Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
206-109
• Image Projeet Well History File .Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - ~ (~ C~' Well History File Identifier Organizing (done> RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proofing BY: Maria ~.~s,d~ uumiiiuiuui DIG AL DATA Diskettes, No.~ ^ Other, No/Type: Date: Date: lsl ~. Scanning Preparation ~ x 30 = ~ ~0 + -~. =TOTAL PAGES~~ Q (Count does not include cover sheet) ~ BY: Maria Date: a !s/ Production Scanning IIIII~IIIIIIII IfIII Stage 1 Page Count from Scanned File: 1 ~~(Count does include cover sheet) Page Count Matches Number in Scanni g Preparation: ~ES NO BY: Maria Date: 1' ~ O U /s/ '~/fj n Stage 1 If NO in stage 1, page(s) discrepancies w{ere found: YES NO y~ BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: d ae.~a~~~ae~ iuumuiuiui OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: lsl P ~~a ,«e~~.d mumiiuuiiu 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell pr Rug FFrforations r Stimulate E Other r Alter Casing r Pull Tubing p Perforate New Pool r Waiver E Time Extension Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r - 206 -109 3. Address: 6. API Number: Stratigraphic r Service P. 0. Box 100360, Anchorage, Alaska 99510 -• 50 - 029 - 23316 - -, QC 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25662, 380058 4 - 1J - 137L1 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 16840 feet Plugs (measured) 2150' true vertical 3361 feet Junk (measured) None Effective Depth measured 16825 feet Packer (measured) none true vertical 3361 feet (true vertucal) Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 108' 108 SURFACE 3743 13.375 3773 2175 INTERMEDIATE 9406 9.625 9434 3530 LINER 7691 4.5" 16827 3357 'SvidAitiED MAR 0 8 2O1 Perforation depth: Measured depth: slotted liner 9197'- 14564', 14680'- 16792' — True Vertical Depth: 3470'- 3376', 3376' -3360' RECEIVED' °,p 22 2011 Tubing (size, grade, MD, and TVD) 4.5 ", L -80, 8837 MD, 3443 TVD A�1 Packers & SSSV (type, MD, and TVD) no packer Maw u14 & Gas t�.,. �x- C ssroe NIPPLE - CAMCO 'DB' NIPPLE @ 517 MD and 517 TVD Anchorage 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 si Subsequent to operation si 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development F,7 • Service r Stratigraphic 15. Well Status after work: • Oil 17 Gas r WDSPL Daily Report of Well Operations XXX GSTOR "" WINJ r WAG r GINJ r SUSP r 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 Brett Packer ( 265 -6845 Printed Name Brett Packer Title Wells Engineer Signature 72--z.-k, 7 -Z p Phone: 265 -6845 Date , ?/ Z ///( RBDMS FEB 2 2 2011 3.7.61 Onl Form 10-404 Revised 10/2010 � Submit Original y N,, KUP 1J -137L1 ConocoPhillips * } weltAtttiblites Max Angle & M D TD Sicei Inc ', 4 Wellbore APUUWI 'Field Herne Well Status I I( °) IMD (ftKB) Act Btm (ftKB) IN . , 500292331660 'Field SAK PROD 95.69 10,770 28 16840.0 ( _— - Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date S w Qp969/,1 n�o.,plgl 1J.73Z41„2L9/2,4/1,84256 AM S SV W NIPPLE 25 7/10/2009 Last O: 2/5/2011 32.00 10/1/2006 _ $c950 o0/f 6 5144 0 - ... .. _ Annotation Depth (ftKB) 'End Date Annotation Last Mod .. 1E d Date Last Tag: Rev Reason WORKOVER Imosbor 1/8/2011 Casing Strings HANGER. 22 - - ' -- . 6 . Casing Description String O String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... IStr g String Top Thrd DSAND LINER l 41/2 / 3476 I 9,135.7 1 168270 3,360.8 1 11601 L80 > a," ,:9 1MIINu , .,, .. .;:4 a/kl,.., Liner Details Top Depth - -_ Space Out Pup, (ND) Top Inc! 801111... 59 N UAW= CONDUCTOR, - Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 9,135.7 3,474.1 92.26 SLEEVE Baker "HR" Liner Setting Sleeve, 5 1/2" ID 5.01" 5.010 'a °: 9,192.0 3,471.9 91.57 XO BUSHING 5 -1/2" H521 x 4 -1/2" BTC Crossover Bushing ID 3.9 3.960 NIPPLE, sn - - ---- R F 16,792.6 3,360.4 89.20 X0 XO Sub 4 1/2" BTC X 3 -1/2" BTC 2.992 ;: 16,794.01 3,360.41 89.201BENTJT 3-1/2" BTC, Bent Joint ID2602" 2.992 GAS LIFT, 2,062 yam . ' ' Merin Hole(Wireline retrievable plugs, valves, pumps, fish, etc -) 9E5 Top Depth - - � _, (TVD) Top Inc! CATCHER, _ Top (MKS) _ (ftKB) (°) Description Comment ___ nt Run Date ID (n) 2,149 •" - - PLUG, 2,150 2,149.0 1,764.7 70.681 CATCHER CATCHER SET ON WRP 2/3/2011 0.000 2,150.0 1,765.0 70.71 (PLUG 4.5' WRP 2/3/2011 0.000 SURFACE, 30 -3,773 c -' Perforations & Slots 01,01 Top (TVD) Btm (TVD) Dens I ' - 1 - _,,_ ftKB B en ftKB ftKB SLEEVE, 6,725 - ) ( �ftKB ( (ftKB) -,_ -� ). Zone Data — (she Type Comment____ ": 9,197.0 14,564.0 3,469.7 3,376.2 WS D, 1J -137L1 9/22/2006 32.0 SLOTS ALL PERFS IN WELLBORE: '. 0@ Alternating solid/slotted pipe - 0.125 "225"x2.5" 4 circumferential fere ential III DISCHARGE, adjacent 99 acent rows, 3" centers staggered 8,772 -_- �. 18 deg, 3' non - slotted ends Mr iffi 14,680.0 16,793.0 3,375.5 3,360.4 WS D, 1J -137L1 9/22/2006 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid /slotted pipe - SEAL ASSV, 0.125 "x2.5" @ 4 circumferential 8.819 c adjacent rows, 3" centers staggered 788, 8,821— - - -- s 18 deg, 3' non slotted ends Anchor, 9.543 St Na¢�; General, & -+ 1 'fir End Date Annotation - _.. _'- 10/3/2006 NOTE MULTI LATERAL WELL: 1J -137 (B- SAND), 1J -137L1 (DSAND) 8/9/2008 NOTE: VIEW SCHEMATIC w/9.OREV 3/12/2009 NOTE: ESP WORKOVER w/Y -BLOCK ESP INSTALL 1 1 1 I I D -SAND LINER LEM, 8,843- 9,056„r D -SAND LINER HH, 8,918 -9,186 VTERMEDIATE, _ 28 -9,434 SLOTS, . Petal's -- 9,197- 14.564 Mandrel SLOTS own. Top Depth Top Port 9427 (TVD) Inc! OD Valve Latch S e TRO Run SLLOTSOTS ,, 14,680-16,793 we* ate St. Top ftKB) (ftKB) () Nate Model Os/ Sew Type Type Os) t (Psi) Run Date Com... SAND 0 , wr 1 2,062.2 1,731.2 67.50 Camco KBMG 1 GAS LIFT OPEN 0.000 i 0.0 2/4/2011 16,827 9,136 - ".4 ' -- - _ _ — _. TD(1J- 137L1), II - 16,840 8'- B -SAND e '�; , LINER, -8 4 - 9,013 - 17,376 "%y 8.,- P. s • ConocoPhillips Time Log & Summary We/Iview Web Reporting Report Well Name: 1J - 137 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 1/17/2011 3:30:00 PM Rig Release: 2/4/2011 6:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/16/2011 24 hr Summary Release Rig from 3G -10 Well. Begin to Mob Rig 09:00 00:00 15.00 MIRU MOVE MOB P Mob Rig to 1J -Pad. 01/17/2011 Mob Rig to 1J -Pad. Accept Rig at 15:30 hrs. Move Rig over Well. Complete rig -up. Pull Back Pressure Valve with Lubricator. 00:00 09:30 9.50 MIRU MOVE MOB P Continue to Mob Rig to 1J -Pad. Accepted Rig at 15:30 hrs. 09:30 14:30 5.00 MIRU MOVE MOB T Wait on Rig Mats. (Shortage of third -party Trucks and Drivers to move support equipmnet). Spot double Rig Mats. 14:30 15:30 1.00 MIRU MOVE RURD P PJSM. Move Rig over 1J -137 Well Slot. 15:30 22:00 6.50 MIRU MOVE RURD P Spot rig support equipment. Level and berm up Rig. Spot and berm up Kill Tank. Lay Hardline. 22:00 00:00 2.00 COMPZ WELCTL RURD P PSSM. Pick -up Lubricator. Pull Back Pressure Valve. Lay down same. 01/18/2011 Hook up Kill Lines to Tree. Take on Hot Fresh Water /3% KCL in Pits. Attempt to Bullhead Kill Well. SIDP = 90 psi. Circulate Well the "long way ". Returns = Gas -cut Diesel /Oil /KCL Water. 00:00 04:30 4.50 COMPZ WELCTL RURD P Hook up Kill Lines to the Tree. Take on Hot Fresh Water w /3% KCL in Pits. Thaw lines. Wait on additional Kill Fluid. Entire Field now back to Phase I driving conditions. 04:30 11:00 6.50 COMPZ WELCTL KLWL T PJSM. Attempt to open Well. Still have a line in Cellar that remains frozen. 11:00 13:00 2.00 COMPZ WELCTL KLWL P PJSM. Notify Security and DSO of planned Gas venting. Initial TBG Psi = 800 psi / Initial IA Psi 230 psi. OAP = 60 psi. Start Bleeding Down TBG & IA. 13:00 15:30 2.50 COMPZ WELCTL KLWL P Bled Down IA to Zero and Bled TBG down to 70 psi. Seeing mostly fluid with a trace of Gas. Bled 29 bbls of fluid back from TBG while bleeding. Line up to pump Hot Seawater Down IA taking Return up TBG. 1 BPM = 240 IA / 240 TBG. 3 BPM = 320 IA / 60psi TBG. 4 BPM 370 IA / 70psi TBG. 5 BPM 420 IA / 80psi TBG. After Pumping 150 bbls hot seawater down IA had Only 20 bbls returned. Blow down Return Iron to Kill Tank. Page 1 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 00:00 8.50 COMPZ WELCTL KLWL P Start Bullheading down TBG © 7 bpm, 2080 psi ( 80 bbls 8.6 ppg KWF). Swap over pumping down IA with another 650 bbls of hot 8.6 ppg KWF 1,040 psi. ISIP = 640 psi, then fell off to 380 psi. Monitor pressure fall -off down to 270 psi. Crack choke and bleed gas and diesel to Kill Tank. Shut in Well with 20 psi. Wellhead pressure built up to 90 psi in 15 minutes. Bring pump on down the Tubing and take Diesel /Oil /Gas /KCL returns to the KIII Tank. Start getting 1:1 returns. Continue circulating returns to Kill Tank. Shut down to have Dirty Vac Truck pull returns from Kill Tank. Thaw out frozen Suction Valve and emty Kill Tank. 01/19/2011 Continue to circulate Well. Returns now 1:1 8.5 lb/gal 3% KCL. SI Well. Monitor SIDP at 40 psi. Calculate new 9.0 lb/gal KWF. Circulate Well over to KWF. Monitor Well on slight vacuum. Set BPV. ND Tree. 00:00 02:30 2.50 COMPZ WELCTL CIRC P Circulate Well at 3.0 bpm /270 psi with 1:1 returns. Well cleaned up with 8.5 lb/gal returns. Shut in Well and monitor. SIDP = 40 psi. Calculate balance Well plus trip margin. New KWF = 9.0 lb/gal. Review plan forward with Anchorage Engineer. 02:30 11:30 9.00 COMPZ WELCTL CIRC P Prep to swap Well over to 9.0 lb/gal KCL. Circulate Pits. Re- direct Vac Trucks. Shuffle Fluids. (Load and tally 2 7/8" PAC Drill Plpe. Begin to load and tally 2 3/8" PH -6 Tubing). 11:30 12:30 1.00 COMPZ WELCTL CIRC T Un -thaw Ciruclating Hoses in Cellar from IA. 12:30 18:00 5.50 COMPZ WELCTL CIRC P Start Circulating 9.0 ppg KWF down TBG. Pumped 70bbI down TBG then Bullheaded 60bbls of 9.0 ppg KWF to B -Sand Window after KWF reached CMU. Continue to Circulate KWF down TBG up IA at 2 bpm @ 320 psi TBG psi and 80 psi on IA after Bull heading 60 bbls down to top of B -Lem. ICP @ 1 bpm = 60 psi TBG / IA = 40 psi 2 bpm = 90 psi TBG / IA = 40 psi 3 bpm = 190 psi TBG / IA = 50 psi 4 bpm = 380 psi TBG / IA = 100 psi Page 2 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:00 2.00 COMPZ WELCTL CIRC P Continue to pump 9.0 lb/gal KWF down Tubing. Sample 8.7 lb/gal in returns. Returns now 9.0 lb /gal. Continue to circulate additional KWF to clean up. Shut down and monitor returns from the IA. Very sight flow then quit. Bring charge pump on and fill any void. Monitor well on slight vacuum. (finish loading and tallying 2 7/8" PAC Drill Pipe and 2 3/8" PH-6 Drill Pipe). 20:00 00:00 4.00 COMPZ WELCTL NUND P Call -out Wellhead Service Rep. PJSM. Set BPV. Pump 10 bbls down IA to check BPV integrity. Good. Nipple down Tree. Inspect Tubing Hanger lift threads. Good. Install Blanking Plug. 01/20/2011 Nipple up BOP Stack. Perform initial BOPE test. Complete rigging up to handle the 3 1/2" ESP Completion. Start to single down 3 1/2" Completion while spooling ESP Cable. 00:00 06:00 6.00 COMPZ WELCTL NUND P Nipple up BOPE Stack. 06:00 07:30 1.50 COMPZ WELCTL PRTS P Perform Shale Test on surface equipment. Found bad grey lock connection. Replaced & test 07:30 12:30 5.00 COMPZ WELCTL BOPE P Perform BOPE test 250 / 2500 psi. Test waived by Chuck Scheve & Louis Grimaldi @ 0700. 12:30 15:30 3.00 COMPZ WELCTL PULD P Load IA with Charge Pump ( 9.0 ppg ) Took 17 bbls. PJSM.BIow Down and Rig Down Testing Equipment. Pull Blanking Plug & BPV. 15:30 19:00 3.50 COMPZ RPCOM OTHR P Changes out Dies and Slip on Elevators for Landing joint to pull tubing hanger and lay down the 4 1/2" full Joint below the Tubing Hanger. Repair overhead safety guard on ESP Spooler. 19:00 22:00 3.00 0 32 COMPZ RPCOM PULD P PJSM. Check IA on slight vacuum. Pick -up 4 1/2" Landing Joint. BOLDS. "Popped" Tubing Hanger free at 190K. Pulling Tubing Hanger at 95K with no problems. Hole Check Fill = 3 bbls (- 50 -ft). Pull Tubing Hanger to floor. Monitor a slow drop in fluid level. Lay down Tubing Hanger and the 4 1/2" Tubing Joint below. Lay down Landing Joint. ESP Cable check indicates a short in the Cable. Change handling equipment back to 3 1/2" Tubing. String ESP Cable over sheave. 22:00 00:00 2.00 32 6,700 COMPZ RPCOM PULL P Begin to single down the 3 1/2" Completion while spooling ESP Cable. 6,700 -ft. Up Weight = 80K. 01/21/2011 Continue to lay down 3 1/2" Completion Tubing. Shut down due to Air Spooler repair problems. Move in Ground Spooler. Resume operation with Ground Spooler. Continue to single down 3 1/2" Completion. Page 3 of 15 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:00 5.00 6,700 3,900 COMPZ RPCOM PULL P Continue to single down the 3 1/2" Completion while spooling ESP Cable. Clear Pipe Shed as needed. Stop to cut and slip Drill Line at —3,900-ft. 05:00 08:30 3.50 3,900 3,900 COMPZ RPCOM SVRG P PJSM. Cut and Slip Drilling. (Continue to monitor Well. Well remains on a slight vacuum). 08:30 14:00 5.50 3,900 900 COMPZ RPCOM PULL P Continue to single down the 3 1/2" Completion while spooling ESP Cable from 3,900' md. Un Load & Clear Pipe Shed as needed. Up Wt =65K. Perform Kill While Tripping Drill. 14:00 16:00 2.00 900 900 COMPZ RPCOM OTHR T Lost Air Motor to ESP Spooler. 16:00 22:00 6.00 900 900 COMPZ RPCOM OTHR T Unable to make repairs to air motor. Order out the ground spooler, secondary containment and generator to power spooler. Spot Ground Spooler inside spill containment. Have electrician install proper plug -in to the Generator. Start and warm -up Spooler. Check for leaks and proper operation. "Good- to -go ". 22:00 22:30 0.50 900 900 COMPZ RPCOM SFTY P PJSM. Discuss safety issues and communications with Centrilift and Rig Crew to continue operations using the Ground Spooler. 22:30 00:00 1.50 900 175 COMPZ RPCOM PULL P Resume operations. Cut ESP Cable and secure to Air Spooler Reel. String ESP Cable to Ground Spooler. Continue to single down remaining 3 1/2" Tubing to Pipe Shed while spooling ESP Cable. 01/22/2011 Finish laying down 3 1/2" Completion. Lay down ESP Assembly. Install 2 3/8" Pipe Rams in the BOP. Tested same. Also tested the VBPR with the 2 7/8" Test Jt and tested the Annular with the 2 3/8" Test Jt. Load and tally the DC /HWDP section. Single in with the DC /HWDP section. Trip out standing back the DC /HWDP section. 00:00 07:30 7.50 175 0 COMPZ RPCOM PULL P Finish laying down Completion Tubing. Break down and lay down ESP Assembly components. ESP Hardware recovered complete (133 ea Cannon Clamps, 6 ea SS Bands, and 6 ea Protectolizers). 07:30 10:30 3.00 0 0 COMPZ RPCOM PULD P Clear & Clean Rig floor of ESP equipment and Tools. Load Start Joints and Tools 10:30 12:00 1.50 0 COMPZ WHDBO OTHR P PJSM. Install 2 3/8" Rams in the upper set of BOPE. 12:00 13:00 1.00 COMPZ WHDBO SEQP P PJSM. Install Test Plug and Rig Up Testing Equipment. 13:00 15:00 2.00 COMPZ WHDBO PRTS P Test Rams and Annular 250/2500 psi. Page 4 of 15 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:30 1.50 COMPZ WHDBO SEQP P PJSM. Remove Testing Equipment and Test plug. Install Wear Ring and RILDS x2. 16:30 20:00 3.50 COMPZ RPEQP1 PULD P Load & Rack & Tally 3.5" HWDP & 4 3/4" DC. 20:00 22:45 2.75 0 1,374 COMPZ RPEQP1 PULD P PJSM. Single in the Drill Collar /Heavey Weight Drill Pipe section from the Pipe Shed. (Drift same). Total section ran 15 stands = 1,373.65-ft. 22:45 23:00 0.25 1,374 1,374 COMPZ RPEQPICIRC P Circulate 30 bbls of 9.O lb/gal KWF to clear the DC /HWDP section and fill hole. Circulate an additional 15 bbls to clean -up oil from the top of the fluid column in the Wellbore. 23:00 00:00 1.00 1,374 367 COMPZ RPEQP1TRIP P Trip out with the DC /HWDP section standing back in the Derrick. Actual Pipe Weight Up = 42K. Pipe Actual Weight Down = 33K. Note: Each Stand consists of 2 ea 4 3/4" Drill Collars and 1 ea 5" Heavy Weight Drill Pipe. 01/23/2011 Trip out with the DC /HWDP section. Make -up a 2 3/8" Mule Shoe Pup Jt. Single in with 2 3/8" PH -6 Tubing. Continue to single in with 2 7/8" PAC Drill Pipe. Secure and monitor Well. Load and tally 3 1/2" Drill Pipe in Pipe Shed. 00:00 00:30 0.50 367 0 COMPZ RPEQP1TRIP P Finish tripping out with the DC /HWDP section. 00:30 13:00 12.50 0 7,711 COMPZ RPEQP1PUTB P PJSM. Change over to 2 3/8" handling equipment. Pick -up a 2 3/8" PH -6 Mule Shoe Pup Joint. Single in and drift 2 3/8" PH -6 Tubing from the Pipe Shed. 13:00 13:45 0.75 7,711 7,711 COMPZ RPEQP1CIRC P Completed Running 2 3/8" PH -6 down to 7711'md. Rig Pumping Equipment and Circulate through PH -6 TBG to clear TBG @ 2 bpm,920 psi. Total Pumped 55 bbls. Seen 9.0 ppg back at pits. Up Wt 39k & Down Wt 39k @ 1000' and Up Wt 43k & Down Wt 43K @ 2000' and Up Wt 47k & Down Wt 47k @ 3000' and Up Wt 50k & Down Wt 50k @ 4000' and Up Wt 54k & Down Wt 49k @ 5000' and Up Wt 55k & Down Wt 49k @ 6000' and Up Wt 59k & Down Wt 49k @ 7000' and UpWt62k & Down Wt50k @7711' and 13:45 14:15 0.50 7,711 7,711 COMPZ RPEQP1SFTY P Blow Pumping Equipment. PJSM. Page 5 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 14:45 0.50 7,711 7,711 COMPZ RPEQPI OTHR P Change over to 2 7/8" handling equipment. ui ment. 14:45 16:45 2.00 7,711 8,633 COMPZ RPEQP1TRIP P Single in 30 Joints of 2 7/8" PAC Drill Pipe down to 8,633'md 16:45 00:00 7.25 8,633 8,633 COMPZ RPEQPI PULD P Loading Pipe Shed with 240 Joints of 3 1/2" Drill Pipe. Tally Same. .01/24/2011 Pick -up single 3 1/2" Drill pipe from Pipe shed and continue RIH. Clean -out the Lower "B" Sand Lateral per program to an expected target of 17,364 -ft (PBTD). 00:00 00:30 0.50 8,633 8,633 COMPZ RPEQPI PULD P Finish loading Pipe Shed woth 3 1/2" Drill Pipe. Complete Drill Pipe tally. 00:30 01:00 0.50 8,633 8,651 COMPZ RPEQP1PUTB P PJSM. Make -up Bumper Sub and Oil Jar. 01:00 05:00 4.00 8,651 10,753 COMPZ RPEQPI PUTB P Begin to single in with 3 1/2" Drill Pipe from Pipe Shed. Up Weight 70K. down Weight = 62K. RTW = 65K. RPMs = 10. Free Torque = 1.3K ft-Ibs. Tagged top of Packer at 8,842.0 -ft dpmd. Continue through Completion Jewelry with no problems. Bring charge Pump on to keep Annulus full. Stop at 9,500 -ft. Make up Head Pin. Circulate 5.0 bbls to clear String. Up Weight = 74K. Down Weight = 55K. Continue to single in. Stop at 10,000 -ft. Circulate 5.0 bbls. Up Weight = 76K. down Weight = 56K. Continue to single in. 05:00 08:00 3.00 10,753 10,753 COMPZ RPEQP1 FCO P Rig Up Pumping Equipment and Circulate Down IA taking Return TBG @ 2 bpm @ 160 psi. Seen small amount of Sand. Losses @ 40% 08:00 11:15 3.25 10,753 10,915 COMPZ RPEQP1 FCO P Continue Cleaning Opeation. Able to Single one joint at a time while rotating @ 9 RPM, Pumping @ 2.0 BPM with 970 psi Circulating Pressure. Up Wt= 80k / Down Wt =67k. 11:15 15:30 4.25 10,915 11,302 COMPZ RPEQPI FCO P Continue to use 3.5" DP to work down to 11,302' and while rotating and ciruclating @ 3.0 bpm with 1900 ciruclating Psi. Up Wt 80k / Down Wt =67k. 15:30 21:30 6.00 11,302 11,430 COMPZ RPEQP1 FCO P Continue down to 11,430 -ft. Still have to rotate and pump. Mix and pump a 40 bbl Hi -Vis Sweep. Circulate back to surface at 3.0 bpm /2,130 psi. Keep Pipe moving while circulating. Recovered "some" Sand. Continue to Single in with 3 1/2" Drill Pipe from 11,430 -ft to 11,720.-ft. Page 6 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 11,430 COMPZ RPEQP1 FCO P Continue to single in with 3 1/2" Drill Pipe while washing at 3.0 bpm /1,750 psi and slow rotating from 11,430 -ft down to 11,720 -ft. Up Weight = 90K. Down Weight = Top Drive (35K) 01/25/2011 Continue to Clean -Out the Lower "B" Sand Lateral to 14,107 -ft. 00:00 05:30 5.50 11,720 12,431 COMPZ RPEQP1 FCO P Continue to single in with 3 1/2" Drill Pipe to clean -out the Lower "B" Sand Lateral.Current Depth @ 0530, 12,431' and while Rotating @ 10 RPM with 2K Torque. Pump at 3 bpm with 1950 psi circulating PSI. Up Wt =85k Down Wt =70k 05:30 11:30 6.00 12,431 12,431 COMPZ RPEQP1CIRC P Pumping a 80 bbl Sweep and CBU @ 3 bpm, 2150 psi. Seen dirty fluid with fine sand mixed into sweep. 11:30 15:30 4.00 12,431 13,043 COMPZ RPEQP1 FCO P Continue to single in with 3.5" DP. Up Wt =80k / Down Wt =70k, While pumping @ 2 bpm, 950 Circulating Psi. Rotating @ 10 RPM and 2k Torque. 15:30 18:00 2.50 13,043 13,320 COMPZ RPEQP1 FCO P Cleaned Down from 13,043' md. to 13,320' md. Pump a 40 bbl High -Vis Sweep and continue to Single in 3.5" DP while circulating @ 3 bpm, 1660 psi, Rotating @ 10 rpm and 2k Torque 18:00 00:00 6.00 13,320 14,107 COMPZ RPEQP1 FCO P Cleaned Down from 13,320' md. to 14,107' md. Continue to Single in 3.5" DP while circulating @ 3 bpm, 1,500 psi, Rotating @ 10 rpm and 2k Torque 01/26/2011 Continue to Clean -Out the Lower "B" Sand Lateral from 14,107 -ft. to 16,075 -ft. 00:00 04:00 4.00 14,107 14,130 COMPZ RPEQP1CIRC P Pump 40 bbl Hi visc sweep at 4.8 bpm at 4,000 psi while working pipe from 14,107 -ft to 14,130 -ft. Circulate sweep out of the hole, torque came up to 3.5 and rpm's stalled, increase travel speed and regain rotation. Spot 20 bbl .6% by volume 776 Lube pill exit tail pipe as hi visc was returning at surface. Increase rotation speed from 10 rpm to 17 rpm attempting to balance out free torque. CaII Town engineer and discuss increasing safe lube from .6% to 1% by volume. 04:00 15:00 11.00 14,130 16,075 COMPZ RPEQP1 FCO P Cleaned Down from 14,130' md. to 16,075' md. Continue to Single in 3.5" DP while circulating @ 3 bpm, 1,500 -1800 psi, Rotating @ 20 rpm and 2 -3k Torque. Up Wt =106k and Rotating Down Wt =75k. Page 7 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 00:00 9.00 16,075 16,075 COMPZ RPEQP1CIRC P Pump a 40 bbl HI -VIS Sweep and CBU to surface @ 4.5 bpm @ 3,920 psi. Attempt to make connection and well flowing back, monitor and recieved a 13 bbl gain in 10 minutes. MU top drive and circulate BU @ 3 bpm @ 1,700 psi taking sample weights in 500 stroke intervals - no change in wt. Shut down pumping operations - flowed back 28 bbls in 30 minutes. Monitor well for pressure - no gain. Had fluid loss of 940 bbls in 24 hr interval. 01/27/2011 Continue to Clean -Out the Lower "B" Sand Lateral from 16,075 -ft. to 17,381 -ft. Circulate wellbore clean. POOH to 8,718 -ft. 00:00 04:00 4.00 16,075 16,870 COMPZ RPEQPI FCO P Cleaned Down from 16,075' md. to 16,870' md. RIH with push pipe from derrick while circulating @ 3 bpm, 1800 - 2,100 psi, Rotating @ 20 rpm and 2 -3k Torque. Up Wt =130k and Rotating Down Wt =86k. 04:00 08:30 4.50 16,870 16,870 COMPZ RPEQP1CIRC P Pump a 40 bbl HI -VIS Sweep and CBU to surface @ 4.5 bpm @ 3,920 psi. 08:30 11:15 2.75 16,870 17,381 COMPZ RPEQP1 FCO P Continue Cleaning Down from 16,870'md, with push pipe while Circulating @ 3 bpm, 2000 psi, Rotating at 26 rpm with 2 -3k Torque. Up Wt =130k and Down Wt 95k while Rotating. 11:15 14:45 3.50 17,381 17,381 COMPZ RPEQP1CIRC P Clean Down to PBTD @ 17,381' DPMD, Up Wt 138k, Rotating Up Wt =108k. PUH and Stand back 1 Stand. Circulate 40 bbl Hi -Vis Sweep and CBU @ 3 bpm, 2030 psi while Rotating @ 22 rpm and 3 -4k Torque. 14:45 15:00 0.25 17,381 17,265 COMPZ RPEQPI OWFF P Done CBU. Seen large amount of fine formation sand mixed in with the Hi -Vis Sweep. Blow Down Top Drive. Observe Well For Flow. 15:00 15:15 0.25 17,265 17,265 COMPZ RPEQP1SFTY P PJSM.POOH standing back push pipe and drill collars. 15:15 18:45 3.50 17,265 16,075 COMPZ RPEQP1TRIP P POOH standing back push pipe and drill collars. 18 :45 22:00 3.25 16,075 9,009 COMPZ RPEQP1TRIP P Continue to POOH from 16,075 -ft to 9,009-ft. 22:00 22:15 0.25 9,009 9,009 COMPZ RPEQP1SFTY P Held PJSM on pulling wear ring, Setting Storm packer and testing, along with setting storm packer. 22:15 23:30 1.25 9,009 9,009 COMPZ RPEQP1OTHR P MU wear ring pulling tool and Attempt to pull wear ring, unable to slide, attempt to rotate - torquing up to 2k. Made decision to POOH with 3 stands of 3 1/2 DP to 8,718 -ft and retry. RD wear ring pulling tool. Page 8 of 15 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 9,009 8,718 COMPZ RPEQPI PULD T POOH standing back 3 1/2 DP to 8,718 -ft - 125 -ft above Upper Torque master packer at 8,843 -ft. 01/28/2011 Pull wear ring and install test plug. Conduct weekly BOP Test. RIH and wash LEM. POOH laying down 2 7/8 and 2 3/8 work string. Set wear ring. Change out Saver sub and wash pipe packing. PU and MU Divertor Assy and RIH to 164 -ft. 00:00 01:00 1.00 8,718 8,718 COMPZ RPEQP1 BOPE P Pull wear ring and set test plug. 01:00 02:00 1.00 8,718 8,718 COMPZ RPEQPI BOPE P RU test equipment and Fill Void in IA for BOP Test. 02:00 08:00 6.00 8,718 8,718 COMPZ RPEQP1 BOPE P Conduct weekly BOP test. Testing at 250 / 2,500 psi Testing UPR's and Annular with 2 3/8, 2 7/8 and 3 1/2 Test joints. Testing LPR's with 2 3/8 Test joint. 24 hr notice was given on 1 -26 -11 at 14:45 hrs and received a return call at 14:50 hrs on 1- 26 -11. Updated at 18:18 hrs on 1 -27 -11 and Right to witness was waived at 00:30 on 1 -28 -11 by John Crisp. 08:00 08:30 0.50 8,718 8,718 COMPZ RPEQPI PULD P R/D Test Hoses. Pull & Lay Down Test Plug. 08:30 09:30 1.00 8,718 8,718 COMPZ RPEQP1CIRC P Bullhead 100 bbls of 9.0 ppg KCL down IA at 8 bpm, 370 psi to flush 9 5/8" CSG. BD/TD. 09:30 10:15 0.75 8,718 8,654 COMPZ RPEQPI PULD P Lay Down 2 single joints of 3 1/2" DP. Change Out handling Equipment for 2 7/8" PAC. 10:15 10:45 0.50 8,654 8,654 COMPZ RPEQP1SFTY P PJSM. Discuss the Hazard of Laying Down 2 7/8" PAC. 10:45 12:30 1.75 8,654 7,714 COMPZ RPEQP1 PULL P POOH, Laying Down 30 jts of 2 7/8" PAC and offload from pipe shed. 12:30 12:45 0.25 7,714 7,714 COMPZ RPEQP1SFTY P Held PJSM on Changing over Tubing equipment from 2 7/8 to 2 3/8 12:45 13:15 0.50 7,714 7,714 COMPZ RPEQP1OTHR P Change Out handling Equipment for 2 3/8" PH -6. 13:15 20:00 6.75 7,714 0 COMPZ RPEQPI PULD P POOH laying down 2 3/8 PH -6 TBG from 7,714 -ft. and lay down mule shoe. 20:00 20:15 0.25 0 0 COMPZ RPEQP1SFTY P Held PJSM on setting wear ring. 20:15 20:30 0.25 0 0 COMPZ RPEQP1OTHR P Set wear ring in place. 20:30 21:00 0.50 0 0 COMPZ RPEQP1SFTY P Held PJSM on changing out Saver sub and Wash pipe packing. Discussed LOTO of top drive. 21:00 22:30 1.50 0 0 COMPZ RIGMNT RGRP P Change out Saver Sub and Wash Pipe packing 22:30 22:45 0.25 0 0 COMPZ RPEQP1 SFTY P Held PJSM on PU and MU of Divertor BHA 22:45 23:45 1.00 0 164 COMPZ RPEQPI PULD P MU Divertor Assy and RIH to 164 -ft 23:45 00:00 0.25 164 164 COMPZ RPEQP1SFTY P Held PJSM on Changing over to 3 1/2 DP equipment 01/29/2011 Continue to RIH with Divertor Assy from 164 -ft to 8,903 -ft. Latch up and release off Divertor. POOH and lay down Divertor running BHA. PU and RIH with 2 3/8 clean out string to 4,178 -ft 00:00 00:30 0.50 164 164 COMPZ RPEQP1 OTHR P Change over to 3 1/2 DP equipment. Page 9 of 15 ! • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 08:30 8.00 164 8,850 COMPZ RPEQP1TRIP P Continue to RIH with DivertorAssy to 8850'. Up wt = 120K, down wt = 81K 08:30 10:30 2.00 8,850 8,900 COMPZ RPEQP1OTHR P RIH down to 8933', started taking weight. Sat down 10K, PU wt = 120K. Made several attempts up and down and only saw a possible indication of latching diverter into the LEM. Closed annular and bullheaded 30 bbl down the annulus at 8 bpm @ 510 psi. RIH with a weight bobble at 8930' sat down 10K at 8933'. PU and weight broke back from 125K to 120K, repeated up down with same weight. RIH back to 8933' and sit down 5K. Pumping down the DP at 2 bpm, pressure up 1000 psi. PU DP 120K with no overpull, released diverter. 10:30 11:30 1.00 8,900 8,900 COMPZ RPEQP1 CIRC P Prepare rig floor to POOH. Pump 1 volume down the DP at 3.5 bpm @ 3000 psi. 11:30 19:00 7.50 8,900 0 COMPZ RPEQP1TRIP P POOH with DP and diverter setting assembly. 19:00 19:30 0.50 0 0 COMPZ RPEQP1SFTY P Held PJSM on RIH w/ 2 3/8 Clean out string 19:30 00:00 4.50 0 4,178 COMPZ RPEQP1 PULD P PU and RIH w/ 2 3/8 mule shoe and 135 jts of 2 3/8 PH -6 to 4,178 -ft. 01/30/2011 Continue to PU and RIH w/ 2 3/8 Clean out string from 4,178 -ft to 8,929 -ft. Attempt to go out D lat window. Unsuccessful. POOH and lay down 2 3/8 PH -6 work string. RIH w/ 4 1/2 GS Spear assy to 7,602 -ft. Slip and cut drill line. 00:00 03:30 3.50 4,178 7,713 COMPZ RPEQP1 PULD P Continue to PU and RIH w/ 2 3/8 PH -6 Hydril workstring from 4,178 -ft to 7,713 -ft. 03:30 04:00 0.50 7,713 7,713 COMPZ RPEQP1 OTHR P Change over from 2 3/8 equipment to 3 1/2 DP equiopment 04:00 05:30 1.50 7,713 8,929 COMPZ RPEQP1TRIP P Continue to RIH w/ 2 3/8 PH -6 Clean out string on 3 1/2 Drill pipe from 7,713 -ft to 8929 -ft 05:30 07:30 2.00 8,929 8,910 COMPZ RPEQP1TRIP P Sitting down at 8929'. Up wt = 74K, down wt = 54K. Sitting down 5K at 8929 ", attempted to work through dry, pumping down the DP, PU and rotating and then RIH. RIH while rotating (9 rpm @ 1.2K torque) torqued up to 2K max. Unable to get through diverter. 07:30 08:00 0.50 8,910 8,910 COMPZ RPEQP1OTHR P Load remaining 4 -1/2" completion. 08:00 09:00 1.00 8,910 7,713 COMPZ RPEQP1TRIP P POOH with the 3 1/2 DP partof the "D" lateral wash string 09:00 09:30 0.50 7,713 7,713 COMPZ RPEQP1OTHR P Change over floor equipment 09:30 10:00 0.50 7,713 7,713 COMPZ RPEQP1SFTY P Held PJSM on laying down 2 3/8 PH -6 work string. 10:00 18:00 8.00 7,713 0 COMPZ RPEQPI PULD P POOH laying down with 2 3/8 PH -6 Page 10 of 15 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T '' Comment 18:00 18:30 0.50 0 0 COMPZ RPEQP1OTHR P Load pipe shed with 2 7/9 PAC drill pipe 18:30 19:00 0.50 0 147 COMPZ RPEQP1 PULD P PU and MU 4 1/2 GS Spear BHA to 147 -ft. 19:00 21:30 2.50 147 7,602 COMPZ RPEQP1TRIP P Continue to RIH w/ 41/2 GS Spear assy from 147 -ft to 7,602 -ft. 21:30 22:00 0.50 7,602 7,602 COMPZ RIGMNT SFTY P Held PJSM on Slip and Cut of drill line and draw works inspection 22:00 00:00 2.00 7,602 7,602 COMPZ RIGMNT SLPC P Slip and cut 84 -ft. 01/31/2011 Inspect draw works and change out brake pads. Continue to RIH and engage diverter. POOH and lay down same. RIH w/ anchor and PBR assy, spot CI Brine. Latch into Torque master packer at 8,843 -ft. and PT IA at 3,500 psi., Shear out of PBR and POOH laying workstring from 8,820 -ft to 7,494 -ft. 00:00 04:00 4.00 7,602 7,602 COMPZ RIGMNT RGRP P Change out brake bands 04:00 05:00 1.00 7,602 7,602 COMPZ RIGMNTSVRG P Service Rig. 05:00 06:30 1.50 7,602 8,880 COMPZ RPEQP1TRIP P RIH to 8880'. Up wt = 125K, down wt = 90K 06:30 07:00 0.50 8,880 8,880 COMPZ RPEQP1CIRC P Bullhead down the IA 8 bpm @ 600 psi. Pumped 40 bbl 07:00 07:30 0.50 8,880 8,880 COMPZ RPEQP1OTHR P RIH to latch diverter. Up wt = 127K, down wt 95K. RIH sit down 5K at 8914', PU over 5K, wt dropped then PUH 10'. Sit back down, drop ball and pump down DP at 2 bpm @ 800 psi. Pumped 52, press dropped to 200 psi @ 2bpm, circ sub open. PU 5K overpull, PUH to 8880'. 07:30 14:00 6.50 8,880 0 COMPZ RPEQP1TRIP P Blow down TD. PJSM. POOH 14:00 15:00 1.00 0 0 COMPZ RPEQP1RURD P Breakdown and unload Baker equipment. Prep rig floor for running anchor and PBR. 15:00 15:30 0.50 0 30 COMPZ RPCOM PULD P PJSM, PU and MU PBR and anchor assembly 15:30 19:30 4.00 30 8,840 COMPZ RPCOM TRIP P RIH with PBR and anchor assembly on DP from 30 -ft to 8,840 -ft. 125k up wt, 97k do wt. 19:30 20:30 1.00 8,840 8,840 COMPZ RPCOM CIRC P Bullhead 30 bbis at 8 bpm at 520 psi down IA to wash off the top of TorqueMaster packer at 8,843 -ft. Pump 25 bbis of CI 9.0 ppg KCL Brine followed by 44 bbis of 9.0 ppg brine to spot CI brine at top of packer. 20:30 21:00 0.50 8,840 8,847 COMPZ RPCOM PACK P Engage seal assy into packer and latch up. Pull 10k over string weight of 125k. 21:00 22:00 1.00 8,847 8,820 COMPZ RPCOM PRTS P Held PJSM with rig crew and close annular and PT IA to 3,500 psi for 30 minutes - Good test. Pull up to 45k over string weight and shear out of PBR (Top at 8,820 -ft) Pull seals from PBR and Blow down Top drive. 22:00 22:15 0.25 8,820 8,820 COMPZ RPEQP1SFTY P Held PJSM with rig crew on POOH laying down DC's and 3 1/2 DP. Along with off loading pipe shed. Page 11 of 15 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 00:00 1.75 8,820 7,494 COMPZ RPEQP1PULD P POOH laying down Hyrids from 8,820 -ft to 7,494 -ft. 02/01/2011 Continue to POOH laying down workstring. Pull wear ring and set test plug. Change out UPR's from 2 3/8 to 2 7/8 x 5" VBR's. Test annular, UPR's and LPR's with 4 1/2 Test jt at 250/2,500 psi. Pull test plug. PU and RIH with 4 1/2 Completion. 00:00 08:00 8.00 7,494 0 COMPZ RPEQPI PULD P POOH laying down DP from 7,494 -ft to 29 ft. Lay down production sea l assy. 08:00 12:00 4.00 0 0 COMPZ RPCOM OTHR P Pull wear ring and set test plug. Change UPR from 2 3/8 to 2 7/8 x 5" VBR's. 12:00 15:00 3.00 0 0 COMPZ RPCOM BOPE P Test LPR's, UPR's and Annular at 250/2,500 psi. with 4 1/2 Test jt. Pull test Plug. 15:00 19:00 4.00 0 0 COMPZ RPCOM OTHR P RU Itec wire sheave and load all equipment preparation to RIH with 4 1/2 Completion string. Tie Itec wire to sensor. 19:00 19:30 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM with Baker and Centrilift. 19:30 00:00 4.50 0 2,500 COMPZ RPCOM PULD P PU and MU seal assy , guardian sensor, CMU and RIH to 2,500 -ft. 69k Up wt, 62k Dn wt. 0 -ft 68.3 degs., o psi, 4.5k ohms.; 1,000 -ft. 37.1 degs., 470 psi, 5k ohms.; 2,000 -ft. 42.6 degs., 820.0 psi, 5k ohms. 02/02/2011 Continue to PU and RIH w/ 4 1/2 Completion to 8,820 -ft. Locate and Space out. Splice in Itec wire. Load IA with 495 bbls of CI 9.0 ppg 3% KCL. Land hanger. Test IA at 1,500 psi and shear SOV. Penetrator leaking. Wait for slick line. Page 12 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 2,500 8,837 COMPZ RPCOM PULD P PU and MU seal assy , guardian sensor, CMU and RIH to 2,500 -ft. 69k Up wt, 62k Dn wt. PU @ 8,750 -ft 95k Up wt, 65k Dn wt. Make mark on joint 286 two feet from tagged up, pull seals from PBR. Space -out final completion. Lay down joint 286,285,284, and 283. Space -out with four pups 9.81,9.80,3.80, and 1.71 (25.12 TL) PU joint 283. 0 -ft 68.3 degs., o psi, 4.5k ohms.; 1,000 -ft. 37.1 degs., 470 psi, 5k ohms.; 2,000 -ft. 42.6 degs., 820.0 psi, 5k ohms.; 3,000 -ft 45.1 degs, 940 psi, 5k ohms.; 4,000 -ft. 49.2 degs, 1,080 psi, 5k ohms.; 5,000 -ft. 54.1 degs, 1,240 psi, 5k ohms.; 6,500 -ft. 61.4 degs, 1,360 psi, 4.5k ohms.; 7,500 -ft. 66.2 degs, 1,480 psi, 5.1k ohms.; 8,500 -ft. 69.3 degs, 1,560 psi, 1.8k ohms.; Landed with mule shoe at 8,837 -ft and sensor at 8,772 -ft. 68.7 degs, 1,587 psi, 1.6k ohms. 12:00 13:00 1.00 8,837 8,807 COMPZ RPCOM PULD P MU tubing hanger and landing joint. Make final splice on TEC connection. 13:00 15:30 2.50 8,807 8,807 COMPZ RPCOM CIRC T Pump 30 bbls sweep, unable to pump corrosion inhibited fluid, troubleshoot pump issues, found wax plug in vac truck hose. 15:30 17:30 2.00 8,807 8,807 COMPZ RPCOM CIRC P Start pumping 540 bbls of corrosion inhibited seawater @ 5 BPM 540 psi down IA, taking returns up tubing,after 230 bbls away with heavy sand returns, cuttings box full, had to shut down pump and wait for dirty returns truck. Resume pumping remaining inhibited seawater @ 5 BPM. 17:30 19:00 1.50 8,807 8,837 COMPZ RPCOM THGR P Stab seals in PBR at 8,820 -ft., Drain stack, Land hanger. RILDS. Test Upper and Lower Void at 250/5,000 psi. 19:00 19:30 0.50 8,837 8,837 COMPZ RPCOM SFTY P Held PJSM with crew on pressure testing IA and Shearing SOV 19:30 21:30 2.00 8,837 8,837 COMPZ RPCOM PRTS P RU hoses in Cellar and PT at 500 psi, for 10 minutes, Increase to 1,000 psi for 10 minutes, then increase to 1,500 psi for 10 minutes. Then increase pressure to 2,400 psi and shear out SOV valve at 2,062 -ft. Page 13 of 15 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 8,837 8,837 COMPZ RPCOM MPSP P Back out landing joint and set Two way check. Pressure up on IA and test below Two way check - something leaking. Pull Two way check and Install BPV - Something leaking. Drain fluid from stack and found Penetrator leaking 500 psi. Call town engr and discuss options - discuss changing out SOV to Dummy valve and setting plug at 500 -ft. Wait on slickline to being timed out. 02/03/2011 Continue to wait for slick line. BOLDS and Pull hanger to rig floor - inspect penetrator. Re land hanger and RILDS. Test Upper and Lower seals. RU slick line RIH w/ 4.5" WRP and set @ 2,150 -ft. Place catcher on top. Swap out SOV for Dummy valve at 2,062 -ft. Test TBG at 2,500 psi for 15 min. Set BPV and ND BOPE, begin to NU Adapter and Tree. Found Penetrator to be wrong dimensions for Tree designs. ND Tree and NU BOPE. 00:00 04:00 4.00 8,837 8,837 COMPZ RPCOM OTHR T Wait on Slick line crew to rest up as they were houred out. RD Kill line from IA and RU Kill line on BOP stack. Test at 250/2,500 04:00 08:00 4.00 8,837 8,807 COMPZ RPCOM THGR T BOLDS and Pull hanger to rig floor - Inspect Dummy Penetrator, Damaged TEC cable pulling hanger to floor. 08:00 09:30 1.50 8,807 COMPZ RPCOM THGR T Splice TEC cable below hanger, test splice, good test, MU TEC to hanger. 09:30 10:30 1.00 COMPZ RPCOM THGR T Align & land hanger, RILDS. Test upper & lower hanger seals. 10:30 11:30 1.00 COMPZ RPCOM SLKL T PJSM with S/L crew. 11:30 12:00 0.50 COMPZ RPCOM SLKL T RIH w/ 3.70" drift to 2,500 -ft. POOH. Decision made from town to test tubing. 12:00 13:00 1.00 COMPZ RPCOM SLKL T Wait on arrival of tubing plug. 13:00 17:30 4.50 COMPZ RPCOM SLKL T RIH w/ 4.5" Weatherford WRP to 2,150 -ft, set plug, POOH. RIH w/ catcher to same depth, set above WPP on 4.5" GS, POOH. RIH w/ 4.5" OK -1 & 1.25" JDS to 2062 -ft, pull 1" SOV, POOH. RIH w/ 4.5" OK -1 & 1" DV to same depth, set DV, POOH. Rig back S/L and test tubing to 2,500 psi for 10 mins. 17:30 18:00 0.50 COMPZ RPCOM OTHR T Lay down landing joint, Set BPV 18:00 18:30 0.50 COMPZ RPCOM SFTY T Held PJSM with rig crew on ND BOPE 18:30 20:00 1.50 COMPZ RPCOM NUND T ND BOPE 20:00 20:30 0.50 COMPZ RPCOM SFTY T Held PJSM with Centrilift, Vetco Gray and Rig crew on NU TBG adapteer and tree Page 14 of 15 Time Logs Date From To Dur : _ S. Depth E. Depth Phase Code Subcode T Comment 20:30 22:00 1.50 COMPZ RPCOM NUND T NU Tree - found wrong Dummy Penetrator was installed for system design. ND tree and Notify AOGCC at 21:25 hrs for NU of BOPE and shell test at 250 / 2,500 psi. Chuck Scheave returned call. Notify Town Engr. 22:00 22:30 0.50 COMPZ RPCOM SFTY T Held PJSM on NU of 11" 5m BOPE and shell test at 250/2,500 psi. 22:30 00:00 1.50 COMPZ RPCOM NUND T NU 11" 5M BOPE 02/04/2011 Shell Test BOPE at 250/2,500 psi. Pull hanger to rig floor and change out penetrator w/ proper design for Vetco Gray 13 5/8 Well head. Land hanger and PT IA at 2,500 psi for 15 min. - good test. ND BOPE and NU Adapter and tree. Test tree at 250 / 5,000 psi. RU Slick line and RIH and pull DV at 2,062 -ft. RD Slick line. RU LRS and FP w/ 160 bbls down IA. RD LRS and allow well to swap. Lubricate BPV Clean and clear cellar. Dress tree. Pull rig off cellar and remove mats. Clean well location. Release rig 00:00 01:00 1.00 COMPZ RPCOM NUND T Finish NU BOPE 01:00 02:00 1.00 COMPZ RPCOM PULD T Shell test BOPE 250/2,500 psi, ggod test. Pull TWC. 02:00 03:00 1.00 COMPZ RPCOM PULD T Pull hanger to floor, change penerator to correct one, land hanger. RILDS. 03:00 03:30 0.50 COMPZ RPCOM DHEQ T PT IA to 2,500 psi for 30 minutes, good test. (Charted) 03:30 04:00 0.50 COMPZ RPCOM PULD P Set TWC 04:00 07:00 3.00 COMPZ RPCOM NUND P NU tree and test to 250/5,000 psi, good test. Pull TWC. 07:00 10:30 3.50 COMPZ RPCOM SLKL P PJSM. RU HES S/L equipment. RIH w/ 4.5" OK -1 & 1.25" JDS to 2,062 -ft, pull 1" DV, POOH w/ DV. RDMO S /L. 10:30 13:00 2.50 COMPZ RPCOM FRZP P PJSM, MIRU LRS pump truck, test surface equipment to 2,500 psi. Pump 160 bbls diesel down IA @ 2 bpm, let IA U -tube with tubing, prep for rig move. 13:00 13:30 0.50 COMPZ RPCOM PULD P Set BPV 13:30 15:30 2.00 COMPZ RPCOM OTHR P Dress Tree and Prep rig for move. 15:30 16:00 0.50 COMPZ RPCOM SFTY P Held PJSM with rig crew on moving rig off well. Cleaning location and loading out rig mats on trucks. 