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
206-077
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - O ~~ Well History File Identifier Organizing (aone> ^ Two-sided III IIIII II III II III ^ Rescan Needed III (IIIII II II III III RESCAN DIGITAL DATA OVERSIZED (Scannable) ~olor Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria Date: D O /s/ Pro-ect Proofin J 9 III (IIIII IIIII II III BY: Maria Date: ~ O $ /s/ Scanning Preparation ~ x 30 = ~ + ~~ =TOTAL PAGES BY: Maria ~0 O ~ Date: (Count does not include cover sheet) /s/ Production Scanning III (IIIII IIIII II III C t f 7 P St t d d File: ~~ C S i he l d t oun ro age age oun oes canne ( m e cov r s e nc u ) Page Count Matches Number in Scanning Preparation : YES NO BY: Maria Date: ~ ~D O 8 Jsl r f Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ls/ Scanning is complete at this point unless rescanning is required. II I II II II I II II (IIII Rescanned II I IIIIIIIIIII IIIII BY: Maria Date: Js/ Comments about this file: Qu ality Checked I II I I'l II II I II) II I 10/6/2005 Well History File Cover Page.doc a r • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended Q 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development si Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: April 18, 2011 206 - 077 / 311 - 054, 311 - 107 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 June 11, 2006 50 103 - 20533 - 00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2928' FNL, 245' FEL, Sec. 24, T11N, R4E, UM June 26, 2006 CD4 - 210 Top of Productive Horizon: 8. KB (ft above MSL): 37' RKB 15. Field /Pool(s): 1621' FSL, 2391' FEL, Sec. 24, T11N, R4E, UM GL (ft above MSL): Colville River Field Total Depth: 9. Plug Back Depth (MD + TVD): 400' FSL, 903' FWL, Sec. 13, T11N, R4E, UM 2430' MD / 2292' TVD Nanuq Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x - 377999 y 5957484 Zone 4 11710' MD / 6217' TVD ADL 380077, 380075 TPI: x - 375841 y- 5956788 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 373922 y 5960879 Zone 4 none 380077 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1377' MD / 1351' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 68# H-40 37' 114' 37' 114' 42" Portland Type III 9.625" 40# L -80 37' 2540' 37' 2386' 12.25" 323 sx AS Lite, 230 sx Class G 7" 26# L -80 37' 7470' 37' 6235' 8.75" 200 sx Class G 3.5" 9.3# L -80 7187' 11210' 6182' 6243' 6.125" slotted liner 24. Open to production or injection? Yes ❑ No pi If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4.5" x 3.5" 2006' kill string none 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED € � �i1IN 1 6 ZU11 plug @ 2430' MD 19.7 bbls of 17.0 ppg cement � Cmi Rd-.2+ •- , R75 ' C / s ei S 64-44.) 34- IC. Zo Ifirt-s 4bac. 27. PRODUCTION TEST (../S4( Date First Production Method of Operation (Flowing, gas lift, etc.) shut -in Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No • If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE RECEIVED F' t ` Form 10-407 Revised 12/2009 ; il V MAY 1 0 i w - ONTINUED ON REVERSE a ' * I. 6. ' ' . ubmi original only 28. GEOLOGIC MARKERS (List all formations and markers entered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1377' 1351' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS J a Summary of Daily Operations, schematic ill/ 2:W 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Winfree © 265 - 6820 Printed Name A L / G. L. Alvord Title: Alaska Drilling Manager ( Signature . a Phone 265 - 6120 Date C `q't Cl Sharon Allsup -Drake INSTRUCTIONS 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. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item la: 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 and Ground level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 • WNS IIP CD4-210 �rhihps well Attribi tes Max Angle & MD ,TD Atas1a.Ir1C ,,, , Wellbore APYUWI Feld Name Well Status Inel (°) MD MKS) Act Btu (ftK6) ' , 501032053300 NANUQ PROD 94.09 11,57822 11,710.0_ C.. ent H2S (ppm) Dab IAn otation 1 End Date [KB (ft) Rig Release Date SSSV: TRDP _ Last WO: 44.03 6/30/2006 :1-,-- L+4?_V _.0 - 4 X11.3 .: PM ._.�. ✓•°� -__ - _ __._- � 1aas e,ogd .--_ A efl Tag: 4 (II 446.0 End d 4/1/2011 Rev Reason: Last Mod By End Dab g: n: PUMP CEMENT Imosbor 422011 �r'z if,F - D. S -- Casing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd WINGER, 26 -- -'. CONDUCTOR44' 16 15.250 36.0 114.0 114.0 65.00 H-40 Insulated a S casing Description String 0... String ID ... Top MKS) Set wpm (f... sat wpm (TVD) -- Siring wt... string ... smog Top net SURFACE 95/8 8.835 37.5 2540.0 2_386.3 40.00 L Casing Description String 0... String ID ... Top (WMCB w ) Sat pm w (f... Sat pm (TVD) ... String _ ng Wt... String String Top Thrd v INTERMEDIATE 7 6.276 34.8 7,470.0 6,234.5 26.00 L-80 r t __-- Gating Description String 0... String ID ... Top (811(6) Set Depth (T... Sat wpm (TVD) ... String WI... String ... String Top Thrd Top Depth Uner Detail SLOTTED LINER 3 1/2 _ 2.992 7,185 9 11,210.0 6,246.3 _ 9 30 L -80 SLH T p/ el - _ - Nom) (TVD( Top loci i ) L joCS CONDUCTOR TO ( (1 It�n wslxi•�•n -- Comment ID (in) 44 atW34. _ 7,185.9 6,181.8 75.04 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4400 SK f k 7,198.9 6,185.1 75.24 NIPPLE BAKER RS' PACKOFF NIPPLE 4.250 /� SAFETY VLV, 7,212.3 6,188.4 _ - -. 75.44 XO BUSHING BAKER * ER B FLEX LOCK HANGER 3.9 ��� , t 2,112 _ r .„ 11 ,1 wo (C . 7,257.6 6,199 -6 76.13 XO BUSHING CROSSOVER BUSHING 4.5x3 5' 2.990 TubingStrings .� �` ,,.9 ,= 14 Tubing Description String 0... String ID ... Top Set Depth (i... Set Depth (ND) .. String Wt... String .. String Top Thrd A V TUBING VIT 3.5" 26 4 1/2 3.500 26.5 5 4,012.0 3 709 7 12.60 L -80 VIT IBT /_yam{ - SURFACE, Inside 4.5" Tubing 37- 2.510 . Completion Details tt If f Top Depth / . (TVD) Top Ind Nomi... V '- To8 HOW) (ft") ___...._.. Item Description Cornment ID (in) I_ 26.5 26.5 0.00 HANGER FMC TUBING HANGER 4.500 �� GAS LIFT. _ 40.1 401 0.36 XO 4.5x3.5 3.500 4 368 _ -_. 2,111.5 2,012.7 25.53 SAFETY VLV CAMCO TRMAXX 5E SSSV 2.812 Tubing Description - e -- String 0... String ID ... Top MKS) Depth (f... Set Depth (ND) ... String WI... String r ng ... String Top Thrd (� (saJ{r e ' bi Tu TUBING 3 12 2.992 4,012.0 7,202.5 I 6,186.0 I 9.30 L -80 EUE 8RD Completion Details .2y30 ... Top Depth ®" (TVD) Top Intl N i... +� Top MKS) OKI3) I7 Item Description Comment ID (in) J O I. GAS LIFT. .__ 6,s57 4,0120 3,709 8 21.69 XO 4.5x3.5 CROSSOVER FROM VACUUM UM I NSULATED TUBING TO REGULAR 3.500 3.5" TUBING 6,746 -1 6, 020.' 60.48 PACKER BAKER PREMIER PACKER 2.875 6,824.7 6,058 1 64.01 NIPPLE HES XN NIPPLE 2.750 TBG PUNCH, 7,17121 61789 /481 WLEG Baker locator assy w/ WIRELINE ENTRY GUIDE 2.992 6.734 .: i I.. I PACKER, 6,746 .7" Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth ^ (TVD) Top Inc1 IF Top MKS) (KB) (1 Description Comment Run Date IDSin)_ NIPPLE, 6,825 it 6,734.0 6,0142 59.94 TBG PUNCH TUBING PUNCHES 5' x 2" OD, 0 DEGREE PHASING 3/25/2011 2.992 CEMENT SOZ, 6 875.0 6,079 3 66.26 CMT Retainer CEMENT RETAINER 3/31/2011 4,448 CMTRet __.._ : 1 1 Perforations &_Slots 1 - Shot .� Top(TVD) 8tm(rVD) Dens ' Top (ftK6) Rim (81(8) MKS) (R)(B) Zone Date (eh... Type Comment II 7,482.0 7,983.0 6,235.4 6,244.8 6/26/2006 32.0 Slots Alternating solid /sloped pipe - 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends CEMENT SOZ, 6,876 [ ill 1 8,540.0 8,854.0 6,247.1 6,238 .1 6/26/2006 32.0 Slots Alternating solid /sloped pipe - ' 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends 9,167.0 10,167.0 6,240.5 6,240.6 6/26/2006 32.0 Sills Alternating solid/slotted pipe - 0.125 "x2.5" @ 4 circumferential il adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends 10,704.0 10,829.0 6,2342 6,235.4 6/26/2006 32.0 Slots Alternating solid/slotted pipe - h 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - sloped ends 10,957.0 11,175.0 6,242.3 6,244.3 6/26/2006 32.0 Slots Alternating solid /slotted pipe - NrERMECwrE. 0.125"x2.5" / 4 circumferential 35 - 7,470 adjacent rows, 3" centers staggered Slots _, 18 deg, 3' non - slotted ends 7,4827983 - _. - -.._.. etc= i .. - Notes: General & Safety End Dab __ -- _ -- Annotation slots, ___ 6/30/2006 NOTE: TREE: FMC 4 -1/16" 5000 psi - TREE CAP CONNECTION: 7" OTIS 8.540 -8,858 6/21/2008 NOT E VIEW SCHEMATIC w/9.0 Slots, 9,167 - 10,167 ■ ■ slots, 10,700.10,628 - Ali la , I L Mandrel Details Slots. _ _ . -- Top Depth Top Port 10.957. 11,175 Y`91 .'�"° (rVDI IncI 0D Valve Latch Size TRO Run 1 e Stn Top (MB) (MKS) () M Model Son Type (In) (Pak Run Date Com... J k Mdl ( Sn TY 1 4,307.9 3,986 7 19 84 CAMCO KBMG 1 GAS LIFT DMY BK - 5 0.000 0.0 629/2006 SLOTTED _ LINER, 2 6,657 3 5,974 .4 56 85 CAMCO KBMG 1 GAS LIFT OV BK - 5 0.250 0.0 7/15/2008 7,168 - 11.210 �- TD, 11,710 -- CD4 -210 Well Work Summary DATE SUMMARY 3/22/11 TBG OPEN TO 2.80" TO 6825' RK . MEASURED BHP @ 6809' SLM: 2671 MOPS! / TEMP 130). READY FOR E -LINE. 3/25/11 SHOOT 5' 2.0" OD 0 DEG PHASING TUBING PUNCH GUN 6.5gram MILLENIUM CIRCULATION CHARGES, 2' UP FROM BOTTOM OF FIRST FULL JOINT ABOVE PACKER @6746'. TS: 6729' BS:6734. AFTER GUN WAS SHOT TUBING DROPPED FROM 700 PSI TO 100 PSI, IA INCREASED FROM 550 PSI TO 600 PSI, OA INCREASED FROM 875 PSI TO 900 PSI. 4/1/11 PUMPED 15 BBLS OF 15.8 CLASS G CEMENT THROUGH RETAINER SET AT 6875 CTMD, PULLED OUT OF RETAINER, PUSHED 60 BBLS CEMENT IN IA, PUMPED ADDITIONAL 20 BBLS IN 3.5 TUBING TO TOC TO 4446 FT . WELL IS FREEZE PROTECTED TO 3000 FT. 4/2/11 TAGGED @ 5109' SLM. JOB SUSPENDED. 4/3/11 MIT TBG @ 2500 PSI. PASSED. MIT IA @ 2500 PSI. PASSED. PULLED DV @ 4308' RKB. READY FOR E- LINE.. 4/4/11 ATTEMPT TUBING CUT WITH 2.70" JRC JET CUTTER. COULD NOT GET PAST 3740' RKB (HARD PARAFFIN ON TOOLSTRING). RAN 2.74" GAUGE RING ON ELINE WITH EVANS JARS. SAT DOWN AT 3740'. WORKED TOOLS TO 4373'. RAN 2.70" JRC JET CUTTER AND CUT TUBING AT 4030' RKB, MIDDLE OF FIRST FULL JOINT BELOW XO TO 3.5" TUBING. TUBING AND I/A PRESSURES EQUALIZED AFTER CUT TO 320 PSI. • • CanocoPhi[lips Time Log & Summary Wellview Web Reporting Report Well Name: CD4 - 210 Rig Name: DOYON 141 Job Type: DRILLING SIDETRACK Rig Accept: 4/13/2011 2:00:00 PM Rig Release: 4/18/2011 4:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/13/2011 24 hr Summary Move from CD4 -208. Accept rig at 1400, 4/13/2011. Displace well to mud. NU BOPE. 00:00 14:00 14.00 MIRU MOVE MOB P Move rig from CD4 -208 to CD4 -210. Set berm and mats. Spot sub base. Spot modules, pits, pumps, boiler, rock washer and pipe shed. ON HIGHLINE POWER @ 1100. 14:00 16:00 2.00 SLOT DRILL RURD P Accept rig at 1400. Take on mud, assemble pumps, level working surfaces. 16:00 16:30 0.50 SLOT DRILL PRTS P PT tubing hanger to 5000 PSI. IA = 0 PSI, OA = 900 PSI. 16:30 19:00 2.50 SLOT DRILL PRTS P PJSM. Test IA to 2000 PSI for 10 min. RU FMC lubricator, test and pull BPV. RD lubricator. 19:00 20:30 1.50 SLOT DRILL CIRC P PJSM. RU to displace wellbore to kill weight mud. 20:30 22:45 2.25 SLOT DRILL CIRC P PJSM. PT lines to 2000 PSI. Pump 50 BBL H2O, 35 BBL spacer, and 120 BBL 9.6 PPG LSND mud. Start @ 3 BPM and stage up to 4 BPM @ 800 PSI. Held 500 PSI back pressure with choke. 22:45 00:00 1.25 SLOT DRILL CIRC P Monitor well f/ 10 min. Set BPV. X4/14/2011 ND Tree/ NU BOPE. Thaw frozen wellbore. Begin POOH w/ tubing. 00:00 01:00 1.00 SLOT DRILL PRTS P Test IA to 250 / 1500 PSI fo 10 minutes each. 01:00 02:30 1.50 SLOT WHDBO NUND P ND Tree. Install Blanking plug. 02:30 05:00 2.50 SLOT WHDBO NUND P NU BOPE. 05:00 09:00 4.00 SLOT WHDBO BOPE P Test BOPE. w/ 4 " & 4.5 " test joints. Annular tests to 250 / 2500. ,p Rams and valves all tested to 250 / pbl r 3500 PSI. Accumulator tested with 1 /' 1, 5 system at 3000 PSI initially and 1800 PSI after close. Had 200 PSI increase in 41 sec with full system recovery in 3 min. 24 sec. N2 Bottle average - 2000 PSI. 09:00 10:00 1.00 SLOT WHDBO BOPE P RD test equip, remobe blanking plug, pull BPV. 10:00 12:00 2.00 SLOT DRILL PULL P MU landing jt into hanger, RU casing equip and Schlumberger spooling unit. Back out LDS and unseat hanger. Pull hanger to floor. Page 1 of 5 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 SLOT DRILL PULL P PJSM. LD landing jt and hanger. RU to circulate. Held kick while tripping drill. 13:00 18:00 5.00 SLOT DRILL CIRC T Attempt to circ BU via top drive and pressured up to 1000 PSI with no circ. Trouble shoot surface equipment and still couldn't pump. RU to circ through cmt hose and still would not circ. Pres up control line to 5500 psi and tubing to 2500 psi and held pres. Observed slight returns. Finally established circ and staged up to 4 BPM @ 900 PSI, dropping to 500 PSI. Observed ice at shakers. Pump nut plug sweep and circ 350 BBL's while warming mud. 18:00 18:30 0.50 SLOT DRILL RURD P RD circ equip. RU 3.5" handling tools 18:30 00:00 5.50 SLOT DRILL PULL P PJSM. POOH with 3.5' X 4.5" vacuum insulated tubing (VIT) 04/15/2011 POOH w/ 3.5" X 4.5" tbg. Test BOP (lower VBR) w/ 4" test joint. Set CIBP after 2nd attempt. 00:00 01:00 1.00 SLOT DRILL PULL P PJSM. Continue to lay down 3.5" X 4.5" vacuum insulated tubing from joint #56 - #65 with control line and insulated connection covers. LD SSSV. 01:00 01:30 0.50 SLOT DRILL PULL P RD Schlumberger spooling unit and equipment. LD from rig floor. 01:30 07:30 6.00 SLOT DRILL PULL P Continue to lay down 3.5" X 4.5" vacuum insulated tubing from joint #65 - 125 and cut joint. Total 123 Cannon Clamps, 123 Insulator sleeves, 246 Pins, 8 stainless bands. 07:30 12:00 4.50 SLOT DRILL PULL P RD casing equipment, clean & LD cannon clamps and insulators and send to warehouse. 12:00 13:00 1.00 SLOT WHDBO BOPE P RU and test lower VBR with 4" test, joint to 250 / 3500 psi. 13:00 14:00 1.00 SLOT DRILL MPSP T PJSM. MU CIBP. Upper slips were improperly made up, had to send plug back to Baker shop in Deadhorse to redress. Decided to RIH while waiting to prevent wellbore freeze -up 14:00 20:30 6.50 SLOT DRILL TRIP T RIH with scraper to 2734' MD. Circ and condition mud @ 8 BPM and 500 psi. POOH and LD scraper. 20:30 00:00 3.50 SLOT DRILL MPSP P_ MU redress-• - .. -.. - n 2670' MD. POOH and LD running tool. 04/16/2011 Run mechanical casing cutter and cut 7" casing below and above surface casing shoe. Displace OA with 9.6 ppg mud. Pull 7" casing above 1st cut. Fish casing stub in open hole with spear and jarring assembly. 00:00 00:45 0.75 SLOT DRILL CPBO P PJSM. MU Baker mechanical casing cutter. Page 2of5 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 03:30 2.75 SLOT DRILL CPBO P RIH. Tag CIBP @ 2670' MD. PU and locate collar @ 2637' MD. Move cutters down and make 1st cut @ 2640' MD. Prior to cutting bled OA G ') to tank from 950 - 100 psi in 15 minutes. Diesel and some gas. 03:30 04:45 1.25 SLOT DRILL CPBO P PU and locate collar @ 2468' MD. PU and make 2nd cut Ca) 2463' MD. Closed annular and circulated OA to 9.6 ppg mud. Had gas and diesel returns. Circulated at 2 BPM and with backpressure starting at 50 psi increasing to 500 psi. 04:45 05:00 0.25 SLOT DRILL CPBO P Monitor well for flow for 30 minutes. POOH with cutter to floor and lay down. 05:00 07:15 2.25 SLOT DRILL CPBO P POOH w/ cutter and LD BHA. 07:15 08:30 1.25 SLOT WHDBO BOPE P PJSM. C/O top pipe rams to 7 ". 08:30 10:00 1.50 SLOT WHDBO BOPE P Set test plug. Test 7" rams to 250/3500 psi and annular to 250/2500 psi. 10:00 10:45 0.75 SLOT WHDBO FISH P Pull 7" pack -off. Set wear bushing. 10:45 13:30 2.75 SLOT DRILL FISH P Make up spear assembly, PJSM. Spear hanger and unseat w/ 82K. Circulate BU @ 5 BPM and 100 psi. Monitor well 30 min. 13:30 14:15 0.75 SLOT DRILL FISH P Pull hanger to rig floor, remove spear and LD hanger. 14:15 16:15 2.00 SLOT DRILL PULL P PJSM. POOH with 7" casing, LD 56 joints and cut joint. 16:15 17:00 0.75 SLOT WHDBO BOPE P RD casing tools, clean rig floor, pull wear ring and set test plug. 17:00 18:15 1.25 SLOT WHDBO BOPE P PJSM. Change out upper rams to 3.5" X 6" VBR's. 18:15 20:30 2.25 SLOT WHDBO BOPE P Test upper rams w/ 4.5" test joint. Tested upper and lower rams and annular w/ 3.5" test joint. Rams tested to 250/3500 psi and annular tested to 250/2500 psi. 20:30 21:00 0.50 SLOT WHDBO BOPE P RD test equip, set wear ring and clear rig floor. 21:00 00:00 3.00 SLOT DRILL FISH P PJSM. MU spear assemblu and RIH . to fish 7" Sat down early at 2421' MD. Depth corresponded to collar above float collar in 9 -5/8 ". Worked past and continued to fish. 04/17/2011 POOH with 7" casing stub. RIH w/ 3.5" cementing string. Pump balanced plug. Land tubing @ 2006' . Prep for rig move. WOC for 15 hrs before PT. 00:00 01:15 1.25 SLOT DRILL FISH P RIH with spear assembly to fish 7 ". Worked past ledge /collar at 2421' MD. Tagged fish at 2463' MD. Engaged fish and jarred 12 times at 200K to break free. Started circulating and POOH to 2300' MD while pumping and taking returns. Page 3 of 5 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 02:00 0.75 SLOT DRILL FISH P Circulated 300 BBL @ 7 BPM @ 400 psi from 2300' MD 02:00 05:30 3.50 SLOT DRILL FISH P Monitor well, pump slug, POOH. LD Baker Fishing / spear assembly BHA. 05:30 06:15 0.75 SLOT DRILL FISH P LD 7" casing fish comprised of 4.2' cut joint ( #118) , 4 full joints of casing ( #117, 116, 115, 114) and 4.4' cut joint ( #113) and 2 centralizers. 06:15 07:30 1.25 SLOT DRILL PULD P LD casing equip, PU tubing equip for 3.5 ", C/O wear bushings 07:30 10:30 3.00 SLOT DRILL PULD P PJSM. Run 3.5" tubing and tag top of CIBP @ 2670. PU 3', PU = 50k, SO = 50K 10:30 12:45 2.25 SLOT CEMEN' CIRC P RU cementers, circulate @ 7 BPM, 400 psi. 12:45 13:30 0.75 SLOT CEMEN CMNT P PJSM. PT lines to 2000 psi, Pump 0 10 BBL Mud Push II, 19.7 bbl. 17 ppq class G, 2 BBL Mud Push II. Displaced with 16 BBL 9.6 ppg mud with rig pumps. CIP © 1330. 13:30 15:00 1.50 SLOT DRILL CMNT P POOH to 2100' MD. Drop wiper ball, pump 40 BBL nut plug sweep and circulate 2 BU. 15:00 15:15 0.25 SLOT DRILL PULD P Monitor well, RD Schlumberger 15:15 17:30 2.25 SLOT DRILL PULD P POOH to 2006' MD. Pull wear ring. MU hanger, install TWC, land hanger, Run in lock down screws. 17:30 18:15 0.75 SLOT DRILL PRTS P RU and test TWC. RD test equip. 18:15 20:30 2.25 SLOT DRILL PULD P Lay down 4" drillpipe using mousehole. 20:30 00:00 3.50 SLOT DRILL WOC P WOC. Clean rig floor, unload pipe shed, clean pits, prep for move. 04/18/2011 Cont to WOC. Test cement plug to 2000 psi. Test good. ND BOP /NU tree. Freeze protect tubing and annulus. RR. 00:00 04:30 4.50 SLOT DRILL WOC P Continue W.O.C. 04:30 05:00 0.50 SLOT DRILL PRTS P PT cement by pressuring up down IA valve to 2000 psi for 30 minutes. Good test. 05:00 07:00 2.00 SLOT WHDBO NUND P PJSM. ND BOPE. Remove FMC speed head from tree. 07:00 08:00 1.00 SLOT WHDBO NUND P NU tree. Test adapter flange to 5000 psi for 10 min. Test tree to 5000 psi for 5 min. 08:00 09:00 1.00 SLOT DRILL RURD P Pull TWC. RU to displace well. 09:00 10:00 1.00 SLOT DRILL CIRC P Displace well to fresh water down tubing taking returns through IA. Pumped 35 BBL viscosified water spacer followed by 290 BBL 10:00 12:30 2.50 SLOT DRILL FRZP P PJSM. RU Little Red, PT lines to 2500 psi and freeze protect well w/ 130 BBL diesel pumping down IA @ 2 BPM and 450 psi. U -Tube Tbg by IA for 30 minutes, set BPV. Page 4 of 5 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 16:00 3.50 SLOT DRILL DMOB P RD Lines and remove double annulus valves. Clean pits, etc. RR RIG AT 1600 HOURS. � IIII Page 5 of 5 • • E[F ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMAIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 G. L. Alvord Drilling Manager ConocoPhillips Alaska, Inc. ` Q P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq Oil Pool, CD4 -210 Sundry Number: 311 -107 Dear Mr. Alvord: 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. 