 140-135 k w/ um s off. 02:45 03:00 0.25 13,297 13,204 PROD2 DRILL REAM T Backream f/ 13297' to 13204'. Pumping 320 gpm w/ 2980 psi. Rotate 100 rpm w/ 11 k torque. PU wt 200k, SO wt 95k. Rotating wt 135k. Need to check out Varco TDS-8SA to drive. 03:00 03:30 0.50 13,204 13,204 PROD2 RIGMN SVRG T Check out dim flashing oil pressure/temp light on Driller's top drive anel. 03:30 03:45 0.25 13,204 13,297 PROD2 DRILL REAM T Make top drive connection and ream f/ 13204' to 13297'. Pump 320 gpm w/ 2980 psi. Rotate 100 rpm w/ 11 k ft Ib torque. PU wt 200k, SO wt 95k, rotatin wt 135k. 03:45 05:00 1.25 13,297 13,487 PROD2 DRILL DDRL T Drilling 6-3/4" production "D" lateral f/ 13297' to 13487' (190') (3340' TVD) Bit hours= 20.26, Jar (#140-01019) hours= 117.23, ART= .98 hrs, W06= 8-10k, 100 rpm, 320 gpm @ 2980 psi on bottom and 2930 psi off bottom. Torque = 12 k ft-Ibs on botttom and 10 k ft-Ibs off bottom. ECD= 10.7 ppg. Max gas 165 units. P/U = 210 k, S/O = 85 k, Rot= 135 k w/ um s off. 05:00 06:00 1.00 13,487 13,554 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 13487' to 13554' (67') (3333' TVD) Bit hours= 20.81, Jar (#140-01019) hours= 117.78, ART= .55 hrs, WOB= 8-10k, 100 rpm, 320 gpm @ 2900 psi on bottom and 2850 psi off bottom. Torque = 12 k ft-Ibs on botttom and 13k ft-Ibs off bottom. ECD= 10.54 ppg. Max gas 96 units. P/U = 205 k, S/O = 85 k, Rot= 135 k w/ um s off. I~~~ 5°t of 69 ~ • i Date From Tn Dur S Denth F Denth Phaca C:nrie Snhrnrla T CnM I 11/05/2006 06:00 12:00 6.00 13,554 13,867 PROD2 DRILL DDRL P Drilling 6-3/4"production "D" lateral f/ 13554' to 13867' (313') (3328' TVD) Bit hours= 25.50, Jar (#140-01019) hours= 122.47, ART= 4.69 hrs, WO6= 8-10k, 100 rpm, 320-315 gpm @ 2900-2800 psi on bottom and 2850-2750 psi off bottom. Torque = 12-13 k ft-lbs on botttom and 13-15k ft-Ibs off bottom. ECD= 10.54-10.4 ppg. Max gas 140 units. P/U = 215 k, S/O = 85-80 k, Rot= 130-135 k w/ um s off. 12:00 12:30 0.50 13,867 13,867 PROD2 RIGMN SVRG T Tighten up Shot Pin assembly on top drive handlin rin assembl . 12:30 12:45 0.25 13,867 13,867 PROD2 RIGMN SVRG P Service wash pipe packing. 12:45 18:00 5.25 13,867 14,560 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 13867' to 14560' (693') (3310' TVD) Bit hours= 28.14, Jar (#140-01019) hours= 125.11, ART= 2.64 hrs, WO6= 8-10k, 100 rpm, 315-305 gpm @ 2750-2925 psi on bottom and 2700-2900 psi off bottom. Torque = 13-15 k ft-Ibs on botttom and 14-15k ft-Ibs off bottom. ECD= 10.6-10.81 ppg. Max gas 140 units. P/U = 215-225 k, S/O = 80-75 k, Rot= 130 k w/ um s off. 18:00 00:00 6.00 14,560 15,387 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 14560' to 15387' (827') (3303' TVD) Bit hours= 31.10, Jar (#140-01019) hours= 128.07, ART= 2.96 hrs, WO6= 8-10k, 100-80 rpm, 310-258-320 gpm @ 2900-2170-3040 psi on bottom and 2825-2130-3040 psi off bottom. Torque = 14-16 k ft-Ibs on botttom and 14-15k ft-Ibs off bottom. ECD= 10.85-11.1 ppg. Max gas 140 units. P/U = 230-250 k, S/O = 72 k, Rot= 140-135 k w/ um s off. 11/06/2006 00:00 06:00 6.00 15,387 16,301 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 15387' to 16301' (914') (3290' TVD) Bit hours= 34.64, Jar (#140-01019) hours= 131.61, ART= 3.54 hrs, WOB= 8-10k, 80 rpm, 320-270 gpm @ 3111-2430 psi on bottom and 2940-2400 psi off bottom. Torque = 16-17 k ft-Ibs on botttom and 15k ft-Ibs off bottom. ECD= 11.29-11.06 ppg. Max gas 268 units. P/U = 255 k, S/O = 72 k, Rot= 150 k w/ um s off. ~'~c~~ Z of 6~ Time Logs _ __ Date From To Dur S. Depth E. De th Phase Code Subcode T_ COM 11/06/2006 06:00 12:00 6.00 16,301 16,813 PROD2 DRILL DDRL P Drilling 6-3l4" production "D" lateral f/ 16301' to 16813' (512') (3287' ND) Bit hours= 38.06, Jar (#140-01019) hours= 135.03, ART= 3.42 hrs, WOB= 8-10k, 100-90 rpm, 310-333 gpm @ 3010-3250 psi on bottom and 3000-3200 psi off bottom. Torque = 14-16 k ft-Ibs on botttom and 15-16k ft-Ibs off bottom. ECD= 11.39-11.53 ppg. Max gas 304 units. P/U = 255 k, S/O = 72 k, Rot= 140-135 k w/ um s off. 12:00 18:00 6.00 16,813 17,451 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 16813' to 17451' (638') (3281' ND) Bit hours= 41.09, Jar (#140-01019) hours= 138.06, ART= 3.03 hrs, WOB= 10k, 90 rpm, 315-310 gpm @ 3000-3130 psi on bottom and 2950-3100 psi off bottom. Torque = 15-17 k ft-Ibs on botttom and 15-16k ft-Ibs off bottom. ECD= 11.54- 11.7 ppg. Max gas 304 units. P/U = 275 k, S/O = 72 k, Rot= 132 k w/ um s off. 18:00 00:00 6.00 17,451 17,737 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 17451' to 17737' (286') (3272' ND) Bit hours= 45.84, Jar (#140-01019) hours= 142.81, ART= 4.75 hrs, WOB= 10k, 90 rpm, 30-312 gpm @ 3130-3150 psi on bottom and 3100-3110 psi off bottom. Torque = 17 k ft-Ibs on botttom and 19-20k ft-Ibs off bottom. ECD= 11.7 ppg. Max gas 275 units. P/U = 270 k, S/O = 75 k, Rot= 135 k w/ um s off. 11/07/2006 00:00 01:15 1.25 17,737 17,757 PROD2 DRILL DDRL P Drilling 6-3/4" production "D" lateral f/ 17737' to 17757' (20') (3272' ND) Bit hours= 46.77, Jar (#140-01019) hours= 143.74, ART= .93 hrs, WOB= 10k, 90 rpm, 30-312 gpm @ 3130-3150 psi on bottom and 3100-3110 psi off bottom. Torque = 17 k ft-Ibs on botttom and 19-20k ft-Ibs off bottom. ECD= 11.7 ppg. Max gas 275 units. P/U = 270 k, 5/O = 75 k, Rot= 135 k w/ um s off. 01:15 04:00 2.75 17,757 17,757 PROD2 DRILL CIRC P Circ and recip 30' stroke.. Pumping 30 BBL 9.8 PPG sweep @ 286 gpm w/ 2800 psi. ECD's 11.7 ppg. Rotate 90 rpm w/ 16-17k ft Ib. UP WT = 270K, SO WT = 72K, ROT WT = 135K. 04:00 04:45 0.75 17,757 17,757 PROD2 DRILL CIRC P Breakout Single, drop 2 1/8" ball down string, make up single. Pump ball down @ 3 BPM - 1070 PSI. Allow to seat, with 711 strokes, 1100 PSI. Continue pressure to 1900 PSI to o en Centurion circulatin valve. ~~~ _ gage 53 of 69 ~ ~ Time Logs _ _ Date From To Dur S De th E. De th Phase Code Subcode T COM __ 11/07/2006 04:45 06:00 1.25 17,757 17,757 PROD2 DRILL CIRC ~ P~ Continue circulating with valve open @ 290 GPM's - 490 PSI. Stage pumps to 397 GPM - 770 PSI, 500 GPM - 1110 PSI, 656 GPM's 1730 PSI, 900 GPM - 2860 PSI. Continue circulate @ 900 GPM's with 2830 PSI observing good hole cleaning with increased cuttings at shakers. Pump until clean. Crew than e 06:00 06:30 0.50 17,757 17,757 PROD2 DRILL CIRC P Break single in string. Pump down closing ball @ 3 BPM - 270 PSI. Observed 720 strokes to seat ball, and 2100 PSI to close valve. Confirmed valve closed with 68 SPM - 2800 PSI. 06:30 12:00 5.50 17,757 15,400 PROD2 DRILL REAM P BROOH from 17757' - 15400' at drilling parameters of 300 GPMs - 3050 PSI. 90 RPM's, ROT WT = 150K with 15K for ue. 12:00 16:30 4.50 15,400 13,078 PROD2 DRILL REAM P Continue BROOH from 15400' - 13078' at drilling parameters of 325 GPMs - 2950 PSI. 90 RPM's, ROT WT = 130K with 12K for ue. 16:30 16:45 0.25 13,078 13,078 PROD2 DRILL SRVY P Perform checkshot survey @ 13078' MD. Verify calculated top of sidetrack at a 3 de ree do le . 16:45 18:00 1.25 13,078 12,253 PROD2 DRILL REAM P Continue BROOH from 13078' - 12253' at drilling parameters of 325 GPMs - 2950 PSI. 90 RPM's, ROT WT = 125K with 12K for ue. Crew Chan e 18:00 00:00 6.00 12,253 9,100 PROD2 DRILL REAM P Continue BROOH from 12253' - 9100' at drilling parameters of 325 GPMs - 2900 PSI. 80 RPM's, ROT WT = 120K with 10K torque. Pull throuh window area with no rotation. Observed no issues with assembly passing through window area. TOW = 9121' MD. 11/08/2006 00:00 02:00 2.00 9,100 9,100 PROD2 DRILL CIRC P Circulate @ 330 GPM - 2850 PSI. No reciprocation. Observe little increase in cuttings across shakers on bottoms u. 02:00 03:00 1.00 9,100 9,100 PROD2 RIGMN RGRP P PJSM with crew. Discuss safety issues and procedure to hang new extension in derrick and proper clamps. Install cement line standpipe extension. 03:00 04:15 1.25 9,100 9,100 PROD2 RIGMN SVRG P PJSM with crew. Discuss safety issues and procedure for slipping & cutting drilling line. Slip & cut 111' of drilling line. Inspect & adjust brakes on draw works. 04:15 06:00 1.75 9,100 9,100 PROD2 RIGMN SVRG P Service Top Drive, Change out filters and gear oil.lnspect shot pin assembly. Monitor well -static. Crew than e 06:00 06:45 0.75 9,100 9,100 PROD2 RIGMN SVRG P Continue & complete servicing of Top Drive and inspection of shot pin assembl .Monitor well -static. f'ag~ 54 ref 89 ~ ~ Time Lo s Date From To Dur S De th E. De th Phase Code Subcode T COM 11/08/2006 06:45 10:30 _ 3.75 9,100 13,450 PROD2 DRILL TRIP P Trip in hole from 9100' - 13450' on elevators. Observe run out of down weight. Obtain T&D parameters as per rig emgineer every 5 stands in open hole. Fill drill strin eve 25 stands. 10:30 12:00 1.50 13,450 15,012 PROD2 DRILL REAM P Wash & ream each stand from 13450' - 15012'. Pumps @ 300 GPM's - 2950 PSI. 50 RPM's with 12-13 K torque. ROT WT = 130K. 12:00 17:00 5.00 15,012 17,757 PROD2 DRILL REAM P Continue Wash & ream each stand from 15012' - 17757' MD. Pumps @ 135 GPM's - 1100 PSI. 50 RPM's with 14-15 K for ue. ROT WT = 126K. 17:00 18:00 1.00 17,757 17,757 PROD2 DRILL CIRC P Circulate & condition mud pumping a 9.8 PPG, 40 BBL Hi Visc sweep @ 295 GPM's - 3100 PSI. 80 RPM's with 16-17K torque. UP WT = 145K, SO WT = 115K, ROT WT = 125K. Reciprocate & rotate drill string in 30' increments while pumping. Crew Chan e 18:00 20:00 2.00 17,757 17,757 PROD2 DRILL CIRC P Continue circulate & condition mud pumping a 9.8 PPG, 40 BBL Hi Visc sweep @ 295 GPM's - 3100 PSI. 80 RPM's with 16-17K torque. UP WT = 145K, SO WT = 115K, ROT WT = 125K. Reciprocate & rotate drill string in 30' increments while pumping. Observed sweep returned with little or no increase in cuttin son shakers. 20:00 20:15 0.25 17,757 17,757 PROD2 DRILL CIRC P Break out single DP, and drop 2 1/8" ball down drill string for Centurion Circulating valve. Total of 3 - 2 1/8" balls in strip . 20:15 20:30 0.25 17,757 17,757 PROD2 DRILL CIRC P Allow ball to fall while pumping down drill string at 3 BPM - 1100 PSI. Obsrve ball on seat with 748 strokes. pressue to 2000 PSI to observe ressure loss of 800 PSI. 20:30 20:45 0.25 17,757 17,757 PROD2 DRILL CIRC P Pump down drill string observing CCV still in closed position. Pressure @ 3100 PSi with 295 GPM's. 20:45 21:00 0.25 17,757 17,757 PROD2 DRILL CIRC P Break out single DP, and drop 2 1/8" ball down drill string for Centurion Circulating valve. Total of 4 - 2 1/8" balls in strip . 21:00 21:15 0.25 17,757 17,757 PROD2 DRILL CIRC P Pump down drill string @ 3 BPM - 1100 PSI observing ball on seat with 758 strokes. Pressure to 2000 PSI to observe CCV in open position. Bleed ressure to zero. Paq~ ~ ~f ~9 C7 Time Lo_~ _ __ __ Date From To Dur _ S. Depth E. De th Phase .Code Subcode T COM _ 11/08/2006 21:15 22:30 1.25 17,757 17,757 PROD2 DRILL CIRC P Verify open CCV valve with 300 GPM - 570 PSI. 70 RPM's. 400 GPM's - 850 PSI, 70 RPM's. 500 GPM's - 1180 PSI, 70 RPM's. 600 GPM's - 1620 PSI, 70 RPM's. 700 GPM's - 2100 PSI, 70 RPM's. 800 GPM's - 2600 PSI, and 900 GPM's - 3100 PSI. Full flow @ 33 %, @ 70 RPM's. Continue circulate a total of 4 bottoms up observing hole clean with little or no increase in cuttings at shakers. ECD's @ 12.17 PPG. No fluid loss. Reci rotate drill strip while um in . 22:30 22:45 0.25 17,757 17,757 PROD2 DRILL CIRC P Break out single DP, and drop 2 1/8" ball down drill string for Centurion Circulating valve. Total of 5 - 2 1/8" balls in strip . 22:45 23:00 0.25 17,757 17,757 PROD2 DRILL CIRC P Pump down drill string @ 3 BPM - 300 PSI observing ball on seat with 741 strokes. Pressure to 2000 PSI to observe CCV in closed position. Bleed ressure to zero. 23:00 23:15 0.25 17,757 17,757 PROD2 DRILL CIRC P Verify CCV valve in closed position pumping down drill string @ 303 GPM's - 3200 PSI. 70 RPM's, and 17% flow. Reci rotate drill strip . 23:15 23:30 0.25 17,757 17,757 PROD2 DRILL SFTY P Continue circulating through bit with a closed CCV valve. Hold PJSM with entire crew and all truck drivers. Designate a spill champion. Discuss safety issues and procedure for displacing well with 8.7 PPG SFMOBM. 23:30 00:00 0.50 17,757 17,757 PROD2 DRILL CIRC P Displace well with 8.7 PPG SFMOBM @ 345 GPM's - 3900 PSI. 80 RPM's with 15K torque. 19 % flow. Reci rotate & rotate drill strip . 11/09/2006 00:00 02:15 2.25 17,757 17,757 PROD2 DRILL CIRC P Continue Displace well with 8.7 PPG SFMOBM @ 345 GPM's - 3900 PSI. 80 RPM's with 15K torque. 19 % flow. Reciprocate & rotate drill string. ECD = 12.17 PPG. Final Circulating pressure with SFMOBM in hole = 345 GPM's - 3650 PSI. ECD = 11.24 PPG. 02:15 02:30 0.25 17,757 17,757 PROD2 DRILL OWFF P Monitor well -static. 02:30 03:00 0.50 17,757 17,291 PROD2 DRILL TRIP P POOH on elevators from 17757' - 17291'. Observe clean hole hole, no swabbin . 5 stands. 03:00 03:30 0.50 17,291 17,291 PROD2 DRILL CIRC P Pump 30 BBL 10.8 PPG dry job. Chase with 10 BBLS SFMOBM. Blow down Top drive & lines. Monitor well - static. 03:30 06:00 2.50 17,291 10,500 PROD2 DRILL TRIP P Continue POOH on elevators from 17291' - 10500'. Observe proper hole fill. Record T&D parameters as per rig en ineer eve 5 stands. Crew Chan e i~ag~ 6 of ~~ Time Logs _ _ _ Date From To Dur S. De th E. Depth Phase Code Subcode T COM _ ___ 11/09/2006 06:00 07:30 1.50 10,500 8,814 PROD2 DRILL TRIP P Continue POOH on elevators from 10500' - 8814'. Observe proper hole fill. Record T&D parameters as per rig engineer every 5 stands. Observe no issues going through window area 9121' MD. 07:30 08:00 0.50 8,814 8,814 PROD2 DRILL PULD P Breakout & lay down Centurion Circulating valve. Recover 5 - 2 1/8" balls. Chan a elevators. 08:00 11:00 3.00 8,814 372 PROD2 DRILL TRIP P Continue POOH from 8814' - 372'. Observe proper hole fill. Monitor well - static. 11:00 11:45 0.75 372 87 PROD2 DRILL PULD P Breakout & lay down BHA #8. Lay down 4 - 4" HWDP (122.70'), 4 3/4" Drilling Jars (28.82'), 1 - 4" HWDP (30.68'), Crossover sub (3.00'), 3 - 4 3/4" Non Mag Flex drill Collars (92.92'), 4 3/4" Welded Blade Stabilizer (4.45'), 4 3/4" Non Mag Float sub 2.18' . 11:45 12:00 0.25 87 87 PROD2 DRILL PULD P Plug in and download MWD assembl . 12:00 12:30 0.50 87 87 PROD2 DRILL PULD P Continue download MWD assembly. 