16:00 18:00 2.00 COMPZ RPCOM OTHR P Clean up well and cellar area, Toad out rig mats. Release Nordic Rig 3 at 18:00 hrs on 2 -4 -11 Page 15 of 15 • yam. ` w, +[~` '; <` ~~ ~ ~• ~ ~ ~, ,r-~: • tt~ Y ~. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc MAR 2 ~ 2010 STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COMMISS N ORT OF SUNDRY WELL OPERATIONS ~. operati n ^ Repair w ell ^ Plug f~rforations Q Stimulate ^ Other Qrj Failed ESP to Gaslift ~ er sin Pull Tubin g ^ g Q F~rforate New Pbol ^ Waiver ^ Time 6ctension Q Change Ap 'roved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Name 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q 13cptoratory ^ 206-109 3. Address: Stratigraphic [~ Service ^ ~ API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23316-60 7. Property ~signati 8. Well Name and Number: ADL 25662 & 380058 ~1J-137L1 9. Field/Pool(s): Kuparuk River Field'/ West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 16840 feet Plugs (measured) None true vertical 3361 feet Junk (measured) None Effective Depth measured 16825 feet Packer (measured) 8188 true vertical 3361 feet (true vertucel) 3315 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 20 80 80 0 0 SURFACE 3743 13.375 3773 2175 ~ ..",: _. ..0 0 INTERMEDIATE 9406 9.625 9434 3529 0 0 D-SAND LINER 7691 4.5 16827 3361 0 0 Perforation depth: Measured depth: 0 True Vertical De the 0 1 Tubing (size, grade, MD, and TVD) 3.5, L-80, 8189 MD, 3301 TVD Packers &SSSV (ty~e, MD, and TVD) PKR -'D' sd HR liner setting sleeve @ 9136 MD and 3474 TVD SSSV -None 11. Stimulation or c~Jment 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 176 157 Subsequent to operation 574 113 15 758 192 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory [j Development ~ Service Well Status after work: Oil Q Gas ^ WDSPL Daily Report of Well Operations X GSTOR ^ WAG ^ GASINJ ^ WINJ ^ SPLUG Q 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 N/A Contact Bob Christensen/Darrell Humphrey Printed Name R ert-6- Christ sen Title Production Engineering Specialist Signature __ Phone: 659-7535 Date ~ ~ ®~ ~ E ~!`° ` ~~.z.6~0 Form 10-404 Revised 7/2009 Submit Original Only • • 1J-137L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/15/10 Attempt To Restart ESP Unsuccessful - Downhole Short 03/04/10 03/05/10 03/06/10 03/0/10 PULLED SLIP STOP FROM 8019 CTMD WITH BAKER 2.31 G-SPEAR, 2ND RUN PULLED STANDING VALVE FROM CMU AT 8020 CTMD. WELL IS FREEZE PROTECTED, RTN IN A.M. TO PULL BLANKING PLUG AND OPEN CMU. PULLED 2.75 XN BLANKING PLUG FROM 8117 CTMD, 2ND RUN OPENED CMU AT 8030 CTMD. WELL IS FREEZE PROTECTED AND READY FOR S/L. SET CATCHER & PULLED SOV @ 1987' RKB. REPLACED WITH GLV. PULLED CATCHER. COMPLETE. SET TEST TOOL @ 2050' SLM, BELOW GLM @ 1987' RKB. LOADED & TESTED TBG TO 1000 PSI, CONFIRMED GLV IN POCKET. PUMPED 120 BBL DSL DOWN TBG, IA INCREASED FROM 290 TO 300 PSI; TBG @ ZERO AFTER PUMP pOWN. JOB SUSPENDED. r KUP ~ 1J-137L1 COI'IOCO~II~~lpS Well Attributes ax An le & MD TD A1~J~ _7 in Wellborn API/UWI Field Nama Well Statue Incl (°) MD (ftNO) Act Btm ((tNB) 500292331660 WEST SAK PROD 95.69 10,770.28 16,840.0 Comment H23 Ippm) Data Annotatlon End Data NBt3fd (H) Rlg Release Data ••• SSSV: NONE 100 7Y2/2007 Last WO: 3/12/2009 32.00 10/1/2006 Wall Confl:Honzonbl-1J-037L7221/201 Schemata:- Na 02:11:15PM Annotation Depth (RKB) Entl Dale Annotation Last Motl By End Date Last Tag: Rev Reason: GLV C/O, Set CAT SV Imosbor 2/21/2010 Casin Strin s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Caning Oeacrip5on String 0... String ID ... Top (ftl(B) Set Depth (f... Sat Depth (TVD) ... String Wt... String ._ String Top Th rtl 0.SAND LINER 4 1/2 3.476 9,135.7 16,827.0 3,360.8 11.60 L80 HANGER, 22 Liner Details Top Depth (TVD) Top Incl Noml... CONDUCTOR, o eo Top (RKB) IRNB) (°) I tem Deacriptbn Comment ID (In) - 9,135.7 3,474.1 92.26 S LEEVE Baker"HR"Liner Setting Sleeve,5112" ID 5.01" 5.010 EsP MANDREL, 9,192.0 3,471.9 91.57 X O BUSHING 5-1/2" H521 x 4-i/2" BTC Crossover Bushing ID 3.9 3.960 1 9B7 16,792.6 3,360.4 89.20 X O XO Sub 4 1Y2" BTC X 3-1/2" BTC 2.992 SURFACE 16,794.0 3,360.4 89.20 B ENT JT 3-112" BTC, Bent Joint ID 2.602" 2.992 , 3'773 Perforations $ Slots SLIPSTOP, B,Otfi Top (TVD) Btm (TVD) Shot Dena VALVE, 8015 Tap (f0(B) Btm (RKB) (RNB) (ftNB) Zona Date lah... Type Comment SLEEVE-c, 9,197 14,564 3,469.7 3,376.2 WS D, 1J-137L7 9/22/2006 32.0 SLOTS ALL PERFS IN WELLBORE: e.o10 Alternating solid/slotted pipe - 0.125"x2.5" @ 4 droumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends S cnuGE, ,aSa iq,6gp 16,793 3,375.5 3,360.4 WS D, 1J-137L7 9/22/2006 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe - PLUO, 6,110 0.125"x2.5" @ 4 droumferential NIPPLE, B,11D PUMP suB, adjacent rows, 3" centers staggered ' e,11n ~ -~ rron-slotted ends 18 deg,3 DISCHARGE, ESP PUM~ Notes: General 8t Safe 5,120 cAS se aramr Entl Dete Annotation , v 6,133 SEAL 8 136 ?-' 1(11312006 NOTE: MULTI-LATERAL WELL: 1J-137 (8-SAND), 1J-137L7 (0.SAND) , , swrvEL.5,113 ESP MOTOR 819/2008 NOTE: VIEW SCHEMATICw/9.OREV , 9,i5D ~ _ SENSOR 3/17/2009 NOTE: ESP WORKOVER w/Y-BLOCK ESP INSTALL , 6,175 - PLUG 8 177 _ , , WLEG, 0,185 D-SAND LEM, 8,813-9056 0-SAND HOOK HANGER, 8,9/8-9,165 TERMEDIATE, 2&9,131 SLOTS, 9,197-14,561 SLOTS, 9,027-17,331 SLOTS, 71,680.16,793 D-SAND LINER, 9,136-16,827 TO 11J-13]L1), 16,890 B SAND - LINER, 9,01317,376 Nlandrel Details Top Oepth lop Port (TVD) Intl OD Valw Latch 5lze TRO ftun Stn Top (ftlta) l~el (`) Maka Model (inl serv TYPa TYPe (l^) (pail Run Date Com... 1 1,987.4 1,703.1 63.77 CAMCO KBMG 1 ESP SOV BK-5 0.000 2,000.0 2/1 71201 0 L . ~ Page 1 of 1 Maunder, Thomas E (DOA) _ _ _ _ _ _ _ __ _ From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Tuesday, April 28, 2009 8:59 AM To: Maunder, Thomas E (DOA) Subject: RE: 1J-137 (206-108) and 1J-174 (207-143) Attachments: 1J-174 Multi-lat RAM.pdf; 1J-137 Multi-lat drawing.pdf; Centrilift Y-Tool Schematic Draft.pdf Tom, I didn't include the profile view schematics because they haven't been updated yet. Those schematics were built by Baker Oil Tools, and they've kept the actual Visio drawing and only provide us with the pdf version, so we can't edit them ourselves. Attached are the schematics we have, but once again, they aren't up to date. 1 J-174 The completion shown is correct, except for the depths of the ESP and GLM's. 1 J-137 The completion shown is completely wrong downsized to 3-1/2" tubing. ~ Brett ~Packer ~Drill'ing eZ'WelCs `Worf~ver~Engineer `Work# (907) 265-6845 Celf# (907) 230-8377 ~~ i ~~~ E--C~--~~~- c~J~~ It now has an LEM installed and a Y-block ESP completion s3>~ky~~i¢1J:CE~~r ~~x~,.1 .f~ C.°~ ~U6t~ _ _ _ _ _ _ . _ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, April 28, 2009 8:19 AM To: Packer, Brett B Subject: 1J-137 (206-108) and 1J-174 (207-143) Brett, I am reviewing the 404s for the recent workovers on these multi-lateral wells. Would you please provide drawings that show the well in a"horizontal formaY' such as are included in the permit to drill? The straight drawings are somewhat difficult to relate to the operations report. I also request that horizontai drawings be included whenever a workover is done on a multilateral well. You can send the drawings via email. Call or message with any questions. Thanks in advance. Tom Maunder, PE AOGCC 9/30/2009 Insulated Conductor, 20" 94iF K-55 x 34" 0.372 WT +I- 80' ~ Wellhead / Tubing / Tree: 13-3I8" x41/2", 5,000 psi ~~O~O~'"'~~ West Sak Hybrid Producer 1J-137 2082' MD, 1741' ND - GLM, Camco, 4-112" x 1" KBMG (66 deg) Dual Lateral Completion 7980' MD, 3266' ND - GLM, Camco, 41/2" x 1" KBMG (77 deg) °'S ~ a-s~a~• ceg~~9 snoe, ~ Q Ill [J l~t~~ 68#, L-80, BTC set ~ 3773' MO, 2775' ND 8199' MD, 3317' ND - BoHom of Motor Centrolizer ~ CentreliH 478 HP KMHFER with FC6000 Pump Tubing String 4112" 72.6#, L-80, IBTM 3.958" ID, 3.833" Drik 897T MD • S12" %9-5/8" Motlel'B' HOOK Hancer ~PZ Rework ~equires PZ LEM) B-sand Window at 8927' MD (79 deg) 'D' Sand Lateral 412" 11.6R, BTC, LAD Sbtted and Blank Liner ~ 8997'MO-4-712"PayZoneECP ~ 7"X9•5/8"ZXP ~~~ Llner7opPacker ~ T' X 9518" Flex Lock 9013' MD- Liner Hanger / Packer Liner Hanger r~xmwy 90d5' MD-Casing Sealbore Receptaele, 30' z 0.75" ID 3•712" Guitle Shce ~ ~ --~` ' '~~ ~ ~~~~~~ "~~~ ~ 41/2" Casing Shoe, 77.6#, L-80 BTCM Set ~ 16827' MD, 3357' ND 9165' MD - 5-112" Tieback Sleeve 9186' MD - BoHom ot 4-1/2" bent joint shoe 'B' Sand Lateral 4112" 11.6#, BTC, L-BO SblMtl and Blank Liner 41/2" Eccenhie Guide Shoe XY6XE5 Bxker Oil Tools Eauinment Specifications 5-1/2" X 9-5/8" HOOK Hanger* Mainbore Drik: 7.00" I Mainbore Drift, with diverter: 6.25" ~~~. Lateral Drift, no diveRer o~ LEM: 6.88" I Latenl Drik, wl diveRer, no IEM: 4.50" LaterellMainbore Diverter OD: B.50" 4-1/2" Lateral Entry Module Mainbore Dritt: 3.68" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drik, wl coil diverter; 3.00" OD of DiveRer and Sleeve: +l- 3.60" Diverter and 3leeve Length: +I-19' 'These. dima are apecific to tl~e PZ rewarked equipment. -~~ .~ ~ ~- ~~~ ~~~ -~ ~ 4-012"CasingShoe,tt.6#,L-SOBTCM 9-5/8" Casing Shoe, 40.Oq, L-80 BTC Set LAi 17376' MD, 3441' ND ~ 9434' MD, 3530' ND (85 tleg inc) ~ ~J m Baker Nughea 21105. T~la Aoc~menl may not be reproEUCeA or Olsirl0uletl, in whok o~ in part in any form ar by any meanc elxtronic or mechaniul, including phofocopying, reeording, o~ by any iniormation sbeage a~W retrieval sysNm now Mown or hereatter inwnteC, withouf wrkMn permisaion trom Baker Hughea Inc. -.~J ~ ~ 5~~. 'F ~ ~ ~ ~~~ a ~ ~ BAKER NU6NE5 Centrilift CentriliftAlaska 9.1-137 9-5/8" ESP BYPASS SYSTEM LENGTH ID OD OD ID LENGTH FT IN ~N DESCRIPTION DESCRIPTION IN IN FT 8.68 9.63 9•5/8" CASING 47q 3•112" 9.3# EUE Prod. Tubing 3.50 2.99 6.00 2.99 4.50 Pup Joint 6 Ft ; 3!. 3~1/2" 9.3# EUE Box Up '~, j 3-112" 92# New Vam Pin Down ~i :~ 9-5/8" Y-Tool Assembly 8.25 2.99 2.16 ~~ ! 3-1/2" 9.2# New Vam Prod } ~~ 3-V2" 92# New Vam Pump i . ~ , ? ; 3.3" SA Bypass i~ i{ .89 .63 .63 ~ i 275" Bypass Nipple Standard ' ~ +i i 'i '' (Blanking Plug Insfalled) ! !! ~ ! i Pump Sub 10 F~ 375 2.99 10.00 375 2.44 3.63 Teleswivel 20" Stroke ! J 31/2" 92# New Vam Pin 2-7/8" PT-X Pin ~ i j j&1/2" 9.3# EUE Pin i', ~ 0.40 N/A 8.50 ~ : 2-7/8" Bypass Neck Clamp ~ i ;~ ~ j Dlscharge Head 513 Series ~ 5.13 N/A .53' Clip MLE ? I ~y # li ~i Centdlift Pump 538 Series G31 /A 11.02' 0.40 N/A 8.50 2-718" Bypass Neck Clamp [ i{ j i CentriliN Clip MLE 1 jj Gas Separator 5.13 N/A 3.1' 7 ~~ ~ ~ Centrilift Upper ~ ~ Seal 513 Series 5.73 NIA 6.89' 0.40 NIA 8.50 2-~18" Bypass Neck Clamp Clip MLE ! ~ 3 Cenirilifl Lower a ~~ Seal 513 Series 5.13 N/A 6.93' i I I ~ 55' 2.44 2.88 By pass T; I ;~ Centrilift Upper 2-7/8" 6.4# PT X ;; Mo~or 562 Series 5.62 NIA 22.5' Box Up x Pin Down ~ i~ ~ jj ~ i CeMrilift ~i': Sensor i~ 4.375 N/A 2.10' 0.40 NIA 8.50 2-718" Bypass Neck Clamp i I Clip MLE i I i Dummy Neck 525 N/A 0.75 075 2.37 4.00 Re Entry Guide ii ~ j 2-7/8" PT-X Box Up 9 ~ i ~ ~I~~Q • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~~aska ~~' ~ ~~~ ~~~~ Cpmmission REPORT OF SUNDRY WELL OPERATIONS AhCharaue ~. Operations Performed: Abandon ^ Repair Well ^~ Piug Pertorations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^~ Perforate New Pooi ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ ' Exploratory ^ 206-109 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23316-60 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1J-137L1 8. Property Designation: 10: Field/Pool(s): ADL 25662 & 380058 Kuparuk River Field /WestSak Oil Pool ° 11. Present Well Condition Summary: Total Depth measured 16840' feet true vertical 3361' feet Plugs (measured) Effective Depth measured 16825' feet Junk (measured) true vertical 3361' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 3745' 13-3/8" 3773' 2175' PRODUCTION 9406' 9-5/8" 9434' 3530' LINER 7689' 4.5" 16825' 3357' Perforation depth: Measured depth: slotted liner 9197'-14564' , 14680'-16792' true vertical depth: 3472'-3376', 3776'-3360' n,A ~,,. ~, ~ "K, ,n ~~~ 1 ~ ~ ~ ~ Tubing (size, grade, and measured depth) tubing in main wellbore, , MD. Packers &SSSV (type & measured depth) no pkr no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 320 64 22 -- 212 Subsequent to operation 319 40 249 -- 218 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Brett Packer @ 265-6845 Printed Name Bre ~ Packe Title Wells En Ineer / ~ L~ ~ g % ~~~ !v~C Signature Phone: 265-6845 Date 1 Pre r Sharon All Drake 263-4612 Form 10-404 Revised 04/2006 -,,,_ 1a't~ `f•ZS~~ Submit Original Only ?~~~ Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 28, 2009 9:02 AM To: 'Packer, Brett B' Subject: RE: 1J-137 (206-108) and 1J-174 (207-143) Brett, OK, so are the BOT drawings in the process of being updated? For me and other users not so intimately involved with these wells, the straight drawings are somewhat confusing to use. I look forward to your reply. Tom From: Packer, Brett B [mailto:J.Brett.Packer@conocophillips.com] Sent: Tuesday, April 28, 2009 8:59 AM To: Maunder, Thomas E (DOA) Subject: RE: 1J-137 (206-108) and iJ-174 (207-143) Tom, I didn't include the profile view schematics because they haven't been updated yet. Those schematics were built by Baker Oil Tools, and they've kept the actual Visio drawing and only provide us with the pdf version, so we can't edit them ourselves. Attached are the schematics we have, but once again, they aren't up to date. 1 J-174 The completion shown is correct, except for the depths of the ESP and GLM's. 1 J-137 The completion shown is completely wrong. It now has an LEM installed and a Y-block ESP completion downsized to 3-1/2" tubing. Batt ~Pac~r ~DriQing s~'WeQs ~Wor~~yrer Engineer `Work# (907) 265-6845 CeIC# (907 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, April 28, 2009 8:19 AM To: Packer, Brett B Subject: 1J-137 (206-108) and iJ-174 (207-143) Brett, I am reviewing the 404s for the recent workovers on these multi-lateral wells. Would you please provide drawings that show the well in a "horizontal format" such as are included in the permit to drill? The straight drawings are somewhat difficult to relate to the operations report. I also request that horizontal drawings be included whenever a workover is done on a multilateral well. You can send the drawings via email. Call or message with any questions. 4/29/2009 Insulated Conductor, 20" 94# K-55x34" 0.312 WT +l- 60' Wellhead (Tubing (Tree: 13-3/8" x 4112", 5,000 psi Tubing String 3-t12" 9.3#, L$0, EUE Brd 2.992" ID, 2,867" Drift 1987' MD-GLM, Camco, 3-112" a 1" KBMG 13-318" Casing Shoe, 68tY, L-60, BTC set LID 3773' MD, 2175' ND 8018' MD dMU Sliding Sleeve. J-Y, x 2.87J DS Profile 8064' MD -A-WNI Discharge Pressure Sub MD-9-618" y-Tpol Assembty !) 2-7/8" Bypass Neck Clamp, Clip MLE ~ Flush Joint Bypass Tubing, 2-718" 6.4#, L$0 - 8189' PT-X Box up i ConocoPhillips West Sak Hybrid Producer 1 J-137 Dual Lateral Completion WO 09 8176' MD -Bottom of Motor Centralizer, \ CentrahR J04 HP KMHG, TC{SP 8843' MD -TorqueMaster Packer iral EAntcry^MTo~d,`ule (LEM( ~.L.~ /~ 9-518" TorqueMaster ` Packer 3.562" DB Nipple Orienting Profile Automatic Alignment of LEM - Positive Latching Collet Indicates Correct Location ~'- Seal Bore for Lateral Isolation -J.688" ID - Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - J.688" ID Isolation Seal Asembly 4.T5" Seal OD 3.875" Seal ID 2' Length ~' eaker Hu9hec 2005. This document may not be repr any means electronic or mechanical. including pholoc ren,eval syst m now known or herealter Inventetl, wal 8876' MD - 3.750" DB Nipple 8904' MD - Lakral Entry Module (LEM) Orkn6ng Prolile. ' - ~: ~~~ ~. 1 \ 'D' Sand Lateral ~~~\\~\~\',~ ~ 6-sand Window ~4 R`~".. at 8921' MD (79 deg) 4-t/2" 11.8%. BTC. L$0 Sbfted all Blank Liner 8997' MD -4112" PayZone ECP ~ BAKER As Completed Raker nil Tnnls With Diverters and Isolation Lateral Access Diverter Lateral Isoktbn Diverter GS Running Tool String Installed Installed (3.00" Lateral Drill) 1250" ID Mainbor e Drift) _ 'GS' Prolile for - Coll Connector !~ Running/Retrieving ~-s (7.00' Length) Snap INSnap Ou[ ~ /~Posltive Locating~ .-Back Pressure Valve Collet (1.60' Length) Lateral Isoktion -'' "-Flow-Thru Swivel Seals (1.25' Length) f Lateral Diverter -Hydraulic Ramp Disconnect olation) Mainbore- " -~ I (1.50' Length) s plverter Sleeve __ --GS Spear " ' i Lateral Isolation -"~ (t.50 Length) S l 6.85R Approx ea s i ~-- nay be required In hphly deviated 19' Diverter Length 19' Sleeve LergM 3-1/2" Guide Shce 4112" Casing Shoe, 11.6p, L-80 BTCM Set ~ 1682T MD, 3357' TVD Model'B' HOOK Hanoer )PZ Rework, requires PZ LEM) 8948' MD - 3.562" 7" X 9-5/8" ZXP C Liner Top Packer 7" X 9-5/e" Flex Lock 9013' MD- Liner Hanger I Packer Liner Hanger Assembly ~/ 9046' MD-Casing Sealbore Receptacle, 20' x 4.75" ID or distributed, in whole or in part. In any loan or by cording, or by any Inronnarion storage and rten permisrbn Irom Baker Hughea Inc. 2006 Wesl Sak Dual Laferal Completion -Injector wabn aD.: 1 16.2008 wn ay Ian Toomey ~ 9165' MD - 5-1/2" Tieback Sleeve 9786' MD - Bottom of d-1I2" bent joint shoe 9056' MD -Bottom of Seal Assembty 0.75" Seal OD, 3.875" ID 'B' Sand Lateral 4112" 11.6#, BTC, L$0 Sbtted 4/12" Eccenhlc arW Bknk Liner Guide Shce Eauioment Specifications 5-112" X 9-518" HOOK Hanger Mainbore Drih: 7.00" Mainbore DrHt, whh diverter: 6.29" Lateral Drift, no diverter or LEM: 4.86" Lateral Drill, w/diverter, no LEM: 4.50" LaterallMainbore Diverter OD: 6.50" 4-112" Lateral Entry Module Mainbore Drift: 3.68" Mainbore Drrft, w/ isolation sleeve: 2,50" Lateral Drift, w/ coil diverter: 3.00" OD of Diverter and Sleeve: +/- 3.60" Diverter and Sleeve Length: +I-19' ~~~ 4112" Casing Shoe, 11.6#, L-80 BTCM 9-SIB" Casing Shoe, 40.0#, L-80 BTC Set ~ 17376' MD, 3441' TVD ~ 9434' MD, 3530' ND (85 deg inc) • • ConocoPhillips APB ;nom.. irV,? ESP MANDREL. 1,98J GAUGE, 8,O6a - - - NIPPLE, 8.110 PUMP SUB, \ 8.110 DISCHARGE, 8,120 ESP PUMP, 8,120 iAS SeVarator. 8,133 SEAL, 8,138 SW IVEL. 8.113 ESP MOTOR, 0,150 ~ SENSOR, 8,1]5 -"" "~ PLUG, 6,177 -- WLEG, 8.188 - D-SAND LEM. 8.843-9.056 D-SAND HOOK MANGER, 8.918-9,186 tTERMEDIATE. 289,430 SLOTS, 9.19710.560 SLOTS. 9q2]-17,331 SLOTS, 10,680'16.793 DSAND LINER, 9,13616.827 TD (1 J~13]L1), 16,800 B-SAND LINER, - _ 9,01317.376 KUP _ Vell Attributes 'ellbore APVU WI Field Name - WeII SL 500292331660 WEST SAK (PROD ent ~H25 (ppm) (Date A SSV: NONE 100 1/1/2009 L. nnotation Depih (ftKB) (End Date (Annotation ast TaD: Rev Reason: WO Top (NKB) IttKB) (°) Item Description Comma« ID (in) 9,135.7 3,474.1 92.26 SLEEVE Baker "HR" liner Setting Sleeve, 5 1/2" ID 5.01" 5.010 9,192.0 3,471.9 91.57 XO BUSHING 5-1/2" H521 z 4-12" BTC Crossover Bushing ID 3.9 3.960 16,792.6 3,360.4 89.20 XO XO Suh 4 1/2" BTC X 3-112" BTC 2.992 16,794.0 3,360.4 89.20 BENT JT 3-1/2" BTC, Bent Joint ID 2.602" 2.992 Perfora tions 8 Slots sn« Top (ftKB) ~~ B1m (ftKB) ~. Top (TVD) Btm (TVD) i Dens (ftKB) (kK8) Zone Data I (sh... Type Comme« _ 9,197 14,5641 3469.7 3,376.2 WS D, 1J-137L7 9/22/2006 ~ 32.O,SLOTS Alternate slotteNSOlid pipe I' 14,680 16.793 3.375.5 3,360.4 WS D, 1J-137L7 9/22/2006 32.O~SLOTS Alternate slotled/solid pipe Notes: General 8 Safet End Dater Annotation _ ___ _ _ iD/3/2006 NOTE MULTI-LATERAL WELL: 1J-137 (B-SAND), 1J-137L1 (DSAND) 8/9/2008 NOTE VIEW SCHEMATIC w/9.0 3!12/2009 NOTE: ESP WORKOVER w/V-BLOCK ESP INSTALL - Va terv Ty SO Port Ive Latch I Sire '.TRO Run pe Type (inl (psi) Run Date C_omm... V BK-5 0.000'( 2,000.0 3/12/2009 ~~~~~ ~~i~li~s Time Log & Summary ~~~,~ffre~~ ~~e ~~,,a,~n~ Report Well Name: 1J-137 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/5/2009 7:00:00 AM Rig Release: 3/13/2009 11:59:00 PM Time Logs __ T Comment Date From To Dur S. Depth E. Depth Phase Code Subcode 3/05/2009 _ 24 hr Summary Pulled rig off well 1J-107, moved rig mats to 1J-137, pulled rig over well and set up tanks, shacks., bermed in cellar, RU hardline., loaded pits, pulled BPV, pumped 6°1° KCUSeawater and killed well, ND tree, NU BOP, started BOP testin . 04:00 07:00 3.00 MIRU MOVE MOB P Relocate rig mats onto 1J-137 and double stack, move rig from 1J-107 and spot over well 1 J-137. Accepted Nordic 3 ri 0700 hrs 3/512009. 07:00 08:30 1.50 MIRU RPCOM RURD P Berm up. RU hardline. Spot cuttings box. 08:30 10:00 1.50 COMPZ RPCOM RURD P RU lubricator, pull BPV. 10:00 10:30 0.50 COMPZ RPCOM RURD P Swap out ESP cable spool using crane. 10:30 13:00 2.50 COMPZ WELCTL KLWL P PJSM. Pressure test lines to 2500 psi. Check pressures. OA- 150 psi IA- 80 psi Tbg- 10psi. Bleed pressure off. Pumped 500 bbls 8.8 ppg Seawater w/6% KCL down tubing taking returns to kill tank. Returns approx. 50% .Pumped at 110 psi w/5BPM. Shut down to empty kill tank. IA pressure 90 psi. Ri on hi hline ower at 11:30 hrs. 13:00 15:00 2.00 COMPZ WELCTL KLWL T Attempt to empty kill tank, valve frozen. RU heater to valve to thaw out. Pulled 290 bbls. 15:00 17:00 2.00 COMPZ WELCTL KLWL P Pumped another 300 bbls 8.8 ppg Sea Water w/trace amount of returns. Shut down, monitor well, still had 80 psi on IA. Pumped 100 bbls Sea Water down IA. Shut down. Blow down lines. Bleed press. Monitorfor 15 min. 0 press. on IA and tubin . 17:00 20:00 3.00 COMPZ WELCTL NUND P Set BPV, ND tree, install test dart. 20:00 22:00 2.00 COMPZ WELCTL NUND P NU 13 5/8" BOP. 22:00 00:00 2.00 COMPZ WELCTL BOPE P RU and test BOPE. Tested all BOPS at 250 Low - 2500 Psi High, AOGCC Rep Jeff Jones waived witnessing of test 16:00 on 3-4-2009. 3/06/2009 Cont BOPE test, pull test dart and BPV, MU landing jnt, BOLD's, unseat hanger, flush IA with hot seawater, POOH LD 4 1!2" ESP com letion e ui ment ko 675'. 00:00 03:30 3.50 COMPZ WELCTL BOPE P Cont testing ROPE at 250/2,500 psi. RD test a ui merit. Page 1 of 7 i • Time Logs Date _ From To Dur _S. De th E. D_e~th Phase Code Subcode T Comment__ _ _ 03:30 04:30 1.00 COMPZ RPCOM OTHR P Pull test dart and BPV, install landing jnt with isolation sleeve, BOLD's, un-seat hanger at 170K, pull and stagejust underannuiar, up wei ht 90K. 04:30 06:00 1.50 COMPZ RPCOM CIRC P Pump 450 bbls hot 6% KCUSeawater down IA to flush and clean completion string ay 5 bpm - ICP 150 si. FCP 240 si. 06:00 07:00 1.00 COMPZ WELCTL CIRC P Shut down pump, monitor well. IA on vac. Tbg press 20 psi. Pumped 50 bbls hot 6 % KCL/Seawater down tubing @ 5 BPM 190 psi. Shut down monitor well 07:00 07:30 0.50 COMPZ RPCOM PULD P LD tubing hanger and landing jt. 07:30 00:00 16.50 8.,187 675 COMPZ RPCOM PULD P POOH laying down 4 1/2" tubing, removing clamps and spooling up ESP cable from 8,187' to 675', strapping tbg and jewelry before offloadin i eshed. 3/07/2009 Cont POOH and break down ESP pump assembly, off load pipeshed, clean rig floor, install wear ring, PU and RIH with snozzlator assembly to a total depth of 9,065', POOH LD washtool assembly, clean floor., pull wear rin , MU outer and inner LEM assembl . 00:00 01:00 1.00 675 0 COMPZ RPCOM PULD P Cont POOH LD tbg and ESP assembl , stra tb . 01:00 03:30 2.50 0 0 COMPZ RPCOM PULD P Break down and LD pump assembly. Recovered 136 Cannon Clamps, 9 of 15 SS Bands, 3 Protectrolizers, and 2 Flat Guards. 03:30 05:00 1.50 0 0 COMPZ RPCOM OTHR P Clean rig floor, off load tbg and jewelry, bring in Baker tools, set wear rin . 05:00 11:00 6.00 0 8,879 COMPZ RPCOM TRIP P PJSM, PU and MU Snozzlator wash tool assembly. RIH on 3 1/2" drill pipe to +!- 1000', pumped thru Schozzlator 2 5 BPM w(1350 psi to confirm not plugged. Continue to RIH to 8879' MD, Obtained pump rates and pressures. 3000 psi @ 7 BPM. U wt 115K Dwn wt. 43K. 11:00 12:00 1.00 8.,879 9,065 COMPZ RPCOM WASH P Pumped down tubing @ 3000 psi @ 7BPM taking full returns to pits. Washed down from 8879' down past the D-lateral hook hanger at 8917' MD, through the B-lateral ZXP packer @ 9013' MD to the bottom of the B-lateral casing seal bore receptacle 9065'. 12:00 13:00 1.00 9.,065 9,065 COMPZ RPCOM CIRC P After washing clean, circualted 1 1/2 Bottoms up to clear up gas and oil. Shut down um s, well talon fluid. 13:00 13:30 0.50 9.,065 8,520 COMPZ RPCOM TRIP P POOH w/5 stands of 3 1/2" workstrin standin back. 13:30 14:30 1.00 8.,520 8,520 COMPZ RPCOM RGRP P Slip & Cut drill line. 14:30 20:00 5.50 8,520 1,660 COMPZ RPCOM TRIP P Pump dry job and continue to POOH standin back workstrin from 7,490'. ~_ Page 2 of 7 • Time Logs _ __ __ Date From To Dur S. De th E. De th Phase Code Subcode T Comment _ 20:00 _ 21:30 1.50 1,660 0 COMPZ RPCOM PULD P LD washtool assembly. 21:30 22:00 0.50 0 0 COMPZ RPCOM OTHR P Clean up rig floor. 22:00 22:30 0.50 0 0 COMPZ RPCOM OTHR P Pull wear ring. 22:30 00:00 1.50 0 224 COMPZ RPCOM TRIP P PU and MU LEM and TorqueMaster Packer assembl . 3/08/2009 RIH 1 stand, perform shallow test, cont RIH with LEM on 3 1/2" DP at 30 fpm to 8,817', orient LEM, cont ease in hole to 8,917' and set LEM., test IA x packer, POOH LD 86 ~nts DP, POOH rack back 60 stands DP. 00:00 00:30 .0.50 224 320 COMPZ RPCOM TRIP P Cont RIH with LEM assembly on 3 1/2" DP from 224' to 320'. 00:30 01:00 0.50 320 320 COMPZ RPCOM DHEQ P Perform shallow test of MWD. Cont rack and tall 2 3/8" PAC pipe. 01:00 01:30 0.50 320 320 COMPZ RPCOM OTHR P Install wear ring. 01:30 11:30 10.00 320 COMPZ RPCOM TRIP P Cont RIH on 3 1/2" DP at 25 to 30 fpm with LEM assembly to 50' above Hook Han er 8837'. 11:30 14:30 3.00 COMPZ RPCOM PACK T Circulated thru MWD to obtain LEM window orientation, could not get readin s to obtain tool face. 14:30 15:30 1.00 COMPZ RPCOM PACK P Ran in w/ stand 87 & 88 thru Hook and into liner top. PU single and slacked off, observed seals dragging. Up wt 128k Dwn wt 45K. Tagged @ 9052', PU, slacked back off and tagged @ 9054', slacked off and put 20K down. Pullled up off and was not latched. Pulled up out of seal bore, rotated 1/2" turn, worked torque down several times. Slacked off and tagged, put 20K wt down. Pulled back off and still not latched. Slacked back off again and observed LEM latching in @9055', slacked off 20K wt dwn. PU 10K overpull to confirm latched ih. Slacked back off to neutral and dropped settin ball. 15:30 16:30 1.00 COMPZ RPCOM PACK P Blow down TD. NU head pin. Pumped ball on seat w/48 bbls to get on seat. Pressure up to 2800 to set packer and held for 5 min. Bled pressure back to 1500 psi and pull tested packer to 25K overpull Slacked off to neutral and pressure back up to 2800 psi. Bled off to 0. W/tool in neutral tested annulus to 2500 for 5 min. OK. Bled off to 0. 16:30 17:00 0.50 COMPZ RPCOM PACK P PU to confirm tool release. Laid down 1jt. RU head pin and pressure to 4300 si and blew ball seat. 17:00 00:00 7.00 COMPZ RPCOM TRIP P POOH Laying down 78 jts 3 1/2"drill pipe and 9 drill collars, then standing back 60 stands of 3 1/2" drill pipe. ~-- Page3of7 ~~ Time Logs _ __~ _ _ Date From To Dur S . Depth E. Depth Phase Cod e S ubcode T Comment _ 3/09/2009 _ _____ _ _ __ 24 hr Summary Clean rig floor, off load Baker tools, set test plug, CO lower pipe rams to 2 3/8", test lower rams at 2 /38" and upper rams at 5", test floor valves and annular all at 250/2.,500 psi, rack and tally 5" DP, RU- PU and RIH with 2 3/8" PH6 to +/- 8.,720', Co floor equipment, racked and tallied 5" DP, tested TIW and floor valves, MU bum er sub and ars, PU RIH one 'nt 5". 00:00 01:00 1.00 0 0 COMPZ RPCOM PULD P LD LEM setting tool and inner string. 01:00 01:30 0.50 0 0 COMPZ RPCOM OTHR P Clean rig floor, clean up tools, off load pipeshed, start rack and tally 5" DP. 01:30 03:00 1.50 0 0 COMPZ RPCOM NUND P CO lower pipe rams to 2 3/8", RU test equipment. 03:00 07:30 4.50 0 0 COMPZ WELCTI BOPE P Test 5" TIW and dart valves, shell test on BOP stack, test lower pipe rams at 2 3/8", test upper pipe rams at 5", test annular at 2 3/8". Charted all tests at 250!2,500 psi. Witness of BOP test was waived by AOGCC Rep Jeff Jones on 3-7-09 at 19:00 hrs. Rig off highline at 07:00 hrs due to hale 3 weather conditions. 07:30 09:30 2.00 0 0 COMPZ RPCOM RURD P Set wear ring. Change out saver sub, RU handling equipment for running 2 3/8" tubin . 09:30 18:00 8.50 0 8,720 COMPZ RPCOM PUTB P MU cleanout assembly (2 3/8" tooth type mule shoe) on 2 3/8' tubing and RIH to 8.,720'. 18:00 22:30 4.50 8.,720 8,720 COMPZ RPCOM OTHR P Finish rack & tally 5"drill pipe, CO floor equipment, test TIW and dart valves at 250/2,500 si. 22:30 00:00 1.50 8,720 8,778 COMPZ RPCOM TRIP P Mu bumper sub, jars and XO's, PU RIH one jnt 5" DP to 8,778'., up wei ht 68K, down wei ht 38K. 3/10/2009 Obtain circ parameters above LEM, PU single in hole with 5" DP from 8,778' to 15,566'. 00:00 00:30 0.50 8,778 8,778 COMPZ RPCOM CIRC P Kelly up and obtain circ parameters through 2 3/8" PH6 at 8,778', 3 bpm - 1860 psi, had 4% return flow rate, up weight 68K, down weight 38K. Blew down to drive. 00:30 03:00 2.50 8,778 9,595 COMPZ RPCOM PULD P PU and single in hole with 5" DP frpm 8.,778' to 9.,595' and tagged up on jnt #27, up weight 83K,, down wei ht 48K. ~---- f Page4of7 ~~ Time Los _ _ _ Date From To Dur _ S_ . De th E. Depth Phase Code Subcode T _Comment 03:00 04:30 1.50 9,595 9,760 COMPZ RPCOM FCO P MU top drive and break eirc at 3 bpm - 1,800 psi, slack off and slow rotate at 7 rpm, torque at 1,400 ft/Ibs, wash down from 9595' to 9,62T with no problem, flow rate increased from 4% to 12 %, shut down pump, made connection, slacked off 10' and string took weight., PU 10' then slacked off start slow rotation at 7 rpm, torque 1.,400 ft/Ibs, and no pump, SO weight at 50K, worked down to 9,760', could not slide, torque still at 1,400 ffllbs, called well Engineer, decision made to add 1% tube to system and attem t to reverse eirc. 04:30 05:30 1.00 9.,760 9,760 COMPZ RPCOM CIRC P Condition seawater in pits with 1% Safelube, line up and break eirc pumping down IA at 4 bpm - 140 psi, lost 20 bbls first 10 minutes of eirc, shut down pumping as per Well En ineer, blow down to drive. 05:30 00:00 18.50 9,760 15,566 COMPZ RPCOM FCO P Cont single in hole with 5" DP, slow. rotation 7 rpm's, no pump from 9,760' to 15,566'. Pump 5 bbls every 1000' to confirm pipe is clear @ 2 bpm @ 800 psi. 150k up wt, 85k do wt. 110k ROT wt w/ 4.,900 ft/Ibs free for ue 35 r m's. 3/11 /2009 Conitnue to clean out "B" sand Lat to 17,368'. POOH laying down 5" DP and 2 3/8 TBG to 4,569' and repair drive chain. 00:00 04:00 4.00 15,566 16,376 COMPZ RPCOM FCO P Continue to Clean out from 15,566' to 16,376', Torqued up from 6,200 ft/Ibs @ 35 rpms free torque to 7,000 ft/Ibs. Make multiple attempts to work past with no success. Pump 5 bbls to clear pipe @ 2 bpm @ 860 psi. 165k up wt, 90k do wt, 110 ROT wt 04:00 .07:00 3.00 16,376 16,376 COMPZ RPCOM OTHR P Clear pipe shed of remaining DP, Load remaining completion equipment., service Top Drive & Blocks. prepare tongs etc for POOH la in down clean out strip . 07:00 08:00 1.00 16,376 15,375 COMPZ RPCOM PULD P POOH laying down 5" DP. Unload pipe shed 08:00 09:00 1.00 15,375 15,375 COMPZ RPCOM OTHR P Switch out ESP Cable Spools while crane was available. 09:00 17:30 8.50 15,375 8,725 COMPZ RPCOM PULD P Continue POOH laying down 5 " DP, empting pipe shed every 30 jts to 8.,725' and lay down Jars and Lub. Bumper sub. 17:30 18:00 0.50 8.,725 8.,725 COMPZ RPCOM OTHR P Change out to 2 3/8 TBG equip. 18:00 23:00 5.00 8.,725 4,569 COMPZ RPCOM PULD P Continue to POOH laying down 2 3/8 Hydril TBG f! 8,725' to 4,569'. 42k u wt, 40k do wt. y~ Page 5 of 7 >~ r Time Logs _ _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 23:00 00:00 1.00 4,569 4,569 COMPZ RIGMN7 RGRP T Repair broken traction motor chain to draw works 3/12/2009 Continue to repair drive chain, POOH laying down 2 318 TBG and mule shoe. Prepare to RIH w/ 3 1/2 ESP Com letion to 5.,366'. 00:00 02:30 2.50 4,569 4,569 COMPZ RIGMN7 RGRP T Continue to Repair broken traction motor chain to draw works 02:30 06:00 3.50 4,569 0 COMPZ RPCOM PULD P Continue to POOH laying down 2 3/8 H dril TBG f/ 4,569' to mule shoe. 06:00 08:00 2.00 0 0 COMPZ RPCOM RCST P LD 2 3/8" muleshoe and Xover. Remove all 2 3/8" pipe and tools from pipe shed. Clean rig floor, prep running tools for ESP and line up components in runnin order. 08:00 14:00 6.00 0 75 COMPZ RPCOM RCST P PU/MU dummy neck, A-Well -Pump Sensor., ESP Motor, Tandem Seal Section. Serviced motor and Seal Section. PU/MU Gas Separator, ESP Pump. PU/MU Y-Block, Telescopic Swivel, and Bypass Nipple w/5 jt (75') 2 7/8" pipe w/Wireline Entry Guide (11.10'talil). MU with pump section, install 6 neck clamps & 2 bands. Connect motor lead and Sensor Gau a control line. 14:00 15:30 1.50 75 172 COMPZ RPCOM RCST P Set the 3 1/2" Y-Block handling pup in slips. MU the first full jt 3 1/2" tubing. Install A Cannon cross-coupling cable clamp on the handling pup. Install the A-Well discharge pressure sub and connect the discharge pressure capillary tubing. MU the second full jt of 3 1/2" tubing and then install the Baker CMU slidin sleeve. 15:30 00:00 8.50 172 5,366 COMPZ RPCOM RCST P Continue running the ESP completion performing electrical inspection/tests on the ESP power cable every 1000', placing Cannon single-channel cross-coupling cable clamps on the first six joints and every other collar there after to 5,366'. 65k u wt, 50k do wt. 3/13/2009 RIH w/ 3 1/2 ESP Completion f/ 5,366' t/ 8,159'. Make final splice and Land Hanger. RILDS, and set BPV. ND BOPE and NU Tree. FP. RDMO Release Nordic ri 3 23:59 hrs on 3-13-09. 00:00 04:30 4.50 5.,366 8,133 COMPZ RPCOM PUTB P Continue running the ESP completion performing electrical inspection/tests on the ESP power cable every 1000', placing Cannon single-channel cross-coupling cable clamps on the first sixjoints and every other collar there after from 5,366' to 8,133' 85k u wt, 50k do wt. Page 6 of ? Time Logs _ _ Date From To Dur S_D~th_ E_ De th Phase Code Subcode __ T Comment__ 04:30 05:00 0.50 8,133 8,133 COMPZ RPCOM PUTB P PU and MU landing jt to hangerjt. MU to TBG string. Used - 133 Cross Cplg Cannon Clamps 6 By Pass Protectorlizers 6 Stainless Steel Bands 05:00 09:00 4.00 8,133 8,133 COMPZ RPCOM OTHR P Make final splice on ESP cable, connect to enetrator. 09:00 10:00 1.00 8.,133 8,189 COMPZ RPCOM HOSO P Land tubing (hanger) and RILDS. Test han er to 5.,000 si. 10:00 12:00 2.00 8.,189 COMPZ RPCOM NUND P Back out the landing jt. and LD. Install two-wa check. ND BOPE. 12:00 15:00 3.00 COMPZ RPCOM NUND P Check the ESP cable/motor electrical integrity and record phase-to-phase and phase-to-ground resistivity for all three phases at the hanger penetrator. NU tree. PT tree and the hanger void/packoff to 5,000 si. Pull two-wa check. 15:00 18:30 3.50 COMPZ RPCOM FRZP P Freeze protect by bullheading 30 bbls diesel down the tubign and 200 bbls diesel down the IA @ 2 BPM w/525 si. 18:30 00:00 5.50 COMPZ RPCOM OTHR P Lubricate in and set CIW 4" H-BPV in tubing hanger profile. Lay down Lubricator in pipe shed. Dress tree. Move rig from over well and remove mats from around well head. Clean out cellar w! Super sucker and around well. RDMO. Release Nordic 3 rig @ 2359 hrs on 3-13-2009. SITP = 150 psi., SIIAP = 150 psi, SIOAP = 0 si. ~_ Page ~ of 7 1 J-137 Post Rig Well Work DATE SUMMARY 3/23/09 INSTALL CAT STANDING VA INTO A 2.812" DS NIPPLE PROFILE O~DOWNHOLE CMU @ 8011' CTMD / 8018' MD.RETURN IN AM TO INSTALL A SLIP-STOP ON TOP OF THE STANDING VALVE 3/24/09 RIH AND SET SLIP-STOP FOR 3.5" TUBING ON TOP OF STANDING VALVE. @ 8018' CTMD.WELL SHUT IN AND FREEZE PROTECTED AND READY FOR DSO TO BRING ON LINE.JOB COMPLETE. WELL LOG T1tANS1dIITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1 J-13 7+L 1 +L 1 PB 1 +L 1 PB2 AK-MW-4559178 October 8, 2008 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-137+L1+L1PB1+L1PB2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-029-23316-00,60,71 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-029-23316-00,71 Digital Log Images 50-029-23 316-00,60,71 L 1 PB 1 HAS NO TVD. 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907-273-3536 Date: " BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 n Signed: 0~1~ ;~~ /~U av~ _cv~s t~l `-Cb ~o~-fog ~- ~(/ l ~1y3 l Nov DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061090 Well Name/No. KUPARUK RIV U WSAK 1J-137L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23316-60-00 MD 16840 TVD 3361 Completion Date 10/1/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Tye Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run OH / Scale Media No Start Stop CH Received Comments __ pt 14220 LIS Verification 3761 16840 Open 11/9/2006 LIS Verification ROP, GR, w/Graphics pt 14220 LIS Verification 3761 13930 Open 11/9/2006 P61 LIS Verification ROP, GR, w/Graphics ~',~tpt ' 14220 LIS Verification 3761 15552 Open 11/9/2006 P62 LIS Verification ROP, ; V GR, w/Graphics C Lis 14220 Gamma Ray 3761 15552 Open 11/9/2006 PB2 ROP, GR ~D C Lis 14220 Gamma Ray 3761 13930 Open 11/9/2006 PB1 ROP, GR ~ D C Lis 14220 Gamma Ray 3761 16840 Open 11/9/2006 ROP, GR rl ~~ D Asc Directional Survey 8921 16840 Open 11/9/2006 D D Asc Directional Survey 8921 13930 Open 11/9/2006 PB 1 D D Asc Directional Survey 8921 15552 Open 11/9/2006 PB 2 Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? N Chi s Received? Y~ F ti T a/ N p orma on ops Analysis ~1~ Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061090 Well Name/No. KUPARUK RIV U WSAK 1J-137L1 Operator CONOCOPHILLIPS ALASKA INC MD 16840 ND 3361 Completion Date 10/1/2006 Completion Status 1-OIL Current Status 1-OIL Compliance Reviewed By: Date: API No. 50-029-23316-60-00 UIC N • ~ ~ • ~ona~oPh ~ I I ~ ps January 29, 2008 T. Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 • J. Eggemeyer Engineering Leader Drilting & Welis P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6049 ~ µ ~ ~~~~~ ~ ~=~ ~ ~ ~.~~ ~.~. " a~.~~,~ Q, ~ '~ C>~~~ i ~~~ ~ ~;Oi'~C~11~5t~~ ;~,t~~~~ ~~,~:1 K~ ~'~~ ~ir~~P~ ~n~~~ Subject: Additional Well Summaries '~'~ Dear Mr. Maunder: `~ ~S-E~-~ ~ l ~~ ~lo ~ i,~ ~' ConocoPhilli s Alaska Inc. submits the attached well summaries for wells 3Q-11 p . , 1 J-137. 1 C-104, 1 E-29, 1 J-176, 1 J-176L1, 1 J-107 and 1 J-107L1 you requested. i'~`~~3~~--~- These summaries will replace the shorter summaries already submitted with the completion reports for these wells. If you have any questions regarding this matter, please contact me at 265-6049. Sincerely, ~~~~ ~ . Eggemeyer Engineering Team Leader CPAI Drilling ~t;~~~~~=~-~ .t.~~~ r ~':; 2Di~~' ~a JE/skad Page 1 of 1 ~ ~ Maunder, Thamas E (DaA) From: Eggemeyer, Jerome C. [Jerorr~.C.Eggemeyer@conocaphiflips.cvrnJ Sent: Wednesday, [3ecember 12, 2007 9:46 AM To: Maunder, Thomas E (DOR) Subject: RE: Detailed Reparts Requests the first package is leaving this morning, we will get these items together also. jce From: Maunder, Thamas E (DOA} [mailto:tom.maunder@alaska.gov] Sent: WecEnesday, December 12, 2007 9:30 AM To: Eggemeyer, Jerorne C. Subject: Detailect Reports Requests Jerame, Further to our discussians, woutd you please provide the detaited operatians reports for fhe faifowing weEt (s)/operations. --~ 1J-137 (206-108} Workover begun 10/15/07 3Q-11 (186-188) Workover begun (~9/07/Q7, non-rig work surnmary provided is suffreient. Thanks in advanee. Cai! or message with any questions. Tom AAaunder, PE AOGCC 12/12/2007 _J ~~ R~V~~~E~ ~ ~i.~-o~ • STATE OF ALASKA ~~~ ~ ~ ZQO7 ALASKA OIL AND GAS CONSERVATION COMMISSION ~~s~a ~~~ ~~~~ ~Q~~* ~~~~~~~~ REPORT OF SUNDRY WELL OPERATIONS Anchnr~~,~ 1. Operations Performed: Abandon ^ Repaif Well ^~ Plug Perforations ~ Stimul8te ~ Othe~ ~ Alter Casing ^ Pull Tubing Q/ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConOCOPhillipS AI8Sk8, InC. Development ~ Exploratory ~ 206-109 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23316-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' - 1J-137L1 ~ 8. Property Designation: 10. Field/Pool(s): ADL 25662, 380058~ .