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 reconsideration. A request for reconsideration 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. Sincerely, Daniel T. Seamount, Jr. Chair DATED this U day of April, 2011. Encl. • • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPhillips Telephone 907 - 276 -1215 March 29 2011 e Alaska Oil and Gas Conservation Commission REC EIVED 333 West 7 Avenue, Suite 100 teats Anchorage, Alaska 99501 4�R ?l(I i Re: Sundry Permit -- Request to Re -Enter CD4 -210 and Plug for Re-Drill nc Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to re -enter the CD4 -210 well with the intention / to set a kick off plug for future sidetrack operations. The predicted start date for the re -entry and plug setting operations is 4/13/2011. Doyon Rig 141 will perform the work. This operation is planned following the pre -rig abandonment work approved in Sundry number 311 -054. The sidetracking procedures will be covered in a separate Application for a Permit to Drill CD4 -10. , ✓ Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments include: 1. Form 10 -403 2. A proposed re -entry and abandonment program 3. CD4 -210 Current Schematic 4. CD4 -210 Pre -Rig Abandonment Schematic 5. CD4 -210 Set up for Sidetrack Schematic 6. Pre -Rig abandonment procedures approved in Sundry #311 -054 Application information already on file with the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Ryan Robertson at 265.6318 or Chip Alvord at 265 -6120. Sincerely, Ryan Robertson Drilling Engineer Attachments: cc: CD4 -10 Well File / Sharon Allsup Drake ATO 1530 Brian Noel ATO 1700 Mark Chambers ATO 1566 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill El • Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well 0 • Stimulate ❑ Alter Casing ❑ Other: &a( jw y g yy,,, 2. Operator Name: 4. Current Well Class: 5. Permit t ill Number: ConocoPhillips Alaska Inc. Development • • Exploratory ❑ 206 -077 . 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P.O. Box 100360, Anchorage, Alaska 50- 103 - 20533 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ CD4 - 210 • 9. Property Designation (Lease Number): 10. Field / Pool(s): 380077, 380075 ' Colville River Field / Nanuq Nanuq Oil Pool • 11. PRESENT WELL CONDITION SUMMARY - DOYON 141 RKB Total Depth MD (ft): ITotal Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): /Mc 11 ¢, 6,217 11,702 6,217 Casing � f Length Size MD TVD Burst Collapse Structural Conductor 78 16' 106 106 Surface 2504 9 -5/8" 2532 2,294 5,750 psi 3,090 psi Intermediate 7434 7" 7462 6,234 5,410 psi 7,240 psi Production Liner 11174 3 -1/2" 11202 6243 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): n/a n/a 3 -1/2" L -80 7,194 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Premier Packer and Camco TRMAXX -5E SSSV Packer set at 6,738' MD (6,022 TVD) -- SSSV set at 2,104' MD (2,013' TVD) 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: • Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/6/2011 Oil • Gas ❑ WDSPL ❑ Suspended • • 16. Verbal Approval: Date: n/a WINJ 0 GINJ El WAG ❑ Abandoned ❑ Commission Representative: 4 � , •tf /( GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ryan Robertson 265 -6318 Printed Name G.L Alvord Title Drilling Manager Signature Phone 907 - 265 -6120 Date 3/29/2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: / 5 /1 — J " (� - 7 Plug Integrity ❑ BOP Test je Mechanical Integrity Test ❑ Location Clearance ❑ 25 RE _ Fes+ �' / ice► Y Other: 3500 f- 150e 7: w� ••� r��eee iii APR 0 1 2011 #- Z son p s� „n "'ILEA ."'ILEA � Za Mc zs: z8s Ch) �4 s ; k L P /Z s 4. . e r 1-a- ` �— ca & Gas Cons. Commission Subsequent Form R c u ired: lanorne lb_ a APPROVED BY Approved by: i COMMISSIONER THE COMMISSION Date: q---/ff 1 ) / 1 V Form 10 -403 Revised 1/2010 / R 1 G 1 N A t ( b ( ' Submit in Duplicate K' • • Doyon 141 CD4 -210 Abandonment Procedures Na4.1_ Vim( ;5 s4sP¢..r.Qc.Q h. re 4ter;ac-s The proposed scope of work for this sundry application includes: 1. MIRU Doyon 141. 2. Test 7" casing, 7" casing pack off and BPV through inner annulus to 1,500 psi. 3. Test tree adaptor to 5,000 psi. 4. Pull BPV. 5. Circulate diesel freeze protect over to 9.0 ppg kill weight brine through tree, taking returns to tiger tank. 6. Set BPV and test through inner annulus to 1,500 psi. • 7. Set blanking plug. 8. Nipple down tree. 9. Nipple up BOPE and pressure test rams with 3.5" and 5" test joints. �-� 35� p S` BC�P s a. Clearance issues with the blanking plug prevent the lower rams from being tested at this point. CPAI requests approval for testing the lower rams after the tubing is pulled from the well. • 10. Remove blanking plug and BPV. 11. Pull 3 -1/2" tubing. 12. Pressure test lower rams with 3.5" and 5" test joints. 13. Run in hole with CIBP on 5" drillpipe and set at 2,712' MD. 14. Run in hole with mechanical casing cutter on 5" drillpipe and cut casing at 2,702' MD. • 15. Flush 7" x 9 -5/8" annulus with 9.0 ppg kill weight brine taking returns to tiger tank. 16. Swap 3.5" x 6" rams to 7" casing rams and pressure test. 17. Pull 7" casing to surface and lay down. 18. Swap 7" casing rams to 3.5" x 6" rams and pressure test. 19. RIH with 3.5" cement stinger and set cement kick off plug from the top of bridge plug to 100 ft within . the surface shoe. 20. Run 3 -1/2" tubing kill string to 2,000' MD. 21. Install TWC and pressure test to 1,500 psi from inner annulus. 22. Nipple down BOP and nipple up tree. 23. Pull TWC and displace well to inhibited brine and diesel freeze protect. 24. Set BPV and secure well. 25. RDMO Doyon 141. ,&eece as f Srr 0t V C4* O� 50111,. A /IAA M ei,r rev.' " CO�r� OSy a (eaves' 07 / ' • I Y 0 h i i46-. tei �i. - 49c c'%.�#'. 0 3 �� • • CD4 -210 Current Schematic � - -, WNS CD4 -210 ConocoPhillips r 8 Well Attributes Max Angle & MD TD Welitwre APIIUWI Field Name Well Status Incl (°) MD OMB) Act Bun MOB) cmotomeampo 501032050300 NANUQ PROD 94.09 11578.22 11,710.0 Comment N2S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date - -- Well can . - t°no-2ta. +,.6.•x9 rav -n Pia SS TRDPP Last WO'. 44.03 6)30;2006 - n - at , • q g Aenotato D epth 1 a End Date Annotation Last Mod _ End Date tall Tag- Rev Reason: OC TALLIES . 12:5:2009 Casing Strings ,_ Casing Description String 0 Suing ID Top (0001 Set Depth If Set Depth INS String Wt.. String... Siring Tap Thud HAasE3;e ";h CONDUCTOR44' 16 '5.250 36.0 V4.0 1143 65.00 H-40 Insulated Casing Description String 0.. String ID ... Top IT1031 Set Depth If... Set Depth (TYCO .. String Wt... Song .. String Top Thrd SURFACE 95/8 8.835 37.5 2.5400 2.386.3 40.00 L Casing Description String 0. Sptng ID ... Top (ftl(B) Set Depth IS... Set Depth :TVDI .. String Wt String ... String Top Thrd INTERMEDIATE 7 . 6.276 34.8 7470.0 6.234.5 26.00 1 - 80 IP Casing Description string C String ID _. Top IAMBI Set Depth 1f... Set Depth (NCI .. Song Wt.. thing ... String Top Thrd SLOTTED LINER 3 12 2.992 7.185 9 11.210.0 6.246.3 9 30 L -80 SLHT it Liner Details Top Depth al /TAD) Top Ind Sorer.. Top (MB) IMO) (1 Item Description Comment ID (In) rrncTDn x 7,185.9 6.181.8 7504 SLEEVE BAKER 'HR LINER SETTING SLEEVE 4 400 ,..... - 36,14 /.198. 6.185.1 /5.24 NIPWE BAKER 'RS HACKUFF NIPPLE 4.150 7.202.6 6.186.0 75.29 HANGER BAKER 'DG' FLEX LOCK HANGER 4.400 SAFETY VLV. 1.272..3 6,168.4 7544 XU BUSHING CROSSOVER B USHING 5x4.5' 3 970 2 -,r3 7.2576 6.199.6 7613 XO BUSHING CROSSOVER BUSHING 4.5x3.5' 2990 Tubing Strings Tubing Description String 0... String ID Top (MB) Set Depth If. Set Depth (NOS, .. Stung Wt.. Sting String Top Thrd TUBING 11T 3 5" 4 1x2 3. 522 26.5 4:2129 3 7 09 ! '2 52 -u.- m de 4S Completion Details }} -2.64a SURFACE, + Top Depth ITVD) Top not Nam, g. ToP (RKBI (hKB1 (1 Item Description Comment ID (in) 26.5 26.5 U W HANGER FMC IUBINIa HANGER 4.500 11111 40.1 40.1 0.36 XU 4 503.5 3 nULf 2.111.5 2.012 -/ 25.53 SAI-E1 Y VLV 't MCO I HMAXX -5E SSSV 2 8°2 OAS L'F`. 1 Tubing Description String 0... String ID _. Top IAMB) ISet Depth (f.. Sat Depth (ND)... Suing Wt.. String .. String Top Turd 4.3CF. TUBING 3 1.2 2.992 4.012.0 7.202.5 6,186.0 9.30 L-02 ELIE 8P•E Completion Details Top Depth ITVD) Top Ind Norm... Top (SOB) (MD) (`) Rem Description Comment ID (int It 4.012.0 3.709.8 21 69 XSi 4.5x3.5 CROSSOVER FROM VACUUM INSULA I ED 1 UBING 1 O REGULAR 3 -500 _ectF- 3.5'TUBING III 6.746.1 8,020.7 6048 PACKER BAKER PREMIER PACKER 2.875 Ili 6.824.1 6,058.1 64.111 NIPPLE HESXN NIPPLE 2.750 7,171.2 6,178.0 74.81 WLEG Baker locate" asst ar. WIRELINE ENTRY GUIDE 2.992 sr PACKER, 1.740 e11=1/11 Perforations & Slots Shot 11 i. Top fTVD) I Sl a [runt Dens Top (5001 Bun (RKB) IRKBt 4l (SOB) Zone hate ( Type Comment art . 7.482 1.983 8.135. 6.244. 626, 2006 32.0 Slots ARematmg soldisioited pipe - 5IPPLE.6Ace g■ 0 125"x2.5" op 4 circumferential Ili adjacent rows. 3" centers staggered 18 deg. 3' non - slatted ends IN 8,540 8.854 6.247.1 6.238.1 526,2006 32.0 Slot ng sold/slottedcope - 0.125"x2 5" 0.: 4 circumferential re adjacent tows. 3" centers staggered 18 deg. 3' nen- scatted end. _ 9. 10.161 6.240.5 6,240,6 622622006 320 Slots Alternating soldislotted pope - I 0 125 "x2 5" 40 4 circumferential adjacent rows. 3" center staggered 18 deg. 3' non - sated end. II 10.704. 10.829 6.234.2 5,235.4 6,262006 32.0 Slot Altemat sold/slotted pipe - 0 125'x2" 40 4 circumferential ID adjacent rows. 3" centers staggered 18 deg, 3' non - slotted ends 10.95/ 11.1 /5 6.242.3 6.244.3 6/26i2(105 32.0 Slot Aiternatrng solid/slotted pope - 0 125'4.5" ore 4 circumferential adjacent rows. 3" center staggered 18 deg, 3' non - slotted ends Notes: General & Safety tRERINEI An!, 4 End Date Annotation 1.5-7 on &/311r2006 IE: > HEE: 1-ML 4-116 SOW pn,- ?Hu=E:.Af'CUNNECI ION: 7 "0115 slag. AIM 6212008 N VIEW SCHEMATIC w/9.0 7.492. 7.963 -r 7- stag. Mandrel Details Top Depth Top Port etas (TO)) Intl 00 Valve Latch Size TRO Run 3. te,- 10.177 �* Stn Top (RKBI IRKS! (`I Make Model (aril Sere Type Type GN Corn.. Run Date Co.. 1 4.307.9 3 986.7 19 84 CAMCO KBMG 1 GAS LIFT DMY BK -5 0 000 0.0 6:29r2006 2 6.65/.3 5,9/4.4 56.85 CAMCO KBMG 1 GAS L1F I OV BK -5 0.250 0.0 ('15.2008 Sion. _„ 6 =a ma-mete I a WR. 4 '3 667-11 SLOTTED 41 l TD 11.7!0 P ee ,- ��� CD4 -210 Pre -Rig Abandonment Schematic (Reference Sundry # 311 -054) t,s CD4 - 210 Nanuq Producer Abandonment All Depths Adjusted for Doyon 141 RKB Updated - 03.29.11 " 1111 16" Insulated Conductor to -106' i. Ne.. ; Diesel (to be removed by rig) © BM 2.813" X TRMAXX SCSSSV • 2) 4 -%2' x 3 -%2" Vacuum insulated tubing (VIT) 1:1111 $ :11111 0 i 5 ■ 9 -5/8" 40 ppf L -80 BTCM Surface Casing 4 0 2532' MD 1 2379' TVD Q 0 4) 4 -' /2" x 3 - %2' Vacuum insulated tubing (VIT) to +/- 4000' MD Upper Completion: Top MD TVD 1) Tubing Hanger 28' 28' 2) 4 -1/2" x 3 - %Z" VIT 3 -' /" buttress -Mod connection Cut Tubing at 3) 3 -1/2" Camco TRMAXX SCSSSV w/ X profile 2104 2013' 4042' MD / 3737' TVD 4) 4 -1/2" x 3 -' /2" VIT 3 -' /" buttress -Mod connection 5) Crossover from VIT (3 -' /" IBTM) to EUE -M tubing 4000' 3708' 6) 3 -' /" 9.3 # /ft, EUE -M 7) Camco KBMG 1" GLM w/ dummy valve 4324' 4000' 8) 3' / "9.3#/ft, EUE -M 9) Camco KBMG 1" GLM w/ dummy valve 6700' 5989' 10) 3-Y2" 9.3 # /ft, EUE -M (2) 11) Baker Premier Packer 6738' 6022' 12) 3 -' /2" 9.3 # /ft, EUE -M (2) 13) HES "XN" (2.75" min ID) 6850' 6065' 8.6 ppg Corrosion 14) 3- 9.3 # /ft, EUE -M inhibited seawater 15) BOT Stinger with Fluted WLEG /pup /shear sub 7270' 6210' bottom, 3' spaceout @ 7308' Lower Completion: Top MD TVD 16) Baker 5" x 7" Flexlock Liner Hanger 7273' 6211' 17) 3-'/2" 9.3 # /ft L -80 SLHT Tubing 18) 3 -' /" 9.3 #/ft L -80 SLHT slotted liner w/ blank across shale iniTA and slots across sand 19) Baker Shoe 11,202' 62043' Planned top of cement 6472' MD / 5867' TVD • 3-'/" 9.3 #/ft L-80 SLHT Slotted liner Pattern: O ® �. 32 slots / ft, 2 -' /<" x 1/8" slots ® 16 18 19 �J r Top Reservoir at +/- Nanuq 7199' MD / 6185' TVD TD 6 - 1/8" hole 7" 26 ppf L -80 BTC Mod 11,702' MD / 6217' TVD Production Casing @ +1- 83° 7462' MD / 6234' TVD I • CD4 -210 Pre -Rig Abandonment Schematic (Reference Sundry # 311 -054) kick _0(/ f/ SeJ Colville River Field t ,,1 A4Jv CD4 -210 Nanuq Producer Rig Abandonment All Depths Adjusted for Doyon 141 RKB ; 0 tirt %VeS . Updated- 03.29.11 m 16 " Insulated Conductor to 4 3'/2 9.3 ppf L -80 EUE 8rd Mod Tubing Kill String with 3? x 4 " cross -over, 2 jts below 4 -' /z" hanger �^ �9 j < #� e,��� -��;; Set at 2,000' MD / 1912' TVD „ : dti 1 „ * Diesel Freeze Protect 8.6 ppg Inhibited Brine ppi ,.';! Top of Plug @ 2432' MD / 2294' TVD 9 -5/8" 40 ppf L -80 BTCM Surface Casing i:.;i 1 P09s € € 2532' MD / 2379' TVD KiGktf is €: € =' i; pliig';i; �K KOP at 2582' MD / 2,422 • L 4 7" Casing Cut at 2702' MD / 2,525' TVD .k.:.. CIBP at 2712' MD / 2,533' TVD 9.0 ppg LSND Mud 4e, triv Cut Tubing @ 4042' MD ! 3,737' TVD 8.6 ppg Corrosion inhibited seawater Planned Top of 15.8 Class G Cement 6472' MD / 5867 TVD 3'/2" 9.3 #/ft L - SLHT Slotted liner Pattern: Q®I Top Reservoir at +/- Nanuq 7199' MD / 6185' TVD TD 6 -1!8" hole 7" 26 ppf L -80 BTC Mod 11,702' MD ! 6217' TVD Production Casing @ +/- 83° 7462' MD / 6234' ND • • Work Approved in Sundry # 311 -054 Obiectives The objective of this procedure is to abandon the existing Nanuq interval and set up the well for a rig • sidetrack. The rig will sidetrack from just below the surface casing shoe. In preparation for the sidetrack this work will be completed to isolate the formation from the wellbore, load the well with inhibited fluid, and cut the tubing below the x -over to end the vacuum insulated tubing (VIT) at 4012' RKB. Procedure • E -Line: 1. RIH and Log packer assembly with CCL to identify tubing punch location just above packer. 2. Shoot 4' of 2" OD tubing punch in tubing just above packer. 3. Pressure up (or bleed off) IA and verify that the IA is tracking and in communication with the TBG. 4. RDMO. Coiled Tubing: 1. RIH and set a 2 -1/8" or 2 -1/2" Baker inflatable cement retainer in 3.5" tubing below the XN nipple at 6825' RKB. Retainer should have internal check valve to prevent backflow of fluid from below (and from above) when un- stung. 2. RIH and sting into retainer. 3. Confirm slotted liner open by pumping 150 bbls of SW 4. Pump 15 bbls of 15.8 ppg Class G cement through retainer. After 15 bbls have been pumped un- sting from retainer and PUH above the holes in tubing, open IA at surface and begin taking returns. Pump an additional 60 bbls of cement taking all returns from the IA. After 60 bbls have been pumped, close IA at surface and begin laying in 20 bbls of cement in the 3.5" tubing. 5. After cement has been pumped and equipment washed up lay in diesel freeze protect from 2000' . to surface. 6. RDMO. Slickline: 1. RIH and gauge tubing down to top of cement. 2. PT tubing to 2000 #. 3. PT IA to 2000 #. 4. Attempt to pull DV from GLM at 4308' RKB. 5. If successful pulling DV leave pocket open and circulate in 85 bbls of 2% CRW -132 corrosion inhibited seawater followed by 70 bbls of diesel. [If unable to pull DV notify Wells Supervisor to schedule a tubing punch to be shot at a depth just shallower than the GLM.] 6. Jumper IA to tubing and let diesel u- tube. 7. Re- install DV into GLM @ 4308' RKB. Confirm set by creating differential pressure. 8. RDMO E -Line: 1. RIH with Jet Cutter (or alternative) and cut the 3.5" tubing at —4042' RKB (must be below x -over to vacuum insulated tubing @ 4012' RKB.) 2. Pressure up (or bleed off) tbg to confirm communication has been made. 3. RDMO. • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 6, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Cut Record: CD4 -210 4 APR 1 9 O 1 Run Date: 4/5/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD4 -210 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20533 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 c2 •b - Klinton Wood @halliburton.com Signed: ed: Date: , f ; gn B� _ • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 30, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch Record: CD4 -210 Run Date: 3/25/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD4 -210 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20533 -00 r D APR " 8 2O1'i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 ,��� � �� Fax: 907 - 273 -3535 Klinton Wood @halliburton.com Date: Signed: Al 'di-7 '` TVIMPl v ` y • • STIA1 II A[LAs[rA SEAN PARNELL, GOVERNOR ALASKA OIL AND GA.S 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 T. Senden Wells Engineer MAC ConocoPhillips Alaska, Inc. a01 0 7 7 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq Oil Pool, CD4 -210 Sundry Number: 311 -054 Dear Mr. Senden: 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. 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 reconsideration. A request for reconsideration 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 holida or weekend. • erel, n K. orman om sioner DATED this day of March, 2011. Encl. STATE OF ALASKA ALASK•IL AND GAS CONSERVATION COMMISS• FEB ?; APPLICATION FOR SUNDRY APPROVALS Ai 20 AAC 25.280 a NI RI Gas I,t;c ('.gym^ , I;.tit 1. Type of Request: Abandon ., V Rug for Redrill • Perforate New Pool r Repair well Change Program r Suspend y Rug Perforations r Perforate r Pull Tubing r Time atension fl Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing E Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r` . Exploratory r 206 - 077 • 3. Address: Stratgraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20533 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No CD4 -210 • 9. Property Designation (Lease N umber): . 10. Field / Pool(s): ADL 380077, 380075 Colville River Field / Nanuq Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11710 • 6217 • 11710' 6217' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114' 114' SURFACE 2503 9.625" 2540' 2386' INTERMEDIATE 7435 7 7470' 6235' SLOTTED LINER 4024 3.5" 11210' 6243' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner 7263' 11208' 6200' - 6246' 3.5 L - 7202 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER PREMIER PACKER MD= 6746 TVD= 6022 SAFETY VLV - CAMCO TRMAXX -5E SSSV MD= 2112 TVD= 2013 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/7/2011 Oil 4 ? 4- I1 Gas WDSPL r Suspended p tt — 16. Verbal Approval: Date: WINJ r 1; GINJ r WAG E Abandoned r ;IF Commission Representative: GSTOR fl SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ty Senden @ 265 -1544 Printed Name T Senden Title: Staff Wells Engineer I 1 er 1 Phone: 265 -1544 Date / Signature � � 4 fff Commission Use Only Sundry Number: o6 I Conditions of approval: Notify Commission so that a representative may witness 3/ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: / D — ■P / 4 y APPROVED BY �� /� Approved by: it C MMISSIONER THE COMMISSION Date: ea Res -s'�f33t\ 3 S ubm it in te 0f SW1 ORIGINAL , - g44 T` -'•\, • WNS • CD4 -210 ConocoPhilt s p tl , Wel o P NANUO [PROD Vii( MD Angle TO • ' Welibore re A PI1U VUW Field Name Well Status Intl ( °) MD (ftKB) [Act Bbn (ftKB) 1 94 09 11,578 22 I 11,710.0 Comment 1I-12S (ppm) Date Annotation End Date 'KB -Grd (ft) Rig Release Date we' cnnfg Goa - meW Actual 10 2/572909x00 7PM SSSV (RDP � I I (Last WO: I 44.03 6/302006 -- ' - $tlle _ Annotation Depth (ftKB) End Date Annotation 1 Last Mod ...[End Date Last Tag- 4 Rev Reason: QC TALLIES Imosbor 12/5/2009 Casing g Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd RANGER, 26 CONDUCTOR44" 16 15250 36.0 114.0 114.0 65.00 H-40 Insulated Casing Description String 0... String ID .. Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 37.5 2,540.0 2386.3 40.00 L - 80 9 ? Casing Description String 0... String ID ... Top 0118) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thld INTERMEDIATE 7 6.276 34 8 7,470.0 6,234.5 26.00 L - 80 Casing Description String 0... String ID ... Top (ftKB) Sat Depth (L.. Set Depth (ND) ••. String Wt... String ... String Top Thrd + ' SLOTTED LINER 3 1/2 2992 7,185.9 11,210.0 6,246.3 9 30 L SLHT ` LinerDgtails Top Depth (WD) Top Intl Nomi... Top OtKB) (ftKB) (1 Item Description Comment ID(in) CONDUCTOR 7,185.9 6,181.8 75.04 SLEEVE BAKER 'HR' UNER SETTING SLEEVE 4.400 or Insulated, 36 - 114 ! 