12:30 13:30 1.00 87 0 PROD2 DRILL PULD P Continue breakout & lay down remaining BHA #8. Lay down 4 3/4" TM HOC (10.98'), 4 3/4" PWD (10.82'), 4 3/4" Gamma/Res (24.51'), 4 3/4" Smart Stabilizer (3.59'), DM HOC (8.53'), 4 3/4" Geo Pilot Flex Drill collar (11.55'), 5 1/4" 5200 series Geo Pilot (16.21'), and 6 3/4" Security bit FMF 36412 (1.30'). Inspect & grade bit to 1/1MIT/C/X/I/NO/TD. Note: Calculated hole fill at 46.58 BBLS, Actual hole fill = 64.5 BBLS. 13:30 14:45 1.25 0 0 COMPZ CASINC RURD P Clear & clean floor area. Rig up to run 4 1/2" slotted liner assembly. Rig up Tongs, slips elevators and double check running detail with equipment in shed. 14:45 15:15 0.50 0 0 COMPZ CASIN( SFTY P Held PJSM with entire crew, BOT rep, GBR reps, Co man, & TP. Discuss safety issues & procedure for running 4 1/2" Slotted liner assembl . 15:15 18:00 2.75 0 4,732 COMPZ CASIN( RUNL P Make up 4 1/2" Silver Bullet Shoe on a joint of 4 1/2" 11.6 PPF L80 BTC Slotted liner, and continue run 4 1/2" slotted liner as per detail. Make up torque = 3800 FT/Ibs, and 5000 ft/Ibs on joints with torque rings. Run liner to 4732' MD. Obtain T&D parameters as per rig engineer every 10 joints starting at 3000' MD. Crew chan e. €~age 57 a~f ~~ Time Loc~s_ Date From To Dur _ S. De th E. Depth Pha e Code_ Subcode T COM __ _ 1 1/09/2006 1 8:00 23:00 5.00 4,732 8,440 COMPZ CASIN( RRUNL P Continue run 4 1/2" L80 BTC slotted liner form 4732' - 8440' MD. Monitor well -static before picking up Hydril 521 linerjoints. Run a total of 177 joints of 4 1/2" Slotted BTC liner, Crossover joint (41.50'), 18 joints of 4 1/2" 11.6 PPF L80 Hydril 521 Slotted, 5 1/2" hydril 521 x 4 1/2" BTC XO bushing, 1 -jnt 5 1/2" 15.5 PPF L80 Hydril 521 and Baker HR liner setting sleeve with Hydril 521 pup and running tool. Make up 3 1/2 IF x 4 1/2 IF crossover to DP. Make up torque = 3800 FT/Ibs, and 5000 ft/Ibs on joints with torque rings. Obtain T&D parameters as per rig engineer every 10 'oints. 23:00 00:00 1.00 8,440 8,440 COMPZ CASIN( RURD P Rig down all GBR Liner running equipment. Clear & clean rig floor. Monitor well -static. 11/10/2006 00:00 04:15 4.25 8,440 13,487 COMPZ CASIN( RUNL P Continue run 4 1/2"slotted liner on drill pipe from 8440' - 13487'. Record T&D parameters as per rig engineer every 5 stands in open hole. At the window, UP WT = 125K, SO WT = 95K, ROT WT = 105K with 4500 ft/Ibs. 04:15 06:00 1.75 13,487 15,199 COMPZ CASIN( RUNL P Rotate liner in hole from 13487' - 15199' MD. 30 RPM's with 11-12K torque. UP WT = 230K, SO WT = 72K, ROT WT = 120K. Crew Chan e 06:00 11:15 5.25 15,199 17,754 COMPZ CASINC RUNL P Continue rotate in hole with 4 1/2" Slotted liner from 15199' - 17754' MD. 30 RPM's - 11-12K Torque. Observed tight hole from 17591' - 17754' working strin to et to bottom. 11:15 11:30 0.25 17,754 17,754 COMPZ CASIN( RUNL P Drop 29/32" ball in drill string. Make To Drive conection. 11:30 12:00 0.50 17,754 17,754 COMPZ CASINC CIRC P Circulate ball down @ 4 BPM - 710 PSI. Continue rotating liner @ 30 RPM's - 12K Torque. UP WT = 280K, SO WT = 72K, ROT WT = 110K. 12:00 12:45 0.75 17,754 17,754 COMPZ CASIN< CIRC P Continue circulate ball down @ 4 BPM - 710 PSI. Continue rotating liner @ 30 RPM's - 12K Torque. UP WT = 280K, SO WT = 72K, ROT WT = 110K. Slow pump rate to 2 BPM - 350 PSI. Allow ball to seat. P~~ ~ of ss Time Logs _ Date From To Dur S. De th E. Depth Phase Code Subcode T COM _ _ 11/10/2006 12:45 13:15 0.50 17,754 17,754 COMPZ CASIN( RUNL P Work torque out of liner string. Slack off to 90K with DP in compression. Pressure up to 4500 PSI to shear out of setting tool as per BOT rep. Leave liner in hole with Guide shoe @ 17754' - and the top of the setting sleeve @ 9314'. The top of the setting sleeve is 176' out of the bottom of the window @ 9138' MD. Pick up on drill string to observe free of liner, breakout & lay down sin le of DP. 13:15 16:45 3.50 9,314 0 COMPZ CASIN( RUNL P POOH from 9314' -surface. Observe ro er hole fill. 16:45 17:30 0.75 0 0 COMPZ CASIN< RUNL P Inspect, breakout & lay down BOT settin tool. Tool intact. 17:30 18:00 0.50 0 0 COMPZ CASINC OTHR P Clean & clear floor area of all tools, and OBM. Pull tools to rig floor for next BHA. Crew Chan e. 18:00 18:15 0.25 0 0 COMPZ FISH SFTY P Held PJSM with rig crew. Discuss safety issues and procedure for makin h u whi stock retrievin BHA. 18:15 19:30 1.25 0 604 COMPZ FISH PULD P Make up Whipstock retrieving BHA. Make up Baker Whipstock retrieving Hook (8.30'), 1 - jnt 5 "HWDP (31.73'), 4 3/4"Oil Jar (11.54'), and 6 stands of 5" HWDP (552.85'). Total BHA length = 604.42'. 19:30 00:00 4.50 604 9,121 COMPZ FISH TRIP P Trip in hole with retrieving BHA #9 from 604' - 9121' MD. Observe DP filling good, and proper hole fill. UP WT = 205K, SO WT = 95K. Make Top Drive connection & obtain circulation @ 300 GPM's - 650 PSI. 11/11/2006 00:00 00:30 0.50 9,121 9,121 COMPZ FISH FISH P Establish circulation @ 300 GPM's - 650 PSI. Slack off to wash slot in slide rotating 1/4 turns in drill string. Locate & engage slot with hook. PU WT = 205K, SO WT = 100K. Pull over 95K to fire jars, repeat 3 times increasing pull weight to 110K over. until observe whipstock assembly coming free. Pull up 45'. Observed wellbore fluid falling. Stand back 1 stand. 00:30 03:00 2.50 9,121 9,030 COMPZ FISH CIRC P Make Top drive connection, circulate @ 6 BPM - 550 PSI. Observe well took 23 BBLS initially to gain returns. Pump @ 6 BPM to observe 1 BPM loss. Circulate @ 5 BPM with .7 BPM loss. Circulate @ 4 BPM to observe only 1/2 BPM loss. Load pits with more SFMOBM form tank farm. Continue circulating bottoms up increasing rate to 7 1/2 BPM until observed losses down to little or none. 03:00 03:15 0.25 9,030 9,030 COMPZ FISH CIRC P Monitor well -static. Mix dry job to 2.0 ounds over. a i~_ Page ~9 crf 69 Time Logs ___ _ _ Date From To Dur S De th E. De th Phase Code Subcode T COM 11/11/2006 03:15 03:30 0.25 _ 9,030 9,030 COMPZ FISH CIRC P Pump 30 BBL dry job, 10.7 PPG, blow down To Drive and all lines. 03:30 06:00 2.50 9,030 2,826 COMPZ FISH TRIP P POOH with whipstock assembly, slow at first monitoring well for swabbing or losses. Pull from 9030' -2826'. Observed ro er hole fill. Crew Chan e 06:00 07:15 1.25 2,826 604 COMPZ FISH TRIP P Continue POOH with whipstock assembly from 2826' -BHA. Observed ro er hole fill. Monitor well -static. 07:15 09:30 .2.25 604 0 COMPZ FISH PULD P Breakout & lay down Baker Whipstock retrieving Hook (8.30'), 1 - jnt 5 "HWDP (31.73'), 4 3/4" Oil Jar (11.54'), and 6 stands of 5" HWDP (552.85'). Total BHA length = 604.42'. Continue Breakout & lay down Whipstock slide (20.56'), Debris Barrier sub (2.0'), Drain Sub (1.5'), Shear disconnect sub (2.72'), Bottom Trip anchor (2.8'), Blanking sub (.99'), 2 - jnts of 5" HWDP (61.62'), Unloader sub (6.47'), Crossover sub (3.0'), Stop sub with seal assembly (5.32'). Total BHA la ed down = 103.54'. 09:30 10:00 0.50 0 0 COMPZ CASIN( RURD P Pull tools to rig floor. Rig up casing runin a ui ment. 10:00 10:15 0.25 0 0 COMPZ CASIN< SFTY P Held PJSM with crew, GBR reps, and BOT reps. Discuss safety issues and procedure for making up Hook Hanger assembly with Super Slim MWD tools. 10:15 11:00 0.75 0 0 COMPZ CASIN( RUNL P Make up Hook Hanger assembly as per detail. Make up 4 1/2" 12.6# L80 Bent joint with Mule shoe (30.16'), 4 1/2" Crossoverjoint (42.98'), 2 - 4 1/2" 11.6# L80 Slotted joints (82.36'), Baker Payzone External Casin g Packer with pups (31.84'), 2 - 4 1/2" pups (20.09'), Baker Model B Flanged Hook Hanger with Crossover bushing and 4 1/2" pup (32.61'), and Hook Hanger running tool. Make up internal Super Slim MWD assembly with Baker ball catcher, and shear out sub. Orient MWD to Hook Han er Hook. 11:00 12:00 1.00 0 240 COMPZ CASIN( RUNL P Make up internal Super Slim MWD assembly with Baker ball catcher, and shear out sub. Orient MWD to Hook Hanger Hook. Total BHA length = 240.04'. 12:00 12:30 0.50 240 804 COMPZ CASIN( RUNL P Trip in hole with Hook Hanger assembl from 240' - 804' MD. 12:30 12:45 0.25 804 804 COMPZ CASIN( CIRC P Make Top Drive dconnection and perform shallow pulse test @ 3.5 BPM - 960 PSI. Good test. Blow down Top Drive and all lines. h_ Page 64 f 63 • r 1 L J Time Logs Date From To Dur S. De th _ E. De th Phase Code Subcode T _ _ COM ----- 11/11/2006 12:45 18:00 5.25 804 8,313 -- COMPZ - CASIN( T RUNL -- P -- - Trip in hole with Hook Hanger assembly from 804' - 8313'. Trip speed at 50 ft/min as per BOT rep. Observe ro er hole fill. Crew than e. 18:00 19:00 1.00 8,313 9,275 COMPZ CASIN( RUNL P Continue trip in hole with Hook Hanger assembly from 8313' - 9275'. Trip speed at 50 ft/min as per BOT rep. Observe proper hole fill. Pick up single of DP. UP WT = 230K, SO WT = 85K. Tag "B" Lateral Liner top @ 9274'. Pull & stand back 2 stands. 19:00 20:15 1.25 9,275 9,374 COMPZ CASIN( RUNL P Establish circulation @ 30 SPM - 780 PSI. Rotate drill string 3 RH turns, slack off to observe going through window @ 9121' - 9138' MD, and continue RIH to Hook Hanger @ 9138.5'. Set down 20K, pump up surveys to see 7 Degrees left of high side, repeat 3 times. Pull up orient Hook to 180 Degrees out, and slack off to tag crossover in setting sleeve @ 9374' (5' deep). Repeat with 10K set down wei ht. 20:15 21:45 1.50 9,374 9,374 COMPZ CASIN( RUNL P Pull up orient Hook to 180 Degrees out, and slack off to tag crossover in setting sleeve @ 9374' (5' deep). Repeat with 10K set down weight. Pull up to rotate drill string once again 180 Degrees and orient Hook to land at 10 Degrees left of high side. Pump up numerous surveys to verify. Pull up to break connection and drop 1 3/4" ball. make conection. 21:45 22:30 0.75 9,138 9,138 COMPZ CASIN( CIRC P Circulate @ 126 GPM's - 800 PSI pumping ball down, increasing rate to 135 GPM's - 910 PSI observing MWD surveys indicating Hook still set at 10 Degrees left of high side. Slow pump to 86 GPM's - 450 PSI, observing ball seated with 1220 strokes pumped.. Pressure to 2000 PSI as per BOT rep. Bleed pressures. Pressure to 3000 PSI to inflate ECP, and observe pressure drop to 1700 PSI. Hold 10 minutes. Pressure to 3000 PSI with a total of 8 strokes, indicating .8 BBLS to fill ECP. Hold pressure to 4000 PSI - 5 minutes. Bleed all ressures. 22:30 23:00 0.50 9,138 9,169 COMPZ CASIN( OTHR P Attempt to pull free of Hook Hanger observing 70K overpull. Slack off, RU & pressure to 1000 PSI. PU WT = 250K, SO WT = 72K. Bleed pressures and work drill string to release from Hook Hanger assembly. POOH and stand back 2 stands of DP. Monitor well -static. I _ ~~---°- f'~g~ 6°t cif ~a9 • • Time Lois Date From To r D u S De th E. Depth Phase Code Subcode T COM __ 11/11/2006 23:00 _ 00:00 _ __ 1.00 9,169 9,169 COMPZ RIGMN SVRG _ P _ Held PJSM with rig crew. Discuss safety issues and procedure for Slipping & cutting Drilling line. Continue monitor well -static. Rig up and slip ~ cut drilling line. Inspect & ad'ust draw works brakes. 11/12!2006 00:00 00:15 0.25 9,169 9,169 COMPZ RIGMN SVRG P Complete Slip & cut drilliong line, and ad'ustin draw works. 00:15 06:00 5.75 9,169 2,611 COMPZ CASIN( OTHR P POOH with 5" DP racking in derrick. Remove 5" Super Sliders from string. WWT rep on rig floor. 114 Total remeoved. Continue POOH rack back 5" DP. Pull from 9169' - 2611' MD. Crew Chan e 06:00 07:15 1.25 2,611 251 COMPZ CASINC OTHR P Continue POOH from 2611' - 251'. Remove remaining super sliders form DP for a total of 114 removed from drill strin .Observed ro er hole fill. 07:15 08:00 0.75 251 0 COMPZ CASIN( OTHR P Breakout & lay down Baker & Sperry Sun Inner string for Hook Hanger. Lay down Su er Slim MWD assembl . 08:00 09:00 1.00 0 0 COMPZ WELCT BOPE P Close Blind rams. Clrear & clean rig floor area. Ri u for testin BOP's. 09:00 09:30 0.50 0 0 COMPZ WELCT BOPE P Open Blind Rams -monitor well - static. Drain stack, Make up test joint & crossovers. Pull wear bushing, and install test plug. Rig up test mainfolsd and chart for BOP test. 09:30 09:45 0.25 0 0 COMPZ WELCT SFTY P Held PJSM with crew. Discuss safety issues and procedure for testing BOP's. Install signs and announce BOP test. 09:45 12:00 2.25 0 0 COMPZ WELCT SOPE P Complete rigging up for BOP test. Test BOP's. BOP test witnessed by Jeff Jones w/ AOGCC. Observed Choke side HCR valve failed test. Observed dart valves and floor safety valves failed tests of 250 PSI Low, and 3000 PSI Hi h. 12:00 14:00 2.00 0 0 COMPZ WELCT BOPE P Continue testing BOP's. Test Annular, Kill Line HCR, Manual Choke, Upper IBOP, Top rams 3 1/2" x 6" VBR's, Lower IBOP, Manual Kill. All test 250 PSI low, 3000 PSI hi h. 14:00 14:15 0.25 0 0 COMPZ WELCT SFTY P Held PJSM with floorhands. Discuss safety issues and procedure for chan in out Choke side HCR valve. 14:15 14:45 0.50 0 0 COMPZ WELCT BOPE P Blow down Top Drive & lines. Blow down Choke & Kill lines. 14:45 17:00 2.25 0 0 COMPZ RIGMN RGRP T Rig up and change out choke side HCR valve. Test gas detectors while chan in out valves. 17:00 18:00 1.00 0 0 COMPZ WELCT BOPE P Continue test BOP's. Test new HCR valve on choke side. Test to 250 PSI low, 3000 PSI hi h. Crew chan e. i eye 62 of 69 • Time Logs ______ _ __ __ Date From To Dur S D th E. De th Phase Code Subcode T COM _ 11/12/2006 18:00 _ 20:00 2.00 0 0 COMPZ WELCT BOPE P _ Held PJSM with new crew. Discuss safety issues and procedure for remaining test of BOP's. Continue test Choke manifold valves 1 - 15. Perform Accumulator draw down test. Pull test joint. Test blind rams. All tests 250 PSI low, 3000 PSI high, all tests recorded on chart. 20:00 21:00 1.00 0 0 COMPZ WELCT BOPE P Rig down test equipment. Blow down all linesincluding choke manifold and gas buster. RIH with test joint, and make up to test plug. Pull test plug. Complete hanging cement line support brace. Note: Fluid loss to weel bore Burin BOP test = 10 BBLS. 21:00 00:00 3.00 0 0 COMPZ WELCT BOPE NP Clean & clear floor area. Decision to install tubing hanger in and lock in same with BPV installed. Accumulator test indicated 2 failed valves, and AOGCC rep asked that they be repaired before completion run. Wait on tubing hanger.Pull all 4 1/2 IF pin protectors to rig floor for laying down DP. Install 5" Elevators. Rig up lines on upper annulus to fill hole and monitor well while la in down DP. 11/13/2006 00:00 00:30 0.50 0 0 COMPZ WELCT BOPE NP Continue wait on Tubing hanger for well head. Clean & clear rig floor. Prepare floor for laying down DP from derrick. Continue rig up lines to upper annulus for hole fill. 00:30 02:30 2.00 0 0 COMPZ WELCT BOPE NP Pick up dummy tubing hanger to rig floor. Install BPV, make up to landing joint. RIH set tubing hanger as per Vetco Gray reps. RILDS. Pull and lay down landin 'oint. 02:30 06:00 3.50 0 0 COMPZ RPCOh OTHR P Install mouse hole in rotary table. Lay down 5" & 4" DP from derrick. Monitor well via trip tank and lines to annulus. Observed 16 BBL fluid loss since midni ht. Crew Chan e 06:00 11:30 5.50 0 0 COMPZ RPCOh OTHR P Continue lay down 5" DP from derrick. Monitor well via trip tank and lines to annulus. 