~ $'6 ~. / Kuparuk River Field / West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 16840' ~ feet true vertical 3361' , feet Plugs (measured) Effective Depth measured 16825' feet Junk (measured) true vertical 3361' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 3745' 13-3/8" 3773' 2175' PRODUCTION 9406' 9-5/8" 9434' 3530' D SLOTTED LINE 7689' 4-1/2" 16825' 3357' Perforation depth: Measured depth: slotted liner from 9197'-1 4564', 14680'-16792' true vertical depth: 3472'-3376', 3776'-3360' Tubing (size, grade, and measured depth) tubing in main wellbore, , MD. Packers & SSSV (type & measured depth) Baker pkr @ sss7' no SSSV 12. Stimulation or cement squeeze summary: - Interoals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 210 2406 1 -- 203 Subsequent to operation 668 1038 365 -- 235 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Weli Status after proposed work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: contact Brett Packer @ 265-6845 Printed Name Brett Packet'~ Title Wells Engineer /2. ~~ /~ ~, ~ ,? A// Signature ~ `.~_ _ Phone T Date Pre ar Sh ron All u-Drake 263-4612 ~._. . .~ ~~~. ii~~- ~ ~ 2061 Form 10-404 Revised 04/2004 Submit Original Only • 1J-137 Well Events Summary • DATE Summary 10/15/07 MIRU Accepted rig @ 21:00 hrs on 10-15-07 10/16/07 Kill well and ND/ NU Bope and Test. 10/17/07 Completed testing BOPE to 250/2500 psi, test OK. Pooh w/ TTCESP 10/18/07 Rih w/ ESP to 150' install 116 stage TTCESP and packoff. Test to 500 psi- good. Install slip stop. Continue to Rih to 212', install GLM w/ dummy valve. Continue to Rih to 6244' and Install GLM w/ Circ Valve. Continue to Rih to 8133', M/U Hanger. 10/18/07 ***RIG JOB*** RUN CENTRILIFT ESP & 4-1/2" PACK-OFF TO 90' SLM FROM NABORS 3S RIG FLOOR. TESTED PACK-OFF TO 800 PSI, GOOD. SET 4-1/2" SLIP STOP. COMPLETE. (per Centrilift: ESP TOTAL LENGTH 47.90') 10/19/07 Install landing jt and make final splice in cable to penetrator. land hanger w/ tail @ 8187' and pump intake @ 8124' t/ 8135'. Run in lock downs and back landing jt. Install 2way check valve and ND BOPE. NU Tree. Pressure test tree, void and packoff to 5000 psi. Install 4" H-BPV. Released rig @ 13:30 hrs on 10/19/2007. 10/20/07 Freeze protect well post Work-Over pumped 35 bbls down tubing and 120 bbls down IA all DieseL 10/22/07 PULLED CV FROM 1899' RKB, REPLACED WITH 2O00 PSI SOV. COMPLETE. • ~ Conc~cv-Phillips Time Log Summary V/elNlew YYeb Reporting ;. : ...,.: ,:; „ :: . ~. ` ~Y~ ~~ \ y~~~ . ... ..~.~. : : : :: .a : .s F~~~ .s..:; ~. ~,u ,,, , v.: . ,..,e ~~ , _._~ ~~~ a Well Name: 1 J-137 Job Type: RECOMPLETION ,~fri~ % :~ ~ , ~ r ; ~~~; :.~~ ~ ~ ~' ~ ~ ~,, . t ~ ;, ~.. ~ .,. . ` : \ y< ~ ~ ~~ ~~~ ,. , ~}€tE~' ~. Tt~i`YI ~II ~Si~ : .~s. ~~ ~1 ~T ~`.,~t~~' ` Sll~3 ~\.~C ,` ,~ w~;~~ ~ ~~~`.c 10/14/2007 02:00 00:00 22.00 MIRU MOVE RURD T Waiting on weather, Standby w/ crews ( High Winds ) Conduct maintance and housekeeping along servicing of ri . 10/15/2007 00:00 06:00 6.00 MIRU MOVE WOW T Stand by waiting on weather ( high winds 06:00 13:00 7.00 MIRU MOVE MOB P Prepare to lower derrick. Lower derrick to carrier, skid pipe shed ahead. Blow down steam lines and lower carrier. Prepare pits for move. PJSM and load out auxillary equipment on trucks. Rig down and move from 1 E-12 to 1 J-137 13:00 21:00 8.00 COMPZ MOVE RURD P Spot rig over well # 1j-137. Raise carrier and pin after leveling. Set pipe shed and pit system. RU and tie in equipment. Rig accepted @ 21:00 Hrs. 21:00 23:30 2.50 COMPZ RPCOh OTHR P Rig to Circulate and Kill well, Tie in Bieed tank to OA and Tiger Tank to Ri choke 2330 00:00 0.50 COMPZ RPCO SFTY P Held PJSM w/ VetcoGray for lubricatin out BPV 10/16l2007 00:00 01:00 1.00 COMPZ RPCO OTHR P Pull BPV, SITP 100 psi. 01:00 01:30 0.50 COMPZ RPCOh SFTY P Pre Job Safety Meeting w/ Rig crew, Little Red Services and Vac Trucks. 01:30 08:00 6.50 COMPZ RPCO CIRC P RU Little Red Services and Pressure test lines to 2500 psi. Open Up well 100 psi SITP, 520 psi SIIAP, 100 psi SIOAP. Bleed down tbg and IA pressure and Begin circ140 degree 8.6 ppg sea water w/ 6% KCL. Circ 450 bbls w/ 232 bbl return of calculated 581 bbl hole vol. Lost motor in LRS Pump truck, RD LRS and continue w/ rig pump, pressure test surface lines to 2500 psi. Pump 135 bbls w/ no returns. 08:00 13:30 5.50 COMPZ WELCT KLWL P Waiting on truck, loading Seawater w/6% KCL from Deadhorse. 13:30 15:30 2.00 COMPZ WELCT KLWL P Unload truck load of 8.6+ H20 w/6% KCL into pits. Shut in tubing, and pumped 380 bbls. down IA @ 3.5 bpm w/100 psi. Shut down, check press on IA and tubin both 0 si. 10/16/2007 15:30 18:30 3.00 COMPZ RPC06 NUND P Install BPV and Test plug. ND tree. Pick Bops from craddle. Check hanger threads and install lifting cross over. 18:30 22:30 4.00 COMPZ RPCO NUND P Install BOPE and Fill stack and lines. 22:30 00:00 1.50 COMPZ WELCT BOPE P Conduct BOPE Test 250/ 2500 Test was waived by Jeff Jones @ 17:15 Oct.15,2007. 10/17/2007 00:00 03:00 3.00 COMPZ WELC BOPE P Continue to Test BOPE 250 / 2500 and Draw down test. RD test equipment and Orain Stack. Blow down choke. 03:00 04:00 1.00 COMPZ RPCO RURD P RU equipment on floor to pull ESP 04:00 06:00 2.00 COMPZ RPCO OTHR P Remove test piug and Lubricate out BPV 06:00 08:00 2.00 COMPZ RPCOh RURD P RU Sheave and Elephant trunk with containment for ullin ESP cable. 08:00 09:00 1.00 8,202 COMPZ RPCOh PULD P Screw landing jt into tubing hanger. Marked pipe at the rig floor. BOLDS. Un-land tubing hanger and pulled to rig floor. Cut cable just below penetrator. RU cable spooler. LD landing jt and tubin han erw/1st't41/2"tubin . 09:00 18:00 9.00 261 COMPZ RPCOh PULD P POOH w/ 4 1/2 Production tbg and lay down 1 joint w/ perf shot holes to ESP completion, removing all of the jewelry,spooling up cable, and standing back the 4 1/2" tubing in the derrick. Every 5 stands pumping 40 bbls KWF. 18:00 21:00 3.00 261 0 COMPZ RPCOti PULD P Continue to POOH ESP , laying down Discharge and pup jts, 2 jts 4 1/2 tbg, 1 pup jt w/ Screen intake, Tandem seal section, motor, A-well I pump gauge. Note: GAUGE LINE WAS PINCHED IN SEVERAL PLACES BETWEEN GAUGE AND MOTOR LEAD TIE IN. A TOTAL OF 3 PROTECTALIZERS, 2 FLAT GUARDS, 6 BANDS & 134 CANNON CLAMPS WERE RECOVERED. 21:00 23:00 2.00 COMPZ RPCOti OTHR P Continue to feed well 10 bbls of kill fluid every hour while out of the hole. Clear and clean rig floor. Remove Elephant trunk. load pump sections into boxes and remove them from the i e shed. 23:00 00:00 1.00 COMPZ RPCOti OTHR P Load new pump sections into pipe shed and lavout in run order. , ` 10/18/2007 00:00 06`00 6.00 COMPZ RPCO DHEQ P Install and test A-Well I pump guage, pick up and service motor, seal section, screen intake, 2 joints, A-Well Discharge sub, 2 joints, A-Well Discharge valve. Tie gauge into valve, Iand in slips and prepare to RU Slick line. Used 2 flat guards, 3 protectalizers, 13 bands and 3 cannon clam s to this oint. 06:00 10:00 4.00 COMPZ RPCOh SLKL P RU Slickline. Installed 116 stg FC6000 TTCESP & packoff in tubing. Press test packoff and check valve to 500 psi. Install slip stop on packoff. RD Slickline. 10:00 00:00 14.00 COMPZ RPCOh RCST P Installed a Cannon single-channnel cross-coupling cable clamp on the third fuli joint of tubing, one jt tubing, Camco GLM w/dummy valve. Continue RIH installing Cannon cable clamps on every collar for the first six collars above the GLM. From that point forward, a Cannon clamp is install on every other collar and remainder of completion as per procedure. Install u't, han er't, han er. 10/19/2007 00:00 00:30 0.50 COMPZ RPCOh HOSO P Make landing joint to hanger. 00:30 04:30 4.00 COMPZ RPCOh OTHR P Make final splice of ESP Cable to Penetrator. 04:30 06:00 1.50 COMPZ RPCOh HOSO P Land tubing w/ tail @ 8187' and pump intake @ 8124' U 8135'. GLM's w/ dummy @ 7957' and w/ circ valve @ 1898'. Run in lock downs. 06:00 07:00 1.00 COMPZ RPCOh DHEQ P Check the ESP cable/motor electricai inte ri . RD cable s ooler. 07:00 13:30 6.50 COMPZ RPCOh NUND P NU tubing adaptor and 5M tree. Test tree to 5000 psi. Test hanger void/packoff to 5000 psi. Check ESP cable motor integrity and A-Well pump guage, OK. Install H-BPV. Clean cellar and surrounding area. Release Ria Ca) 13:30 hrs on 10-19-07. ~ ~ _J KRU 1 J-137L1 ~~r~~c~~~a~l~~p~ ~1~~~a, ~r~c. ~ ~ ~ ~ RECEIVED STATE OF ALASKA (~pY 1 ~ ZQQ7 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION-~aska Oil & Gas Cons. Commission. 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^~ r Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development^Exploratory ^ 206-109 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23316-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-137L1 8. Property Designation: s 30~~5~ +Z ¢D L 2~u 10. Field/Pool(s): k Oil P l i l /W t S i / Kuparuk River Unit / ~-~;e1 es a oo Kuparuk River F e d 11. Present Well Condition Summary: Total Depth measured 16840' , feet true vertical 3361' - feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 3624' 13-3/8" 3733' 2163' WINDOW L1 1' 9-5/8" 8922' 3456' PRODUCTION 9325' 9-5/8" 9434' 3528' D-SAND SLOTTE 7689' 4-1/2" 16825' 3361 Perforation depth: Measured depth: Liner slots 9197-1456 14680-16793 wsd true vertical depth: Liner slots 3472-3376 3376-3360 wsd Tubing (size, grade, and measured depth) 4-1/2" , L-80, 8140' MD. Packers &SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions inGuding volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI SI SI Subsequent to operation 692 519 ~ 1 825 287 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development^ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oi10 ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. F~cempt: 307-142 Contact Marie McConnell / Perry Klein Printed Name Marie McConnell Title Problem Well Supervisor ,~~ Signature -' ~ ~,, 4G' ~~~e~/ Phone 659-7224 Date 5/12/2007 Form 10-404 Revised 04/2004 ~ ~~ ~'°~ ~.. ~B ~ ~~~ ~~N ~ ~ 2D01 Submit Origi nl~~~ 7 ~• 1J-137L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 3/3/2007 ESP failed due to downhole electical failure 3/20/2007 installed OV in GLM @ 2080' 3/24/2007 Unable to pull slip stop above ESP pump. Perforated tubing from 7,913' - 7,915' RKB with 1.56" Tubin Puncher- 4 SPF .23" hole with .05" penetration 3/27/2007 AOGCC approval for temp test with GL 3/29/2007 Brou ht well on line with gas lift 4/21/2007 Submitted 10-403 for approval to as lift for up to 2 years while waiting on RWO repair. 4/26/2007 AOGCC approved GL production per sundry approval #307-142 • Marie McConnell Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK Re: Kuparuk River Field, West Sak Oil Pool, 1J-137L 1 Sundry Number: 307-142 Dear Ms. McConnell: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this l!F~day of April, 2007 Encl. i~ ._ ( (', ~ r L' Sincerely. ~ ~ ~ ~' ~ ~'°~`~~ DECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,~~ APR 2 4 2007 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.2so Alaska Oil & Gas Cons. Commission 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 6@ & 2061090 3. Address: Stratigraphic ^ Service ^ ~?_e~~~~~ ~O P. O. Box 100360, Anchorage, Alaska 99510 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownershi p or landownership changes: y~,-~~~ ~~ Spacing Exception Required? YeS ^ NO ^ J-137L1 ..~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Kuparuk River Unit RKB 109' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDlT10N SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17386' 3441' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108 SURFACE 3664' 13-3/8" 3773' 2163 WINDOW L1 1' 9-5/8" gg22' 3456 PRODUCTION 9325' 9-5/8" 9434' 3528 B-SAND SLOTTED LINER/ D- SAND SLOTTED LINER 8363' / 7689' 4-1/2" / 4-1/2" 17376' / 16825' 3441' / 3361' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Liner slots: 9427-17331 BSand / 9197-16793 D San Liner slots: 3528-3441 BSand / 3472-3360 D Sand 4-1 /2" l_°80 8140' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV no SSSV 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: March 29, 2007 Oil ^~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is tru e and correct to the best of my knowledge. Contact: Marie McConnell / Perry Klein Printed Name: Marie McConnell Title: Problem Well Supervisor `~~ ~~ Signature Phone 659-7224 Date 4/21/07 Commission Use Only Sundry Nu mber: Conditions of approval: Notify Commission so that a representative may witness Q ' ~~ 3 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ,~'IIS E~FI- aP~ ~ 7 2007 Subsequent Form Required: ~V APPROVED BY ~ 6~~ Approved by: C MISSIONER j, THE COMMISSION Date: ~ Form 10-403 Revised 06/2006 ~ ~ ~ GSA L ~ Submit in Duplicate C~ J ConocoPhillips Alaska, Inc. West Sak Injection Well 1J-137 (PTD 2061080) & 1J-137L1 (PTD 2061090) SUNDRY NOTICE 10-403 VARIANCE REQUEST 04/21 /07 The purpose of this Sundry Notice is for approval to produce dual lateral West Sak producer 1J- 137via gas lift until the failed ESP is replaced. The well is completed as an ESP (electric submersible pump) producer and does not have a packer. 1J-137 was worked over in February, 2007 to replace a failed ESP motor. The well produced via ESP until 03/3/07, at which time it was shut-in due to a downhole motor electrical failure. Prior to failure, the ESP had drawn the bottom hole pressure down to 800 psi; however, the well was not producing as expected with the drawdown achieved. A temporary test on gas lift was started on 3/29/07 after receiving verbal approval from Tom Maunder on 3/27/07 to help troubleshoot production rates before the next RWO. The test was expected to last for no more than 30 days, as a low production rate was expected. Test results indicate the well will continue to produce on gas lift for several months. A RWO is planned to replace the failed ESP within the next 2 years. The tubing is configured with two gas lift mandrels at 2080' RKB (1740' TVD) and 7977' RKB (3265' TVD). An orifice valve was installed in the upper gas lift mandrel. The lower gas lift mandrel could not be accessed by slickline due to solids problems and remains dummied off. The tbg was perforated with coiled tbg from 7,913' - 7,915' RKB, 4 SPF to allow gas lift injection as deep as possible into the tbg. Gas lift will be applied in the "standard" configuration; i. e., gas will be injected down the annulus and enter the tubing through the orifice valve and tbg holes. The last production test on 04/13/07 recorded 692 BOPD, 1 BWPD (0%WC), and 519 MSCF of gas at a gas lift rate of 2.SMMSCFD. Attached is a wellbore diagram of the well. The following is a summary of the proposed plan: The AOGCC approve this request for a time period not to exceed 24 months from the approval date; 2. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. • • ~j} KRU 1J-137 (~~ ConocoPhillips Alaska, Inc. • ConocoPhillips Alaska, Inc. • KRU 1J-137L1 1J-137L7 API: 500292 3316 60 Well Type: PROD Angle @ TS: deg @ SSSV Type: _ _ . Orig Com letion: 10/1/2006 Angle @ TD: _ 89 deg @ 16840 Annular Fluid: Last W/O: 2/4/2007 Rev Reason: ADD PERF TO MAIN WELLBORE Reference L 28' RKB Ref Lo Date: Last U ate: 4/1/2007 _ Last Tag_ ______ TD: 16840 ftK8 Last Ta Date: Max Hole An le: 96 de 10770 Casing Strin -COMPLETION Description Size To Bottom ND Wt Grade Thread TUBING CONDUCTOR 20.000 _ 0 108 108 94.00 H-40 WELDED (o-atao, OD:4 500 SURFACE 13.375 0 3733 2163 68.00 L-80 BTC . , ID:3.476) ~ PRODU_CTION _ 9.625 0 9434 -34f>'h'3 40.00 L-80 BTCM ~ WINDOW L1 10.000 8921 8922 3456 0.00 D-SAND SLOTTED LINER 4.500 9136 16825 3361 11.60 L-80 BTC Tubing. Strin -TUBING Size T~_ __ Bottom ----- _ TVD_ ____ Wt Grade Thread 4.500 0 8140 3303 11.60 L-80 IBTM-SCC XO/SCREEN 8 Perforations Summa -- ( 140151, 130) OD:5 _ Interval _ ND Zone Status_ Ft SPF - Date T e Comment . 9197 - 14564 3472 - 3376 i WS D ~ 5367 32 9/22/2006 SLOTS Alternate slottedlsolid i sEnL 14680 - 16793 3376 - 3360 __ WS D 2113 32 9/22/2006 SLOTS Alternate slotted/solid i (6,5,~,sa, OD:5.130) Gas Lift MandrelsNalves MOTOR St MD TVD Man Mfr I Man Type V Mfr V Type V OD Latch Port TRO Date Run , ~'' Vlv Cmnt (elsa$1s6, 1 2080 1740 CAMCO _ KBMG __ -Q8V _ _ 1.0 _ BK-5 4.0130 - -2/4/2007- z . "t OD:5.620) ~ 2 7977 3265 CAMCO KBMG DMY 1.0 - BK-5 0.000 0 2/4/2007 ~~ Other plu s, equi ., etc,~_D-SAND HOOK HANGER ASSY De th TVD _ _ Type _ Descri lion ID 8939 3458 HANGER _ BAKER MODEL PZ HOOK HANGER 4.767 8943 3459 JDINT 3.960 8956 _ 3461 XO BUSHING CROSSOVER BUSHING 3.920 8997 3467 PACKER BAKER PAYZONE EXTERNAL CASING PACKER 3.900 9159 3472 Bent Joint 3.960 Other lu s e ui .etc. - D-SAND LINER DETAIL De th __TVD T e Descri lion ID 9136 3473 SLEEVE BAKER'HR' LINER SETTING SLEEVE 5.010 9292 3470 XO B_ USHING BTC CROSSOVER BUSHING 3.960 16792 3360 XO CROSSOVER 3.500 JOINT _16793 _3360_ Bent Joint _ _ 2.602 (esa3-s1sa, 16825 3361 SHOE _ BAKER GUIDE SHOE NO FLOAT 0.000 OD:4.530) Other lu s, a ui ., etc . -COMPLETION POST WORKOVER -~ - De th _TVD___ Type - Descri tlon ID 22 _ 22 HANGER _ VETCO GRAY, MCA TOP CONNECTION MADE 3.958 8059 3284 Discharge Sub A-WELL DISCHARGE SUB 0.000 8083 _3290 PUMP 4.5" GS, ESP PUMP (44.09 OAL G-FN D8D Packoff ASSY 0.000 I I 8140 3303 O/SCREE TTT CROSSOVER w/SCREEN INTAKE 0.000 8151 3306 SEAL TANDEM SEAL SECTION GSB AB/HSN PFSA 0.000 8164 3309 MOTOR 418 HP KMHFER 1620 / 90 MOTOR 0.000 8198 3317 PUMP GAUGE A-WELL 1 PUMP GAUGE 0.000 8200 3317 Centralizer MOTOR CENTRALIZER 0.000 ' 8918 3455 L1 HANGER L1 BAKER MODEL PZ HOOK HANGER 7.660 RODUCTION (0-9434, General Notes ODS.6z5, Date No;e_ w1:ao.oo) 10/3/2006 -- NOTE: MULTI-LATERAL WELL: 1J-137 B-SAND 1J-137L1 D-SAND Pert (9197-14564) Perf ;14680-16793) i - -- ~/ .p ~N Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri121, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: r ~ .: 1 ,:'', :. Enclosed please find a 10-403 Sundry Notice variance request for ConocoPhillips Alaska, Inc., West Sak well 1 J-13 7 & 1 J-13 7L 1. The variance request is for approval to temporarily use gaslift to produce the ESP completed well. Also attached is a discussion and well schematic. Please call Perry Klein or me at 907-659-7224 if you have any questions. Sincerely, c ~~ ~~~~ Marie McConnell Problem Well Supervisor Attachments RE: FW: 1J-137 (PTD 206-108) Failed ESP -request to test with gas Subject: RE: FW: 1J-137 (PTD 206-108) Failed ESP -request to test with gas lift. I+~rom: NSK Problem Well Supv <n1617@conocophillips.com> Date: Sat, 21 Apr ?007 16:31:57 -0800. To: Thomas 1~Iaunder ~--tot~1 maundci~(u~~admin.statc.ak.us-= CC: lames Rc,~~~~ ~=jim_re~~~("u?admin.state.ak.us.= Tom, Same good news regarding an update and plan forward for 1 J-137 (PTD 2061080) Failed ESP. The weld was brought on trine on gas lift on 3{29/07 and has performed much better than expected. It appears that the welk will continue to produce on gas lift for several months while waiting on a rig workover to replace the ESP. I just completed a 10-403 requesting a waiver to continue producing the weld on gas lift. You shoukd receive it in the maik this week, hopefulky before the 30 day approval has kapsed. Attached is an electronic version of the 10-403 for your reference. Please !et me know if there are any questions. Marie McConnekl Problem Well Supervisor (907) 659-7224 n1617 a~conocophikkips.com From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, March 27, 2007 9:28 AM To: NSK Problem Well Supv Cc: James Regg Subject: Re: FW: 1J-137 (PTD 206-108) Failed ESP -request to test with gas lift. Hi Marie, Unf ate on the short lived repair. It is acceptable to return the well to gas lift to help determine the path ard. At the end of 30 days (~ April 23)) let us know the results of this testing. Call or messag ith any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On~3,(~3/2007 11:12 AM: Tom, West Sak ESP producer 1J-137 is having e bad ku A RWtJ was compketed in Feb 2007 that replaced the previously reported faik P with a new ES .The newly installed ESP failed on 3f31Q7 shortly after it was turns for a past RWO fkowback. failure was due to a downhole electrical problem requiri RW® to repair the ESP. Prior to failur e ESP had drawn the bottom poke pressure down to 800 psi, ever, the well was not pro wng as expected with the drawdown achieved. A temporary test on gas ~ ~ desired to hekp troubkeshoot production rates before the next RWO. `' ~.. 1 of ~ 4/25/2007 12:50 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~CEIVED ~~1~ MAR 0 ~ 1~O1 Ahska 8il b Gas Cons. Cornmission REPORT OF SUNDRY WELL OPERATIONS Anchor~ae 1. Operations Pertormed: Abandon ^ Repair Well ~ ` Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConOCOPhillips Alaska, InC. Development ~ Exploratory ^ 206-109 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23316-60 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1J-137L1 - 8. Property Designation: 10. Field/Pool(s): ADL 25662, 380058 ~ Kuparuk River Field /West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 16840' ~ feet true vertical 3361' feet Plugs (measured) Effective Depth measured 16825' feet Junk (measured) true vertical 3361' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 3745' 13-3/8" 3773' 2175' PRODUCTION 9406' 9-5/8" 9434' 3530' D SLOTTED LINE 7689' 4-1/2" 16825' 3357' Perforation depth: Measured depth: slotted liner from 9197'-14564', 14680'-16792' true vertical depth: 3472'-3376', 3776'-3360' Tubing (size, grade, and measured depth) tubing in main wellbore, , MD. Packers &SSSV (type & measured depth) Baker pkr @ sss7' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1554 904 1 -- 218 Subsequent to operation SI -- 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: contact Brett Packer @ 265-6845 Printed Name Brett Packer _~ Title Wells Engineer ~ ~Z ~~ ®~"~ D t a e Signature Phone Pre are b Sharon Allsu -Drake 263-4612 Form 10-404 Revised 04/2004 ^I 1 ~ ~ ~ ~ ~ ~A~ ~ ~ Z0~! Submit Ori rnal Onl ---~,, ~: KRU 1J-137L1 CcanocoPhiltips At~lsk~~ InC. '1J-137L1 API: 500292331660 Well T e: PROD An le TS: de SSSV Type: Orig 10/1/2006 Angle @ TD: 89 deg @ 16840 TUBING (0-8140, OD:4.500, ID:3.476) XO/SCREEN (8140-8151, OD:5.130) SEAL (8151-8164, OD:5.130) MOTOR (8164-8198, oD:s.s2o> JOINT (8943-9159, OD:4.530) 'RODUCTION (0-9434, OD:9.625, W 1:40.00) Perf (9197-14564) Com letion: - Annular Fluid: Last W/O: 2/4/2007 Rev Reason: Reference Lo : 28' RKB Ref Lo Date: Last U date: Last Ta TD: 16840 ftK6 ,;, Last Tag Date: Max Hole Angle: __ Casing String -COMPLETION Descri lion- Size To 96 deg Cad 10770 Bottom VD t .._._ CONDUCTOR 20.000 0 108 108 94.00 • SURFACE 13.375 0 3733 2163 68.00 PRODUCTION 9.625 0 9434 3467 40.00 WINDOW L1 10.000 8921 8922 3456 0.00 «~ ~': D-SAND SLOTTED LINER ,Tubing String -TUBING Size To 4.500 9136 1fi825 Bottom TVD Wt 3381 11.60 Grade 4.500 0 8140 3303 11.60 L-80 Perforations Summary ~~> Interval TVD Zone Status Ft SPF Date T Comment 9197 - 14564 3472 - 3376 WS D 5367 32 9/22/2006 SLOTS Alternate slotted/solid i e 14680 - 16793 3376 - 3360 WS D 2113 32 9/22/2006 SLOTS Altemate slotted/solid pipe - - _._ Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V DD Latch Port TR© Date Run Vlv Cmnt 1 2080 1740 CAMCO KBMG SOV 1.0 BK-5 0.000 0 2/4/2007 2 7977 3265 CAMCO KBMG DMY 1.0 BK-5 0.000 0 2/4/2n(rl __ 'Other 4plu_gs, equip., etc.) - D-SAND HOOK HANGER ASSY r-n....~u rim 'r..s ne~..r~r.~~.... Ifl 8939 3458 HANGER BAKER MODEL PZ HOOK HANGER 4.767 8943 3459 JOINT 3.960 8956 3461 XO BUSHING CROSSOVER BUSHING 3.920 8997 3467 PACKER BAKER PAYZONE EXTERNAL CASING PACKER 3.900 I yl5`U 134 /~ I tsen[ JOlnt I ~ •s yhu ~ Other lu s, equip., etc.) - D-SAND LINER DETAIL __ - De h TVD T e Descn Ion ID 9136 3473 SLEEVE BAKER'HR' LINER SETTING SLEEVE 5.010 9292 3470 XO BTC CROSSOVER BUSHING 3.960 ~ 16825 Other De th ~ 3361 (plugs, TVD SHOE ~ BAKER GUIDE SHOE NO FLOATS I 0.000 I eguip.~c.) - COMPLETION_POST WORKOVER T e Descri lion ID 22 22 HANGER VETCO GRAY, MCA TOP CONNECTION MADE 3.958 8059 3284 Discharge Sub A-WELL DISCHARGE SUB 0.000 8083 3290 PUMP 4.5" GS, ESP PUMP 44.09 OAL, G-FN , D&D Packoff ASSY 0.000 8140 3303 O/SCREE TTT CROSSOVER w/SCREEN INTAKE 0.000 8151 3306 SEAL TANDEM SEAL SECTION GSB AB/HSN PFSA 0.000 8164 3309 MOTOR 418 HP KMHFER 1620 / 90 MOTOR 0.000 8198 3317 PUMP GAUGE A-WELL 1 PUMP GAUGE 0.000 8200 3317 Centralizer MOTOR CENTRALIZER 0.000 8918 3455 L1 L1 BAKER MODEL PZ HOOK HANGER 7.660 _ HANGER i General Notes Perf ~ ~_ ;14680-16793) ,"", ~ -_ _~ j • Cnr>~o~c~-P~ips Time Log_ Summary 4Lellv7ew V/eb Re~ortmg _______ Well Name: 1J-137 Job Type: RECOMPLETION _ - - ---- Time Loys - - _ _ _ - - -- ~aie -__ - From To Dur S Depth E Deptn Phase Cede Subco~ie T C(~P.1 01/29/2007 12:00 13:00 1.00 COMPZ MOVE DMOB P Rig down, Blow down, Disconnect Power & Sull lines. 13:00 13:15 0.25 COMPZ MOVE MOB P PJSM, Rig move hazard recognition. 13:15 15:00 1.75 COMPZ MOVE MOB P Move pipe sheds,. Rock washer, Boiler, Motor, Pump, Mud pit com lexs, Move mats. 15:00 16:30 1.50 COMPZ MOVE MOB P Move rig off 1J-103 to 1J-137. 16:30 19:30 3.00 COMPZ MOVE MOB P Set mats, Spot Mud pits, Pumps, Motosr, Boilers, Rock washer, Pipe sheds com leis. 19:30 21:30 2.00 COMPZ MOVE RURD P Rig up, Set stairs /.Landings & Brems, Connect Suppy lines, Connect Power lines, Rig up Mud & Pump lines: 21:30 00:00 2.50 COMPZ RPCOh PULD P Remove Tubing Actuator valve, Rig up ' Scaffolding aroung wellhead, Lay He~culite for tanks and Spot Tiger tanks, Rig pupip lines to kill well. Acce ted ri 21:30 hrs 1/29/07 01/30/2007 00;00 00:15 0.25 COMPZ RPCOh PULD P Pulled BPV and checked well pressures, TP-90 psi, IA-370 psi, OA 100 si 00:15 02:45 2.50 COMPZ RPCOti RURD P Held PJSM then RU hardline from well to choke house, tiger tanks and flowline. 02:45 03:45 .1.00 COMPZ RPCOti SFTY P Held PJSM on killing of well with rig crew and ado erator. 03:45 04:30 0.75 COMPZ RPCOti SFEQ P Pressure tested surface lines to 2,500 si. 04:30 09:00 4.50 COMPZ RPCOh CIRC P Began to kill well by pumping 8.2 ppg MOBM down the tbg, staged pump rate up to 3 bpm and after 50 bbls holding 350 psi on the IA and decreaed pressure to 150 psi, increased rate to 4 bpm while taking returns to flowline mainifold, after 550 bbls switched returns to tiger tank and determined hole was taking fluid, slowed to 2 bpm and after pumping 230 bbls (780 bbls total) had only recovered 81 bbls of gas cut oil to tiger tank. shutdown pumping. Note: Was. unable to determine amount of returns down flowline. • • ~ Time Logs _____ Dat? Fro~~~ _ To __D_ur 5 D_epih __E. Dep±h Phase Code ~ubcc~ ie T C;OM ____ _ __ _ _ _ ~ 01/30/2007 09:00 13:45 4,75 COMPZ RPCOti OWFF P Monitored well, initail TP 10 psi and initial IA pressure 165 psi, treated 700 bbls of 8.2 ppg MOBM, final TP 10 psi, final IA 190 si. 13:45 18:30 4.75 COMPZ RPCOh CIRC P Cont to attempt to kill well, pumpedan add. 425 bbls of 8.2 ppg MOBM, (1,205 bbls total) cont to circ with partial returns, shut down pumping and recovered an add. 208 bbls for 289 total recovered in tiger tanks (24% returns). Decision was made to bullhead 8.2 ppg MOBM down the IA to kill well 18:30 00:00 5.50 COMPZ RPCOf~ OWFF P Monitored well while waiting on add. 8.2 ppg MOBM, initial tbg pressure 120 psi, initial IA185 psi, final tbg press. -0-and final IA 110 psi. began offloadin MOBM 01/31/2007 00:00 01:15 1.25 COMPZ RPCOh CIRC P Held PJSM then bullheaded 530 bbls of 8.15 ppg MOBM down the IA with tbg shut. in, ave 7 bpm at 930 psi, tbg ressure was 650 psi and OA 400 si. 01:15 01:30 0.25. COMPZ RPCOh OWFF P Monitored well-SITP 540 psi, IA/SICP 540 si 01:30 02:45 1.25 COMPZ RPCOti RURD P RU to circ down tbg and bled off well pressure thru choke, shut in well and had70 psi SITP and 40 psi IA pressure after 15 min. opened well back u thru the choke. 02:45 05:30 2.75 COMPZ RPCOI~ CIRC P Circ 1 complete hole volume (600 bbls) at 4 bpm ave 500 psi, had 8.15 ppg MOBM in and outand lost 14 bbls of mud while circ hole. 05:30 06:30 1.00 COMPZ RPCOti OWFF P Monitored well, gained 1.3 bbls in first 30 min, slight flow and no gain last 30 min. decision made to raise MW to 8.3 p . 06:30 12:00 5.50 COMPZ RPCOti CIRC P Began to circ hole raising MW from 8.45 ppg to 8.3 ppg, circ hole at 30 spm, 3 bpm at 300 psi. PHASE 3 weather in effect at 12:00 hrs., lost 14 bbls of mud while circ and weighting up. 12:00 18:30 6.50 COMPZ RPCOh CIRC P Cant to circ hole raising MW from 8.15 ppg to 8.3 ppg, circ hole at 3 bpm and 300 si. 18:30 19:00 0.50 COMPZ RPCOti OWFF P Monitored well and still had slight flow. 19:00 00:00 5.00 COMPZ RPCOti CIRC P Circ hole raising MW from 8.3 ppg to 8.4 ppg, began circ hole at 3 bpm at 300 psi then increased to 4 bpm at, 560 psi. 8.4 ppg MW in and out at 24:00 hrs. Lost an add. 29 bbls mud while circ hole (43 total). PHASE 3 weather was lifted at 24:00 hrs _ _ ~.._ ~ __~ _e.. • Time Loys- _ - --- - _ ----- - __ U .te From To Dur 5- L1~pth_ ~_D_e_ pth Phase Code S ibcod2 T COM 02/01/2007 00:00 00:30 0.50 COMPZ RPCOti CIRC P Fin circ and raising MW to 8.4 ppg in and out, circ at 4 bpm at 560 psi, Phase 3 was lifted at 00:00 hrs. 00:30 01:30 1.00 COMPZ RPCOti OWFF P Monitored well-static, no fluid movement final 30 min's 01:30 02:30 1.00 COMPZ RPCOti OTHR P Installed Cameron HP-BPV, blew down surface lines and RD squeeze manifold. 02:30 03:00 0.50 COMPZ RPCOh KURD P RD scaffolding 03:00 03:30 0.50 COMPZ RPCOti NUND P ND tree and installed HP plug in BPV 03:30 05:00 1.50 COMPZ RPCOti NUND P NU BOP stack and lines 05:00 05:30 0.50 COMPZ WELCT OTHR P MU testjt and RU to test BOPE 05:30 08:15 2.75 COMPZ WELCT OTHR NP Attempted to gef landing jt to seal, had to change out o-rings several times, ended up installing TIW valve on landin 't to test. 08:15 13:30 5.25 COMPZ WELCT BOPE P Tested BOPE, tested rams, valves and manifold to 250 psi low and 2,500 psi high, tested with 4 1/2" testjt. Upper IBOP valve on top drive#ailed. NOTE: John Crisp W/AOGCC waived witnessin of the test 13:30 14:00 0.50 COMPZ RIGMN SFTY NP Held PJSM on changing out IBOP and blew down top drive 14:00 18:30 4.50 COMPZ RIGMN RGRP NP Changed out upper IBOP on top drive 18:30 19:00 0.50 COMPZ WELCT BOPE P Re-tested upper IBOP to 250 and 2;500 si and checked ok. 19:00 19:30 0.50 8,199 8,199 COMPZ RPCOh OTHR P Checked well for pressure thru Cameron HP plug and well was satic, ulled HP lu and BPV out of han er. 19:30 20:30 1.00 8,199 8,169 COMPZ RPCOti OTHR P MU lahdingjtto hanger, backed out lock down screws, PU on completion string to 120K and pulled hanger to rig floor, st wt up 105K 20:30 23:30 3.00 8,169 8,169. COMPZ RPCOti CIRC P Est circ at 4 bpm at 600 psi, (took 25 bbls to est circ), circ hole at 4 bpm and after 100 bbls, (122 bbls tbg cap) pressured up to 1,500 psi, slowed rate to 3 bpm at 1,000 psi and fin. circ btms up, lost 8 bbls to hole while circ and no as at btms u . 23:30 00:00 0.50 8,169 8,169 COMPZ RPCO OWFF P . Monitored well, well -static. 02/02/2007 00:00 00:15 0.25 8,169 8,169 COMPZ RPCOh SFTY P Held PJSM with crew, Centrilift rep and Doyon tong operator on pulling of ESP completion. 00:15 01:00. 0.75 8,169 8,169 COMPZ RPCOti RURD P RU Centrlifts tools and pumped dry 'ob. f Pars 3 o fi ~~..._ _ ~ ._-_-____ ------ ----I l I r~ i Tirne LocJs -- ~! Dare From To Dur 5- Deoth E Depfh Ph~s~ Cn~1e if~co,~ T___COM - - _ - -- 02/02/2007 01:00 04:45 3.75 8,169 6,100 COMPZ RPCOti TRIP P LD Vetco Gray tbg hanger then POOH from 8,169' with 4 1/2" 12.6#, L-80 IBTM tbg and ESP wire to 6,100', POOH standing back 21 stds tbg and LD sin le, a 't and up er GLM. 04:45 05:45 1.00 6,100 6,100 COMPZ RPCOti OTHR P .Changed out ESP spool in spooling unit. Tested ESP cable. 05:45 10:45 5.00 6,100 1,875 COMPZ RPCOti TRIP P POOH wet with 4 1/2" ESP completion from 6,100' to 1,875', calculated fill 28 bbls, actual fill 60 bbls. 10:45 11:15 0.50 1,875 1,875 COMPZ RPCOti OTHR P Cleaned rig floor 11:15 12:00 0.75 1,875 1,875 COMPZ RPCOti KURD P Held PJSM and RU HES slickline and scheaves 12:00 13:45 1.75 1,875 1,875 COMPZ RPCOti SLKL P RIH with tbg drift and set down at packoff, POOH, RIH with retrieving tool and was unable to latch onto same, POOH 13:45 14:00 0.25 1,875 1,875 COMPZ RPCOti CIRC P Circ down tbg at 3 bpm at 650 psi in attem t to clean around ackoff 14:00 14:45 0.75 1,875 1,875 COMPZ RPCOh SLKL P RIH and attempted to pull packoff with no success, POOH. 14:45 15:15 0.50 1,875 1,875 COMPZ RPCOh RURD P RD slickline. 15:15 16:45 1.50 1,875 210 COMPZ RPCOh TRIP P Cont. to POOH with 4 1/2" comp. from 1,875' to 210' 16:45 17:45 1.00 210 130 COMPZ RPCOti PULD P POOH with 2-jts 4 1/2" tbg, 1-jt was (perfd) then LD discharge sub. POOH to 130' 17:45 19:30 .1.75 130 130 COMPZ RPCOti SLKL P RU slickline and attempted to pull` pump with no success, used rig's tugger and POOH with the pump, um was sanded u and locked u . 19:30 21:00 1.50 130 0 COMPZ RPCOt~ PULD P POOH from 130' LD 2-add. jts 4 1/2" tbg, screen intake, seal section and ESP motor, SLM out and had full recove of clam s and a ui . 21:00 22:00 1.00 0 0 COMPZ RPCOti OTHR P Cleaned rig floor after wet trip. NOTE: NORMED ESP s ool and ck'd ok. 22:00 22:15 0.25 0 0 COMPZ RPCOti SFTY P Held PJSM with Centrilift rep on ickin u new ESP assembl . 22:15 00:00 1.75 0 0 COMPZ RPCOh RCST P Began to MU ESP assembly, RIH with screen intake, 2-jts 4 1/2", 12.6#, L-80 IBTM tbg and well discharge sub, installed pump inside string, preparing. to install ackoff with slickline.. 02/03/2007 00:00 03:45 3.75 0 0 COMPZ RPCOti SLKL P RU slickline and installed ESP pump and packoff, set test tool and attempted to test packoff and would not test, cont. to pound on packoff and testing same with no success, POOH with packoff. Packoff rubber looked new. u~~~ B of rr'~ • • I Tirne Logs ---- - - - - -- _ - - - - _ - - - - - -_ --- Data __ From To Dur _ S Deofh _E. De_~th Phase __Code ubcn~~!a T COM _ ____ 02/03/2007 03:45 04:45 1.00 0 0 COMPZ RPCOf~ OTHR P Sent packoff to Y pad to be rebuilt, - removed used cannon clamps from rig floor and placed new clamps on rig floor. 04:45 08:45 4.00 0 0 COMPZ RPCOh SLKL NP RU slickline and steamed rebuilt packoff, RIH setting same, attempted to test and would not test, added additional wt. bars and cont to try to get packoff to seal and test with no success, POOH with rebuilt packoff. Packoof looked good, RD slickline and POOH with pump assembly and stood back in derrick. 08:45 10:30 1.75 0 50 COMPZ RPCOti RCST P MU ESP tandem seal section and motor RIH to 50' while waiting on 3rd. ackoff 10:30 12:30 2.00 50 150 COMPZ RPCO SLKL NP PU pump assembly in tbg and RIH with same and motor to 150', RU slickline &RIH with used packoff and set same, tested packoff to 850 psi for 5 min, good test. Pulled test tool and installed sli sto , RD slickline. 12:30 14:30 2.00 150 232 COMPZ RPCOti PULD P MU ESP cable to motor and connected pump gauge,. ran control line to pressure sub then RIH with 2 jts 4 /12", 1.2.6#, L-80 IBTM tbg and GLM to 232' 14:30 22:30 8.00 232 5,232 COMPZ RPCOti RCST P RIH with 4 1/2".ESP completion from 232' to 5,232', checked ESP cable continuity every 1,000', discovered that the GLM with shear valve had been ran in lace of dumm GLM. 22:30 00:00 1.50 5,232 4,209 COMPZ RPCOh TRIP NP POOH wet from 5,232' to 4,209' to swa out GLM's 02/04/2007 00:00 04:15 .4.25 4,209 213 COMPZ RPCOh TRIP NP Fin POOH wet from 4,209' to GLM at 213', LD GLM with shear valve. 04:15 05:45 1.50 213 213 COMPZ RPCOti OTHR NP Cleaned rig floor after wet trip. 05:45 10:00 4.25 213 3,286 COMPZ RPCOti RCST NP MU GLM with dummy valve and cont to RIH with 4 1/2" ESP completion, tested continuity every 1,000' and at 3,286' had a weak si nal. 10:00 10:45 0.75 3,286. 2,600 COMPZ RPCOh TRIP NP POOH checking continuity and. had ood readin at 2,600' 10:45 14:15 3.50 2,600 2,600 COMPZ RPCOh OTHR NP Spliced ESP cable and tested continut and checked ok. 14:15 16:45 2.50 2,600 5,232 COMPZ RPCOti RCST NP Cont. RIH with 4 1/2" ESP completion to 5,232' checking continuity every 1, 000'. 16:45 21:15 4.50 5,232 8,170 COMPZ RPCOti RCST P RIH with 4 1/2" completion from 5,232', checking continuity every 1,000'. MU 6' pup on full jt below hanger RIH to 8,170', checked continui and ck'd ok ~ - _ I € -°- _-- 1 ;'~rt~ ~ of 6,, ~ I ~ J Time Log s I Date From To Dur S D~oth E Depth Phase Code tiuLccde T COP.1 02/04/2007 21:15 00:00 2.75 8,170 8,170 COMPZ RPCOti OTHR P Madefinal cut on ESP cable and installed penetrator. NOTE: RIH with 260 jts of 4 1/2", 12.6#, L-80 IBTM tbg, 1-6' pup jt, 2-GLM's with pups above and below and ESP assembly, Ran 132 round cannon clamps, 3 protectolizer' gaurds, 2 flat gaurds and 6 stainless steel bands, st wt up 102K, do wt 55K, blk wt 35K. 02/05/2007 00:00 01:45 1.75 8,170 8,203 COMPZ RPCOti RCST P Tested ESP cable on hanger and ck'd ok then RIH landing 4 1/2" completion at 8,202.6', st wt up 102K, do wt 55K, RILDS and tested upper and lower seals to 5,000 psi for 10 min. ea. LD landin 't. 01:45 02:15 0.50 8,203 8,203 COMPZ RPCOti NUND P ND BOPE 02:15 04:15 2.00 8,203 8,203 COMPZ RPCOti NUND P NU Vetco Gray tree, tested ESP cable and had good meggar readings, tested void and tree to 5,000 psi for 10 min. each, ood test. 04:15 05:00 0.75 8,203 8,203 COMPZ RPCOti DHEQ P Pulled TWC then tested 4 1/2" tbg to 1,000 si for 10 min, ood test. 05;00 05:30 0:50 8,203 8,203 COMPZ RPCOh RURD P Held PJSM with RU Little Red and RU same, tested lines to 2,500 si. 05:30 10:30 5.00 8,203 8,203 COMPZ RPCOti FRZP P Displaced hole over from 8.4 ppg MOBM to diesel, after pumping 602 bbls had good diesel back (talc 581 bbls), ave 2.5 bpm, ICP 1,200 psi, FCP 800 psi. Sim-Ops-slip and cut drlg line and changed over top drive and ri floor to 5" DP. RD Little Red 10:30 12:00 1.50 8,203 COMPZ RPCOti OTHR P RU lubricator and installed BPV, secured well, RD scaffolding and fin. cleaning mud pits and rock washer. Note: Lost approx 1,402 bbls of MOBM to well. RELEASED RIG @ 12:00 hrs 2/5/07 -- - ~ ~- faa~~ 5 of S ... ~~ ~ STATE OF ALASKA ~ ~ ~ '~ '~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANA LC~(`'~ 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1b. Well Class: ", tj~•~i~~n Development Q Exploratory L~J1 Service ^ SGatigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: October 1, 2006 ~ 12. Permit to Drill Number: 206-109 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: f.• ~Di ~ l D //~ 13. API Number: ~ 50-029-23316-60 4a. Location of Well (Governmental Section): Surface: 1545' FSL, 2278' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: September 20, 2006 14. Well Name and Number: 1J-137L1 At Top Productive Horizon: 604' FNL, 1503' FEL, Sec. 11, T10N, R10E, UM 8. KB Elevation (ft): 28' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 2050' FSL, 1419' FEL, Sec. 14, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 16825' MD / 3361' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558936 y- 5945359 - Zone- 4 10. Total Depth (MD + TVD): ' 16840' MD / 3361' TVD 16. Properly Designation: ADL 25662 & 380058 TPI: x- 559776 y- 5937937 Zone- 4 Total Depth: x- 559930 . - 5930033 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 6296' MD 21. Logs Run: u.3 89.38 ~D, 3 S8 7"7~b~ ~/•~•l~ GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 272 sx AS 1 13.375" 68# L-80 28' 3773' 28' 2175' 16" 715 sx AS Lite, 21 o sx DeepCrete 9-5/8" 40# L-80 28' 9434' 28' 3530' 12.25" 672 sx DeepCRETE 4.5" 11.6# L-80 9136' 16825' 3472' 3357' 6.75" slotted liner 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in original wellbore slotted liner from 9197' - 14564' and 14680'-16792' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production October 23, 2006 Method of Operation (Flowing, gas lift, etc.) ESP Oil Producer -shares production with 1J-137 Date of Test 10/26/2006 Hours Tested 9 hours Production for Test Period --> OIL-BBL 581 GAS-MCF 122 WATER-BBL 16 CHOKE SIZE 20% GAS-OIL RATIO 242 Flow Tubing press. 