7,198.9 6,185.1 75.24 NIPPLE BAKER 'RS' RACKOFF NIPPLE 4.250 -[ 7,202.6 5186.0 7529 HANGER - BAKER 'DG' FLEX LOCK HANGER 4.400 SAFETYVLV, t ) 7,212.3 6,188.4 Nu XO BUSHING CROSSOVER B USHING 5x45" 3.970 2.112 7,257.6 6,199.6 76.13 XO BUSHING CROSSOVER BUSHING 4.5x3 5" 2.990 i �' Tbin9- Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING VIT 3.S" 4 1/2 3.500 26.5 4,012.0 3,7097 12.60 L -80 VIT IBT L inside 4.5" Completion Details SURFACE, ._ _A ��� Top Depth -_. 37 -2,540 (ND) Top Intl Nomi... Top iNKB) (ftKB) ( °) Item Description _ Comment _., ID(in) _ 26.5 26.5 0.00 HANGER FMC TUBING HANGER 4.500 40.1 40.1 0.36 XO 4.5x3 5 3.500 2,111.5 2,012.7 25.53 SAFETY VLV ICAMCO TRMAXX 5E SSSV 2.812 GAS LIFT, _ ._ 4 308 .r ul e TubmgDescription String 0... String ID ... Top (ftKB) Set Depth (f Set D pth (TVD) String Wt String String Top Thrd TUBING 3 1/2 I 2.992 I 4,012 0 I 7,202.5 6,186.0 9 30 L-80 EUE 8RD I Completion Details 1 , , ` „ _....r,. z, - =. : Top Depth (TVD) Top Ind Nomi... Top (ftKB) (ft68) j°) item Desorption Comment ID (in) 4,012.0 3,709.8 21.69 XO 4.5x3.5 CROSSOVER FROM VACUUM INSULATED TUBING TO REGULAR 3.500 000 LIFT 3.5" TUBING 6.657 - - -- -- - -_.�. - -- 6,746.1 6,020 7 60.48 PACKER BAKER PREMIER PACKER 2.875 6,824.7 6058.1 64.01 NIPPLE HES XN NIPPLE 2.750 7171 G 173.0' 74 81 WLEG 'Baker locator assy w/ WIRELINE ENTRY GUIDE 2.992 PACKER, 6,746 - . w: Perforations & Slots -.. r Shot Top (TVD) Btm (TVD) Dens 1 Top (ftKB) Bbn (ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment 7,482 7,983 6,235.4 6,244.8 6/26/2006 32.0 Slots Alternating solid/slotted pipe - NIPPLE, 6,825 - t 0.125 "x2.5" @ 4 circumferential L adjacent rows, 3" centers staggered 4 �� 6 18 deg, 3' non - slotted ends 3 5 6,247.1 I' l le 1.1 ,'' 8,540 8,854 6,238.1 6/26/2006 32.0 Slots Alternating solid /slotted pipe - 0.125"x2.5" © 4 circumferential adjacent rows, 3" centers staggered 1 ' 18 deg, 3' non - slotted ends 9,167 10,167 6,240.5 6,240.6 6/26/2006 32.0 Slots Alternating solid /slotted pipe - I I 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered - - 18 deg, 3' non - slotted ends ill 10,704 10,829 6,234.2 6,235.4 6/26/2006 32.0 Slots Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends 10,957 11,175 6,242.3 6,244.3 6/26/2006 32.0 Slots Alternating solid/slotted pipe - 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends 1 Notes: General & Safety NTERMED'ATE, _ _._._ .... End Date Annotation 06 4 __ 35 - 7,470 6/30/2006 NOTE: TREE: FMC 5000 psi - TREE CAP CONNECTION: 7" OTIS slain,"' 6/21/2008 NOTE: VIEW SCHEMATIC w/9 0 7.482.7.983 .L -. r SIGN,___ _ 8,540-8,854 _ Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run Slots, = Stn To ftKB (ftKB) 1') Make Model (in) Sery _ Type Type (in) (pai) Run Date Can... 9,187 - 10,167 �___ P ( ) 1 4,307.9 3,986.7 19.84 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/29/2006 2 6,657.31 5,974.4 56.85 CAMCO KBMG 1 GAS LIFT OV BK -5 0.250 0.0 7/152008 sots. - -- 10,704 -113829 i i Slots, 10,957 - 11,175 i 1 i SLOTTED L LINER, - 7,188- 11,210 TD, 11,710 • . CD4 -210 Abandonment The following procedure will be used to isolate the perforations and protect the - production packer from the reservoir. The well will be sidetracked under a • separate Sundry and permit to drill. 1. Shoot squeeze perfs above the packer at 6746' RKB. 2. Run in hole and set inflatable retainer below packer. syAV BL 3. Pump 15 bbls of 15.8 ppg Class G cement through retainer. 4. After 15 bbls into the slotted liner pull up and squeeze 60 bbls of the same 15.8 ppg Class G cement into the IA above the packer. 5. La y top in 20 bbls of cement on to of the retainer. - 2 Yoe.' 4 c .,t ..� TO C 6. Tag cement top. . p 7. PT tubing and IA to 2000 #. 8. Pull gas lift valve from mandrel at 4308' RKB. 9. Circulate in corrosion inhibited seawater and diesel freeze protect. 10. Equalize tubing to ensure freeze protect on both tubing and IA. 11. Cut tubing at 4050' RKB (below vacuum insulated tubing). 12. Set back pressure valve in preparation for the rig. f et cosvvrsctio4 w" 4 Aim r4 e Cift 21D u-el/ ls Rio eXrt Pete 1 /00 !' f tvJL/ ce e Wh / 4 1 eh �^�''W ov Ge1Us .0i 10 f ecoiG/t 54 ,' y /IV I vcy o f Pegged 4/- !30 Of# t old Tic we 40, 00)4 ( "pet cgp¢f/ o{ ror/*/.0 Pte, ed �, f f n )0,1e/v came ip IC to �. 'F /ews � hem/ ' 4"c die 70 )fie TO i 1`1 aw fv,deb+ee o� P4,5 also exittf f Comm iJ5Dh 1. 60.110j Wi �� S1,o.rt 77+C. w4,1( I�af n Unab /e To frolvcr kr A"ec 7*44 Q 64. 6 1 1) 4 /40e/1 Ueei haP,S. /mit cpd wow /ro cfro `i f Colel i/ ( , .,,- 7 Ca, tot .'4414 C/ v,'GM f To if It /1 TI* wea ' r Erg 0 / 10 „( k !4 y po o.tP //pit .'01 /It ems ri' zy iv / a' d ,: Ib c S t ' a rick 4 A•/ ro ,'m /fm i vcc c %" feay.' d �" 1 < <H Tie iiK ©. / e n d q4° (o C/i i t Avowal, ,3/ • • • CD4 - 210 Nanuq Producer Abandonment February 25, 2011 Diesel (to be removed by rig) A p 16" Insulated Conductor to —114' J 2) 4 - x 3 -' /z" Vacuum insulated tubing (VIT) 2.813" X' TRMAXX SCSSSV 0 9 -5/8" 40 ppf L -80 BTCM Surface Casing A .'. , 2540' MD / 2400' TVD © X 4) 4 - %" x 3 -%" Vacuum insulated P, / : -•4'0•,<'c tubing (VIT) to +/- 4000' MD 4I, '0. $ :. +; / Upper Completion: Top MD TVD 1) Tubing Hanger 32' 32' 2) 4 -1/2" x 3'/2' VIT 3 -'/2' buttress -Mod connection 3) 3 -1/2" Camco TRMAXX SCSSSV w/ X profile 2094' 2000' Cut Tubing @ 4050' 4) 4 - 1/2" x 3-W VIT 3 -' /2' buttress -Mod connection 5) Crossover from VIT (3 -1/2' IBTM) to EUE -M tubing 4000' 3708' 6) 3-W 9.3 # /ft, EUE -M 7) Camco KBMG 1" GLM w/ dummy valve 4324' 4000' 8) 3- 9.3 # /ft, EUE -M 9) Camco KBMG 1" GLM w/ dummy valve 6700' 5989' 10) 3 -'W' 9.3 # /ft, EUE -M (2) 11) Baker Premier Packer 6780' 6031' 12) 3 -' /2' 9.3 # /ft, EUE -M (2) 13) HES "XN" (2.75" min ID) 6850' 6065' Corrosion inhibited 14) 3 - /2' 9.3 # /ft, EUE - M seawater 15) BOT Stinger with Fluted WLEG /pup /shear sub 7270' 6210' bottom, 3' spaceout @ 7308' Lower Completion: Top MD TVD 16) Baker 5" x 7" Flexlock Liner Hanger 7273' 6211' SA D 17) 3 9.3 #/ft L -80 SLHT Tubing D % y 18) 3-W 9.3 #/ft L -80 SLHT slotted liner w/ blank across shale 4610110111 T and slots across sand !� 19) Baker Shoe 13105' 6205' 15.8 ppg Class G cement • 3 -'/" 9.3#/ft L -80 SLHT Slotted liner Pattern: Planned top of cemen 0��� E 32 slots / ft 2 '/4' x 1/8" slots • 6480' MD / 5857' TVD ® 16 18 m •j � Top Reservoir at +/- • Nanuq 7199' MD / 6193' TVD TD 6 -1/8" hole 13115' MD / 6205' TVD 7" 26 ppf L -80 BTC Mod Production Casing @ +/ -83° 7423' MD, 6235' TVD • 110 Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill," 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: / /F: \Daily_Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE -D... 2/28/2011 • _~...,.~ ~,~ ~,, .~~ ~~ .~ ,~ „~.~ ~:` ~~~+. ~ ~. FILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc MICRO ~ ~ ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 J Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ci'+_~~o Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped March 18~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sinc Perry iuciii ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD4-301 B 207-180 SF NA 7" NA 2.55 3/18/2009 CD4-302 207-056 28" NA 28" NA 22.95 3/18/2009 CD4-304 207-132 8" NA 8" NA 1.70 3/18/2009 CD4-05 207-155 SF NA 7" NA 1.70 3/18/2009 CD4-306 207-094 SF NA 5" NA 1.70 3/18!2009 CD4-07 207-118 SF NA 6" NA 0.42 3/18/2009 CD4-208 205-162 SF NA 7" NA 1.27 3/18/2009 CD4-209 206-065 SF NA 6" NA 0.85 3/18/2009 CD4-210 206-077 SF NA 7" NA 1.27 3/18/2009 ~ CD4-211 ' 206-153 9" NA 9" NA 3.82 3/18/2009 CD4-214' 206-145 7" NA 7" NA 2.12 3/18/2009 CD4-215 ~ 206-157 5" NA 5" NA 2.55 3/18/2009 GD4-16 206-131 SF NA 5" NA 2.55 3/18/2009 C 4-17 206-118 SF NA 11" NA 1.27 3/18/2009 CD4-318A 206-113 7" NA 7" NA 1.70 3/18/2009 CD4-319 205-148 SF NA 7" NA 1.27 3/18/2009 CD4-320 206-055 6" NA 6" NA 0.85 3/18/2009 CD4-321' 206-142 SF NA 8" NA 1.70 3/18/2009 CD4-322 207-101 SF NA 5" NA 1.27 3/18/2009 3 ~ 1 w~ DATA SUBMITTAL COMPLIANCE REPORT 6/25/2008 Permit to Drill 2060770 Well Name/No. COLVILLE RIV NAN-N CD4-210 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20533-00-00 MD 11710 TVD 6217 Completion Date 6/30/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve~ Yes~~ DATA INFORMATION Types Electric or Other Log s Run: GR/Res, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 0 11710 Open 8/22/2006 14025 LIS Verification 0 0 Open 8/22/2006 I. ~ ED C Lis 14025 Induction/Resistivity 2513 11652 Open 8/22/2006 GR, ROP, FET, Res /5018 LIS Verification 2513 11710 Open 4/17/2007 LIS Veri, GR, FET, ROP "This Data replace previous' ED C 15856 Induction/Resistivity 114 6217 Case 1/31/2008 TVD and MD for ROP, DGR, EWR-Phase 4 in PDF, EMF and CGM graphics Well Cores/Samples Information: Name Interval Start Stop Sample Set Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? V N Chips Received? 'H'IS' Formation Tops ~/ N ./ Analysis Y / N Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 6/25/2008 Permit to Drill 2060770 Well Name/No. COLVILLE RIV NAN-N CD4-210 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20533-00-00 MD 11710 TVD 6217 ompletion pate 6/30/2006 Completion Status 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: _____ Date: _-~ ~~ WELL LOG TRANSMITTAL To: State of Alaska January 21, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-210 AK-MW-4443583 CD4-210• Digital Log Images: 50-103-20533-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 x. ~, -- '~ ~~ _; ~ - ,_~ ~~_ ~ Date: , ;, ~ , ~ i~~'!l~ Signed: 1 ,~,9 ~:, ~ ~6Cp - O~'~ ~ 155 ~ • WELL LOG TRANSMITTAL To: State of Alaska April 16, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-210, AK-MW-4443583 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD rom with verification listing. API#: 50-103-20533-00. Note: This data replaces any previous data for well CD4-210. G C~- ~ ~. ~ ~ ~ ~ d~ - ~~~ ., ~t~~~~ • -~ - SARAHPALIN, GO~/ERNOR 1~~77~-ay~~i --~stt~~r t~T ® 333 W. 7th AVENUE, SUITE 100 ~L~o~~4~~~~iis ~ ~''e~'~~~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska PO Box 100360 Anchorage, AK 99507 Re: Colville River Field, Alpine Oil Pool, CD4-210 Sundry Number: 306-372 Dear Mr. Alvord: Your Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well is denied. While the construction of CD4-210 was determined satisfactory, the differential equivalent mud weight ("EMW") between the formation integrity test of 18.0 pounds per gallon ("ppg") and the inflection point at 17.3 ppg on the subsequent pump-in test is small. Although steady pump-in was achieved at 14.8 ppg, the annulus of another well experienced difficulties pumping with similar EMWs. An additional pump-in test was performed and the determined inflection was 17.4 ppg, with steady pump-in at 16.8 ppg. Given the low differential EMW, it is not certain that the requirements of 20 AAC 25.080(e)(2) would be met during pumping operations in CD4-210. 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 d c'sion to Superior Court unless rehearing has been requested. ~ ,^ ~~„ Chairman DATED this day of January, 2007 Encl. Cv" (>~~` _. , .., STATE OF ALASKA ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 1. Operator 3. Permit to Drill Name: Number: 206-077 COnOCOPhIIIIpS Alaska 4. API Number: 50-103-20533- 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4- 0 6. Field: Colv' a River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulu . Nanuq 3, Nanuq 5, CD4-319, CD4-208, CD4-209, CD4-320 Torok and Seabee form on, shale, siltstone and sandstone CD4-17, CD4-214 (~M~~~=~~1~r~~3~®~~~-~~~5~ b) Waste receiving zone: b) water wells within one mile: ~ ~~~5 ~~ ~~~~ Sand layers below the 30 marker in the Seabee formation \ ihc~`:v~,~vc~~. vJ~~.~ None c) Confinement: ~`~S~ ` ~~ The Schrader B formation provides an upper barrier and marine shales and claystones ~/~ l of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1630' MD / 1600' TVD 0 ~~ None 11. Previous volume disposed in annulus and date: 12.fstim sl ry density. 13. Maximum anticipated pressure at shoe: None d sities range from diesel to 12#/gal 2233 PSI 14. Estimated volume to be disposed with this request: 1 ui is o d: 35,000 bbls. f may be drilling mud, drilling cuttings, reserve pit fluids, cement- nta d rilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: a t rilli g a well, drill rig wash fluids, domestic waste water, any added water 3-Nov-06 ne to cilitate pumping of drilling mud or drilling cuttings,`new product cleanup su has cement rinsate, and mud and brine pit rinse from mixing operations and an other fluids associated with drillin a well. 17. Attachments: Well Schematic (Include MD an D) Q Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Dat 0 Other 0 previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the for o' g is true and correct to the best of my knowledge. Jf y Signature: ~,/ Title: /~ (u ~~ ~ r'~ ~ I.e~/~ Printed Phone ] ( I t ~ (Y N N b Z um ame: Chip Alvord er: 265-6120 Date: ~9 G 1 Commission Use Only t i'~ - Conditions of approval: LOT review and approva-: ~~ Subsequent form required: Approval number: p~J / O~ dP ry r~r.S ~ 8 7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403RD Rev. 6/200 ~ I G, ~ ~ I ~ISTRUCTIONS ON REVERSE ~ Submit in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 ~ « ~ ~~~~~~~'"' ~ Telephone 907-276-1215 ~ November 15, 2006 Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD4-210 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD4-210 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD4-210 approximately November 30, 2006. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD2 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within % mile radius at AOGCC:CD4-209, CD4-320, CD4-214 12. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (17.3 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Vern Johnson at 265-6081; Chip Alvord can also be reached by calling 265-6120. Si rely, .-- ~ _ //~s~6 Vern Johnson Drilling Engineer cc: CD4-210 Well File Chip Alvord ATO-1700 Anadarko Sharon Allsup-Drake ATO-1530 Annulus Disposal Transmittal Form -Well 4-210 AOGCC Reeulations, 20 AAC 25.080 (b) 1 Desi nation of the well or wells to receive drillin wastes: CD4-210 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste maybe drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD 1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2233 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A d th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the. drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD4-211, CD4-16, CD4-215, CD4-207, CD4-205, CD4-213, will be enerated. CD4-212 CD4-203 CD4-204 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. • • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Well CD4-210 Assumptions Date 11/15/2006 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi 2,386 TVD Version L0 - Jan'OS Pburst85% - PHydrostatic +PApplied " PFormation 4,888 = ( 2,386 * 0.052 * MW,~,a,~ ) + 1500 - (0.4337 * 2,386 ) MWmax = 35.6 PPg Surface Casing Strin Size 9.625 in Weight 40 ppf Grade L 80 rburscloo°r° 5,750 Psi Pburst85% 4,888 psi Depth of Shoe 2,386 ft FIT/LOT @ Shoe 18 ppg or 2,233 psi FIT/LOT for Annulus 17.3 ppg Max Surf. Pressure 1,500 psi TOC Est. @ 6,480' MD 5,857 TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% - PHydrostatic +PApplied " PGasGradient " PHeader 4,599 = ( 5,857 * 0.052 * MWm~ )+ 1,500 - (0.0700 * 5,857) - 1,000 MW,,,ax = 14.8 PPg a.5 "Tubing 2nd Casing String Size 7 in ,6,235 TVD Weight 26 ppf Grade L 80 rcollapse100% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 5,857 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = ( 2,386 * .052 * 18 ) Pmax allowable = 2,233 psI This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". ~0~1~C ~~I~ ~ Casing Detail 9 5/8" Surface Casing Well: CD4 - 210 Date: 6/14/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 37.10 FMC Gen V Hanger 2.08 37.10 Jts 3 to 65 63 Jts 9 5/8" 40# L-80 MBTC Csg 2420.91 39.18 Weatherford Float Collar 1.41 2460.09 Jts 1 to 2 2 Jts 9 5/8" 40# L-80 MBTC Csg 75.89 2461.50 Ray Oil tools (Silver Bullet) 2.26 2537.39 2539.65 TD 12 1/4" Surface Hole 2550.00 12 1/4" Hole @2550 ' MD 12395' TVD 9 5/8" Shoe @ 2539.65' MD / 2386 'TVD RUN TOTAL 40 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #14 (stop ring on Jt #1 8~ 2 ) and over collars on jts# 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 59 61, 62, 63 68 joints in the pipe shed. Run 65 joints Last 3 joints stay out Use Best-o-Life 2000 i e do e MU torque ~ ft/Ibs Remarks: Up Wt - 160k Dn Wt - 145k Block Wt - 75k Supervisor. D. Lutrick/L. Hill Cement Detail Report CD4-210 Surface Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10137724 6/11/2006 6/11/2006 6/30/2006 `Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 6/14/2006 03:35 6/14/2006 05:25 CD4-210 Comment cement Sta es '-_ g - -- -- _- - - --- - _ _ _ _ - - - Sta e # 1 Description - - Objective _ -- - Top (ftK6) Bottom (ftKB) Full Return? _ Cmnt Rtm (... Top Plug? Btm Plug? Surface Casing Cement 0.0 2,540.0 Yes 65.0 Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 4 6 630.0 1,200.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Cement Fluids & Additives - !,Fluid - - - --- -- -- ' Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Gfass Volume Pumped (bbQ Lead Cement 0.0 2,040.0 323 256.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) 4.45 20.15 10.70 Additives Additive Type Concentration Conc Unit label 'Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,040.0 2,540.0 230 G 48.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description _ _ Estimated Top (ftK6) Est Btm (ftKB) Amount (sacks) Glass Volume Pumped (bbl) 1,890.0 1,890.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprSti' 1 (psi) Additives Additive Type Concentration Conc Unit label IStage # 2 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? No No No O (start) (bbl/min) O (end) (bbl/min) Q (avg) (bbllmin) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment - Cement Fluids 8 Additives _ _ -_ Fluid -- -- - _ _ _ -_ _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/6 Report Printed: 11/15/2006 Daily Drilling Report .. CD4-210 .. , , - Report Date: 6/14!2006 Report Number Days From Spud (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) Wellbore 4 3.10 2,550.0 2,550.0 0.00 CD4-210 Spud Date Contractor Rig NamelNo Field Name Well Type Target Depth (ftK6) 6/11/2006 DOYON 19 NANUO Development 13,115.0 AFE / RFE I Maint.# Total AFE Amount Average ROP (ft/hr) 10137724 5,469,157.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Surface, 2,540.OftK6 Ops and Depth ~ Morning Report Daily Cost Total Cummulative Cost Drilling shoe track. 333,418.40 1,023,132.03 24hr Forecast Daily Mud Cost Cummulative Mud Cost Finish picking up BHA. RIH to TOC. Cut drilling li ne. Drill 20' and FIT. Change out mud and Drill. 5,590.40 45,233.75 Last 24hr Summary Ran and cemented 9 5/8" casing. Tested casing. Nippled down riser. Made up speed head and nippled up BOP. Tested BOP. Picked up BHA. General Remarks Weather Head Count 40 Deg Wind NE @ 10 mph 47.0 - SUpervtSn- - ---- -- _ _ _ ---- - T~flp - - _ ___ ----- Dave Burley Rig Supervisor 1 Don Mickey Rig Supervisor ime o 9 _ _ r -- ~ r _ - -- s,a Fr,~ ' T~n~_ D_ntri sr.~n of ri Fns Tina TI-na n~~~~nr,i~ Gr,.~o nr.^~~~~. 'n.,, r-C~,n.:F-N-T ~,oicnrla ~ftKBl i ~hF,B~, cnrmvflneration 00:00 01:00 1.00 SURFAC CASING RNCS P 1,641.0 2,540.0 RIH w/ 9 5/8" csg from 1641' to 2500'. MU hanger and landing joint. Land csg at 2540'. 01:00 01:15 0.25 SURFAC CASING RURD P 2,540.0 2,540.0 RD Franks fill up tool. Blow down top drive. 01:15 01:30 0.25 SURFAC CASING RURD P 2,540.0 2,540.0 RU cement head and lines. 01:30 03:30 2.00 SURFAC CEMENT CIRC P 2,540.0 2,540.0 Circ and condition mud for cement job. Stage pumps up to 7 bpm at 300 psi. Pumped a total of 453 bbls. 03:30 05:30 2.00 SURFAC CEMENT DISP P 2,540.0 2,540.0 PJSM. Test lines to 2500 psi. Pump 40 bbls biozan / nutplug spacer. Drop bottom plug. Dowell pumped 50 bbls 10.5 mud push, 256 bbls of 10.7 lead and 49 bbls 15.8 tail. Dropped top plug. Pumped 20 bbls H2O and rig displaced with 167 bbls mud. Bumped plug. Floats OK. 05:30 06:30 1.00 SURFAC CASING DHEO P 2,540.0 2,540.0 Test csg to 2500 psi for 30 min. 06:30 07:30 1.00 SURFAC CASING RURD P 0.0 0.0 RD csg and circulating equipment. 