11:30 12:00 0.50 0 0 COMPZ RPC06 OTHR P Pull mouse hole from rotary table. RIH with 1 stand of 5" DP. RU for Accumulator test. i ~ _ Pie a3 rr$ 69 • Time Logs Date From To Dur Dgetlt S. E. De th Phase Code Suhcod T GOM _ 11/13/2006 12:00 13:00 1.00 _ 0 0 COMPZ RPCOR OTHR P __ Perform Accumulator draw down test. Observed initial pressures @ 2925 PSI, and after closing 1500 PSI. 200 PSI increase in 34 seconds, with full pressure observed at 2 minutes 45 seconds. Good test. Observed 5 nitrogen bottles with an average of 2300 PSI. Notify AOGCC of repaired Accumultor valves. Re-install mousehole in the rotary table for la in down DP. 13:00 15:30 2.50 0 0 COMPZ RPCOh OTHR P Continue lay down 5" DP from derrick. Layed down a total of 106 stands - 5". Continue monitor well for losses. 15:30 16:00 0.50 0 0 COMPZ RPCOA OTHR P Change out elevators from 5" to 4" DP. Pull 4" XT39 thread protectors to rig floor. 16:00 18:00 2.00 0 0 COMPZ RPCOR OTHR P Breakout & lay down Dailey combo drilling jars, and 5 joints of 4" HWDP. Continue lay down 21 stands of 4" xt39 DP from derrick. Note: Fluid loss last 12 hrs = 8.5 BBLS. Crew Chan e. 18:00 00:00 6.00 0 0 COMPZ RPCOh OTHR P Continue breakout & lay down 64 stands of 4" xt39 DP from derrick. Monitor well for losses. 11/14/2006 00:00 00:30 0.50 0 0 COMPZ RPCOh OTHR P Continue breakout & lay down 5 stands of 4" XT39 DP from derrick. Monitor well for losses. 00:30 01:00 0.50 0 0 COMPZ RPCOh OTHR P Clean & clear rig floor area. Pull joimnt of 5" DP to rig floor and breakout 10' u 'oint on bottom. La down same. 01:00 01:30 0.50 0 0 COMPZ RPCOh PULD P Change out elevators. Pull mousehole from rotary table and lay down same. Pull completion running equipment to rig floor. Move jewelry in pipe shed as to run entire 4 1/2" completion string in hole. 01:30 02:15 0.75 0 0 COMPZ WELCT OTHR P Make up landing joint. Check well for any pressure. RIH, make up to dummy hanger. BOLDS. Pull dummy hanger to rig floor. Breakout, lay down hanger and landing joint. NOTE: It was observed that the dummy hanger did not seat completly in the wellhead. When the lock down screws were run in, they did not engage correctly. The hanger was installed & removed as per Vetco Gra re s. 02:15 03:00 0.75 0 0 COMPZ RPCOR PULD P Rig up completion running equipment, power tongs, elevators and Cavin tubing slips as per DDI casing rep. Observe the throttle shaft broke on the power tongs while testing. The power tongs were changed out with no issues. 03:00 03:30 0.50 0 0 COMPZ RIGMN SVRG P Service rig. Inspect & service Top Drive & draw works. • • Time Logs - i Date___ Fmrn _ To__ - Dur S De th E. Depth_ Phase Code SuCc~de T COM __ 11/14/2006 03:30 03:45 0.25 0 0 COMPZ RPCOR SFTY P Held PJSM with rig crew &GBR Reps. Discuss safety issues and procedure for making up and running in hole with 4 1/2" Completion tubing. Monitor well -static. 03:45 06:00 2.25 0 1,519 COMPZ RPCOh PULD P Make up 4 1/2" Mule Shoe (2.98'), on first joint, and continue RIH with 4 1/2" completion string. Make up torque = 3800 FULBS. Ran 49 joints. Crew Chan e 06:00 11:00 5.00 1,519 7,905 COMPZ RPCOh PULD P Continue RIH with 4 1/2" completion string. Make up torque = 3800 FULBS. Ran a total of 255 joints.Observe ro er hole fill. 11:00 12:00 1.00 7,905 7,905 COMPZ RPCOA PULD P Remove air slips from table. Install stripping rubbers and RU to POOH standin back 4 1/2" tubin . 12:00 13:00 1.00 7,905 7,905 COMPZ RIGMN RGRP T Service Rig. Check & repair leak on Top Drive. Remove ODS link Tilt c tinder for re air. 13:00 14:00 1.00 7,905 7,800 COMPZ RPCOI\ PULD P POOH breakout & lay down joint # 253 with dams ed box. Re lace 'oint. 14:00 14:30 0.50 7,800 7,800 COMPZ RPCOh CIRC P Make up TIW valve & crossover on tubing string. Pump dry job fro POOH. Pump 15 BBLS - 10.2 PPG. Lay down crossover & valve. Blow down Top Drive & lines. 14:30 16:15 1.75 7,800 3,522 COMPZ RPCOfi PULD P POOH racking back 46 stands of 4 1/2" tubing in derrick. Install thread protectors on pin end. Observe proper hole fill 16:15 17:00 0.75 3,522 3,522 COMPZ RIGMN RGRP T Install rebuilt Link tilt cylinder on Top Drive. Monitor well -static 17:00 18:00 1.00 3,522 825 COMPZ RPCOR PULD P Continue POOH racking back 29 stands of 4 1/2" tubing. Observe ro er hole fill. Crew Chan e 18:00 18:45 0.75 825 0 COMPZ RPCOh PULD P Continue POOH racking back 10 stands of 4 1/2" tubing. Observe ro er hole fill. 18:45 19:00 0.25 0 0 COMPZ RPCOA PULD P Clean & clear rig floor area of OBM. Send out all tools not needed. 19:00 22:15 3.25 0 0 COMPZ RPCOti PULD P Held PJSM with crew, GBR reps & Centrilift rep.Pick up ESP tools. Make Motor with A-Well I-Pump & centralizer. Make up Upper & lower tandem seal sections. Check Motor rotation & fill motor with Centrlift CL-5 oil. 22:15 23:45 1.50 0 0 COMPZ RPCOA PULD P Make up Joint #1 on ESP assembly. Rig up to run ESP cable. Install Big Sheave on tugger line with cable, raise sheave to running height and pull cable through sheave. Install wind break on beaver slide door. ~~e £5 of 6~ i i Time Logs _ Date From To _ __ D ur S De th E. De th Phase Cade Subcode T _ COM _ 11/14/2006 23:45 00:00 _ 0.25 0 0 COMPZ RPCOh PULD P Install 1/4" control line on A-well I-Pump. Install ESP cable to motor. Check & record phase resistivities. R!H attaching Lasalle Protectolizers as er Centrilift re . . 11/15/2006 00:00 01:45 1.75 0 0 COMPZ RPCOh PULD P Terminate ESP cable to motor. Install protectolizers, canon clamps as per Centrilift rep. RIH with a stand of 4 1/2" tubing. POOH breakout & lay down 2 'oints. 01:45 05:30 3.75 0 0 COMPZ RPCOh PULD P Held PJSM with crew, GBR reps, Centrilift rep, and Halliburton Slicline reps. Discuss safety issues and procedure for pump installation. Rig up Slicline sheaves and line. Make up pumps to slickline connection, WLIH to set same. Release from pumps, WLOH. MAke up packoff assembly on slicline. WLIH to set and beat down to set packoff for test. WLOH. Make up crossover, valve & lines for testing inside tubing packoff. Pressure to 400 PSI as per Centrilift. Hold pressure for 5 minutes. Bleed pressure and rig down lines. Blow down same. Rig Down Halliburton slickline Unit. 05:30 06:00 0.50 0 0 COMPZ RPC06 PULD P Make up Unique Discharge valve with pups. Attach 1 /4" control line & install clamps as per Centrilift rep. Crew Chan e 06:00 12:00 6.00 0 3,300 COMPZ RPCOA PULD P Continue install 1/4" control line on dischsarge sub. Test line & connections. Continue RIH with 4 1/2" tubing from derrick. Test ESP cable. Continue RIH with tubing to 3300' MD, and test ESP cable every 1000'. Observe ro er hole fill. 12:00 18:00 6.00 3,300 6,190 COMPZ RPCOA PULD P Continue RIH with 4 1/2" completion string from 3300' - 6190'. Install clamps on every connection for ESP cable. Observe proper hole fill. Test ESP line every 1000' as per Centrilift re .Crew Chan e 18:00 18:30 0.50 6,190 6,190 COMPZ RPCOA PULD P Pull more ESP cable clamps to rig floor. Count same. Perform continuity test. 18:30 21:00 2.50 6,190 7,200 COMPZ RPCOh PULD P Continue RIH with 4 1/2" completion string from 6190' - 7200'. Install clamps on every connection for ESP cable. Observe proper hole fill. Test ESP line every 1000' as per Centrilift re . l~ae 6 cuff 69 • • Time Logs _ Date From To Dur S. De th E. De th Phase Code Su6code T COM 11/15/2006 21:00 00:00 3.00 7,200 7,200 COMPZ RPCOA OTHR P Install safety valve in Tubing string. Change out ESP cable spools in spooling unit. It was observed that there wasn't enough cable to get to bottom and spool had to be changed out. After changing out spool. Perform ESP cable splice & test as per Cenrilift re . 11/16/2006 00:00 02:30 2.50 7,200 7,200 COMPZ RPCOh OTHR P Continue change out ESP cable spools in spooling unit. It was observed that there wasn't enough cable to get to bottom and spool had to be changed out. After changing out spool. Perform ESP cable splice & test as er Cenrilift re . 02:30 03:30 1.00 7,200 8,050 COMPZ RPCOh PULD P Continue RIH with 4 1!2" tubing from derrick installing ESP cable clamps on every other connection from the GLM. Observe proper hole fill. Make u tot ue = 3800 FUlbs. 03:30 04:00 0.50 8,050 8,050 COMPZ RPCOb PULD P Install 9.85' pup joint as per detail. Make up lastjoint with Vetco Gray 11" x 4 1/2" Tubing hanger. Make up landing joint. UP WT = 155K, SO WT = 95K. 04:00 06:00 2.00 8,050 8,050 COMPZ RPCOh OTHR P Install clamp below hangerjoint, lower hanger to rotary table. Install penetrator sub into the tubing hanger as per vetco Gray and tighten gland nut. Rig up Centrilift equipment on rig floor. Lower ESP cable sheave. Measure & cut ESP cable. Perform ESP cable splice to penetrator pigtail as per Centrilift rep. Monitor well - static. Obtain Hot work permit fro slicing operation. Crew change NOTE: Total fluid loss to date in this B lateral = 1089 BBLS. Total Fluid loss in the D lateral 202 BBLS. 06:00 08:30 2.50 8,050 8,050 COMPZ RPCOh OTHR P Continue perform Splice on ESP cable to pigtail and penetrator sub. Perform megger test. Drain stack, and flush load shoulder in well head. Blow down choke & kill lines. 08:30 09:30 1.00 8,050 8,099 COMPZ RPCOA PULD P Land tubing hanger as per Vetco rep. RILDS. Verify lock down screws run in correctly. Rig up and test hanger seals to 250 PSI low, & 5000 PSI high ressure. Good test. 09:30 10:00 0.50 8,099 8,099 COMPZ RPCOh NUND P Backout & lay down landing joint. Install two way check in hanger as per vetco re . 10:00 11:00 1.00 8,099 8,099 COMPZ RPCOII NUND P Vac out & clean drip pans under rotary table, & remove turnbuckles from BOP stack. €~~~ &7 of 69 i • Time Lo s - $ _ --- -- Date From To Dur S De th E. De th Ph e Code Subcode T COM 11/16/2006 11:00 11:15 0.25 8,099 8,099 COMPZ RPCOh SFTY P _ Held PJSM with crew. Discuss safety issues and procedure for nipple down BOP stack & lines. Discuss Nipple up of tree with Vetco re s. 11:15 12:00 0.75 COMPZ RPCOfi NUND P Nipple down BOP stack & Lines. 12:00 14:30 2.50 COMPZ RPCOh NUND P Continue nipple down BOP stack & lines. Set stack back on stum . 14:30 16:30 2.00 COMPZ RPCOA NUND P Nipple up tree. Orient tree as per Vetco rep. Perform megger test on ESP cable after tree installed. Install win valves. 16:30 17:30 1.00 COMPZ RPCOh NUND P Rig up and fill tree with diesel for test. Test tree to 300 PSI low, and 5000 PSI for high test. Good. Bleed pressure. rig down test lines and um . 17:30 17:45 0.25 COMPZ RPCOh OTHR P Rig up Lubricator as per Vetco gray rep. Pull two way check from well head. No ressure. 17:45 18:00 0.25 COMPZ RPC06 FRZP P Rig up lines and Little Red services for freeze protecting well head. Rig up topump down 4 1/2" x 9 5/8" annulus, and take returns out of the tubing through the wing valve. Rig return line to the choke manifiold for holding back pressure when pumping. Test all lines to 1000 PSI with Little Red services. Crew Chan e. 18:00 18:30 0.50 COMPZ RPCOh SFTY P Held PJSM with new crew and Little Red reps. Discuss safety issues and procedure for displacing SFMOBM and freeze protecting with diesel. Double check all lines ri ed u . 18:30 23:30 5.00 COMPZ RPCOA FRZP P Displace well with freesze protect diesel taking returns through choke manifold initially. Observed only getting half the returns we were pumping at 3 BPM - 700 PSI. Rig up return lines straight to pits. Continue pumping diesel still observing only getting half of what we are pumping until observing a total of 637 BBLS pumped away and then getting diesel returns. Pump a total of 700 BBLS of diesel, with a total of 430 BBLS returned, including last 60 BBLS being clean diesel. These returns indicated a total of 270 BBLS pumped away into the wellbore. Final circulating pressure 3 BPM - 475 PSI. 23:30 23:45 0.25 COMPZ RPCOh FRZP P Bleed and blow down all lines with well shut in. Ri down Little red services. 23:45 00:00 0.25 COMPZ RPCOh OTHR P Remove tree cap, and rig up lubricator as er Vetco re s. €~~c~e s8 oaf ~~ j Time Logs __ Date From To Dur S. De th E. De th Phase Code Su6code T COM 11/17/2006 00:00 01:15 1.25 COMPZ RPCOA OTHR P Install BPV as per Vetco Gray reps. with Lubricator. SIMOPS: Cleaning its. 01:15 02:00 0.75 COMPZ RPCOh OTHR P Rig down Lubricator. Secure Tree. Close all valves. Remove secondary valve on annulus. Install Blanking flange. Shut in pressure on tree = lower annulus = 150 PSI, Upper annulus = 700 PSI, and tubing = 600 PSI. BPV in place @ 0115 HRS. Continue with Cleanin its. 02:00 06:00 4.00 COMPZ RPCOh OTHR P Continue cleaning all pits. Vac out cellar, clean & secure same. Prepare rig for move. Disconnect all mud, water, air & hydraulic lines. Skid rig floor as per TP. Rig Released @ 0600 H RS E'~z~e 69 of 6~ • • 29-Dec-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-182 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 12,978.05' MD Window /Kickoff Survey 13,045.00' MD (if applicable) Projected Survey: 17,757.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date g Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a~~ - ~3~ • C 29-Dec-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-182 L1 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,090.74' MD Window /Kickoff Survey 9,121.00' MD (if applicable) Projected Survey: 13,487.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE _ ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date tl Si ned Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~01~- 13~ Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, AL4SKA 9950f-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-182L1 ConocoPhillips Alaska, Inc. Permit No: 206-133 Surface Location: 1570' FSL, 2434' FEL, SEC. 35, T11N, RlOE, UM Bottomhole Location: 1374' FSL, 4269' FEL, SEC. 14, T l ON, R 10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you fr n obtaining additional permits or an approval required by law from other go .. rnmental 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) ~9-3607 (pager). .N DATED this day of September, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ ~,~~G' i ~"`" ALASKA OIL AND GAS CONSERVATION COMMISSI PERMIT TO DRILL SEP 1 9 2006 20 AAC 25.005 Alaska Uil & Gas Cons. Commission 1a. Type of Work: Drill ^/ Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory ^ Development Oil ^/ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^/ 1c. Specify if well is Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-182L1 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17789' TVD: 3259' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1570' FSL, 2434' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25662, 380058 West Sak Oil Pool - Top of Productive Horizon: 4638' FSL, 4246' FEL, Sec. 11, T10N, R10E, UM 8. Land Use Permit: ALK 2177, 4604 13. Approximate Spud Date: 10/9/2006 Total Depth: 1374' FSL, 4269' FEL, Sec. 14, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to ~. 