296 psi Casing Pressure not available Calculated 2a-Hour Rate -> OIL-BBL 1476 GAS-MCF 358 WATER-BBL 44 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". NONE ~ ~~. l~"1' ~. ~~ ~0~~ ~ ~~.., Form 10-407 Revised 12/2003 CONTKQZ(ENIR~QSE ~ ~ /~/ ~~/~$/~•c~ ~"`" I(~"dt°. gip ~~Vi C !+~/ , / /(W r r~ 2a. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-137L1 West Sak D 8912' 3454' 1 J-137L1 P61 N/q TD 13930' 3372' 1J-137L1 PB2 TD 15552' 3382' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Nugent @ 265-6862 Printed N Ra om Title: Greater Kuoaruk Area Drillino Team Leader ~ t ~~ i~~. r ~~ ~ ~ ~ .._ ~~o .,~ Date Signature -. ~---~...1 - ~~ c: s~~ ~ a~C INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b; TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The APi number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: tf this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ~Ialliburton Company Survey Report Company: ConocoPhillipsAlaska Ina Date: 10/18/2006 Time: 13:54:42 Pape: 1 Field: Kuparuk River Unit Caordinate(NE) Reference: Well: 1 J-137, True North Site: Kuparuk 1J Pad Vertical(TVD) Re ference: 1J-137L1109.0 Well: 1J-137 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Weltpath: 1J-137L1 Survey Calculatio n Method: Minimum Curvature llb: Oracle -_ Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-137 Slot Name: Well Position: +N/-S -562.20 ft Northing: 5945358.62 ft Latitude; 70 15 40.728 N +E/-W 141.55 ft Easti ng : 55893 5.87 ft Longitude: 149 31 24.888 W Position Uncertainty: 0.00 ft Weltpath: 1 J-137L1 Drilled From: 1 J-137L1 P62 500292331660 Tie-on Depth: 13757.69 ft ~ Current Datum: 1J-137L1: Height 109.00 ft Above System Datum: Mean Sea Level ~ Magnetic Data: 8/9/2006 Declination: 23.84 deg Field Strength: 57607 nT Mag Dip Angl e: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 180.00 , Survey Program for Definitive Weltpath Date: 10/18/2006 Validated: No Version: 1 ~ Actual From To Survey ft ft Toolcode Tool Name 50.00 724.00 1J-137 gyro (50.00-724.00) (2) CB-GYRO-SS Camera based gyro single shot 763.95 8846.13 1 J-137 (763.95-17352.25) (2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8921.00 11058.82 1 J-137L1 PB1 (8921 .00-13894.20) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11115.00 13757.69 1 J-137L1 PB2 (11115.00-15516.80 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 13840.00 16793.94 1 J-137L1 (13840.00 -16793.94) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ~ Survey MD Incl Azim TVD SysTVD N/S E/W 111apN MapE fool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945358.62 - 558935.87 • TIE LINE i 50.00 0.13 197.98 50.00 -59.00 -0.02 -0.01 5945358.60 558935.86 CB-GYRO-SS 100.00 0.24 63.32 100.00 -9.00 -0.03 0.07 5945358.59 558935.94 CB-GYRO-SS 172.00 0.30 138.87 172.00 63.00 -0.10 0.33 5945358.52 558936.20 CB-GYRO-SS 266.00 0.53 174.43 266.00 157.00 -0.72 0.53 5945357.90 558936.41 CB-GYRO-SS 355.00 2.61 178.49 354.96 245.96 -3.16 0.62 5945355.47 558936.52 CB-GYRO-SS 447.00 5.47 183.45 446.72 337.72 -9.63 0.42 5945348.99 558936.36 CB-GYRO-SS 539.00 8.20 189.23 538.06 429.06 -20.49 -0.90 5945338.13 558935.13 CB-GYRO-SS 631.00 10.28 191.38 628.86 519.86 -35.01 -3.57 5945323.58 558932.57 CB-GYRO-SS 724.00 13.86 185.23 719.79 610.79 -54.25 -6.23 5945304.33 558930.07 CB-GYRO-SS 763.95 15.51 179.17 758.44 649.44 -64.35 -6.59 5945294.22 558929.79 MWD+IFR-AK-CAZ-SC 823.36 17.99 175.81 815.33 706.33 -81.45 -5.80 5945277.14 558930.71 MWD+IFR-AK-CAZ-SC 887.30 18.59 175.68 876.04 767.04 -101.46 -4.31 5945257.14 558932.35 MWD+IFR-AK-CAZ-SC ~ 949.28 20.29 172.60 934.48 825.48 -121.97 -2.18 5945236.65 558934.64 MWD+IFR-AK-CAZ-SC ~ 1042.06 23.01 173.50 1020.71 911.71 -155.95 1.94 5945202.71 558939.03 MWD+IFR-AK-CAZ-SC ~ I 1135.19 26.07 176.82 1105.42 996.42 -194.47 5.14 5945164.21 558942.53 MWD+IFR-AK-CAZ-SC 1226.83 29.28 172.02 1186.58 1077.58 -236.79 9.37 5945121.93 558947.09 MWD+IFR-AK-CAZ-SC 1320.18 35.08 170.94 1265.55 1156.55 -285.93 16.77 5945072.86 558954.87 MWD+IFR-AK-CAZ-SC 1412.00 40.64 174.74 1338.03 1229.03 -341.81 23.67 5945017.04 558962.21 MWD+IFR-AK-CAZ-SC 1503.17 41.99 173.66 1406.50 1297.50 -401.69 29.76 5944957.21 558968.77 MWD+IFR-AK-CAZ-SC ' , 1598.34 46.25 172.02 1474.81 1365.81 -467.40 38.05 5944891.57 558977.58 MWD+IFR-AK-CAZ-SC 1689.63 47.62 171.58 1537.14 1428.14 -533.41 47,57 5944825.65 558987.61 MWD+IFR-AK-CAZ-SC 1782.86 52.69 172.13 1596.86 1487.86 -604.25 57.69 5944754.90 558998.28 MWD+IFR-AK-CAZ-SC 1874.98 58.51 171.82 1648.88 1539.88 -679.48 68.31 5944679.76 559009.49 ~ MWD+IFR-AK-CAZ-SC 1968.36 62.75 172.58 1694.67 1585.67 -760.09 79.34 5944599.25 559021.15 MWD+IFR-AK-CAZ-SC 2060.33 67.69 174.04 1733.21 1624.21 -843.00 89.04 5944516.43 559031.50 MWD+IFR-AK-CAZ-SC ~Ialliburton Company Survey Report Compam: ConocoPhillipsAlaska Inc. Field: Kuparuk River Unit Site: Kuparuk 1J Pad Well: 1J-137 Wellpath: 1J-1371.1 Date: 10!18/2006 Co-ordinate(NE} Reference: Vertical (TVD) Reference: Section (VS) Reference: Survey Calculation Method: limn. 13:54:42 P;~~c: 3 Well: 1J-137, True North 1 J-137L1: 109.0 Welt (O.OON,O.OOE,180:OOAzi) .. Minimum Curvature llb: Oraeie tiurvev - ___ MD Inc! Azim TVD SySTVT) N/S 1':n~" 'Map: _ __ MapE ~ Tool ft deg deg ft ft ft ft ft ft 2154.58 70.88 174 __ .98 1766. 54 1657.54 ____ -930 .74 97.47 5944428 .76 559040 .61 MWD+IFR-AK-CAZ-SC 2245.74 74.22 173 .42 1793 .88 1684.88 -1017 .24 106.26 5944342 .34 559050 .08 MWD+IFR-AK-CAZ-SC 2339.09 74.41 172 .78 1819 .11 1710.11 -1106 .46 117.06 5944253 .21 559061 .58 MWD+IFR-AK-CAZ-SC 2431.72 75.51 173 .66 1843 .15 1734.15 -1195 .29 127.62 5944164 .48 559072 .83 MWD+IFR-AK-CAZ-SC 2524.49 74.98 174 .15 1866. 78 1757.78 -1284 .49 137.15 5944075. 36 559083. 05 MWD+IFR-AK-CAZ-SC 2617.50 74.92 174 .02 1890. 93 1781.93 -1373 .83 146.40 5943986. 10 559093. 00 MWD+IFR-AK-CAZ-SC 2710.09 76.61 173 .80 1913. 70 1804.70 -1463 .07 155.92 5943896. 95 559103. 22 MWD+IFR-AK-CAZ-SC 2806.73 76.45 174 .39 1936. 21 1827.21 -1556 .55 165.59 5943803. 56 559113. 62 MWD+IFR-AK-CAZ-SC 2893.92 76.38 173 .83 1956. 69 1847.69 -1640 .86 174.29 5943719. 33 559122 .98 MWD+IFR-AK-CAZ-SC 2987.00 76.20 174 .83 1978. 75 1869.75 -1730 .84 183.22 5943629 .43 559132 .62 MWD+IFR-AK-CAZ-SC 3080.29 77.63 173 .97 1999. 87 1890.87 -1821 .27 192.09 5943539 .08 559142 .19 MWD+IFR-AK-CAZ-SC 3173.18 77.93 174 .51 2019. 53 1910.53 -1911 .60 201.20 5943448 .84 559152 .01 MWD+IFR-AK-CAZ-SC 3266.00 76.70 174 .66 2039 .91 1930.91 -2001 .75 209.75 5943358 .77 559161 .26 MWD+IFR-AK-CAZ-SC 3357.70 75.26 175 .44 2062 .13 1953.13 -2090 .38 217.43 5943270 .21 559169 .63 MWD+IFR-AK-CAZ-SC 3450.47 74.84 174 .98 2086 .06 1977.06 -2179 .70 224.91 5943180 .96 559177 .81 MWD+IFR-AK-CAZ-SC 3544.51 73.79 174 .11 2111. 48 2002.48 -2269 .82 233.52 5943090. 91 559187. 12 MWD+IFR-AK-CAZ-SC 3635.78 74.92 174 .34 2136. 10 2027.10 -2357 .26 242.36 5943003. 55 559196. 65 MWD+IFR-AK-CAZ-SC 3728.89 72.89 175 .08 2161. 91 2052.91 -2446 .34 250.61 5942914. 55 559205 .59 MWD+IFR-AK-CAZ-SC 3849.43 73.59 173 .94 2196. 67 2087.67 -2561 .22 261.65 5942799 .77 559217 .53 MWD+IFR-AK-CAZ-SC 3945.06 73.77 174 .38 2223 .54 2114.54 -2652 .53 270.99 5942708 .55 559227 .59 MWD+IFR-AK-CAZ-SC 4037.39 73.66 174 .59 2249 .43 2140.43 -2740 .74 279.51 5942620 .41 559236 .79 MWD+IFR-AK-CAZ-SC j 4130.08 73.38 174 .15 2275 .73 2166.73 -2829 .19 288.23 5942532 .04 559246 .20 MWD+IFR-AK-CAZ-SC ~ 4221.53 73.07 175 .42 2302 .12 2193.12 -2916 .39 296.19 5942444 .92 559254 .84 MWD+IFR-AK-CAZ-SC 4314.42 72.29 174 .98 2329 .77 2220.77 -3004 .75 303.61 5942356 .62 559262 .95 MWD+IFR-AK-CAZ-SC 4407.30 71.64 174 .56 2358 .53 2249.53 -3092 .70 311.66 5942268 .75 559271 .69 MWD+IFR-AK-CAZ-SC 4500.05 70.40 175 .27 2388 .70 2279.70 -3180 .06 319.43 5942181 .46 559280 .15 MWD+IFR-AK-CAZ-SC 4593.31 69.54 175 .23 2420. 64 2311.64 -3267 .38 326.69 5942094. 21 559288 .09 MWD+IFR-AK-CAZ-SC 4686.06 67.99 174 .93 2454. 23 2345,23 -3353 .51 334.10 5942008 .15 559296 .17 MWD+IFR-AK-CAZ-SC 4722.17 67.88 174 .99 2467. 80 2358.80 -3386 .85 337.04 5941974 .84 559299 .37 MWD+IFR-AK-CAZ-SC ; 4774.74 68.06 175 .07 2487 .51 2378.51 -3435 .39 341.26 5941926 .33 559303 .98 MWD+IFR-AK-CAZ-SC 4867.41 70.58 172 .10 2520 .24 2411.24 -3521 .53 350.97 5941840 .28 559314 .35 MWD+IFR-AK-CAZ-SC 4959.80 70.52 172 .73 2551 .01 2442.01 -3607 .88 362.47 5941754 .03 559326 .53 MWD+IFR-AK-CAZ-SC 5053.68 73.11 172 .65 2580 .30 2471.30 -3696 .34 373.81 5941665 .67 559338 .56 MWD+IFR-AK-CAZ-SC 5078.87 73.41 172 .76 2587 .56 2478.56 -3720 .27 376.88 5941641 .77 559341 .81 MWD+IFR-AK-CAZ-SC 5146.52 73.91 173 .06 2606 .59 2497.59 -3784 .69 384.89 5941577 .42 559350 .33 MWD+IFR-AK-CAZ-SC 5238.16 73.84 171 .70 2632 .05 2523.05 -3871 .95 396.56 5941490 .27 559362 .68 MWD+IFR-AK-CAZ-SC 5332.09 73.99 172 .10 2658 .07 2549.07 -3961 .30 409.28 5941401 .03 559376 .10 MWD+IFR-AK-CAZ-SC 5424.24 76.40 171 .46 2681. 62 2572.62 -4049 .47 422.02 5941312 .97 559389 .53 MWD+IFR-AK-CAZ-SC 5517.07 76.63 171 .01 2703. 26 2594.26 -4138 .68 435.77 5941223 .87 559403 .98 MWD+IFR-AK-CAZ-SC 5608.84 74.29 171 .44 2726 .30 2617.30 -4226 .47 449.33 5941136 .21 559418 .22 MWD+IFR-AK-CAZ-SC 5702.22 76.83 172 .48 2749 .59 2640.59 -4316 .00 461.97 5941046 .78 559431 .56 MWD+IFR-AK-CAZ-SC 5787.86 77.17 169 .47 2768 .85 2659.85 -4398 .40 475.06 5940964 .49 559445 .29 MWD+IFR-AK-CAZ-SC 5881.33 77.80 170 .37 2789 .11 2680.11 -4488 .24 491.03 5940874 .79 559461 .96 MWD+IFR-AK-CAZ-SC 5973.35 77.62 170 .98 2808 .70 2699.70 -4576 .96 505.60 5940786 .19 559477 .22 MWD+IFR-AK-CAZ-SC 6065.88 77.99 172 .92 2828 .24 2719.24 -4666 .51 518.26 5940696 .76 559490 .58 MWD+IFR-AK-CAZ-SC 6158.25 76.81 173 .93 2848 .39 2739.39 -4756 .06 528.58 5940607 .30 559501 .61 MWD+IFR-AK-CAZ-SC 6253.05 78.05 176 .87 2869 .03 2760.03 -4848 .28 536.00 5940515 .15 559509 .74 MWD+IFR-AK-CAZ-SC 6342.80 76.93 177 .06 2888 .47 2779.47 -4935 .77 540.64 5940427 .71 559515 .07 MWD+IFR-AK-CAZ-SC 6437.48 76.47 176 .98 2910 .25 2801.25 -5027 .79 545.43 5940335 .74 559520 .57 MWD+IFR-AK-CAZ-SC i 6529.67 76.10 176 .08 2932 .11 2823.11 -5117 .18 550.85 5940246 .40 559526 .69 MWD+IFR-AK-CAZ-SC ~ 6622.56 76.84 175 .50 2953 .84 2844.84 -5207 .25 557.48 5940156 .39 559534 .03 MWD+IFR-AK-CAZ-SC 6714.88 77.55 174 .13 2974 .30 2865.30 -5296 .90 565.61 5940066 .82 559542 .87 MWD+IFR-AK-CAZ-SC 6807.71 77.36 174 .04 2994 .47 2885.47 -5387 .03 574.95 5939976 .77 559552 .91 MWD+IFR-AK-CAZ-SC ~ialliburton Company Survey Report Compam : ConocoPhillipsAlaska Inc. Date: 10/18!2006 'l'ime: 13:54:42 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeII: 1J-13 7, TrueNorth Site: Kuparuk 1J Pad Vertic al (TVD)Reference: 1J-137L1:109.0 R'ell: 1J -137 Sectio n'(VS)Reference:`' Well (O.OON,O.OOE,180.OOAzi) 1'fellpath: 1J -137L1 Survey Calculati on Method: Minimum C urvature Db: Oracle Survey __ _ Nt11 Licl claim ~fVD 1vs TV D ti'!S EJW __ MapA' MapE foo! ', ft deg deg ft ft ft ft ft ft 6899. 57 77.48 173. 81 3014. 47 2905 .47 -5476. 18 584.44 5939887. 70 559563. 09 MWD+IFR-AK-CAZ-SC 6992. 24 77.42 173. 18 3034. 61 2925 .61 -5566. 06 594.69 5939797. 92 559574. 04 MWD+IFR-AK-CAZ-SC 7085 .82 77.87 173. 78 3054. 63 2945 .63 -5656. 88 605.07 5939707. 19 559585. 13 MWD+IFR-AK-CAZ-SC 7177. 28 76.75 173. 77 3074. 72 2965 .72 -5745. 58 614.74 5939618. 58 559595. 50 MWD+IFR-AK-CAZ-SC 7270. 11 76.04 174. 21 3096. 56 2987 .56 -5835. 30 624.19 5939528. 94 559605. 65 MWD+IFR-AK-CAZ-SC 7363. 92 76.22 174. 08 3119. 05 3010 .05 -5925. 90 633.48 5939438. 42 559615. 65 MWD+IFR-AK-CAZ-SC 7456. 86 76.16 173. 38 3141. 23 3032 .23 -6015. 62 643.34 5939348. 80 559626. 20 MWD+IFR-AK-CAZ-SC ~ 7548. 24 75.47 171. 20 3163. 63 3054 .63 -6103. 40 655.22 5939261. 12 559638. 77 MWD+IFR-AK-CAZ-SC 7641. 58 74.89 170. 79 3187. 50 3078 .50 -6192. 53 669.34 5939172. 12 559653. 59 MWD+IFR-AK-CAZ-SC I 7734. 23 75.56 171. 49 3211. 13 3102 .13 -6281. 04 683.14 5939083. 72 559668. 08 MWD+IFR-AK-CAZ-SC 7826. 90 77.66 171. 21 3232. 59 3123 .59 -6370 .16 696.70 5938994. 72 559682. 33 MWD+IFR-AK-CAZ-SC 7920. 45 77.49 171. 41 3252. 72 3143 .72 -6460. 47 710.50 5938904. 53 559696. 84 MWD+IFR-AK-CAZ-SC 8012. 05 76.67 172. 46 3273. 20 3164 .20 -6548. 87 723.03 5938816. 24 559710. 06 MWD+IFR-AK-CAZ-SC 8104. 88 76.05 173. 76 3295. 09 3186 .09 -6638. 43 733.85 5938726. 78 559721. 58 MWD+IFR-AK-CAZ-SC 8198. 91 76.79 174. 84 3317. 17 3208 .17 -6729. 37 742.93 5938635. 91 559731. 37 MWD+IFR-AK-CAZ-SC 8289. 86 77.36 175. 41 3337. 52 3228 .52 -6817. 70 750.46 5938547. 66 559739. 59 MWD+IFR-AK-CAZ-SC 8382. 40 78.23 176. 23 3357. 08 3248 .08 -6907. 90 757.05 5938457. 52 559746. 89 MWD+IFR-AK-CAZ-SC 8475. 66 78.37 176. 20 3375. 99 3266 .99 -6999. 03 763.08 5938366. 45 559753. 63 MWD+IFR-AK-CAZ-SC 8567. 44 79.91 177. 82 3393. 28 3284 .28 -7089. 04 767.78 5938276. 49 559759. 03 MWD+IFR-AK-CAZ-SC 8660. 16 79.04 177. 65 3410. 22 3301 .22 -7180. 12 771.38 5938185. 44 559763. 34 MWD+IFR-AK-CAZ-SC ~ 8753. 21 79.80 177. 26 3427. 31 3318 .31 -7271. 50 775.44 5938094. 11 559768. 12 MWD+IFR-AK-CAZ-SC 8846. 13 80.61 177. 85 3443. 11 3334 .11 -7362. 98 779.35 5938002. 67 559772. 74 MWD+IFR-AK-CAZ-SC 8921. 00 79.82 177. 82 3455. 84 3346 .84 -7436. 71 782.14 5937928. 97 559776. 11 MWD+IFR-AK-CAZ-SC 9008 .99 83.59 181. 17 3468. 53 3359 .53 -7523. 75 782.89 5937841. 95 559777. 54 MWD+IFR-AK-CAZ-SC 9101. 15 90.40 184. 62 3473. 36 3364 .36 -7615. 59 778.24 5937750. 08 559773. 61 MWD+-FR-AK-CAZ-SC 9194. 39 91.54 183. 98 3471. 78 3362 .78 -7708. 56 771.25 5937657. 08 559767. 35 MWD+IFR-AK-CAZ-SC 9286. 16 90.41 183. 99 3470. 22 3361 .22 -7800. 09 764.87 5937565. 50 559761. 69 MWD+IFR-AK-CAZ-SC 9379. 16 91.21 184. 54 3468. 91 3359 .91 -7892. 82 757.96 5937472. 73 559755. 50 MWD+IFR-AK-CAZ-SC 9473. 15 93.47 183. 65 3465. 07 3356 .07 -7986. 49 751.25 5937379. 03 559749. 53 MWD+IFR-AK-CAZ-SC 9566. 73 91.08 180. 16 3461. 36 3352 .36 -8079. 92 748.14 5937285. 58 559747. 15 MWD+IFR-AK-CAZ-SC i 9658. 92 90.41 178. 23 3460. 16 3351 .16 -8172. 09 749.44 5937193. 43 559749. 17 MWD+IFR-AK-CAZ-SC 9751. 15 88.74 176. 78 3460. 84 3351 .84 -8264. 22 753.45 5937101. 34 559753. 90 MWD+IFR-AK-CAZ-SC i 9843. 84 89.56 177. 78 3462. 22 3353 .22 -8356. 80 757.85 5937008. 81 559759. 02 MWD+IFR-AK-CAZ-SC t 9936. 42 90.86 179. 71 3461. 88 3352 .88 -8449. 35 759.88 5936916. 29 559761. 78 MWD+IFR-AK-CAZ-SC 10029. 32 93.46 181. 26 3458. 38 3349 .38 -8542. 17 759.09 5936823. 48 559761. 72 MWD+IFR-AK-CAZ-SC i 10121. 23 92.89 179. 40 3453. 28 3344 .28 -8633. 93 758.57 5936731. 72 559761. 91 MWD+IFR-AK-CAZ-SC 10213 .64 92.89 178. 10 3448. 63 3339 .63 -8726. 20 760.58 5936639. 48 559764. 64 MWD+IFR-AK-CAZ-SC 10307 .32 90.28 178. 39 3446. 03 3337 .03 -8819 .79 763.45 5936545. 92 559768. 24 MWD+IFR-AK-CAZ-SC 10399. 79 91.97 180. 37 3444. 22 3335 .22 -8912. 23 764.45 5936453. 50 559769. 97 MWD+tFR-AK-CAZ-SC 10492. 00 90.72 180. 55 3442. 05 3333 .05 -9004. 41 763.71 5936361. 33 559769. 95 MWD+IFR-AK-CAZ-SC 10584. 46 91.29 180. 51 3440. 43 3331 .43 -9096. 85 762.85 5936268. 89 559769. 82 MWD+IFR-AK-CAZ-SC I 10677. 42 93.21 181. 94 3436. 78 3327 .78 -9189. 71 760.87 5936176. 03 559768. 56 MWD+IFR-AK-CAZ-SC 10770. 28 95.69 181. 10 3429. 58 3320 .58 -9282. 25 758.41 5936083. 48 559766. 83 MWD+IFR-AK-CAZ-SC 10867. 01 94.49 180. 01 3421. 00 3312 .00 -9378. 59 757.48 5935987. 15 559766. 65 MWD+IFR-AK-CAZ-SC 10963 .48 90.89 178. 59 3416. 47 3307 .47 -9474 .93 758.66 5935890. 83 559768. 58 MWD+IFR-AK-CAZ-SC 11058. 82 92.03 178. 88 3414. 04 3305 .04 -9570. 21 760.76 5935795. 57 559771. 43 MWD+IFR-AK-CAZ-SC 11115. 00 92.38 179. 07 3411. 88 3302 .88 -9626. 34 761.77 5935739. 46 559772. 87 MWD+IFR-AK-CAZ-SC 11155. 95 88.34 178. 96 3411. 62 3302 .62 -9667. 28 762.47 5935698. 54 559773. 90 MWD+IFR-AK-CAZ-SC 11252. 30 89.38 179 23 3413 54 3304 .54 -9763 59 763 99 5935602. 24 559776 17 MWD+IFR-AK-CAZ-SC i 11347. 65 90.49 . 177. 74 . 3413. 65 3304 .65 . -9858. 91 . 766.51 5935506. 96 . 559779. 44 MWD+IFR-AK-CAZ-SC 11444. 97 88,87 175. 54 3414. 19 3305 .19 -9956. 05 772.22 5935409. 88 559785. 90 MWD+IFR-AK-CAZ-SC 11543. 17 89.87 174. 41 3415. 27 3306 .27 -10053. 86 780.82 5935312. 14 559795. 27 MWD+IFR-AK-CAZ-SC ~Ialliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Ritei Kuparuk 1J Pad «'cll: 1J-137 ~1~cllpath: 1J-13711 Survey _____ M71 ]nc1 Azim TVD ft deg deg ft a TVD ft _ S ft _ Date: 10/18/2006 Caordinate(NE) Reference: 'Vertical (TVD?Reference: Section (VS) Reference: Survey Calculation ~Miethod: EtW 1~1apN ft ft Time:. 13:54:42 Page: -t 1PJell: 1J-137, True North 1J-137L1' 1.09.0 Well (O.OON;O:OOE,180.OOAZi) Minimum Curvature Db: Oracfe MapE Cool ft 11640 .46 91.48 173.82 3414. 12 3305.12 -10150 .63 790.79 5935215 .47 559806.00 __..-- MWD+IFR-AK-CAZ-SC 11735 .74 93.09 172.49 3410. 32 3301.32 -10245 .15 802.14 5935121 .05 559818.08 MWD+IFR-AK-CAZ-SC 11832 .41 89.79 171.57 3407. 90 3298.90 -10340 .84 815.53 5935025 .47 559832.23 MWD+IFR-AK-CAZ-SC 11929 .18 88.50 171.85 3409. 34 3300.34 -10436 .59 829.48 5934929 .85 559846.93 MWD+IFR-AK-CAZ-SC j 12025 .39 91.62 172.92 3409. 24 3300.24 -10531 .94 842.23 5934834 .61 559860.42 MWD+IFR-AK-CAZ-SC ! 12122 .14 90.48 173.04 3407. 47 3298.47 -10627 .94 854.05 5934738 .71 559872.99 MWD+IFR-AK-CAZ-SC 12218 .21 89.43 174.09 3407. 54 3298.54 -10723 .40 864.82 5934643 .34 559884.50 MWD+IFR-AK-CAZ-SC 12314 .98 85.96 172.71 3411. 43 3302.43 -10819 .44 875.93 5934547 .41 559896.36 MWD+IFR-AK-CAZ-SC 12412 .24 87.47 173.09 3417. 01 3308.01 -10915 .79 887.93 5934451 .16 559909.12 MWD+IFR-AK-CAZ-SC 12506 .19 86.28 171.74 3422. 13 3313.13 -11008 .78 900.31 5934358 .28 559922.22 MWD+IFR-AK-CAZ-SC 12603 .85 87.10 172.38 3427. 77 3318.77 -11105 .34 913.78 5934261 .84 559936.44 MWD+IFR-AK-CAZ-SC 12700 .51 89.95 175.55 3430. 26 3321.26 -11201 .41 923.94 5934165 .86 559947.35 MWD+IFR-AK-CAZ-SC 12797 .27 93.79 175.52 3427. 10 3318.10 -11297 .81 931.46 5934069 .54 559955.63 MWD+IFR-AK-CAZ-SC 12893 .91 92.94 176.67 3421. 43 3312.43 -11394 .05 938.03 5933973 .35 559962.95 MWD+IFR-AK-CAZ-SC 12990 .77 90.15 178.30 3418. 81 3309.81 -11490 .77 942.28 5933876 .68 559967.96 MWD+IFR-AK-CAZ-SC 13086 .06 89.99 181.90 3418. 70 3309.70 -11586 .05 942.11 5933781 .42 559968.54 MWD+IFR-AK-CAZ-SC 13182 .97 90.61 182.01 3418. 19 3309.19 -11682 .90 938.81 5933684 .55 559965.99 MWD+IFR-AK-CAZ-SC ~ 13279 .81 92.22 182.58 3415. 80 3306.80 -11779 .63 934.93 5933587 .80 559962.87 MWD+IFR-AK-CAZ-SC 13376 .58 90.66 183.75 3413. 37 3304.37 -11876 .21 929.59 5933491 .19 559958.28 MWD+IFR-AK-CAZ-SC 13472 .15 90.67 185.41 3412. 26 3303.26 -11971 .47 921.96 5933395 .88 559951.40 MWD+IFR-AK-CAZ-SC 13567 .91 91.35 183.42 3410. 57 3301.57 -12066 .92 914.59 5933300 .38 559944.78 MWD+IFR-AK-CAZ-SC 13663 .58 93.15 183.61 3406. 81 3297.81 -12162 .34 908.73 5933204 .94 559939.67 MWD+IFR-AK-CAZ-SC 13757 .69 95.07 182.75 3400. 07 3291.07 -12256 .05 903.52 5933111 .19 559935.19 MWD+IFR-AK-CAZ-SC ! 13840 .00 92.89 182.69 3394. 36 3285.36 -12338 .07 899.63 5933029 .15 559931.94 MWD+IFR-AK-CAZ-SC 13904 .99 90.49 183.32 3392. 44 3283.44 -12402 .94 896.22 5932964 .27 559929.04 MWD+IFR-AK-CAZ-SC 13943 .35 90.74 183.44 3392. 03 3283.03 -12441 .23 893.96 5932925 .97 559927.08 MWD+IFR-AK-CAZ-SC 13984 .80 90.61 184.29 3391. 54 3282.54 -12482 .58 891.16 5932884 .60 559924.61 MWD+IFR-AK-CAZ-SC 14034 .92 89.18 184.40 3391. 63 3282.63 -12532 .55 887.37 5932834 .60 559921.20 MWD+IFR-AK-CAZ-SC 14075 .20 88.75 183.93 3392. 36 3283.36 -12572 .72 884.44 5932794 .41 559918.59 MWD+IFR-AK-CAZ-SC 14137 .97 89.57 180.64 3393. 28 3284.28 -12635 .43 881.94 5932731 .70 559916.58 MWD+IFR-AK-CAZ-SC ~ 14230 .79 92.54 177.04 3391. 57 3282.57 -12728 .18 883.82 5932638 .96 559919.18 ~ MWD+IFR-AK-CAZ-SC 14321 .69 93.96 178.39 3386. 42 3277.42 -12818 .86 887.44 5932548 .33 559923.51 MWD+IFR-AK-CAZ-SC i 14413 .80 93.26 177.20 3380. 62 3271.62 -12910 .72 890.97 5932456 .51 559927.77 MWD+IFR-AK-CAZ-SC 14507 .87 91.23 177.04 3376. 93 3267.93 -13004 .59 895.70 5932362 .68 559933.23 MWD+IFR-AK-CAZ-SC 14599 .10 90.68 177.23 3375. 41 3266.41 -13095 .70 900.26 5932271 .63 559938.50 MWD+IFR-AK-CAZ-SC 14691 .95 89.07 174.09 3375. 61 3266.61 -13188 .26 907.28 5932179 .13 559946.25 MWD+IFR-AK-CAZ-SC 14784 .53 87.30 173.59 3378. 55 3269.55 -13280 .26 917.21 5932087 .22 559956.89 MWD+IFR-AK-CAZ-SC 14877 .85 88.14 174.66 3382. 26 3273.26 -13373 .01 926.75 5931994 .55 559967.16 MWD+IFR-AK-CAZ-SC 14970 .44 90.84 177.68 3383. 08 3274.08 -13465 .37 932.94 5931902 .25 559974.07 MWD+IFR-AK-CAZ-SC 15063 .17 90.39 180.22 3382. 09 3273.09 -13558 .08 934.64 5931809 .58 559976.49 MWD+IFR-AK-CAZ-SC 15155 .90 90.24 181.07 3381. 58 3272.58 -13650 .80 933.59 5931716 .86 559976.17 MWD+IFR-AK-CAZ-SC 15247 .65 90.39 180.16 3381. 07 3272.07 -13742 .54 932.61 5931625 .12 559975.91 MWD+IFR-AK-CAZ-SC 15341 .88 90.25 181.49 3380. 55 3271.55 -13836 .76 931.25 5931530 .90 559975.29 MWD+IFR-AK-CAZ-SC 15432 .51 91.72 183.12 3378. 99 3269.99 -13927 .29 927.61 5931440 .35 559972.35 MWD+IFR-AK-CAZ-SC 15526 .41 92.17 182.95 3375. 80 3266.80 -14021 .01 922.64 5931346 .61 559968.12 MWD+IFR-AK-CAZ-SC 15618 .54 90.55 183.99 3373. 62 3264.62 -14112 .94 917.06 5931254 .65 559963.26 MWD+IFR-AK-CAZ-SC '; 15710 .96 91.57 183.49 3371. 91 3262.91 -14205 .15 911.04 5931162 .40 559957.96 MWD+IFR-AK-CAZ-SC '~ 15804 .23 92.17 182.98 3368. 86 3259.86 -14298 .22 905.77 5931069 .30 559953.43 MWD+IFR-AK-CAZ-SC 15896 .93 91.43 183.42 3365. 95 3256.95 -14390 .73 900.60 5930976 .77 559948.98 MWD+IFR-AK-CAZ-SC i 15991 .00 90.24 184.17 3364. 58 3255.58 -14484 .58 894.38 5930882 .88 559943.49 MWD+IFR-AK-CAZ-SC 16080 .69 90.30 184.84 3364. 16 3255.16 -14573 .99 887.33 5930793 .42 559937.14 MWD+IFR-AK-CAZ-SC 16176 .31 91.56 183.45 3362. 61 3253.61 -14669 .34 880.42 5930698 .03 559930.98 MWD+IFR-AK-CAZ-SC 16268 .02 90.18 181.07 3361. 21 3252.21 -14760 .96 876.81 5930606 .39 559928.08 MWD+IFR-AK-CAZ-SC ~Ialliburton Company Survey Report Company; ConocoPhillipsAlaska Inc. Date: 10/18/2006 Timr. 13:54:42 Pagc: 5 Rield: Kuparuk Ri~erUnit Co-ordinate(NE} Reference: Well: 1J-137, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-137L1: 109.0 Well: 1J-137 Seetion(VS)Reference: Well (OQON,O.OOE,180.OOAzi) Wellpath: 1J-137L1 __ _ _ Survey Calculation Method: Minimum Curvature Db: Oracle , Survey MD Incl Azim TVD SysTVD N/S ft deg deg ft ft ft 16361 .64 89.44 178.49 3361.52 3252.52 -14854 .57 16453 .81 91.47 181.04 3360.79 3251.79 -14946 .72 16546 .52 91.11 179.71 3358.70 3249.70 -15039 .41 16639 .19 89.39 180.23 3358.30 3249.30 -15132 .07 16730 .96 89.15 180.96 3359.47 3250.47 -15223 .83 16793 .94 89.20 181.20 3360.38 3251.38 -15286 .79 . 16840 .00 89.20 181.20 3361.02 .3252.02 -15332 .84 E/W 1~1apN ft ft 877.17 ~ 5930512.80 877.54 5930420.66 876.94 5930327.98 876.99 5930235.33 876.03 5930143.58 874.85 5930080.61 873.88 5930034.56 MapE Tool ft 559929.17 MWD+IFR-AK-CAZ-SC 559930.27 MWD+IFR-AK-CAZ-SC 559930.39 MWD+IFR-AK-CAZ-SC 559931.17 MWD+IFR-AK-CAZ-SC 559930.93 MWD+IFR-AK-CAZ-SC 559930.24 MWD+IFR-AK-CAZ-SC 559929.63 .PROJECTED to TD ~Ialliburton Company ;~ Survey Report C.ompam: GonocoPhillipsAlaska inc. Uarc: 10118!2006 Time: 13:40:41 P~gc: 1 Field: Kuparuk River Unit Co -ordinate(NE) Reference: Well: 1J-137, True North Site: Kuparuk 1J Pad Ve rtical (TVD) Re ference: 1J-137L1P61: 109.0 WeH: 1 J-137 Section (VS) Reference: Well (O.OON,0.OOE,180:OOAzi) Wellpath: ~1J-i37L1P61 Su rvey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-137 Slot Name: Well Position: +N/-S -562.20 ft Northing: 5945358.62 ft Latitude: 70 15 40.728 N +E/-W 141.55 ft Easti ng : 558935.87 ft Longitude: 149 31 24.888 W Position Uncertainty: 0.00 ft ~ Wellpath: 1J-137L1P61 Drilled From: 1J-137 500292331670 Tie-on Depth: 8846.13 ft Current Datum: 1 J-137L1 PB1: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 8/9/2006 Declination: 23.84 deg Field Strength: 57607 nT Mag Dip Angl e: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~ 28.00 0.00 0.00 180.00 Survey Program for DeTinitive Wellpath Date: 10/18!2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 724.00 1 J-137 gyro (50.00-724.00) (2) C B-GYRO-SS Camera based gyro si ngle shot 763.95 8846.13 1 J-137 (763.95-17352.25) (2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8921.00 13894.20 1 J-137L1 P61 (8921 .00-13894.20) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey VID Inc! Azim IVU Sys"Nll N/5 E/W MapN ytapL fool ', ft deg deg ft ft ft ft_, " ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945358.62 558935.87 TIE LINE 50.00 0.13 197.98 50.00 -59.00 -0.02 -0.01 5945358.60 558935.86 CB-GYRO-SS 100.00 0.24 63.32 100.00 -9.00 -0.03 0.07 5945358.59 558935.94 CB-GYRO-SS 172.00 0.30 138.87 172.00 63.00 -0.10 0.33 5945358.52 558936.20 CB-GYRO-SS 266.00 0.53 174.43 266.00 157.00 -0.72 0.53 5945357.90 558936.41 CB-GYRO-SS 355.00 2.61 178.49 354.96 245.96 -3.16 0.62 5945355.47 558936.52 CB-GYRO-SS 447.00 5.47 183.45 446.72 337.72 -9.63 0.42 5945348.99 558936.36 CB-GYRO-SS 539.00 8.20 189.23 538.06 429.06 -20.49 -0.90 5945338.13 558935.13 CB-GYRO-SS 631.00 10.28 191.38 628.86 519.86 -35.01 -3.57 5945323.58 558932.57 CB-GYRO-SS 724.00 13.86 185.23 719.79 610.79 -54.25 -6.23 5945304.33 558930.07 CB-GYRO-SS ' , 763.95 15.51 179.17 758.44 649.44 -64.35 -6.59 5945294.22 558929.79 MWD+IFR-AK-CAZ-SC ~ 823.36 17.99 175.81 815.33 706.33 -81.45 -5.80 5945277.14 558930.71 MWD+IFR-AK-CAZ-SC ~ 887.30 18.59 175.68 876.04 767.04 -101.46 -4.31 5945257.14 558932.35 MWD+IFR-AK-CAZ-SC 949.28 20.29 172.60 934.48 825.48 -121.97 -2.18 5945236.65 558934.64 MWD+IFR-AK-CAZ-SC 1042.06 23.01 173.50 1020.71 911.71 -155.95 1.94 5945202.71 558939.03 MWD+IFR-AK-CAZ-SC ~ 1135.19 26.07 176.82 1105.42 996.42 -194.47 5.14 5945164.21 558942.53 MWD+IFR-AK-CAZ-SC ~ 1226.83 29.28 172.02 1186,58 1077.58 -236.79 9.37 5945121.93 558947.09 MWD+IFR-AK-CAZ-SC j 1320.18 35.08 170.94 1265.55 1156.55 -285.93 16.77 5945072.86 558954.87 MWD+IFR-AK-CAZ-SC ~ 1412.00 40.64 174.74 1338.03 1229.03 -341.81 23.67 5945017.04 558962.21 MWD+IFR-AK-CAZ-SC 1503.17 41.99 173.66 1406.50 1297.50 -401.69 29.76 5944957.21 558968.77 MWD+IFR-AK-CAZ-SC 1598.34 46.25 172.02 1474.81 1365.81 -467.40 38.05 5944891.57 558977.58 MWD+IFR-AK-CAZ-SC 1689.63 47.62 171.58 1537.14 1428.14 -533.41 47.57 5944825.65 558987.61 MWD+IFR-AK-CAZ-SC 1782.86 52.69 172.13 1596.86 1487.86 -604.25 57.69 5944754.90 558998.28 MWD+IFR-AK-CAZ-SC 1874.98 58.51 171.82 1648.88 1539.88 -679.48 68.31 5944679.76 559009.49 MWD+IFR-AK-CAZ-SC 1968.36 62.75 172.58 1694.67 1585.67 -760.09 79.34 5944599.25 559021.15 MWD+IFR-AK-CAZ-SC 2060.33 67.69 174.04 1733.21 1624.21 -843.00 89.04 5944516.43 559031.50 MWD+IFR-AK-CAZ-SC 2154.58 70.88 174.98 1766.54 1657.54 -930.74 97.47 5944428.76 559040.61 MWD+IFR-AK-CAZ-SC 2245.74 74.22 173.42 1793.88 1684.88 -1017.24 106.26 5944342.34 559050.08 MWD+IFR-AK-CAZ-SC alliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 10/18/2006 Time: 13:40:41 Page: Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-13 7, True North Site: Kuparuk 1J Pad Vertic at4TVD) Reference: 1J-137L1P61: 109.0 Well: 1J -137 Sectio n (VS) Refereuce: Well (O.OON,O.OOE,180.OOAzi) W'el-path: 1J -137L1PB1 Survey Calculafion Method: Minimum C urv ature Db:l Oracle Survey bID Intl 1Lini ill) ti~sT'VD ti'iS F/~~~ ~~tapA JfapE ---_ ~ILuI ft deg deg ft ft ft ft ft ft 2339 .09 74.41 172 .78 1819. 11 1710.11 -1106. 46 117.06 5944253. 21 559061. 58 MWD+IFR-AK-CAZ-SC 2431 .72 75.51 173 .66 1843. 15 1734.15 -1195 .29 127.62 5944164. 48 559072. 83 MWD+IFR-AK-CAZ-SC 2524 .49 74.98 174 .15 1866. 78 1757.78 -1284 .49 137.15 5944075 .36 559083 .05 MWD+IFR-AK-CAZ-SC ~ 2617 .50 74.92 174 .02 1890. 93 1781.93 -1373 .83 146.40 5943986 .10 559093 .00 MWD+IFR-AK-CAZ-SC i 2710 .09 76.61 173 .80 1913. 70 1804.70 -1463 .07 155.92 5943896 .95 559103 .22 MWD+IFR-AK-CAZ-SC I 2806 .73 76.45 174 .39 1936. 21 1827.21 -1556 .55 165.59 5943803 .56 559113 .62 MWD+IFR-AK-CAZ-SC 2893 .92 76.38 173 .83 1956. 69 1847.69 -1640 .86 174.29 5943719. 33 559122. 98 MWD+IFR-AK-CAZ-SC 2987 .00 76.20 174 .83 1978. 75 1869.75 -1730 .84 183.22 5943629. 43 559132 .62 MWD+IFR-AK-CAZ-SC 3080 .29 77.63 173 .97 1999. 87 1890.87 -1821 .27 192.09 5943539 .08 559142 .19 MWD+IFR-AK-CAZ-SC 3173 .18 77.93 174 .51 2019. 53 1910.53 -1911 .60 201.20 5943448 .84 559152 .01 MWD+IFR-AK-CAZ-SC 3266 .00 76.70 174 .66 2039. 91 1930.91 -2001 .75 209.75 5943358 .77 559161 .26 MWD+IFR-AK-CAZ-SC 3357 i .70 75.26 175 .44 2062. 13 1953.13 -2090 .38 217.43 5943270 .21 559169 .63 MWD+IFR-AK-CAZ-SC 3450 .47 74.84 174 .98 2086. 06 1977.06 -2179 .70 224.91 5943180. 96 559177. 81 MWD+IFR-AK-CAZ-SC 3544 .51 73.79 174 .11 2111. 48 2002.48 -2269 .82 233.52 5943090 .91 559187 .12 MWD+IFR-AK-CAZ-SC 3635 .78 74.92 174 .34 2136. 10 2027.10 -2357 .26 242.36 5943003 .55 559196 .65 MWD+IFR-AK-CAZ-SC 3728 .89 72.89 175 .08 2161. 91 2052.91 -2446 .34 250.61 5942914 .55 559205 .59 MWD+IFR-AK-CAZ-SC 3849 .43 73.59 173 .94 2196. 67 2087.67 -2561 .22 261.65 5942799 .77 559217 .53 MWD+IFR-AK-CAZ-SC 3945 .06 73.77 174 .38 2223. 54 2114.54 -2652 .53 270.99 5942708. 55 559227. 59 MWD+IFR-AK-CAZ-SC 4037 ,39 73.66 174 .59 2249. 43 2140.43 -2740 .74 279.51 5942620. 41 559236. 79 MWD+IFR-AK-CAZ-SC 4130 .08 73.38 174 .15 2275. 73 2166.73 -2829 .19 288.23 5942532 .04 559246 .20 MWD+IFR-AK-CAZ-SC 4221 .53 73.07 175 .42 2302. 12 2193.12 -2916 .39 296.19 5942444 .92 559254 .84 MWD+IFR-AK-CAZ-SC 4314 .42 72.29 174 .98 2329. 77 2220.77 -3004 .75 303.61 5942356 .62 559262 .95 MWD+IFR-AK-CAZ-SC 4407 .30 71.64 174 .56 2358. 53 2249.53 -3092 .70 311.66 5942268 .75 559271 .69 MWD+IFR-AK-CAZ-SC 4500 .05 70.40 175. 27 2388. 70 2279.70 -3180 .06 319.43 5942181. 46 559280. 15 MWD+IFR-AK-CAZ-SC 4593 .31 69.54 175 .23 2420. 64 2311.64 -3267 .38 326.69 5942094 .21 559288 .09 MWD+IFR-AK-CAZ-SC 4686 .06 67.99 174 .93 2454. 23 2345.23 -3353 .51 334.10 5942008 .15 559296 .17. MWD+IFR-AK-CAZ-SC 4722 .17 67.88 174 .99 2467. 80 2358.80 -3386 .85 337.04 5941974 .84 559299 .37 MWD+IFR-AK-CAZ-SC 4774 .74 68.06 175 .07 2487. 51 2378.51 -3435 .39 341.26 5941926 .33 559303 .98 MWD+IFR-AK-CAZ-SC 4867 .41 70.58 172 .10 2520. 24 2411.24 -3521 .53 350.97 5941840 .28 559314 .35 MWD+IFR-AK-CAZ-SC 4959 .80 70.52 172. 73 2551. 01 2442.01 -3607 .88 362.47 5941754. 03 559326. 53 MWD+IFR-AK-CAZ-SC 5053 .68 73.11 172 .65 2580. 30 2471.30 -3696 .34 373.81 5941665 .67 559338. 56 MWD+IFR-AK-CAZ-SC 5078 .87 73.41 172 .76 2587. 56 2478.56 -3720 .27 376.88 5941641 .77 559341 .81 MWD+IFR-AK-CAZ-SC 5146 .52 73.91 173 .06 2606. 59 2497.59 -3784 .69 384.89 5941577 .42 559350 .33 MWD+IFR-AK-CAZ-SC 5238 .16 73.84 171 .70 2632. 05 2523.05 -3871 .95 396.56 5941490 .27 559362 .68 MWD+IFR-AK-CAZ-SC 5332 .09 73.99 172 .10 2658. 07 2549.07 -3961 .30 409.28 5941401 .03 559376 .10 MWD+IFR-AK-CAZ-SC 5424 .24 76.40 171. 46 2681. 62 2572.62 -4049 .47 422.02 5941312 .97 559389 .53 MWD+IFR-AK-CAZ-SC 5517 .07 76.63 171. 01 2703. 26 2594.26 -4138 .68 435.77 5941223. 87 559403. 98 MWD+IFR-AK-CAZ-SC 5608 .84 74.29 171 .44 2726. 30 2617.30 -4226 .47 449.33 5941136 .21 559418 .22 MWD+IFR-AK-CAZ-SC 5702 .22 76.83 172 .48 2749. 59 2640.59 -4316 .00 461.97 5941046 .78 559431 .56 MWD+IFR-AK-CAZ-SC 5787 .86 77.17 169 .47 2768. 85 2659.85 -4398 .40 475,06 5940964 .49 559445 .29 MWD+IFR-AK-CAZ-SC 5881 .33 77.80 170 .37 2789. 11 2680.11 -4488 .24 491.03 5940874 .79 559461 .96 MWD+IFR-AK-CAZ-SC 5973 .35 77.62 170 .98 2808. 70 2699.70 -4576. 96 505.60 5940786 .19 559477 .22 MWD+IFR-AK-CAZ-SC 6065 .88 77.99 172 .92 2828. 24 2719.24 -4666 .51 518.26 5940696 .76 559490. 58 MWD+IFR-AK-CAZ-SC 6158 .25 76.81 173 .93 2848. 39 2739.39 -4756 .06 528.58 5940607 .30 559501 .61 MWD+IFR-AK-CAZ-SC 6253 .05 78.05 176 .87 2869. 03 2760.03 -4848 .28 536.00 5940515 .15 559509 .74 MWD+IFR-AK-CAZ-SC 6342 .80 76.93 177 .06 2888. 47 2779.47 -4935 .77 540.64 5940427 .71 559515 .07 MWD+IFR-AK-CAZ-SC 6437 .48 76.47 176 .98 2910. 25 2801.25 -5027 .79 545.43 5940335 .74 559520 .57 MWD+IFR-AK-CAZ-SC 6529 .67 76.10 176. 08 2932. 11 2823.11 -5117 .18 550.85 5940246 .40 559526. 69 MWD+IFR-AK-CAZ-SC 6622 .56 76.84 175 .50 2953. 84 2844.84 -5207 .25 557.48 5940156 .39 559534 .03 MWD+IFR-AK-CAZ-SC 6714 .88 77.55 174 .13 2974. 30 2865.30 -5296 .90 565.61 5940066 .82 559542 .87 MWD+IFR-AK-CAZ-SC 6807 .71 77.36 174 .04 2994. 47 2885.47 -5387 .03 574.95 5939976 .77 559552 .91 MWD+IFR-AK-CAZ-SC 6899 .57 77.48 173 .81 3014. 47 2905.47 -5476 .18 584.44 5939887 .70 559563 .09 MWD+IFR-AK-CAZ-SC ~alliburton Company ;~ Survey Report Company: ConocoPhillips Alaska inc. Date: 10/18/2006 Timr. 13:40:41 Pa;;e: 3 Field: Ku paruk River Unit Co-ordinate(NE) Reference: Well: 1J-137, True North Site: Ku paruk 1 J Pad Vertical (TVD) Reference: 1 J-137L1 PB1: 109.0 Well: 1J -137 Sectio n (VS) Reference: Well (O.OON,O.QOE,180.OOAzi),, ~Yellpath: 1J -137L1P61 Survey Calculation Method: Minimum Curv ature Db: Oracle Survey' ?VID Incl Azim TVD Sysll'IJ N/S Erti~' 'v1apN ~[apE Foul ft deg deg ft ft ft ft ft ft _ 6992.24 77. 42 173.18 - 3034 .61 2925. - 61 - -5566. 06 594.69 5939797 .92 _ 559574.04 __ _ MWD+IFR-AK-CAZ-SC 7085.82 77. 87 173.78 3054 .63 2945. 63 -5656. 88 605.07 5939707 .19 559585.13 MWD+IFR-AK-CAZ-SC 7177.28 76. 75 173.77 3074 .72 2965. 72 -5745. 58 614.74 5939618 .58 559595.50 MWD+IFR-AK-CAZ-SC 7270.11 76. 04 174.21 3096 .56 2987. 56 -5835. 30 624.19 5939528 .94 559605.65 MWD+IFR-AK-CAZ-SC 7363.92 76. 22 174.08 3119 .05 3010. 05 -5925. 90 633.48 5939438 .42 559615.65 MWD+IFR-AK-CAZ-SC 7456.86 76. 16 173.38 3141. 23 3032. 23 -6015. 62 643.34 5939348 .80 559626.20 MWD+IFR-AK-CAZ-SC I 7548.24 75. 47 171.20 3163. 63 3054. 63 -6103. 40 655.22 5939261 .12 559638.77 MWD+IFR-AK-CAZ-SC 7641.58 74. 89 170.79 3187 .50 3078. 50 -6192. 53 669.34 5939172 .12 559653.59 MWD+IFR-AK-CAZ-SC 7734.23 75. 56 171.49 3211 .13 3102. 13 -6281. 04 683.14 5939083 .72 559668.08 MWD+IFR-AK-CAZ-SC 7826.90 77. 66 171.21 3232 .59 3123. 59 -6370. 16 696.70 5938994 .72 559682.33 MWD+IFR-AK-CAZ-SC 7920.45 77. 49 171.41 3252 .72 3143. 72 -6460. 47 710.50 5938904 .53 559696.84 MWD+IFR-AK-CAZ-SC 8012.05 76. 67 172.46 3273. 20 3164. 20 -6548. 87 723.03 5938816 .24 559710.06 MWD+IFR-AK-CAZ-SC 8104.88 76. 05 173.76 3295. 09 3186. 09 -6638. 43 733.85 5938726 .78 559721.58 MWD+IFR-AK-CAZ-SC 8198.91 76. 79 174.84 3317 .17 3208. 17 -6729. 37 742.93 5938635 .91 559731.37 MWD+IFR-AK-CAZ-SC 8289.86 77. 36 175.41 3337 .52 3228. 52 -6817. 70 750.46 5938547 .66 559739.59 MWD+IFR-AK-CAZ-SC 8382.40 78. 23 176.23 3357 .08 3248. 08 -6907. 90 757.05 5938457 .52 559746.89 MWD+IFR-AK-CAZ-SC 8475.66 78. 37 176.20 3375 .99 3266. 99 -6999. 03 763.08 5938366 .45 559753.63 MWD+IFR-AK-CAZ-SC 8567.44 79. 91 177.82 3393 .28 3284. 28 -7089. 04 767.78 5938276 .49 559759.03 MWD+IFR-AK-CAZ-SC 8660.16 79. 04 177.65 3410. 22 3301. 22 -7180. 12 771.38 5938185 .44 559763.34 MWD+IFR-AK-CAZ-SC 8753.21 79. 80 177.26 3427 .31 3318. 31 -7271. 50 775.44 5938094 .11 559768.12 MWD+IFR-AK-CAZ-SC 8846.13 80. 61 177.85 3443 .11 3334. 11 -7362. 98 779.35 5938002 .67 559772.74 MWD+IFR-AK-CAZ-SC 8921.00 79. 82 177.82 3455 .84 3346. 84 -7436. 71 782.14 5937928 .97 559776.11 MWD+IFR-AK-CAZ-SC 9008.99 83. 59 181.17 3468 .53 3359. 53 -7523. 75 782.89 5937841 .95 559777.54 MWD+IFR-AK-CAZ-SC 9101.15 90. 40 184.62 3473 .36 3364. 36 -7615. 59 778.24 5937750 .08 559773.61 MWD+IFR-AK-CAZ-SC 9194.39 91. 54 183.98 3471 .78 3362. 78 -7708. 56 771.25 5937657 .08 559767.35 MWD+IFR-AK-CAZ-SC 9286.16 90. 41 183.99 3470. 22 3361. 22 -7800. 09 764.87 5937565 .50 559761.69 MWD+IFR-AK-CAZ-SC 9379.16 91. 21 184.54 3468 .91 3359. 91 -7892. 82 757.96 5937472 .73 559755.50 MWD+IFR-AK-CAZ-SC 9473.15 93. 47 183.65 3465 .07 3356. 07 -7986. 49 751.25 5937379 .03 559749.53 MWD+IFR-AK-CAZ-SC 9566.73 91. 08 180.16 3461 .36 3352. 36 -8079. 92 748.14 5937285 .58 559747.15 MWD+IFR-AK-CAZ-SC 9658.92 90. 41 178.23 3460 .16 3351. 16 -8172. 09 749.44 5937193 .43 559749.17 MWD+IFR-AK-CAZ-SC 9751.15 88. 74 176.78 3460 .84 3351. 84 -8264. 22 753.45 5937101 .34 559753.90 MWD+IFR-AK-CAZ-SC 9843.84 89. 56 177.78 3462. 22 3353. 22 -8356. 80 757.85 5937008 .81 559759.02 MWD+IFR-AK-CAZ-SC 9936.42 90. 86 179.71 3461 .88 3352. 88 -8449. 35 759.88 5936916 .29 559761.78 MWD+IFR-AK-CAZ-SC 10029.32 93. 46 181.26 3458 .38 3349. 38 -8542. 17 759.09 5936823 .48 559761.72 MWD+IFR-AK-CAZ-SC 10121.23 92. 89 179.40 3453 .28 3344. 28 -8633. 93 758.57 5936731 .72 559761.91 MWD+IFR-AK-CAZ-SC 10213.64 92. 89 178.10 3448 .63 3339. 63 -8726. 20 760.58 5936639 .48 559764.64 MWD+IFR-AK-CAZ-SC 10307.32 90. 28 178.39 3446 .03 3337. 03 -8819. 79 763.45 5936545 .92 559768.24 MWD+IFR-AK-CAZ-SC 10399.79 91. 97 180.37 3444 .22 3335. 22 -8912. 23 764.45 5936453 .50 559769.97 MWD+IFR-AK-CAZ-SC 10492.00 90. 72 180.55 3442. 05 3333. 05 -9004. 41 763.71 5936361 .33 559769.95 MWD+IFR-AK-CAZ-SC 10584.46 91. 29 180.51 3440 .43 3331. 43 -9096. 85 762.85 5936268 .89 559769.82 MWD+IFR-AK-CAZ-SC 10677.42 93. 21 181.94 3436 .78 3327. 78 -9189. 71 760.87 5936176 .03 559768.56 MWD+IFR-AK-CAZ-SC 10770.28 95. 69 181.10 3429 .58 3320. 58 -9282. 25 758.41 5936083 .48 559766.83 MWD+IFR-AK-CAZ-SC 10867.01 94. 49 180.01 3421 .00 3312. 00 -9378. 59 757.48 5935987 .15 559766.65 MWD+IFR-AK-CAZ-SC 10963.48 90. 89 178.59 3416 .47 3307. 47 -9474. 93 758.66 5935890 .83 559768.58 MWD+IFR-AK-CAZ-SC 11058.82 92. 03 178.88 3414 .04 3305. 04 -9570. 21 760.76 5935795 .57 559771.43 MWD+IFR-AK-CAZ-SC 11157.51 92. 65 179.21 3410 .01 3301. 01 -9668. 81 762.41 5935697 .01 559773.85 MWD+IFR-AK-CAZ-SC 11252.25 92. 92 178.68 3405 .41 3296. 41 -9763. 42 764.15 5935602 .42 559776.33 MWD+IFR-AK-CAZ-SC 11348.74 91. 03 179.23 3402 .08 3293. 08 -9859. 83 765.91 5935506 .03 559778.84 MWD+IFR-AK-CAZ-SC 11444.42 88. 80 178.22 3402 .22 3293. 22 -9955. 48 768.04 5935410 .41 559781.72 MWD+IFR-AK-CAZ-SC I 11542.83 87. 01 178.31 3405 .82 3296. 82 -10053. 77 771.01 5935312 .15 559785.46 MWD+IFR-AK-CAZ-SC ~ 11639.59 89. 82 180.70 3408 .50 3299. 50 -10150. 48 771.85 5935215 .47 559787.06 MWD+IFR-AK-CAZ-SC 11734.79 92. 16 181.03 3406 .85 3297. 85 -10245. 64 770.41 5935120 .30 559786.36 MWD+IFR-AK-CAZ-SC 11831.90 91. 15 183.46 3404 .05 3295. 05 -10342. 63 766.61 5935023 .30 559783.32 MWD+IFR-AK-CAZ-SC ~ I ~Ialliburton Company Survey Report Company : ConocoPhillips,Alaska Inc. Date: 10/18!2006 Time: 13:40:41 P~tic: 4 Field: Ku paruk Rive r Unit Co-ordinate(NE) Reference: Well: 1J-13 7, T rue North 'Site: Ku paruk 1J Pad Vertic al (TVD} Reference; ' -1J-137L1P61: 109.0 Well: 1 J- 137 Sectio n (V5) Reference: Well (O.OON,O.OOE,180AOAzi) Wellpath: 1J- 137L1PB1 Surve~Calculati onmethod: Minimum C urv ature llb: Oracle Sure ey MD lucl Azim TVD SysTVD N/S ENV ti1apV MapE Tuul ~i ', ft deg deg ft - ft ft ft ft ft 11928. 24 91.10 186.27 3402.16 3293.16 -10438 .60 758.44 5934927.28 559775. 90 MWD+IFR-AK-CAZ-SC 12023. 84 90.97 190.49 3400.43 3291.43 -10533 .14 744.51 5934832.64 559762. 72 MWD+IFR-AK-CAZ-SC 12121. 52 90.05 189.28 3399.56 3290.56 -10629 .36 727.74 5934736.30 559746. 71 MWD+IFR-AK-CAZ-SC ~ ~ 12217. 19 87.76 186.61 3401.39 3292.39 -10724. 08 714.52 5934641.49 559734. 23 MWD+IFR-AK-CAZ-SC 12315. 14 88.57 183.22 3404.53 3295.53 -10821. 61 706.14 5934543.91 559726. 61 MWD+IFR-AK-CAZ-SC 12411. 17 92.17 185.11 3403.91 3294.91 -10917. 36 699.17 5934448.12 559720. 38 MWD+IFR-AK-CAZ-SC 12507. 92 93.88 183.64 3398.80 3289.80 -11013. 69 691.80 5934351.74 559713. 77 MWD+IFR-AK-CAZ-SC 12604. 06 92.82 180.29 3393.18 3284.18 -11109 .59 688.51 5934255.82 559711. 23 MWD+IFR-AK-CAZ-SC 12700. 98 91.46 178.60 3389.56 3280.56 -11206 .43 689.44 5934159.00 559712. 93 MWD+IFR-AK-CAZ-SC 12797. 79 89.17 180.83 3389.03 3280.03 -11303 .23 689.93 5934062.22 559714. 17 MWD+IFR-AK-CAZ-SC 12894. 11 91.42 181.27 3388.53 3279.53 -11399. 52 688.16 5933965.93 559713. 16 MWD+IFR-AK-CAZ-SC ~ 12990. 41 90.60 184.38 3386.83 3277.83 -11495. 68 683.42 5933869.75 559709. 16 MWD+IFR-AK-CAZ-SC 13086. 45 90.48 186.76 3385.93 3276.93 -11591 .25 674.10 5933774.11 559700. 59 MWD+IFR-AK-CAZ-SC 13184. 16 91.23 189.09 3384.47 3275.47 -11688 .01 660.63 5933677.26 559687. 