07:30 08:30 1.00 SURFAC CASING NUND P 0.0 0.0 PJSM. ND surface riser. 08:30 09:45 1.25 SURFAC CASING NUND P 0.0 0.0 NU well head adapter assembly and test to 1000 psi. 09:45 11:30 1.75 SURFAC WELCTL NUND P 0.0 0.0 NU BOPE. Install mousehole. 11:30 16:30 5.00 SURFAC WELCTL BOPE P 0.0 0.0 Set test plug.Tested BOPE - Hydrill to 250 & 3500 psi -Test pipe rams, kill & choke lines, choke manifold valves, to 250 & 5000 psi -tested closing unit. 16:30 22:00 5.50 SURFAC WELCTL BOPE T Rig 0.0 0.0 Auto (BOP leaking -Attempt to test blind rams found leak on BOP to wellhead flange. Replaced (BOP and tightened flange. Tested blind rams and (BOP 250/5000 psi. Witiness of test waived by John Crisp AOGCC. 22:00 22:30 0.50 SURFAC DRILL RURD P 0.0 0.0 Pulled test plug and set wear bushing. Picked up bales. 22:30 00:00 1.50 SURFAC DRILL PULD P 0.0 90.0 Picked up bit and BHA. Upload MWD. Mud Check Data ___ - -- T _-_ °~[, rr H1HF Fait Den i ~ 1em~ h ~;o,^ YP Calc Gel C- ~ ~ i 10ni ~cl Type DeF.h ;fIY.E'; Parv_, kga. Vi_ isl~tj P/ r i_ ::r^) (Ibf1100R~) (Ibf uiRF; li ~„-:'i Ib 1 ~~ ~: MBT Qblbbi) „~ T L ~ninl pH i F'~ Water 2,550.0 9.75 72 24.0 20.000 4.000 30.000 32.000 27.5 9.0 8.5 Based Mud -~ In~ection Fluid - - - - -- - - ~-- ~1Jll~ .SOUfCe F rlll lea iht~l Jiti92tNfl _ N~ ~ Cementing Fluids 280.0 CD1-19 !SAME Recycled mud 1400.0 CD1-19 From CD4-210 -- _ ___ - Welibores Wellbore Name Wellbore API/UWI CD4-210 501032053300 Latest BOP Test Data Date C ,mme~nt 5/14/2006 (Tested BDP 250/5000 psi. Page 1/2 Report Printed: 10/10/200E Daily Drilling Report CD4-210 Section Size {in) Act Top {ftK6) Act Btm {ftK COND1 44 0.0 SURFAC 12 1 /4 114.0 INTRM1 8 3/4 2,550.0 PROD1 6 1 /8 7,480.0 ----_ - B': Start Date _ 114.0 6/11/2006 2,550.0 6/11/2006 7,480.0 6/15/2006 11, 710.0 6/21 /2006 Casing Strings _ _ - -- _ioG Ge_,,, ~~ption Run Daie OD (iel Wt (lbsfft~ ~ ~ade ;?t DeFt ,r:81 j --._. Report Date: 6/14/2006 Enu l ~ --a c- 6/11 /2006 6/15/2006 6/13/2006 6/26/2006 ~, orni;~crn. Surface 6/14/2006 9 5/8 40.00 L-80 2,540.0 Cement -- - - _- --- _ Surface Casio Cement -Started 6/14/2006 Type Wellbore String Cement Evaluation Results casing CD4-210 Surface, 2,540.OftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 0.0 2,540.0 4 630.0 .Fluid I ~ Class Amotiint {sacks) V (bbl) i3ensity (Iblgal) Yield (ft /sacF ~ Est T ",FI31 ~s? Btm (ftKB) Lead Cement 323 256.0 10.70 4.45 0.0 2,040.0 Tail Cement G 230 48.0 15.80 1.17 2,040.0 2,540.0 1,890.0 1,890.0 Stg No. Description Top (ftKB) Bottom (ftK6) Q (end) (bbl/... P (Foal) (psi) 2 Page 2/2 Report Printed: 10/10/2006 ' o ~ o ~ o tD N ~ O O '~ 0 0 0 0 O r N ~ '~ a ~ ~ ~ ~ aO+ d ~ 7 ~ c L O In lf) r ~ '~•' (n C N p r ~ ~ O E 7 m d +'' a ~ ~ o 0 0 0 0 ' i a ~ tZ y O Y In O i ~' d ~ C _ ~ O O ~ m 3 ~~~., " N ~ O y O ~ O •-- G 1 H O ~ O 7 Q , N ~ N L U c_ a °' m ~ E N o ~ in d ~ ~ Y ~ O (Q Y N a_ J J_ a V Z V ~~~ d7 ~~07~~~4)~Oa7 Y C1 V R 3 m L(')~t!') ~ ~CD~f~u700~0~0 p'a M ~ In CO I~ 00 O ~ ~ m °I`~INI cN., ' ' ~ ' N ~ , •N O - Q N ~ ~ ~ O C ~ O o c ~ ^ O N O Q~ ~ ~ Q•N ~ N O a ~ . y nJ JJ as ra ~ ~ p ~ ~n o o o o in ~•~ ~ ~ '~ ~ ~ N D ~ ~ ~ G1 ~ ~ ~ .C N L ~ ~ Vl 7 C ~ d '~ ~ .O ~~ ~ d • N ~• a~ ~ a~ ~ W H ~ ~ ~ E 7 E ~ to d a~~Oi E 7 O C a fnI a' a' a a ', a ~~ -o-~ °' ~~ + Q C O` , p ~ , ~ a, ~ O p .L O'~ ~ ~' ~ N •~ ~' ~ O M OO O p L ~ ~ U ~ Y p yi U W O N ~ G ~ ~m m o x 11 . _ = Q N J \ O O L y# ~ J ~ (q p o ~ ~•+ I L ~ ~ v ~ ~ ~ ~ . ~ ~O L ~ •'y t0 ~ ' ~n 0+ ~ ~ CO M J U o O u p ~ `~ N ~ w a ~ .~ ~ 9 .C ~ ' " ~ :A O_ J O_ J J ~ •~ ~ O J ~ / O O O Qj O N O 0 O 0 O 0 t G ~ ~ N ~ U - ~:. ' +' N <n N 0 O 0 S "8 O 3 ~ Q s ~ v ~ M t~ g N U `" .~ ~ Q C _ _ L N ~L ~ N D1 ~ L0 ~ 16 U C`'~ C •~ ~ ~ _ ._ d Q~ C N ~ ~ ~ 3 N _ .. ~ ~ U ~ ~ ~ ~ ~ O 'y I K ~ N m N j O d~> N d ~ W N d 00 N ~ in :_• p y ~ ~ O w Li. j~~ n v 0 0 O ~ ~j ~ Ci m U cYiW J Z ~ ~ N Y ~ ~ m II ._ ~, ~ d ~ •L o o = ~ Iw ~I r 0 0 0 0 Y ~ ~ ~ ~ R N N N N ~ m 7 ~ O H O 0'p m 0 I i i ii ~ I r Y I c ~ I ~,.i N N ~ °' o \ 0 0 ~ a r ~ M N N G~ 3 o N c +- a° o :_ ~, a 3 N _ v, t O N .°. ~ J O 0 C F O ~ O) W ~ ~ a LL ~ ~ .Q Q ~ J ~ N ~ O O O L ~ t6 N m O O) ~- U W ~ ~ ~ Z ~ ~ U ~ 0 0 0 0 0 0 0 o w ~ N O ~ O ~ ~ 3bnss3bd i • ~onocoPhilli $ Casing Detail 7" Casing Well: CD4-210 Date: 6/20/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.85 FMC Gen V Hanger 2.66 34.85 Jts 3 to 174 172 Jts 7 " 26# L-80 BTCM Csg 7342.71 37.51 Weatherford Float Collar 1.25 7380.22 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.46 7381.47 Ray Oil Tools Float Shoe 2.09 7467.93 7470.02 TD 8 3/4" Hole 7480.00 8 3/4" Hole TD @7480 ' MD /6236 ' TVD 7" Shoe @ 7470.02' MD / 6235' TVD Total Centralizers: 45 Straight blade centralizer one perjt on jts # 1-14 Straight blade centralizer one per jt jts. # 115,116, 117, Straight blade centralizer one per jt on every other joint Starting @ # 119 to # 172 Top Nanuq - 7180 ' MD - 6180' TVD 185 joints in shed - 174 total jts. to run Last 11 jts. out Use Run 8~ Seal i e do e Average MU torque 6500 ft/Ibs Remarks: Up Wt - 265k Dn Wt-185k Block Wt - 75k Supervisor.' D. Lutrick/ L. Hill ~ Cement Detail Report. CD4-210 Intermediate Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10137724 6/11/2006 6/11/2006 6/30/2006 -- _ - --- - -- - - Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 6/20/2006 00:34 6/20/2006 01:55 CD4-210 Comment ~ Cement Stages ' -__ ~ ~ - - -- _ -- Sta a#1 _____ _ Description Objective Top (ftKB) Bottom (ftK6) Full Return? Cmnt Rfm (... Top Plug? Btm Plug? Intermediate Casing Primary 6,480.0 7,470.0 Yes 0.0 Yes Yes Cement Q (start) (bbllmin) Q (end) (bbllmin) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 4 6 400.0 1,050.0 Yes 20.00 No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment _- ---- --- Cement Fluids S Additives Fluid -_ _-- Fluid Type Primary Cement Fluid Description ' Estimated Top (ftKB) 6,480.0 Est Btm (ftKB) 7,470.0 Amount (sacks) 200 Glass G Volume Pumped (bbl) 41.0 Yield (ft /sack) 1.17 Mix H2O Ratio (gal/sa... 5.17 Free Water (%) Density (Ib/gal) 15.80 Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/6 Report Printed: 11/15/2006 Daily Drilling Report C D4-210 ,..~ Report Date: 6/20/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 10 9.10 7,480.0 7,500.0 20.00 CD4-210 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 6/11/2006 DOYON 19 NANUO Development 13,115.0 AFE / RFE I Maint.# Total AFE Amount Average ROP (ft/hr) 10137724 5,469,157.00 69.0 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 7,470.OftK6 Ops and Depth ~ Morning Report Daily Cost Total Cummulative Cost POOH for GeoPilot 215,089.78 2,369,778.76 24hr Forecast Daily Mud Cost Cummulative Mud Cost Finish POOH -Change GP -RIH - Chnager over to Flo Pro -Drill 6 1/8" hole 6,540.78 199,398.48 Last 24hr Summary Circ & Cond. mud for cmt job - Cmt 7' csg CIP @ 0155 hrs. Test 7" csg - MU BHA # 4 - PU 4" DP -RIH -Drill ST- Drill 20' new hole to 7500' -Perform FIT to 12.5 ppg EMW - GP failure -POOH General Remarks Weather Head Count 44/41 WC/ NE @ 6 mph 50.0 Title Supernsor - ~ _ Dave Burley Rig Supervisor Don Mickey Rig Supervisor Time Loa - S~art End - ~, Time - Dep.h stmt Depth End - -- - Tine Time Dur {hrs ' F hse Gp ~~de GpSub-Code P-N-T Trb1 G,utle ^h:H; (ftKB) Cor r uperst:on 00:00 00:30 0.50 INTRM1 CEMENT CIRC P 7,470.0 7,470.0 Finish circulate and condition mud. Stage pumps to 6 born at 550 psi. 00:30 02:00 1.50 INTRM1 CEMENT DISP P 7,470.0 7;470.0 PJSM. Dowell pumped 5 bbls CW100. Test lines to 3700 psi. Pumped 25 bbls CW100 and 30 bbls 12.5 ppg mud push. Dropped bottom plug. Mix and pumped 41 bbls of 15.8 ppg cement.. Dropped top plug. Pumped 20 bbls H2O and displace with mud with rig pumps. Bumped plug. Checked floats. OK. 02:00 02:45 0.75 INTRM1 CASING DHEQ P 7,470.0 7,470.0 Test 7" csg to 3500 psi for 30 min. 02:45 03:30 0.75 INTRMI CASING RURD P 0.0 0.0 RD csg and circulating equipment. LD LJ. 03:30 04:30 1.00 INTRMI CASING OTHR P 0.0 0.0 Pull thin wear bushing. Install packoff and test to 5000 psi. 04:30 05:45 1.25 INTRMI WELCTL EQRP P 0.0 0.0 Change upper pipe rams from 7" to 3 1/2" x 6" varibles. Test rams to 5000 psi. 05:45 06:15 0.50 INTRM1 DRILL OTHR P 0.0 0.0 Pull test plug. Install short wear bushing. LD test jt. 06:15 06:30 0.25 INTRM1 DRILL RURD P 0.0 0.0 RU short bails and drill pipe elevators. 06:30 09:45 3.25 INTRMI DRILL PULD P 0.0 189.0 PU and MU BHA #4. Upload MWD. Shallow test MWD and GeoPilot at 189'. 09:45 14:30 4.75 INTRM1 DRILL PULD P 189.0 7,232.0 PU and RIH w/ 129 jts of 4" DP.to 4466' -RIH f/ derrick w/ DP to 7232' 14:30 15:00 0.50 INTRMI DRILL REAM P 7,232.0 7,370.0 Wash down f/ 7232' to 7370' (top of cmt) 15:00 21:30 6.50 INTRMI CEMENT DRLG P 7,370.0 7,500.0 Drill wiper plugs - FC - Cmt - FS -Drill 20' new hole to 7500' MD 6238' TVD - ADT .29 hrs. WOB 3/12 k RPM 60 GPM 200 String wt. PU 205 SO 135 Rot 165 Torque on/off btm. - 10,500/10,000 ft. Ibs "` Note Geo Pilot failure 21:30 22:00 0.50 INTRM1 DRILL CIRC P 7,500.0 7,500.0 Circ hole clean for FIT 22:00 23:00 1.00 INTRMI DRILL FIT P 7,500.0 7,500.0 RU & perform FIT to 12.5 ppg EMW - RD 23:00 00:00 1.00 PROD1 DRILL TRIP T BHA 7,500.0 7,041.0 Flow check (static) POOH on TT for GeoPilot ----- _ -- - - --- Mud Check Data _ _ _ . ---- Gel - _..- ~~ ._ YP Calc GeI (10s) ~ Cal rim) (3Grn) HT}iP Filt Den i y Temp S I -1< Co. f. T~se Depth (ftKB) Dens(Iblg~~V~ ,,qtj PV Cale~rp~ I Ibz%,.60ft~) (Ibt/100ft~) Qbf7100ff) ~ (bfllIXift°~ MBT I .~t-I, 4mU30minj 'i pH `Fl ~;~` - Water 7,470.0 9.80 40 9.0 14.000 6.000 8.000 9.000 18.0 9.4 8.5 Based Mud Latest BOP Test Data _ - -- - - - - _ T -- - - - Date ~ __ _ Comment 1 - _ - --- - -- - -- - _ ----- 6/14/2006 Tested B©P 250/5000 si. Page 1/2 Report Printed: 10/10/2006 Daily Drilling Report CD4-210 ,. Report Date: 6/20/2006 In'ection fluid - -- _ - G.wd r Erorn L a r~~h ~ : ,r D .otinasior Nste~ Diesel 60.0 Freeze Protect CD4-210 Water 300.0 Annular Flush CD4-210 Water Based Mud 1530.0 CD 1-19 f/ CD4-210 Water Based Mud 7.0 Annular LOT -CD4-210 ;Drill Strin s: BHA No. 4 - Steerable / Bit Run No. 4 - 6 1/bin, Halliburton SeCUri DBS , FS2553Z , 10823086' Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in~j Nozzles (!32") IADC Bit Dull String Wt (10001bf) WOB (max) {100... WOB (min) (1000... 7,480.0 7,500.0 1-1-NO-A-X-O-NO- DTF 8 0 0 Drill Strin Com onents J's _ Item Descnpfron OD fr~~ ID i~n~ Top Conn 5~ ~".n. - - Tap~hrea~ -hum Len frtt 1 Geo Pifot 4 3/4 1.500 3 1/2 NC 38 16.19 1 Drill Collar -Flex Non Mag 4 3/4 1.500 3 1/2 NC 38 27.73 1 Stabilizer (Non Mag) 4.76 1.500 3 1/2 NC 38 31.31 1 MWD DM HOC 4 3/4 1.500 3 1/2 NC 38 39.87 1 MWD GR/RES 4.73 1.500 3 1/2 NC 38 62.40 1 PWD 4.7 1.500 3 1/2 NC 38 73.26 1 MWD TM HOC 4.62 1.500 3 1/2 NC 38 84.44 1 Float Sub 4.66 2.313 3 1/2 NC 38 86.61 1 Stabilizer (Non Mag) 4 3/4 2.250 3 1/2 NC 38 92.13 1 NMDC 4.56 2.250 3 1/2 NC 38 123.13 1 NMDC 4.52 2.250 3 1/2 NC 38 154.28 1 XO Sub 4.8 2.563 4 XT 39 156.93 4 HWDP 4 2.563 4 XT 39 279.60 1 Drilling Jars - DNT 4 3/4 2.000 4 XT 39 311.93 2 HWDP 4 2.563 4 XT 39 373.28 Drillin Parameters - -_ _. _ _ D ink Ti r ~ ~ .gym hall t1 (flow) ~ I f r ht _ _ L Start ftKB) Enri iWr!B~ { ~ ~F - r~:,m f)e ch ft 7 p ( ~ ~ ds) lnt De th (tt (9Pm) WOB (ILfj { rcF t_ - p :. _._~ iy ivi (iyni) j SPP tpsij ~ Jr C 7,480.0 7.500 0 O ~ l G 20.00 0.2 , 20 00 ~ _ 200 12.0 60 - 1,200.0 10,500.0 - - Wellbores - Wellbore Name - - - Wellbore API/UWI - CD4-210 501032 053300 Section S z~ (m' COND1 44 SURFAC 12 1/4 tia T>p !ftKEs; Act Btrn jfiiCBi Star 0.0 114.0 6/11/2006 114.0 2,550.0 6/11/2006 G~~3;~ ~ Ertl Date 6/11/2006 6/15/2006 INTRMI 8 3/4 2,550.0 7 ,480.0 6/15/2006 6/13/2006 PROD1 6 1/8 7,480.0 11 - - - - -~- - ,710.0 6/21/2006 --- - --- 6/26/2006 - - - - Survey Data [.9D `t N':H1 In~l i`) Azm 1'~ - ND !YKBi VS ~, `' ~~ - - NS IfJ - EW (ftj ' D' S "'/i00fti - --.~ -. _ - -_ _ --- -----...- 7.401.16 85.76 3 _- - - -. _.. - - 01.00 6.235.43 1.321.68 - --_ - 4 ~ 5.03 _ y 2,296.08 11 _~7 j - - Casi ng Strin s g - _ -- - i _ 3 i pDe F'~~~ Hate 6D .;gym VJt (Ibs/ft~. _. txax S.:: Left :"KB) Comment '2020 Intermediate 6. 06 i 26 00 L 80 7.470.0 __ I - -- - _ Cement _ __ - --- intermediate Casin Cement -Started 6/20/2006 Type Wellbore String Cement Evaluation Results casing CD4-210 Intermediate, 7,470.OftKB Stg No. Description Top (ftKB) Bottom (ftK6) Q (end) (bbl/... P (final) (psi) 1 Intermediate Casing Cement 6,480.0 7,470.0 4 400.0 Ffuicl T Gass Amount (sacks} V (bbl) ~ i3ensity (Iblgal) Yield (fiN/sank) Est Tap {ftKB) Est Bim (ftKB) Primary Cement ~G I 200 41.0 15.80 1.17 6,480.0 7,470.0 Leak Off and Formation Integrity Tests Leap. ~ '. D~nS FWid ''t'~~ Last CasingStnngRun Dent^.i':K6) ~IblgaU Fwid P~.Sur`I!Fsii I DensF'~u-j{tb/Qa`j ~, P L~J!(psii No Intermediate, 7,470.OftKB ~ 7,470.0 9.90 WBM ~ 850.0 12.52 4,056.3 Page 2/2 Report Printed: 10/10/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alas c:--_ Well Name: CD4-210 Rig: Doyon 19 Date: 6/20/2006 Volilme Input Pum Rate: Drilling Supervisor: - Lutrick /Mickey Pump used: Cem t Unit _ ~ P i T f T ~ d ~ Barrels ~ Bbls/strk ~ 0.80 Bbl/min ~ ~ ~ ype o est: Annulus Leak Off Test for Disposal Adequacy ump ng own annulus. Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe Depth Hole Depth Pumpin Shut-in Pumpin Shut-in RKB-CHF: 34.7 Ft 2540.0 Ft-MD 2386.0 Ft-TVD 6480.0 Ft-MD 5857.0 Ft-TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ ~ 0 0 50 0.00 61 1 Chan es for Annular Ade uac Test Pressure Int e rit Test 1 0.5 174 0.25 520 Enter outer casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 284 0.50 493 Casing description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 405 1.00 479 Hole Size is that drilled below outer casing. 4 2 519 1.50 473 Use estimated TOC for Hole Depth. 5 2.5 627 2.00 ~' Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 6 3 733 2.50 <1 ___ _ Estimates for Test: 645 psi 0.4 bbls 7 3.5 839 3.00 460 ~ ~ 8 4 929 3.50 454 ___ _ _ EMW =Leak-off Pressure + Mud Weight = 929 + 9 8 _ _ ---- PIT 15 Second 9 4.5 692 4.00 453 0.052 x TVD 0.052 x 2386 Shut-in Pressure, si 10 5 658 4.50 453 EMW at 2540 Ft-MD (2386 Ft-ND) = 17.3 520 15 5.5 630 5.00 449 iooo - - 20 6 630 5.50 447 25 6.5 620 6.00 447 30 7 620 6.50 444 _.. 7.00 444 - 7.50 440 - - 8 00 439 . w '~ 8.50 439 ~ - ~ - -- 9.00 435 soo -- - -- ~ ~ 9.50 433 N w - ~ 10.00 433 ~ -- a -- 0 o ~ z s a s s ~ s o s , o , s z o z s s o ~~ CASING TEST Barrel s t LEAK-O FF TEST S hut-I O P n tim IT Poin e, M t inute s Volume PUm ed Volume Bled Back Volume PUm ed Volume Bled Back s s s s Comments: 9 518" shoe LOT @ 18.0 ppg VLIY-L I V /11111UIG1 LV I Summary OC1t?CU~~"l1~~1~t ~~s~a CD4-210 W~~.~~~~-~~ iFn«,rr oxe~et a,.we::.... ~ n'!' 02/~/ /~• .~. G C Su~'ve t PQ..~~ CD4-210 ~ CD4-208 (CD4-2081 I Quarter Mile (1320 feet) radius plot SURFACE CASING SHOE SEPARATION FROM CD4-210 CD4-210 x ~ Y Surface Casing Shoe ASP 4 Coordinates NAD 27: 377547.421 5956963.174 ells Nanuk 1 Nanuk 2 Details @ AOGCC** n n Ann. Disp. Permit # ermit Date ource well Ann. Vol. tart Date nd Date i n from Object well* Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surf LOT (ppg) Surface casing TVD (ft) Annular LOT (ppg) omments Exploration P&A'd Exploration P&A'd Nanu 3 1128 376499.69 5957381.96 11.8 1781 Ex loration Nanu 5 1062 378326.61 5956241.68 14.9 2393 15.1 Not for annular dis osal CD2-319 305-373 12/9/2005 CD4-208, CD4318, CD4-209, CD4-320 32000 12/14/2005 7/2/2006 1231 377174.72 5955790.42 18.4 2400 16.1 CD4-208 306-183 5/30/2006 CD4-318a, CD4-320, CD4-214, CD4-321 58495 7/3/2006 10/31/2006 611 378134.16 5956792.74 16.3 2439 14.4 volume extension to 70000 bbl, ermit#306-266 CD4-318 306-181 5/26/2006 CD4-209, CD4-320 457 5/31/2006 7/2/2006 1554 376138.41 5956308.25 18.2 2375 17.1 Unable to um - SD um in CD4-209 536 377934.93 5957333.86 14.7 2377 17.5 Not for annular dis osal CD4-210 0 377547.421 5956963.174 18.0 2386 17.3 CD4-320 1199 377914.23 5958105.03 17.1 2378 17.8 Not for annular dis osal CD4-17 1160 376416.34 5957221.03 18.1 2387 16.2 CD4-321 1752 375795.55 5956945.42 18.0 2385 16.3 CD4-214 907 377040.88 5956962.79 18.2 2365 17.6 Not for annular dis osal * Lateral distance in feet, between surface casing shoes, in the X-Y plane ** As of Nov. 14, 2006 Note that this sheet is not the definitive record for annular disposal volumes ~_~ • Note to File CD4-210 (206-077...306-372) Colville River Unit (CD4 Alpine) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends denial of ConocoPhillips' request. While review of the submitted information indicated that CD4-210 was satisfactorily constructed, the differential EMW between the formation integrity test (18.0 ppg) and the inflection point on subsequent pump-in (17.3 ppg) is small. Steady pump-in is at 14.8 EMW, however another wells annulus experienced difficulties pumping with similar EMWs. An additional pump-in test was performed and the determined inflection EMW was 17.4 ppg with steady pump-in at 16.8 EMW. Given the low differential EMW, it is not certain that the requirement of 20 AAC 25.080 (e)(2) [...downhole disposal pressure may not exceed that determined by the formation integrity test...] can. be met during pumping operations. Based on examination of the submitted request for the subject well be denied. Tom Maunder, PE Sr. Petroleum Engineer January 4, 2007 information, I recommend ConocoPhillips' G:\common\tommaunder\Well Information\By Subject\Annular Disposal\070104--CD4-210.doc PRESSURE INTEGRITY TEST CONOCOPHILLIPS AI Inc. Well Name: CD4-210 Rig: Doyon 19 Date: 11 /25/2006 Drilling Supervisor: D. Burley / L Hill Pump used: Cement Unit ~ olume Input Pump Rate: Barrels ~ Bbls/Strk ~ 0.5 Bbl/min ~ ~ Type Of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ asin Test Pressure In te ri Tes1 Hole Size: 8-3/4" ~ Casin Shoe Depth Hole De th Pum pin Shut-in Pumpin Shut-in RKB-CHF: 34.7 Ft 2,540 Ft-MD 2,386 Ft-TV 6,480 Ft-MD 5,857 Ft-TVD Bbls psi Min psi Bbls psi Min psi CBSInq Slze and DeSCrlptlOn: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 500 0 1206 Chan es for Annula r Ade u ac Tes Pressure Int e ri Tes 1 1 1 510 0.25 1095 outer casing shoe test result in comments Mud Weight: 7.0 ppg 2 2 530 0.5 1040 Description references oute casing string Inner casing OD 7.0 In. 3 3 550 1 1030 ize is that drilled below oute casing. 4 4 581 1.5 999 timated TOC for Hole Depth 5 5 611 2 974 Enter inner casing OD at righ Desired PIT EMW: 16.0 ppg 6 6 641 2.5 954 Estimates for Test: 1117 psi 0.8 bbls 7 7 671 3 936 . j ~, ~ 8 8 702 3.5 914 EMW =Leak-off Pressure + Mud Weight = ~ 1287 PIT 15 Second 9 9 742 4 904 + 7 0.052 x TVD 0.052 x 2386 Shut-in Pressure, psi 10 10 803 4.5 893 EMW at 2540 Ft-MD (2386 Ft-TVD) = 17.4 1095 15 11 873 5 s7s - ,soo - 20 12 949 5.5 868 - ~ 25 13 1015 6 858 _ _ ,-_ _ - _~ ~~ ~ 30 14 1075 6.5 848 __ ' ~ 1(~ ~ „ ~ ~ _ __ 15 1136 7 843 .--~ C i --~ L~ _ ~ 16 1211 7.5 833 ' ~, ~ i 17 1262 8 823 w ~ ~; 17.5 1287 8.5 818 ~ - - - -- - _~ ---- - 18 1242 9 813 ~ ~ - -~'` ~~j 18.5 1227 9.5 803 ~ ~ ~ ~ 19 1227 10 798 w - - ~ 19 5 1227 a -- - i . soo - - 20 1222 - - _ 20.5 1216 i -- ~ 21 1216 - - --- - 1 - ~ ~ I -- - ~ - - -- r ~ -~ -- ~ 0 s ,o ,a zo zs o s ,o ,s zo zs so o Barrels Shut-In time, Minutes OFF TEST O PIT Point t T ~~LEAK Vol PUm ume ed Vol Bled ume Back Vol Pu ume m ed Vol Bled ume Back - CASING TES S S S S omments: 9 5/8" shoe test = 18.0 ppg EMV~ 7 ppg mud weitght includes a weighted average to account for freshwater and diesel fluid column .J RE: CD4-17 AD Request • ~ Subject: RE: CD4-17 AD Request From: "Johnson, Very" <Vern.Johnson@conocophillips.com> Date: Wed, 22 Nov 2006 12:38:50 -0900 To: "1~homas Maunder <tom maunder(i;admin.state-.ak.us=- Tom, In addition to our discussion this morning, please see my answers below. 