31K/ ~ Nearest Property: />2•rttil'~s ~~; 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558780 ' y- 5945382 Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Ne ~e~,S,Z~y'~ well within Pool).d~184 , 16. Deviated wells: Kickoff depth: 9159 ft. Maximum Hole Angle: 95° ~ deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) ~ 2S4~i Downhole: 1521 psig ~ Surface: 1149 psig 18. Casing Program S ifi ti Setting Depth Quantity of Cement Size pec ca ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 62.5# H-40 Welded 80' 28' 28' 80' 80' 260 cf ArcticCRETE 16" 13-3/8" 68# L-80 BTC 3670' 28' 28' 3670' 2153' 710 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 9767' 28' 28' 9767' 3420' 610 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTCM 8630' 9159' 3359' 17789' 3259' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structu ra I Surface Intermediate Production Liner Perforation Depth MD (ft): ~ IO /_ /_ t ~ 4) '~~ ) Perforation Depth TVD (ft): Drilling Program / Time v. Depth Plot ^ Shallow Hazard Analysis / 20. Attachments: Filing Fee BOP Ske t c h ^ 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 David Nugent @ 265-6862 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature }~.~~~ ~~~'~~~ ~ ~~~~ j Phone ~~ ..~~Ly y Date ~/~i y~~ ~ h n II k Commission Use Only Permit to Drill Number: •Z~~j ^ ~,3 3 API Number: 50-(~~~•Z„~Z~ ~~ Permit Approval Date: ~ ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrat , or gas contained in shales: ~~v, ` - Samples req'd: Yes ^ No [+~ ud log r q'd: Yes ^ No [~ Other: ~d P~ ` T~~"~S~S eVCI,~'~I~ o H2S measures: Yes ^ No it s eq'd: Yes [~ No ^ PROVED BY THE COMMISSION DATE: ^~~~D ,COMMISSIONER Form 10-401 Revised 12/2005 Sub~t ii~uplicate ~l ~ r•. ~. ~ r~~, App~n for Permit to Drill, Well 1J-182 L1 Revision No.O Saved:18-Sep-06 Permit It -West Sak Well #1J-182L1 Application for Permit to Drill Document M{~xittiiag Well Vplue Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ............................................................................................................. 2 2. Location Summary .................................................................................. ................ .. 2 Requirements of 20 AAC 25.005(c)(2) .................................................................................. .................... 2 Requirements of 20 AAC 25.OS0(b) ............................................................................................................. 2 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 2S.OOS(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)(S) ........................................................................................................ 3 6. Casing and Cementing Program ................................................................................. 3 Requirements of 20 AAC 25.005(c)(6) ..............................•••••••••......................•••••....................................... 3 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 2S.OOS(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ................................................................................ ........... ... 4 Requirements of 20 AAC 2S.OOS(c)(8) ......................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ............................................................................... 4 9. Abnormally Pressured Formation Information ........................................................... 4 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ 4 10. Seismic Analysis .......................................................................................... ........... ... 5 Requirements of 20 AAC 25.005 (c)(10) ...................................................................................................... 5 11. Seabed Condition Analysis .......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ...................................................................................................... 5 12. Evidence of Bonding ................................................................................................... 5 1J-182 L1 PERMIT IT Page 1 of 6 ~ k Printed:18-Sep-06 ~~~`~... • App~n for Permit to Drill, Well 1J-182 L1 Revision No.0 Saved: 18-Sep-06 Requirements of 20 AAC 25.005 (c)(12) ...................................................................................................... 5 13. Proposed Drilling Program ......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ...................................................................................:.................. 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....:............................. 6 Requirements of 20 AAC 25.005 (c)(14) ...................................................................................................... 6 15. Attachments ............................................................................................................... 6 Attachment 2 Directional Plan (6 pages) .................................................................................................... 6 Attachment 3 Drilling Hazards Summary (1 page) ...................................................................................... 6 Attachment 4 Well Schematic (1 page) ....................................................................................................... 6 1. Well Name Requirements of 20 AAC 25.005 (~ Each well rnatst be iderztificzd by a unique name design^aated by the operator and a unique API number assigned by the commissiorz ztnder 20 AAC 25.040{lz). For a vvell with multiple well branches, each branch must similarly be identified by a unique name and API nzember by adding a sufffrx to tlae name designated for the well by the operator grad to the number assigrzecd to the well by the cornrriission. The well for which this Application is submitted will be designated as 1J-182 L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application fir ct Permit to Drill must be uccompunied t_ry each of the followfng items, except for an item adreudv on file with the cornrnission and ident fied in the appication: ("2) a plat identifying the property and the property s owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective, formation, and at total depth, referenced to governmental section lines, (B) the coordinates of tlae proposed location of the x~ell at the sztrfice, referenced to the state plane coordinate system for this state as mairatuined by the r~'atiorzal Geodc;tic Survey in the National Oceanic and Atmasplzeric Admirzistratinn; {C) ttae purposed depth of the well at the top t~Feach objective formation and at total depth; Location at Surface 1,570' FSL, 2434' FEL, Section 35, T11N, R10E ' ASP Zone 4 NAD 27 Coordinates RKB Elevation 121' AMSL Northings: 5,945,382 Eastings: 558,780 Pad Elevation 81' AMSL Location at Top of Productive Interval (West Sak "D" Sand 4638' FSL, 4,246' FEL, Section 11, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 9,105 Northings: 5,937,930 Eastings: 557,034 Total Vertical Depth, RKB: 3,350 Total Vertical Depth, SS: 3,229 Location at Total De th 1,374' FSL, 4,269' FEL, Section 14, T10N, R10E - ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 17,789 ' Northings: 5,929,252 Eastings: 557,086 Total Vertical De th, RKB: 3•,259 Total Vertical De th, SS: 3,138 and (DJ other information required fiy 20.4AC 25.050(b); Requirements of 20 AAC 25.050(b) Zf a well is to be irttentiortully cdevzczted, the applicaiion for• u Permit to Drill (Form 1 t)-~IOI) rnztsi {"l) include a plat, drmvn to a suitable scale, showing the path of the proposed wellbore, inclztdirag all adjacent wellborrs within 200 feet of cr2y portion ~f the proposed well; 1J-182 L1 PERMIT IT Page 2 of 6 Printed: 18-Sep-06 • Appl~aa for Permit to Drill, Well 1J-182 L1 Revision No.0 Saved: 18-Sep-06 Please see Attachment 1: Directional Plan and (2) for all veils within 200 feet of the proposed 7vellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in puhlte records, and show that each named operator has beery furnished a copy of the application by certified mar."l; or (B) state that the applicant is the onhz affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application fiat ca .Permit to Drill must be accompanied by each of the following atoms, kept for an item already an f le with the conarnission and ident~ed in the application: (3) a diagraarra and deseriptiora of the blowout prevention equaprnent (BQ£'E) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.0.37, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-182 L1. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) Ara applicatiara.far a Permai to Z)rill must be accompanied by each of tlae following items, except for an item already on file villa the commission and ident~ed ira the application: (4) inforrraatioea on drilling hazards, including (A) the maximum downhote pressure that maybe encaunter-e~~ criteria used to determine it, and rraaxirmam potential surface pressure bared on a rnatlaane gradient, The expected reservoir pressure in the West Sak sands in the 1J-182 L1 is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,149 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak D sand. formation is 3,380'. The MPSP is: MPSP = (3,380 ft)(0.45 - 0.11 psi/ft) =1,149 psi (B) data art paiential gas zaraes; The well bore is not expected to penetrate any gas zones. And (C) data concerning potential causes of hate problems szrch as abnormally gea-pressured strata, lost circulation zaraes, and zones that hence a propensity. for diffareratial stichirag; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application far a Permit to L?rill must Ire accorrzpanaed by each of the, fallowing items, except for an item alreadv on file with the cornmissian and identified in the application: (5) a descriptiara of the procedure for cvrtduclirag farrraatiart izategr itv tests, as required under 20 AAC 25.031){f); No formation integrity test will be performed in the drilling of 1J-182 L1 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application firr~ a Permit to Drill must he accorrzpanic:d by each of the following aterras, except for ara item already on file with tlae commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030,, and a description of anv slatted liner, pre-perfr~rated laver, or• screen to be Installed; 1J-182 L1 PERMIT IT Page 3 of 6 Printed: 18-Sep-06 ~~~~~ Appl~n for Permit to Drill, Well 1J-182 L1 Revision No.0 Saved: 18-Sep-O6 Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length NID/TVD MD/TVD OD (in) (in) (lb/ t Grade Connection t) t) t) Cement Pro ram 20" 40" 62 5 H-40 Welded 80 28' / 28' 80' / 80' Cemented to surface with 260 cf . ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 3,670 28' / 28' 3,670' / 2,153' 71o sx ArcticSet Lite Lead, 220 sx Dee CRETE Tail Cement Top planned @ 6,226' 9-5/8" 12-1/4" 40 L-80 BTCM 9,767 28' / 28' 9,267' / 3,420' MD / 2,601' TVD. Cemented w/ 610 sx DeepCRETE 4-1/2 6-3/4" B Sand Lateral 11.6 L-80 BTCM 023 8 420' 9 767' / 3 325' 17 790' / 3 Slotted-no cement - 2 , , , , , 4-1/2 6-3/4" D Sand Lateral 11.6 L-80 BTCM 8 630 9 159' / 3 359' 17 789' / 3 259' Slotted-no cement slotted (l.r-182L1) , , , , , 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applieatian for u Permit to Drifl rntrst he accompanied [~y each oJ7he fallowing rtenzs, except for an item ulready art file with the cammissian arad identified in the application: (7) a diagram and description of the diverter system as required lay 20 AAC 25.U35, unless thin r'er7rrtrement is waived by the cornrnissian under 20 A_4C 25.035(h)(2); No diverter system will be used during operations on 1J-182 L1 8. Drilling Fluid Program Requirements of 20 AAC 25.005(e)(8) An application far a Permit to Drill mtcst be accompanied t>y each of the follawirtg rterrts, exee_pt for• an item adreatty on file with the commission and identified it^a the application: (8) a dritlinglluid program, including a diagram and description of the drilliragfluids}stern, as rr~quired by 2(3.RAC 2 x.1135; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) Value Density (p) 9.0 Plastic Viscostiy (lb/100 s 15-25 Yield Point 18-28 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200psi & 1 SO° Oil /Water Ratio 80:20 Electrical >600 Stability 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 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) Ar^t application, for a Permit to Drill must be accompanied by each of the fottox~ing items, except fur- an item alrearl}° oti ale svitla the commission and identified to the apph~catian: 1J-182 L1 PERMIT IT Page 4 of 6 Printed: 18-Sep-O6 t ~~!°_~~ • App~n for Permit to Drill, Well 1 J-182 L1 Revision No.0 Saved: 18-Sep-06 {'9).for an exploratory or stratigraphic test well, a tabulation settirag out the depths of predicted abnormally geo pressured strata as required fiy Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) .4n appficati<rn for ca Perrndt fa Drill must be accompanied by each of the fr~ilowing items, except fcrr an item already on f le wills the cvrnrnissii?n and identified in the application• (10) for an exploratory or stt atigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC' 25.Ofz1(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(I1) _An application for a Permit to Drill must be accompanied by each rf the following items, except for an item already on f le with the comnzissian and identified in the application: (11) for a welt drilled from ara offshore platform, mobile hoftorrt founded structure, jack=up rig, or floating drilling vessel, ar^t analysis` of seabed coraditians as required by 20.2.40 2 5,067('6); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) .2n application for ca Per-rnit to Drill must be accompanied by each of the following items, except_~rr an item already on file ;vith the corrarnisrion and identified in the rxlrplica>?ort: (12) evidence showing that the requirements of 20 A•4C 25.025 {Ponding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) _An application for a Permit to Drill must be accompanied by each of the, following items, exxcept for art item already on fzle with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-182 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 9,159' MD / 3,359' TVD, at the top of the "D" sand. 2. Mi116-3/4" window. POOH. 3. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "D" sand lateral at 17,789' MD / 3,259' TVD, as per directional plan. _ 5. POOH, back reaming out of lateral. POOH. 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. 10. POOH, laying down drill pipe as required. 11. PU injection completion as required and RIH to depth. Land tubing. Set BPV. 12. Nipple down BOPE, nipple up tree and test. Pull BPV. 13. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 14. Set BPV and move rig off. 1J-182 L1 PERMIT IT Page 5 of 6 Printed: 18-Sep-06 ~` App~n for Permit to Drill, Well 1J-182 L1 Revision No.0 Saved: 19-Sep-06 15. Rig up wire line unit. Pull BPV. 16. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 17. Rig up wireline. Replace gas lift valves with blank dummy valves. 18. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular. Disposal Requirements of 20 AAC 25.005 (c)(14) Art applications, fnr a Permit to Drill ntuste be accompanied by each of the following items, except for an item already on~le with the cotnrnission ancd idenfifzed in the application: (14) a general description of ltow the operator plans to dispose of drilling rnud anti. cuttitags and a stcaternent of whether ilte operator intet2dr to request authorization under 20 rLAC 2.1.080 for ara annular disposal operation in t{te well.; 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 Well Schematic 1J-182 L1 PERMIT lT Page 6 of 6 ("~ Printed: 19-Sep-06 • Conoc~l~hillips Alaska • Plan: 1J-182 L1 (wp12) r ill i e Proposal Report -Geographic 13 September, 2006 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-182 -Slot 1J-182 1J-182 L1 Local Coordinate Origin: Centered on Well Plan 1J-182 -Slot 1J-182 Viewing Datum: Plan RKB (copy) @ 121.OOft (Doyon 15 {40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet ._ Sperry Grilling Services ~~r~ Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-182 Wellbore: 1J-182 L1 Pian: 1J-182 L1 {wp12} CASING DETAILS No TVD MD Name Size 1 2153.00 3670.22 13 3/8" 13-3/8 2 3258.70 17788.94 41/2" 4-1/2 3 3359.30 9158.91 9 5/8" TOW 9-5/8 FORMATION TOP DETAILS NoTVDPath TVDSS MDPath Formation 1 1550.00 1429 1702.82 Base Perm 2 1646.00 1525 1850.54 T3 3 1953.00 1832 2771.29 K15 4 2153.00 2032 3670.22 T3+550 5 2827.00 2706 6699.60 Ugnu C 6 3403.00 2882 7490.66 Ugnu B 7 3065.00 2944 7769.33 Ugnu A 8 3216.00 3095 8448.02 K13 9 3350.00 3229 9105.36 WSAK D -,~ ....~,~ a.--.° ~s ~~ ~.R: ~.~...a, ~~"°'~ 3 L1 : TOW @ 9159' MD, 3359' TVD - 4638ft FSL & 4246ft FEL -Sec 11 - T10N - R10E 2500 L1 ;Bottom of Window -Drill 30' Rathole, 9174' MD, 3362' TVD L1 : BHL @ 17789' MD, 3259' TVD :1374ft FSL & 4269ft FEL -Sec 14 - T10N - R10E .' -^ , ' " ~ / L1 _Continue Geosteemg in D-Sand _ Note Undulation Critical Targets: 9406' MD, 3380' TVD _ _ _ \ \ ~ ~ , _ \ _ 1J-182 L1 (wp12~ - ,,' __--- ~, I ' -- 3000 _ & _ _ ~ _. _ _.. ._ -- --- -~- --- 4 ,~~ _---- I. L 500 ~ ~ i ~ m i n ~ ` °o I ~ 9 5/8" TGW ~\ o i ~ ` I U_ ` *~000 ` 1J-182 L1 T2 (Exit Upper) (wp12 > ~ ~ ~ 2 ` 1J-182 L1 T9 (D-Land'eng}(wp11 r ~ 4500 ' L1 : Build @ 4°/100ft to 92.62°Inc : 9204' MD, 3366' TVD I ~ II 1J-182(wp11) I~~ I ~o I m a I m o I I '~ ~ N W O I O O I O I I O I ..~ O I G I O I O I I O ~ O I I I I I I I I I II I I I I 1J-182 L1 T3 (Exit Lower} (wp12 I 1J-182 L1 T5 (Exit Lower} (wp12 I 1J-182 L7 T7 (wp12 I I 1J-182 L1 T4 (Exit Upper) (wp12 1J-182 Li Tfi (Stay in Upper} (wp12 1J-182 L1 T6 (Toe} (w 7000 7500 8000. 8500 9000 9500 10000 10500 .~ ~C~t14Cfl~~lI~~1~tS Adaslta 11000 11500 12000 12500 13000 13500 14000 14500 15000 15500 16000 l'~~~r1a;~al Sa:rstirr=i as€, i8C3.~fi' 1t1(1G Ellin} L.L.f~"S'91~1 Ctr~utr+gand. ~arrnatlan Evetu~tlao:re Project: Kuparuk River Un Site: Kuparuk 1J Pad -aooo Well: Plan 1J-182 Wellbore: 1J-182 L1 Plan: 1J-182 L1 (wp12) -sooo -sooo -7000 9 5/8" TOW -aooo ~-182 L1 T1 (D-Landing) (w11)1- - - 1J-182 L1 T2 {Exit Upper) (wp12) --- 10000 ~ 0 0 v_ 1 J-182 L1 T {Exit Lower) (wp12) - - - 11000 + s 1= 0 Z r lzooo ~ _ 1~J-182 L1 T (Exit Upper) (wp12) - - - 13000 i 1J-182 L1 T {Exit Lower) (wp12) - - -1 CASING DETAILS No TVD MD Name Size 193° 1 2153.00 3670.22 13 3/8" 13-3/8 2 3259.67 17704.46 4 1 /2" 4-1 /2 3 3359.30 9158.91 9 5/8" TOW 9-5/8 30p0 L1 : TOW @ 9159' MD, 3359' TVD - 4638ft FSL & 4246ft FEL -Sec 11 - T10N - R1 E 190° _---"- _ _ _ _ - _ _ ~ L1 : Bottom of window -Drill 30' Rathole, 9174' MD, 3362' TV 80~ - _ _ _ L7 : Build @ 4°/100ft to 92.62°Inc :9204' MD, 3366' TV L7 : Continue Geosteemg in DSand -Note Undulation Critical Targets: 9406' MD, 3380' D 180° 180° 180° 180° T M Azi=rE:h:, .c True Rorh Magnetic North: 23.98° Magnetic Field Strength:57564.4nT Dip Angle: 80.78° Date: 9/1/2006 Model: BGGM2005 CtL3 Pnlygan 1.7esctitses a t:arridar 11}0' wide with a 50'~°f-allowance ElW fram the roared vuelibare. 1 J-tad L N i a (1 oe j tw~3 t L' 1 rte- L1 : BHL @ 17789' MD, 3259' TVD :1374ft FSL & 4269ft FEL -Sec 14 - T10N - R1 E i . , 1J-182 L1 (wp12) ~tuxvl~llps Al8sl4't 8000 -6000 -5000 -4000 -3000 -2000 -1000 0 1000 2000 West(-)/East(+l (1500 ft/inl m ~ ~=~,a t7rltttrfg arxd Fnrnrsnttcn I»v~lu~i€i3ri 3000 4000 ~a ~t~ ~ ? _ -'~ • • C Halliburton Energy Services w~lytl~° n ,~5 Planning Report -Geographic drilling anct Formation Alaska svaiuation Database: _EDM_2003.11__b48 Local Co-ordinate Reference: Well Plan 1J-182 -Slot 1J-182 Company: ConocoPhiltips Alaska, Inc. ND Reference: Plan RKB (copy) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Plan RKB (copy) @ 121.OOft (Doyon 15 (40+81)) Site' Kuparuk 1J Pad North Reference: True Well: Plan 1J-182 Survey Calculation Method: Minimum Curvature Wellhore: 1J-182 L1 Design: 1J-182 L1 (wp12) f Project Ku~ar k R ver !!~ r nl„rtf, einnA A!aska I i„~rAd States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 'LI-1>`~ - 51ot 1J-182 Well Position +N/-S 0.00 ft Northing: 5,945,381.64 ft Latitude: 70° 15' 40.967" N +E/-W 0.00 ft Easting: 558,779.69 ft Longitude: 149° 31' 29.427" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground LeveL• 81.00 ft Wellhore 1J-182 L1 Magnetics Model Name Sample Date Dect)nation Dip Angle Field Strength BGGM2005 9/1/2006 23.98 80.78 57,564 Design 1J-181 L1 Iwp121 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,158.91 Vertical Section: Depth From (TVD) +NI-S +EI-W Direction (ft) (ft) (ft) ~°) 40.00 0.00 0.00 180.00 ~ 9/13/2006 3:37:06PM Page 2 of 8 COMPASS 2003.11 Build 50 t „,. 3 ~ ~W P ~ ~ a~ u • • COt'I P~'l ~l Halliburton Energy Services OCO l l 5 Planning Report -Geographic Alaska ~ Database: EDM_2003.11_b48 Local Co-ordinate Reference: Company: ~onocoPhillips Alaska, Inc. TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: ', Well: Plan 1J-182 Survey Calculation Method: Wellbore: 1J-182 L1 Design: 1J-182 L1 (wp12) Plan Summary ~ Measured Vertical Depth Inclination Azimuth Depth +N;-S +E/-W (ft) (°~ ('~~ (ft} (ft) (ft) 9,158.91 80.00 180.20 3,359.30 -7,491.50 -1,804.39 9,173.91 82.04 180.20 3,361.64 -7,506.32 -1,804.44 9,203.91 82.04 180.20 3,365.80 -7,536.03 -1,804.55 9,406.18 90.13 180.09 3,379.59 -7,737.66 -1,805.06 9,511.06 95.36 179.63 3,374.57 -7,842.38 -1,804.81 9,537.95 95.36 179.63 3,372.06 -7,869.16 -1,804.64 9,625.41 91.02 180.20 3,367.20 -7,956.46 -1,804.51 10,945.41 91.02 180.20 3,343.70 -9,276.24 -1,809.12 11,008.69 87.86 180.05 3,344.32 -9,339.51 -1,809.26 11,134.86 87.86 180.05 3,349.03 -9,465.59 -1,809.38 11,195.37 90.88 180.22 3,349.70 -9,526.09 -1,809.52 12,445.37 90.88 180.22 3,330.50 -10,775.94 -1,814.41 12,535.73 95.39 180.47 3,325.56 -10,866.13 -1,814.96 12,597.55 95.39 180.47 3,319.75 -10,927.67 -1,815.47 12,696.12 90.47 180.19 3,314.71 -11,026.09 -1,816.04 13,946.12 90.47 180.19 3,304.46 -12,276.04 -1,820.27 13,998.94 87.83 180.28 3,305.24 -12,328.85 -1,820.49 14,148.07 87.83 180.28 3,310.89 -12,477.87 -1,821.23 14,196.48 90.25 180.18 3,311.70 -12,526.27 -1,821.43 15,446.48 90.25 180.18 3,306.27 -13,776.25 -1,825.35 15,560.94 94.52 184.00 3,301.51 -13,890.49 -1,829.51 15,576.40 94.52 184.00 3,300.29 -13,905.87 -1,830.59 15,699.04 90.25 179.59 3,295.19 -14,028.28 -1,834.41 16,499.04 90.25 179.59 3,291.70 -14,828.25 -1,828.66 16,946.26 92.48 179.59 3,281.05 -15,275.31 -1,825.44 17,788.95 90.56 179.64 3,258.70 -16,117.64 -1,819.74 Drilling and Formation Eveluativn Well Plan 1J-182- Slot 1J-182 Plan RKB (copy) @ 121.UOft (Doyon 15 (40+81)) Plan RKB (copy) @ 121.OOft (Doyon 15 (40+81)) True Minimum Curvature Dogleg Build Tura Rate Rate Rate TFO (`i100ft) ('/100ft) (~1100ft) (~~ 0.00 0.00 0.00 0.00 13.60 13.60 0.00 0.00 0.00 0.00 0.00 0.00 4.00 4.00 -0.05 -0.76 5.00 4.98 -0.44 -5.02 0.00 0.00 0.00 0.00 5.00 -4.96 0.65 172.53 0.00 0.00 0.00 0.00 5.00 -4.99 -0.23 -177.35 0.00 0.00 , 0.00 0.00 5.00 4.99 0.28 3.23 0.00 0:00 0.00 0.00 5.00 4.99 0.28 3.17 0.00 ' 0.00 0.00 0.00 5.00 -4.99. -0.28 -176.73 0.00 0.00 0.00 0.00 5.00 -5.00 0.17 178.06 0.00 0.00 0.00 0.00 5.00 5.00. -0.21 -2.45 0.00 0.00 0.00 0.00 5.00 3.73 3.33 41.71 0.00 0.00 0.00 0.00 5.00 -3.48 -3.59 -133.98 0.00 0.00 0.00 0.00 0.50 0.50 0.00 0.00 0.23 -0.23 0.01 178.57 9/13/2006 3:3Z:O6PM Page 3 of 8 COMPASS 2003.11 Build 50 d~~~ ~~~ s i B E 5 k~ ~7~.: ~ ,~"w,m • • eoPillips Alaska Halliburton Energy Services Planning Report -Geographic t_N°r Drilling and Farmatian Evaluation Database: EDM_2003.11_b48 Carnpany: ConocoPhillips Alaska, Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-182 Wellbore: 1J-182 L1 Design: 1J-182 L1 (wp12) Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Planned Survey 1J-1~T~%L1 ; Well Plan 1J-182 -Slot 1J-182 P an RKB (copy) @ 121.OOft (Doyon 15 (40+81)) P'an RKB (copy) @ 121.OOft (Doyon 15 (40+81)) True Minimum Curvature Map Map MD Inclination Azimuth TVD SSTV^ +NI-S +E/-W Norfhir~g Easting DLSEV Vert Section (ft) O (') (ft) (ft) (fq (ft) (ftl Ift) (`i100fry Ift) 1,702.82 47.14 205.00 1,550.00 1,429.00 -475.97 -221.95 5,944,904.00 558,561.48 0.00. 475.97 Base Perm 1,850.54 52.76 202.03 1,646.00 1,525.00 -578.65 -267.07 5,944,800.98 558,517.17 4.10 578.65 T3 2,771.29 77.14 192.81 1,953.00 1,832.00 -1,406.70 -489.61 5,943,971.30 558,301.13. 2.80 1,406.70 K15 3,670.22 77.14 192.81 2,153.00 2,032.00 -2,261.28 -683.93 5,943,115.31 558,113.50 0.00 2,261.28 T3+550 -13 3/8" 6,699.60 77.14 192.81 2,827.00 2,706.00 -5,141.22 -1,338.81 5,940,230.63 557,481.18 0.00 5,141.22 Ugnu C 7,490.66 77.14 192.81 3,003.00 2,882.00 -5,893.25 -1,509.81 5,939,477.36 557,316.07 0.00 5,893.25 Ugnu B 7,769.33 77.14 192.81 3,065.00 2,944.00 -6,158.17 -1,570.05 5,939,212.00 557,257.90 0.00 6,158.17 Ugnu A 8,448.02 77.14 192.81 3,216.00 3,095.00 -6,803.38 -1,716.77 5,938,565.73 557,116.24 0.00 6,803.38 K73 9,105.36 80.00 180.20 3,350.00 3,229.00 -7,438.77 -1,804.21 5,937,929.74 557,033.77 1.93 7,438.77 WSAK D 9,158.91 80.00 180.20 3,359.30 3,238.30 -7,491.50 -1,804.39 5,937,877.00 557,034.00 0.00 7,491.50 L1 : TOW @ 9159' MD, 3359' ND - 4638ft FSL & 4246ft FEL -Sec 1 1 - T10N - R1 O E - 9 5/8" TOW - 9,173.91 82.04 180.20 3,361.64 3,240.64 -7,506.32 -1,804.44 5,937,862.19 557,034.06 13.60 7,506.32 L1 : Bottom of Window -Drill 30' Rath ole, 9174' MD, 3362' ND 9,200.00 82.04 180.20 3,365.25 3,244.25 -7,532.16 -1,804.53 5,937,836.35 557,034.18 0.00 7,532.16 9,203.91 82.04 180.20 3,365.80 3,244.80 -7,536.03 -1,804.55 5,937,832.48 557,034.19 0.00 7,536.03 L1 : Build @ 4°f100ft to 92.62°Inc :9204' MD, 3366' ND 9,300.00 85.88 180.15 3,375.90 3,254.90 -7,631.57 -1,804.84 5,937,736.95 557,034.65 4.00 7,631.57 9,400.00 89.89 180.10 3,379.59 3,258.59 -7,731.48 -1,805.05 5,937,637.05 557,035.21 4.00 7,731.48 9,406.18 90.13 180.09 3,379.59 3,258.59 -7,737.66 -1,805.06 5,937,630.87 557,035.25 4.00 7,737.66 L1 : Continue Geosteerng in D-Sand -Note Undulation Critical Targets: 9406' MD, 3380' ND -1J-182 L1 T1 (D-Landing) (wp11) 9,500.00 94.80 179.68 3,375.55 3,254.55 -7,831.37 -1,804.88 5,937,537.18 557,036.17 5.00 7,831.37 9,511.06 95.36 179.63 3,374.57 3,253.57 -7,842.38 -1,804.81 5,937,526.17 557,036.32 5.02 7,842.38 9,537.95 95.36 179.63 3,372.06 3,251.06 -7,869.16 -1,804.64 5,937,499.40 557,036.70 0.00 7,869.16 9,600.00 92.28 180.04 3,367.93 3,246.93 -7,931.06 -1,804.46 5,937,437.50 557,037.36 5.00 7,931.06 9,625.41 91.02 180.20 3,367.20 3,246.20 -7,956.46 -1,804.51 5,937,412.11 557,037.51 5.01 7,956.46 9,700.00 91.02 180.20 3,365.87 3,244.87 -8,031.04 -1,804.77 5,937,337.54 557,037.83 0.00 8,031.04 9,800.00 91.02 180.20 3,364.09 3,243.09 -8,131.02 -1,805.12 5,937,237.56 557,038.26 0.00 .8,131.02 9,900.00 91.02 180.20 3,362.31 3,241.31 -8,231.00 -1,805.47 .5,937,137.59 557,038.69 0.00 8,231.00 10,000.00 91.02 180.20 3,360.53 3,239.53 -8,330.99 -1,805.82 5,937,037.62 557,039.13 0.00 8,330.99 10,100.00 91.02 180.20 3,358.75 3,237.75 -8,430.97 -1,806.17 5,936,937.64 557,039.56 0.00 8,430.97 10,200.00 91.02 180.20 3,356.97 3,235.97 -8,530.95 -1,806.52 5,936,837.67 557,039.99 0.00 8,530.95 10,300.00 91.02 180.20 3,355.19 3,234.19 -8,630.94 -1,806.86 5,936,737.69 557,040.42 0.00 8,630.94 9/13/2006 3:37:06PM Page 4 of 8 COMPASS 2003.11 Build 50 ~~ ~ ~ 4 ~~ • • coPhllli Alaska Database: Company: Project: Site: Well: Wcllbore: Design: Planned Survey Halliburton Energy Services Planning Report -Geographic _EDM_ 2003.11_b48 Local Co-ordinate Reference ConocoPhillips Alaska, Inc. TVD Reference: Kuparuk River Unit MD Reference: Kuparuk 1J Pad North Reference: Plan 1J-182 Survey Calculation Method: 1J-182 L1 1J-182 L1 (wp12) `diell Plan 1J-182 -Slot 1J-182 Plan RKB (copy) @ 121.OOft (Doyon 15 (40+81)) Plan RKB (copy) @ 121.OOft (Doyon 15 (40+81 )) True F.'inimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E!-W Northing Easting DLSEV Vert Section (fq O (°) (ft) (ft) (ft) (ft) (ft) (~) ('!100ft) (ft) 10,400.00 91.02 180.20 3,353.41 3,232.41 -8,730.92 -1,807.21 5,936,637.72 557,040.85 0.00 8,730.92 10,500.00 91.02 180.20 3,351.63 3,230.63 -8,830.91 -1,807.56 5,936,537.75 557,041.28 0.00 8,830.91 10,600.00 91.02 180.20 3,349.85 3,228.85 -8,930.89 -1,807.91 5,936,437.77 557,041.71. 