88 MWD+IFR-AK-CAZ-SC 13280. 55 90.97 190.77 3382.62 3273.62 -11782 .94 644.01 5933582.21 559672. 01 MWD+IFR-AK-CAZ-SC 13376. 07 92.16 195.43 3380.01 3271.01 -11875 .91 622.37 5933489.08 559651. 10 MWD+IFR-AK-CAZ-SC 13472. 66 91.22 190.67 3377.16 3268.16 -11969 .94 600.58 5933394.90 559630. 05 MWD+IFR-AK-CAZ-SC i 13568. 31 91.04 186.18 3375.27 3266.27 -12064. 51 586.57 5933300.23 559616. 78 MWD+IFR-AK-CAZ-SC 13664. 40 90.36 186.38 3374.10 3265.10 -12160. 02 576.06 5933204.65 559607. 02 MWD+IFR-AK-CAZ-SC 13757. 22 90.55 189.99 3373.36 3264.36 -12251 .87 562.85 5933112.70 559594. 53 MWD+IFR-AK-CAZ-SC 13850. 20 90.36 193.20 3372.62 3263.62 -12342 .94 544.17 5933021.50 559576. 56 MWD+IFR-AK-CAZ-SC 13894. 20 90.86 194.13 3372.15 3263.15 -12385 .69 533.77 5932978.67 559566. 50 MWD+IFR-AK-CAZ-SC 13930. 00 90.86 194.13 3371.62 3262.62 -12420 .41 525.03 5932943.90 559558. 04 I PROJECTED to TD ~Ialliburton Company Survey Report Cumpam: ConoCOPhillipsAlaska Inc. Date: 10/18/2006 Time: 13:48:07 Pale: I Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well`.' 1J-137, True North Site: Kuparuk 1 J Pad Vertical (TVD) Re ference: 1 J-137L1 PB2: 1 09.0 Well: iJ-137 Section (VS) References Well'(O:OON,O.OOE,180.OOAzi) Wellpath: 1J-137L1P62 _. Survey Calculation Method: Minimum'Curva ture Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1J-137 Slot Name: Well Position: +N/-S -562.20 ft Northing: 594535 8.62 ft Latitude: 70 15 40.728 N +E/-W 141.55 ft Easti ng : 55893 5.87 ft Longitude: 149 31 24.888 W Position Uncertainty: 0.00 ft Wellpath: 1 J-137L1 PB2 Drilled From: 1 J-137L1 PB1 500292331670 Tie-on Depth: 11058.82 ft Current Datum: 1J-137L1P62: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 8/9/2006 Declination: 23.84 deg Field Strength: 57607 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 180.00 ~ Survey Program for Definitive Wellpath Date: 10/18/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 724.00 1 J-137 gyro (50.00-724.00) (2) CB-GYRO-SS Camera based gyro single shot 763.95 8846.13 1 J-137 (763.95-17352.25) (2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C ~ 8921.00 11058.82 1J-137L1 P61 (8921 .00-13894.20) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11115.00 15516.80 1J-137L1 PB2 (11115.00-15516.80 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey -- _____ _- MD Intl ~zim TVD Sys TVD N!S E/W MapN MapE Tuul ' ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945358.62 558935.87 TIE LINE 50.00 0.13 197.98 50.00 -59.00 -0.02 -0.01 5945358.60 558935.86 CB-GYRO-SS 100.00 0.24 63.32 100.00 -9.00 -0.03 0.07 5945358.59 558935.94 CB-GYRO-SS 172.00 0.30 138.87 172.00 63.00 -0.10 0.33 5945358.52 558936.20 CB-GYRO-SS 266.00 0.53 174.43 266.00 157.00 -0.72 0.53 5945357.90 558936.41 CB-GYRO-SS 355.00 2.61 178.49 354.96 245.96 -3.16 0.62 5945355.47 558936.52 CB-GYRO-SS 447.00 5.47 183.45 446.72 337.72 -9.63 0.42 5945348.99 558936.36 CB-GYRO-SS 539.00 8.20 189.23 538.06 429.06 -20.49 -0.90 5945338.13 558935.13 CB-GYRO-SS 631.00 10.28 191.38 628.86 519.86 -35.01 -3.57 5945323.58 558932.57 CB-GYRO-SS i 724.00 13.86 185.23 719.79 610.79 -54.25 -6.23 5945304.33 558930.07 CB-GYRO-SS ~ 763.95 15.51 179.17 758.44 649.44 -64.35 -6.59 5945294.22 558929.79 MWD+IFR-AK-CAZ-SC 823.36 17.99 175.81 815.33 706.33 -81.45 -5.80 5945277.14 558930.71 MWD+IFR-AK-CAZ-SC 887.30 18.59 175.68 876.04 767.04 -101.46 -4,31 5945257.14 558932.35 MWD+IFR-AK-CAZ-SC 949.28 20.29 172.60 934.48 825.48 -121.97 -2.18 5945236.65 558934.64 MWD+IFR-AK-CAZ-SC 1042.06 23.01 173.50 1020.71 911.71 -155.95 1,94 5945202.71 558939.03 MWD+IFR-AK-CAZ-SC 1135.19 26.07 176.82 1105.42 996.42 -194.47 5.14 5945164.21 558942.53 MWD+IFR-AK-CAZ-SC ~ 1226.83 29.28 172.02 1186.58 1077.58 -236.79 9.37 5945121.93 558947.09 MWD+IFR-AK-CAZ-SC 1320.18 35.08 170.94 1265.55 1156.55 -285.93 16.77 5945072.86 558954.87 MWD+IFR-AK-CAZ-SC 1412.00 40.64 174.74 1338.03 1229.03 -341.81 23.67 5945017.04 558962.21 MWD+IFR-AK-CAZ-SC 1503.17 41.99 173.66 1406.50 1297.50 -401.69 29.76 5944957.21 558968.77 MWD+IFR-AK-CAZ-SC ~ 1598.34 46.25 172.02 1474.81 1365.81 -467.40 38.05 5944891.57 558977.58 MWD+IFR-AK-CAZ-SC 1689.63 47.62 171.58 1537.14 1428.14 -533.41 47.57 5944825.65 558987.61 MWD+IFR-AK-CAZ-SC ' 1782.86 52.69 172.13 1596.86 1487.86 -604.25 57.69 5944754.90 558998.28 MWD+IFR-AK-CAZ-SC 1874.98 58.51 171.82 1648.88 1539.88 -679.48 68.31 5944679.76 559009.49 MWD+IFR-AK-CAZ-SC 1968.36 62.75 172.58 1694.67 1585.67 -760.09 79.34 5944599.25 559021.15 MWD+IFR-AK-CAZ-SC 2060.33 67.69 174.04 1733.21 1624.21 -843.00 89.04 5944516.43 559031.50 MWD+IFR-AK-CAZ-SC 2154.58 70.88 174.98 1766.54 1657.54 -930.74 97.47 5944428.76 559040.61 MWD+IFR-AK-CAZ-SC ~alliburton Company ,~, Survey Report Cun~pany: ConocoPhiilips Alaska Inc. Date: 10/18/2006 Time: 13:48:07 Page: 2 Field: Ku paru k River Unit Co-ordinate(NE) Reference: Well: 1J-13 7, True North Site: Kuparu k 1J Pad Vertic a#{'fVD)Reference 1J-1371_1PB2: 109.0 Well: 1J -137 Sectio n (VS) ReTerence: ' Well (O.OON,O.OOE,180.OOAzi) ~Velip.irh: 1J -137G1P62 Survey Calculati on Method: . Minimum C urv ature Db; Oracle Sine c~ .lIll Int l Azim "(`VD Sys TVD T'%S I:~' h1apN I19xpH: Tool '~ ft deg deg ft ft ft ft ft ft 2245 .74 74 .22 173. 42 1793. 88 1684.88 -1017. 24 106.26 5944342. 34 559050. 08 MWD+IFR-AK-CAZ-SC 2339 .09 74 .41 172. 78 1819. 11 1710.11 -1106. 46 117.06 5944253. 21 559061. 58 MWD+IFR-AK-CAZ-SC , 2431 .72 75 .51 173 .66 1843. 15 1734.15 -1195 .29 127.62 5944164. 48 559072. 83 MWD+IFR-AK-CAZ-SC 2524 .49 74 .98 174 .15 1866. 78 1757.78 -1284 .49 137.15 5944075. 36 559083. 05 MWD+IFR-AK-CAZ-SC 2617. 50 74 .92 174. 02 1890. 93 1781.93 -1373. 83 146.40 5943986. 10 559093. 00 MWD+IFR-AK-CAZ-SC 2710. 09 76 .61 173. 80 1913. 70 1804.70 -1463. 07 155.92 5943896. 95 559103. 22 MWD+IFR-AK-CAZ-SC 2806 .73 76 .45 174. 39 1936. 21 1827.21 -1556. 55 165.59 5943803. 56 559113. 62 MWD+IFR-AK-CAZ-SC 2893 .92 76 .38 173. 83 1956. 69 1847.69 -1640. 86 174.29 5943719. 33 559122. 98 MWD+IFR-AK-CAZ-SC 2987 .00 76 .20 174 .83 1978. 75 1869.75 -1730 .84 183.22 5943629. 43 559132. 62 MWD+IFR-AK-CAZ-SC 3080 .29 77 .63 173 .97 1999, 87 1890.87 -1821 .27 192.09 5943539. 08 559142. 19 MWD+IFR-AK-CAZ-SC 3173 .18 77 .93 174 .51 2019. 53 1910.53 -1911 .60 201.20 5943448. 84 559152. 01 MWD+IFR-AK-CAZ-SC 3266. 00 76 .70 174. 66 2039. 91 1930.91 -2001. 75 209.75 5943358. 77 559161. 26 MWD+IFR-AK-CAZ-SC ~ 3357. 70 75 .26 175. 44 2062. 13 1953.13 -2090. 38 217.43 5943270. 21 559169. 63 MWD+IFR-AK-CAZ-SC 3450 .47 74 .84 174. 98 2086. 06 1977.06 -2179. 70 224.91 5943180. 96 559177. 81 MWD+IFR-AK-CAZ-SC 3544 .51 73 .79 174. 11 2111. 48 2002.48 -2269 .82 233.52 5943090. 91 559187. 12 MWD+IFR-AK-CAZ-SC 3635 .78 74 .92 174. 34 2136. 10 2027.10 -2357 .26 242.36 5943003. 55 559196. 65 MWD+IFR-AK-CAZ-SC 3728 .89 72 .89 175 .08 2161. 91 2052.91 -2446 .34 250.61 5942914. 55 559205. 59 MWD+IFR-AK-CAZ-SC 3849 .43 73 .59 173 .94 2196. 67 2087.67 -2561 .22 261.65 5942799. 77 559217. 53 MWD+IFR-AK-CAZ-SC 3945. 06 73 .77 174. 38 2223. 54 2114.54 -2652 .53 270.99 5942708. 55 559227. 59 MWD+IFR-AK-CAZ-SC 4037 .39 73 .66 174. 59 2249. 43 2140.43 -2740 .74 279.51 5942620. 41 559236. 79 MWD+IFR-AK-CAZ-SC 4130 .08 73 .38 174. 15 2275. 73 2166.73 -2829 .19 288.23 5942532. 04 559246. 20 MWD+IFR-AK-CAZ-SC 4221 .53 73 .07 175. 42 2302. 12 2193.12 -2916 .39 296.19 5942444. 92 559254. 84 MWD+IFR-AK-CAZ-SC 4314 .42 72 .29 174 .98 2329. 77 2220.77 -3004 .75 303.61 5942356. 62 559262. 95 MWD+IFR-AK-CAZ-SC 4407 .30 71 .64 174 .56 2358. 53 2249.53 -3092 .70 311.66 5942268. 75 559271 .69 MWD+IFR-AK-CAZ-SC 4500. 05 70 .40 175. 27 2388. 70 2279.70 -3180. 06 319.43 5942181. 46 559280. 15 MWD+IFR-AK-CAZ-SC 4593. 31 69 .54 175. 23 2420. 64 2311.64 -3267 .38 326.69 5942094. 21 559288. 09 MWD+IFR-AK-CAZ-SC ~ 4686. 06 67 .99 174. 93 2454. 23 2345.23 -3353. 51 334.10 5942008. 15 559296. 17 MWD+IFR-AK-CAZ-SC ~ 4722. 17 67 .88 174. 99 2467. 80 2358.80 -3386 .85 337.04 5941974. 84 559299. 37 MWD+IFR-AK-CAZ-SC 4774. 74 68 .06 175. 07 2487. 51 2378.51 -3435 .39 341.26 5941926. 33 559303. 98 MWD+IFR-AK-CAZ-SC 4867 .41 70 .58 172 .10 2520. 24 2411.24 -3521 .53 350.97 5941840. 28 559314. 35 MWD+IFR-AK-CAZ-SC 4959. 80 70 .52 172. 73 2551. 01 2442.01 -3607 .88 362.47 5941754. 03 559326 .53 MWD+IFR-AK-CAZ-SC 5053. 68 73 .11 172. 65 2580. 30 2471.30 -3696. 34 373.81 5941665. 67 559338. 56 MWD+IFR-AK-CAZ-SC ~ 5078. 87 73 .41 172. 76 2587. 56 2478.56 -3720. 27 376.88 5941641. 77 559341. 81 MWb+IFR-AK-CAZ-SC I i i 5146. 52 73 .91 173. 06 2606. 59 2497.59 -3784 .69 384.89 5941577. 42 559350. 33 MWD+IFR-AK-CAZ-SC 5238. 16 73 .84 171. 70 2632. 05 2523.05 -3871 .95 396.56 5941490. 27 559362. 68 MWD+IFR-AK-CAZ-SC 5332. 09 73 .99 172 .10 2658. 07 2549.07 -3961 .30 409.28 5941401. 03 559376. 10 MWD+IFR-AK-CAZ-SC 5424. 24 76 .40 171 .46 2681. 62 2572.62 -4049 .47 422.02 5941312. 97 559389 .53 MWD+IFR-AK-CAZ-SC 5517. 07 76 .63 171. 01 2703. 26 2594.26 -4138 .68 435.77 5941223. 87 559403 .98 MWD+IFR-AK-CAZ-SC 5608. 84 74 .29 171. 44 2726. 30 2617.30 -4226 .47 449.33 5941136. 21 559418. 22 MWD+IFR-AK-CAZ-SC ! 5702. 22 76 .83 172. 48 2749. 59 2640.59 -4316 .00 461.97 5941046. 78 559431. 56 MWD+IFR-AK-CAZ-SC 5787. 86 77 .17 169. 47 2768. 85 2659.85 -4398 .40 475.06 5940964. 49 559445. 29 MWD+IFR-AK-CAZ-SC 5881. 33 77 .80 170. 37 2789. 11 2680.11 -4488 .24 491.03 5940874. 79 559461. 96 MWD+IFR-AK-CAZ-SC 5973. 35 77 .62 170. 98 2808. 70 2699.70 -4576 .96 505.60 5940786. 19 559477 .22 MWD+IFR-AK-CAZ-SC 6065. 88 77 .99 172. 92 2828. 24 2719.24 -4666 .51 518.26 5940696. 76 559490 .58 MWD+IFR-AK-CAZ-SC 6158. 25 76 .81 173. 93 2848. 39 2739.39 -4756. 06 528.58 5940607. 30 559501. 61 MWD+IFR-AK-CAZ-SC ~ 6253. 05 78 .05 176. 87 2869. 03 2760.03 -4848 .28 536.00 5940515. 15 559509. 74 MWD+IFR-AK-CAZ-SC 6342. 80 76 .93 177. 06 2888. 47 2779.47 -4935 .77 540.64 5940427. 71 559515. 07 MWD+IFR-AK-CAZ-SC 6437. 48 76 .47 176. 98 2910. 25 2801.25 -5027 .79 545.43 5940335. 74 559520. 57 MWD+IFR-AK-CAZ-SC 6529. 67 76 .10 176 .08 2932. 11 2823.11 -5117 .18 550.85 5940246. 40 559526 .69 MWD+IFR-AK-CAZ-SC 6622 .56 76 .84 175 .50 2953. 84 2844.84 -5207 .25 557.48 5940156. 39 559534 .03 MWD+IFR-AK-CAZ-SC i 6714. 88 77 .55 174. 13 2974. 30 2865.30 -5296 .90 565.61 5940066. 82 559542 .87 MWD+IFR-AK-CAZ-SC 6807. 71 77 .36 174. 04 2994. 47 2885.47 -5387 .03 574.95 5939976. 77 559552. 91 MWD+IFR-AK-CAZ-SC 6899. 57 77 .48 173. 81 3014. 47 2905.47 -5476 .18 584.44 5939887. 70 559563. 09 MWD+IFR-AK-CAZ-SC ~ _ r~alliburton Company *, Survey Report Company: ConocoPhillipsAlaska Inc. Date: 10/18/2D06 Time: 13:48:07 Page:. 3 Ficld:- Kuparuk River Unit Co-ordinate(NE) [teference: Well: 1J-137, True North Site: Kuparuk 1 J Pad Vertical (TVD) Reference: '' 1 J-137L1 P82: 109.0 Well: 1J-137 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-137L1PB2 Survey Calculation Method: Minimum Curvature Db: Oracle __ _ __ Su rve~~ ~1i1 Intl ~1~im TVD SysTVD \ ti E%1S IvtapN ManF l~uol ft deg deg ft ft ft ft ft ft I -- __ _ _ _ 6992.24 77.42 173.18 3034.61 2925.61 -5566.06 594.69 5939797.92 559574.04 MWD+IFR-AK-CAZ-SC 7085.82 77.87 173.78 3054.63 2945.63 -5656.88 605.07 5939707.19 559585.13 MWD+IFR-AK-CAZ-SC 7177.28 76.75 173.77 3074.72 2965.72 -5745.58 614.74 5939618.58 559595.50 MWD+IFR-AK-CAZ-SC 7270.11 76.04 174.21 3096.56 2987.56 -5835.30 624.19 5939528.94 559605.65 MWD+IFR-AK-CAZ-SC 7363.92 76.22 174.08 3119.05 3010.05 -5925.90 633.48 5939438.42 559615.65 MWD+IFR-AK-CAZ-SC ~ 7456.86 76.16 173.38 3141.23 3032.23 -6015.62 643.34 5939348.80 559626.20 MWD+IFR-AK-CAZ-SC ~ 7548.24 75.47 171.20 3163.63 3054.63 -6103.40 655.22 5939261.12 559638.77 MWD+IFR-AK-CAZ-SC 7641.58 74.89 170.79 3187.50 307$.50 -6192.53 669.34 5939172.12 559653.59 MWD+IFR-AK-CAZ-SC 7734.23 75.56 171.49 3211.13 3102.13 -6281.04 683.14 5939083.72 559668.08 MWD+IFR-AK-CAZ-SC 7826.90 77.66 171.21 3232.59 3123.59 -6370.16 696.70 5938994.72 559682.33 MWD+IFR-AK-CAZ-SC 7920.45 77.49 171.41 3252.72 3143.72 -6460.47 710.50 5938904.53 559696.84 MWD+IFR-AK-CAZ-SC 8012.05 76.67 172.46 3273.20 3164.20 -6548.87 723.03 5938816.24 559710.06 MWD+IFR-AK-CAZ-SC 8104.88 76.05 173.76 3295.09 3186.09 -6638.43 733.85 5938726.78 559721.58 MWD+IFR-AK-CAZ-SC 8198.91 76.79 174.84 3317.17 3208.17 -6729.37 742.93 5938635.91 559731.37 MWD+IFR-AK-CAZ-SC 8289.86 77.36 175.41 3337.52 3228.52 -6817.70 750.46 5938547.66 559739.59 MWD+IFR-AK-CAZ-SC 8382.40 78.23 176.23 3357.08 3248.08 -6907.90 757.05 5938457.52 559746.89 MWD+IFR-AK-CAZ-SC 8475.66 78.37 176.20 3375.99 3266.99 -6999.03 763.08 5938366.45 559753.63 MWD+IFR-AK-CAZ-SC 8567.44 79.91 177.82 3393.28 3284.28 -7089.04 767.78 5938276.49 559759.03 MWD+IFR-AK-CAZ-SC 8660.16 79.04 177.65 3410.22 3301.22 -7180.12 771.38 5938185.44 559763.34 MWD+IFR-AK-CAZ-SC 8753.21 79.80 177.26 3427.31 3318.31 -7271.50 775.44 5938094.11 559768.12 MWD+IFR-AK-CAZ-SC 8846.13 80.61 177.85 3443.11 3334.11 -7362.98 779.35 5938002.67 559772.74 MWD+IFR-AK-CAZ-SC 8921.00 79.82 177.82 3455.84 3346.84 -7436.71 782.14 5937928.97 559776.11 MWD+IFR-AK-CAZ-SC 9008.99 83.59 181.17 3468.53 3359.53 -7523.75 782.89 5937841.95 559777.54 MWD+IFR-AK-CAZ-SC 9101.15 90.40 184.62 3473.36 3364.36 -7615.59 778.24 5937750.08 559773.61 MWD+IFR-AK-CAZ-SC ~ 9194.39 91.54 183.98 3471.78 3362.78 -7708.56 771.25 5937657.08 559767,35 MWD+IFR-AK-CAZ-SC i 9286.16 90.41 183.99 3470.22 3361.22 -7800.09 764.87 5937565.50 559761,69 MWD+IFR-AK-CAZ-SC 9379.16 91.21 184.54 3468.91 3359.91 -7892.82 757.96 5937472.73 559755.50 MWD+IFR-AK-CAZ-SC 9473.15 93.47 183.65 3465.07 3356.07 -7986.49 751.25 5937379.03 559749.53 MWD+IFR-AK-CAZ-SC 9566.73 91.08 180.16 3461.36 3352.36 -8079.92 748.14 5937285.58 559747.15 MWD+IFR-AK-CAZ-SC 9658.92 90.41 178.23 3460.16 3351.16 -8172.09 749.44 5937193.43 559749.17 MWD+IFR-AK-CAZ-SC 9751.15 88.74 176.78 3460.84 3351.84 -8264.22 753.45 5937101.34 559753.90 MWD+IFR-AK-CAZ-SC 9843.84 89.56 177.78 3462.22 3353.22 -8356.80 757.85 5937008.81 559759.02 MWD+IFR-AK-CAZ-SC 9936.42 90.86 179.71 3461.88 3352.88 -8449.35 759.88 5936916.29 559761.78 MWD+IFR-AK-CAZ-SC 10029.32 93.46 181.26 3458.38 3349.38 -8542.17 759.09 5936823.48 559761.72 MWD+IFR-AK-CAZ-SC 10121.23 92.89 179.40 3453.28 3344.28 -8633.93 758.57 5936731.72 559761.91 MWD+IFR-AK-CAZ-SC I 10213.64 92.89 178.10 3448.63 3339.63 -8726.20 760.58 5936639.48 559764.64 MWD+IFR-AK-CAZ-SC 10307.32 90.28 178.39 3446.03 3337.03 -8819.79 763.45 5936545.92 559768.24 MWD+IFR-AK-CAZ-SC I 10399.79 91.97 180.37 3444.22 3335.22 -8912.23 764.45 5936453.50 559769.97 MWD+IFR-AK-CAZ-SC i 10492.00 90.72 180.55 3442.05 3333.05 -9004.41 763.71 5936361.33 559769.95 MWD+IFR-AK-CAZ-SC 10584.46 91.29 180.51 3440.43 3331.43 -9096.85 762.85 5936268.89 559769.82 MWD+IFR-AK-CAZ-SC 10677.42 93.21 181.94 3436.78 3327.78 -9189.71 760.87 5936176.03 559768.56 MWD+IFR-AK-CAZ-SC 10770.28 95.69 181.10 3429.58 3320.58 -9282.25 758.41 5936083.48 559766.83 MWD+IFR-AK-CAZ-SC 10867.01 94.49 180.01 3421.00 3312.00 -9378.59 757.48 5935987.15 559766.65 MWD+IFR-AK-CAZ-SC 10963.48 90.89 178.59 3416.47 3307.47 -9474.93 758.66 5935890.83 559768.58 MWD+IFR-AK-CAZ-SC 11058.82 92.03 178.88 3414.04 3305.04 -9570.21 760.76 5935795.57 559771.43 MWD+IFR-AK-CAZ-SC I 11115.00 92.38 179.07 3411.88 3302.88 -9626.34 761.77 5935739.46 559772.87 MWD+IFR-AK-CAZ-SC I 11155.95 88.34 178.96 3411.62 3302.62 -9667.28 762.47 5935698.54 559773.90 MWD+IFR-AK-CAZ-SC 11252.30 89.38 179.23 3413.54 3304.54 -9763.59 763.99 5935602.24 559776.17 MWD+IFR-AK-CAZ-SC 11347.65 90.49 177.74 3413.65 3304.65 -9858.91 766.51 5935506.96 559779.44 MWD+IFR-AK-CAZ-SC 11444.97 88.87 175.54 3414.19 3305.19 -9956.05 772.22 5935409.88 559785.90 MWD+IFR-AK-CAZ-SC 11543.17 89.87 174.41 3415.27 3306.27 -10053.86 780.82 5935312.14 559795.27 MWD+IFR-AK-CAZ-SC ~ 11640.46 91.48 173.82 3414.12 3305.12 -10150.63 790.79 5935215.47 559806.00 MWD+IFR-AK-CAZ-SC _ i ~Ialliburton Company Survey Report Company: ConocoPhillipsAlaska Inc. Field: Kuparuk River Unit tine: KuparuklJPad ~4cll: 1J-137 )~~cllpath: 1 J-137L1 PB2 Date: 10/18/2006 Co-ordinate(NE) Reference: Vertieat(T~'D)Reference: Section (VS) Reference: Survey Calculation Method: 'Time: 13;48:07 P~~tie: 4 Well: 1J-137, True North 1J-137L1PB2:109.0 Well (O.OON,O.OOE;180.OOAzi) Minimum Curvature llb: Oracle Survey __- - -- lID Incl Azim TVD Sys TV iI N!S E/W MaftN Mat~F Tool ', ft deg deg ft ft ft ft ft ft 11735 .74 93.09 172 .49 3410. 32 3301 .32 -10245 .15 802.14 5935121 .05 559818.08 MWD+IFR-AK-CAZ-SC ~ 11832 .41 89.79 171. 57 3407. 90 3298 .90 -10340 .84 815.53 5935025. 47 559832.23 MWD+IFR-AK-CAZ-SC ~ 11929 .18 88.50 171. 85 3409. 34 3300 .34 -10436 .59 829.48 5934929. 85 559846.93 MWD+IFR-AK-CAZ-SC 12025 .39 91.62 172. 92 3409. 24 3300 .24 -10531 .94 842.23 5934834. 61 559860.42 MWD+IFR-AK-CAZ-SC 12122 .14 90.48 173. 04 3407. 47 3298 .47 -10627 .94 854.05 5934738. 71 559872.99 MWD+IFR-AK-CAZ-SC 12218 .21 89.43 174. 09 3407. 54 3298 .54 -10723 .40 864.82 5934643. 34 559884.50 MWD+IFR-AK-CAZ-SC 12314 .98 85.96 172 .71 3411. 43 3302 .43 -10819 .44 875.93 5934547. 41 559896.36 MWD+IFR-AK-CAZ-SC 12412 .24 87.47 173 .09 3417. 01 3308 .01 -10915 .79 887.93 5934451. 16 559909.12 MWD+IFR-AK-CAZ-SC 12506 .19 86.28 171. 74 3422. 13 3313 .13 -11008 .78 900.31 5934358 .28 559922.22 MWD+IFR-AK-CAZ-SC 12603 .85 87.10 172. 38 3427. 77 3318 .77 -11105 .34 913.78 5934261. 84 559936.44 MWD+IFR-AK-CAZ-SC 12700 .51 89.95 175: 55 3430. 26 3321 .26 -11201 .41 923.94 5934165. 86 559947.35 MWD+IFR-AK-CAZ-SC ~ 12797 .27 93.79 175. 52 3427. 10 3318 .10 -11297 .81 931.46 5934069. 54 559955.63 MWD+IFR-AK-CAZ-SC i 12893 .91 92.94 176. 67 3421. 43 3312 .43 -11394 .05 938.03 5933973. 35 559962.95 MWD+IFR-AK-CAZ-SC i 12990 .77 90.15 178 .30 3418. 81 3309 .81 -11490 .77 942.28 5933876. 68 559967.96 MWD+IFR-AK-CAZ-SC 13086 .06 89.99 181 .90 3418. 70 3309 .70 -11586 .05 942.11 5933781. 42 559968.54 MWD+IFR-AK-CAZ-SC 13182 .97 90.61 182 .01 3418. 19 3309 .19 -11682 .90 938.81 5933684. 55 559965.99 MWD+IFR-AK-CAZ-SC 13279 .81 92.22 182 .58 3415. 80 3306 .80 -11779 .63 934.93 5933587 .80 559962.87 MWD+IFR-AK-CAZ-SC I 13376. 58 90.66 183. 75 3413. 37 3304 .37 -11876 .21 929.59 5933491. 19 559958.28 MWD+IFR-AK-CAZ-SC 13472 .15 90.67 185. 41 3412. 26 3303 .26 -11971 .47 921.96 5933395. 88 559951.40 MWD+IFR-AK-CAZ-SC 13567 .91 91.35 183. 42 3410. 57 3301 .57 -12066 .92 914.59 5933300. 38 559944.78 MWD+IFR-AK-CAZ-SC 13663 .58 93.15 183. 61 3406. 81 3297 .81 -12162 .34 908.73 5933204. 94 559939.67 MWD+IFR-AK-CAZ-SC 13757 .69 95.07 182 .75 3400. 07 3291 .07 -12256 .05 903.52 5933111. 19 559935.19 MWD+IFR-AK-CAZ-SC 13849 .79 92.63 182 .68 3393. 89 3284 .89 -12347 .84 899.17 5933019 .38 559931.56 MWD+IFR-AK-CAZ-SC i 13943 .30 91.78 183 .02 3390. 29 3281 .29 -12441 .16 894.52 5932926 .04 559927.64 MWD+IFR-AK-CAZ-SC ~ 14035. 03 90.66 184. 24 3388. 33 3279 .33 -12532 .68 888.72 5932834. 48 559922.55 MWD+IFR-AK-CAZ-SC 14128 .00 90.36 186. 12 3387. 51 3278 .51 -12625 .27 880.32 5932741. 84 559914.89 MWD+IFR-AK-CAZ-SC 14221 .97 90.61 187. 36 3386. 71 3277 .71 -12718 .58 869.30 5932648. 45 559904.59 MWD+IFR-AK-CAZ-SC 14314 .96 90.92 188. 17 3385. 47 3276 .47 -12810 .71 856.73 5932556. 24 559892.75 MWD+IFR-AK-CAZ-SC 14407 .34 90.36 189 .93 3384. 44 3275 .44 -12901 .93 842.20 5932464 .92 559878.94 MWD+IFR-AK-CAZ-SC 14500 .15 91.17 193 .89 3383. 20 3274 .20 -12992 .71 823.06 5932373. 99 559860.50 MWD+IFR-AK-CAZ-SC ~ 14591 .19 90.91 195 .10 3381. 55 3272 .55 -13080 .84 800.27 5932285 .70 559838.41 MWD+IFR-AK-CAZ-SC 14683 .70 90.98 194 .71 3380. 02 3271 .02 -13170 .23 776.48 5932196 .14 559815.32 MWD+IFR-AK-CAZ-SC 14773 .30 90.92 195 .46 3378. 53 3269 .53 -13256 .73 753.17 5932109 .47 559792.69 MWD+IFR-AK-CAZ-SC i 14869 .51 90.73 196. 85 3377. 15 3268 .15 -13349 .12 726.40 5932016. 87 559766.65 MWD+IFR-AK-CAZ-SC 14961. 80 90.10 198. 17 3376. 48 3267 .48 -13437 .13 698.63 5931928. 66 559739.57 MWD+IFR-AK-CAZ-SC 15054 .63 85.70 197. 20 3379. 88 3270 .88 -13525 .49 670.46 5931840. 09 559712.09 MWD+IFR-AK-CAZ-SC 15146 .60 86.16 194 .25 3386. 41 3277 .41 -13613 .79 645.60 5931751. 61 559687.93 MWD+IFR-AK-CAZ-SC 15240 .01 87.16 191 .50 3391. 85 3282 .85 -13704 .69 624.82 5931660 .56 559667.87 MWD+IFR-AK-CAZ-SC 15332 .87 87.71 191 .57 3396. 01 3287 .01 -13795 .58 606.27 5931569 .53 559650.03 MWD+IFR-AK-CAZ-SC i 15426 .49 95.04 196 .48 3393. 76 3284 .76 -13886 .29 583.62 5931478 .65 559628:09 MWD+IFR-AK-CAZ-SC 15516. 80 95.68 194. 78 3385. 33 3276 .33 -13972 .88 559.40 5931391. 89 559604.54 MWD+IFR-AK-CAZ-SC 15552. 00 95.68 194. 78 3381. 84 3272 .84 -14006 .75 550.46 5931357. 95 559595.88 PROJECTED to TD --- --- Time Logs. Date From To Dur S D E. De th Phase Code Subcode T cif 09/09/2006 13:00 14:00 1.00 0 0 PROD2 DRILL PULD _ P Lay down MWD & milling assembl -u er mill full au e. 14:00 14:45 0.75 0 0 PROD2 DRILL OTHR P Pull wear ring & flush bop stack @ 550 m. 14:45 15:00 0.25 0 0 PROD2 DRILL SFTY P PJSM=Topic-Change saver sub-review rocedures On hit & ich oints. 15:00 16:30 1.50 0 0 PROD2 DRILL OTHR P Change out saver sub-replace grabber dies & set wear rin . 16:30 16:45 0.25 0 0 PROD2 DRILL SFTY P PJSM+ topic-Cut drlg. line-wickers-hand placement-pinch points-good comunication & man rider ermit. 16:45 17:45 1.00 0 0 PROD2 DRILL OTHR P Slip & cut 80' drlg. line-inspect & ad'ust brakes-check crown-o-matic. 17:45 19:15 1.50 0 0 PROD2 DRILL PULD P Pick up BHA #8 & mwd tools. 19:15 20:45 1.50 0 0 PROD2 DRILL OTHR P Program MWD. 20:45 22:00 1.25 0 461 PROD2 DRILL TRIP P RIH w/ BHA-pick up circ. sub & XO-RIH 1 std. 4" DP & Spot @ 461'. Down link eo- ilot. 22:00 00:00 2.00 461 4,852 PROD2 DRILL TRIP P RIH (Fill DP @ 3635') RIH to 4852'-P/U 75k S/O 55k RT 65k TQ 2k. 09/10/2006 00:00 00:15 0.25 4,852 4,852 PROD2 DRILL SFTY P PJSM=Topic-Tripping in hole. 00:15 02:00 1.75 4,852 8,951 PROD2 DRILL TRIP P Continue trip in hole from 4852.0 to 8951.0. Fill pipe @ 5500' & 8214'. Went thru window w/ no roblems. 02:00 04:45 2.75 8,951 9,136 PROD2 DRILL DDRL P Drlg. from 8951.0 to 9136.0. (Trouble shoot detection problems w/signal. No signal w/ rotating-good signal without rotatin 04:45 07:30 2.75 9,136 9,136 PROD2 DRILL OTHR NP Mad Pass from 9136' to 8995' @ 2 fpm 300 m 2500 si w/ no rotation. 07:30 12:00 4.50 9,136 9,508 PROD2 DRILL DDRL P Drlg. 6 3/4" horizontal hole from 9136' to 9508' MD 3461 TVD ADT 3.08 hrs. 12:00 12:15 0.25 9,508 9,508 PROD2 DRILL SFTY P PJSM=Topic-Drill-making connections & inch oints. 12:15 00:00 11.75 9,508 11,070 PROD2 DRILL DDRL P Drlg. 6 3/4" Horizontal hole from 9508' to 11070. TVD 3418' (Pump hi vis sweep @ 10249 Returned 15% excess, ADT-6.94 hrs. P/U 135k S/O 60k ROT 90k-TQ 9k ECD-10.17 Max gas-91 units SPR #1 pump 25 spm 550 si #2 um 25 s m 530 si. 09/11/2006 00:00 00:15 0.25 11,070 11,070 PROD2 DRILL SFTY P PJSM on drilling ahead (hazard reco nition 00:15 12:00 11.75 11,070 12,306 PROD2 DRILL DDRL P Drill "D" lateral from11,070'to 12,306'. ADT=7.13 hours. P/U = 145k, S/0= 57k, Rot=91 k, Torque on bottom= 11 k ft-Ibs, off bottom= 12k ft-Ibs. ECD= 10.32 ppg EMW, Max gas = 978 units, Jar hours =73.6 hours. 12:00 12:15 0.25 12,306 12,306 PROD2 DRILL SFTY P PJSM on drlg. ahead (hazard reco nition t___.. sem~~ ~~~~~~ ~s.... --, .. a.eQ__ _-v . ~ ~..w~__m~_.~... ~_n.~e~~ ~as_ ._._. yy~¢___~ i ~ %}° -34R SSE 3~. ~ _, Time Los Date From To Dur S D E. De th Phase Code Subcode __ T ~ 09/11/2006 12:15 21:00 8.75 12,306 13,365 PROD2 DRILL DDRL P Drill "D" lateral from 12306' to 13365'. ADT=5.71 hours. PlU=150k, S/O=48k,=ROT=98k,Torque on bottom=13k, off bottom=14k ft. lbs. ECD=10.6 ppg EMW, Max gas=662 units, Jar hours 79.33 hours. (Difficulty controlin turn on eo ilot. 21:00 22:30 1.50 13,365 13,365 PROD2 DRILL CIRC T Circ. & Reciprocate @ 340 gpm-145 rpm=Bottoms up & monitor well-pump slu . 22:30 00:00 1.50 13,365 12,159 PROD2 DRILL TRIP T POH from 13365' to 12159'. 09/12/2006 00:00 01:30 1.50 12,159 8,862 PROD2 DRILL TRIP T PJSM and cunt to POOH on elevators from 12,159' to 8,862' (TOW @ 8,921'), Pulled 25-30K over at 12,060' and 11,800', no other roblems POOH 01:30 01:45 0.25 8,862 8,862 PROD2 DRILL OWFF T Monitored well at 8,862', well-static 01:45 04:30 2.75 8,862 371 PROD2 DRILL TRIP T POOH from 8,862' to BHA #8 at 371' 04:30 07:00 2.50 371 0 PROD2 DRILL PULD T POOH from 371' standing back HWDP, jars and NMFDC's, downloaded MWD and fin LD BHA #8, cleared rig floor, geo-pilot oil level was ood 07:00 09:00 2.00 0 371 PROD2 DRILL PULD T MU BHA #9 RIH to 371', changed out bits, geo-pilot and 2 pieces of MWD tool, uploaded MWD RIH with NMFDC's, 'ars and HWDP to 371' 09:00 09:30 0.50 371 464 PROD2 DRILL DHEQ T RIH 1 std to 464' and shallow tested MWD and eo- ilot 09:30 14:30 5.00 464 10,530 PROD2 DRILL TRIP T Cont to RIH from 464' to 10,530' when we lost all down wt 14:30 17:45 3.25 10,530 13,365 PROD2 DRILL REAM T Washed and reamed from 10,530' to btm at 13,365', washed down at 200 gpm, 1,500 psi, 70 rpm's with 8-10K ft-Ibs for ue 17:45 22:45 5.00 13,365 13,930 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole with rotary steerable system in WS "D" lateral from 13,365' to 13,930' MD/ 3,372' TVD (565'), ADT 2.61 hrs, 4-10K wob, 140 rpm's, 93 spm, 330 gpm at 3,100 psi, off btm torque 14K ft-Ibs on btm 13K ft-Ibs, rot wt 100K, up wt 155K, do wt 45K, 8.8 ppg MOBM, ave ECD 10.6 ppg, ave BGG 200 units, max gas 515 units, jar hrs 81.94. 22:45 23:30 0.75 13,930 13,930 PROD2 DRILL CIRC T Circ hole at 13,930' while discussing with town the inability to get left hand turn in the sand, currently approx 220' right of the planned line and would be approx 700-800' right of the planned line at TD if we maintained 190 AZ, decision was made to POOH to +/- 11,100' and o en hole sidetrack well. ~~~~~ r~ ~~ ;# t:~ ~._ ~..~~.m.~___W__ .~.~ __~____ .~~..~_.~e_ee ~ _v.~ ~~ Time Logs _ Date From To._ Dur S. D ~ E. Depth Phase Code Subcode T ~_ 09/12/2006 23:30 00:00 0.50 13,930 13,606 PROD2 STK TRIP T POOH on elevators from 13,930' to 13,606', hole not taking calc fill, to be in um in out at 13,606' 09/13/2006 00:00 02:45 2.75 13,606 11,098 PROD2 STK TRIP T Pumped out of hole due to hole not taking talc fill, pumped out from 13,606' to 11,098', 139 mat 780 si 02:45 04:45 2.00 11,098 11,115 PROD2 STK OTHR T Trough well for sidetrack from 11,098' to 11,115' 04:45 06:45 2.00 11,115 11,122 PROD2 STK KOST T Time drilled to sidetrack well, sidetracked well at 11,115' MD/ 3,412' TVD time drilling to 11,122', 0-2K wob, 120 rpm's, 84 spm, 300 gpm at 2,500 si 06:45 12:00 5.25 11,122 11,553 PROD2 DRILL DDRL T Sidetracked well and directionally drilled 6 3/4" hole with rotary steerable system in WS "D" lateral from 11,122' to 11,553' MD/ 3,418' TVD (431'), ADT 5.84 hrs, 4-6K wob, 100 rpm's, 88 spm, 312 gpm at 2,600 psi, off btm torque 9K ft-Ibs on btm 10K ft-Ibs, rot wt 92K, up wt 135K, do wt 60K, 8.7 ppg MOBM, ave ECD 9.6 ppg, ave BGG 50 units. 12:00 00:00 12.00 11,553 13,025 PROD2 DRILL DDRL T Cont to drill sidetrack 6 3/4" hole with rotary steerable system in WS "D" lateral from 11,553' to 13,025' MD/ 3,416' TVD (1,472'), ADT 7.15 hrs, 8-10K wob, 130 rpm's, 95 spm, 337 gpm at 3,200 psi, off btm torque 11 K ft-Ibs on btm 11 K ft-Ibs, rot wt 100K, up wt 145K, do wt 57K, 8.75 ppg MOBM, ave ECD 10.5 ppg, ave BGG 50 units, max gas 409 units, jar hrs 94.93, pumped 35 bbl wt'd hi vis sweep (2# over MW) at 12,735' with 5% increase in cuttings back from the sweep. Concretions: 12,356'-358', 12,430'-436', 12,447'-450' 14' total 09/14/2006 00:00 08:30 8.50 13,025 13,930 PROD2 DRILL DDRL T Fin drilling sidetrack in "D" lateral from 13,025' to the original hole depth of 13,930' MD (905'), ADT 5.61 hrs, 6-10K wob, 90-140 rpm's, 94 spm, 334 gpm at 3,100 psi, off btm torque 12K ft-Ibs on btm 11 K ft-Ibs, rot wt 95K, up wt 150K, do wt 50K, 8.8 ppg MOBM, ave ECD 10.8 ppg, ave BGG 70 units, max gas 155 units, pumped 35 bbl wt'd hi vis sweep (2# over MW) at 13,793' with 10% increase in cuttings back from the sweep. Concretions: 13,775'-780` and 13,789'-799' (15' total _a® w..~~ ~ ,..._ ®m-_ ®._sAm~~ ~ ®e.. ~..~r _~ ®em®~ ~~~___-~ ~~.~ 6 ,,~W C°,f ., , E Time Logs Date From To Dur S. D E. De th Phase .Code Subcode T 09/14/2006 08:30 13:00 4.50 13,930 14,534 PROD2 DRILL DDRL P Cont drilling 6 3/4" hole with rotary steerable system in WS "D" lateral from 13,930' to 14,534' MD/ 3,382' TVD (604'), ADT 2.29 hrs, 5-12K wob, 80-130 rpm's, 90 spm, 320 gpm at 2,970 psi, off btm torque 12K ft-Ibs on btm 12K ft-Ibs, rot wt 100K, up wt 155K, do wt 40K, 8.8 ppg MOBM, ave ECD 10.7 ppg, ave BGG 90 units, max gas 884 units, began having trouble steerin Geo- ilot 13:00 13:45 0.75 14,534 14,534 PROD2 DRILL CIRC T Circ hole while trouble shooting Geo-pilot, Circ at 330 gpm at 3,100 psi and 130 rpm's, decision was made to POOH and chan a out tools 13:45 20:45 7.00 14,534 9,140 PROD2 DRILL REAM T Held PJSM, then BROOH from 14,534' to 9,140', BROOH at 220 gpm, 1,500 si at 90 r m's and no roblems 20:45 23:30 2.75 9,140 9,140 PROD2 DRILL CIRC T Dropped dart and Circ down opening Circ sub at 8,960', circ btms up while circ hole across window, circ at 540 gpm at 3,200 psi and 130 rpm's, pumped 30 bbl wt'd hi vis sweep (2# over mw) and cont to circ hole at 630 gpm at 3,900 psi, had 5% increase in cuttings back from sweep, circ an add. btms up and was clean at the shakers, circ a total of 3X btms u . 23:30 00:00 0.50 9,140 9,140 PROD2 DRILL OWFF T Monitored well-static, pumped dry job re arin to fin POOH 09/15/2006 00:00 02:45 2.75 9,140 371 PROD2 DRILL TRIP T POOH from 9,140' to BHA at 371' 02:45 04:45 2.00 371 0 PROD2 DRILL PULD T POOH standing back HWDP, jars and NMFDC's, downloaded MWD, stood back MWD and LD Geo-pilot and bit, cleared ri floor 04:45 05:00 0.25 0 0 PROD2 RIGMN SFTY P Held PJSM and hazard assessment on sli and cuttin of drl line 05:00 07:00 2.00 0 0 PROD2 RIGMN SVRG P Slip and cut 71' of drlg line, serviced top drive and changed out swivel ackin ,serviced drawworks. 07:00 09:30 2.50 0 90 PROD2 DRILL PULD T MU BHA #10 RIH to 90', MU RR bit #6 on new Geo-pilot and changed out EWR tool on MWD, programmed MWD and Geo- ilot 09:30 10:00 0.50 90 557 PROD2 DRILL TRIP T RIH from 90' with NMFDC's, jars and HWDP then RIH to 557' and shallow tested MWD and Geo- ilot 10:00 16:15 6.25 557 13,414 PROD2 DRILL TRIP T Cont to RIH from 557' to 13,414' when we lost all down wt, no problems going thru window or sidetrack at 11,115' 16:15 17:45 1.50 13,414 14,534 PROD2 DRILL REAM T Washed and reamed from 13,414' to btm at 14,534', washed down at 275 gpm at 2,000 psi, 90 rpm's with 10K ft-Ibs for ue with no roblems. m® esa~.~ ~ ._ ~~ ~.m ~ ~r~~ ~ ,,~ ._._.~_ .~ _ ,_...... __~_. ~ ,. _..w._ ~ -,_.__ ~ _ __-__ _.r ~ _r ~ ~ __ _.~ _ _. _ . ~. ~~ e~ -~ Time Los ~ i Date From To Dur S. D E. De th Phase Code Subcode T 09/15/2006 17:45 00:00 6.25 14,534 15,150 PROD2 DRILL DDRL P ____ _ Cont drilling 6 3/4" hole with rotary steerable system in WS "D" lateral from 14,534' to 15,150 MD/ 3,390' TVD (616'), ADT 3.15 hrs, 5-12K wob, 130 rpm's, 80 spm, 285 gpm at 2,600 psi, off btm torque 13.5K ft-Ibs on btm 13K ft-Ibs, rot wt 97K, up wt 167K, do wt 40K, 8.8 ppg MOBM, ave ECD 10.5 ppg, ave BGG 40 units, max gas 109 units. 09/16/2006 00:00 03:45 3.75 15,150 15,552 PROD2 DRILL DDRL P Cont drilling 6 3/4" hole with rotary steerable system in WS "D" lateral from 15,150' to 15,552' MD/ 3,381' TVD (402'), ADT 3.15 hrs, 10-12K wob, 100 rpm's, 80 spm, 285 gpm at 2,600 psi, off btm torque 12K ft-Ibs on btm 11 K ft-Ibs, rot wt 95K, up wt 150K, do wt 45K, 8.8 ppg MOBM, ave ECD 10.5 ppg, ave BGG 40 units, max gas 61 units, concretion's 15,334' & 15,552' (18' total). still unable overcome right hand turn in well and decison was made to sidetrack u hole. 03:45 06:15 2.50 15,552 13,820 PROD2 STK TRIP T POOH on elevators from 15,552' to 15,186' and hole didn't take calc fill, pumped out of hole to 13,820', pumped out at 220 mat 1,350 si 06:15 07:45 1.50 13,820 13,840 PROD2 STK OTHR T Trough hole from 13,820' to 13,840' for sidetrackin well. 07:45 09:15 1.50 13,840 13,867 PROD2 STK KOST T Time drilled to sidetrack well at 13,840' MD/3,394' TVD, time drilled at 6' per hr from 13,840' to 13,852' and at 50'/hr to 13, 867' 09:15 18:45 9.50 13,867 14,110 PROD2 DRILL DDRL T Sidetracked well and directionally drilled 6 3/4" hole from 13,867' to 14,110' MD/3,393' ND (243') ADT 6.96 hrs, 2-10K wob, 90-140 rpm's, 84 spm, 300 gpm, 2,400 psi, torque off and on btm at 12K ft-Ibs, rot wt 100K, up wt 155K, do wt 48K, 8.75 ppg MOBM, ave ECD 10.0 ppg, ave BGG 40 units, unable to steer Geo-pilot, tool having slow to no reaction when downlinked, decision was made to POOH and PU motor with A itator and shock tool. 18:45 00:00 5.25 14,110 10,344 PROD2 DRILL TRIP T Pumped out of hole from 14,110' to 10,344', pumped out of hole at 300 m at 2,350 si with no roblems 09/17/2006 00:00 01:00 1.00 10,344 8,859 PROD2 DRILL TRIP T Cont to Pump out of hole from 10,344' to 8,859', (TOW @ 8,921') pumped out of hole at 300 mat 2,350 si. 01:00 02:30 1.50 8,859 8,859 PROD2 DRILL CIRC T Circ btms up above TOW at 8,859', circ at 335 gpm at 2,600 psi, 90 rpm's with 5K ft-Ibs for ue 02:30 02:45 0.25 8,859 8,859 PROD2 DRILL OWFF T Monitored well-static, pumped dry job ~..~. ~.. m ~~ ~,m..-~~.____ e~ ~.®®~.. ~ ~ _ _. e ~~ ~.~~a.~_-- _.~~..~..~~.~.~__~__ ,.x~;~.~~~a Time Logs __ Date From To' Dur S. D E. De th Phase Code Subcode T G - 09/17/2006 02:45 05:00 2.25 8,859 371 PROD2 DRILL TRIP T -- POOH from 8,859' to BHA at 371', calc hole fill 55 bbls, actual fill 55 bbls 05:00 07:15 2.25 371 0 PROD2 DRILL PULD T POOH from 371', stood back HWDP, jars and NMFDC's, downloaded MWD and fin POOH LD BHA #10, found wear on wear bands on MWD tool located approx 50' up from the bit, cleared ri floor 07:15 07:30 0.25 0 0 PROD2 DRILL SFTY P Held PJSM on testing of BOPE 07:30 09:30 2.00 0 0 PROD2 DRILL OTHR NP Attempted to pull wear bushing, drained stack and found wiper rubber in wear bushing, fished out rubber and wire backin 09:30 10:00 0.50 0 0 PROD2 DRILL PULD P Pulled wear bushing 10:00 14:15 4.25 0 0 PROD2 WELCT BOPE P RU and tested BOPE, tested rams, valves and manifold to 250 psi low and 3,000 psi high ,tested annular to 250/3,000 and tested VBR's with both 4" and 5" DP, NOTE: Chuck Scheve with AOGCC waived witnessin of test 14:15 14:30 0.25 0 0 PROD2 DRILL PULD P Installed wear bushing 14:30 15:30 1.00 0 0 PROD2 DRILL OTHR P MU stack washer and circ thru stack and recovered several add. pieces of wi er rubber, cleaned ri floor 15:30 17:45 2.25 0 180 PROD2 DRILL PULD T MU BHA #11 RIH to 180', MU 6 3/4" bit #7 on motor with 1.5 deg bend and MWD tool and u loaded same 17:45 18:45 1.00 180 1,500 PROD2 DRILL TRIP T RIH from 180' with HWDP, jars, NMFDC's and 4" DP to 1,500' 18:45 19:45 1.00 1,500 1,500 PROD2 DRILL DHEO T Shallow tested MWD at 275 gpm at 1,500 psi, MU AGitator and Shock sub and re-tested MWD and had a 500 psi increase in ressure. 19:45 22:00 2.25 1,500 8,213 PROD2 DRILL TRIP T RIH with BHA #11 on 4" DP from 1,500' to 8,213' 22:00 00:00 2.00 8,213 10,827 PROD2 DRILL TRIP P RIH from 8,213' with 5" DP to 10,827', TIH with 28 stds, prep to POOH and std back 26 stds to reposition LO-tads and super sliders in drill string for motor run 09/18/2006 00:00 03:45 3.75 10,827 8,415 PROD2 DRILL TRIP P POOH to 8,415' and stood back 26 stds of slick 5" DP, RIH with 30 stds of 5" DP with Lo-Tads and POOH standing back same, repositioned pipe to place super sliders deeper in hole with Lo-Tads above for motor run 03:45 04:00 0.25 8,415 8,415 PROD2 RIGMN SFTY P Held PJSM on slip and cutting of drlg line 04:00 05:00 1.00 8,415 8,415 PROD2 RIGMN SVRG P Slip and cut 81' of drlg line then ad'usted the brakes on the drawworks. 05:00 08:00 3.00 8,415 11,940 PROD2 DRILL TRIP T RIH with BHA #11 from 8,415' to 11,940' when we lost all down wt. ~.®~ m ~m.®- ~~____ - ~® e.®®~- -- ~ mse _____d ~ ..~~ ~_ _..~..~ ~ . ~ ...~~ ~ ._,_ _~__~ __~_.~ ~__~.....~__ ~ m~.e.._ -~ ~ ~~ ~_.__~_.~...._. _.....~_.W__~________~..~~.___~ ....._.__ ~ _......~ Time Logs ~_ Date From To Dur S. D E. De th Phase Code Subcode T L _ 09/18/2006 08:00 10:45 2.75 11,940 14,110 PROD2 DRILL REAM T Washed and reamed from 11,940' to btm at 14,110', no problems going thru sidetracks, washed down at 63 spm, 223 mat 2,000 si and 60 r m's. 10:45 00:00 13.25 14,110 14,864 PROD2 DRILL DDRL T Cont to Sidetrack well and directionally drilled 6 3/4" hole in "D" lateral with 1.5 deg motor assembly with agitator and shock tool, drilled from 14,110' to 14,864' MD/3,383' TVD (754') ART 3.92 hrs, AST 3.47 hrs, Total 7.39 hrs, 7-11 K wob, 90 rpm's, 89 spm, 315 gpm, off btm pressure 3,600 psi, on btm 3,750 psi, torque off and on btm at 12K ft-Ibs, rot wt 93K, up wt 170K, do wt at blk wt 35K, 8.70 ppg MOBM, ave ECD 10.5 ppg, ave BGG 30 units, max gas 57 units. Concretions: 14147'-157', 14172'-174', 14180'-184', 14189'-193', 14213'-215', 14218'-233'14237'-248', 14250'-264', 14272'-275'. 09/19/2006 00:00 11:00 11.00 14,864 15,552 PROD2 DRILL DDRL T Cont to Sidetrack well and directionally drilled 6 3/4" hole in "D" lateral with 1.5 deg motor assembly with agitator and shock tool, drilled from 14,864' to 15,552' MD/3,372' TVD, orig. hole's TD, (688') ART 3.06 hrs, AST 3.41 hrs, 5-10K wob, 80-90 rpm's, 91 spm, 321 gpm, off btm pressure 3,850 psi, on btm 3,900 psi, torque off and on btm at 13K ft-Ibs, rot wt 95K, up wt 180K, do wt at blk wt 35K, 8.75 ppg MOBM, ave ECD 10.6 ppg, max gas 58 units. Concretions: 15170'-180', 15228'-233', 15281'-291', 15303'-309', 15395'-398', 15492'-508' 52' total 11:00 13:30 2.50 15,552 15,758 PROD2 DRILL DDRL P Drilled 6 3/4" hole from 15,552'to 15,758' MD/ 3,378' TVD (206') ART .73 hrs, AST -0- 13:30 16:00 2.50 15,758 15,758 PROD2 DRILL CIRC P Stood 1 std back POOH to 15,666', pumped a 35 bbl wt'd hi vis sweep and circ out of hole, circ out of hole at 322 gpm at 4,000 psi and 90 rpm's, had 10% increase in cuttings back from the swee , RIH to btm. 16:00 00:00 8.00 15,758 16,148 PROD2 DRILL DDRL P Cont to directionally drill 6 3/4" hole in "D" lateral with motor assembly from 15,758' to 16,148' MD/3,363' TVD, (390') ART 1.24 hrs, AST 1.61 hrs, 2-11K wob, 80-90 rpm's, 91 spm, 321 gpm, off btm pressure 3,850 psi, on btm 3,950 psi, torque off and on btm at 14K ft-Ibs, rot wt 97K, up wt 195K, do wt at blk wt 35K, 8.75 ppg MOBM, ave ECD 10.6 ppg, max gas 69 units. No Concretions e® ~ ~ ~. _ ,..._ ~.« ~„m.._.. _.m ~~ ..~... ~ ~. ~._.~~._ __~ ~~ ~ _~__~_. Time Logs _ _ Date From To Dur S. D ,~ E. De th Phase Code Subcode T 09/20/2006 00:00 08:45 8.75 16,148 16,840 PROD2 DRILL DDRL P _ Cont to directionally drill 6 3/4" hole in "D" lateral with motor assembly from 16,148' to 16,840' MD/3,361' TVD, "D" Lateral TD, (692') ART 1.20 hrs, AST 2.68 hrs, 2-10K wob, 75 rpm's, 82 spm, 291 gpm, off btm pressure 3,350 psi, on btm 3,400 psi, torque off and on btm at 14K ft-Ibs, rot wt 100K, up wt 185K, do wt at blk wt 35K, 8.75 ppg MOBM, ave ECD 10.5 ppg, max gas 93 units. No Concretions, took an ave of 1.25 hrs to set tool face for a slide, Pumped wt'd hi vis sweep at 16,780' 3# over mw 08:45 11:30 2.75 16,840 16,779 PROD2 DRILL CIRC P Stood back 1 std POOH to 16,779' then fin circ wt'd hi vis sweep out of the hole, circ at 320 gpm at 3,860 psi and 90 rpm's, had 25% increase in cuttings back from the swee . 11:30 12:00 0.50 16,779 16,779 PROD2 DRILL OWFF P Monitored well-static, took SPR's 12:00 20:45 8.75 16,779 16,779 PROD2 DRILL REAM P BROOH from 16,779' to 9,130' then POOH thru the window to 8,882' with no problems, BROOH at 94 spm, 340 gpm, 3,500 psi, 85 rpm's with 10-12K ft-Ibs for ue, monitored well-static 20:45 23:15 2.50 16,779 16,779 PROD2 DRILL CIRC P Pumped a 25 bbl low vis sweep followed with a 35 bbl hi vis sweep (3# over mw), circ sweep out of hole at 94 spm, 340 gpm at 3,500 psi, 90 rpm's with 6K ft-Ibs torque, saw no increase in cuttings back from the sweep, circ an add. btms up and was clean at the shakers. 