1. In general, the distance is from a 2-D calculation based on the global x/y locations of the surface casing shoes. This works well for the bulk of the wells because almost all the shoes are at very similar TVD. The. equation is less applicable for Nanuq 3 due to the difference in TVD, so the X-Y location used for Nanuq 3 is the wellbore X-Y at 2400 ft TVD, this is ± 529' TVD below the shoe. 2. I searched for an annular LOT plot for Nanuq 3 but I was not able to find one. The well was drilled by the exploration group in 2001, and they may not have considered annular disposal as an option at that time. 3. Estimated TOC for the second stage on CD4-17 was ± 5575' MD / 3833' TVD. As discussed, we will arrange to have the annulus on CD4-210 tested again in the next several days. Let me know if you have any questions. ~ ~ ~ ~ ~~ Vern Johnson -----Original Message----- From: Thomas Maunder (mailto:tom maunder:~admin.state.ak.us] Sent: Tuesday, November 21, 2006 3:15 PM To: Johnson, Vern Subject: CD4-17 AD Request Vern, I am looking at the AD request for CD4-17 and have a couple of questions. According to the proximity plot, Nanuq 3 is fairly close to CD4-17. A distance of 181 feet is given in the spreadsheet page. 1. Is this the distance separating the wellbores at the surface shoe of Nanuq 3 or CD4-17? Would you please clarify the distance separating the wellbores at the respective surface casing shoes? 2. No pressure/EMW is given for the annular LOT on Nanuq 3. Is any such information available? 3. Do you have a TOC estimate for the 2nd stage job on the 7" casing? Thanks in advance for your reply. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 11/27/2006 10:30 AM Latest AD applications • • Subject: Latest AD applications From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 22 Nov 2006 12:09:16 -0900 '['o: Vca~l Johnson <=Vei-n.Johnsonrci?conocophilli7~s.com:. CC: ChiE~ ~111ord ° ~Chii~.Alvord~<<conocoi~hillips.com=, Vern, Thanks for the discussion this morning regarding the latest applications for AD at CD-4. As we discussed, it does not appear that the application for CD4-17 can be approved due to the uncemented section of the production casing annulus in Nanuq 3 lieing only about 180' away. ~--~t 2 CJ Co -°~~~ On CD4-210 we discussed the comment regarding the delta between initial leakoff and pump in EMWs made in the letter submitted with the volume increase request for CD4-208. In order to provide further clarification, it may be appropriate to conduct a new pump in on CD4-210. Please look at the information you have for that well to make your determination regarding a new pump in. That decision is solely CPAI's Good luck. I am sure we will talk further. Tom Maunder, PE AOGCC 1 of 1 11/27/2006 10:30 AM ~i ConocoPhillips September 12, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 • G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 SEP 1 3 2006 Alaska Qi18c has Cons. Co-nmission Anchorage Subject: Well Completion Report for CD4-210 (APD 206-077) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine wells CD4-210. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, .~ ~~~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad S STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION COMMISSION ~E~EIVEC~ S E P 1 3 2006 WELL COMPLETION OR RECOMPLETION REPOI~~k~l~~©~sll Commission 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other_ 1b. Well Class: AnChOrage Development ^/ Exploratory I^I Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or,4band.: June 30, 2006 12. Permit to Drill Number: 206-077 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 11, 2006 ~ 13. API Number: 50-103-20533-00 4a. Location of Well (Governmental Section): Surface: 2928' FNL, 245' FEL, Sec. 24, T11 N, R4E, UM . 7. Date TD Reached: June 26, 2006 ~ 14. Well Name and Number: CD4-210 ' At Top Productive Horizon: 1621' FSL, 2391' FEL, Sec. 24, T11 N, R4E, UM 8. KB Elevation (ft): 37' RKB 15. Field/Pool(s): Colville River Field Total Depth: 400' FSL, 903' FWL, Sec. 13, T11 N, R4E, UM 9. Plug Back Depth (MD + ND): 11710' MD / 6217' TVD Nanuq Oil Pool , 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377999 y- 5957484 ~ Zone- 4 10. Total Depth (MD + ND): .11710' MD / 6217' TVD 16. Property Designation: ADL 380077, 380075 TPI: x- 375841 y- 5956788 Zone- 4 Total Depth: x- 373922 - 5960879 Zone- 4 11. Depth where SSSV set: SSSV @ 2112' 17. Land Use Permit: ALK 380077 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1377' MD 21. Logs Run: GR/Res/Dens/Neutron 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 68# H-40 37' 114' 37' 114' 42" Portland Type III 9.625" 40# L-80 37' 2540' 37' 2386' 12.25" 323 sx AS Lite, 23o sx Class G 7" 26# L-80 37' 7470' 37' 6235' 8.75" 200 sx Class G 3.5" 9.3# L-80 7187' 11210' 6182' 6243' 6.125" slotted liner 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" x 3.5" 4012' / 7202' 6746' slotted liner from 7263' - 11208' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production August 28, 2006 Method of Operation (Flowing, gas lift, etc.) flowback Date of Test 8/28/2006 Hours Tested flowback Production for Test Period --> OIL-BBL not available GAS-MCF WATER-BBL CHOKE SIZE not available GAS-OIL RATIO not avail Flow Tubing press. psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL 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". ~~ S ~F~, CEP ~ ~ 2006 -~~Y NONE V£ !I';EO Form 10-407 Revised 12/2003 ~ ~ ~ ~ ~ N A L CONTINUED ON REVERSE ~ ~. ~~ ,pd `~ft`t iG q~j~~ ~ 2s. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD4-210 K-3 4152' 3840' K-2 4418' 4090' Nanuq Sand 7178' 6180' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, MIT 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name,/~ Q /~7C"~Alvo~rd Title: Alpine Drillino Team Leader ~ I ~L ~ oG * Signature ~c}.C-. f> /~ Phone Z (~ ~ ., (p ~ Z ~ Date INSTRUCTIONS 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. Prepared by Sharon Allsup-Drake Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Carnocc Phiii s ~ Ti m p me Log Sum ary ', Weltview 1:'eU RepvriJng '~, Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 06/11/2006 08:00 13:00 5.00 0 0 MIRU MOVE RURD P Moved rig to CD4-210 and rigged up. 13:00 15:15 2.25 0 0 MIRU MOVE RGRP P Nippled up riser and flowline. 15:15 17:30 2.25 0 114 MIRU DRILL PULD P Made up bit on HWDP and tested lines to 3500 psi. RIH and cleaned Ice out of Conductor to 114'. POOH. Chan ed lift sub on 'ars. 17:30 19:00 1.50 114 114 COND1 DRILL PULD T Picked up Mud motor and attempted to set angle without success. Laid down motor and picked up backup motor. 19:00 21:30 2.50 114 114 COND1 DRILL PULD P Adjusted moror angle to 1.83 Deg. Picked up BHA. Held Pre Spud while u loadin MWD. 21:30 00:00 2.50 114 254 SURFA DRILL DDRL P Drill 12 1/4" hole f/ 114' to 254' MD 254' TVD ADT - .95 hrs =ART - .95 hrs AST - 0.0 hrs WOB 5/10 RPM 50 GPM 450 @ 800 psi String wt. PU 90 SO 90 Rot 90 Torque on/off btm. -5000/4000 ft/Ibs 1 G ro surve . 06/12/2006 00:00 12:00 12.00 254 796 SURFA DRILL DDRL P Drill 12 1/4" hole f/ 254' to 796' MD 796' TVD ADT - 7.05 hrs =ART - 4.55 hrs AST - 2.5 hrs WOB 10/25 RPM 55 GPM 550 @ 1430 psi String wt. PU 115 SO 112 Rot 115 Torque on/off btm. -4500/3500 ft/Ibs Ran gyro suryeys @ 170', 261', 350', 442, 478, 533', 722', 713' 12:00 00:00 12.00 796 1,932 SURFA DRILL DDRL P Drill 12 1/4" hole f/ 796' to 1,932' MD 1,850' TVD ADT - 6.12 hrs =ART - 3.84 hrs AST - 2.88 hrs WOB 10/33 RPM 70 GPM 610 @ 2000 psi String wt. PU 130 SO 125 Rot 130 Torque on/off btm. -7000/6000 ft/Ibs Ran gyro suryeys @ 774', 803', 897', 991, 1086'. rage 1 ~t 11 ~ Time Logs Da e From To Dur S. th E. De th Phase Code Subcode T M 06/13/2006 00:00 07:30 7.50 1,932 2,550 SURFA DRILL DDRL P Drill 12 1/4" hole f/ 1932' to 2550' MD 2395' TVD ADT - 5.86 hrs =ART - 4.85 hrs AST - 1.01 hrs WOB 20/35 RPM 55 GPM 650 @ 2390 psi String wt. PU 143 SO 130 Rot 140 Tor ue on/off btm. 8000/6000 ft/Ibs 07:30 08:30 1.00 2,550 2,550 SURFA DRILL CIRC P CBU. 650 GPM 2160 psi. 08:30 11:00 2.50 2,550 890 SURFA DRILL WPRT P Back reamed out to 890' with 550 GPM 55 RPM. 11:00 12:15 1.25 890 2,550 SURFA DRILL WPRT P RIH and washed to 2,550'. 12:15 13:30 1.25 2,550 2,550 SURFA DRILL CIRC P Circulated and conditioned hole. 650 GPM 2160 si. 13:30 16:30 3.00 2,550 164 SURFA DRILL TRIP P POOH from 2550' to 164'. 16:30 19:00 2.50 164 0 SURFA DRILL PULD P Laid down BHA. 19:00 21:00 2.00 0 0 SURFA CASIN( RURD P Rigged up to run 9 5/8" casing. PJSM. 21:00 23:30 2.50 0 1,641 SURFA CASIN( RNCS P Ran 43 Jts 9 5/8" 40# L-80 BTC casing to 1641'. 23:30 00:00 0.50 1,641 1,641 SURFA CASIN( CIRC P Circulated casing volume + 10 Bbls @ 4 BPM. 06/14/2006 00:00 01:00 1.00 1,641 2,540 SURFA CASIN( RNCS P RIH w/ 9 5/8" csg from 1641' to 2500'. MU hanger and landing joint. Land csg at 2540'. 01:00 01:15 0.25 2,540 2,540 SURFA CASIN( RURD P RD Franks fill up tool. Blow down top drive. 01:15 01:30 0.25 2,540 2,540 SURFA CASIN( RURD P RU cement head and lines. 01:30 03:30 2.00 2,540 2,540 SURFA CEME~ CIRC P Circ and condition mud for cement job. Stage pumps up to 7 bpm at 300 psi. Pum ed a total of 453 bbls. 03:30 05:30 2.00 2,540 2,540 SURFA CEME~ DISP P PJSM. Test lines to 2500 psi. Pump 40 bbls biozan / nutplug spacer. Drop bottom plug. Dowell pumped 50 bbls 10.5 mud push, 256 bbls of 10.7 lead and 49 bbls 15.8 tail. Dropped top plug. Pumped 20 bbls H2O and rig displaced with 167 bbls mud. Bumped lu .Floats OK. 05:30 06:30 1.00 2,540 2,540 SURFA CASIN( DHEQ P Test csg to 2500 psi for 30 min. 06:30 07:30 1.00 0 0 SURFA CASIN( RURD P RD csg and circulating equipment. 07:30 08:30 1.00 0 0 SURFA CASIN( NUND P PJSM. ND surface riser. 08:30 09:45 1.25 0 0 SURFA CASIN( NUND P NU well head adapter assembly and test to 1000 si. 09:45 11:30 1.75 0 0 SURFA WELCT NUND P NU BOPE. Install mousehole. Pag~ot11 Time Logs ~__ _ Date From To Dur ~ th E. De th Phase Code Subcode T OM 06/14/2006 11:30 16:30 5.00 0 0 SURFA WELCT BOPE P Set test plug.Tested BOPE - Hydrill to 250 & 3500 psi -Test pipe rams, kill & choke lines, choke manifold valves, to 250 & 5000 si -tested closin unit. 16:30 22:00 5.50 0 0 SURFA WELCT BOPE T Auto IBOP leaking -Attempt to test blind rams found leak on BOP to wellhead flange. Replaced IBOP and tightened flange. Tested blind rams and IBOP 250/5000 psi. Witiness of test waived b John Cris AOGCC. 22:00 22:30 0.50 0 0 SURFA DRILL KURD P Pulled test plug and set wear bushing. Picked u bales. 22:30 00:00 1.50 0 90 SURFA DRILL PULD P Picked up bit and BHA. Upload MWD. 06/15/2006 00:00 01:30 1.50 90 385 SURFA DRILL PULD P Upload MWD. PU 3 flex collars, HWDP and jars to 385'. Test Geospan unit to 3000 psi. Shallow test MWD and Geo ilot. 01:30 02:45 1.25 385 2,350 SURFA DRILL TRIP P RIH w/ 5" and 4" DP to 2350'. 02:45 04:15 1.50 2,350 2,350 SURFA RIGMN SVRG P Cut and slip drilling line. Service top drive and ri . 04:15 07:15 3.00 2,350 2,550 SURFA CEMEI~ DRLG P Cleaned out to float collar and drilled shoe track. 07:15 07:45 0.50 2,550 2,570 SURFA DRILL DDRL P Drill 8 3/4" hole f/ 2550' to 2570' MD 2400' TVD ADT - .30 hrs WOB 2/5 RPM 60 GPM 567 @ 1740 psi String wt. PU 145 SO 120 Rot 130 Tor ue on/off btm. 8000/6000 ft/Ibs 07:45 08:15 0.50 2,570 2,570 SURFA DRILL CIRC P CBU. 08:15 09:00 0.75 2,570 2,570 SURFA CEME~ FIT P Pertormed FIT to 18 PPG EMW. 09:00 09:30 0.50 2,570 2,570 INTRM1 DRILL CIRC P Displaced to new mud system. 09:30 12:00 2.50 2,570 2,732 INTRM1 DRILL DDRL P Drill 8 3/4" hole f/ 2570' to 2732' MD 2551' TVD ADT - 1.53 hrs WOB 3/10 RPM 120 GPM 575 @ 1330 psi String wt. PU 148 SO 122 Rot 135 Torque on/off btm. 7500/7000 ft/Ibs ECD 10 12:00 00:00 12.00 2,732 3,969 INTRM1 DRILL DDRL P Drill 8 3/4" hole f/ 2732' to 3969' MD 3670' TVD ADT - 7.67 hrs WOB 8/13 RPM 120 GPM 620 @ 2250 psi String wt. PU 165 SO 130 Rot 140 Torque on/off btm. 8000/6000 ft/Ibs ECD 10.2 - 11.1 06/16/2006 00:00 12:00 12.00 3,969 5,168 INTRM1 DRILL DDRL P Drill 8 3/4" hole f/ 3969' to 5168' MD 4772' TVD ADT - 9.07 hrs WOB 10k/15k RPM 150 GPM 626 @ 2560 psi String wt. PU 192 SO 144 Rot 165 Torque on/off btm. 10,000/8500 fUlbs ECD 10.6 - 11.2 Time Logs Date From To Dur th E. De th Phase Code Subcode T M 06/16/2006 1.2:00 19:00 7.00 5,168 5,911 INTRM1 DRILL DDRL P Drill 8 3/4" hole f/ 5168' to 5911' MD 5435' TVD ADT - 5.51 hrs WOB 25k/30k RPM 80 GPM 500 @ 1900 psi String wt. PU 205 SO 148 Rot 170 Torque on/off btm. 11,000/9000 ft/Ibs ECD 10.6- 11.2 19:00 20:00 1.00 5,911 5,911 INTRM1 DRILL CIRC T CBU @ 600 gpm 2480 psi. 20:00 00:00 4.00 5,911 1,972 INTRM1 DRILL TRIP T Checked well POOH on trip tank from 5911' to 1972'. 06/17/2006 00:00 01:00 1.00 1,972 170 INTRM1 DRILL TRIP T POH on trip tank from 1972' to 721'. Check flow. OK. POH w/ HWDP and 'ars. to 170'. 01:00 02:30 1.50 170 0 INTRM1 DRILL PULD T Stand back DC's. LD MWD, GeoPilot and bit. 02:30 04:45 2.25 0 172 INTRM1 DRILL PULD T MU bit, motor and MWD. Orient motor. Shallow test MWD at 172'. OK. function tested BOP . 04:45 07:45 3.00 172 5,829 INTRM1 DRILL TRIP T RIH w/ HWDP, jars, 5" and 4" DP from 172' to 5829'. Fill i e eve 2000'. 07:45 08:00 0.25 5,829 5,911 INTRM1 DRILL REAM T Break circ. Wash and ream from 5829' to 5911'. 08:00 08:45 0.75 5,911 5,911 INTRM1 DRILL CIRC T CBU 08:45 12:00 3.25 5,911 5,992 INTRM1 DRILL DDRL P Drill 8 3/4" hole f/ 5911' to 5992' MD 5504' TVD ADT - 1.71 hrs ART - .08 hrs AST - 1.73 hrs WOB 3k/10k RPM 0/80 GPM 600 @ 2620 psi String wt. PU 200 SO 160 Rot 180 Torque on/off btm. 9,000/8000 ft/Ibs ECD 10.1 12:00 00:00 12.00 5,992 6,546 INTRM1 DRILL DDRL P Drill 8 3/4" hole f/ 5992' to 6546' MD 5909' TVD ADT - 8.56 hrs ART - 1.13 hrs AST - 7.43 hrs WOB 8k/12k RPM 0/80 GPM 600 @ 2950 psi String wt. PU 190 SO 165 Rot 175 Torque on/off btm. 9,000/7000 fUlbs ECD 10.3 06/18/2006 00:00 12:00 12.00 6,546 7,128 INTRM1 DRILL DDRL P Drill 8 3/4" hole f/ 6546' to 7128' MD 6166' TVD ADT - 8.1 hrs ART - 2.71 hrs AST - 5.39 hrs WOB 8k/12k RPM 0/80 GPM 600 @ 2950 psi String wt. PU 190 SO 160 Rot 180 Torque on/off btm. 9,500/8,500 ft/Ibs ECD 10.4 _ ~~ ~ ~~ Pie ~ ofi 1 ~ Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 06/18/2006 12:00 18:30 6.50 7,128 7,480 INTRM1 DRILL DDRL P Drill 8 3/4" hole f/ 7128' to 7480' MD 6234' TVD ADT - 4.53 hrs ART - .98 hrs AST - 3.55 hrs WOB 8k/12k RPM 0180 GPM 600 @ 3040 psi String wt. PU 192 SO 157 Rot 175 Torque on/off btm. 9,500/8,000 ft/Ibs ECD 10.4. 18:30 20:00 1.50 7,480 7,309 INTRM1 DRILL CIRC P CBU X 2. Stood bak 1 stand each 30 min. 630 GPM 3050 si. 20:00 22:30 2.50 7,309 5,877 INTRM1 DRILL WPRT P POOH back reaming from 7309' to 5877'. 500 GPM 60 RPM 1940 si. 22:30 23:00 0.50 5,877 7,480 INTRM1 DRILL WPRT P Flow check. RIH to 7480'. 23:00 00:00 1.00 7,480 7,309 INTRM1 DRILL CIRC P CBU X 2. Stood back 1 stand each 30 min. 630 GPM 3300 si. 06/19/2006 00:00 00:45 0.75 7,309 7,480 INTRM1 DRILL CIRC P Finish circ 2X bottoms up at 630 gpm - 3150 psi - 80 rpms. Stood back 1 std every 20 min. RIH to 7480' Spot WBS and lub ills to bit. 00:45 02:00 1.25 7,480 6,546 INTRM1 DRILL TRIP P Check flow.OK. POH spotting WBS and lub pills to 6546'. Check flow. OK. Blow down to drive. 02:00 06:30 4.50 6,546 1,973 INTRM1 DRILL TRIP P POH on trip tank from 6546' to 1973'. Check flow at shoe. OK. No hole roblems. 06:30 07:00 0.50 1,973 1,973 INTRM1 DRILL RURD P Change all handling equipment over to 5". 07:00 08:45 1.75 1,973 170 INTRM1 DRILL TRIP P Continue POH w/ 5" DP, HWDP and 'ars. 08:45 10:30 1.75 170 0 INTRM1 DRILL PULD P Download MWD. LD BHA #3. 10:30 13:30 3.00 0 0 INTRM1 CASIN( NUND P Pulled wear bushing and set test plug. Changed rams from VBR to 7". Tested rams 5000 psi. Pulled test plug and installed thin wear bushin . 13:30 14:30 1.00 0 0 INTRM1 CASIN( RURD P Rigged up to run 7" casing. 14:30 17:30 3.00 0 2,565 INTRM1 CASIN( RNCS P Ran 60 Jts 7" 26# L-80 BTCM casing to 2565'. 17:30 18:00 0.50 2,565 2,565 INTRM1 CASIN( CIRC P Circulated casing volume + 10 Bbls @ 5 BPM 350 si. 18:00 20:00 2.00 2,565 5,122 INTRM1 CASIN( RNCS P Ran 60 Jts 7" 26# L-80 BTCM casing to 5122'. 20:00 20:30 0.50 5,122 5,122 INTRM1 CASIN( CIRC P CBU @ 5 to 6 BPM 610 psi. 20:30 23:00 2.50 5,122 7,470 INTRM1 CASIN( RNCS P Ran 54 Jts 7" 26# L-80 BTCM casing to 7432'. Made up landing Jt. and landed casing @ 7470'. Laid down Franks tool and made up cement head. 23:00 00:00 1.00 7,470 7,470 INTRMI CEMEI~ CIRC P Circulated 2 - 5 BPM 590 psi. 06/20/2006 00:00 00:30 0.50 7,470 7,470 INTRM1 CEME-~ CIRC P Finish circulate and condition mud. Sta a um s to 6 bom at 550 si. ~~~~ 5 ~f 11 Time Logs Date From To Dur .. th E. De th Phase Code Subcode T OM 06/20/2006 00:30 02:00 1.50 7,470 7,470 INTRM1 CEMEh DISP P PJSM. Dowell pumped 5 bbls CW100. Test lines to 3700 psi. Pumped 25 bbls CW100 and 30 bbls 12.5 ppg mud push. Dropped bottom plug. Mix and pumped 41 bbls of 15.8 ppg cement.. Dropped top plug. Pumped 20 bbls H2O and displace with mud with rig pumps. Bumped plug. Checked floats. OK. 02:00 02:45 0.75 7,470 7,470 INTRM1 CASIN( DHEQ P Test 7" csg to 3500 psi for 30 min. 02:45 03:30 0.75 0 0 INTRM1 CASIN( RURD P RD csg and circulating equipment. LD LJ. 03:30 04:30 1.00 0 0 INTRM1 CASIN( OTHR P Pull thin wear bushing. Install packoff and test to 5000 si. 04:30 05:45 1.25 0 0 INTRM1 WELCT EQRP P Change upper pipe rams from 7" to 3 1/2" x 6" varibles. Test rams to 5000 si. 05:45 06:15 0.50 0 0 INTRM1 DRILL OTHR P Pull test plug. Install short wear bushin . LD test 't. 06:15 06:30 0.25 0 0 INTRM1 DRILL RURD P RU short bails and drill pipe elevators. 06:30 09:45 3.25 0 189 INTRM1 DRILL PULD P PU and MU BHA #4. Upload MWD. Shallow test MWD and GeoPilot at 189'. 09:45 14:30 4.75 189 7,232 INTRM1 DRILL PULD P PU and RIH w/ 129 jts of 4" DP.to 4466' - RIH f/ derrick w/ DP to 7232' 14:30 15:00 0.50 7,232 7,370 INTRM1 DRILL REAM P Wash down f/ 7232' to 7370' (top of cmt 15:00 21:30 6.50 7,370 7,500 INTRM1 CEMEI~ DRLG P Drill wiper plugs - FC - Cmt - FS -Drill 20' new hole to 7500' MD 6238' TVD - ADT .29 hrs. WOB 3/12 k RPM 60 GPM 200 String wt. PU 205 SO 135 Rot 165 Torque on/off btm. - 10,500/10,000 ft. Ibs "Note Geo Pilot failure 21:30 22:00 0.50 7,500 7,500 INTRM1 DRILL CIRC P Circ hole clean for FIT 22:00 23:00 1.00 7,500 7,500 INTRM1 DRILL FIT P RU & perform FIT to 12.5 ppg EMW - RD 23:00 00:00 1.00 7,500 7,041 PROD1 DRILL TRIP T Flow check (static) POOH on TT for GeoPilot 06/21/2006 00:00 01:45 1.75 7,041 4,562 PROD1 DRILL TRIP T POH on trip tank from 7041' to 4562'. Hole not taking proper fill. Monitor well. Static. 01:45 02:15 0.50 4,562 5,516 PROD1 DRILL TRIP T RIH to 5516'. 02:15 03:30 1.25 5,516 5,516 PROD1 DRILL CIRC T CBU. No gas or influx at bottoms up. Monitor well. Static. 03:30 09:15 5.75 5,516 219 PROD1 DRILL CIRC T POH on trip tank from 5516' to 219'. Monitor well at 751'. Static. 09:15 10:15 1.00 219 0 PROD1 DRILL PULD T Stand back 1 std DC's. LD stab, GeoPilot and bit. -_._ . ~,.~ s P~~ 6 01 '11 Time Logs ~ Date From To Dur th E. De th Phase Code Subcode T --- GM 06/21/2006 10:15 12:00 1.75 0 188 PROD1 DRILL PULD T PU new GeoPilot. MU BHA #5. Upload MWD. Shallow test MWD and GeoPilot at 188'. 