0.00 8,930.89 10,700.00 91.02 180.20 3,348.07 3,227.07 -9,030.87 -1,808.26 5,936,337.80 557,042.15 0.00 9,030.87 10,800.00 91.02 180.20 3,346.29 3,225.29 -9,130.86 -1,808.61 5,936,237.83 557,042.58 0.00 9,130.86 10,900.00 91.02 180.20 3,344.51 3,223.51 -9,230.84 -1,808.96 5,936,137.85 557,043.01 0.00 9,230.84 10,945.41 91.02 180.20 3,343.70 3,222.70 -9,276.24 -1,809.12 5,936,092.46 557,043.20 0.00 9,276.24 1J-182 L1 T2 (Exit Upper) (wp12) 11,000.00 88.29 180.07 3,344.03 3,223.03 -9,330.83 -1,809.25 5,936,037.88 557,043.50 5.00 9,330.83 11,008.69 87.86 180.05 3,344.32 3,223.32 -9,339.51 -1,809.26 5,936,029.19 557,043.56 5.00 9,339.51 11,100.00 87.86 180.05 3,347.73 3,226.73 -9,430.76 -1,809.34 5,935,937.96 557,044.18 0.00 9,430.76 11,134.86 87.86 180.05 3,349.03 3,228.03 -9,465.59 -1,809.38 5,935,903.13 557,044.42 0.00 9,465.59 11,195.37 90.88 180.22 3,349.70 3,228.70 -9,526.09 -1,809.52 5,935,842.63 557,044.75 5.00 9,526.09 11,200.00 90.88 180.22 3,349.63 3,228.63 -9,530.72 -1,809.54 5,935,838.00 557,044.77 0.00 9,530.72 11,300.00 90.88 180.22 3,348.09 3,227.09 -9,630.71 -1,809.93 5,935,738.03 557,045.16 0.00 9,630.71 11,400.00 90.88 180.22 3,346.56 3,225.56 -9,730.70 -1,810.32 5,935,638.05 557,045.55 0.00 9,730.70 11,500.00 90.88 180.22 3,345.02 3,224.02 -9,830.68 -1,810.71 5,935,538.07 557,045.94 0.00 9,830.68 11,600.00 90.88 180.22 3,343.48 3,222.48 -9,930.67 -1,811.10 5,935,438.09 557,046.33 0.00 9,930.67 11,700.00 90.88 180.22 3,341.95 3,220.95 -10,030.66 -1,811.50 5,935,338.12 557,046.71 0.00 10,030.66 11,800.00 90.88 180.22 3,340.41 3,219.41 -10,130.65 -1,811.89 5,935,238.14 557,047.10 0.00 10,130.65 11,900.00 90.88 180.22 3,338.88 3,217.88 -10,230.63 -1,812.28 5,935,138.16 557,047.49 0.00 10,230.63 12,000.00 90.88 180.22 3,337.34 3,216.34 -10,330.62 -1,812.67 5,935,038.18 557,047.88 0.00 10,330.62 12,100.00 90.88 180.22 3,335.80 3,214.80 -10,430.61 -1,813.06 5,934,938.20 557,048.27 0.00 10,430.61 12,200.00 90.88 180.22 3,334.27 3,213.27 -10,530.60 -1,813.45 5,934,838.23 557,048.66 0.00 10,530.60 12,300.00 90.88 180.22 3,332.73 3,211.73 -10,630.58 -1,813.84 5,934,738.25 .557,049.05 0.00 10,630.58 12,400.00 90.88 180.22 3,331.20 3,210.20 -10,730.57 -1,814.23 5,934,638.27 .557,049.44 0.00 10,730.57 12,445.37 90.88 180.22 3,330.50 3,209.50 -10,775.94 -1,814.41 5,934,592.91 557,049.62 0.00 10,775.94 1J-182 L7 T3 (Exit Lower) (wp12) 12,500.00 93.60 180.38 3,328.36 3,207.36 -10,830.52 -1,814.69 5,934,538.33 557,049.76 5.00 10,830.52 12,535.73 95.39 180.47 3,325.56 3,204.56 -10,866.13 -1,814.96 5,934,502.72 557,049.77 5.01 10,866.13 12,597.55 95.39 180.47 3,319.75 3,198.75 -10,927.67 -1,815.47 5,934,441,18 557,049.74 0.00 10,927.67 12,600.00 95.27 180.47 3,319.52 3,198.52 -10,930.12 -1,815.49 5,934,438.74 557,049.74 4.90 10,930.12 12,696.12 90.47 180.19 3,314.71 3,193.71 -11,026.09 -1,816.04 5,934,342.78 557,049.94 5.00 11,026.09 12,700.00 90.47 180.19 3,314.68 3,193.68 -11,029.97 -1,816.05 5,934,338.90 557,049.96 0.00 11,029.97 12,800.00 90.47 180.19 3,313.86 3,192.86 -11,129.96 -1,816.39 5,934,238.91 557,050.40 0.00 11,129.96 12,900.00 90.47 180.19 3,313.04 3,192.04 -11,229.96 -1,816.73 5,934,138.92 557,050.84 0.00 11,229.96 13,000.00 90.47 180.19 3,312.22 3,191,22 -11-,329.96 -1,817.07 5,934,038.94 557,051.28 0.00. 11,329.96 13,100.00 90.47 180.19 3,311.40 3,190.40 -11,429.95 -1,817.41 5,933,938.95 557,051.72 0.00 11,429.95 13,200.00 90.47 180.19 3,310.58 3,189.58 -11,529.95 -1,817.75 5,933,838.97 557,052.17 0.00 11,529.95 13,300.00 90.47 180.19 3,309.76 3,188.76 -11,629.94 -1,818.09 5,933,738.98 557,052.61 0.00 11,629.94 13,400.00 90.47 180.19 3,308.94 3,187.94 -11,729.94 -1,818.42 5,933,638.99 557,053.05- 0.00 11,729.94 13,500.00 90.47 180.19 3,308.12 3,187.12 -11,829.94 -1,818.76 5,933,539.01 557,053.49 0.00 11,829.94 13,600.00 90.47 180.19 3,307.30 3,186.30 -11,929.93 -1,819.10 5,933,439.02 557,053.93 0.00 11,929.93 13,700.00 90.47 180.19 3,306.48 3,185.48 -12,029.93 -1,819.44 5,933,339.04 557,054.38 0.00 12,029.93 13,800.00 90.47 180.19 3,305.66 3,184.66 -12,129.92 -1,819.78 5,933,239.05 557,054.82 0.00 12,129.92 13,900.00 90.47 180.19 3,304.84 3,183.84 -12,229.92 -1,820.12 5,933,139.06 557,055.26 0.00 12,229.92 t¢°r°sa drill€ng and Formation Evelust€on 9/13/2006 3:37:06PM Page 5 of 8 COMPASS 2003.11 Build 50 y~q ~ ~ FFF { ~.: P mwu C P~'tl~llp5 Alaska • Halliburton Energy Services Planning Report -Geographic ~~ Grilling and Formatian Bvaiuatmn Database' _EDM_2003.11 b48 Local Go-ordin ate Reference: Well Plan 1J-182 -Slot 1J-182 Company: ConocoPhillips Alas ka, Inc. TVD Reference : Plan RKB (co py) @ 121.OOft ( Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Plan RKB (co py) @ 121.OOft ( Doyon 15 (40+g1)) Site: Kuparuk 1J Pad North Referenc e: True Well: Plan 1J-182 Survey Calcula tion Method: Minimum Cu rvature Wellbore: iJ-182 L1 Design: 1J-182 L1 (wp12) Planned Survey i i-18" L i `: ~~12) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Fasting DLSEV Vert Section (ft) O (~) (ft) (ft) (ft) (ft) (ft) lft) (~/100ft) (ft) 13,946.12 90.47 180.19 3,304.46 3,183.46 -12,276.04 -1,820.27 5,933,092.95 557,055.46 0.00 12,276.04 1J-182 L7 T4 (Exit Upper) (wp12) 13,998.94 87.83 180.28 3,305.24 3,184.24 -12,328.85 -1,820.49 5,933,040.15 557,055.66 5.00. 12,328.85 14,000.00 87.83 180.28 3,305.28 3,184.28 -12,329.91 -1,820.50 5,933,039.09 557,055:66 0.00 12,329.91 14,100.00 87.83 180.28 3,309.07 3,188.07 -12,429.83 -1,820.99 5,932,939.17 557,055.94 0.00 12,429.83 14,148.07 87.83 180.28 3,310.89 3,189.89 -12,477.87 -1,821.23 5,932,891.14 557,056.08 0:00 12,477.87 14,196.48 90.25 180.18 3,311.70 3,190.70 -12,526.27 -1,821.43 5,932,842.74 .557,056.26 5.00 12,526.27 14,200.00 90.25 180.18 3,311.68 3,190.68 -12,529.79 -1,821.44 5,932,839.22 557,056.28 0.00 12,529.79 14,300.00 90.25 180.18 3,311.25 3,190.25 -12,629.79 -1,821.75 5,932,739.24 557,056.75 0.00 12,629.79 14,400.00 90.25 180.18 3,310.82 3,189.82 -12,729.79 -1,822.07 5,932,639.25 557,057.21 0.00 12,729.79 14,500.00 90.25 180.18 3,310.38 3,189.38 -12,829.78 -1,822.38 5,932,539.26 557,057.68 0.00 12,829.78 14,600.00 90.25 180.18 3,309.95 3,188.95 -12,929.78 -1,822.69 5,932,439.27 557,058.15 0.00 12,929.78 14,700.00 90.25 180.18 3,309.51 3,188.51 -13,029.78 -1,823.01 5,932,339.28 557,058.61 0.00 13,029.78 14,800.00 90.25 180.18 3,309.08 3,188.08 -13,129.78 -1,823.32 5,932,239.29 557,059,08 0.00 13,129.78 14,900.00 90.25 180.18 3,308.64 3,187.64 -13,229.78 -1,823.64 5,932,139.31 557,059,54 0.00 13,229.78 15,000.00 90.25 180.18 3,308.21 3,187.21 -13,329.78 -1,823.95 5,932,039.32 557,060.01 0.00 13,329.78 15,100.00 90.25 180.18 3,307.78 3,186.78 -13,429.78 -1,824.26 5,931,939.33 557,060.48 0.00 13,429.78 15,200.00 90.25 180.18 3,307.34 3,186.34 -13,529.77 -1,824.58 5,931,839.34 557,060.94 0.00 13,529.77 15,300.00 90.25 180.18 3,306.91 3,185.91 -13,629.77 -1,824.89 5,931,739.35 557,061.41 0.00 13,629.77 15,400.00 90.25 180.18 3,306.47 3,185.47 . -13,729.77 -1,825.21 5,931,639.36 557,061.88 0.00 13,729.77 15,446.48 90.25 180.18 3,306.27 .3,185.27 -13,776.25 -1,825.35 5,931,592.88 557,062.09 0.00 13,776.25 1J-182 L1 TS (Exit Lower) (wp12) 15,500.00 92.24 181.96 3,305.10 3,184.10 -13,829.74 -1,826.35 5,931,539.40 557,061.51 4.99 13,829.74 15,560.94 94.52 184.00 3,301.51 3,180.51 -13,890.49 -1,829.51 5,931,478.63 557,058.83 5.01 13,890.49 .15,576.40 94.52 184.00 3,300.29 3,179.29 -13,905.87 -1,830.59 5,931,463.25 557,057.87 0.00. 13,905.87 15,600.00 93.70 183.15 3,298.60 3,177.60 -13,929.36 -1,832.05 5,931,439.75 557,056.59 4.99 13,929.36 15,699.04 90.25 179.59 3,295.19 3,174.19 -14,028.28 -1,834.41 5,931,340.83 557,055.01 5.00 14,028.28 15,700.00 90.25 179.59 3,295.19 3,174.19 -14,029.24 -1,834.40 5,931,339.86 557,055.02 0.00 14,029.24 15,800.00 90.25 179.59 3,294.75 3,173.75 -14,129.23 -1,833.68 5,931,239.88 557,056.52 0.00 14,129.23 15,900.00 90.25 179.59 3,294.31 3,173.31 -14,229.23 -1,832.96 5,931,139.91 557,058.02 0.00 14,229.23 16,000.00 90.25 179.59 3,293.88 3,172.88 -14,329.23 -1,832.25 5,931,039.93 557,059.52 0.00 14,329.23 16,100.00 90.25 179.59 3,293.44 3,172.44 -14,429.22 -1,831.53 5,930,939.95 557,061.02 0.00 14,429.22 16,200.00 90.25 179.59 3,293.00 3,172.00 -14,529.22 -1,830.81 5,930,839.97 557,062.52 0.00 14,529.22 16,300.00 90.25 179.59 3,292.57 3,171.57 -14,629.22 -1,830.09 5,930,739.99 557,064.02 0.00 14,629.22 16,400.00 90.25 179.59 3,292.13 3,171.13 -14,729.21 -1,829.37 5,930,640.02 557,065.52 0.00 14,729.21 16,499.04 90.25 179.59 3,291.70 3,170.70 -14,828.25 -1,828.66. 5,930,541.00 557,067.00 0.00 14,828.25 1J-182 L1 T6 (Stay in Upper) (wp12) 16,500.00 90.25 179.59 3,291.70 3,170.70 -14,829.21 -1,828.65 5,930,540.04 557,067.01 0.50. 14,829.21 16,600.00 90.75 179.59 3,290.82 3,169.82 -14,929.20 -1,827.93 5,930,440.06 557,068.51 0.50 14,929.20 16,700.00 91.25 179.59 3,289.07 3,168.07 -15,029.18 -1,827.21 5,930,340.10 557,070.01. 0.50 15,029.18 16,800.00 91.75 179.59 3,286.45 3,165.45 -15,129.15 -1,826.49 5,930,240.15 557,071.51 0.50 15,129.15 16,900.00 92.25 179.59 3,282.96 3,161.96 -15,229.08 -1,825.78 5,930,140.24 557,073.01 0.50 15,229.08 16,946.26 92.48 179.59 3,281.05 3,160.05 -15,275.31 -1,825.44 5,930,094.02. 557,073.70 0.50 15,275.31 1J-182 L1 T7 (wp12) 17,000.00 92.36 179.59 3,278.78 3,157.78 -15,328.99 -1,825.06 5,930,040.34 557,074.51 0.23 15,328,99 17,100.00 92.13 179.60 3,274.87 3,153.87 -15,428.91 -1,824.35 5,929,940.44 557,075.99 0.23 15,428,91 9/13/2006 3:37:06PM Page 6 of 8 COMPASS 2003..11 Build 50 ~t~ • • Halliburton Energy Services a~.>~.i~ ®1'ldC®hl~llp$ Planning Report -Geographic orattEng and Forrrs~tion Alaska ~v®~Uat~an Database: _EDM 2003.11 b48 Local Co-ordinate Reference: `:'':ell Plan 1J-182 -Slot 1J-182 Company: ConocoPhillips Alaska, Inc. TVD Reference : Plan RKB (copy) @ 121.OOft (Doyon 15 ( 40+81)) Project: Kuparuk River Unit MD Reference: Plan RKB (copy) @ 121.OOft (Doyon 15 ( 40+81)) Site: Kuparuk 1J Pad North Referenc e: True Well: Plan 1J-182 Survey Calcula tion Method: Minimum Curvature Wellhore: 1J-182 L1 Design: 1J-182 L1 (wp12) Planned 5urveY 1J-lr'~:'' L1 f~:•: i.-~1"1 Map Map MD Inclination Azimuth TVD SSTVD +N,'-5 +E/-W Northing Easting DLSEV Vert Section (ft) O (') (ft) (ft) (ft) (ft) (ft1 (if) {`;1DOft) (ft) 17,200.00 91.90 .179.60 3,271.35 3,150.35 -15,528.85 -1,823.65 5,929,840.52 557,077.47 0.23 15,528.85 17,300.00 91.67 179.61 3,268.23 3,147.23 -15,628.80 -1,822.96 5,929,740.59 557,078.94 0.23 15,628.80 17,400.00 91.45 179.61 3,265.51 3,144.51 -15,728.76 -1,822.29 5,929,640.65 557,080.40 0.23. . 15,728.76 17,500.00 91.22 179.62 3,263.19 3,142:19 -15,828.73 -1,821.62 5,929,540.70 557,081.85 0.23. 15,828.73 17,600.00 90.99 179.63 3,261.26 3,140.26 -15,928.71 -1,820.96 5,929,440.74 557,083.29 0.23 15,928.71 17,700.00 90.76 179.63 3,259.73 3,138.73 -16,028.70 -1,820.31 5,929,340.77 557,084.72 0.23 16,028.70 17,788.95 ~ 90.56 179.64 3,258.70 - 3,137.70 -16,117.64 -1,819.74 5,929,251.84 557,085.98 0.23 16,117.64 L1 : BHL @ 17789' MD, 3259' TVD :1374ft FSL & 4269ft FEL -Sec 14 - T10N - R10E - 4 1l2" -1J-182 L1 T8 (Toe) (wp12) . Geologic Targets 1J-1 P-L1 --- - -~ TVD Tarrct G'~;nm~~: +N!-S +E-W Northing Easting ~'~ (ft) -.~~. ff ft (f t) (ft) 3,306.27 1J-182 L1 T5 (Exit Lower) {wp12} -13,776.25 -1,825.35 5,931,592.88 557,062.09 - Point 3,343.70 1J-182 L1 T2 (Exit Upper) {wp12) -9,276.24 -1,809.12 5,936,092.46 557,043.20 - Point 3,304.46 1J-182 L1 T4 (Exit Upper} {wp12} -12,276.04 -1,820.27 5,933,092.95 557,055.46 - Point 3,379.59 1J-182 L1 T1 (D-Landing} (wp11} -7,737.66 -1,805.06 5,937,630.87 557,035.25 - Point 3,330.50 1J-182 L1 T3 (Exit Lower) (wp12) -10,775.94 -1,814.41 5,934,592.91 557,049.62 - Point 3,281.05 1J-182 Li T7 (wp12} -15,275.31 -1,825.44 5,930,094.02 557,073.70 - Point 3,291.70 1J-182 L1 T6 {Stay in Upper) {wp12} -14,828.25 -1,828.66 5,930,541.00 557,067.00 - Point 3,258.70 1J-182 L1 T8 (Toe) (wp12) -16,117.64 -1,819.74 5,929,251.84 557,085.98 - Point ' Prognosed Casing Points i Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (tt) (~~) (~~) 3,670.22 2,153.00 13-3/8 16 17,788.94 3,258.70 4-1/2 6-3/4 9,158.91 3,359.30 9-5/8 12-1/4 9/13/2006 3:37:O6PM Page 7 of 8 COMPASS 2003.11 Build 50 i~~ ..~ }~~ E,,.~ i C ' Halliburton Energy Services c~~ C l Ips Planning Report -Geographic Oriiling anct Formation Alaska EvaluatEon Database: EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-182 -Slot 1J-182 Company: ConocoPhillips Alaska, Inc. TVD Reference: `' Plan RKB (copy) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Plan RKB (copy) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: I-rue Well: Plan 1J-182 Survey Calculation Method: L'inimum Curvature Wellbore: 1J-182 L1 Design: 1J-182 L1 (wp12) Prognosed Formation Intersection Point s Measured Vertical Depth Inclination Azimuth Depth (tt) (°) ~~ ift) 1,702.82 47.14 205.00 1,550.00 1,850.54 52.76 202.03 1,646.00 2,771.29 77.14 192.81 1,953.00 3,670.22 77.14 192.81 '2,153.00 6,699.60 77.14 192.81 2,827.00 7,490.66 77.14 192.81 3,003.00 7,769.33 77.14 192.81 3,065.00 8,448.02 77.14 192.81 3,216.00 9,105.36 80.00 180.20 3,350.00 +N.