23:15 00:00 0.75 16,779 16,779 PROD2 RIGMN SVRG P Inspected saver sub and found to be worn, be an to chan a out same. 09/21/2006 00:00 01:00 1.00 16,779 16,779 PROD2 RIGMN SVRG P Fin. changing out top drive saver sub then serviced top drive, blocks and crown 01:00 03:45 2.75 16,779 12,743 PROD2 DRILL TRIP P RIH after circ hole clean above the TOW from 8,882' to 12,743' when we lost all down wt. 03:45 08:30 4.75 12,743 16,840 PROD2 DRILL REAM P Wash and reamed from 12,743' to btm at 16,840' with no problems thru sidetracks. Washed down at 210 gpm at 2,000 si and 70 r m's 08:30 10:15 1.75 16,840 16,840 PROD2 DRILL CIRC P Circ btms up at 16,840' with no increase in cuttings at btms up, circ at 318 gpm, at 3,700 psi and 80 rpm's. Max as 140 units. 10:15 10:30 0.25 16,840 16,840 PROD2 DRILL SFTY P Held PJSM with crew and vac truck drivers on displacing open hole over to SFMOBM f 4~n .,r.~~ E Time Logs ~- 4 Date From To Dur S. D Elf De th Phase Code Subcode T 09/21/2006 10:30 12:00 1.50 16,840 16,840 PROD2 DRILL CIRC P _ Displaced over "D" lateral from 8.75 ppg MOBM to 8.7 ppg SFMOBM, pumped 424 bbls (calc on 10% over 6 3/4" hole vol) of 8.7 ppg SFMOBM to cover open hole. String wt up 225K, do wt 35K 12:00 17:30 5.50 16,840 8,882 PROD2 DRILL TRIP P POOH wet on elevators from 16,840' to 8,882', no problems POOH or going thru window, talc fill on trip out 53 bbls, actual 66 bbls, OW at 8,921' 17:30 20:00 2.50 8,882 8,882 PROD2 DRILL CIRC P Pumped 35 bbl wt'd (3# over mw) hi vis sweep and circ out of hole, had no increase in cuttings back from the sweep, circ an add. btms up and was clean at the shakers, circ hole at 97 spm, 340 gpm at 3,600 psi, 90 rpm's with 7K ft-Ibs for ue 20:00 20:15 0.25 8,882 8,882 PROD2 DRILL OWFF P Monitored well-static, pumped dry job. 20:15 00:00 3.75 8,882 1,510 PROD2 DRILL TRIP P POOH with BHA #11from 8,882' to 1,510', LD AGitater and shock sub 09/22/2006 00:00 00:30 0.50 1,510 370 PROD2 DRILL TRIP P Fin POOH from 1,510' to BHA at 370'. 00:30 01:00 0.50 370 90 PROD2 DRILL PULD P POOH from 370' to 90' LD HWDP, jars and NMFDC's 01:00 02:45 1.75 90 0 PROD2 DRILL PULD P Downloaded MWD and fin. LD BHA #11, cleared ri floor 02:45 03:00 0.25 0 0 COMPZ RIGMN SFTY P PJSM on slip and cutting of drlg line. 03:00 04:00 1.00 0 0 COMPZ RIGMN SVRG P Slip and cut 66' of drlg line, inspect and ad'ust brakes on drawworks 04:00 04:30 0.50 0 0 COMPZ CASIN( RURD P RU Doyon's handling tools and tongs to run 4 1/2" liner 04:30 04:45 0.25 0 0 COMPZ CASIN( SFTY P Held PJSM with crew and tong o erator on runnin of liner 04:45 09:00 4.25 0 7,630 COMPZ CASIN( PUTS P PU &RIH with 4 1/2" liner to 7,630', MU 3 1/2" bent, XO, then RIH with 49 jts of 4 1/2" 11.6#, L-80 BTC slotted liner, 3-blanks and 125 slotted liner with torque rings, ave MU torque 8,100 ft-Ibs 09:00 09:30 0.50 7,630 7,700 COMPZ CASIN( PUTB P MU Baker 5 1/2" x 4 1/2" liner receptacle and HR setting sleeve RIH to 7,700'. String wt up 77K, do wt 56K, rotated 20 rpm's W/O pump at 3K ft-Ibs for ue. 09:30 15:15 5.75 7,700 13,930 COMPZ CASIN( RUNL P RIH with 4 1/2" liner on DP from 7,700' and tagged up at 13,930', orig. hole prior to sidertrack #1, took torque and drag readings at TOW (8,921'), st wt up 91 K, do wt 62K, rotated at 20 rpm's with 3500 ft-Ibs torque, st wt up at 13,930', 145K, do wt 40K 15:15 17:15 2.00 13,930 11,041 COMPZ CASIN( RUNL T POOH from 13,930' to 11,041' 17:15 17:45 0.50 11,041 11,041 COMPZ CASIN( RUNL T Oriented string 180 degrees and worked 6 times to work for ue down ~_. ,..®®.~® e.®. _ ~b~~~....e~ ~ ~®.®~.._ ~ ~~ ~~Ea~ ~~ ,y ,~ Time Logs Date From To Dur S. D E. De th Phase Code Subcode T 09/22/2006 17:45 19:00 1.25 11,041 13,930 COMPZ CASIN( RUNL T RIH from 11,041' and tagged up again at 13,930' 19:00 20:30 1.50 13,930 11,041 COMPZ CASIN( RUNL T POOH from 13,930'to 11,041' 20:30 20:45 0.25 11,041 11,041 COMPZ CASIN( RUNL T Oriented string 90 degrees and worked 2 times to work for ue down 20:45 22:00 1.25 11,041 13,930 COMPZ CASIN( RUNL T RIH from 11,041' to 13,930' and was in new hole, st wt do 35-40K 22:00 00:00 2.00 13,930 15,326 COMPZ CASIN( RUNL P Cont to RIH with 4 1/2" liner from 13,930' rabbiting DP while RIH, RIH to 14,677' when we lost all down wt, st wt up 165K, set TD torque at 11 K ft-Ibs and est rotation at 10-15 rpms at 11 K torque, cont to rotate liner in the hole from 14,677' to 15,326' 09/23/2006 00:00 03:00 3.00 15,326 16,827 COMPZ CASIN( RUNL P Cont to RIH with 4 1/2" liner from 15,326' rabbiting DP while RIH, RIH and tagged btm at 16,840', PU and set liner on depth, st. wt. up on btm 195K, no do wt w/o rotating, rotating wt on btm 85K, do wt rot. 50K, staged top drive torque up from 11 k to 16,500 ft-Ibs at TD, ave 15-20 r m's 03:00 04:45 1.75 16,827 9,136 COMPZ CASIN( CIRC P Dropped 29/32" ball and pumped down to seat, initial rate 4 bpm at 5 bpm, slowed to 3 bpm at 350 psi, ball seated 60 bbls past talc cap. pressured up to 3,000 psi to release running tool, slacked off 40K then PU and liner was released, pressured up to 4,390 psi and blew the ball seat. Set "D" lateral liner with top of receptacle at 9,136' with shoe at 16,827' 04:45 05:00 0.25 9,136 9,136 COMPZ CASIN( OTHR P Monitored well-static, pumped dry job 05:00 08:30 3.50 9,136 100 COMPZ CASIN( RUNL P POOH from 9,136' to Baker running tool at 100' 08:30 10:15 1.75 100 0 COMPZ CASIN( PUTB P Held PJSM then POOH from 100' LD Baker's liner running tool, cleared and cleaned ri floor 10:15 10:30 0.25 0 0 COMPZ STK OTHR P Held PJSM with crew and Baker rep on MU fishing tools for retrieving whi stock 10:30 11:00 0.50 0 61 COMPZ STK PULD P MU fishing BHA #12 with whipstock retrieving hook, 1 jt of 5" HWDP, flt sub, bumper sub and oil jars RIH to 61'. 11:00 16:00 5.00 61 8,928 COMPZ STK TRIP P RIH with fishing BHA #12 from 61' to WS slide at 8,828' then washed across WS slot, st wt up 148K, do wt 68 K 16:00 17:00 1.00 8,928 8,928 COMPZ STK OTHR P Worked retrieving tool and latched onto whipstock, worked jars and came loose from WS, rehooked same and staged up wt to 150K over st wt (300K) and WS came free, st wt 150K ~~ ®. ~ ®e ____ ~. m mm__. m w ~ ~ __.___ . __ .~w~ewm®~ _ ~ ®.m _~.. ______ ~m_ ®m~~ ~ Q..~_. ~..a_e. ~, ~....._____ ~ _ W.. _.~..., _...-......~.,~ ®~~®.~ Time Logs - _~-- _-~ -_ - - Date From To Gur 5. D , E. De th Phase Code Subcode T 09/23/2006 17:00 17:30 0.50 8,928 8,794 COMPZ STK TRIP P POOH 2 stds to 8,794' and hole was swabbin 17:30 18:45 1.25 8,794 8,794 COMPZ STK CIRC P Circ btms up at 8,794', max gas at btms up 44 units, circ at 90 spm, 320 gpm at 600 psi, 8.8 ppg MOBM in and out 18:45 19:00 0.25 8,794 8,794 COMPZ STK OWFF P Monitored well-static, pumped dry job 19:00 00:00 5.00 8,794 2,564 COMPZ STK TRIP P POOH slow with whipstock from 8,794' to 2,564', hole takin talc fill. 09/24/2006 00:00 01:00 1.00 2,564 0 COMPZ FISH TRIP P Cont to POOH from 2,564' to fishing BHA #12 and had no recove 01:00 02:30 1.50 0 0 COMPZ FISH PULD T LD retrieving hook, 1-jt HWDP, bumper sub and 'ars 02:30 02:45 0.25 0 0 COMPZ FISH PULD T MU 8 3/8" box tap flt sub, bumper sub and oil jars on BHA #13 RIH and took wt while oin thru stack 02:45 06:30 3.75 0 0 COMPZ FISH OTHR T Drained stack and found an additional piece of DP wiper rubber on wear bushing, circ out of hole using WS retrieving hook and circ out while rotating and recip. pipe, circ at 650 gpm, 1,000 psi and 60 rpm's, LD retrievin hook. 06:30 09:45 3.25 0 8,500 COMPZ FISH TRIP T RIH with fishing BHA #13 to 8,500', box to ,bum er sub and oil 'ars 09:45 10:00 0.25 8,500 8,500 COMPZ RIGMN SFTY P Held PJSM on slip and cutting of drlg line 10:00 11:30 1.50 8,500 8,500 COMPZ RIGMN SVRG P Slip and cut 71' of drlg line and serviced ri 11:30 12:00 0.50 8,500 8,852 COMPZ FISH TRIP T RIH from 8,500' to 8,852' 12:00 12:45 0.75 8,852 8,852 COMPZ FISH CIRC T Pumped 35 bbl wt'd hi vis sweep (3# over mw) at 8,852' and circ hole clean, had no increase in cuttings back from the sweep, circ at 185 spm, 650 gpm at 2,150 psi and 40 rpm's with 6-9K ft-Ibs for ue, st wt u 140K, do wt 67K 12:45 13:15 0.50 8,852 8,924 COMPZ FISH FISH T RIH and tagged top of whipstock at 8,924', worked box tap over top of WS, worked torque up to 15K ft-Ibs, PU and saw 15K dra and si n of swabbin 13:15 13:30 0.25 8,924 8,924 COMPZ FISH OTHR T Monitored well-pumped dry job 13:30 19:30 6.00 8,924 0 COMPZ FISH TRIP T POOH from 8,924' and had no recovery, talc fill on trip out 71 bbls, actual fill 79 bbls. 19:30 20:15 0.75 0 0 COMPZ FISH PULD T LD box tap, no wear spots in ID of box to 20:15 20:30 0.25 0 61 COMPZ FISH PULD T MU j-hook retrieving tool on jt of HWDP and RIH with float sub, bumper sub and oil 'ars on fishin BHA #14 20:30 23:00 2.50 61 8,886 COMPZ FISH TRIP T RIH with BHA #14 to 8,886', st wt up 138K, do wt 64K mm-.~~ .. ~~ ~~ u... ____ ~ _._~ ~ ~~ _.me _ e~m _ e~m~__s~_~ ~ ~ ~ _.® ~wm~~~..~.. ~Ma.........~, _~ ~ ....d.__-___._ _._ _. a ---- - -- - ---- - --- Time Los ~ Date From To Dur S. D E. De th Phase Code Subcode T I 09/24/2006 23:00 00:00 1.00 8,886 8,924 COMPZ FISH FISH T Washed across whipstock face at 90 spm, 320 gpm at 850 psi, then attempted to hook WS, after several attempts hooked WS and was able to set 10K wt down with no increase in up wt, after 2nd time slipped off WS, cont to work hook. 09/25/2006 00:00 03:30 3.50 8,924 8,924 COMPZ FISH FISH T Cont to attempt to hook whipstock (WS) was able to set up to 25K wt do and wouldn't see any PU wt, would unhook and rehook and no change, circ across WS slide also and still would not see an si ns of add. wt. 03:30 07:30 4.00 8,924 62 COMPZ FISH TRIP T Pumped dry job and POOH from 8,924' to BHA #14 at 62' 07:30 08:00 0.50 62 0 COMPZ FISH PULD T LD retrieving hook and set jt of HWDP and 'ars on skate. 08:00 08:30 0.50 0 62 COMPZ FISH PULD T MU fishing BHA #15 with bent hook retrieving tool, HWDP, flt sub, bumper 'ars and oil 'ars RIH to 62' 08:30 12:00 3.50 62 8,886 COMPZ FISH TRIP T RIH with BHA #15 from 62' to 8,886', st wt u 140K, do wt 72K 12:00 13:00 1.00 8,886 8,930 COMPZ FISH FISH T Washed down from 8,886' to 8,936' washing across WS face, then worked bent hook and latched in WS setting up to 20K wt dn, would PU and not see any increase in up wt, attempted to wash WS slide and was unable to o ast 8,930', 13:00 13:15 0.25 8,930 8,930 COMPZ FISH OTHR T Monitored well-static, pumped dry job 13:15 16:45 3.50 8,930 92 COMPZ FISH TRIP T POOH from 8,930' to 92' and had recovered WS slide with the bent hook, WS appears to have sheared off at the safety disconnect. (WS will rotate once sheared, possibly not allowing box tap to catch WS) ,top of WS looked ok, calc fill on trip out 72 bbls, actual 77 bbls 16:45 17:45 1.00 92 0 COMPZ FISH PULD T LD bent hook and WS slide 17:45 19:00 1.25 0 241 COMPZ FISH PULD T MU fishing BHA #16 RIH to 241', MU 8 1/8" overshot with 4 3/4" grapple, flt sub, bumper sub,oil jars and 7 jts 5" HWDP. 19:00 22:45 3.75 241 8,881 COMPZ FISH TRIP T RIH from 241' to 8,881' 22:45 23:30 0.75 8,881 8,942 COMPZ FISH FISH T Est circ at 2 bpm at 220 psi, rot at 20 rpm's, rot wt 85K, up wt 138K, do wt 70K, washed down w/o rotating and engaged fish at 8,942', worked st wt up to 225K setting off jars twice then PU to 200K and tool pulled free, had 5-6K increase in st wt. ~~ ~ ~, _ ~emm _ m ~._.~ _ dwm ~ 1 ~~ . . ~ .e.m. . ._ .,.. _.. m_ .,.__m __ .., Time Logs Date From To Dur S. D E. De th'+ Phase Code Si~bcode T 09/25/2006 23:30 00:00 0.50 8,942 8,942 COMPZ FISH OTHR T Monitored well, fluid level began to drop, took 15 bbls to fill hole, hole took 10 bbls in 15 min, held PJSM on POOH wet. 09/26/2006 00:00 00:15 0.25 8,942 8,942 COMPZ FISH PULD P PJSM-Topic-Tripping out of hole. 00:15 04:30 4.25 8,942 242 COMPZ FISH TRIP T POH from 8942' to 242' MD. 04:30 06:00 1.50 242 0 COMPZ FISH PULL T Lay down fish & retrieving tool assembly (Liner seals-stop-unloader-space out pup-blank sub-anchor & bottom half of safet disconnect. 06:00 06:30 0.50 0 0 COMPZ FISH OTHR T Clear & clean rig floor. 06:30 07:30 1.00 0 0 COMPZ DRILL PULD P P/U & R/U mouse hole=lay down 6 jts. hwd =R/D & UD mouse hole. 07:30 08:30 1.00 0 0 COMPZ DRILL OTHR P Rig up to run plop & Drop assembly with inner strin & Slim MWD. 08:30 08:45 0.25 0 0 COMPZ DRILL SFTY P PJSM-Topic=Plop & Drop. 08:45 12:00 3.25 0 466 COMPZ DRILL PULD P Pick up & make up plop & drop assembl as er baker re . 12:00 12:30 0.50 466 466 COMPZ DRILL OTHR P Change out handling equipment=rig down slimhole cs .tools. 12:30 13:00 0.50 466 466 COMPZ DRILL OTHR P Clear & clean rig floor. 13:00 13:15 0.25 466 466 COMPZ DRILL OTHR P Pulse test MWD Good detection @ 36 s m 750 si. 13:15 18:00 4.75 466 9,184 COMPZ DRILL TRIP P Trip in hole w/ H.H from 466.0 to 9184.0 @ 70-80 fpm-fill every 20 stands-talc. disp.=71.25 bbls. Actual dis .70.2 bbls. P/U 137k S/O 70k. 18:00 18:30 0.50 9,184 9,095 COMPZ DRILL OTHR P Rack back 1 stand to orient bent sub thru window. 18:30 21:30 3.00 9,095 8,825 COMPZ DRILL OTHR P Tag @ 9184.0 & latch hook, Pick up & turn 180 deg.-unlatch & slack off to no-go @ 9190-pick up turned 180 deg.-rehooked, dropped 29/32 ball-circ. down 3454 strokes, release running tool & inflate packer-pull stand to 8825=5k less than icku . 21:30 21:45 0.25 8,825 8,825 COMPZ DRILL OWFF P Monitor well-static-pump slug. 21:45 00:00 2.25 8,825 5,592 COMPZ DRILL TRIP P POH w/ running tool &slimhole MWD from 8825 to 5592'. 09/27/2006 00:00 00:15 0.25 5,592 5,592 COMPZ DRILL SFTY P PJSM-Topic=Tripping out of hole. 00:15 02:30 2.25 5,592 0 COMPZ DRILL TRIP P Continue POH from 5592 to running tool + inner strin w/ Slim MWD. 02:30 03:30 1.00 0 0 COMPZ DRILL PULD P Lay down hook hanger running tool + inner strin w/ Slim MWD. 03:30 04:00 0.50 0 0 COMPZ DRILL PULD P Clean & lay down all Baker tools out beaver slide. 04:00 04:30 0.50 0 0 COMPZ DRILL OTHR P Pick up DP protectors. Pick up & rig u mouse hole. ~ ~~ _ ~...~__ ~md-.,~ _sm~ ~m ~.~e- ~~a_- .... .. ~a ~~ ~__ ~ ~ .. ~® ~..mmmew~,~ . ~~_____ ~as~.~ ......_....~,..~,, 3 _ t L ~ __,___ .. _. _ _~ ®®m ~ ®®e ~.~. ®_ .~®.de _ .. ~,__.. _ .,~ .~__ ~ _.....___ ~~_._ _ ~~e~..... _ _ _ _..._ _ i Time Logs Date From To Dur S. D E. Depth Phase Code Subcode T __ 09/27/2006 04:30 12:00 7.50 0 0 COMPZ DRILL PULD P Lay down DP 36 jts. 5"=change over handling equipment to 4". continue la in down 196 'ts. 4" DP. 12:00 13:15 1.25 0 0 COMPZ DRILL PULD P Lay down 19 stds. 4" DP. 13:15 13:45 0.50 0 0 COMPZ DRILL OTHR P Change out handling tools=pick up thread protectors-remove 4" DP from i e shed. 13:45 22:00 8.25 0 0 COMPZ DRILL PULD P Lay down 100 stds. 5" DP-30 w/ su ersliders-40 slick-30 w/ to-tads. 22:00 22:45 0.75 0 0 COMPZ DRILL PULD P Clean & clear floor-lay down to-tads & mouse hole. 22:45 23:30 0.75 0 0 COMPZ RPCOh RURD P PU 1 jt 4.5" #12.6 L80 IBTM tbg. 23:30 00:00 0.50 0 0 COMPZ RPCOh PULD P Make up guide shoe. 09/28/2006 00:00 00:15 0.25 0 0 COMPZ RPCOh SFTY P PJSM-Topic=Running 4.5" tbg. 00:15 05:30 5.25 0 8,000 COMPZ RPCOh PULD P Run in hole picking up 4.5" Tbg. 255 'ts. 05:30 06:30 1.00 8,000 8,000 COMPZ RPCOh RURD P Rig down single csg. tongs & pick up stacked ton s from beaver slide. 06:30 07:30 1.00 8,000 7,820 COMPZ RPCOI~ CIRC P Pulled 2 stands wet=mixed & pumped slu . 07:30 12:00 4.50 7,820 1,000 COMPZ RPCOh TRIP P POH standing back in derrick 74 stands 4.5" tb . 12:00 12:15 0.25 1,000 0 COMPZ RPCOh TRIP P POH standing back in derrick 11 stands 4.5" tb .Total 85 stands. 12:15 12:45 0.50 0 0 COMPZ RPCOh OTHR P Clear & clean floor. 12:45 13:30 0.75 0 0 COMPZ RPCOh OTHR P Pull wear bushing-lay down same & uller. 13:30 14:00 0.50 0 0 COMPZ RPCOh SFTY P PJSM-Topic=Make up ESP assembly. 14:00 20:45 6.75 0 100 COMPZ RPCOh PULD P Pick up pump motor, fill w/oil, vacume seal air out, pick up tandem seal section, 2 jts. 4.5" tbg & discharge sub. 20:45 21:30 0.75 100 100 COMPZ RPCOti PULD P Assemble pump. 21:30 21:45 0.25 100 100 COMPZ RPCOh RURD P Rig up hawco wire line. 21:45 00:00 2.25 100 100 COMPZ RPCOh PULD P Run pump &packoff in on wireline. Chan a out seals on ackoff. 09/29/2006 00:00 00:15 0.25 200 200 COMPZ RPCOh SFTY P PJSM-Topic=ESP Completion. 00:15 00:30 0.25 200 200 COMPZ RPCOh DHEQ P Test packoff to 1000# OK. Chart same. 00:30 00:45 0.25 200 200 COMPZ RPCOti RURD P Rig Down Hawco wire line unit. 00:45 02:00 1.25 200 973 COMPZ RPCOti TRIP P Pick up 2 jts. 4.5" tbg. & 1 GLM w/ dummy valve installed & run in hole w/ stands from derrick to 973.0 02:00 03:00 1.00 973 973 COMPZ RPCOh DHEQ T Test electric cable w/ 3 different meters. Test Failed e.®~ m m.m~ ~me~ _._~. ~ ~.~.®~ . w m _sm~ ~ ~-- _ ~. _._ ~....~... _...~......, .... _ me. a .~~ fit. ~: i3I a ~ ~ ~.....s. ~m ..m.~~,..~ ,.__._,_. a ,. ~.m.~.~.~....... ...~.®.._ ~...__._ ...e~.~ ...., e ...~.~ ....®t` Time Logs _ Date From To Dur S. D E.;De~th Phase Code _ Subcode T 09/29/2006 03:00 06:00 3.00 973 0 COMPZ RPCOI~ TRIP T POH wet to A well discharge sub removing clamps & bands. Lay down same, Pull up to A well pump gauge laying down 2 jts. 4.5" tbg. 1 GLM Testing cable several times. (Found bad A Well um Gau e 06:00 07:30 1.50 0 0 COMPZ RPCOh OTHR T Wait on wire line unit to pull slip top ackoff & um . 07:30 12:00 4.50 0 0 COMPZ RPCOh PULD T Rig up wire line unit-pull slip stop packoff &pump-reinstall-redress ackoff & install same. 12:00 12:30 0.50 0 0 COMPZ RPCOh DHEQ T Rig up & test ESP pump packoff to 1000# on chart for 10 mins. OK. 12:30 13:00 0.50 0 0 COMPZ RPCOh RURD T Rig down hawco wire line unit. 13:00 14:00 1.00 0 0 COMPZ RPCOh PULD T Lay down pump motor & pump gauge. 14:00 15:00 1.00 0 0 COMPZ RPCOh OTHR T Uncrate new A-Well pump gauge in i eshed. CO same. 15:00 15:45 0.75 0 0 COMPZ RPCOti PULD T Pick up pump motor w/new gauge-fill w/oil-vac out air. 15:45 16:15 0.50 0 0 COMPZ RPCOh OTHR T Tie in control line to motor. 16:15 18:00 1.75 0 0 COMPZ RPCOh PULD T Latch up intake screen & seal assembly from derrick, Attach pump motor &gauge-recheck oil level, Attach ESP Cable. 18:00 20:00 2.00 0 140 COMPZ RPCOh TRIP T RIH to 140'. Pick up discharge sub, tie in control line for pump motor, pick up 2 sin les & 1 GLM w/ dumm valve. 20:00 21:00 1.00 140 973 COMPZ RPCOh TRIP T RIH to 973'. 21:00 21:15 0.25 973 973 COMPZ RPCOh DHEQ P Test cable. OK 21:15 00:00 2.75 973 2,147 COMPZ RPCOti TRIP P RIH testing cable every 10 stands to 2147'. 09/30/2006 00:00 00:15 0.25 2,147 2,147 COMPZ RPCOh SFTY P PJSM-Topic=4.5" ESP completion. 00:15 09:30 9.25 2,147 7,301 COMPZ RPCOh TRIP P RIH from 2147' to 7301' w/ 4.5" tbg. using cannon clamps every other jt. for cable (Testing cable every 1000') chan ed 2 collars out on 't. # 132-241. 09:30 12:00 2.50 7,301 7,301 COMPZ RPCOh OTHR P Ran out of cable-splice on new reel-simops flush both pumps w/ water & safesurf-0, take apart sperry geo-manifold, change roughneck heads to 5". 12:00 15:00 3.00 7,301 7,301 COMPZ RPCOh OTHR P Continue splicing on new rell sime-ops clean out cellar box w/ guzzler, fix top drive service loop D-rings, ready tools in cellar for ni le down. 15:00 15:30 0.50 7,301 7,622 COMPZ RPCOti TRIP P Continue RIH from 7301' to 7622'. 15:30 15:45 0.25 7,622 7,622 COMPZ RPCOh DHEQ P Test cable. OK ~~~. .®®®e® -m ~~.~ emm~ m®_e .. ~ ~.~ ~.~.~.. ~. ~ F~ f ~~ Time Logs ~ Date From To Dur S. D E. De th Phase Code Subcode T 09/30/2006 15:45 17:15 1.50 7,622 8,141 COMPZ RPCOti TRIP P RIH from 7622' to 8141', lay down top jt. of stand #86, pick up 6.20' pup. 32.90' single w/ 1.82' vetco-gray han er-orient same. 17:15 20:15 3.00 8,141 8,141 COMPZ RPCOh OTHR P Plice in lower pigtail/penetrator. 20:15 20:30 0.25 8,141 8,141 COMPZ RPCOti DHEO P Test Cable. OK 20:30 20:45 0.25 8,141 8,210 COMPZ RPCOh OTHR P Orient & land tbg. hanger in tbg. spool, RILDS, la down landin 't. 20:45 21:45 1.00 8,210 8,210 COMPZ RPCOh OTHR P Lay down csg. tools & clear floor. 21:45 22:00 0.25 8,210 8,210 COMPZ RPCOh DHEQ P Test tbg. hanger-upper & lower to 5000# OK. 22:00 22:45 0.75 8,210 8,210 COMPZ RPCOh NUND P Nipple down BOPE-choke line & pull riser. 22:45 00:00 1.25 8,210 8,210 COMPZ RPCOh NUND P Nipple up & orient tree. 10/01/2006 00:00 00:15 0.25 COMPZ RPCOti SFTY P PJSM -Hazard Recognition NU tree & Test 00:15 01:30 1.25 COMPZ RPCOti SIPB P Finish NU Tree -Test Hanger void 5000psi, 10 min Good test -Test Penetrator Good megger, Fill tree with diesel and test Lo 250 & 5000 hi. Dry rod 2 wa check out. 01:30 02:00 0.50 COMPZ RPCOti RURD P R/U Scaffold on tree, clean cellar box with su er sucker 02:00 05:30 3.50 COMPZ RPCOti FRZP P PJSM - RU Little Red Serv., Pressure test lines to 2500 psi for 10 min Good Test, Freeze protect well pumping 595 bbls diesel down ann taking returns thru 4.5" tbg and Willis choke. Start pumping @ 3bpm with full returns and stagged up to 5 bpm = 980 psi. After pumping 595 bbls no diesel had reached surface. After checking volume of fluid returns it was noted that 200 bbls was total returns. More diesel was ordered because mud was still returning to surface. ""*"Note""' Siops Change out bttm rams to 7 5/8" while dis lacin . 05:30 09:00 3.50 COMPZ RPCOti FRZP T Get 300 bbls diesel from CPF1 09:00 10:45 1.75 COMPZ RPCOh FRZP T Hot Oil pump diesel. Start @ 1.5 bpm= 690 psi No Loses, Final @1.7 bpm = 300-400 psi. Pumped 157 bbls w/ 178 bbls returns. 10:45 11:00 0.25 COMPZ RPCOh FRZP P Secure well - RD and blow down Little Red 11:00 12:00 1.00 COMPZ RPCOh NUND P RU Lubricator and install BPV - Secure Tree & Well head. *"** Note **'`" Release Rig@ 12:00 Noon 10/1/06 -Will move to 1J-115 mm~~._. ~ __._e_ __.. ~_____ _~ee__._ _~_____~.___ ~ . .._. ~~~ .. ~. ~w _,~ __.__... ~ ~_ _.. ~ ~ _.__.~ ...._ .._ ~. ~ ,..._ _.....~. _~ _ _ __~__ __ _... .. ~_ ._ . _ es® ~ _ ~ .__.__..._ . ~ . ~_. • • 30-Oct-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-137L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 13,757.69' MD Window /Kickoff Survey: 8,921.00' MD (if applicable) Projected Survey: 16,840.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICHCHALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchordag~e, AK 99518 Date I DU t v ~~ ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) acs c~-~~q ~ • 30-Oct-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-137L1 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,846.13' MD Window /Kickoff Survey: 8,921.00' MD (if applicable) Projected Survey: 13,930.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date I Si ned v ~L y Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~o ~- l o~ ~J • 30-Oct-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-137L1 PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,058.82' MD Window /Kickoff Survey: .8,921.00' MD (if applicable) Projected Survey: 15,552.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorageh^ AK 99518 ~'1 Date ~ Nar ~d~ ~ Signed V Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • WELL LOG TRANSMITTAL • To: State of Alaska October 20, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data: IJ-137, L1, LI PB 1 & L1 PB2, AK-MW-4559178 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23316-00, 60, 70 & 71 PLEASE ACI~VOWLEDGE RECEIPT BY SIGNLNG AND RETURi~TING A COPY OF THE TRANSNIITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: r Signed: 6 1 J t3~ ao~ -'v~ ¢ 'zPa'~' ~ a~a~~ ~ o~ -t o ~ [Fwd: RE: PB2 1J-137L1 (206-109)] • • Subject: [Fwd: RE: PB2 1J-137L1 (206-109)] From: Thomas Maunder <tommaunder~a~,admin.state.ak.us> Date: Thu,'21 Sep 2000 1 ~~: ~~~:C~3 -0800 To: tom m~umder~u~.admin.s~ate.ak.us Tom, This abandoned well bore segment was in the West Sak sands. Based on my personal experience with the West Sak, I agree that it will collapse and it will not contribute to production. I don't think it's worth making the operator apply for a separate permit to drill for this abandoned section. Steve D.. ------- Original Message -------- Subject:RE: PB2 1J-137L1 (206-109) Date:Tue, 19 Sep 2006 08:34:15 -0800 From:Nugent, David Arnold <David.A.Nugent(dconocophillps.com> To:Thomas Maunder <tom maunder~ladmn.state.ak.us> Hi Steve, After I found out yesterday Tam was out of the office; f spoke with liVinton Aubert and forwarded the e-mail on to him. The abandoned interval was within the target reservoir. About 1732' was open to the reservoir. David A. Nugent -----Original Message----- From: Thomas Maunder [mailto:tommaunder@admin.state.ak.us] Sent: Tuesday, September 19, 2006 8:06 AM To: Nugent, David Arnold Subject: Re: PB2 1J-137L1 (206-109) David, Tom is out of the office for a week or so, and I am monitoring his email. Was the abandoned interval within the target reservoir? If so, what amount of wellbore was open to the reservoir? Thanks, Steve Davies AOGCC 793-1224 Nugent, David Arnold wrote, On 9/18/2006 10:45 AM: 1 of 2 9/25/2006 4:12 PM [Fwd: RE: PB2 1J-137L1 (206-109)] • • Tom, We are continuing to experience difficulties with this well with its tendency to walk hard right. We had to plug back again over the weekend. PB2 • Well: 1 J-137L1 • Rig: Doyon 141 • Permit #: 206-109 • Date: September 16, 2006 • Time: 0615 hours • Last casing: 9-5/8" at 9435' • Top of window for L1: 8921' • MD of abandoned section: 13,820' - 15,552' At 15,552', we were approximately 200' right of our intended line. The well continues to walk to the right and we are unable to turn the well back to the left to get it back to our intended direction. This lateral has stayed in the sand the entire time, however, we project we could be as much as 500' right of our intended line at TD. We backed up to 13,820' and are sidetracking the well. We drilled to 14,110' when we experienced a GeoPilot failure. We are about back on bottom now after our trip to replace the GeoPilot with a motor. Our intent is to initially stay somewhat left of our intended line to compensate for the right hand walk. We plan to continue to drill to our original targeted TD. We will not case off the abandoned hole and expect it will eventually collapse. If you have any questions, please contact me. David A. Nugent Staff Drilling Engineer ConocoPhillips Alaska 907-265-6862 (office) 918-662-6886 (fax) 2 of 2 9/25/2006 4:12 PM RE: 1 J-137L 1 sidetrack Subject: RE: 1J-137L1 sidetrack From: "Nugent, David Arnold" <David.A.Nugent@conocophillips.com=> Date: Wed, 13 Sep 2006 10:07:5.7 -0800 To: L homas 1~laundc~ ~ atom ~naunderr~'admin.stat~.~ik.us=> Thanks. ~o~-~o~ -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, September 13, 2006 9:59 AM To: Nugent, David Arnold Subject: Re: 1J-137L1 sidetrack David, Unfortunate that you weren't able to steer as desired. I think experience has shown that WS sand penetrations will collapse unless they are lined. Your penetration is also within the sand. The "lost" section should be called the PB 1. Good luck with the navigation in the new penetration. No new permit is needed. Tom Maunder, PE AOGCC Nugent, David Arnold wrote, On 9/13/2006 9:46 AM: Tom, Sidetrack PB1 • Well: 1J-137L1 • Rig: Doyon 141 • Permit #: 206-109 • Date: September 13, 2006 • Time: 0700 hours • Last casing: 9-5/8" at 9435' • Top of window for L1: 8921' • MD of abandoned section: 11,120' - 13,930' We kicked this well off out of a window at 8921' and it has exhibited a strong right hand walk in the D Sand. At 13,930', we were approximately 220' right of our intended line. The well continues to walk to the right and we are unable to turn the well back to the left to get it back to our intended direction. This lateral has stayed in the sand the entire time, however, we project we could be as much as 800' right of our intended line at TD. We backed up to 11,120' and are sidetracking the well. Our intent is to begin this sidetrack left of the line to compensate for the right hand walk. We expect this sidetrack will somewhat parallel the abandoned section of the hole for the first 2900', and we plan to continue to drill to our original targeted TD. We will not case off the abandoned hole and expect it will eventually collapse. If you have any questions, please contact me. 1 of 2 9/13/2006 10:09 AM !~ ~^,4 ,tea { ~ ~ ~ $ ~ •I~1 ~ °i "9 i 3 ALASSA OIL Al`ID GAS COI~TSERQATIOI~T C01~1Il~iISSIOI~T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-137L1 ConocoPhillips Alaska, Inc. Permit No: 206-109 Surface Location: 1545' FSL, 2278' FEL, SEC. 35, T11N, RlOE, UM Bottomhole Location: 1420' FSL, 1566' FEL, SEC. 14, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907)-3607 (pager). hairman DATED this ?day of July, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~~~ RECEIVED JUL 2 4 20Q6 20 AAC 25.005 Alaska Oil ~ Gas Cons. Commission 1 a. Type of Work: Drill ^/ ~ Re-drill ^ Re-entry ^ 1 b. Curcent Well Class: Exploratory ^ Development Oil ^/ - Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^/ ~ 1 c. Specify if well is propos 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-137L1 - 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17479' TVD: 3348' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surtace: 1545' FSL, 2278' FEL, Sec. 35, T11N, R10E, UM 7. Property Designation: ADL 25662 & 380058 ~ West Sak Oil Pool Top of Productive Horizon: 4773' FSL, 1490' FEL, Sec. 11, T10N, R10E, UM 8. Land Use Permit: ALK 471 & 2177 13. Approximate Spud Date: 8/14!2006 Total Depth: 1420' FSL, 1566' FEL, Sec. 14, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 558936 y- 5945359 ~ Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest .~ ~ ~ ~.:, -fv~- ~~±' ~ ~ /~~ well within Pool: none , 16. Deviated wells: Kickoff depth: $$42 : ft. Maximum Hole Angle: 93° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1557 psig °' Surface: 1176 psig 18. Casing Program S e ifi ti Setting Depth Quantity of Cement Size p c 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 Weided 80' 28' 28' 80' 80' 282 sx AS 1 16" 13.375" 68# L-80 BTC 3663' 28' 28' 3663' 2183' 690 sx AS Lite, 210 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 9262' 28' 28' 9262' 3502' 630 sx DeepCRETE 8.5" 4.5" 11.6# L-80 BTCM 8637' 8842' 3440' 17479' 3348' see above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Tota! Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): 1~~- Perforation Depth TVD (ft): 20. Attachments: Filing Fee _ BOP Sketch^ Drilling Programa Time v. Depth Plot ^ Shallow Hazard Analysis / Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 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 ~ l ~ Phone Z~~-G~ 3~ Date p~LY~oC r a db h nAll D Commission Use Only Permit to Drill / Number: ,' ~ ~ 6 r!.~%~ API Number: 50- p~~ ~~' ~~~~~µ- >~` Permit Approval ~ Date:y 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, g ydrdtes, or gas contained in shales: Samples req'd: Yes ^ No ~ d log req'd: Yes ^ No [~ Other: egg ~~~}~-fyc,, O~C~t~~~, H2S measures: Yes ^ No irecti n svy req'd: Yes [~ No ^ O(/I ROVED BY THE COMMISSION DATE: ~ {{{//// ,COMMISSIONER Form 10-401 Revised 12/2005 ~,; ~ ~ Submit in Duplicate L Applic~r Permit to Drill, Well 1J-137 L1 Revision No.O Saved: 19-Jul-06 Permit It -West Sak Well #1J-137L1 ""~ Application for PeYmit to D~'ill Document r.~ +'t r ~~~~~ M p x i m i a E 1N~11 5fQ1~uQ Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 25.005 (~........., ................................................................................................... 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25.OOS(c)(2) ......................................................................................................... 2 Requirements of 20 AAC 25.OS0(b) ............................................................................................................. 2 3. Blowout Prevention Equipment Information ...................................................... ..... 3 Requirements of 20 AAC 25.005(c)(3) ...........................................................•-•••......................................... 3 4. Drilling Hazards Information ..................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ........................................................................................................ 3 5. Procedure for Conducting Formation Integrity Tests .................................................. 3 Requirements of 20 AAC 25.005 (c)(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 25.005(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 25.005(c)(8) ......................................................................................................... 4 Lateral Mud Program (MI YersaPro Mineral Oil Base) ............................................................................:.. 4 9. Abnormally Pressured Formation Information ........................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .......................................................................•--.............................. 5 10. Seismic Analysis .............................•---........................................................................ 5 Requirements of 20 AAC 25.005 (c)(10) ....................................................................................................:. 5 11. Seabed Condition Analysis .......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11)......•••••••••••••••••• ...........................................••••••.•••..................•••••.. 5 12. Evidence of Bonding ................................................................................................... 5 ORIGINAL 1J-137 L1 PERMIT IT Page 1 of 6 Printed: 19-Jul-O6 Applic~or Permit to Drill, Well 1 J-137 L1 Revision No.O Saved: 19-Jul-O6 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 nutst he identified by a unique name designated by the operator and a unique API nutrzher assigned by the commission ztnder 20 AAC 25.040(Ir). f'or a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suuffaz to the rtarne designated fern the well Iry the operator and to the number assigned to the well by the comrrzisston. The well for which this Application is submitted will be designated as 1J-137 L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Per-rnit tv Drill must be accompanied by each of the following items, exccpt f<rr an item alreaa'y on file with the corrzrnistsion and identified in the application: {"2) a plat identifying the prvperry and the property s owners and showing (A)the coordinates of the proposed location of tlae well cat the surface, at the top of each objective fvrrnativrz, and at total depth, referenced to governrrtental section lines. (B) the coordinates of the proposed lacatiotz z?f the well at the surface, referenced to the state plane coordinate systeru for this state c7s maintained by the National fieodetic Suawev in the National {'lceanic and Atmo plzeric Admirzisiz-ativn; (C) the proposed depth of the wolf at the top «f each o[?jectiae formation and at total depth; Location at Surface 1,545' FSL, 2278' FEL, Section 35, T11N, R10E - ASP zone 4 NAD 27 Coordinates RKB Elevation 109' AMSL Northings: 5,945,359 Eastings: 558,936 Pad Elevation 81' AMSL Location at Top of Productive Interval (West Sak "D" Sand 4,773' FSL, 1,490' FEL, Section 11, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 8,842 Northings: 5,938,034 Eastings: 559,788 Total Vertical Depth, RKB: 3,440 Total VerticaZDepth, SS: 3,319 Location at Total De th 1,420' FSL, 1,566' FEL, Section 14, T10N, R10E ASP zone 4 NAD 27 Coordinates Measured Depth, RKB: 17,479 Northings: 5,929,401 Eastings: 559,788 Total Vertical Depth, RKB: 3,348 Total Vertical Depth, SS: 3,227 and (D) otlaer• information required try 2t) AAC 25.0?0("6); Requirements of 20 AAC 25.050(b) f a well is to be itztentivrzally deviated, the application for a Permit to Drill (Form 111-41I f) rrtttst (I) inchade a plat, drativn tv a suitable scale. showing the path of the proposed wellbore, iruazading atd adjacent wellbores within 200 feet of any portzon of the pr-oposzd well; 21GINAL 1J-137 L1 PERM/T!T Page 2 of 6 Printed: 19-Jul-O6 Applica~r Permit to Drill, Well 1J-137 L1 Revision No.0 Saved: 19-Jul-06 Please see Attachment l: Directional Plan and (?) for ail wells within 200 feet of the lroposed wellbore (Aj list the names of the operators of7hose wells, to tlae extent that those names are krsown or discoverable fn public records,, and show that each named operator has beery furnished a copy of the application 77v cerllfied mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevenfion Equipment Information Requirements of 20 AAC 25.005(c)(3) An caphliccation for ca Per-rnit to Drill must be accompanied by each of the following items, except for an item already on file with the cornrnission and identifier) in the application: (3) a diagram and description of the blugout prevention equipment (BOf'E) as required by 20 AAC 2S.t735, 20 A.AC 25.03f, or 20.A.RG ?5.0.3i, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-137 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) Arz application for a Permit to Drill must be accompanied by eaa12 of the following items, except for an item alread}~ on file with the commission and identified in the application: (4) iraforrrtatr,'on on drilling hazarcLs, including (A) tlae rracrxirrrum downhole pressure that may fie encounter-e~~ criteria zased to determine it, and mcaxirraum potential surface pressure hcased on a methane gradient; The expected reservoir pressure in the West Sak sands in the 1J-137 L1 is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,176 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 3,460'. The MPSP is: MPSP = (3,460 ft)(0.45 - 0.11 psi/ft) =1,176 psi ' (13) data ora poiential gas zones; The well bore is not expected to penetrate any gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation goner, and zones that have a propensity for differential sticla'rzg; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) _An izppliccation for a Permit to Drill must be accompanied by each of the,following> items, except_fcrr an item already on file with the corraraaission and ident~ied in the application: (~) a description of the procedzare for coraductirag frrrrnation integrity tests, as regzired under 20 A~IC 2 6.0300; No formation integrity test will be performed in the drilling of 1J-137 L1 6. Casing and Cementing Program Requirements of 20 AAC 25.OOS(c)(6) An application f<rr a Permit to Drill mast be accompanied by each of the follcnving iterrts, except fnr an item already on file v~ith tlae commission artd identified in the application: (fi) a complete proposed casing and cementing program as required by 20.2-AG?5.030,, and a description of`anv slotted liner; pre-perfi~rated liner, or screen to he lrastalled,~ 1J-137 L1 PERMIT IT Page 3 of 6 Printed: 19-Jul-06 Casing and Cementing Program See also Attachment 3: Cement Summa Applic~or Permit to Drill, Well 1J-137 L1 Revision No.O Saved: 19-Jul-O6 Hole Top Btm Csg/Thg Size Weight Length tLID/TVD tLID/TVD OD (in) (in) (Ib/ 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 3,663 28' / 28' 3,663' / 2,183' 690 sx ArcticSet Lite Lead, 210 sx Dee CRETE Tail Cement Top planned @ 5,785' 9-5/8" 12-1/4" 40 L-80 BTCM 9 262 28' / 28' 262' / 3 9 502' MD / 2,618' TVD. Cemented , , , w/ 630 sx Dee CRETE 5-1/2 8-1/2" B Sand Later TCM 8 220 9 262' / 3 502' 17,482' / 3 400 Slotte - o ted , , , _ 5-1/2 slotted 8-1/2" D Sand Lateral (1J-137L1) 11.6 L-80 BTCM 8,637 8,842' / 3,440' 17,4.79' / 3,348 Slotted- no cement 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application fhr ce .Permit to Drild must be accompanied lry each of the following items, except,firr an item adreadv on file with the corrttttission rand identified in the application: (?) a diagram and description of the diverter system as required fiy 20.L4C 25.035, unless this requiremertt is waived by the commission under 20 AAC 25.035(h)(2); No diverter system will be used during operations on 1J-137 L1 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) stn rtpplication for a Perrrait to Drill must he accompanied by each of the, following items, except,for an item already on file with the commission and idetzt~ed in the application: (z4) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20,4t1C 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) Value Densi (pp) 9.0 Plastic Viscostiy (Ib/100 s 15-25 Yield Point 18-28 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200 si & 150° Oil /Water Ratio 80:20 Electrical stabir >600 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. 