12:00 16:30 4.50 188 7,423 PROD1 DRILL TRIP T RIH f/ 188' to 7423' 16:30 18:00 1.50 7,423 7,423 PROD1 RIGMN SVRG P Cut & slip drill line -Service TD 18:00 18:30 0.50 7,423 7,507 PROD1 DRILL REAM P Wash down f/ 7423' to 7500' -Drill 6 1/8" hole f/ 7500' to 7507' -ADT- .2 hrs. 18:30 20:00 1.50 7,507 7,507 PROD1 DRILL CIRC P Change well over f/ LSND mud to 9.2 ppg FloPro - 200 gpm @ 1380 psi w/ 60 rpm -Shut down /Flow check well - Static 20:00 00:00 4.00 7,507 7,680 PROD1 DRILL DDRL P Drill 6 1/8" horiz. section f/ 7507' to 7680' MD - 6243' TVD ADT - 3.0 Hrs. ECD - 10.44 ppg WOB8/10K RPM 90 GPM 212@ 1500 psi String wt. - PU 180 SO 148 Rot 162 Tor ue on/off btm. - 8500/7000 ft./Ibs. 06/22/2006 00:00 12:00 12.00 7,680 8,228 PROD1 DRILL DDRL P Drill 6 1/8" horiz. section f/ 7680' to 8228' MD - 6250' TVD ADT - 9.6 Hrs. ECD - 10.65 ppg WOB 8/ 13 K RPM 90/130 GPM 211 @ 1740 psi String wt. - PU 180 SO 145 Rot 164 Tor ue on/off btm. - 9000/7500 ft./Ibs. 12:00 00:00 12.00 8,228 8,889 PROD1 DRILL DDRL P Drill 6 1/8" horiz. section f/ 8228' to 8889' MD 6236' TVD ADT - 10.40 hrs. ECD - 10.67 ppg WOB 8/12 K RPM 140 GPM 212 @ 1620 psi String wt. PU 185 SO 140 Rot 163 Tor ue on/off btm. - 9500/8500 ft/Ibs 06/23/2006 00:00 12:00 12.00 8,889 9,521 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole f/ 8889' to 9521' MD 6243' TVD ADT - 10.45 hrs. ECD - 10.86 ppg WOB 9/12 K RPM 120 GPM 210 @ 1800 psi String wt. PU 187 SO 135 Rot 160 Torque on/off btm. - 10,000/8,000 ft. lbs. 12:00 00:00 12.00 9,521 10,282 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole f/ 9521' to 10,282' MD 6238' TVD ADT - 10.05 hrs. ECD 11.14 ppg WOB 9/12 K RPM 140 GPM 210 @ 1910 psi String wt. PU 190 SO 130 Rot 160 Torque on/off btm. - 11,000/9,000 ft. lbs. ~° ~~e T of 11 Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 06/24/2006 00:00 12:00 _ 12.00 10,282 10,620 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole f/ 10,282' to 10,620' MD 6231' TVD ADT - 10.16 hrs. ECD 10.7 ppg WOB 9/14 K RPM 140/110 GPM 210 @ 1880 psi String wt. PU 195 SO 125 Rot 160 Torque on/off btm. - 10,500/9,000 ft. lbs. 12:00 13:00 1.00 10,620 11,226 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole f/ 10,620' to 11,226' MD 6243' TVD ADT 10.44 hrs. ECD - 10.59 ppg WOB 10/13 K RPM 110 GPM 212 @ 1840 psi String wt. PU 205 SO 116 Rot 160 Tor ue on/off btm. - 12000/10500 ft Ibs 06/25/2006 00:00 12:00 12.00 11,226 11,370 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole f/ 11,226'to 11,370' MD 6236' TVD ADT 10.1 hrs. ECD - 10.6 ppg WOB 12/14 K RPM 110/120 GPM 220 @ 2010 psi String wt. PU 205 SO 120 Rot 160 Tor ue on/off btm. - 11500/10500 ft Ibs 12:00 00:00 12.00 11,370 11,574 PROD1 DRILL DDRL P Dril6 1/8" horiz. hole f/ 11,370'to 11,574' MD 6228' TVD ADT - 11.10 hrs. ECD - 10.56 ppg WOB 16/18 K RPM 100 GPM 220 @ 1900 psi String wt. PU 205 SO 115 Rot 160 Torque on/off btm. - 11,500/10,000 ft. lbs. 06/26/2006 00:00 08:45 8.75 11,574 11,710 PROD1 DRILL DDRL P Dril 6 1/8" horiz. hole f/ 11,74' to 11,710' MD 6217' TVD ADT - 8.34 hrs. ECD - 10.55 ppg WOB 12/16 K RPM 100 GPM 220 @ 1970 psi String wt. PU 205 SO 115 Rot 160 Torque on/off btm. - 11,500/10,000 ft. lbs. 08:45 12:00 3.25 11,710 11,333 PROD1 DRILL CIRC P CBU at 220 gpm at 1750 psi and 100 rpms. Monitor well. Mud was aired up and had small flow out annulus. CBU to condition mud. Set back 1 std every 30 min. f/ 11,710'to 11,333' 12:00 14:00 2.00 11,333 11,233 PROD1 DRILL CIRC P Flow check -slight flow - Wt. up to 9.5 ppg -Pumping 220 gpm @ 1830 pis w/ 70 r m -Std back f/ 11, 333' to 11,233' 14:00 22:00 8.00 11,233 7,423 PROD1 DRILL TRIP P Flow check (static) POOH w/ pump f/ 11,233' to 7423' - 180 gpm @ 1190 psi w/ 80 rpm " dro ed hallow drift 7804' 22:00 23:00 1.00 7,423 7,423 PROD1 DRILL CIRC P Flow check (static) -Circ btms up @ 7423' - 220 gpm @ 1590 psi -flow check static 23:00 00:00 1.00 7,423 6,945 PROD1 DRILL TRIP P Continue POOH w/ pump @ 126 gpm 600 si f/ 7423' to 6945' age E of 11 Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 06/27/2006 00:00 06:45 6.75 6,945 2,185 PROD1 DRILL TRIP P POOH w/ pump from 6,945' to 2,185' - 3 bpm 1480 - 400 psi, flow check well static. 06:45 09:30 2.75 2,185 375 PROD1 DRILL TRIP P POOH on trip tank from 2185' to 375' - flow check well, static. 09:30 10:00 0.50 375 90 PROD1 DRILL PULD P Handle BHA -Std back HWDP & jars - LD NM flex DC's - XO -stab & Float sub 10:00 12:00 2.00 90 0 PROD1 DRILL PULD P Down load MWD -Pull up & break bit - service Geo Pilot - LD MWD &Geo Pilot 12:00 13:00 1.00 0 0 PROD1 CASIN( OTHR P Clean up floor - RU to run 3 1/2" liner - Held PJSM 13:00 18:00 5.00 0 3,946 PROD1 CASIN( RUNL P Run 3 1/2" 9.3 # L-80 SLHT Blank & Slotted liner 126 'ts. to 3946' 18:00 19:00 1.00 3,946 3,946 PROD1 CASIN( OTHR P PU & MU liner hanger -Mix & spot pal mix in settin tool 19:00 21:00 2.00 3,946 7,456 PROD1 CASIN( RUNL P RIH w/ 3 1/2" liner on 4" DP to 7456' - PU wt. 155 SO 135 21:00 21:30 0.50 7,456 7,456 PROD1 CASIN( CIRC P Circ DP vol. 3 BPM @ 250 psi - 5 K for ue 10 RPM 21:30 23:00 1.50 7,456 11,080 PROD1 CASIN( RUNL P Continue RIH w/ 3 1/2" liner on 4" DP f/ 7456' to 11,080' - 23:00 00:00 1.00 11,080 11,210 PROD1 CASIN( OTHR P Establish Circ-Wash down f! 11,080' to 11,175' -Drop liner setting ball - PU next std & run liner to setting depth @ 11,210' -Circ & pump down setting ball @ 2 BPM - PU wt. 200 SO wt. 140 06/28/2006 00:00 01:00 1.00 11,210 7,157 PROD1 CASIN( OTHR P Set liner hanger with 4200 psi -anchor test hanger with 70K SOW -release from liner with Shoe @ 11,210', Top of Liner @ 7187' -Circ BU 4.5 bpm / 570 si -flow check well, static 01:00 02:30 1.50 7,157 7,157 PROD1 CASIN( CIRC P Displace casing to 9.5 ppg KCL brine from 7,157' - 4.5 bpm / 520-340 psi - flow check well, static. 02:30 08:00 5.50 7,157 0 PROD1 CASIN( OTHR P POOH -Lay down Baker running tools 08:00 09:00 1.00 0 0 COMPZ RPCOh OTHR P Pull wear bushing -Clear floor of e ui ment and tools 09:00 11:30 2.50 0 0 COMPZ RPCOh OTHR P Move VI tubing jewelry omto rig floor - RU to run 3 1/2" completion -spot Control lines ooler 11:30 12:00 0.50 0 0 COMPZ RPCOh SFTY P Held Pre-job Safety and Opts meeting for runnin Lower Com letion F'c~ oaf Time Lo s Date From To Dur th E. De th Phase Code Subcode T OM 06/28/2006 12:00 17:30 5.50 0 3,167 COMPZ RPCOh RCST P Run Completion as follows: Baker Shear indicating WLEG assembly w/ fluted No-Go - Pup jt - 11 jts. 3 1/2" 9.3# EUE mod tbg - XN nipple - 2 jts. 3 1/2" 9.3# EUE mod tbg -Baker Premier packer - 2 jts 3 1/2" 9.3# EUE mod tbg -Camco KBMG GLM w/ dummy - 75 jts 3 1/2" 9.3# EUE mod tbg -Camco KBMG GLM w/dummy - 9 jts. 9.3# EUE mod tbg - to 3167' (99 'ts tb total 17:30 17:45 0.25 3,167 3,167 COMPZ RPCOh SFTY P Held PJ safety & Ops. meeting for runnin VIT & hardwear 17:45 23:30 5.75 3,167 5,057 COMPZ RPCOh RCST P Continue running completion - XO 3 1/2" EUE x 3 1/2" IBT - 60 jts. 3 1/2" x 4 1/2" IBT VIT w/ insulator sleeve & Cannon clam s to 5057' 23:30 00:00 0.50 5,057 5,057 COMPZ RPCOti RCST P PU Camco TRMAXX -5E -SSSV - MU control line * Note -Spoke with AOGCC Lou Grimaldi concerning BOPE test prior to runnin com letion 06/29/2006 00:00 00:45 0.75 5,057 5,057 COMPZ RPCOh PULD P Complete MU of SSSV -pressure test valve and controle line to 5000 si 00:45 07:00 6.25 5,057 7,125 COMPZ RPCOh RCST P Continue to PU and RIH with 3 1/2" x 4 1/2" IBT VIT w/ insulator sleeve & Cannon clamps to 7,125' (total of 125 'ts VI tb 07:00 09:15 2.25 7,125 7,202 COMPZ RPCOh HOSO P Locate liner top -observed pins shear @ 10K - LD 2 locating joints - PU space out pup - mu 3 1/2" IBT X 4 1/2" IBTM XO, 10' pup -FMC tubing hanger and LJa -run single control line thru hanger - MU and test tie in to 5000 psi - Land hanger in wellhead with tail @ 7,202' -Equipment Tops - XN nipple 6,825' -Premier Pkr. 6,746' -GLM 6,657' -GLM 4,308' -SSSV 2,112' - Spaced out Locator sub 4' above Top of Liner. 09:15 11:15 2.00 0 0 COMPZ RPCOCL OTHR P RILDS - LD LJa -Install TWC -MU LJb - RU and test hanger seals -Top M/M seal leakin 11:15 16:15 5.00 0 0 COMPZ RPCOh OTHR T LD LJb -Pull TWC - MU LJa -pull hanger to rig floor -remove control line from hanger -change out hanger -Tie in control line and test fittings to 5000 psi -test full control line to 6000 psi - MU LJa -land hanger -RILDS - LD LJa - Install TWC - MU LJb - RU and test hanger seals -both upper and lower seals leakin ~. - P~~ ~~ ofi ~~ Time Lo s Date From To Dur th E. De th Phase Code Subcode T OM 06/29/2006 16:15 19:00 2.75 0 0 COMPZ RPCOh OTHR T LD LJ B -Pull TWC - MU LJ A -pull hanger to floor -Remove control line - Change out hanger (# 3) Hook up control line & test fittings to 5000 psi - test line to 5100 psi -Land tbg - RILNS -LDLJA-SetTWC-MULJB-Test seals to 5000 si - LD LJ B 19:00 20:30 1.50 0 0 COMPZ RPCOh P ND BOPE -Change out junk sub 20:30 22:00 1.50 0 0 COMPZ RPCOti P Termitate control line through wellhead - NU tree 06/30/2006 00:00 01:00 1.00 0 0 COMPZ RPCOh OTHR P RU FMC lubricator -test lubricator and tree to 5000 psi -pull TWC - RD FMC lubricator 01:00 03:00 2.00 0 0 COMPZ RPCOb CIRC P RU circulating manifold and hardlines to wellhead -Line up to Dowell -Test lines to 3500 psi -Displaced well with 100 bbls of 9.6 ppg brine followed by 105 bbls of diesel. 03:00 03:30 0.50 0 0 COMPZ RPCOh PACK P RU lubricator -drop setting ball/rod - RD lubricator 03:30 05:30 2.00 0 0 COMPZ RPCOh DHEQ P Test lines to 5000 psi -set packer with 4793 psi -tested tubing for 30 minutes final pressure 4417 psi -bled tubing down to 1200 psi -test 3 1 /2" X 7" annulus to 3518 psi for 30 minutes, final ressure 3396 si. 05:30 08:30 3.00 0 0 COMPZ RPCOh OTHR P Blow down lines - RD circulating manifold and hardpipe - RU FMC lubricator, test to 2500 psi -Install BPV (900 psi sitp) - RD FMC lubricator - Secure wellhead -install mousehole 08:30 13:00 4.50 0 0 COMPZ RPCOti OTHR P LD 4" drill pipe from derrick for rig move 146 'ts 13:00 14:00 1.00 0 0 COMPZ RPCOh OTHR P LD mousehole -position 6" collars in derrick for move -clear tools from rig floor released rig to Well CD4-320 at 1400 hours. Page 11 cf 91 • Halliburton Company, Survey Report Company: ConocoPhillips Alaska Inc. Uate: 7/12/2006 Time: 10:04:01 Page: 1 Field: Colville River Unit Co-ordinatc(NE) Reference: Well: CD4-210, True North . Site: Alpine CD4 Ve rtical {TVD) Re ference: CD4-210: 37.2 Well: CD4-210 Sec tion (VS) Refer ence: Well (O.OON,QOOE,314.11Azi) Wellpath: CD4-210 Survey Calculation 1Vlethod: Minimum Curvature ~ Db: Oracle Field: Colville River Unit North Slope Alaska ~ United States i Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Coordinate System: Well Centre Geomagnetic Model: bggm2005 ~ Well: CD4-210 Slot Name: Alpine CD4 Well Position: +N/-S -45.21 ft Northing: 5957483.73 ft ' Latitude: 70 17 32.521 N +E/-W -174.54 ft Easti ng : 377999.46 ft Longitude: 150 59 15.850 W i I "Position Uncertainty: 0.00 ft ii - - Wellpath: CD4-210 - -- Drilled From: - Well Ref. Point -~ 501032053300 Tie-on Depth: 18.20 ft ', Current Datum: CD4-210: Height 37.20 ft Above System Datum: Mean Sea Level Magnetic Data: ~~~ Field Strength: 6/11/2005 57493 nT Declination: Mag Dip Angl 23.67 deg e: 80.61 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction I ft -_-- - ft ft ----- deg --~ 18.20 0.00 0.00 314.11 Survey Program for Definitive Wellpath Date: 6/29/2005 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft --- .~ 37.20 1086.00 CD4-210 gyro (37.20-1086.00) CB-GYRO-SS Camera based gyro sin gle shot 1125.53 11672.88 CD4-210 ( 1125.53-1 1672.88) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC i Survey X111 Incl Azim TVD Sys'I'~'D N/S E/~'i' MapV MapE Tool ft deg deg ft ft ft ft ft ft 18.20 0.00 0.00 18.20 -19.00 0.00 0.00 5957483.73 377999.46 __ TIE LINE 37.20 0.00 0.00 37.20 0.00 0.00 0.00 5957483.73 377999.46 CB-GYRO-SS ~, 78.00 0.40 336.00 78.00 40.80 0.13 -0.06 5957483.86 377999.40 CB-GYRO-SS 170.00 0.50 356.00 170.00 132.80 0.82 -0.22 5957484.56 377999.26 CB-GYRO-SS 261.00 0.50 346.00 260.99 223.79 1.61 -0.34 5957485.34 377999.15 CB-GYRO-SS I 350.00 0.50 334.00 349.99 312.79 2.33 -0.60 5957486.07 377998.89 CB-GYRO-SS ~ 442.00 0.75 346.00 441.98 404.78 3.28 -0.93 5957487.02 377998.59 CB-GYRO-SS j 478.00 0.90 356.00 477.98 440.78 3.79 -1.00 5957487.53 377998.52 CB-GYRO-SS ~ 533.00 0.25 92.00 532.98 495.78 4.21 -0.91 5957487.96 377998.62 CB-GYRO-SS 622.00 1.10 175.00 621.97 584.77 3.36 -0.64 5957487.10 377998.87 CB-GYRO-SS 713.00 2.00 184.00 712.94 675.74 0.90 -0.68 5957484.64 377998.80 CB-GYRO-SS 774.00 4.00 201.00 773.85 736.65 -2.15 -1.52 5957481.61 377997.91 CB-GYRO-SS i 803.00 5.00 206.00 802.76 765.56 -4.23 -2.43 5957479.54 377996.96 CB-GYRO-SS t 897.00 8.20 208.00 896.13 858.93 -13.83 -7.38 5957470.02 377991.86 CB-GYRO-SS ~~ 991.00 13.70 i 218.00 988.39 951.19 -28.53 -17.39 5957455.48 377981.62 CB-GYRO-SS 1086.00 16.10 220.00 1080.19 1042.99 -47.49 -32.78 5957436.78 377965.92 CB-GYRO-SS it 1125.53 16.98 220.81 1118.08 1080.88 -56.06 -40.08 5957428.33 377958.48 MWD+IFR-AK-CAZ-SC 1220.30 20.98 222.42 1207.68 1170.48 -79.07 -60.57 5957405.66 377937.62 MWD+IFR-AK-CAZ-SC ~~ 1315.59 24.38 225.62 1295.59 1258.39 -105.43 -86.15 5957379.73 377911.62 MWD+IFR-AK-CAZ-SC 1411.13 25.32 226.76 1382.29 1345.09 -133.21 -115.12 5957352.41 377882.20 MWD+IFR-AK-CAZ-SC ', 1506.01 25.68 227.44 1467.93 1430.73 -161.02 -145.05 5957325.10 377851.83 MWD+IFR-AK-CAZ-SC 1601.22 25.41 219.45 1553.85 1516.65 -190.75 -173.23 5957295.83 377823.17 MWD+IFR-AK-CAZ-SC ~~ 1696.58 26.34 216.46 1639.66 1602.46 -223.57 -198.80 5957263.44 377797.07 MWD+IFR-AK-CAZ-SC 1791.53 27.02 217.39 1724.50 1687.30 -257.65 -224.42 5957229.78 377770.91 MWD+IFR-AK-CAZ-SC 1886.69 25.40 219.61 1809.87 1772.67 -290.55 -250.56 5957197.31 377744.24 MWD+IFR-AK-CAZ-SC 1981.78 25.67 220.58 1895.67 1858.47 -321.90 -276.96 5957166.39 377717.34 MWD+IFR-AK-CAZ-SC ~~ 2076.78 25.47 220.49 1981.37 1944.17 -353.06 -303.61 5957135.67 377690.19 MWD+IFR-AK-CAZ-SC ~ 2171.84 25.64 220.94 2067.13 2029.93 -384.14 -330.35 5957105.03 377662.94 MWD+IFR-AK-CAZ-SC 2267.33 28.51 219.09 2152.15 2114.95 -417.45 -358.27 5957072.19 377634.49 MWD+IFR-AK-CAZ-SC Halliburton Company! Survey Report Company: ConocoPhillips Alaska Inc. Date: 7/12/2006 Time: 10:04:01 Page: 2 Field: Colville Rive r Unit Co-ordinate (NE) Reference: WeII: CD4-210, True North Site: Alpine CD4 Verti cal (TV D) Reference: CD4-210: 37.2 Well: CD4-21 0 Section (VS) Reference: WeII (O.OON,O.OOE,314.11Azi) Wellpath: CD4-21 0 Survey Calculati on Method: Minimum Curva ture bb: Oracle S w-~ ey __ _ __ ___ ', JID Incl Azim TVD Svc TVD N!S E/W hlapN MapE Tool ', ft deg de g ft ft ft ft ft __-- ft _ ___ 2362.67 31. 32 216 .91 2234 .78 2197. 58 -454 .93 -387. 50 5957035 .19 377604.66 MWD+IFR-AK-CAZ-SC 2457.95 31. 35 217 .42 2316 .16 2278. 96 -494 .41 -417. 44 5956996 .20 377574.09 MWD+IFR-AK-CAZ-SC 2499.60 31. 34 218 .17 2351 .73 2314. 53 -511 .53 -430. 71 5956979 .30 377560.54 MWD+IFR-AK-CAZ-SC 2606.36 30. 91 217 .50 2443 .13 2405. 93 -555 .12 -464. 57 5956936 .27 377525.99 MWD+IFR-AK-CAZ-SC 2701.82 30. 62 217 .58 2525 .15 2487. 95 -593 .83 -494. 32 5956898 .05 377495.61 MWD+IFR-AK-CAZ-SC 2796.70 29. 72 217 .62 2607 .18 2569. 98 -631 .61 -523. 41 5956860 .75 377465.91 MWD+IFR-AK-CAZ-SC 2891.46 28. 78 218 .25 2689. 86 2652. 66 -668 .13 -551. 87 5956824 .70 377436.86 MWD+IFR-AK-CAZ-SC ~ 2986.37 27. 65 217 .95 2773. 49 2736. 29 -703 .44 -579. 56 5956789 .84 377408.61 MWD+IFR-AK-CAZ-SC '; 3081.92 26. 57 218 .00 2858. 54 2821. 34 -737 .77 -606. 35 5956755 .96 377381.27 MWD+IFR-AK-CAZ-SC 3177.39 25. 78 217 .59 2944. 22 2907. 02 -771 .04 -632. 16 5956723 .11 377354.92 MWD+IFR-AK-CAZ-SC 3272.64 24. 83 217 .91 3030. 33 2993. 13 -803 .23 -657. 09 5956691 .33 377329.48 MWD+IFR-AK-CAZ-SC 3368.48 23. 86 218 .56 3117. 64 3080. 44 -834 .27 -681. 53 5956660 .70 377304.53 MWD+IFR-AK-CAZ-SC 3463.98 23. 43 218 .46 3205. 13 3167. 93 -864 .24 -705. 38 5956631 .12 377280.20 MWD+IFR-AK-CAZ-SC ~, 3559.09 23. 49 220 .32 3292. 37 3255. 17 -893 .50 -729. 41 5956602 .26 377255.71 MWD+IFR-AK-CAZ-SC li 3654.36 23. 39 224 .22 3379. 79 3342. 59 -921 .53 -754. 88 5956574 .65 377229.78 MWD+IFR-AK-CAZ-SC 3749.49 22. 65 224 .19 3467. 34 3430. 14 -948 .20 -780. 82 5956548 .41 377203.42 MWD+IFR-AK-CAZ-SC 3845.25 22. 99 223 .34 3555. 61 3518. 41 -975 .02 -806. 51 5956522 .01 377177.30 MWD+IFR-AK-CAZ-SC ~ 3940.60 22. 48 223 .17 3643. 55 3606. 35 -1001 .86 -831. 76 5956495 .59 377151.62 MWD+IFR-AK-CAZ-SC II 4035.97 21. 43 224 .50 3732 .00 3694. 80 -1027 .58 -856. 45 5956470 .27 377126.52 MWD+IFR-AK-CAZ-SC 4131.37 20. 44 222 .97 3821. 10 3783. 90 -1052 .20 -880. 02 5956446 .04 377102.56 MWD+IFR-AK-CAZ-SC 4227.12 20. 29 223 .63 3910 .87 3873. 67 -1076 .45 -902. 87 5956422 .16 377079.32 MWD+IFR-AK-CAZ-SC II 4322.51 19. 87 224 .42 4000 .46 3963. 26 -1100 .00 -925. 63 5956398 .99 377056.18 MWD+IFR-AK-CAZ-SC I~ 4418.04 20. 08 224 .62 4090 .24 4053. 04 -1123 .27 -948. 51 5956376 .09 377032.93 MWD+IFR-AK-CAZ-SC 4513.28 19. 79 222 .84 4179 .78 4142. 58 -1146 .73 -970. 96 5956353 .00 377010.10 MWD+IFR-AK-CAZ-SC i~ 4608.72 20. 97 221 .58 4269 .24 4232. 04 -1171 .35 -993. 28 5956328 .75 376987.39 MWD+IFR-AK-CAZ-SC I 4704.30 22. 43 222 .95 4358 .05 4320. 85 -1197 .49 -1017. 05 5956303 .00 376963.19 MWD+IFR-AK-CAZ-SC ~ 4799.25 24. 00 223 .57 4445 .31 4408. 11 -1224 .74 -1042. 71 5956276 .17 376937.10 MWD+IFR-AK-CAZ-SC 4894.62 25. 81 225 .35 4531 .80 4494. 60 -1253 .39 -1070. 85 5956247 .99 376908.50 MWD+IFR-AK-CAZ-SC 4989.92 27. 85 225 .57 4616 .84 4579. 64 -1283 .56 -1101. 51 5956218 .32 376877.36 MWD+IFR-AK-CAZ-SC i 5085.41 29. 89 227 .30 4700 .46 4663. 26 -1315 .31 -1134. 92 5956187 .12 376843.44 MWD+IFR-AK-CAZ-SC I 5180.82 30. 10 229 .66 4783 .09 4745. 89 -1346 .92 -1170. 63 5956156 .10 376807.22 MWD+IFR-AK-CAZ-SC 5275.47 28. 81 235 .57 4865 .53 4828. 33 -1375 .19 -1207. 54 5956128 .44 376769.86 MWD+IFR-AK-CAZ-SC ', 5370.77 27. 13 242 .84 4949 .72 4912. 52 -1398 .10 -1245. 83 5956106 .15 376731.21 MWD+IFR-AK-CAZ-SC ', i 5465.83 25. 33 251 .06 5035 .01 4997. 81 -1414 .60 -1284. 36 5956090 .28 376692.42 MWD+IFR-AK-CAZ-SC ', 5561.12 25. 04 257 .72 5121. 26 5084. 06 -1425 .50 -1323. 36 5956080 .01 376653.26 MWD+IFR-AK-CAZ-SC 5656.23 24. 95 267 .21 5207. 50 5170. 30 -1430 .76 -1363. 08 5956075 .39 376613.46 MWD+IFR-AK-CAZ-SC 5751.62 26. 21 272 .96 5293. 55 5256. 35 -1430 .66 -1404. 22 5956076 .17 376572,33 MWD+IFR-AK-CAZ-SC ~ 5847.09 27. 03 279 .01 5378. 92 5341. 72 -1426 .17 -1446. 71 5956081 .34 376529.92 MWD+IFR-AK-CAZ-SC 5940.86 30. 89 286 .54 5460. 97 5423. 77 -1415 .97 -1490. 86 5956092 .26 376485.95 MWD+IFR-AK-CAZ-SC 6035.56 32. 64 296 .33 5541. 54 5504. 34 -1397 .71 -1537. 08 5956111 .26 376440.03 MWD+IFR-AK-CAZ-SC 6131.47 35. 44 301 .00 5621 .02 5583. 82 -1371 .91 -1584. 12 5956137 .82 376393.42 MWD+IFR-AK-CAZ-SC 6226.39 39. 28 303 .53 5696 .46 5659. 26 -1341 .12 -1632. 77 5956169 .39 376345.27 MWD+IFR-AK-CAZ-SC 6322.07 44. 89 305 .62 5767 .44 5730. 24 -1304 .70 -1685. 51 5956206 .66 376293.14 MWD+IFR-AK-CAZ-SC 6416.87 49. 81 309 .52 5831 .66 5794. 46 -1262 .14 -1740. 68 5956250 .11 376238.67 MWD+IFR-AK-CAZ-SC 6513.29 52. 81 315 .47 5891 .96 5854. 76 -1211 .28 -1796. 07 5956301 .85 376184.12 MWD+IFR-AK-CAZ-SC 6608.60 l 55. 59 319 .91 5947 .73 5910. 53 -1154 .11 -1848. 04 5956359 .86 376133.09 MWD+IFR-AK-CAZ-SC 6703.98 58. 06 324 .05 5999 .93 5962. 73 -1091 .22 -1897. 16 5956423 .53 376085.00 MWD+IFR-AK-CAZ-SC 6799.32 62. 87 324 .94 6046 .92 6009. 72 -1023 .71 -1945. 31 5956491 .81 376037.96 MWD+IFR-AK-CAZ-SC 6894.53 67. 14 325 .57 6087 .14 6049. 94 -952 .81 -1994. 47 5956563 .49 375989.96 MWD+IFR-AK-CAZ-SC ~ 6990.41 69. 80 325 .66 6122 .32 6085. 12 -879 .21 -2044. 83 5956637 .89 375940.80 MWD+IFR-AK-CAZ-SC i ji 7085.82 72. 01 325 .09 6153 .53 6116. 33 -805 .03 -2096. 06 5956712 .89 375890.78 MWD+IFR-AK-CAZ-SC 7180.17 74. 95 325 .47 6180 .36 6143. 16 -730 .69 -2147. 57 5956788 .05 375840.49 MWD+IFR-AK-CAZ-SC -- --_ _ _-- - - -_-- - ------1 Halliburton Company Survey Report ' Compan~~: ConoeoPhiltips Alaska Inc. Uate: 7/12/2006 Time: 10:04:01 Page: 3 Field: GolviBe Rive r Unit Co-ordinate ~NE) Reference: Well: CD4- 210, True North Site: Alpine CD4 Verti cal (TV D) Reference: CD4-210: 37.2 Well: CD4-210 Seeti on(VS) Reference: Well (O.QON,O.O OE,314.11Azi) Welipath: CD4-210 SurveyCalculati on Method: Minimum C urva ture Db: OraCie Survcv - __ __ NID Incl Azim TVD Sys TVD N/S E/W MapN MapE _ Tooi ft deg deg ft ft ft ft ft ft 7275 - .65 76.41 328 .62 _ _ 6203. _ 98 _ 6166.78 -653 .07 -2197. 88 5956866 .47 375791 .45 MWD+IFR-AK-CAZ-SC 7370 .77 81.22 329 .77 6222. 42 6185.22 -572 .94 -2245. 65 5956947 .36 375744 .99 MWD+IFR-AK-CAZ-SC 7444 .78 83.81 333 .30 6232. 07 6194.87 -508 .44 -2280. 61 5957012 .41 375711 .09 MWD+IFR-AK-CAZ-SC 7481 .75 85.76 337 .00 6235. 43 6198.23 -475 .04 -2296. 08 5957046 .05 375696 .17 MWD+IFR-AK-CAZ-SC 7577 .60 87.79 336 .99 6240. 82 6203.62 -386 .96 -2333. 48 5957134 .72 375660 .21 MWD+IFR-AK-CAZ-SC 7672 .81 89.83 335 .28 6242. 