-E +E/-W (ftl (ftl -475.97 -111.y5 Base Ferm -578.65 -267.07 T3 -1,406.70 -489.61 K15 -2,261.28 -683.93 T3+550 -5,141.22 -1,338.81 Ugnu C -5,893.25 -1,509.81 Ugnu B -6,158.17 -1,570.05 Ugnu A -6,803.38 -1,716.77 K'13 -7,438.77 -1,804.21 WSAK D Plan Annotations Measured Vertical Local Coor dinates ~' Depth Depth +Nl-S +EI-W Co mment eft) (ft) eft) (ft) 9,158.91 3,359.30 -7,491.50 -1,804.39 L1 : TOW @ 9159' MD, 3359' TVD - 4638ft FSL & 4246ft FEL -Sec 11 - T10N - R10E 9,173.91 3,361.64 -7,506.32 -1,804.44 L1 : Bottom of Window- Drill 30' Rathole, 9174' MD, 3362' TVD 9,203.91 3,365.80 -7,536.03 -1,804.55 L1 : Build @ 4°/100ft to 92.62°Inc :9204' MD, 3366' TVD 9,406.18 3,379.59 -7,737.66 -1,805.06 L1 : Continue Geosteerng in D-Sand -Note Undulation Critical Targets: 9406' MD, 3381 17,788.95 3,258.70 -16,117.64 -1,819.74 L1 : BHL @ 17789' MD, 3259' TVD :1374ft FSL & 4269ft FEL -Sec 14 - T10N - R10E 9/13/2006 3:37:06PM Page 8 of 8 COMPASS 2003.11 Build 50 ORIG!, • • ~.. Alaska Plan: 1J-182 L1 (wp12) r ii i Anticollision Summary 14 September, 2006 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1 J Pad Plan 1J-182 1 J-182 L1 Centered on Well Plan 1 J-182 -Slot 1 J-182 Plan RKB (copy) @ 121.OOft (Doyon 15 (40+81)) N True API - US Survey Feet [ :., ! t 1 _ _,. ~ i Sperry Orilfing Services ~a^i< ~: Halliburton Company Anticollision Report __ Compam: ConocoPhillips Alaska Inc. -- Dare: 9/14/2006 Time: 14:44:48 Page l Field: Kuparuk River Un it Reference Site: Kuparuk 1J Pad Co-ordinate(NE) Reference: Well: Plan 1J-182, Tr ue North Reference y~'ell: Plan 1J-182 Vertical (TVD) Reference: Doyon 15 (40+81) 121.0 Rei'erence~Vcllpath: 1J-182 L1 Db: Oracle - - -- _ GLOBAL SCAN APPLIED: All wellpa _ ths within 200'+ 100/1000 of reference Reference: - Plan: 1 J-182 L1 (wp12) & NOT PLANNE Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 9158.91 to 17788.38 ft Scan Method: Trav Cylinder No rth Maximum Radius: 1974.84 ft Error Surface: Ellipse + Casing Casing Points (VID TVD Diameter Hole Size Name ft ft in in 9156.94 3359.54 9.625 12.250 9 5/8" 17704.46 3259.66 ' 4.500 6.750 4 1 /2" l Plan: 1J-182 L1 (wp12) Date Composed: 9/ 14/2006 Version: 1 Principal: Yes Tied-to: From: Definitive Path Summary I <---------------------- Offset ~Vcllpath --- ----------------> Reference Offset Ctr-Ctr Nu Go Allowable Site ~1'cll yVcllpath MD J1D Distance Area Deviation Warning ft ft ft ft ft ___ I Kuparuk 1J Pad 1J-152 1J-152L1 V2 ___-- _- - _ _ _ __ 1 Out of range Kuparuk 1J Pad 1J-152 1J-152L2 V1 Out of range Kuparuk 1J Pad 1J-184 1J-184 V5 15500.00 15350.00 1400.38 383.90 1016.47 Pass: Major Risk Kuparuk 1J Pad 1J-184 1J-184L1 V5 16677.49 16450.00 1420.91 402..98 1017.93 Pass: Major Risk Kuparuk 1J Pad Plan 1J-180 Plan 1J-180 L1 V1 Plan 17483.64 17862.97 1082.91 442.35 640.56 Pass: Major Risk Kuparuk 1J Pad Plan 1J-180 Plan 1J-180 V2 Plan: 1 17549.55 17931.82 1085.13 478.12 607.01 Pass: Major Risk Kuparuk 1J Pad Plan 1J-182 1J-182 V1 Plan: 1J-182 9199.99 9200.00 0.75 0.00 0.75 Pass: No Errors Kuparuk River Unit N West Sak 5 West Sak 5 V5 10440.54 3400.00 981.52 321.57 659.95 Pass: Major Risk 'ROGRAh Closest in Pool 1 J-182 L1 (wp12) D-Sand Closes t A roach: Reference Wel l: 1J-182 L1 w 12 Plan Offse# Well: 1J-152 L2 Coords.- Coords.- ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas, Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. ND E + /W - 180° Comments Depth Incl. An le TRUE Azi. TVD E + /w _ 180° Comments POOL Min Distance POOL Min Distance (542.75 ft) in POOL (542.75 ft) in POOL (9105.3 - 17788.95 (9105.3 - 17788.95 MD) MD) to 1J-152 L2 (5403 tc 1J-182 L1 (wp12) Plan 542.75 9105.36 80 180.2 3229.574 5937929 557034.1 7438.702 - 13112 MD) 13112 89.69 182.82 3249.155 5938467 556965.5 6900.113 (5403 - 13112 MD) Closest A roach: Reference Well : 1J-182 L1 w 12 Plan C7ffset Well: 1J -154 L2 Coords. - Coords. - ASP ASP. 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments De th Incl. An le TRUE Azi. ND E + /w _ 180° Comments POOL Min Distance POOL Min Distance (1292.03 ft) in POOL (1292.03 ft) in POOL (9105.3 - 17788.95 (9105.3 - 17788.95 MD) MD) to 1J-154 L2 (4079 to 1J-182 L1 (wp12) Plan '1292.03 9105.36 80 180.2 3229.574 5937929 557034.1 7438.702 -10964 MD) 10964 94.48 182.92 3248.504 5938474 558205.2 6902.658 (4079-10964 MD) Closest A roach: Reference Well : 1J-182 L1 w 12 Plan Offset Well: 1J -159 L2 Coords..- Coords - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. ND E + /W - 180° Comments Depth Incl. Angle TRUE Azi. TVD E + /W(-) 180° Comments POOL Min Distance POOL Min Distance (2470 ft) in POOL (2470 ft) in POOL (9105.3-17788.95 (9105.3-17788.95 MD) MD) to 1J-159 L2 (4565 to 1J-182 L1 (wp12) Plan 2470 ~.: ~ '•+: 9105.36 80 180.2 3229.574 5937929 557034.1 7438.702 -10884 MD) 10884 94.51 180.37 3316.841 5938576 559416.3 6810.604 (4565-10884 MD) Closest Ap roach: Reference Well : 1J-182 L1 wp12 Plan Offset Well: 1J -184 L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. An le TRUE Azi. ND E + /W _ 180° Comments Depth Incl. An le TRUE Azi. TVD E + /W - 180° Comments POOL Min Distance POOL Min Distance (1274.9 ft) in POOL (1274.9 ft) in POOL (9105.3 - 17788.95 (9105.3 - 17788.95 MD) MD) to 1J-184 L1 (8825 to 1J-182 L1 (wp12) Plan 1274.9 9400 89.89 180.1 3259.176 5937636 557035.5 7731.414 - 16692 MD) 9175 90.28 180.12 3267.818 5937644 558310.4 7734.111 (8825 - 16692 MD) Closest A roach: Reference Well : 1J-182 L1 w 12 Plan Offse# Well: 1J -180 L1 w 2 Coords. - Coords. - ASP ASP 3-D ctr-ctr - Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl: An le TRUE AzY. TVD E + /W - 180° Comments Depth Incl. An le TRUE Azi. TVD E + /w - 180° Comments POOL Min Distance (1107.55 ft) in POOL POOL Min Distance (9105.3 - 17788.95 (1107.55 ft) in POOL MD) to 1J-180 L1 (9105.3 - 17788.95 MD) (wp02) (10317.4 - to 1J-182 L1 (wp12) Plan 1107.55 15625 92.83 182.25 3176.744 5931413 557056.4 13954.22 15892.05 MD) .15892.05 89.61 178.99 3160.187 5931468 555950.3 13891.43 (10317.4 - 15892.05 MD) • ~-182L1~rillina Haz (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Low Stripping drills, shut-in drills, increased Pressure ~ 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 '~ ~_ ~ S ~ ~ ,~~" ~ ,~ 1J-182L1 Drilling Hazards Summary t ~~, ~ ~,,,,,~ ~ °:~ ,~"""~~ 9/12/2006 1:18 PM ~~,., ~':~~, { fi Insulated Conductor, 20" 94# K-55 x 34" 0.312 WT +/- 80' Wellhead /Tubing ! Tree: 13-3/8" x 4-1/2", 5,000 psi GLM, Camco, 4.1/2"k 1" KBMG 13-3/8" Casing Shoe, 68#, L-80, BTC set @ 3678' MD, 2153' TVD Tubing String 4-1/2" 12.5#, L-80, IBTM 3.958" ID, 3.833" Drift G LM, Camco, 4-1 /2" x 1"KBMG Bottom of Motor Centralizer / Centralift 418 HP KMHFER witk FC6000 pump 7"X9.518"7XP ~....... ,a~ Liner Top Packer ///'j `~,i, \~`r~ 7" X 9.5/B" Flex Loek .Liner Hanger/Packer Assembly at Liner Hanger +1-i9yC MD / 9Zs9' Caa{ng Bealboro Receptacle 4.75" ID B-sand Window at'4834 MD,3428'TVD 'D' Sand Lateral ,~ .-112",,.Bp,BTD, 1 ~-~~a L.~ L-80 Slotted Liner 7" x -5/8" -~-~_ ~ 4.7/2" PayZOne ECP Adel HOOK ~ . ~ / q.vz" Dwde shoe. H ger ~-~~ ~ <: i - ~ a '"""" 4-112" Casing Shoe, 11'.8#, L-80 BTCM 412" bent Joint shoe Set @ 17789' MD, 3259' 5.112" Tieba ®Baker Hughes 8005. This tlocument may not ba reproduced ortlH4lbutetl, In wholear in part, In any roan a by eny means electronic or mechanical, Inclutling photocopying, rxordlrp, or by any Information sbrage arM retrieval system now known or hereafter Irnentad, wtthwt wrHten permission from Baker Hughes Ina NY61~S Baker Oil Tools Equipment Specifications 7"" X 9-5/8" HOOK Hanger Mainbore Drift: 7.00" Mainbore Drift, with diverter: 6.25" .Br Sand Lateral Lateral DrifQ no diverter or LEM: 6,15" ., Lateral Drift, w/ diverter, no LEM: 5.13" ~ LaterallMainbore Diverler OD: 8.50" \., 4.12" 71.5#, BTC, ~~ L-80 Slotted Liner \ 472" Eccentric ~„ ~ :r 6uida Shoe „ ~ -~ 4.1/2" Casing Shoe, 11.8#, L-80 BTCM 9-5/8" Casing Shoe, 40.0#, "L-80 BTC Set @ 17790' MD, 3325' ND @ 9LDB' MD, 3420' TVD ~767y~85 deg inc) !~t~nc~COPh~Ii~ West Sak Hybrid Producer 1 J-182 Dual Lateral Completion 5 ~ntt • • • TRANSMITTAI, LETTER CIIECKLIST WELL NAME IL~~ ~ ~ ~-- ~ ~~ ~~ PTD# ~©~o ° t ~ ~Develo pment Servdce Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-Oiv`S WHAT ~ (OPTIONS) APPLIES I TEXT FOR APPROVAL LETTER MliLTI LATERAL i The permit is for a new wellbore segment of existing we I l 1~L2.~ ~ ~ -\.~ a (If [ast two digits in I ,Permit No.~OC~-\7,~ , API No. 50-f~`=1 - r~-3 3~l - ~C~. ,' ~ r 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 f ~ well name ( PH) and API number ~ (~0- - -_) from records, data and logs ~ acquired for well ~ ;SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 25.055. Approval to perforate and produce /inject is contingent I I upon issuance of a conservation order approving a spacing i I ~ exception. assumes the ~ j liability of any protest to the spacing exception that may occur. ;DRY DITCH ~ All dry ditch sample sets submitted to the Commission must be in ~ SAMPLE I no greater than 30' sample intervals from below the permafrost or I (from where samples are first caught and l0' sample intervals through target zones. i ~ ~ ~ Non-Conventional ~ Please note the following special condition of this permit: Well production or production testing of coat bed methane is not allowed ~ for (name of well) until after (Company Name) has designed and j implemented a water well testing program to provide baseline data ~ ~ ~ on water quality and quantity. _(Com~any Name) must contact the j Commission to obtain advance approval of such water well testing Rev: 1 /25/06 C:\jody\transmittal checklist WELL PERMIT CHECKL Field & Pool KUPARUK RIVER, WEST SAKOIL - 490150 Well Name: KUPARUK RIV U WSAK 1 J-182L1 .___Program DEV _ Well bore seg 0 PTD#:2061330 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV / PEND GeoArea 890 Unit 11160 _ On/Off Shore On Annular Disposal Administration 1 Permitfee attached_ . _ - _ _ - _ _ _ - - - N_A. West Sak D Sand multilateral well branch; fee waived per 20 AAC 25.005(e)_ - - - _ . _ _ --------------- 2 Lease number appropriate_ Yes - - _ - _ - Surface Location in ADL 025661;_ top pr_oductive_ interval inADL-024662; Tp in ADL_0380058._ _ - _ - _ , - - 3 Unique well-name and number -- - ------ - -- --- ---- --- Yes- -- - -- ---- -- ~ - ----- -- -- ----- - 4 Well located ina_definedpool------------------------------ ------- Yes. _____KuparukRver,West_SakOilPool-490150,_governed-by CO406B______---_--_---_-.___,,,..- 5 Well located proper distance from drilling unit_boundary. - - - . Yes - _ - Well ismore-than-500 feet from an external property line. - .. - - . - - - - . _ - - . - - .. . 6 Well located proper distance from other wells_ _ _ . _ _ - - - _ - Yes CO 4066, Rule 3:_ no restrictions as-to well spacing except that no_pay shall be opened in a well closer _ , 7 Sufficient acreage_avail_able in-drilling unit_ Yes than 500 feet to-an extemal_property line where ownership-or landownership changes- - - - - - - - - - - - - - - - - - 8 If_deviated,is_wellboreplat-included---------------- --___-.. ...-_.--_Yes ____._...-_--__-_-_ - - - 9 Operatoronlyaffectedparty_____________________ _________ __ _____Yes- _______.--. - - 10 Operator has.appropriate.bondin force---- ----- - ----- - -- --Yes. - -- -- ----- ----- - -- -- --- ---- --- -- --- - -- ------- -- -- 11 Permit can be issued without conservation order - Yes - - Appr Date 12 Permit can be issued without administrativ_e_appr_oya_I _ _ . - Yes - . _ . - -- SFD 912512006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Ihjection Order # (put IO# in-comrnents).(For_ NA_ 15 All wells within 1/4_mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ - - _ _ _ _ _ - - _ _ _ - - _ _ _ _ _ - - _ ------------------------------------------------- 16 Pre-produced injector; duration_of preproduction less than 3 months_ {For_service well only) _ NA_ -- 17 Nonconven, gas conforms to AS31,04_D30(j,1_.A),(j.2.A-D) - - - - . - - _ . NA - - - Engineering 18 Conductor string_p_rovided__________________----,.__ ____ ___ ___ -NA- ___- Conductorsetinmgtherbore,-1J-182(206-132).____-_--.-____-________--_--__-.-,---- 19 Surface casing-protects all-known. USDWs _ NA_ _ - . _ _ ..All aquifers exempted, 40 CFR-147.1 D2_ (b)(3)._ - 20 CMT_vol adequate_to circulate_onconductor & surf csg NA_ _ _ _ _ - .Surface casing set in_ 1J-1.82.- - - - . _ _ - _ ----------------------------------- 21 CMT_vol-adeguate_totie-in long string tosurfcsg_ tJA- _ _ _ _ _ Production_casin set in-1J-182._ _ 9- X 22 CMT_willcoyerallknownproductiyehorizons_____________________ _________ No__ _.__..Slottedlinercompletionpl_anned._-._---_.-___.____________....._________________ 23 Casing desgns adequate for C, T, l3 &_permafrost_ - - - - NA_ iJ-182 met design specifications. _NA for slotted liner.. - - - _ . - 24 Adequate tankage_or reserve pit - . - ... - _ - - - - Yes - - - - - - -Rig is_equipped with steel_pits. -NO reserve-pitplanned, All waste to approved annulus or disposal well._ - _ - - 25 Ifa_re-drill,has_a_1.0-403 for abandonment been app_roved_____________ ____ ____NA-_ _--______ ______--_-_-_--__ - - - 26 Adequate wellbore separation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ . _ - - -Proximity analysis performed: Nearest well segment is motherbore about X75'-tvd deeper, _ _ _ _ - _ _ _ _ - _ _ - _ 27 If diverter required, does it meet regu_la_tions_ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - tJA _ BQP stack.will already_be in place. Appr Date 1 28 Drilling fluid_program schematic & equip list adequate- - - ....... -Yes Maximum expected formation pressure 8,6-EMW.- Planned MW 9.0_ppg., _ _ . - _ - . TEM 912 29 BOPEs,.dotheymeetregulation - Yes 9 30 BOPE_press rating appropriate; test to_(put prig incomments)_ Yes MASP calculated at 11.49 psi. 3K equipment arrangement and test pressure_planned, _ : _ _ _ 31 Choke_manifoldcomplieswlAPI_RP-53(May84)___________________ _________Yes_ __________:---_. 32 Work willoccurwithoutoperationshutdown__-__________________ ____--.-Yes_ _____ ____--._____-.-_-___ 33 Ispresence_ofH2Sgasprobable ___--_____________________ ___ ____No-- _-_.H2Shasnotbeenreportedat1J_pad.___________----__-__-____-_---__--_---.__--- 34 Mechanical condition ofweflswithinAORverifiedGForservicewellonly)____ _--.--.-_N_A__ ___________________________ _____________________-_--_--_-________-__-_ Geology 35 Pe[mit_can be issued w/o hydrogen. sulfide measures _ - - _ - - - _ _ - . Yes _ - _ _ _ . H2$ has not_been encountered in W Sak_wells drilled tothe_south from 1J-Pad.. - . _ _ 36 Data_presented on_ potential overpressure zones - ... - . - - - . - Yes - - _ - Expected res.pressure is ~8.6ppg EMW, will be drilled with Q.0 ppq oil-based mud. Mud weight will be .... - . . Appr Date 37 Seismic.analysis ofshallow gas-zones- - - - NA_ - - - - . adjusted as needed. SFD 9/2512006 38 Seabed condition survey-(if off-shore) tJA- _ _ . -- - - 39 Contactnamelphoneforweekly_progressreports-[exploratoryonly]________ _________ tJA_ _ _--..._.______ __-..-..._--___________-----______-.____ Geologic Date: Engineering Date lic Date West Sak D sand producer. This is a well branch from dual-lateral production well KRU 1J-182. SFD Commissioner: Commissioner: Co sinner I 9f g r • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve tl~e readability of the Well Nistory file and to simplify finding information, information- of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 08 13:45:10 2007 Reel Header Service name .............LISTPE Date .....................07/02/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................07/02/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 3 JOB NUMBER: MW0004665704 LOGGING ENGINEER: R. FRENCH OPERATOR WITNESS: F. HERBERT SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD ~" Scientific Technical Services Scientific Technical Services 1J-182 L1 PB1 500292332170 ConocoPhillips Alaska Inc. Sperry Drilling Services 08-FEB-07 MWD RUN 5 MWD RUN 6 MW0004665704 MW0004665704 R. FRENCH R. FRENCH F. HERBERT F. HERBERT 35 11N l0E 1569 2433 121.30 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3680.0 2ND STRING 8.500 9.625 9121.0 3RD STRING PRODUCTION STRING Co - 1 ~ qtr 5~1.