1J-137 L1 PERMIT IT Page 4 of 6 Printed: 19-Jul-O6 a s. ~ ~ ~~ • Applic~r Permit to Drill, Well 1J-137 L1 Revision No.0 Saved: 19-Jul-06 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) .4rt application, far a Permit to Drill must be accompanied by each of tlae following hems, except for an item already an f le wiih the commission and identified ira the applicatian: (9) far an exploratory ar stratigraphic test rovell a talrulatian setting out ilae depths of predicted abnormally geo-pressured strata as rerizzired by 20r11t{:25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An applicatian far u Permit to L)rill rnzrst Ire accompczrticd by each ~f the fallowing itezrts, exe.ept far an item already ort_~le with the commissiara oral identified in the applicatian: (10).far an explaratorv or stratigraphic test well, a seismic refraction ar reflection analysis as r-eguired by 20 A.AC 25.C161(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) .4n application far a Permit to Drill must be accompanied by each o_f the following ziems, ea-cept for an item already on file with the commission and identified in the applicatian: (11) for a well drilled front an offshore platform, mobile hottom-founded stzn~rcture, jack-tip rig, ar floaFzng drilling veasel, an analysis of seabird canditiarzr us r-eyuired by 20 s~1 C 25.061(h),' Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application fcu^ a Permit to Drill roust be accompanied by each cf thefallawing items, except for an item already art,fle with the commission and identified in the applicatian: (12) evider~aae showing that the reguirements raj 20 ~2C 25.025 rBonding}have hegira rnet,~ 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) Arz application far a Permit to gill must be accompczraied by each of the following items, except for an item already orz tale with the commission arad 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-137 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 8,842' MD / 3,440' TVD, the top of the "D" sand. 2. Mi118-1/2" window. POOH. 3. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "D" sand lateral at 17,479' MD / 3,348' 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. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. 11. POOH, laying down drill pipe as required. 1J-137 L1 PERMIT IT Page 5 of 6 „~~ ~ Printed: 19-Jul-O6 • Applic~r Permit to Drill, Well 1J-137 L1 Revision No.0 Saved: 19-Jul-06 12. PU injection completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPE, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel by pumping into 4-1l2" x 9-5l8" annulus, taking returns from tubing and allowing to equalize. 15. Set BPV and move rig off. 16. Rig up wire line unit. Pull BPV. 17. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 18. Rig up wireline. Replace gas lift valves with blank dummy valves. 19. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) Ara application for a Permit to Drill rnuste _he accompanied by each of the follawzng items, except far an item already on file with the commission and identified in the application: (14} a general description rf Itow the operator plans to dispose of drilling nturt and cuttr.'ngs and a statement of whether the operator intenets to request autharizatiart Lander 2ll LAC 25.OhU far art annular disposal operation in t6ae welt.; 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 lE 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-137 L1 PERMIT IT Page 6 of 6 t~ ~.y ~ ~ ~ ~ n { Printed: 19-Jul-06 ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-137 -Slot 1 J-137 1J-137 L1 i Proposal Report 18 July, 2006 ~; ~ '~ ~p~rry Drilling ~-ervice~ C'RIGINAL J H W D Z Q U y~aON NM1nr fA r 01 d' ~~~ R M ~ ~ Z~a» ~COOM1 MNO~ M O~0 ~ r ~ O O ~ O N ~ M 0 Z r N M ._ `y a n J O M Q ~~~M3 3 7~"7J R R R ~ n 3 ~a ~~ YY_~or Y ~ ~ _ d N ~ ~o 'o a a '~ N m s~ ~` X 0 N 3. 3 a. c l ~ n ~ ~ r ~ , ~ 0 r ~ a ~ 00 r ,.~ r v o ------ ------- z- o N --- - 000 - _ _ d ~ ~ e68 ~ d °o ~ N ~ O M G ~ ti P ~ o N w O N \ x W n ~ 1\ ~ oss ~ d 'L G \~ J ~ d ~ ~ N O J C ;o \ ~ \\ ` rn ~~„ N lh \ c J j \ v m d 0 ~ L a \~ ~aoD&- o W _ _~ - o ~ __ -- - ~ _~ 0008 N W 00 ~ 9 F 0p~~ ~ J y V n D / rn H ' 0009 0 ~ 0 O ~ J m J age OQ~S r oooy i+f _ _ M ~ --O ~~~E ~a~A ~ °~n 0 0 100 a ~ O z )00 M 0 ____ --- - ___ ~ v 000 _- ~ - 3 m ~ C r^ _! F Q oDa r "P) ~ O e 'j~ C . 000 ~ d m J 'g00 r ~` 0 ~ N ~ o ~ °~ °o \ O \ ~ ~ g] 1f1 4~ W \ ~ g$y -~ F ~ m r ~ J ~ ~ r O ~ d O J xO W m w d c 0 U J v 0 °o N r N M LL] O N O •= O ~ ~ ~~ ~ ~ ~` ~ ~ ~~ r ~ r ~ - r o o u ~) r N N r V O M N N n w O Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-137 Wellbore: 1J-137 L1 Plan: 1J-137 L1 (wpO8) I -1 13 3/8" - - tt4° Spi~rryf Drilling Servlest- CUnv~caPhillipS Alaska 1'- 1 L7 : TOW @ 8842ft MD, 3440ft TVD - 4773ft FSL & 1490ft FEL -Sec 11 - T10N - R7 E ' ~I I~ 0 3000 L7 : BOW @ 8859ft MD, 3443ft I -61 -1051 -113'. -122! -131; c_ 0 ~-- ~ 1J-137 L1 Ti (wp08 L O Z \ L7 : Begin Exit of Lower D-Sand, Build @ 5°/100' 10612ft MD, 3431ft 7 O L1 : End Rathole -Build @ 3.5° to 91.2°, 8889ft MD, 3447ft T~ 'rao°----- _ L1 : Land in Lower D-Sand - Geosteer in Lower D, 9112ft MD, 3459ft~ 181° 180°-------- 1J-137 L1 T2{wp08 L1 : Begin Exit of Upper DSand, Drop @ 5°/100', 12112ft MD, 3399ft D- -- - - _ _ _ _ _ 180° - - - - iJ-137 L1 T3 {wp08 180° L1 : Begin Exit of Lower DSand, Build @ 5°N00', 13611ft MD, 3390ft TV~D 180° -. - iJ-137 L1 T4 (wp08 180° L7 _Begin Exit of Upper D-Sand, Drop @ 5°/100', 15111ft MD, 3362ft TUID 1J-13T L1 TS {wp08 180° -14000 1J-137 L1 T6 (wp08 180° " " " L1: Continue Geosteering in Lower DSand,16610ft MD, 3355ft TV - ' " -14875 - - _ iJ-137 L1 T7 (wp08 180° -15750 rL1: 17479ft MD, 3348ft TVD : 1420ft FSL & 1566ft FEL -Sec 14 - T10N - R7 E , iJ-137 L9 TS (Toe} (wp08 4 1/2" -16625 -6125 -5250 -4375 -3500 -2625 -1750 -875 ~~0 875 j~ 1750 2625 3500 4375 5250 6125 7000 (~~f~~t(~(1~'50ft/in) :: a ~ H alliburton Ener Services gy ° C ~ P'hiIl ~'~'~~`' C~iI taCQ 5 Planning Report -Geographic ---- - -~- ASaska Sipeirry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-137 -Slot 1J-137 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-137 Survey Calculation Method: Minimum Curvature Wellbore: 1J-137 L1 Design: 1J-137 L1 (wp08) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-137 -Slot 1J-137 Well Position +N/-S 0.00 ft Northing: 5,945,358.62 ft Latitude: 70° 15' 40.728" N +E/-W 0:00 ft Easting: 558,935.87 ft Longitude: 149° 31' 24.888" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-137 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 9/1/2006 23.98 80.78 57,564 Design 1J 137 L1 (wp08) Audit Notes: Version: Vertical Section: 11 Phase: PLAN Tie On Depth; Depth From (TVD) +N/-S +E/-W (ft) (ft) (ft) 40.00 0.00 0.00 Direction (°) 180.00 8,842.08 7/18/2006 4:53:58PM Page 2 of 7 COMPASS 2003.11 Build 50 `~~~~AL ~Halliburton Ener Services ~talnoCQP"hil~ ~ gy Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-137 Wellbore: 1J-137 L1 Design: 1J-137 L1 (wp08) Sperry Dr311ing Services Local Co-ordinate Reference: Well Plan 1J-137 -Slot 1J-137 TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) North Reference: True Survey Calculation Method: Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) ~ 8,842.08 80.00 178.71 3,440.00 -7,331.77 794.85 0.00 0.00 0.00 0.00 8,858.58 82.24 178.71 3,442.55 -7,348.06 795.22 13.60 13.60 0.00 0.00 8,888.58 82.24 178.71 3,446.59 -7,377.78 795.89 0.00 0.00 0.00 0.00 9,111.83 91.17 178.71 3,459.40 -7,600.38 800.90 4.00 4.00 0.00 0.00 9,181.90 91.08 180.81 3,458.02 -7,670.43 801.20 3.00 -0.13 3.00 92.51 10,598.09 91.08 180.81 3,431.33 -9,086.23 781.17 0.00 0.00 0.00 0.00 10,611.92 90.88 180.45 3,431.09 -9,100.05 781.01 3.00 -1.45 -2.63 -118.83 10,658.64 93.22 180.45 3,429.42 -9,146.75 780.65 5.00 5.00 0.01 0.11 10,959.85 93.22 180.45 3,412.52 -9,447.47 778.28 0.00 0.00- 0.00 0.00 11,011.98 90.61 180.45 3,410.78 -9,499.56 777.87 5.00 -5.00 -0.01 -179.90 12,111.98 90.61 180.45 3,399.07 -10,599.46 769.29 0.00 0.00 0.00 0.00 12,152.34 88.59 180.45 3,399.35 -10,639.83 768.97 5.00 -5.00 0.01 179.94 12,465.51 88.59 180.45 3,407.05 -10,952.89 766.52 0.00 0.00 0.00 0.00 12,511.47 90.89 180.45 3,407.26 -10,998.85 766.16 5.00 5.00 0.00 -0.03 13,611:47 90.89 180.45 3,390.17 -12,098.68 757.56 0.00 0.00 0.00 0.00 13,653.59 93.00 180.45 3,388.74 -12,140.77 757.23 5.00. 5.00 0.01 0.16 13,960.31 93.00 180.45 3,372.71 -12,447.06 754.81 0.00. 0.00 0.00 0.00 14,010.83 90.47 180.45 3,371.18 -12,497.55 754.41 5.00 -5.00 -0.01 -179.86 15,110.83 90.47 180.45 3,362.16 -13,597.48 745.82 0.00 0.00 0.00 0.00 15,142.08 88.91 180.44 3,362.33 -13,628.73 745.58 5.00 -5.00 -0.01 -179.89 15,473.97 88.91 180.44 3,368.66 -13,960.55 743.01 0.00 0.00 0.00 0.00 15,510.22 90.72 180.45 3,368.78 -13,996.80 742.72 b.00 5.00 0.02. 0:17 16,610.22 90.72 180.45 3,354.96 -15,096.68 734.09 0.00 0.00 0.00 0.00 16,845.86 90.72 180.45 3,352.00 -15,332.29 732.24 0.00 0.00 0.00 90.00 16,858.21 90.35 180.45 3,351.88 -15,344.64 732.14 3.00 -3.00 -0.03 -179.45 . 17,478.94 90.35 180.45 3,348.10 ~ -15,965.33 727.28 0.00 0.00 0.00 0.00 7/18/2006 4:53:58PM Page 3 of 7 COMPASS 2003.11 Build 50 '~~~L ~ ~ H alliburton Ener Services - - 9Y - A . ~Qt1000~"~"llEt 5 Pl i R rt G hi E : .._ __ ___W~.,~~ ann ng epo - eograp c Alaska Sperry Drtlfer~g Services, Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-137 -Slot 1J-137 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Doyon 15.(40+g1) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+g1) @-121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-137 Survey Calculation Method: Minimum Curvature Wellbore: 1J-137 L1 Design: 1J-137 L1 (wp08) Planned Survey 1J-137 L1 (wp08) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) lft) 8,842.08 80.00 178.71 3,440.00 3,319.00 -7,331.77 794.85 5,938,034.00 559,788.00 0.00 7,331.77 L1 : TOW @ 8842ft M D, 3440ft TVD - 4773ft FSL 8~ 1490ft FEL -Sec 11 - T10N - R10 E - 9 5/8" L1 TOW 8,858.58 82.24 178.71 3,442.55 3,321.55 -7,348.06 795.22 5,938,017:71 559,788.49 13.60 7,348.06 L1 : BOW @ 8859ft MD, 3443ft TVD 8,888.58 82.24 178.71 3,446.59 3,325.59 -7,377.78 795.89 5,937,988:.00 559,789.40 0.00 7,377.78 L1 : End Rathole -Build @ 3.5° to 91.2°, 8889ft MD, 3447ft ND 8,900.00 82:70 178.71 3,448.09 3,327.09 -7,389.10 796.15 5,937,976.69 559,789.74 3.99 7,389.10 9,000.00 86.70 178.71 3,457.32 3,336.32 -7,488.63 798.39 5,937,877.19 559,792.76. 4.00 7,488.63 9,100.00 90.70 .178.71 3,459.59 3,338.59 -7,588.56 800.64 5,937,777.29 559,795.79 4.00 7,588.56 I 9,111.83 91.17 178.71 3,459.40 3,338.40 -7,600.38 800.90 5,937,765.47 559,796.15 4.01 7,600.38 L1 : Land in Lower D-Sand - Geosteer in Lower D, 9112ft MD, 3459ft N D -1J-137 L1 T1 (wp08) 9,181.90 91.08 180.81 3,458.02 3,337.02 -7,670.43 801.20 5,937,695.43 559,796.99 3.00 .7,670.43 9,200.00 91.08 180.81 3,457.68 3,336.68 -7,688.53 800.94 5,937,677.33 559,796.88 0.00 7,688.53 9,300.00 91.08 180.81 3,455.80 3,334.80 -7,788.50 799.53 5,937,577.36 559,796.25 0.00 7,788.50 9,400.00 91.08 180.81 3,453.91 3,332.91 -7,888.47 798.11 5,937,477.39 559,795.61 0.00 7,888.47 9,500.00 91.08 180.81 3,452.03 3,331.03 -7,988.44 796.70 5,937,377.42 559,794.98 0.00 7,988.44 9,600.00 91.08 180.81 3,450.14 3,329.14 -8,088.42 795.28 5,937,277.45 559,794.35 0.00 8,088.42 9,700.00 91.08 180.81 3,448.26 3,327.26 -8,188.39 793.87 5,937,177.48 559,793.72 0.00. 8,188.39 9,800.00 91.08 180.81 3,446.37 3,325.37 -8,288.36 792.45 5,937,077.51 559,793.09 0.00 8,288.36 9,900.00 91.08 180.81 3,444.49 3,323.49 -8,388.33 791.04 5,936,977.54 559,792.45 0.00 8,388.33 10,000.00 91.08 180.81 3,442.60 3,321.60 -8,488.31 789.63 5,936,877.57 559,791:82 0.00 8,488.31 10,100.00 91.08 180.81 3,440.72 3,319.72 -8,588.28 788.21 5,936,777.60 559,791.19 0.00 8,588.28 10,200.00 91.08 180.81 3,438.83 3,317.83 -8,688.25 786.80 5,936,677.63 559,790.56 0.00 8,688.25 10,300.00 91.08 180.81 3,436.95 3,315.95 -8,788.22 785.38 5,936,577.66 559,789.93 0.00 8,788.22 10,400.00 91.08 180.81 3,435.06 3,314.06 -8,888.19 783.97 5,936,477.69 559,789.30 0.00 8,888.19 10,500.00 91.08 180.81 3,433.18 3,312.18 -8,988.17 782.55 5,936,377.72 559,788.66 0:00 8,988.17 10,598.09 91.08 180.81 3,431.33 3,310.33 -9,086.23 781.17 5,936,279.66 559,788.04 0.00 9,086.23 10,600.00 91.05 180.76 3,431.29 3,310.29 -9,088.14 781.14 5,936,277,74 559,788.03 2.93 9,088.14 10,611.92 90.88 180.45 3,431.09 3,310.09 -9,100.05 781.01 5,936,265.83 559,788.00 3.01 9,100.05 L1 : Begin Exit of Lower DSand, B uild @ 5°11 00' 10612ft MD, 3431ft TVD - 1J-137 L 1 T2 (wp08) 10,658.64 93.22 180.45 3,429,42 3,308.42 -9,146.75 780.65 5,936,219.14 ` 559,788.00 5.00 9,146.75 I 10,700.00 93.22 180.45 3,427.10 3,306.10 -9,188.04 780.32 5,936,177.85 559,788.00 0.00 9,188.04 ~ 10,800.00 93.22 180.45 3,421.49 3,300.49 -9,287.88 779.54 5,936,078.02 559,787.99 0.00 9,287.88 10,900.00 93.22 180.45 3,415.88 3,294.88 -9,387.71 778.75 5,935,978.19 .559,787.99. 0.00 9,387.71 10,959.85 93.22 180.45 3,412.52 3,291.52 -9,447.47 778.28 5,935,918.44 559,787.98 0.00 9,447.47 11,000.00 91.21 180.45 3,410.97 3,289.97 -9,487.59 777.96 5,935,878.32 559,787.98 4.99 9,487.59 11,011.98 90.61 180.45 3,410.78 3,289.78 -9,499.56 777.87 5,935,866.35 559,787.98 5.02 9,499.56 11,100.00 90.61 180.45 3,409.84 3,288.84 -9,587.58 777.18 5,935,778.34 559,787.98. 0.00 9,587.58 ~ 11,200.00 90.61 180.45 3,408.78 3,287.78 -9,687.57 776.40 5,935,678'..36 559,787.99 0.00 9,687.57 11,300.00 90.61 180.45 3,407.71 3,286.71 -9,787.56 775.62 5,935,578.37 559,787.99 0.00 9,787.56 11,400.00 90.61 180.45 3,406.65 3,285.65 -9,887.55 774.84 5,935,478.39 559,787.99 0.00 9,887.55 11,500.00 90.61 180.45 3,405.59 3,284.59 -9,987.54 774.06 5,935,378.40 559,787.99 0.00 9,987.54 11,600.00 90.61 180.45 3,404.52 3,283.52 -10,087.53 773.28 5,935,278.42 559,788.00 0.00 10,087.53 11,700.00 90.61 180.45 3,403.46 3,282.46 -10,187.52 772.50 5,935,178.43 559,788.00 0.00 10,187.52 11,800.00 90.61 180.45 3,402.39 3,281.39 -10,287.51 771.72 5,935,078.45 559,788.00- 0.00. 10,287.51. 11,900.00 90.61 180.45 3,401.33 3,280.33 -10,387.51 770.94 5,934,978.46. 559,788:00 0.00 10,387.51 12,000.00 90.61 180.45 3,400.26 3,279.26 -10,487.50 770.16 5,934,878'.48 559,788.01 0.00 10,487.50 12,100.00 90.61 180.45 3,399.20 3,278.20 -10,587.49 769.38 5,934,778.49 559,788.01 0.00 10,587.49 7/18/2006 4:53:58PM Page 4 of 7 COMPASS 2003.11 Build 50 ~~r~~IAL ~ H alliburton Ener Services Pl i R rt G hi ann eograp ng epo - c ~~~{~ Sperry ilriiling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-137 -Slot 1J-137 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-137 Survey Calculation Method: Minimum Curvature Wellbore: 1J-137 L1 Design: 1J-137 L1 (wp08) Planned Survey 1J-137 L1 (wp08) ' Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 12,111.98 90.61 180.45 3,399.07 3,278.07 -10,599.46 769.29 5,934,766.52 :559,788.01 0.00 10,599.46 L1 : Begin Exit of UpperDSand, Drop @ 5°/100', 12112ft MD, 3399ft ND -1J-137 L1 T3 (wp08) 12,152.34 88.59 180.45 3,399.35 3,278.35 -10,639.83 768.97 5,934,72616. 559,788.01 5.00 10,639.83 12,200.00 88.59 180.45 3,400.52 3,279.52 -10,687.47 768.60 5,934,678.52 559,788.01 0.00 10,687.47 12,300.00 88.59 180.45 3,402.98 3,281.98 -10,787.43 767.82 5,934,578.56 559,788.01 0.00 10,787.43 12,400.00 88.59 180.45 3,405.44 3,284.44 -10,887.40 767.03 5,934,478.60 559,788.01 0.00 10,887.40 .12,465.51 88.59 180.45 3,407.05 3,286.05 -10,952:89 766.52 5,934,413.12 559,788.01 0.00 10,952.89 12,500.00 90.31 180.45 3,407.38 3,286.38 -10,987.38 766.25 5,934,378.63 559,788.01 4.99 10,987.38 12,511.47 90.89 180:45 3,407.26 3,286.26 -10,998.85 766.16 5,934,367.16 559,788.01 5.02 10,998.85 12,600.00 90.89 180.45 3,405.88 3;284.88 -11,087.36 765.47 5,934,278.65 559,788.01 0.00 11,087.36 12,700.00 90.89 180.45 3,404.33 3,283.33 -11,187.35 764.69 5,934,178.68 559,788.01 0.00 11,187.35 12,800.00 90.89 180.45 3,402.77 3,281.77 -11,287.33 763.91 5,934,078.70 559,788.01 0.00 11,287.33 12,900.00 90.89 180.45 3,401.22 3,280.22 -11,387.32 763.12 5,933,978.72 559,788.01 0.00 11,387.32 13,000.00 90.89 180.45 3,399.67 3,278.67 -11,487.30 762.34 5,933,878.74 559,788.01 0.00 11,487.30 13,100.00 90.89 180.45 3,398.11 3,277.11 -11,587.29 761.56 5,933,778.76 559,788.01 0.00 11,587.29 13,200.00 90.89 180.45 3,396.56 3,275.56 -11,687.27 760.78 5,933,678.78 559,788.02 ~ 0.00 11,687.27 13,300.00 90.89 180.45 3,395.01 3,274.01 -11,787.25 760.00 5,933,578.81 559,788.02 0.00 11,787.26 13,400.00 90.89. 180.45 3,393.45 3,272.45 -11,887.24 759.22 5,933,478.83 559,788.02 0.00 11,887.24 13,500.00 90.89 180.45 3,391.90 3,270.90 -11,987.22 758.44 5,933,378.85 559,788.02 0.00 11,987.22 13,600.00 90.89 180.45 3,390.35 3,269.35 -12,087.21 757.65 5,933,278.87 559,788.02 0.00 12,087.21 13,611.47 90.89 180.45 3,390.17 3,269.17 -12,098.68 757.56 5,933,267.40 559,788.02 0.00 12,098.68 L1 : Begin Ezit of Lower D-Sand, Build @ 5°/100', 13611ft MD, 3390ft ND -1J-137 Li T4 (wp08) 13,653.59 93.00 180.45 3,388.74 3,267.74 -12,140.77 757.23 5,933,225.31 559,788.02 5.00 12,140,77 13,700.00 93.00 180.45 3,386.32 3,265.32 -12,187.12 756.87 5,933,178.97 559,788.01 0.00 12,187,12 13,800.00 93.00 180.45 3,381.09 3,260.09 -12,286.98 756.08 5,933,079.12 559,788.01 0.00 12,286.98 13,900.00 93.00 180.45 3,375.86 3,254.86 -12,386.84 755.29 5,932,979.26 559,788.00 0.00 12,386.84 13,960.31 93.00 .180.45 3,372.71 3,251.71. -12,447.06 754.81 5,932,919.05 559,787.99 0.00 12,447.06 ..14,000.00 91.01 180.45 3,371.32 3,250.32 -12,486.72 754.50 5,932,879.38 559,787.99 4.99 12,486.72 14,010.83 90.47 180.45 3,371.18 3,250.18 -12,497.55 754.41 5,932,868.56 559,787.99 5.03 12,497.55 14,100.00 90.47 180.45 3,370.45 3,249.45 -12,586.72 753.72 5,932,779.40 559,787.99 0.00 12,586:72 14,200.00 90.47 180.45 3,369.63 3,248.63 -12,686.71 752.94 5,932,679.41 559,787.99 0.00 12,686.71 14,300.00 90.47 180.45 3,368.81 3,247.81 -12,786.70 752.15 5,932,579.42 559,787.99 0.00. 12,786.70 14,400.00 90.47 180.45 3,367.99 3,246.99 -12,886.70 751.37 5,932,479.43 559,788.00 0.00 12,886.70 14,500.00 90.47 180.45 3,367.17 3,246.17 -12,986.69 750.59 5,932,379.45 559,788.00 0.00. 12,986.69 14,600.00 90.47 180.45 3,366.35 3,245.35 -13,086.68 749.81 5,932,279.46 559,788.00 0.00 13,086.68 14,700.00 90.47 .180.45 3,365.53 3,244.53 -13,186.68 749.03 5,932,179.47 559,788.00 0.00 13,186.68 14,800.00 90.47 180.45 3,364.71 3,243.71 -13,286.67 .748.25 5,932,079.49 559,788.00 0.00 13,286.67 14,900.00 90.47 180.45 3,363.89 3,242.89 -13,386.67 747.47 5,931,979.50 559,788.01 0.00 13,386.67 15,000.00 90.47 180.45 3,363.07 3,242.07 -13,486.66 746.69 5,931,879.51 559,788.01 0.00 13,486.66 I 15,100.00 90.47 180.45 .3,362.25 3,241.25 -13,586.65 745.91 5,931,779.53 559,788.01 0.00 13,586.65 15,110.83 90.47 180.45 3,362.16 3,241.16 -13,597.48 745.82 5,931,768.70 559,788.01 0.00 13,597.48 L1:Begin Exit of Upper DSand, Drop @ 5°/100', 15111ft MD, 3362ft TVD -1J-137 L1 T5 (wp08) 15,142.08 88.91 180.44 3,362.33 3,241.33 -13,628.73 745.58 5,931,737.45 559,788.01 5.00 13,628.73 15,200.00 88.91 180.44 3,363.43 3,242.43 -13,686.64 745.13 5,931,679.55 559,788.02 0.00 13,686.64 ,15,300.00 88.91 180.44 3,365.34 3,244.34 -13,786.62 744.36 5,931,579.58 559,788.02 0.00 13,786.62 15,400.00 88.91 180.44 3,367.25 3,246:25 -13,886:59 743.58 5,931,479..60 559,788.03 0.00 13,886.59 15,473.97 88.91 180.44 3;368.66 3,247.66 -13,960.55 743.01 5,931,405.65 559,788.04 0.00 13,960.55 15,500.00 90.21 180.45 3;368.86 3,247.86 -13,986.58 742.80 5,931,379.63 559,788.04 4.99 13,986.58 ~ 15,510.22 90.72 180.45 3,368.78 3,247.78 -13,996.80 742.72 5,931,369.41 559,788.04 .5.03 13,996.80 7/18/2006 4:53:58PM Page 5 of 7 COMPASS 2003.1 LBuild 50 ~~~~~~~ ~ H alliburton Ener Services 9Y Ct311©CUPI"lII1 S {~ Pl hi i R t G ~ ~,>~li ann ng epor - eograp c Alaska S~isrry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-137 -Slot 1J-137 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-137 Survey Calculation Method: Minimum Curvature Wellbore: 1J-137 L1 Design: 1J-137 L1 (wp08) Planned Survey 1J-137 L1 (wp08) -- - Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft} (ft) 15,600.00 90.72 180.45 3,367.65 3,246.65 -14,086.57 742.02 5,931,279.64 559,788..03 0.00 14,086.57 15,700.00 90.72 180.45 3,366.39. 3,245.39 -14,186.56 741.23 5,931,179.66 559,788.03 0.00 14,186.56 15,800.00 90.72 180.45 3,365.14 3,244.14 -14,286.54 740.45 5,931,079.68 559,788.03 0.00 14,286.54 15,900.00 90.72 180.45 3,363.88 3,242.88 -14,386.53 739.66 5,930,979.70 559,788.03 0.00. 14,386.53 16,000.00 90.72 180.45 3,362.63 3,241.63 -14,486.52 738.88 5,930,879.71 559,788.02 0.00 14,486.52 16,100.00 90.72 180.45 3,361.37 3,240.37 -14,586.51 738.09 5,930,779.73 559,788.02 0.00 14,586.51 16,200.00 90.72 180.45 3,360.11 3,239.11 -14,686.50 737.31 5,930,679.75 559,788.02 0.00 14,686.50 16,300.00 90.72 180.45 3,358.86 3,237.86 -14,786.49 736.52 5,930,579.77 559,788.02 0.00 14,786.49 16,400.00 90.72 180.45 3,357.60 3,236.60 -14,886.48 735.74 5,930,479.78 559,788.01 0.00 14,886.48 16,500.00 90.72 180.45 3,356.34 3,235.34 -14,986.47 734.96 5,930,379.80 559,788.01. 0.00 14,986.47 16,600.00 90.72 180.45 3,355.09 3,234.09 -15,086.46 734.17 5,930,279.82 559,788.01 0.00 15,086.46 16,610.22 90.72 180.45 3,354.96 3,233.96 -15,096.68 734.09 5,930,269.60 559,788.01 0.00 15,096.68 L1: Contin ue Geostee ring in Low er DSand, 1 6610ft MD, 3 355ft TVD -1J-137 L1 T6 (wp08) 16,700.00 90.72 180.45 3,353.83 3,232.83 -15,186.45 733.38 5,930,179.84 559,788.01 0.00 15,186.45 16,800.00 90.72 180.45 3,352.58 3,231.58 -15,286.43 732.60 5,930,079.85 559,788.00 0.00 15,286.43 16,845.86 90.72 180.45 3,352.00 3,231.00 -15,332.29 732.24 5,930,034.00 559,788.00 0.00 15,332.29 1J-137 L1 T7 (wp08) 16,858.21 90.35 180.45 3,351.88 3,230.88 -15,344.64 732.14 5,930,021:66 559,788.00 3.00 15,344.64 16,900.00 90.35 180.45 3,351.63 3,230.63 -15,386.43 731.81 5,929,979.87 559,788.00 0.00 15,386.43 17,000.00 90.35 180.45 3,351.02 3,230.02 -15,486.42 731.03 5,929,879.88 559,788.00 0.00 15,486.42 17,100.00 90.35 180.45 3,350.41 3,229.41 -15,586.42 730.25 5,929,779.89 559,788.00 0.00 15,586.42 17,200.00 90.35 180.45 3,349.80 3,228.80 -15,686.41 729.46 5,929,679.90 559,788.00 0.00 15,686.41 17,300.00 90.35 180.45 3,349.19 3,228.19 -15,786.41 728.68 5,929,579.92 559,788.00 0.00 15,786.41 1.7,400.00 90.35 180.45 3,348.58 3,227.58 -15,886.40 727.90 5,929,479.93 559,788.00 0.00 15,886.40 17,478.94 90.35 180.45 3,348.10 3,227.10 -15,965.33 727.28 5,929,401.00 559,788.00 0.00 15,965.33 L1: 17479ft MD, 3348ft TVD : 1420ft FSL & 1566ft FEL -Sec 14 - T10N - R10E - 41/2" -1J-137 L1 T8 (Toe) (wp08) 7/18/2006 4:53:58PM Page 6 of 7 COMPASS 2003.11 Build 50 ~'RIGINAL ~ ~ Halliburton Ener Services gy - - Ct~t"1c~Ct~Philli s ~' Pl i R t G hi - 1 ~`~ - --- ann eograp ng epor - c A{aska Sperry Drilling Scrrvices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-137 - Slot 1J-137 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Doyo n 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyo n 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-137 Survey Calculation Method: Minim um Curvature Wellbore: 1J-137 L1 Design: 1J-137 L1 (wp08) Geologic Targets 1J-137 L1 TVD °C~~rc1~t P~~~~~ +N/-S +E/-W Northing Easting (ft) - S9~~sgr~ ft ft (ft) (ft) 3,348.10 1J -137 L1 T$ {Toe} {wp08} -15,965.33 727.28 5,929,401.00 559,788.00 - Point 3,390.17 1J-137 t_1 T4 {wp08} -12,098.68 757.56 5,933,267.40 559,788.02 -Point 3,399.07 1J-137 L.1 T3 {wp0$} -10,599.46 769.29 5,934,766.52 559,788.01 - Point 3,352.00 1J-137 L1 T7 {wp0$} -15,332.29 732.24 5,930,034.00 559,788.00 - Point 3,362.16 1J-137 L1 T5 {wp08} -13,597.48 745.82 5,931,768.70 559,788.01 - Point 3,459.40 1J-137 ~1 T1 {wp0$} -7,600.38 800.90 5,937,765.47 559,796.15 - Polygon 3,354.96 1J-1371.1 T6 (wp08} -15,096.68 734.09 5,930,269.60 559,788.01 - Point 3,431.09 1J-137 L1 T2 {wp0$} -9,100.05 .781.01 5,936,265.83 559,788.00 - Point - ~' Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter {ft) (ft) (") {~~) 3,663.00 2,183.00 13-3/8 16 8,842.09 3,440.00 9-5/8 12-1 /4 17,478.93 3,348.10 4-1/2 6-3/4 I--- - - ---- - - 7/18/2006 4:53:58PM Page 7 of 7 COMPASS 2003.11 Build 50 F e ~~+~~ v + ii ri COf1000 s~h1111~5 Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-137 1J-137 L1 1 J-137 L1 (wp08) Anticollision Report 18 July, 2006 T' Sperlry QIt7~1~11t~ ~ervic~s ~~ SURVEY PROGRAM Date: 200607-18700:00:00 Validated: Yes Version: 11.000 Depth From Depth To Survey/Plan Tool 40.00 800.00 CB-GYR0.55 800.00 8842.08 MWD+IFR-AK-CAZ~SC 8842.08 17478.94 1J-137 L1 (wp08) MWD+IFR-AK-CA7.SC ANTI-COLLISION SETTINGS Interpola0on Method: MD Interval: 50Sta0ons Depth Range From: 8842.08 To 17478.9355326689 Maximum Range:1943.89355326289 Reference: Plan: 1J-137 L1 (wp08) NAD 27 ASP Zone 4: WELL DETAILS: Plan 1J-137 Ground Level: 81.00 +NIS +EI-W Northing Easting Latittude Longitude 0.00 0.00 5945358.62 558935.87 70°15'40.728N 149°31'24.888W ConocoPhillips Alaska (K Drilling & Wells West Sak Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surfa Elli tic l C nic 7g p ce: a o Warning Method: Rules Based 330 - 30 25 0 20 300 60 1 1 270 5 ~.: 1 1 270 90 240 120 20 25 210 150 30 From Colour To MD 180 Travelling Cylinder Azimuth (TFO+AZn [°] vs Centre to Centre Separation X15 ft/in] 0 .250 250 500 SECTION DETAILS ' 500 750 Sec MD Inc Azi ND +N/S +ELW DLeg TFace VSec Target 750 1000 1 8842.08 80.00 178.71 3440.00 -7331.77 794.85 0.00 0.00 7331.77 2 8858.58 82.24 178.71 3442.55 -7348.06 795.22 13.60 0.00 7348.06 1000 """ 1250 3 8888.58 82.24 178.71 3446.59 -7377.78 795.89 0.00 0.00 7377.78 1250 1500 4 9111.83 91.17 178.71 3459.40 -7600.38 800.90 4.00 0.00 7600.38 1J-137 L1 T1 (wp08) 5 9181.90 91.08 180.81 3458.02 -7670.43 801.20 3.00 92.51 7670.43 1500 1750 6 10598.09 91.08 180.81 3431.33 5086.23 781.17 0.00 0.00 9086.23 7 10611.92 90.88 180.45 3431.09 5100.05 781.01 3.00 -118.83 9100.05 1J-137 L1 T2 (wp08) 1750 """"'"`"""""""'°'"" " 2000 8 10658.64 93.22 180.45 3429.42 5146.75 780.65 5.00 0.11. 914675 2000 2500 9 10959.85 93.22 180.45 3412.52 5447.47 778.28 0.00 0.00 9447.47 10 11011.98 90.61 180.45 3410.78 5499.56 777.87 5.00 -179.90 9499.56 2500 - - - 3000 11 12111.98 90.61 180.45 3399.07-10599.46 769.29 0.00 0.00 10599.46 1J-137 L1 T3 (wp08) 180 3000 3500 1212152.34 88.59 180.45 3399.35-10639.83 768.97 5.00 179.9410639.83 13 72485.51 88.59 180,45 3407.05-10952.89 766.52. 0.00 0.00 10952.89 3500 5000 14 12511.47 90.89 180.45 3407.28.10998.85. 766.16 5.00 -0.03 10998.85 sooo 6500 15 13611.47 90.89 180.45 3390.17 -72098.68 757.56 0.00 0.00 12098.68 1J-137 L7 T4 (wp08) Travellin C under Azimuth TFO+AZ p ~ 1 g y ( n [°] vs Centre to Centre Se aration 150 ft/in 16 13653.59 93.00 180.45 3388.74-12140.77 75723 5.00 0.16 12140.77 6500 8000 17 13960.31 93.00 180.45 3372.71 -12447.06 754.81 0.00 0.00 12447.06 18 14010.83 90.47 180.45 3371.18.12497.55 754.41 5.00 -179.86 12497.55 8000. 9500 19 15110.83 90.47 180.45 3362.16.13597.48 745.82 0.00 0.00 13597.48 1J-137 Lt TS (wp08) 9500 1100 20 15142.08 88.91 180.44 3362.33.13626.73 745.58 5.00 -179.89 13628.73 21 15473.97 86.91 180.44 3366.66.13960.55 743.01 0.00 0.00 13960.55 11000 1250 2215510.22 90.72 780.45 3366.78-13996.80 742.72 5.00 0.1713996.80 12500 1400 23 16610.22 90.72 180.45 3354.96-15096.68 734.09 0.00 0.00 15096.68 1J-037 L1 T6 (wp08) 24 16845.86 90.72 180.45 3352.00 -15332.29 732.24 0.00 90.00 75332.29 1J-137 L7 T7 (wp08). 14000 1550 25 16858.21 90.35 180.45 3351.88-15344.64 732.14 3.00 -179.45 15344.64 REFERENCE INFORMATION 15500 1700 26 17478.94 90.35 180.45 3348.10 -15965.33 727.28 0.00 0.00 15965.33 1J-137 L1 TB (Toe) (wp08) Coordinate (N/E) Reference: Well Plan 1J-137 -Slot 1J-137, True North 17000 0 Vertical (ND) Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Section (VS) Reference: Slot -1J-137(O.OON, O.OOE) Measured Depth Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)} Calculation Method: Minimum Curvature Slot 1J-137 Halliburton Energy Services ConoeOPhilli5 Anticollision Repoli Alaska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-137 Well Error: O.OOft Reference Wellbore 1J-137 L1 Reference Design: 1 J-137 L1 (wp08) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Lt_I tJ Sperry Drilling Services Well Plan 1J-137 -Slot 1J-137 Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Reference 1J-137 L1 (wp08) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 100.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,943.89ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 7/18/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 40.00 800.00 1J-137 (wp08) (1J-137) CB-GYRO-SS Camera based gyro single shot 800.00 8,842.08 1J-137 (wp08) (1J-137) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,842.08 17,478.94 1J-137 L1 (wp08) (1J-137 L1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/18/2006 5:01:19PM Page 2 of 4 COMPASS 2003.11 Build 50 • Halliburton Energy Services ConocoPh illips Anticollision Report Alaska Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Reference Site: Kuparuk 1J Pad MD Reference: Site Error:. O.OOft North Reference: Reference Well: Plan 1J-137 Survey Calculation Method: Well Error. O.OOft Output errors are at Reference Wellbore 1J-137 L1 Database: Reference Design: 1 J-137 L1 (wp08) Offset TVD Reference: Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning.. Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad. 1 J-127 - 1 J-127 - 1 J-127 392.94 400.00 201.69 8.47 193.22 Pass -Major Risk 1 J-.127 - 1 J-127 L1 - 1 J-127 L1 .392.94 400.00 201.69 8.47 193.22 Pass -Major Risk 1J-127 - 1J-127 L1 PB1 - 1J-127 L1 PB1 392.94 400.00 201.69 8.47 193.22 Pass -Major Risk 1 J-127 - 1 J-127 L2 - 1 J-127 L2 392.94 400.00 201.69 8.47 193.22. Pass -Major Risk 1J-127 - 1J-127 PB1 - 1J-127 PB1 392.94 400.00 201.69 8.47 193.22 Pass -Major Risk 1 J-127 - 1 J-127 PB2 - 1 J-127 P62 392.94 400.00 201.69 8.47 193.22. Pass -Major Risk 1J-14 - 1J-14 - 1J-14 1,312.26 1,300.00 64.69 24.94 40.68 Pass -Major Risk 1J-159 - 1J-159 L1 - 1J-159 L1 8,600.84 11,187.00 381.07 247.05 140.54 Pass -Major Risk 1 J-159 - 1 J-159 L2 - 1 J-159 L2 8,280.84 10,884.00 358.05 242.23 120.75 Pass -Major Risk 1 J-184 - 1 J-184 - 1 J-184 411.91 400.00 147.56 8.99 138.57 Pass -Major Risk 1J-184 - 1J-184 L1 - 1J-184 L1 411.91 400.00 147.56 8.99 138.57 Pass -Major Risk Plan 1J-102 - 1J-102 - 1J-102 (wp07) 9,863.60 13,676.17 956.44 321.03 648.45 Pass -Major Risk Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp07) 8,742.08 12,480.30 923.85 313.78 614.88 Pass -Major Risk Plan 1J-102 - 1J-102 L2 - 1J-102 L2 (wp07) 8,469.64 12,175.28 921.96 306.93 619.01 Pass -Major Risk Plan 1J-124 - 1J-124 - 1J-124 (wp02) 480.58 500.00 260.25 10.56 249.69 Pass -Major Risk Plan 1J-130 - 1J-130 - 1J-130 (wp02) 394.94 400.00 140.39 8.61 131.78 Pass -Major Risk Plan 1J-133 - 1J-133 - 1J-133 (wp06) 493.58 500.00 80.39 10.70 69.70 Pass -Major Risk Plan 1J-133 - 1J-133 - 1J-133 Rig Surveys 40.00 40.00 79.57 1.22 78.35 Pass -Major Risk Plan 1J-133 - 1J-133 L1 - 1J-133 L1 (wp06) 493.58 500.00 80.39 10.70 69.70 Pass -Major Risk Plan 1 J-135 - 1 J-135 -Plan 1 J-135 (wp01) 312.98 300.00 39.58 6.06 33.52 Pass -Major Risk Plan 1 J-136 - 1 J-136 - 1 J-136 (wp05) 399.22 400.00 21.23 8.67 12.56 Pass -Major Risk Plan 1 J-136 - 1 J-136 L1 - 1 J-136 L1 (wp05) 399.22 400.00 21.23 8.67 12.56 Pass -Major Risk Plan 1 J-137 - 1 J-137 - 1 J-137 (wp08) 17,478.62 17,482.28 51.40 162.24 -16.38 FAIL - No Errors Plan 1J-176 (Q2 Phase 2) - 1J-176 - 1J-176 (wp01 405.36 400.00 233.40 8.81 224.59 Pass -Major Risk Plan 1J-176 (Q2 Phase 2) - 1J-176 L1 - 1J-176 L1 405.36 400.00 233.40 8.81 224.59 Pass -Major Risk Plan 1J-178 (Q3 Phase 2) - 1J-178 L1 - 1J-178 (wp 395.51 400.00 203.75 8.62 195.12 Pass -Major Risk Plan 1J-178 (Q3 Phase 2) -Plan 1J-178 - 1J-178 395.51 400.00 203.75 8.62 195.12 Pass -Major Risk. Plan 1 J-180 -Plan 1 J-180 - 1 J-180 (wp03) 396.99 400.00 177.94 8.64 169.30 Pass -Major Risk Plan 1J-180 -Plan 1J-180 L1 - 1J-180 L1 (wp03) 396.99 400.00 177.94 8.64 169.30 Pass -Major Risk Plan 1J-182 - 1J-182 - 1J-182 (wp10) 398.42 400.00 158.93 8.66 150.27 Pass -Major Risk Plan 1J-182 - 1J-182 L1 - 1J-182 L1 (wp10) 398.42 400.00 158.93 8.66 150.27 Pass -Major Risk WSP-08 -WSP-08 -WSP-08 406.37 400.00 186.37 16.10 174.47 Pass -Major Risk WSP-09 -WSP-09 -WSP-09 394.54 400.00 125.71 9.88 115.83 Pass -Major Risk WSP-10 -WSP-10 -WSP-10 315.89 300.00 70.41 7.35 63.07 Pass -Major Risk WSP-11 -WSP-11 -WSP-11 498.28 500.00 35.41 11.60 23.82 Pass -Major Risk WSP-12 -WSP-12 -WSP-12 803.67 800.00 44.36 20.62 23.75 Pass -Major Risk WSP-13 -WSP-13 -WSP-13 1,027.56 1,000.00 47.56 20.91 26.67 Pass -Major Risk WSP-14 -WSP-14 -WSP-14 1,127.66 1,100.00 60.56 23.92 36.65 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/18/2006 5:01:19PM Page 3 of 4 COMPASS 2003. i 1 Build 50 ILL.t tJRT Sperry Driiling Services Well Plan 1J-137-Slot 1J-137 Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81 )) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum O~IGlf~:~~~ 17-137L1 ~rillinq Hazards momma (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate " Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin 1J-137L1 Drilling Hazards Summary 7/6/2006 3:30 PM `*r.y~ ~„" insulated Conduotar, 20" 84# K-6b x 34" 0,312 W T +/- 80' Wellhead ! Tubing f Tree: 13-3/8" x 4-1/2", 6,000 psi C„onocoPhillips West Sak Hybrid Producer 1J-137 2300' Mb, 1843' TVD -GLM, Camco, 4-112" x 1" KBMG Dual Lateral Completion 8000' MD, 3230' TVD -GLM, Camco, 4.1/2" x 1" KBMG 13-9f8" Casing Shoe, 88A~ L-80, BTC set Q 3883' MD, 2183' TVD Tubing String 4.112" 12.ellti L-80, IBTM 3.858" ID, 3.893" Drift Lateral Entrv Module (LEMI Assembly ~`. 7" X 9.5/8" ZXP Lmer Top Packer weh Hold Dowrre 7.500" Tk+back Ext. b 6.278" Tool Body ID ~"'~ Ca91hg 89a8wre Recaptacb 4.76" ID, 5,75' OD 20' Length CNtelltktg proftle AutomaRcA9gnmerd of LEM PosBive Lffichmg Collet mdicffiea Coned LocffiIon 8effi Bore for Lffierel Isolation-3.888" ID Access Window Po9Rlve Lffieral Acces9 Via Thru•Tubkrg Dlverter Seal Bore for Lateral Isolffilon • 3.668" ID ~~ IsdffiIon3effiAsembry 4.75" Seal OD 5.875" SeffiID 2' Length 8475' MD, 3348' TVD-Bottom of Motor Centrellzer Centretift 418 HP KMHPER wah FC8000 Pump 8-012'X9416' ~ Model ~' HOd(Henaer r-"~ WZ Rewak) 4.312" 12.Gr ru 3.899" DrD 9.058' D Latm'at Enby Mo W e p.enq Oderdkg Frolic B-Band Window at Bear MD, 3440' TVD 'D' Sand Lateral 4.112' 11.67r, BTC, LAO Bloltetl Lba PayZOneECP._ 3.112" bent]olm shoe CC' Tieback Sleeve DB Nipple ~.. Baker Otl Tools As Planned With Div erters and Isolation Cetera Access Dlvaelr Lateral IsolatMn Ixvelta RS RunNnp TodBMg Instated metaled (9.00" Lffierel Drrtf (2.SM ID Melnbo re0rA1 '6B' Protbhr Coe Corrector ' i fRUnninglRehievmp , (1.00 Lenglry ~ ~ I ~ '~ Bnap INSnap da i i ~' ' lP ^~. '~`' IB L Back PressureVaNe OS Ya OC ~8 (too' Lengtlt) i ~ ; ~. T Colet ~ ~ ,. , . ~ Lateral Isdason r'' r PlovhThrutANVN ~ ; ; : ~ ,. Bow ~ . (1,28'Len964 d i ,I i ~LatoR Diverkr i ~ Ny ral~c Olaeonned (1.80'LSrgllp a"D IsoladoN MaYYlora~i I~ ~ / DB Spear i DIYlner BNeYe ~ ill (1.80'Leng60 Lateral lso6elan.~ ~..,~ e.ad n Approx. oa." ~,: e r~ ~'~' I ' I ~' , ' r mil or deep~appkcaBonetl In PI~ :.I 19' Diverter txrgm 10' Bleeve Leng91 ~ 4-112" Oulde Shoe 4.1/2" Casing Shoe, 11.8#, L•80 BTCM Set ~ 17478' MD, 3348' 7VD 7' X 9418" DfP Beal As Liner TOp Packer 4.73`Beds IOD o.a7s"D 'B' Sand feral 4.1f2" 11.88, BTC, 7' X 9416' Flex Lode LAO Sbded Lhwr LlnerHangerf PacKer Assaraxyffi Liner Hager +1.6940' MD Casing Bealbore Raceptack 4.78" ID ~~ 9.618" Casing Shoe, 40,0#, L•80 BTC ~ 8282' MD, 3602' TVD (86 deg inoj e Baker Hugh- 2006. This daeumeM mrynd ho reproduced a dMdbutad, In whole ar In part, In any form or by emymwns ekdronb amadlankal, Yxkakp phalocopylnp, recording, or by any Inrormellon atoraga azM rerdwN system rww known aher-RaklVeMad, wahoul wdaan parmlealon Iran Baker Hughaa Ino. 4.112" Ecoaritrk: Eauioment Sneciflcatlons 6"1/2" X 9-S/8" HOOK Hanger« Malnbore Drift: 7.00" Mffinbore Drat, with divener: 8.25" Lateral DrM, no dlverter or LEM: 4.88" Lateral Drill, w/ divertar, no LEM: 4.50" LffieraUMffinbore Dlvener OD: 8.50" 4-1/2" Lateral Entry Module Mffinbore Odft: 3.88" Mainbore DrtR, w/ IsoWtlon sleeve: 2.50" Lateral Orin, w/toll diverter: 9.00" OD of DNeR9r and Sleeve: +!• 3.80" Diverter and Sleeve Lanp$1: +f-19' 4.1/2" Casing Shoe, 11.6#, L•60 BTCM Set ~ 174$2' M D, 3400' TVD • • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~-~~~~ ` ~ ~~...~ ~~- PTD# ~ ~~~ _. ~~%~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter .CHECK ADD-Olv'S TEXT FOR APPROVAL LETTER I WHAT (OPTIONS) ~ APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well ~~(~~ ~ .~~ ~ ~ (If fast two digits in permit No. ~~.~~lE; _ G'~ Z~-GrlU ~ API No. 50-~~` - API number are between 60-69) ~ Production should continue to be reported as a function of the original API number stated above. i PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in ~ SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and IO' sample intervals through target zones. ~ Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of welly until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. Company NameZmust contact the Commission to obtain advance approval of such water well testing rogram. Rev: U25106 C:\jodyltransmittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WESTSAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1J-137L1 Program DEV Well bore seg ^v PTD#:2061090 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11160 OnlOff Share On Annular Disposal ^ Administration 1 Pe[mitfee attached- - _ _ - - No- - - - - - - -West Sak D Sand multilateral well branch; fee waived per 20 AAC 25.095(e), - - - - . - ---------------- 2 Lease number appropriate------- -------------------- ------- Yes_____- Top_prod_interyalin_ADL-025662; TD inAD_L380058.____________-__--_--__-__ 3 Unique well-name and number_________________________ ______..-.._Yes,.--_- ---------_---.,___--_- 4 Well located in a_definedpool-___________----.---.---_ .-__-______ Yes______ KuparukRiver,West_SakOilPool-490150,_goyemedbyCO40.66________________________- 5 Well located proper distance from drilling unit_boundary . ......... . . . . . . . Yes Well is more than- 500 feet from an external property line. - 6 Well located proper distance_from other wells- - _ - - - _ Yes . - _ . _ _ CO 406B, Rule 3:- no restrictions as-to well spacing except that no-pay shall be opened ina well closer - - _ 7 Sufficient acreage available in_drilling unit- - Y_es than 50.0 feet to-an extetnal_prope[ty line where ownership- or landownership changes. 8 If_deyiated,is_wellboreplat_included_____---________ ____ _____________Yes_----- --------------_--__.