80 6205.60 -299 .92 -2371. 98 5957222 .37 375623 .12 MWD+IFR-AK-CAZ-SC 7768 .23 89.46 334 .86 6243. 39 6206.19 -213 .39 -2412. 20 5957309 .53 375584 .31 MWD+IFR-AK-CAZ-SC 7863 .77 89.58 334 .47 6244. 19 6206.99 -127 .04 -2453. 08 5957396 .52 375544 .84 MWD+IFR-AK-CAZ-SC 7958 .19 88.29 335 .84 6245. 95 6208.75 -41 .38 -2492. 75 5957482 .81 375506 .58 MWD+IFR-AK-CAZ-SC 8053 .45 87.92 334 .32 6249. 10 6211.90 44 .96 -2532. 86 5957569 .79 375467 .87 I MWD+IFR-AK-CAZ-SC 8148 .51 89.83 333 .78 6250. 96 6213.76 130 .42 -2574. 45 5957655 .90 375427 .68 MWD+IFR-AK-CAZ-SC 8243 .16 90.75 333 .24 6250. 48 6213.28 215 .13 -2616. 67 5957741 .27 375386 .85 MWD+IFR-AK-CAZ-SC 8338 .36 91.43 332. 46 6248. 67 6211.47 299 .82 -2660. 10 5957826 .65 375344 .80 MWD+IFR-AK-CAZ-SC 8434 .04 90.69 333 .84 6246. 90 6209.70 385 .17 -2703. 31 5957912 .69 375302 .99 MWD+IFR-AK-CAZ-SC 8529 .17 91.06 336 .97 6245. 45 6208.25 471 .65 -2742. 89 5957999 .79 375264 .81 MWD+IFR-AK-CAZ-SC ; 8624 .81 91.74 338 .57 6243. 11 6205.91 560 .15 -2779. 06 5958088 .86 375230 .09 MWD+IFR-AK-CAZ-SC !~ 8720 .34 90.63 337 .35 6241. 14 6203.94 648 .68 -2814. 90 5958177 .95 375195 .69 MWD+IFR-AK-CAZ-SC ~, 8815 ~ .82 91.80 334 .69 6239. 11 6201.91 735 .89 -2853. 69 5958265 .77 375158 .32 MWD+IFR-AK-CAZ-SC I i, 8911 .40 91.00 334 .06 6236. 78 6199.58 822 .04 -2895. 01 5958352 .57 375118 .41 MWD+IFR-AK-CAZ-SC 9006 .93 89.33 333 .89 6236. 50 6199.30 907 .88 -2936. 93 5958439 .07 375077 .90 MWD+IFR-AK-CAZ-SC 9102 .34 87.98 334 .71 6238. 74 6201.54 993 .82 -2978. 29 5958525 .67 375037 .94 MWD+IFR-AK-CAZ-SC 9197 .77 89.77 335 .86 6240. 61 6203.41 1080 .49 -3018. 18 5958612 .97 374999 .46 MWD+IFR-AK-CAZ-SC i 9293 .44 89.46 334 .32 6241. 26 6204.06 1167 .26 -3058. 47 5958700 .37 374960 .59 MWD+IFR-AK-CAZ-SC 9388 .85 89.46 331 .56 6242. 16 6204.96 1252 .21 -3101. 87 5958786 .01 374918 .57 MWD+IFR-AK-CAZ-SC 9484 .37 90.01 330 .38 6242. 60 6205.40 1335 .73 -3148. 22 5958870 .26 374873 .59 MWD+IFR-AK-CAZ-SC ~ 9579 .79 88.72 330 .69 6243. 66 6206.46 1418 .80 -3195. 16 5958954 .07 374828 .01 MWD+IFR-AK-CAZ-SC ~ 9674 .85 89.09 332 .60 6245. 47 6208.27 1502 .43 -3240. 29 5959038 .42 374784 .24 MWD+IFR-AK-CAZ-SC ~, ~, 9769 .91 89.15 334 .18 6246. 93 6209.73 1587 .41 -3282. 86 5959124 .07 374743 .06 MWD+IFR-AK-CAZ-SC I 9865 .15 91.93 336 .19 6246. 03 6208.83 1673 .84 -3322. 83 5959211 .13 374704 .51 MWD+IFR-AK-CAZ-SC 9960 .44 90.57 335 .94 6243. 96 6206.76 1760 .91 -3361. 48 5959298 .81 374667 .28 MWD+IFR-AK-CAZ-SC 10055 .81 90.88 334 .61 6242. 75 6205.55 1847 .53 -3401. 36 5959386 .06 374628. 81 MWD+IFR-AK-CAZ-SC 10150 .78 91.31 333 .92 6240. 93 6203.73 1933 .06 -3442. 59 5959472 .25 374588. 98 MWD+IFR-AK-CAZ-SC 10246 .11 90.69 332 .84 6239. 27 6202.07 2018 .27 -3485. 30 5959558 .13 374547 .66 MWD+IFR-AK-CAZ-SC 10341 .29 91.74 329 .90 6237. 25 6200.05 2101 .79 -3530. 89 5959642 .37 374503 .44 MWD+IFR-AK-CAZ-SC ', ~, 10436 .45 91.19 330 .24 6234. 82 6197.62 2184 .23 -3578. 35 5959725 .56 374457 .32 MWD+IFR-AK-CAZ-SC I, ' 10531 .60 91.25 331 .97 6232. 79 6195.59 2267 .51 -3624. 32 5959809 .57 374412 .72 MWD+IFR-AK-CAZ-SC i! 10626 .32 89.27 333 .23 6232. 36 6195.16 2351 .60 -3667. 90 5959894 .35 374370 .51 MWD+IFR-AK-CAZ-SC li I 10721 .44 87.61 335 .05 6234. 95 6197.75 2437 .16 -3709. 37 5959980 .56 374330 .43 MWD+IFR-AK-CAZ-SC 10816 .37 88.78 337 .49 6237. 94 6200.74 2524 .01 -3747. 55 5960068 .01 374293 .67 MWD+IFR-AK-CAZ-SC 10911 .32 87.54 337 .35 6240. 99 6203.79 2611 .63 -3783. 99 5960156 .21 374258 .66 MWD+IFR-AK-CAZ-SC 11006 .43 89.21 336 .85 6243. 69 6206.49 2699 .21 -3820. 99 5960244 .37 374223 .10 MWD+IFR-AK-CAZ-SC 11101 .60 90.14 335 .19 6244. 23 6207.03 2786 .16 -3859. 66 5960331 .92 374185 .84 MWD+IFR-AK-CAZ-SC 11196 .83 89.71 334 .70 6244. 35 6207.15 2872 .43 -3899. 99 5960418 .83 374146 .92 MWD+IFR-AK-CAZ-SC , 11291 .98 92.98 333 .39 6242. 12 6204.92 2957 .94 -3941. 62 5960505 .00 374106 .69 MWD+IFR-AK-CAZ-SC 11387 .15 93.04 333 .33 6237. 12 6199.92 3042 .89 -3984. 23 5960590 .63 374065 .47 MWD+IFR-AK-CAZ-SC 11482 .43 92.85 332 .32 6232. 23 6195.03 3127 .54 -4027. 69 5960675 .96 374023 .39 MIND+IFR-AK-CAZ-SC 11578 .23 94.09 332 .14 6226. 43 6189.23 3212 .15 -4072. 24 5960761 .28 373980 .22 MWD+IFR-AK-CAZ-SC ~I~ 11672 .88 93.97 332. 76 6219. 78 6182.58 3295 .86 -4115. 91 5960845 .68 373937 .92 MWD+IFR-AK-CAZ-SC • 11710 .00 93.97 332 .76 6217. 21 6180.01 3328 .79 -4132. 86 5960878 .87 - 373921. 51 - PROJECTED to TD j • • 04-Aug-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD4-210 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 11,710.00' 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~~ oZ~`lS Signed V Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) a~ ~- ~7~ • • WELL LOG TRANSMITTAL To: State of Alaska ~ July 20, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-210, AK-MW-4443583 The technical data listed below is being submitted hercwilh. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20533-00. ~~~~~~~~ AUG 2 2 2006 ,~ Oll ~ Gas Cons. Gommissian Anchorage ~OCo °O~~r ~ ~yoa5" ConocaPh[It 5 Casing Detail 9 5/8" Surface Casing 6 -0l1`Z Well: CD4 - 210 Date: 6/14/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring FMC Gen V Hanger 37.10 2.08 2420.91 37.10 39.18 Jts 3 to 65 63 Jts 9 518" 40# L-80 MBTC Csg 41 1 09 2460 Weatherford Float Collar . 75.89 . 2461.50 Jts 1 to 2 2 Jts 9 5/8" 40# L-80 MBTC Csg Ray Oil tools (Silver Bullet) 226 2537.39 65 2539 . " 00 2550 Surface Hole TD 12 1/4 . ' TVD 12 1/4" Hole @2550 ' MD / 2395 9 5/8" Shoe @ 2539.65' MD / 2386 ' TVD ~~< ~ +. c ~ ~ ~ Co- Co RUN TOTAL 40 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #14 (stop ring on Jt #1 8~ 2 ) 30 , and over collars on jts# 16, 18, 20, 22, 24, 26, 28, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 59 62 63 61 , , 68 joints in the pipe shed. Run 65 joints Last 3 joints stay out Use Best-o-Life 2000 i e do e MU torque ~ 1t/Ibs Remarks: Up Wt - 160k Dn Wt - 145k • Block Wt - 75k D. LutricWL. Ifni ~ Cement Detail Report CD4-210 SurFace Casing Cement ary Job Type t Job Category AFE I RFE Start Date Spud Date End Date . DRILLING ORIGINAL DRILLING 10137724 6/11/2006 -- ---- - - - -J - Cement Details_ _ _ _ _ __ Cementing Start Date Cementing End Date -- - Wellbore Name Description 6/14/2006 03:35 6/14/2006 05:25 CD4-210 Surface Casing Cement Comment - - - Cement S_ta es ~ -- _- - - - - -- Sta e # 1 - Description- - -- - Objective -'-- - Bottom ftK6 Full Return? nt Rtrn (... op Plug? Btm Plug? Top (itKB) ( ) 0 Yes Yes 65 . Surface Casing Cement 0.0 2,540.0 Yes end bbllmin O (av bbllmin P final si P (bump) (psi) Recip? Stroke (ft Rotated? Pipe RPM (rpm) Q ( ) ( ) 9) ( ) ( ) (P ) bbll i t n) m O (star ) ( 0 1,200.0 Yes 6 630 20.00 No . 6 4 Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Depth tagged (ftK8) Comment --- - - - - -- CementFluids 8~ Additives .. --- - - - -- - _ _ _ - _ _ _ -- "- -- _ _ Fluid. Fluid Type Fluid Description , . ~. - -- Estimated Top (ftKB) Est Btm (flK6) Amou 3235) - Volume Pum d bbl Class ~ 0 256 Lead Cement Mix H2O Ratio (gallsa ' p_0 2,040.0 Free Water (%) Density (Iblgal) Plas " Viscosity (cp . Thickening Time (hrs) CmprStr 1 (psi) ... Isack) Yield (ft 70 10 4.45 20.15 . Additives Concentration Conc Unit label Additive Type --- - - - FWid Fluid Type Flwd Description A (sacks ~` Estimated Top (ttK6) Est Btm (ftKB) ~ ) __ _ GfassVolume Pumped (bbl) G 48.0 :ement . Mix H2O Ratio (gal/sa ' 230 2,040.0 2,540.0 Free Water (°~) Density (Iblgal) PI tic Viscosity (cp) ickening Time (hrs) CmprStr 1 (psi) .. /sack) • (ft 1.17 5.10 15.80 Additives Concentration Conc Unit label Additive Type Fluid --- -__- - - Fluid Type Fluid Description Estimated Top (ftICB) Est Btm (ftK6) Amount (sacks) -- --- -Volume Pum ed bbl Class p ( ) Yield (ft%sack) Miz H2O Ratio (gallsa... 1,890.0 1,890.0 Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Concentration Conc Unit label Additive Type -- Daily Drilling Report CD4-210 .~.~ Report Date: 6/13/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 3 2.09 1,932.0 2,550.0 618.00 CD4-210 Spud Date Contractor Rig NamelNo Field Name Well Type Target Depth (ftKB) 6/11/2006 DOYON 19 NANUO Development 13,115.0 AFE / RFE / Maint.# Total AFE Amoum Average ROP (ft/hr) 10137724 5,469,157.00 105.5 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Conductor, 114.OftK6 Daily Cost Total Cummulative Cost Ops and Depth @ Morning Report 818.45 689,713.63 162 Testing casing. , Daily Mud Cost Cummulative Mud Cost 24hr Forecast Cement casing. Test casing. Nipple down riser. Nipple up and test BOP. PU BHA. 24,677.45 39,643.35 Last 24hr Summary Drilled to TD @ 2550'. Circulated and short tripped. Circulated hole clean. POOH and laid down BHA. RU and ran 43 Jts 9 5/8" casing. Circulated. General Remarks Weather Head Count Bumped plug @ 0525 CIP. 65 Bbls cement to surface. 44 Deg Wind E @ 12 mph 48.0 - - -- - -- - Supervisor - - Rig Supervisor Dave Burley -- - - -- I Rig Supervisor Don Mickey T:-... f. 1 ~.- _ -- - -. S~ 7 Ci d .- - ~ " - -_~ ~ ~ _ ' lu,~e S P N-TI T l D pLY M:~rt ~ Def:Lh tn7 ~ (fth:B) (fthBj d Ccmr~.~Ope-atlon T r Tl~,i Der, hi F.r ~s c Up C._ ,dr ,p}_~L G r - , o e _ - ' ' ' -. _ 00 00 07:30 7.5U SURFAC DRILL DDRL P 1,9320 2,550.0 TVD MD 2395 to 2550 Drill 12 1/4" hole f/ 1932 . ADT - 5.86 hrs =ART - 4.85 hrs AST - 1.01 hrs WOB 20/35 RPM 55 GPM 650 @ 2390 psi String wt. PU 143 SO 130 Rot 140 Torque on/off btm. 8000/6000 ft/Ibs 07:30 08:30 1.00 SURFAC DRILL CIRC P 2,550.0 2,550.0 CBU. 650 GPM 2160 psi. 08:30 11:00 2.50 SURFAC DRILL WPRT P 2,550.0 890.0 Back reamed out to 890' with 550 GPM 55 RPM. 11:00 12:15 1.25 SURFAC DRILL WPRT P 890.0 2,550.0 RIH and washed to 2,550'. 12:15 13:30 1.25 SURFAC DRILL CIRC P 2,550.0 2,550.0 Circulated and conditioned hole. 650 GPM 2160 psi. 13:30 16:30 3.00 SURFAC DRILL TRIP P 2,550.0 164.0 POOH from 2550' to 164'. 16:30 19:00 2.50 SURFAC DRILL PULD P 164.0 0.0 Laid down BHA. 19:00 21:00 2.00 SURFAC CASING RURD P 0.0 0.0 Rigged up to run 9 5/8" casing. PJSM. 21:00 23:30 2.50 SURFAC CASING RNCS P 0.0 1,641.0 Ran 43 Jts 9 5/8" 40# L-80 BTC casing to 1641'. 23:30 00:00 0.50 SURFAC CASING CIRC P 1,641.0 1,641.0 Circulated casing volume + 10 Bbls @ 4 BPM. Mud Check - - Data - -, -- I- ~ - PP C ~ ~ ~ - ~~ ~ , i ~ C ~ m rFl i mj ~ HTHP F It ' DY, v T:.no ~ , I I -- ; n,r '~ Depth (ftKB)' Dents (lblgal) Vts~slgt)' PV t,~lc icy ~ ,ILf"~.~ ~ Tvoe Water 2,550.0 9.90 300 37.0 63.000 t=H Fi - 1 27 ~~fl~, , ...,...:,c) Q"; ,r,ft r r.9DT I uil i , 2?gym n1 30.000 90.000' 90.000 30.0 8.8 ~ ^~ '. 9.5 Based Mud 1 I 1 -- - - - In~ection Fluid ~ uu SJI,r ~ _ - -_ - - - - -- - _ ~:'P - - `'113•IU~ - Rccycled mud - ~- - From CD4210 20 - - I :Drill Sfrin s: BHA No. 1 - St raee hIe / Bit Run No. _MXL-1, 5090101 loin Hu hes Christensen - 1 12 1 ~ Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles (132") IADC Bit Dull String Wt (10001b~ WOB (max) (100... WOB (mm) (1000... 0.0 2,550.0 2-3-WT-A-E-1-ER-TD 13 0 0 i ill St D onents Com n r r J~s _ I p g - - Item ~escripfion - - - - I OD {inj -1D {in) Tcp 1_nxa5z [ 2j. ~~ lop Thread' Cu m Ler_'ft1 Motor with Stabilizer - 8 4.947 6 5/8 H 90 2$.00 Float Sub 7 7/8 3.000 6 5/8 H 90 30.23 Stabilizer 8 2.875 6 5/8 H 90 37.24 XO Sub 8 2.900 6 5/8 Reg 38.92 MWD (DM) 7.99 3.000 6 5/8 Reg 48.12 MWD (HCIM) 7.98 1.920 6 5/8 Reg 56.66 MWD (TM) 8.02 3.250 6 5/8 H 90 66.41 UBHO 8 3.500 6 5/8 H 90 68.81 NMDC 7 1/2 2.813 6 518 H 90 9982 NMDC 7 3/4 2.813 6 5/8 H 90 130.82 Drilling Jars -Mechanical 7 3/4 2.750 4 1/2 IF 165.39 Latest BOP Test Data - -- - -- - -- - - - - Page 1/2 Report Printed: 8/7/2006 Daily Drilling Report C D4-210 Report Date: 6113/2006 Drill) Strln Com onents 9 ~ - - - ; ' - - - -- ~ , ~ _ -- - -- - - a _ _- Item Oescrg tioii - - 4 ~~ rn, i ID_l^~~ fop t, ~_ ~.u -- 1 IF ,a1 7r i.i ---- ~ C^m L n 1 -~ - -- - ISO 39~ ~ ~'HWDP ~ 5 3 000 ~-- - ~ _ Drilling Parameters __ - -- - -- ~ St~l FLKB) Crw t~ KG ;r ~ ~~~ ~,ii hrC; ~ li~ir~ Hi I, 'min tit i:~ n D th ; t ~ T - o~~n urr une ihr;l L Y ~ n Irt Cl^otl', In) ~ ~ 7pr ! V ~1D ~IbP ~ -__ - Ff'Iv1 irL i r ~ -- SF ~ psi' ~ -_ Drib l7 ~. _ _--. - - ~ 0 0 ~ 114.0 ~ ___ 0.01 i_. _ 114 00' ~. 0 01 I 1 14.00 450 10 0 50 ~ 800.0 ~ 5,000.0 1,932.0' 2,550.0'. 5.861 2,550 00 19 99~ 618.00 650 _ ---- 35.0!, 'r7 - - 1- ~ 2390.0 - -- _ - 8,D00 0 - - - -- - Wellbores - _ ~ _ -_ - - -- _ - __ _ Wellbore ame Wellbore API!UWI CD4-210 501032053 00 - 1 n i s~.e~~n~ tictaap'rthi~; ~ ,~ctBtr~lft~cP --- J - t~nuazE - _ End Date. _ J -- t,t)ND1 44 _ _ 0.0 114.0 - 6/11/2006 6/11/2006 SURFAC 12 1/4 114.0 2,550.0 6/11/2006 6/15/2006 INTRM1 8 3/4 2,550.0 7,480.0 6/15/2006 6/13/2006 PROD1 6 1/8 7,480.0 11,710,0 6/21/2006 6/26/2006 Surve . _ ' ~ "' ~ p 1 G~~i n 1 ~ ll t v: n; - [~ ,/!n1 rVs~ ti .1 °~ -~~ii _ 1 981.78 - 25.67 220.58 1 895.68 24.36 321.88 276.97 U.52 2,076.78 25.47 220,49 1,981.37 -26.84 -353.05 -303.62 0.21 2,171.84 25.64 220.94 2,067.13 -29.19 -384.13 -330.37 0.27 2,267.33 28.51 219.09 2,152.15 -32.24 -417.43 -358.29 3.13 2,362.67 31.32 216.91 2,234.78 -37.25 -454.91 -387.52 3.16 2,457.95 31.35 217.42 2,316.16 -43.15 -494.40 -417.45 0.28 2,499.60 31.34 218.17 2,351.74 -45.49 -511.52 -430.73 0.94 page 2/2 Report Printed: 8/7/20061 Co~r~ocoF~h~~l;~ps Daily Drilling Page 1 of 2 Report Printed: $'~4'2°O6 w'NRviesr we6Reparting € i i Re art Header Well: Report Date: Job Type: Network: Report # Daily Cost: Cum Cost: CD4-210 06/14!2006 DRILLING 10137724 4 $333,418 $1,023,132 ORIGINAL Field: Rin Name: Riq Supervisor: Ria Accept: Riq Release: NANUQ DOYON 19 Dave 6/11/2006 1:00:00 Burley/Don PM 24 hr Summary: Ran and cemented 9 5/8" casing. Tested casing. Nippled down riser. Made up speed head and nippled up BOP. Tested BOP. Picked up BHA. Summary ~ Rpt Time: Drilling shoe track. 24 hr Forecast: Finish picking up BHA. RIH to TOC. Cut drilling line. Drill 20' and FIT. Change out mud and Drill. ~-- I` Tirne Log _- _ _ _ _ - - From To Duration Ph~e Op Cow Subcode Time Activi _ 00:00 01:00 1.00 SURFAC CASING RNCS P RIH w/ 9 5/8" csg from 1641' to 2500'. MU hanger and landin 'oint. Land cs at 2540'. 01:00 01:15 0.25 SURFAC CASING RURD P RD Franks fill up tool. Blow down top drive. 01:15 01:30 0.25 SURFAC CASING RURD P RU cement head and lines. 01:30 03:30 2.00 SURFAC CEMENT CIRC P Circ and condition mud for cement job. Stage pumps u to 7 b mat 300 si. Pum ed a total of 453 bbls. 03:30 05:30 2.00 SURFAC CEMENT DISP P PJSM. Test lines to 2500 psi. Pump 40 bbls biozan / nutplug spacer. Drop bottom plug. Dowell pumped 50 bbls 10.5 mud push, 256 bbls of 10.7 lead and 49 bbls 15.8 tail. Dropped top plug. Pumped 20 bbls H2O and rig displaced with 167 bbls mud. Bumped plug. Floats OK. n5:30 06:30 1.00 SURFAC CASING DHEQ P Test csg to 2500 psi for 30 min. __ 06:30 _ -- 07:30 _ 1.00 SURFAC CASING RURD P RD csg and circulating equipment. 07:30 08:30 1.00 SURFAC CASING NUND P PJSM. ND surface riser. 08:30 09:45 1.25 SURFAC CASING NUND P NU well head adapter assembly and test to 1000 psi. 09:45 11:30 1.75 SURFAC WELCTL NUND P NU BOPE. Install mousehole. 11:30 16:30 5.00 SURFAC WELCTL BOPE P Set test plug.Tested BOPE - Hydrill to 250 & 3500 psi - Test pipe rams, kill & choke lines, choke manifold valves, to 250 & 5000 si -tested closin unit. 16:30 22:00 5.50 SURFAC WELCTL ROPE T Auto IBOP leaking -Attempt to test blind rams found leak on BOP to wellhead flange. Replaced IBOP and tightened flange. Tested blind rams and IBOP 250/5000 si. Witiness of test waived b John Cris AOGCC. 22:00 22:30 0.50 SURFAC DRILL RURD P Pulled test plug and set wear bushing. Picked up bales. 22:30 00:00 1.50 SURFAC DRILL PULD P Picked up bit and BHA. Upload MWD. _ - _ Mud Checks - - -- -~ _ Time 1`yRE~ Source De th Den sit H F Vis. PV YP - Gels HTHP MBT FL Temp _ ~~JJ 21:00 Water In 2,550 9 .7 9.0 72.0 24 ?0.00 4.00 30.00 32.0 27.5 Based Mud __~ ~ ~ --- -_-__._ _ _~ Page 1 ~~s PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. IlVell Name: CD4-210 Rig: Doyon 19 Date: 6/15/2006 Volume Input Volume/Stroke Pum Rate: ('Drilling Supervisor: D. Lutrick / L. Hill Pump used: #2 Mud Pump ~ Strokes • 0.1000 Bbls/Strk • 0.8 Bbl/min Type of Test: Casing Shoe Test LOT/FIT ~ Pumping down annulus and DP. ~ asin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe De th Hole De th Pum in Shu t-in Pum in Shut-in RKB-CHF: 37.1 Ft 2,540 Ft-MD 2,386 Ft-TVD 2,570 Ft-MD 2,412 Ft-TVD Strks si Min si Strks si Min si Casinst Size and De scription: 9-5/a" 4o#/Ft L-so BTC ~ 0 0 0 2500 0 70 0 1060 Casin Test Pressure Int e rit Tes t 2 125 1 2500 1 140 0.25 1025 Mud Weight: 9.9 ppg Mud Weight: 9.5 ppg 4 300 2 2500 2 250 0.5 1010 Mud 10 min Gel: 22.0 Lb/100 Ft2 Mud 10 min Gel: 22.0 Lb/100 Ft2 6 550 3 2500 3 360 1 1005 Test Pressure: 2,500 psi Rotating Weight: 135,000 Lbs 8 800 4 2500 4 490 1.5 100 Rotating Weight: 130,000 Lbs Blocks/Top Drive Weight: 74,000 Lbs 10 950 5 2500 5 600 2 1000 B locks/Top Drive Weight: 74,000 Lbs Desired PIT EMW: 18.0 ppg 12 1125 6 2500 6 740 2.5 995 Estimates for Test: 1.6 bbls Estimates for Test: 1055 si 0.7 bbls 14 1300 7 2500 7 850 3 995 ~ ~ 16 1550 8 2500 8 940 3.5 995 EMW =Leak-off Pressure + Mud Weight = 1100 + 9 5 PIT 15 Second 18 1800 9 2500 9 1000 4 990 0.052 x TVD 0.052 x 2386 Shut-in Pressure, si 20 2000 10 2500 10 1060 4.5 990 EMW at 2540 Ft-MD (2386 Ft-ND) = 18.4 1025 22 2200 15 2500 11 5 985 soot ' " `' ---'--' `''~'"""°' 24 2350 20 2500 12 5.5 985 25 2500 25 2500 13 6 985 14 6 5 985 30 2500 . 1 7 985 25oc 5 16 7 5 980 . 8 980 2ooc 8.5 980 W p~ 9 980 ~ 9.5 980 N 1501 10 98 W ' Q' a ~ ~ i l 1001 5(N ~ 0 5 10 16 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume VoU ~~CASING TEST -FLEAK-OFF TEST O PIT Point Pum ed Bled Back Pum ed Bled s s s Tested 9 5 8' csg to 2500 psi after bumping plug on cmt job • ConacoPhilli s p Casing Detail 7" Casing Well: CD4-240 Dater 6/20/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.85 FMC Gen V Hanger 2.66 34.85 Jts 3 to 174 172 Jts 7 " 26# L-80 BTCM Csg 7342.71 37.51 Weatherford Float Coltar 1.25 7380.22 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.46 7381.47 Ray Oil Tools Float Shoe 2.09 7467.93 7470.02 TD 8 3/4" Hole 7480.00 8 314" Hole TD @7480 ' MD /6236 ' TVD 7" Shoe @ 7470.02' MD / 6235' TVD Total Centralizers: 45 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt jts. # 115,116, 117, Straight blade centralizer one per jt on every other joint Starting @ # 119 to # 172 Top Nanuq - 7180 ' MD - 6180' TVD 185 joints in shed - 174 total jts. to run Last 11 jts. out Use Run & Seal i e do e Average MU torque 6500 ft/Ibs Remarks: Up Wt - 265k Dn Wt - 185k Block Wt - 75k Supervisor. D. Lutrick/ L. Hill Cement Detail Report CD4-210 Intermediate Casing Cement (DRILLING ORIGINAL -- - - - - Cement Details Description - -- Intermediate Casing Cement Comment - - Cement Staffs _ _- _ _ -- _ Sta e # 1 _ _ Description Objective ~ Intermediate Casing Primary Cement Q (start) (bbllmin) Q (end) (bbllmin) Q (avg) (bbllmii g 4 6 DRILLING I 10137724 ~ 6/11/2006 ~ ~ _ _ - -- - - Cementing Start Date Cementing End Date IWellbore Name 6/20/2006 0034 ~ 6/20/2006 01:55 CD4-210 - - - - - - iftK6) Bottom (ftKB) Full Retum? Gmnt Rtrn (... Top Plug? Btm Plug? 6,480.0 7,470.0 Yes 0.0 Yes Yes P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 400.0 1,050.0 Yes 20.00 No - - - Cement Fluids 8 Additives - - Fluid- __ _ - - Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ttKB) Amount (sacks) Class 'Volume Pumped (bbq Primary Cement 6,480.0 7,470.0 200 G 41.0 veld (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.17 15.80 1 /1 • Daily Drilling Report CD4-210 Report Date: 6120/2006 teport Number Days From Spud (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) Wellbore 10 9.09 7,480.0 7,500.0 20.00 CD4-210 Well Type Target Depth (ftK6) Spud Date Contractor Rig NamelN9 Ai td1eame Development 13,115.0 6/11 /2006 DOYON p AFE I RFE I Maint# Total AFE Amount Average ROP (ftlhr) 10137724 5,469,157.00 Last Casing String Nett Casing OD (in) Next Casing Set Depth (ttK6) 3 1 /2 13,105.00 Intermediate, 7,470.OftK6 Ops and Depth ~ Morning Report Daily Cost Total Cummutative Cost 215,089.78 2,369,778.76 POOH for GeOPllot Daily Mud Cost Cummulative Mud Cost 24hr Forecast 6,540.78 199,398.48 Finish POOH -Change GP -RIH - Chnager over to Flo Pro -Drill 6 1/8" hole Last 24hr Summary Circ i£ Cond. mud for cmt job - Cmt 7' csg CIP @ 0155 hrs. Test 7" csg - MU BHA # 4 - PU 4" DP -RIH -Drill ST- Drill 20' new hole to 7500' - Perform F o 12.5 ppg EMW - GP failure -POOH ,.,.,~ae~ Head Count ~ _ -T - -- -- - - _ -_ - - -- i n:e - - - - - - - - - - - -- l - -... g r. vi~.or __ - _ - - -- -. -.