~ • 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. MWD RUNS 1,2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 9121' MD/3351'TVD, WITHIN THE RUN 3 INTERVAL OF THE 1J-182 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 5. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 5. MWD RUNS 3,6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 6 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) EWR MEMORY FILLED TOWARD THE END OF MWD RUN 3. REAL-TIME DATA (SEDP,SESP,SFXE ONLY) WERE USED TO FILL IN THIS GAP, FROM 8697.5'MD-9121'MD. GAPS REMAIN IN THE SEMP & SEXP DATASETS BECAUSE DATA FROM THESE SENSORS ARE NOT PULSED UP REAL-TIME. 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 1-3,5,6 REPRESENT WELL 1J-182 L1 PB1 WITH API#= 50-029-23321-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13487'MD/3347'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.......07/02/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 3638.0 FET 3650.0 RPD 3650.0 RPS 3650.0 RPM 3650.0 RPX 3650.0 ROP 3692.5 all bit runs merged. STOP DEPTH 13429.5 13436.5 13436.5 13436.5 13436.5 13436.5 13487.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO .MWD 3 MWD 5 MWD 6 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 3638.0 9121.0 9121.5 9161.0 9161.0 13487.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data. Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 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 3638 13487 8562,5 196.99 3638 13487 RPD MWD OHMM 1.34 2000 35.9961 19574 3650 13436.5 RPM MWD OHMM 0.67 2000 44.1041 18726 3650 13436.5 RPS MWD OHMM 1.75 2000 41.19 19574 3650 13436.5 RPX MWD OHMM 2.85 2000 43.3583 18726 3650 13436.5 FET MWD HOUR 0.15 349.68 1.44593 19574 3650 13436.5 GR MWD API 21.27 139.56 67.5978 19584 3638 13429.5 ROP MWD FT/H 0.02 3818.42 230.481 19590 3692.5 13487 . First Reading For Entire File.... .......3638 Last Reading For Entire File...........13487 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 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.......07/02/08 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 3638.0 9121.0 FET 3650.0 9121.0 RPX 3650.0 8697.0 RPS 3650.0 9121.0 RPM 3650.0 8697.0 RPD 3650.0 9121.0 ROP 3692.5 9121.0 LOG HEADER DATA DATE LOGGED: 20-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9121.0 TOP LOG INTERVAL (FT) 3691.0 BOTTOM LOG INTERVAL (FT) 9121.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 73.6 MAXIMUM ANGLE: 84.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 81797 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 3680.0 • BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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 Fresh Water Gel 9.00 61.0 9.4 650 5.3 3.500 72.0 2.570. 100.4 4.000 73.0 3.200 73.0 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 3638 9121 6379.5 10967 3638 9121 RPD MWD030 OHMM 1.34 2000 15.2075 10943 3650 9121 RPM MWD030 OHMM 0.67 44.92 12.7507 10095 3650 8697 RPS MWD030 OHMM 1.75 40.45 11.8967 10943 3650 9121 RPX MWD030 OHMM 2.85 30.29 10.366 10095 3650 8697 FET MWD030 HOUR 0.23 119.7 1.80488 10943 3650 9121 GR MWD030 API 21.27 139.56 70.7613 10967 3638 9121 ROP MWD030 FT/H 0.23 3818.42 192.001 10858 3692.5 9121 First Reading For Entire File..........3638 Last Reading For Entire File...........9121 File Trailer Service name .............STSLIB.002 Service Sub Level Name... • • Version Number...........1.0.0 Date of Generation.......07/02/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 9121.5 9161.0 LOG HEADER DATA DATE LOGGED: 02-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9161.0 TOP LOG INTERVAL (FT) 9121.0 BOTTOM LOG INTERVAL (FT) 9161.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 9121.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000. 87.8 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL • MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9121.5 9161 9141.25 80 9121.5 9161 ROP MWD050 FT/H 0.02 20.17 10.7832 80 9121.5 9161 First Reading For Entire File..........9121.5 Last Reading For Entire File...........9161 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 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.......07/02/08 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: 6 DEPTH INCREMENT: .5000 • • FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 9121.5 13436.5 RPD 9121.5 13436.5 GR 9121.5 13429.5 RPM 9121.5 13436.5 FET 9121.5 13436.5 RPS 9121.5 13436.5 ROP 9161.5 13487.0 LO G HEADER DATA DATE LOGGED: 04-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13487.0 TOP LOG INTERVAL (FT) 9161.0 BOTTOM LOG INTERVAL (FT) 13487.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.6 MAXIMUM ANGLE: 95.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 9121.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 67,0 MUD PH: .0 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 95.3 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 • Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9121.5 13487 11304.3 8732 9121.5 13487 RPD MWD060 OHMM 9.76 2000 62.3533 8631 9121.5 13436.5 RPM MWD060 OHMM 9.19 2000 80.7757 8631 9121.5 13436.5 RPS MWD060 OHMM 9.46 2000 78.33 8631 9121.5 13436.5 RPX MWD060 OHMM 5.61 2000 81.9467 8631 9121.5 13436.5 FET MWD060 HOUR 0.15 3 49.68 0.990835 8631 9121.5 13436.5 GR MWD060 API 35.6 1 12.02 63.5715 8617 9121.5 13429.5 ROP MWD060 FT/H 5.01 6 26.36 280.803 8652 9161.5 13487 First Reading For Entire File..........9121.5 Last Reading For Entire File...........13487 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/02/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................07/02/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF • End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 08 13:08:54 2007 Reel Header Service name .............LISTPE Date .....................07/02/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................07/02/08 Origin ...................ST5 Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River Unit West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA • Scientific Technical Services Scientific Technical Services 1J-182 L1 500292332160 ConocoPhillips Alaska Inc. Sperry Drilling Services 08-FEB-07 MWD RUN 3 MWD RUN 5 MWD RUN 6 JOB NUMBER: MW0004665704 MW0004665704 MW0004665704 LOGGING ENGINEER: R. FRENCH R. FRENCH R. FRENCH OPERATOR WITNESS: F. HERBERT F. HERBERT F. HERBERT MWD RUN 7 JOB NUMBER: MW0004665704 LOGGING ENGINEER: R. FRENCH OPERATOR WITNESS: F. HERBERT SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1569 FEL: 2433 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 121.30 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CA SING DRILLERS c"'~-1~~ g ~t{~~~ • BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3680.0 2ND STRING 8.500 9.625 9121.0 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. MWD RUNS 1,2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. THIS WELLBORE IS AN OPENHOLE SIDETRACK EXITING THE 1J-182 L1 PB1 WELLBORE AT 13045'MD/3337'TVD. 5. MWD RUNS 3,6,7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 6,7 ALSO INCLUDED GEO- PILOT ROTARY STEERABLE BHA (GP) EWR MEMORY FILLED TOWARD THE END OF MWD RUN 3. REAL-TIME DATA (SEDP,SESP,SFXE ONLY) WERE USED TO FILL IN THIS GAP, FROM 8697.5'MD-9121'MD. GAPS REMAIN IN THE SEMP & SEXP DATASETS BECAUSE DATA FROM THESE SENSORS ARE NOT PULSED UP REAL-TIME. 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 1-3,5-7 REPRESENT WELL 1J-182 L1 WITH API#: 50-029-23321-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17757'MD/3275'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.......07/02/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record ~~ FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 3638.0 FET 3650.0 RPM 3650.0 RPS 3650.0 RPD 3650.0 RPX 3650.0 ROP 3692.5 all bit runs merged. STOP DEPTH 17699.0 17706.5 17706.5 17706.5 17706.5 17706.5 17757.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 3 3638.0 5 9121.5 6 9161.0 7 13045.5 REMARKS: MERGED MAIN PASS. MERGE BASE 9121.0 9161.0 13045.0 17757.5 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame 5pacing .....................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 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 3638 17757.5 10697.8 28240 3638 17757.5 RPD MWD OHMM 1.34 2000 37.7308 28114 3650 17706.5 RPM MWD OHMM 0.67 2000 49.1802 27266 3650 17706.5 RPS MWD OHMM 1.75 2000 48.5157 28114 3650 17706.5 RPX MWD OHMM 2.85 2000 49.4287 27266 3650 17706.5 FET MWD HOUR 0.15 349.68 1.2216 28114 3650 17706.5 GR MWD API 21.27 139.56 66.2756 28123 3638 17699 ROP MWD FT/H 0.02 3818.42 233.007 28131 3692.5 17757.5 First Reading For Entire File..........3638 Last Reading For Entire File...........17757.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 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.......07/02/08 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 3638.0 9121.0 RPD 3650.0 9121.0 RPX 3650.0 8697.0 RPM 3650.0 8697.0 FET 3650.0 9121.0 RPS 3650.0 9121.0 ROP 3692.5 9121.0 LOG HEADER DATA DATE LOGGED: 20-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory. TD DRILLER (FT) 9121.0 TOP LOG INTERVAL (FT) 3691.0 BOTTOM LOG INTERVAL (FT) 9121.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 73.6 MAXIMUM ANGLE: 84.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 81797 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.-250 DRILLER'S CASING DEPTH (FT) 3680.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 61.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 650 FLUID LOSS (C3): 5.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.500 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.570 100.4 MUD FILTRATE AT MT: 4.000 73.0 MUD CAKE AT MT: 3.200 73.0 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 3638 9121 6379.5 10967 3638 9121 RPD MWD030 OHMM 1.34 2000 15.2075 10943 3650 9121 RPM MWD030 OHMM 0.67 44.92 12.7507 10095 3650 8697 RPS MWD030 OHMM 1.75 40.45 11.8967 10943 3650 9121 RPX MWD030 OHMM 2.85 30.29 10.366 10095 3650 8697 FET MWD030 HOUR 0.23 119.7 1.80488 10943 3650 9121 GR MWD030 API 21.27 139.56 70.7613 10967 3638 9121 ROP MWD030 FT/H 0.23 3818.42 192.001 10858 3692.5 9121 First Reading For Entire File..........3638 Last Reading For Entire File...........9121 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 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; 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 9121.5 9161.0 LOG HEADER DATA DATE LOGGED: 02-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9161.0 TOP LOG INTERVAL (FT) 9121.0 BOTTOM LOG INTERVAL (FT) 9161.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 9121.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 87.8 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 • NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9121.5 9161 9141.25 80 9121.5 9161 ROP MWD050 FT/H 0.02 20.17 10.7832 80 9121.5 9161 First Reading For Entire File..........9121.5 Last Reading For Entire File...........9161 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 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.......07/02/08 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: 6 DEPTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9121.5 13045.0 FET 9121.5 13045.0 RPX 9121.5 13045.0 RPM 9121.5 13045.0 RPD 9121.5 13045.0 RPS 9121.5 13045.0 ROP 9161.5 13045.0 LOG HEADER DATA DATE LOGGED: 04-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13045.0 TOP LOG INTERVAL (FT) 9161.0 BOTTOM LOG INTERVAL (FT) 13045.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.6 MAXIMUM ANGLE: 95.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 9121.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S): 67.0 MUD PH: .0 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 95.3 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ}: REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN . . Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9121.5 13045 11083.3 7848 9121.5 13045 RPD MWD060 OHMM 12.89 2000 66.4882 78.48 9121.5 13045 RPM MWD060 OHMM 9.19 2000 86.4525 7848 9121.5 13045 RPS MWD060 OHMM 13.99 2000 83.7134 7848 9121.5 13045 RPX MWD060 OHMM 5.61 2000 87.5757 7848 9121.5 13045 FET MWD060 HOUR 0.15 3 49.68 1.05492 7848 9121.5 13045 GR MWD060 API 37.06 91.87 61.9323 7848 9121.5 13045 ROP MWD060 FT/H 5.01 6 26.36 282.031 7768 9161.5 13045 First Reading For Entire File..........9121.5 Last Reading For Entire File...........13045 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 13045.5 17706.5 GR 13045.5 17699.0 RPD 13045.5 17706.5 FET 13045.5 17706.5 RPM 13045.5 17706.5 ROP 13045.5 17757.5 RPS 13045.5 17706.5 LO G HEADER DATA DATE LOGGED: 07-NOV- 06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 17757.0 TOP LOG INTERVAL (FT) 13045.0 BOTTOM LOG INTERVAL (FT) 17757.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.5 MAXIMUM ANGLE: 93.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 9121.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 67.0 MUD PH: .0 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 108.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13045.5 17 757.5 15401.5 9425 13045.5 17757.5 RPD MWD070 OHMM 5.73 2000 39.9601 9323 13045.5 17706.5 RPM MWD070 OHMM 7.39 2000 57.2509 9323 13045.5 17706.5 RPS MWD070 OHMM 11.33 2000 61.8686 9323 13045.5 17706.5 RPX MWD070 OHMM 15.65 2000 59.6144 9323 13045.5 17706.5 FET MWD070 HOUR 0.15 5.4 0.677276 9323 13045.5 17706.5 GR MWD070 API 39.85 97.01 64.6523 9308 13045.5 17699 ROP MWD070 FT/H 1.95 6 52.47 241.729 9425 13045.5 17757.5 First Reading For Entire File..........13045.5 Last Reading For Entire File...........17757.5 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/02/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................07/02/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File