-_-_____--_----_-----__--_-__ ------------------- 9 Operator only affected party- - - - - - - - - - - - - - Yes - - - - - - 10 Operatorhas-appropriate-bondln force-------------------- ---------- -- Yes ----- -- -- ------- -- ------------- -- -- -- --- --- -- ------- ~ - 11 Permit can be issued without conservation order -- -- Yes Appr Date 12 Permit_can be issued without administrativ_e_approyal - - - - _ , _ _ Yes - SFD 7!25!2006 13 Can permit be approved before 15~ay wok Yes 14 Well located within area and strata authorized by Injection Orde[ # (put1O# in_comments)-(For- NA- - - - - - - - - - - - -- - - - - _ - - . _ - - - - _ _ - _ _ _ _ .. _ - - - . - - . - - . - - - - - _ _ - _ _ _ - _ _ _ - - _ _ - 15 All wells-within 114.mile area of review identified (For sen!ice well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ - _ - - _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ - ------------------------------------------------ 16 Pre-produced injector;dur_ationofprep[oductionlessthan3months_(for _servicewellonly)_-NA-------- -_--------------------------------------------------- -------------- 17 Nonconven, gas conforms to A$31,05,030((.1_.A),(j.2_.A-D) - - - - - - - - - - - - - - - - - - - - - NA- - - Engineering 18 Condu_ctorst[ing-provided---------------------------- ----------_ NA _ _ Con_ductorset_inmother_bore,_1J-137(206-108)._______________________..______---_._- 19 Surface casing-prQteetsall-kn4wgUSDWs________----____ .............NA__-__ Allaqutfersexempted,40CFR_147.102(b)~3)._______________-__-_________-_--___--__ 20 CMT_vol-adequate_tocirculate-onconductor&surf_csg______ ____-.------NA-----_- Surface casing set in-1J-137._-__._______-____________________________________ 21 CMT_v_oladeguate-to tie-in long string tosu_rfcsg--------------- ---------_-_ NA-______ Production_casingsetin_1J-137._____________________--__--_--__--_ 22 CMT_will coverall known_productiye horizons- - _ _ _ _ _ _ _ _ _ _ _ _ - . _ - . - - No. - .. - .. - Slotted liner completion planned-- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 23 Casing desgns adequate for C, T, B &-permafrost- - . _ . - .. - - - _ NA_ - 1J-1.37 met design specifications..NA forslotted line[.- - - . - _ . - - . - - - - . - - - _ - - 24 Adequate tankage-or reserve pit - - _ - _ - - - -Yes _ . - - .. - Rig is-equipped with steel_pits. -No reserve-pitplanned: All waste to approved annulus or disposal wells. - - . - 25 Ifa-re-drill,has-a-10-403 forabandon_mentbeenapp_roved-.-----_ _____________ NA________ ____________-___---- ------------------------------------------------ 26 Adequate wellbore separation-proposed- - - - - - - - - - - - - - - - - - - - - - - - - --- - - - - -Yes . - _ - _ . _ Proximity analysis perf_o[med, Traveling cylinder path calculated, Nearest segnent, B lateral ~15t)' tvd deep.. _ . 27 Ifdiverterrequired,doesitmeetregulations__________________ _____________ NA_-_-__-- BOPstackwillalready-be in place,--__--__-__-_-------_---___--_- Appr Date 28 Drilling fluid_program schematic_$ equip listadequate- - Yes Maximum expected fgrmatien pressure 8,6-EMW._ Planned MW pp 9.0 ppg___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ TEM 7127/2006 29 BOPEs,-doiheymeetregulation------------------------ -------------Yes-----__ -_______ ~Q(~y,/~ ~ 30 BOPE_press rating appropriate; test to-(put prig incomments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ Yes - - - - _ - - MASP calculated at 1176psi, 3K stack_arrangementand BOP test planned.- - - - - - - - - - - - - - - _ _ _ _ _ _ _ _ ~i 31 Choke-manifold complies wIAPI_RP-53 (May 84)- - - _ - - _ _ - _ - Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work will occur without operation shutdown_---_-._--_--.__- --_____-___Yes_______ ___--________________________________________________________ _____ 33 IspresenceofH2$gas_probable------------------------ ------------- No_____ H2Shasnotbeenreportedat1J_pad._________-_ -____-_-_-___________-______ __ 34 Mechanical condition of wells within AOR yer~ed (FOr_service well onlya _ - - - NA- - - - - - - - - - - - - - - - - Geology 35 Permit.ean be issued wlo hydrogen_sulfide measures - - - - - - - - - - - - - - - - - - - - - - - -Yes _ - - _ H2S has not been encountered in W Sak wells drilled to the_south from 1J-Pad. 36 Data_presented on potential overpressure zones- - _ - - . _ Yes - Expected r_es._pressure is ~8.6ppg EMW; will be drilled with 9.0 ppgoil-based mu_d. - Appr Date 37 Seismic analysis ofshallow gas_zones- - - - - - - - - - .. - NA- _ _ - -- - SFD 7!2512006 38 Seabed condition suryey_(if off--shore) - - - - - - - - - - - - - - - - - NA 39 C9ntact namelphone for weekly,progress reports [exploratory only] _ _ NA- - - - - - - - - - - - - - -- - - - - - - - - - - - Geologic Engineering Date: Date West Sak D sand producer. This is a well branch from dual-lateral production well KRU 1J-137. SFD Date Commissioner: Commissioner: mmi er ~ j s ~ IZT ~ ~z~- ~ f Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and io simplify finding infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this calegory of information. Sperry-Sun Dri'Tling Services LIS Scan Utility $Revision: 3 LisLib $Revision: 4 $ Thu Oct 19 08:48:04 2006 Reel Header Service name .............LISTPE Date .....................06/10/19 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date..........'...........06/10/19 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF C7 Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-137 L1 API NUMBER: 500292331660 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 19-OCT-06 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: MW0004559178 MW0004559178 MW0004559178 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 7 MWD RUN 8 MWD RUN 10 JOB NUMBER: MW0004559178 MW0004559178 MW0004559178 LOGGING ENGINEER: T. CALVIN T. CALVIN T. CALVIN OPERATOR WITNESS: G. WHITLOCK G. WHITLOCK G. WHITLOCK MWD RUN 12 MWD RUN 13 JOB NUMBER: MW0004559178 MW0004559178 LOGGING ENGINEER: T. CALVIN T. CALVIN OPERATOR WITNESS: G. WHITLOCK G. WHITLOCK SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: ~~ _~6~ FSL: ~ 1545 FEL: 2278 ~~ ' (~~j~ FWL: 1/,r," 1 ELEVATION (FT FROM MS'L 0) ~~~V KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: • OPEN HOLE BIT SIZE (IN) 12.250 6.750 109.00 81.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 13.375 3773.0 9.625 8921.0 • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-137 L1 PB2 WELLBORE AT 13840'MD/3394'TVD. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3-5,8,10,12,13 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 3,4,8,10,12 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUN 13 ALSO INCLUDED AT-BIT INCLINATION (ABI) ONLY SROP DATA WERE ACQUIRED ON MWD RUNS 3 & 7. 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 1-5,7,8,10,12,13 REPRESENT WELL 1J-137L1 WITH API#:50-029-23316-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16840'MD/3361'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type .............. 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 RPM 3761.5 RPS 3761.5 RPX 3761.5 RPD 3761.5 FET 3761.5 GR 3770.5 ROP 3780.5 all bit runs merged. STOP DEPTH 16781.5 16781.5 16781.5 16781.5 16781.5 16774.5 16840.0 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE FBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 3780.5 3805.0 MWD 4 3761.5 4717.0 MWD 5 4673.5 8921.0 MWD 7 8921.0 8951.0 MWD 8 8921.5 11115.0 MWD 10 11115.5 13840.0 MWD 12 13840.5 14110.0 MWD 13 14052.5 16840.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .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 Name Service Unit Min Max Mean Nsam Reading Last Reading DEPT FT 3761. 16840 10300.8 26158 761.5 16840 RPD MWD OHMM 3.07 2000 26.7416 26041 3761.5 16781.5 RPM MWD OHMM 1.3 1592.16 27.4109 26041 3761.5 16781.5 RPS MWD OHMM 2.5 2000 27.4122 26041 3761.5 16781.5 RPX MWD OHMM 2.84 2000 24.8116 26041 3761.5 16781.5 FET MWD HOUR 0.11 303.44 1.28404 26041 3761.5 16781.5 GR MWD API 17.73 131.84 72.4434 26009 .3770.5 16774.5 ROP MWD FT/H 0.08 1869.42 239.065 26120 3780.5 16840 First Reading For Entire File..........3761.5 Last Reading For Entire File...........16840 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH ROP 3780.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 3805.0 23-AUG-06 Insite 66.37 Memory 3805.0 3780.0 3805.0 72.9 72.9 TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (I DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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 12.250 3773.0 Native/Spud Mud 9.10 38.0 .0 250 13.4 2.900 71.0 3.020 68.0 3.700 71.0 1.910 71.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3780.5 3805 3792.75 50 3780.5 3805 ROP MWD030 FT/H 0.38 1372.51 210.653 50 3780.5 3805 First Reading For Entire File..........3780.5 Last Reading For Entire File...........3805 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical E0F File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPS 3761.5 RPD 3761.5 FET 3761.5 RPX 3761.5 RPM 3761.5 GR 3770.5 ROP 3805.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 24-AUG-06 Insite 66.37 Memory 4717.0 3805.0 4717.0 68.0 73.8 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 67981 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: STOP DEPTH 4673.0 4673.0 4673.0 4673.0 4673.0 4681.0 4717.0 12.250 3773.0 Native/Spud Mud 9.10 300.0 8.9 250 5.6 2.900 71.0 2.880 71.6 3.700 71.0 1.910 71.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN):~ TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3761.5 4717 4239.25 1912 3761.5 4717 RPD MWD040 OHMM 4.4 2000 21.3583 1824 3761.5 4673 RPM MWD040 OHMM 1.3 15 92.16 15.1554 1824 3761.5 4673 RPS MWD040 OHMM 2.5 32.71 12.9966 1824 3761.5 4673 RPX MWD040 OHMM 2.84 48.19 11.6786 1824 3761.5 4673 FET MWD040 HOUR 0.11 74.97 2.82534 1824 3761.5 4673 GR MWD040 API 17.73 1 22.74 81.3588 1822 3770.5 4681 ROP MWD040 FT/H 1.4 18 69.42 343.724 1824 3805.5 4717 First Reading For Entire File..........3761.5 Last Reading For Entire File...........4717 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name......~SLIB.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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4673.5 8921.0 RPX 4673.5 8921.0 RPD 4673.5 8921.0 RPS 4673.5 8921.0 RPM 4673.5 8921.0 GR 4681.5 8921.0 ROP .4717.5 8920.5 LOG HEADER DATA DATE LOGGED: 29-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8921.0 TOP LOG INTERVAL (FT) 4717.0 BOTTOM LOG INTERVAL (FT) 8921.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.9 MAXIMUM ANGLE: 85.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 78633 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 3773.0 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): Fresh Water Gel 9.10 71.0 9.0 250 4.2 2.900 70.0 2.230 93.2 3.700 70.0 1.910 70.0 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 MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4673.5 8921 6797.25 8496 4673.5 8921 RPD MWDO50 OHMM 5.87 94.31 14.354 8496 4673.5 8921 RPM MWD050 OHMM 5.55 83.04 13.5638 8496 4673.5 8921 RPS MWD050 OHMM 5.06 79.15 12.8612 8496 4673.5 8921 RPX MWD050 OHMM 4.67 56.61 11.1648 8496 4673.5 8921 FET MWD050 HOUR 0.19 20.2 1.24756 8496 4673.5 8921 GR MWD050 API 29.46 1 31.84 75.993 8480 4681.5 8921 ROP MWD050 FT/H 2.23 10 07.71 206.542 8407 4717.5 8920.5 First Reading For Entire File..........4673.5 Last Reading For Entire File...........8921 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 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.......06/10/19 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 ROP 8921.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 8951.0 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 09-SEP-06 Insite 68.18 Memory 8951.0 8921.0 8951.0 .0 .0 TOOL NUMBER 163686 8.500 3773.0 Mineral Oil Base 8.80 99.0 .0 23000 3.4 .000 .0 .000 75.0 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT ROP MWD070 FT FT/H 4 1 68 0 1 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8921 8951 8936 61 8921 8951 ROP MWD070 FT/H 0.26 25.23 12.6367 61 8921 8951 First Reading For Entire File..........8921 Last Reading For Entire File...........8951 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 8921.5 11115.0 RPS 8921.5 11115.0 RPD 8921.5 11115.0 FET 8921.5 11115.0 RPX 8921.5 11115.0 GR 8921.5 11115.0 ROP 8951.5 11115.0 LOG HEADER DATA DATE LOGGED: 11-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11115.0 TOP LOG INTERVAL (FT) 8951.0 BOTTOM LOG INTERVAL (FT) 11115.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 79.8 MAXIMUM ANGLE: • TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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 95.7 TOOL NUMBER 156436 162742 6.750 8921.0 Mineral Oil Base 8.80 110.0 .0 23000 3.4 .000 .0 .000 108.0 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8921.5 11115 10018.3 4388 8921.5 11115 RPD MWD080 OHMM 3.07 131.65 38.3132 4388 8921.5 11115 RPM MWD080 OHMM 14.6 105.74 41.3586 4388 8921.5 11115 RPS MWD080 OHMM 15.72 1094.04 42.1255 4388 8921.5 11115 RPX MWD080 OHMM 14.69 120.19 38.4173 4388 8921.5 11115 FET MWD080 HOUR 0.11 303.44 0.980684 4388 8921.5 11115 GR MWD080 API 41.7 95.68 68.9432 4388 8921.5 11115 ROP MWD080 FT/H 3.5 1032.73 264.668 4328 8951.5 11115 First Reading For Entire File..........8921.5 Last Reading For Entire File...........11115 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ....:...........LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: ,5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11115.5 13840.0 FET 11115.5 13840.0 RPX 11115.5 13840.0 RPS 11115.5 13840.0 ROP 11115.5 13840.0 RPM 11115.5 13840.0 RPD 11115.5 13840.0 LOG HEADER DATA DATE LOGGED: 13-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13840.0 TOP LOG INTERVAL (FT) 11115.0 BOTTOM LOG INTERVAL (FT) 13840.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.3 MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 # • BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 8921.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S): 82.0 MUD PH: 2.0 MUD CHLORIDES (PPM): 19000 FLUID LOSS (C3) 3.6 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 MWD100 OHMM 4 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11115.5 13840 12477.8 5450 11115.5 13840 RPD MWD100 OHMM 14.89 60.17 32.5259 5450 11115.5 13840 RPM MWD100 OHMM 14.6 73.95 34.6825 5450 11115.5 13840 RPS MWD100 OHMM 14.4 74.58 34.5637 5450 11115.5 13840 RPX MWD100 OHMM 13.11 65.7 32.1737 5450 11115.5 13840 FET MWD100 HOUR 0.14 56.13 0.503026 5450 11115.5 13840 GR MWD100 API 44.15 102.99 68.5653 5450 11115.5 13840 ROP MWD100 FT/H 0.19 487.42 253.055 5450 11115.5 13840 First Reading For Entire File..........11115.5 Last Reading For Entire File...........13840 • • File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF File Header Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13840.5 14052.0 ROP 13840.5 14110.0 RPM 13840.5 14059.5 RPS 13840.5 14059.5 RPX 13840.5 14059.5 RPD 13840.5 14059.5 FET 13840.5 14059.5 LOG HEADER DATA DATE LOGGED: 16-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14110.0 TOP LOG INTERVAL (FT) 13840.0 BOTTOM LOG INTERVAL (FT) 14110.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.8 MAXIMUM ANGLE: 92.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 8921.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) ~ 8.80 MUD VISCOSITY (S) 78.0 MUD PH: .0 MUD CHLORIDES (PPM): 20500 FLUID LOSS (C3): 3.8 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 MWD120 OHMM 4 1 68 4 2 RPM MWD120 OHMM 4 1 68 8 3 RPS MWD120 OHMM 4 1 68 12 4 RPX MWD120 OHMM 4 1 68 16 5 FET MWD120 HOUR 4 1 68 20 6 GR MWD120 API 4 1 68 24 7 ROP MWD120 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13840.5 14110 13975.3 540 13840.5 14110 RPD MWD120 OHMM 23.82 34.8 28.01 439 13840.5 14059.5 RPM MWD120 OHMM 22.93 35.95 26.5403 439 13840.5 14059.5 RPS MWD120 OHMM 21.22 38.16 27.4166 439 13840.5 14059.5 RPX MWD120 OHMM 18.9 39.46 28.5779 439 13840.5 14059.5 FET MWD120 HOUR 0.33 50.04 2.33681 439 13840.5 14059.5 GR MWD120 API 51.87 87.4 68.8554 424 13840.5 14052 ROP MWD120 FT/H 0.08 342.93 126.753 540 13840.5 14110 First Reading For Entire File..........13840.5 Last Reading For Entire File...........14110 File Trailer Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ............... • Next File Name...........STSLIB.009 Physical EOF File Header Service name .............STSLIB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14052.5 16774.5 RPS 14060.0 16781.5 RPX 14060.0 16781.5 RPD 14060.0 16781.5 RPM 14060.0 16781.5 FET 14060.0 16781.5 ROP 14110.5 16840.0 LOG HEADER DATA DATE LOGGED: 20-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 16840.0 TOP LOG INTERVAL (FT) 14110.0 BOTTOM LOG INTERVAL (FT) 16840.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.3 MAXIMUM ANGLE: 94.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156430 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 8921.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 90.0 MUD PH: .0 MUD CHLORIDES (PPM): 22500 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULA~G TERMPERATURE: .000 1~0 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 MWD130 OHMM 4 1 68 4 2 RPM MWD130 OHMM 4 1 68 8 3 RPS MWD130 OHMM 4 1 68 12 4 RPX MWD130 OHMM 4 1 68 16 5 FET MWD130 HOUR 4 1 68 20 6 GR MWD130 API 4 1 68 24 7 ROP MWD130 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14052.5 16840 15446.3 5576 14052.5 16840 RPD MWD130 OHMM 9.83 78.69 32.6576 5444 14060 16781.5 RPM MWD130 OHMM 9.29 234.69 34.6756 5444 14060 16781.5 RPS MWD130 OHMM 8.87 2000 35.9316 5444 14060 16781.5 RPX MWD130 OHMM 8.1 2000 31.8686 5444 14060 .16781.5 FET MWD130 HOUR 0.12 42.69 1.76608 5444 14060 16781.5 GR MWD130 API 44.49 102.15 70.9138 5445 14052.5 16774.5 ROP MWD130 FT/H 0.62 684.57 233.817 5460 14110.5 16840 First Reading For Entire File..........14052.5 Last Reading For Entire File...........16840 File Trailer Service name .............STSLIB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.010 Physical EOF Tape Trailer Service name ....... ......LISTPE Date ............... ......06/10/19 Origin ............. ......STS Tape Name .......... ......UNKNOWN Continuation Number ......01 Next Tape Name..... ......UNKNOWN Comments ........... ......STS LIS Reel Trailer Service name .............LISTPE Date .....................06/10/19 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF • Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services End Of LIS File Sperry-Sun Dri17ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Oct 19 09:46:27 2006 Reel Header Service name .............LISTPE Date .....................06/10/19 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/10/19 Origin ...................STS Tape Name........... ....UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF • Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-137 L1 PB1 API NUMBER: 500292331670 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 19-OCT-06 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: MW0004559178 MW0004559178 MW0004559178 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 7 MWD RUN 8 MWD RUN 9 JOB NUMBER: MW0004559178 MW0004559178 MW0004559178 LOGGING ENGINEER: T. GALVIN T. GALVIN T. GALVIN OPERATOR WITNESS: G. WHITLOCK G. WITLOCK G. WITLOCK SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1545 FEL: 2278 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS a ~~, -t o9 1 L12ab BIT SI~(IN) 1ST STRING 12.250 2ND STRING 6.750 3RD STRING PRODUCTION STRING REMARKS: SIZE (IN) DEPTH (FT) 13.375 3773.0 9.625 8921.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 8921' MD/3456'TVD, WITHIN THE RUN 5 INTERVAL OF THE 1J-137 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 7. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3-5.,8,9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 3,4,8,9 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) ONLY SROP DATA WERE ACQUIRED ON MWD RUN 3. 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 1-5,7-9 REPRESENT WELL 1J-137 L1 PB1 WITH API#: 50-029-23316-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13930'MD/3372'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPM 3761.5 13879.5 FET 3761.5 13879.5 RPD 3761.5 13879.5 RPX 3761.5 13879.5 RPS 3761.5 13879.5 GR 3770.5 13872.5 ROP 3780.5 13930.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 3 3780.5 4 3805.0 5 4717.0 7 8921.0 8 8951.0 9 13366.0 REMARKS: MERGED MAIN PASS. MERGE BASE 3805.0 4717.0 8921.0 8951.0 13366.0 13930.0 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 3761.5 13930 8845.75 20338 3761.5 13930 RPD MWD OHMM 3.07 2000 26.4676 20237 3761.5 13879.5 RPM MWD OHMM 1.3 1592.16 27.1466 20237 3761.5 13879.5 RPS MWD OHMM 2.5 1094.04 26.6235 20237 3761.5 13879.5 RPX MWD OHMM 2.84 120.19 24.006 20237 3761.5 13879.5 FET MWD HOUR GR MWD API ROP MWD FT/H 0.11 303.44 17.73 131.84 0.26 1869.42 First Reading For Entire File..........3761.5 Last Reading For Entire File...........13930 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type.... ..........LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER 1.22776 20237 72.8969 20205 244.141 20300 761.5 13879.5 3770.5 13872.5 3780.5 13930 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 ROP 3780.5 3805.0 LOG HEADER DATA DATE LOGGED: 23-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 3805.0 TOP LOG INTERVAL (FT) 3780.0 BOTTOM LOG INTERVAL (FT): 3805.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 72.9 MAXIMUM ANGLE: 72.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 3773.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) ~ 9.10 MUD VISCOSITY (S) 38.0 MUD PH: .0 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3) 13.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.900 71.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.020 68.0 MUD FILTRATE AT MT: 3.700 71.0 MUD CAKE AT MT: 1.910 71.0 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 MWD030 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3780.5 3805 3792.75 50 3780.5 3805 ROP MWD030 FT/H 0.38 1372.51 210.653 50 3780.5 3805 First Reading For Entire File..........3780.5 Last Reading For Entire File...........3805 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record.~35 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 3761.5 4673.0 RPX 3761.5 4673.0 RPD 3761.5 4673.0 RPS 3761.5 4673.0 FET 3761.5 4673.0 GR 3770.5 4681.0 ROP 3805.5 4717.0 LOG HEADER DATA DATE LOGGED: 24-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4717.0 TOP LOG INTERVAL (FT) 3805.0 BOTTOM LOG INTERVAL (FT) 4717.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 68.0 MAXIMUM ANGLE: 73.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 67981 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 3773.0 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): Native/Spud Mud 9.10 300.0 8.9 250 5.6 2.900 71.0 2.880 71.6 3.700 71.0 1.910 71.0 REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3761.5 4717 4239.25 1912 3761.5 4717 RPD MWD040 OHMM 4.4 2000 21.3583 1824 3761.5 4673 RPM MWD040 OHMM 1.3 1592.16 15.1554 1824 3761.5 4673 RPS MWD040 OHMM 2.5 32.71 12.9966 1824 3761.5 4673 RPX MWD040 OHMM 2.84 48.19 11.6786 1824 3761.5 4673 FET MWD040 HOUR 0.11 74.97 2.82534 1824 3761.5 4673 GR MWD040 API 17.73 122.74 81.3588 1822 3770.5 4681 ROP MWD040 FT/H 1.4 1869.42 343.724 1824 3805.5 4717 First Reading For Entire File..........3761.5 Last Reading For Entire File...........4717 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4673.5 8921.0 RPD 4673.5 8921.0 RPM 4673.5 8921.0 RPX 4673.5 8921.0 RPS 4673.5 8921.0 GR 4681.5 8921.0 ROP 4717.5 8920.5 LOG HEADER DATA DATE LOGGED: 29-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8921.0 TOP LOG INTERVAL (FT) 4717.0 BOTTOM LOG INTERVAL (FT) 8921.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.9 MAXIMUM ANGLE: 85.0 -TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 78633 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 3773.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S): 71.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3) 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.900 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.230 93.2 MUD FILTRATE AT MT: 3.700 70.0 MUD CAKE AT MT: 1.910 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta 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 MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4673.5 8921 6797.25 8496 4673.5 8921 RPD MWD050 OHMM 5.87 94.31 14.354 8496 4673.5 8921 RPM MWD050 OHMM 5.55 83.04 13.5638 8496 4673.5 8921 RPS MWD050 OHMM 5.06 79.15 12.8612 8496 4673.5 8921 RPX MWD050 OHMM 4.67 56.61 11.1648 8496 4673.5 8921 FET MWD050 HOUR 0.19 20.2 1.24756 8496 4673.5 8921 GR MWD050 API 29.46 1 31.84 75.993 8480 4681.5 8921 ROP MWD050 FT/H 2.23 10 07.71 206.542 8407 4717.5 8920.5 First Reading For Entire File..........4673.5 Last Reading For Entire File...........8921 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 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.......06/10/19 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 ROP 8921 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8951.0 09-SEP-06 Insite 66.37 Memory 8951.0 8921.0 8951.0 .0 .0 TOOL NUMBER 163686 8.500 8921.0 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 Mineral Oil Base 8.80 99.0 .0 23000 3.4 000 .0 000 75.0 000 .0 000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 Name Service Unit. Min Max DEPT FT 8921 8951 ROP MWD070 FT/H 0.26 25.23 First Reading For Entire File..........8921 Last Reading For Entire File...........8951 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY Mean Nsam 8936 61 12.6367 61 FS'r s t Reading 8921 8921 for each bit run in separate files. VENDOR TOOL CODE START DEPTH GR 8921.5 FET 8921.5 RPX 8921.5 RPS 8921.5 RPD 8921.5 RPM 8921.5 ROP 8951.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 13308.5 13315.5 13315.5 13315.5 13315.5 13315.5 13366.0 11-SEP-06 Insite 68.18 Memory 13366.0 8951.0 13366.0 79.8 95.7 TOOL NUMBER 156436 Last Reading 8951 8951 ~ EWR4 Ele omag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 8921.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 110.0 MUD PH: .0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3) 3.4 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 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWDOSO OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8921.5 13366 11143.8 8890 8921.5 13366 RPD MWD080 OHMM 3.07 131.65 37.6104 8789 8921.5 13315.5 RPM MWD080 OHMM 14.36 105.74 40.3505 8789 8921.5 13315.5 RPS MWD080 OHMM 13.89 1094.04 40.2697 8789 8921.5 13315.5 RPX MWD080 OHMM 13.19 120.19 36.5152 8789 8921.5 13315.5 FET MWD080 HOUR 0.11 303.44 0.734361 8789 8921.5 13315.5 GR MWD080 API 41.71 99.2 69.1945 8775 8921.5 13308.5 ROP MWD080 FT/H 1.51 1032.73 259.501 8830 8951.5 13366 First Reading For Entire File..........8921.5 Last Reading For Entire Fil~ ........13366 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY • for each bit run in separate files. VENDOR TOOL CODE START DEPTH GR 13309.0 RPX 13316.0 RPD 13316.0 FET 13316.0 RPM 13316.0 RPS 13316.0 ROP 13366.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13872.5 13879.5 13879.5 13879.5 13879.5 13879.5 13930.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12-SEP-06 Insite 68.18 Memory 13930.0 13366.0 13930.0 13376.1 92.2 TOOL NUMBER 156436 162742 6.750 8921.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S): 82.0 MUD PH: .0 MUD CHLORIDES (PPM): 21500 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 97.0 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 MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13309 13930 13619.5 1243 13309 13930 RPD MWD090 OHMM 32.48 51.71 39.1468 1128 13316 13879.5 RPM MWD090 OHMM 37.57 60.6 45.9615 1128 13316 13879.5 RPS MWD090 OHMM 37.17 65.35 45.9877 1128 13316 13879.5 RPX MWD090 OHMM 37.2 60.98 43.1917 1128 13316 13879.5 FET MWD090 HOUR 0.17 21.14 2.33972 1128 13316 13879.5 GR MWD090 API 42.41 83.82 64.7552 1128 13309 13872.5 ROP MWD090 FT/H 2.92 523.7 257.104 1128 13366.5 13930 First Reading For Entire File..........13309 Last Reading For Entire File...........13930 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation....../10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/10/19 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/10/19 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 E S err -Sun Dr~in Services p Y g LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Oct 19 14:35:54 2006 Reel Header Service name .............LISTPE Date .....................06/10/19 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/10/19 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-137 L1 PB2 API NUMBER: 500292331671 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 19-OCT-06 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: MW0004559178 MW0004559178 MW0004559178 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 7 MWD RUN 8 MWD RUN 10 JOB NUMBER: MW0004559178 MW0004559178 MW0004559178 LOGGING ENGINEER: T. CALVIN T. CALVIN T. CALVIN OPERATOR WITNESS: G. WHITLOCK G. WITLOCK G. WITLOCK MWD RUN 11 JOB NUMBER: MW0004559178 LOGGING ENGINEER: T. CALVIN OPERATOR WITNESS: G. WITLOCK SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL : I' p ~/d~~ /O l FEL: 2278 FWL : ,,gyp-~h,,,,,, ELEVATION (FT FROM MSL 0) '-YN~I~~ .~ L~ aab KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 12.250 2ND STRING 6.750 3RD STRING PRODUCTION STRING REMARKS: 109.00 81.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 13.375 3773.0 9.625 8921.0 • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-137 L1 PBl WELLBORE AT 11115'MD/3412'TVD. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3-5,8,10,11 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3,4,8,10,11 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) ONLY SROP DATA WERE ACQUIRED ON MWD RUNS 3 & 7. 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 1-5,7,8,10,11 REPRESENT WELL 1J-137 L1 PB2 WITH API#: 50-029-23316 -71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15552'MD/3382'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 ~ ! Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 3761.5 15501.5 RPM 3761.5 15501.5 RPX 3761.5 15501.5 RPD 3761.5 15501.5 RPS 3761.5 15501.5 GR 3770.5 15494.0 ROP 3780.5 15552.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 3780.5 3805.0 MWD 4 3805.0 4717.0 MWD 5 4717.0 8921.0 MWD 7 8921.0 8951.0 MWD 8 8951.0 11115.0 MWD 10 11115.5 14534.0 MWD 11 14534.0 15552.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical Iog 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 3761.5 15552 9656.75 23582 3761.5 15552 RPD MWD OHMM 3.07 2000 26.332 23481 3761.5 15501.5 RPM MWD OHMM 1.3 15 92.16 26.8966 23481 3761.5 15501.5 RPS MWD OHMM RPX MWD OHMM FET MWD HOUR GR MWD API ROP MWD FT/H ~ 2.5 1094.04 2.84 216.28 0.11 303.44 17.73 131.84 0.19 1869.42 First Reading For Entire File..........3761.5 Last Reading For Entire File...........15552 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER 26.6271 23480 761.5 15501.5 24.7524 23481 3761.5 15501.5 1.15822 23481 3761.5 15501.5 72.0779 23448 3770.5 15494 247.912 23544 3780.5 15552 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 ROP 3780.5 3805.0 LOG HEADER DATA DATE LOGGED: 23-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 3805.0 TOP LOG INTERVAL (FT) 3780.0 BOTTOM LOG INTERVAL (FT) 3805.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM .ANGLE: 72.9 MAXIMUM ANGLE: 72.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 3773.0 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 Native/Spud Mud 9.10 38.0 .0 250 13.4 2.900 71.0 3.020 68.0 3.700 71.0 1.910 71.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3780.5 3805 3792.75 50 3780.5 3805 ROP MWD030 FT/H 0.38 1372.51 210.653 50 3780.5 3805 First Reading For Entire File..........3780.5 Last Reading For Entire File...........3805 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 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..........~.0 Date of Generation.......06/10/19 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD, 3761.5 4673.0 RPM 3761.5 4673.0 RPX 3761.5 4673.0 RPS 3761.5 4673.0 FET 3761.5 4673.0 GR 3770.5 4681.0 ROP 3805.5 4717.0 LOG HEADER DATA DATE LOGGED: 24-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4717.0 TOP LOG INTERVAL (FT) 3805.0 BOTTOM LOG INTERVAL (FT) 4717.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 68.0 MAXIMUM ANGLE: 73.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 67981 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 3773.0 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): Native/Spud Mud 9.10 300.0 8.9 250 5.6 2.900 71.0 2.880 71.6 3.700 71.0 1.910 71.0 EWR FREQUENCY (HZ) REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data .Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3761.5 4717 4239.25 1912 3761.5 4717 RPD MWD040 OHMM 4.4 2000 21.3583 1824 3761.5 4673 RPM MWD040 OHMM 1.3 15 92.16 15.1554 1824 3761.5 4673 RPS MWD040 OHMM 2.5 32.71 12.9966 1824 3761.5 4673 RPX MWD040 OHMM 2.84 48.19 11.6786 1824 3761.5 4673 FET MWD040 HOUR 0.11 74.97 2.82534 1824 3761.5 4673 GR MWD040 API 17.73 1 22.74 81.3588 1822 3770.5 4681 ROP MWD040 FT/H 1.4 18 69.42 343.724 1824 3805.5 4717 First Reading For Entire File..........3761.5 Last Reading For Entire File...........4717 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name.... Version Number...........1.0.0 Date of Generation.......06/10/19 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4673.5 8921.0 RPM 4673.5 8921.0 RPX 4673.5 8921.0 RPD 4673.5 8921.0 RPS 4673.5 8921.0 GR 4681.5 8921.0 ROP 4717.5 8920.5 LOG HEADER DATA DATE LOGGED: 29-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8921.0 TOP LOG INTERVAL (FT) 4717.0 BOTTOM LOG INTERVAL (FT) 8921.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.9 MAXIMUM ANGLE: 85.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 78633 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 3773.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 71.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3) 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.900 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.230 93.2 MUD FILTRATE AT MT: 3.700 70.0 MUD CAKE AT MT: 1.910 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block ~ipe .....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 N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4673.5 8921 6797.25 8496 4673.5 8921 RPD MWD050 OHMM 5.87 94.31 14.354 8496 4673.5 8921 RPM MWD050 OHMM 5.55 83.04 13.5638 8496 4673.5 8921 RPS MWD050 OHMM 5.06 79.15 12.8612 8496 4673.5 8921 RPX MWD050 OHMM 4.67 56.61 11.1648 8496 4673.5 8921 FET MWD050 HOUR 0.19 20.2 1.24756 8496 4673.5 8921 GR MWD050 API 29.46 131.84 75.993 8480 4681.5 8921 ROP MWD050 FT/H 2.23 1007.71 206.542 8407 4717.5 8920.5 First Reading For Entire File..........4673.5 Last Reading For Entire File...........8921 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 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.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: header data for each bit run in separate files. 7 5000 ~ • FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 8921.0 8951.0 LOG HEADER DATA DATE LOGGED: 09-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8951.0 TOP LOG INTERVAL (FT) 8921.0 BOTTOM LOG INTERVAL (FT) 8951.0 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 DGR DUAL GAMMA RAY 163686 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 3773.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 99.0 MUD PH: .0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 75.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8921 8951 8936 61 8921 8951 ROP MWD070 FT/H 0.26 25.23 12.6367 61 8921 8951 First Reading For Entire File..........8921 Last Reading For Entire File...........8951 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 8921.5 11115.0 FET 8921.5 11115.0 RPX 8921.5 11115.0 RPM 8921.5 11115.0 GR 8921.5 11115.0 RPD 8921.5 11115.0 ROP 8951.5 11115.0 LOG HEADER DATA DATE LOGGED: 11-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11115.0 TOP LOG INTERVAL (FT) 8951.0 BOTTOM LOG INTERVAL (FT) 11115.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 79.8 MAXIMUM ANGLE: 95.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE DGR EWR4 TOOL~PE DUAL GAMMA RAY Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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 TOOL NUMBER 156436 162742 6.750 3773.0 Mineral Oil Base 8.80 110.0 .0 23000 3.4 000 .0 000 108.0 000 .0 000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8921.5 11115 10018.3 4388 8921.5 11115 RPD MWD080 OHMM 3.07 131.65 38.3132 4388 8921.5 11115 RPM MWD080 OHMM 14.6 105.74 41.3586 4388 8921.5 11115 RPS MWD080 OHMM 15.72 1094.04 42.1255 4388 8921.5 11115 RPX MWD080 OHMM 14.69 120.19 38.4173 4388 8921.5 11115 FET MWD080 HOUR 0.11 303.44 0.980684 4388 8921.5 11115 GR MWD080 API 41.71 95.68 68.9432 4388 8921.5 11115 ROP MWD080 FT/H 3.5 1032.73 264.668 4328 8951.5 11115 • • First Reading For Entire File..........8921.5 Last Reading For Entire File...........11115 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11115.5 14476.5 FET 11115.5 14483.5 RPX 11115.5 14483.5 RPM 11115.5 14483.5 RPS 11115.5 14483.5 RPD 11115.5 14483.5 ROP 11115.5 14534.0 LOG HEADER DATA DATE LOGGED: 13-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME}: Memory TD DRILLER (FT) 14534.0 TOP LOG INTERVAL (FT) 11115.0 BOTTOM LOG INTERVAL (FT) 14534.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.3 MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH~T): 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 9435.0 Mineral Oil Base 8.80 82.0 2.0 19000 3.6 .000 .0 .000 108.0 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD100 OHMM 4 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11115.5 14534 12824.8 6838 11115.5 14534 RPD MWD100 OHMM 14.89 60.17 32.8768 6737 11115.5 14483.5 RPM MWD100 OHMM 14.6 73.95 35.4312 6737 11115.5 14483.5 RPS MWD100 OHMM 14.4 74.58 35.1483 6737 11115.5 14483.5 RPX MWD100 OHMM 13.11 65.7 32.8512 6737 11115.5 14483.5 FET MWD100 HOUR 0.11 56.13 0.47936 6737 11115.5 14483.5 GR MWD100 API 44.15 102.99 67.9701 6723 11115.5 14476.5 ROP MWD100 FT/H 0.19 569.66 265.902 6838 11115.5 14534 First Reading For Entire File..........11115.5 Last Reading For Entire File...........14534 File Trailer Service name .............STSLIB.007 Service Sub Level Name...• Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF File Header Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14477.0 15494.0 RPM 14484.0 15501.5 RPD 14484.0 15501.5 RPS 14484.0 15501.5 FET 14484.0 15501.5 RPX 14484.0 15501.5 ROP 14534.5 15552.0 LOG HEADER DATA DATE LOGGED: 16-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15552.0 TOP LOG INTERVAL (FT) 14534.0 BOTTOM LOG INTERVAL (FT) 15552.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.7 MAXIMUM ANGLE: 95.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 9435.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S): 78.0 MUD PH: .0 MUD CHLORIDES (PPM): ~ 20500 • FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 100.0 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 .12N Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MWD110 OHMM 4 1 68 16 5 FET MWD110 HOUR 4 1 68 20 6 GR MWD110 API 4 1 68 24 7 ROP MWD110 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14477 15552 15014.5 2151 14477 15552 RPD MWD110 OHMM 16.11 48.89 33.2924 2036 14484 15501.5 RPM MWD110 OHMM 15.16 51.02 33.6428 2036 14484 15501.5 RPS MWD110 OHMM 14.77 54.53 34.6953 2036 14484 15501.5 RPX MWD110 OHMM 14.64 216.28 36.9155 2036 14484 15501.5 FET MWD110 HOUR 0.15 29.19 1.92083 2036 14484 15501.5 GR MWD110 API 42.97 91.2 67.7846 2035 14477 15494 ROP MWD110 FT/H 5.2 487.47 244.826 2036 14534.5 15552 First Reading For Entire File..........14477 Last Reading For Entire File...........15552 File Trailer Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.009 • Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/10/19 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/10/19 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