- _ -- - - - - _ Rig Supervisor Donnie Lutrick f Don Mickey Rig Supervisor - ----- -- I~Time Log - --- - ~. , - ---- art ~ Gnd ~. T. ~ ~- ~.Tn~x~ ~ Depth ariDepth Eru+ -_.-.. - - _ - - - CommlGipar.ation Tune ~ T1R.e ~Dujhr,)~ F ha e Gp Cede ~P ub-t;n~' ~~-N-l l-ol Gnde ffchC) ff hB) - - - - - - - - - - - 7,470.0 7,470.0 Finish circulate and condition mud. Stage pumps to 6 bom at 00:00 00:30 0.50 INTRMI DEMENT ' GIRC P 550 psi. nn•~n ro:00 1.50 INTRM1 CEMENT DISP P 7,470.0 7,470.0 PJSM. Dowell pumped 5 bbls CW100. Test lines to 3700 psi. bbl CW100 and 30 bbls 12 5 ppg mud push. 1.00 1.25 4:30 I 4.75 Pumped 25 s Dropped bottom plug. Mix and pumped 41 bbls of 15.8 ppg cement.. Dropped top plug. Pumped 20 bbls H2O and displace with mud with rig pumps. Bumped plug. Checked floats. OK. si for 30 min to 3500 7" T 1 CASING DHEO P 7,470.0 7,470.0 . p csg est LD LJ. equipment d circulatin RD 1 CASING RURD P 0.0 0.0 . g csg an Install packoff and test to 5000 psi. ar bushin ll thi P 1 CASING OTHR P 0.0 0.0 g. n we u e rams from 7" to 3 1/2" x 6" varibles. Test i er Ch 1 WELCTL EQRP P 0.0 0.0 p p ange upp rams to 5000 psi. Install short wear bushing. LD test jt. t l ll t P 1 DRILL OTHR P 0.0 0.0 ug. es p u nou i ai tRn P 0.0 0.0 RU short bails and drill pipe elevators. GeoPilot at 189'. 7,232.0 PU and RIH w/ 129 jts of 4" DP.to 4466' -RIH f/ derrick w/ to 7232' 7,370.0 Wash down f/ 7232' to 7370' (top of cmt) 7,500.0 Drill wiper plugs - FC - Cmt - FS -Drill 20' new hole to 751 MD 6238' TVD - ADT .29 hrs. WOB 3/12 k RPM 60 GPM 200 String wt. PU 205 SO 135 Rot 165 Torque on/off btm. - 10,500/10,000 ft. Ibs Note Geo Pilot failure p 7,500.0 7,500.0 Clrc hole clean ror ri i p 7,500.0 7,500.0 RU 8 perform FIT to 12.5 ppg EMW - RD Mud Check Data hype Depth {ft'~. Water 7,47 Based Mud 7,500.0 7,041.0 Flow check (static) POOH on I I ror tseoruot ~D1 DRILL TRIP T _ _ _- ------ ---- - - -~ ~.- - HTHP FII ! Temp 6cttcn Sollds ('o YP r~lc f Gel {7 ps) Lsl ~1Lhn) GeI {3(.~) ~ Hole (°F) ~ '.°n~) JM7~C'1"'- i IbItODt17 {Ibfl90Dft-~~{Jbfl'L~'Jft~ ~ MBT(Ib/bbll ?m'J3GmTnj pH - i __ _ _ Dens {Iblgalj Gis {s/qt)~ Cale. (tp) ~ d_ ) ~ ~ - --- -- _ ~ 9.4 9.80 401 9.~ 14.000 ~ 6.000 I 8.000 ~ 9.0001 18.0 Latest BOP Test Data Page 1/2 Report Printed: 121/2DOi Daily Drilling Report CD4-210 l~ - - ilnjection Fluid _ Diesel Water Based Mud Water Based Mud flrill Strings: BHA No` 4 - Report Date: 6!20/2006 - - ---- -~. NotF ---- - From tease (bbl/ Deshnation Source _~- _ _ -_._--_-_- -_. - _ _ - - 60.0 Freeze Protect CD4-210 300.0 Annular Flush CD4-210 1530.0 CD1-19 f/ CD4-210 7 0 Annular LOT -CD4-210 -- - - - - - eerable / Bit Run No 4 - 6 118in, Halliburton 5ecuri D6S , FS25532 , 1082308fi _ _ - _- ~ I Strin Wt (10001b~ ' WOB (max) (100... WOB (min) (1000.. Depth in (ftKB) Depth Out (ftKB) i~A (incl Noz) (in') Noales (l32) IADC Bit Dul 9 8 0 0 7,480.0 7,500.0 Drill String Components _-- - - -- - - ---, ~ - - _ ~~D (n) - 113Qn) ~ - To~CoiarJ - (;n)- ,~ea~t -.. ~ Sz - - Carai.e~(ft~ - - - pis ~ IterriDescraption7 - 3 7 1 Geo Pilot 4 3/4 1.500 3 1/2 NC 38 .73 2 1 Drill Collar -Flex Non Mag 4 76 1.500 3 1/2 NC 38 31.31 1 Stabilizer (Non Mag) . 4 3/4 1.500 3 1/2 NC 38 39.87 1 MWD DM HOC 4 73 1.500 3 1/2 NC 38 62.40 1 MWD GR/RES . 4.7 1.500 3 1/2 NC 38 73.26 1 PWD 62 4 1.500 3 1/2 NC 38 84.44 1 MWD TM HOC . 4 66 2.313 3 1/2 NC 38 86.61 1 Float Sub . 4 3/4 2.250 3 1/2 NC 38 92.13 1 Stabilizer (Non Mag) 4.56 2.250 3 1/2 NC 38 123.13 1 NMDC 52 4 2.250 3 1/2 NC 38 154.28 1 NMDC . 4.8 2.563 4 XT 39 156.93 1 XO Sub 4 2.563 4 XT 39 279.60 4 HWDP 4 3/4 2.000 4 XT 39 311.93 1 Drilling Jars - DNT 4 2.563 4 XT 39 373.28 2 HWDP Drilling Parameters - i - ~ ~. tirs ~ ; or~n ~ T T ~~ Ino,.~ _ ~ ~ } ~ - ; ~~r I art [`'LKBj ~ Cn iYY.-B} -- 1 ~ .>i~d a i~u rim ~~~ m ,~~ c~,rn n_ n n ~•` 1 ~ _~ ) _ P O ~ ~ _ ~ Irn Dc tr ttQ 00 (. ~ ~ , IuF'm~ ~~ WOB ~t~i~~ r ~ PhA Ir~m i SP!' ~~ - 1 ~00 0~', b0' r~r,n r Q ~ 10,50I).~J ~ 7.450 0' r 500 0 ~ - ~ 20.00 - - - - ~ - ~ - - - -- - i Wellhores - - - -- - - Wellbore API/UVY -- - _ l Wellbore Name K I 33 0 5010 - - --- - 1 - GD4 210 - - - -.. ~.. kcl Too {itKB) i= ) -- ` - . 5 3 - - d Date _ _ - - I Act Bfi1,(~ H~ , _ --~-- - i J on se:t - - -- - ~ 44 -- - -- 0 0 1- - 114.0 6/11/2006 6/11/2006 COND7 12 1/4 . 114.0 2,550.0 6/11/2006 6/15/2006 SURFAC 8 3/4 550.0 2 7,480.0 6/15/2006 6/13!2006 INTRMI 6 1 /8 , 480.0 7 6/21 /2006 PROD 1 -- - - - , ICasin~Stnn~s -i- - Vh (Ibsfft) ~ (trade J Set n ~~ODli~) ~ Rw~Dah __ p'h (ftKE) ~- - - ~onmcnl -- - - - sin D,.~criFlion = e -_ , _ ~ 005 16/20/2 J ~+ i 26.GG~L EG L 7,470.0 - - -- IntPrfllBdlate -- - L ' _ Cement: ~..a.,....e.a:~re c~~r.,~ comPnt - - Started ([a 6/20/2006 -- - - - -- - - -- - -- - - g CD4-210 Intermediate, 7,470.OftKB Top (ttKB) Bottom (ftKB) O (end) (bbl/.. >. Descnption 4 1 Intermediate Casing Cement 6 480.0 7,470.0 _ -- --- - -`-- ~ Glass Amott~t lSiC}s~- V It`UI) ~D y {Iblgalt l"i eJ~ [ft'1 ~ackl ~ Esf Top (ftK8) Fi~~a - -- -- -- 6,480.0 .--^--.-. - --I r. -- I 2001 41.0 15.80 1.17 L _ 400 0 Esi L'tm(ftKB) -7,470.0 Page 212 Report Printed: 6lzllzoul PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. ell Name: CD4-210 Rig: Doyon 19 Date: 6/20/2006 Volume Inpu ~illing Supervisor: Lutrick /Mickey Pump used: Cement Unit ~ Barrels ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Cas ale Size: 8-3/4" ~ Casin Shoe De th Hole Depth Pum in RKB-CHF: 34.7 Ft 2540.0 Ft-MD 2386.0 Ft-TVD 6480.0 Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC Chan es for Annular Ade uac Test Pressure Int Enter outer casing shoe test results in comments Mud Weight: Casing description references outer casing string. Inner casing OD: Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. Desired PIT EMW: Estimates for Test; 1000 off Pressure + Mud Weight = 929 + 9.8 0.052 x TVD 0.052 x 2386 EMW at 2540 Ft-MD (2386 Ft-ND) = 17.3 PP9 7.0 In. PP9 osi 0.4 bbls Shut-in Pressu 520 Bbls/Strk ~ ~ Shut-in in 0 1 2 3 4 7 Pum Rate: 30 Bbl/min ~ Im in Shut-in si Min si 0 50 0.00 611 1.5 405 1.00 4ry 2 519 1.50 473 41 92911 3.50 10 5 658 4.50 453 15 5.5 630 5.00 449 20 6 630 5.50 447 ~S 6.5 620 6.00 447 7 w N 500 W a a 0 1 2 3 4 5 6 7 Barrels ~~CASING TEST ~' LEAK-OFF TEST Volume Volume volume volume Pumped Bled Back Pum ed Bled Back Summary 0 5 10 15 20 25 30 Shut-In time, Minutes O PIT Point T STATE OF ALASKA ' 11/09!04 OIL AND GAS CONSERVATION COMMISSION ROPE Test Report Submit to: dim repg~~adr~:i:l.stUte.ak.tls ac~cn p;~_4d~os '3r:v~adnn.stae.ak.us boi €sckenatAirl:~adrr:i:~.state.a>~.u ~• Contractor: Doyon Rig No.: 19 DATE: 6/14/2006 Rig Rep.: Krupa/Grazulis Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Lutrick/Hill Field/Unit & Well No.: Colville Rv CD4-210 PTD # 206-077 Operation: Drlg: x Test: Initial: x Test Pressure: Rams: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Annular Preventer 1 13-5/8 Workover: Weekly: Annular: 250/3500 Explor.: Bi-Weekly Valves: 250/5000 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Ri P Upper Kelly 1 FP P Lower Kelly 1 P P Ball Type 1 P Inside BOP 1 P Test Result P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results CHOKE MANIFOLD: Quantity Test Resu No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: TimelPressure Test Resu System Pressure 2900 P Pressure After Closure 1525 P 200 psi Attained 37 sec P Full Pressure Attained 3 min 02 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ psi 2050 Number of Failures: 1 Test Time: 7 Hours Components tested 28 Repair or replacement of equipment will be made within Immediately days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: dim regg~yadrr:i:~.state.a>i.us• Remarks: Replaced IBOP and retested OK. 24 HOUR NOTICE GIVEN YES X NO Date 06/13/06 est start Time 7:OOam Finish Waived By John C Witness BOP Test (for rigs) BFL 11/09!04 Doyon19 6-14-06 CD4-209.x1s Re: Colville River Field, Nanuq Oil Pool, CD4-210 ConocoPhillips Alaska, Inc. Permit No: 206-077 Surface Location: 2928' FNL, 245' FEL, SEC. 24, T11N, R4E, UM Bottomhole Location: 3612' FNL, 4988' FEL, SEC. 13, T11N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the. Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this day of June, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~~ STATE OF ALASKA ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill /^ ' Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ ,, Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed for: 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: CD4-210 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13115' TVD: 6205' ' 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 2928' FNL, 245' FEL, Sec. 24; T11 N, R4E, UM ~ 7. Property Designation: ADL 380077, 380075 Nanuq Nanuq Oil pool Top of Productive Horizon: 3449' FNL, 2499° FEL. Sec. 24, T11 N, R4E, UM 8. Land Use Permit: ALK 380077 13. Approximate Spud Date: 6/15/2006 Total Depth: 3612' FNL, 4988° 1=EL, Sec. 13, T11 N, R4E, UM ' 9. Acres in Property: 2560 14. Distance to Nearest Properly: 15840' FNL 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377999 y- 5957484 Zone- 4 10. KB Elevation (Height above GL): 36.7' RKB feet 15. Distance to Nearest well within Pool: CD4-208 , 1483' 16. Deviated wells: Kickoff depth: 600 ft.r Maximum Hole Angle: 92.4° deg 17. Maximum Anticipated Pressures in psig (see zo AAC 25.035) Downhole: 2821 psig Surface: 2201 psig 18. Casing Program ifi ti S Setting Depth Quantity of Cement - Size ons pec ca Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 62.5# I-§-40 ~~le(ded 75 37 37 112 112 pre-installed 12.25 9-518" 40~ L-80 BTC 2503 37 37 2540 ~ 2440 ' 481 sx AS Lite. 230 sx LiteCRETE 8.75 7" 26# L-80 BTCM 7386 37 37 7423 6235 170 sx Class G 6.125 3.5" 9.3# L-80 SLHT 5842 7273 6177 13115 ~ 6205 slatted liner in open hole 3.5" 9.3# L-80 BTCM 7276 32 32 7308 6218 Tubing/vacuum insulated tbg 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^/ BOP Sketch^ Drilling Program^ Time v. Depth Plot^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program /^ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V. Johnson 265-6t3$1 Printed Name Chip Alvord 6 Title WNS Drilling Team Lead 7 Signature ~ ~ ~,, ~~ Phone ZGS- I:9~ g Date S/2S"/O (, V John n Commission Use Only Permit to Drill Number: ~~~ - ~ ~'~ API Number: 50- ~Q 3 - ~ 533 ~~ Permit Approval Date: ~ ~ . O See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydr es or gas contained in shales: Samples req'd: Yes ^ No u o req'd: Yes ^ No Other: 3SnU~*~~ t~.~r`.~vr~ 3bQ ~S~ H2S measures: Yes ^ o it io req'd: Yes [>r]'r No ^ PPROVE Y THE COMMISSION ~ s DATE: ~~ O , COMMISSIONE Form 10-401 Revised 12/2005 Sub~~n ~ pljcaoteG d~t • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 25, 2006 Conoco~illi s p -r l , v Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-210 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well from the Nanuq (CD4) drilling pad. The intended spud date for this well is 06/15/2006. It is intended that Doyon Rig 19 be used to drill the well. After setting 7" intermediate casing, the undulating horizontal section will be drilled and the well completed as a slotted liner producer. At the end of the rig work program, the well will be flowed back for 5 - 15 days to mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities construction that will allow the well to begin production fourth quarter 2006. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. There have been 5 surface holes drilled at CD4. and there has not been a significant show of shallow gas or gas hydrates. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, 6081, or C ip Alvord at 265-6120. Si ely, ~~ ~/~ ~_ Vern Joh on Drilling Engineer please contact Vern Johnson at 265- • • Attachments cc: CD4-210 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Liz Galiunas ATO 1704 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation CD4-210 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casino Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densi cement slurries 8-3/4" Hole / 7" Casino Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations ~~~ ' ~ cS S C ` ov ~ Check for flow during connections and if needed, >2000 TVD a -~ increase mud wei ht. Lost circulation ~ ~« Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1 /8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers ~'~~AL • Nanug : CD4-210 Procedure 1) Move on Doyon 19, dewater cellar as needed. 2) Rig up riser. • 3) Drill 12-%" hole to the surface casing point as per the directional plan. (Directional/MWD). 4) Run and cement 9-5/8" surface casing. 5) Install and test BOPE to 5000 psi. 6) Pressure test casing to 2500 psi. 7) Drill out 20' of new hole. Perform leak off test. 8) Pick up and run in hole with 8-3/4" drilling BHA. s 9) Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 10) Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11) BOPE test to 5000 psi. 12) Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 13) Displace well to Mineral oil based mud. 14) Drill 6-1 /8" horizontal section to well TD (LWD Program: GR/RES/PWD/Sonic tool for cement evaluation). 15) Circulate the hole clean and pull out of hole. 16) Run lower completion with slotted liner and liner hanger, set hanger and pull out of hole. 17) Run 3-'/z, 9.3#, L-80 tubing with Vacuum insulated tubing, TRMAXX SCSSSV, gas lift mandrels, packer and stinger assembly. Sting in, space out and land hanger. 18) Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19) Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20) Circulate tubing to diesel and install freeze protection in the annulus. 21) Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 22) Set BPV and secure well. Move rig off. ~''~ ~ ~l SAL • • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. Nanuq 5 is the closest well. Well separation is 18.2 @ 830' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Nanuq reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally - as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD4-210 will be injected into a permitted annulus on CD4 pad or the class 2 disposal well on CD1 pad. The CD4-210 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Nanuq reservoir and there will be 500' of cement fill above the top of the Nanuq as per regulations. Upon completion of CD4-210 form 10-403, Application for Sundry Operations,will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500'. thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi .~ ~:' ~~ SAL • • DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint-12'/" Intermediate hole to 7" casing point - 8 3/4" Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 8.1-8.8 ppg PV 10-25 10-15 YP 20 - 60 15 - 25 25 -30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10-15 10 minute gels <18 12-20 API Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) NA HPHT Fluid Loss at 160 12-14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0-9.5 KCL 6% Oil /water ratio Approx. 60/30 Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. - Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a 60/30 oil/water ratio M-I Versa-Pro mineral oil based drill-in fluid. The base fluid will consist of high flashpoint (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. oRiriNa~ • • CD4 - 210 Nanuq Nauuq Producer Completion 16" Insulated Conductor to -114' 2) 4-'/2' x 3-'/z" Vacuum insulated tubing (VIT) 2.813" 'X' TRMAXX SCSSSV 9-5/8" 40 ppf L-80 BTCM Surtace Casing 2540' MD / 2400' TVD 4) 4-'/=' x 3-'/:" Vacuum insulated tubing (VIT) to +/- 4000' MD Upper Completion: Top MD TVD 1) Tubing Hanger 32' 32' 2) 4-1/2" x 3 '/~' VIT 3-''/d' buttress-Mod connection 3) 3-1/2" Camco TRMAXX SCSSSV w/ X profile 2094' 2000' 4) 4-1/2" x 3 '/~' VIT 3-'/~' buttress-Mod connection 5) Crossover from VIT (3-%' IBTM) to EUE-M tubin g 4000' 3708' 6) 3-'/~' 9.3#/ft, EUE-M 7) Camco KBMG 1" GLM w/dummy valve 4324' 4000' 8) 3 '/~' 9.3#/ft, EUE-M 9) Camco KBMG 1" GLM w/dummy valve 6700' 5989' 10) 3 '/z' 9.3#/ft, EUE-M (2) 11) Baker Premier Packer 6780' 6031' 12) 3-'/~' 9.3#/ft, EUE-M (2) 13) HES "XN" (2.75" min ID) 6850' 6065' 14) 3-'/i' 9.3#/ft, EUE-M 15) BOT Stinger with Fluted VVLEG/pup/shear sub 7270' 6210' bottom, 3' spaceout @ 7308' Planned top of cement 6480' MD / 5857' TVD Nanuq Reservoir at +/- Lower Completion: Top MD TVD 16) Baker 5" x 7" Flexlock Liner Hanger 7273' 6211' 17) 3-'/~' 9.3#/ft L-80 SLHT Tubing 18) 3-'/~' 9.3#/ft L-80 SLHT slotted liner w/ blank across shale and slots across sand 19) Baker Shoe 13105' 6205' 3-'/~' 9.3#/ft L-80 SLHT Slotted liner Pattern: .... :!`,I 32 slots / ft. 2-'/<" x 1 /8" slots 7" 26 ppf L-80 BTC Mod Production Casing @ +/-83° 7423' MD, 6235' TVD TD 6-1/8" hole 13115' MD / 6205' TVD ~'R~GINAL C D4-210 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 2540 / 2400 14.5 1086 1598 7" 7423 / 6235 16.0 2821 2201 N/A 13115 / 6205 16.0 2807 - N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x 114=53 psi OR ASP =FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1 ] x 2400 = 1570 psi OR ASP =FPP - (0.1 x D) = 2821 - (0.1 x 6235') = 2197 psi 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 2821 - (0.1 x 6205') = 2201 psi ~ ~~ ~~' ~` ~ A L ,~ • Cementing Program: 9 5/8" Surface Casing run to 2540' MD / 2400' TVD. Cement from 2540' MD to 2040' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2040' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1000' MD). Lead slurry: (2040'-1600') X 0.3132 ft3/ft X 1.5 (50% excess) = 206.7 ft3 below permafrost 1600' X 0.3132 ft3/ft X 4 (300% excess) = 2004.5 ft3 above permafrost Total volume = 206.7 + 2004.5 = 2211.2 ft3 => 497 Sx @ 4.45 ft3/sk System: 497 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 7423' MD / 6235' TVD Cement from 7423' MD to 6480' MD (300' MD above the packer & minimum 500' MD above top of Nanuq reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (7423' X480') X 0.1503 ft3/ft X 1.4 (40% excess) = 198.4 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 198.4 + 17.2 = 215.6 ft3 => 186 Sx @ 1.16 ft3/sk System: 186 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk ' By Weight Of mix Water, all other additives are ~~~~ ~ ~ r • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD4 Plan: CD4-210 Plan: CD4-210 Plan: CD4-210wp06 Proposal Report 10 May, 2006 Sperry Drilling Services ORIGINAL .~ ConocoPhillips Alaska MALLIBIJRTOfV Ep~rry Driillny >hrvie~s 4500 ~I ~ 3000 ~+ 1 1500 Sun Method: Trav. G~Ainder North Errn Surfaca: Elliptical Canic Colville River Unit Warning Method: Rules Based Geodetic Datum: NAD 7927 (NADCON CONUS) Alpine CD4 Magnetic Model: BGGM2095 Plan: CD4-210 CD4-210wp06 Ground Level: 19.60 Plan: CD4-210 RKB: Planned Doyon 19 C 55.90ft IDOyon 19 (36.3 + 19.6)1 NorthinglASP V: 595748377 CD4-210wp06 6 c0°' 2,~Qo " " 4 1 /2 Ln r- 6 1 /8 Hole j _ ~ Target (Toe); 13115' MD, 6205' TVD, 3612' FNL 8 4988' FEL; Sec13-T11 N-R04E ~ Target (T4); 11917' MD, 6250' TVD Target (T3); 11018' MD, 6230' TVD Target (T2); 8323' MD, 6250' TVD 0 _ Target (Heel); 7423' MD, 6235' TVD ; 7" Csg - 8 3/4" Hole -- 7" Csg Pt; 7423' MD, 6235' TVD; 3449' FNL 8 2499' FEL; Sec24-T11 N-R04E SHL; 2928' FNL 8 245' FEL; Sec24-T11 N-R04E ', Kick-Gff Point; 3° DLS, 0° TFO, 600' MD, 600' TVD Start Sail; 26.3° INC, 1475' MD, 1445' -1500- - - _ - '`~ Begin Dir; 4° DLS, 115° TFO, 5073' MD, 4671' TVD -6000 -4500 -3000 -1500 West(-)/East(+l (1500 ft/inl 0 _ I _ O - - O ~ Base Permafrost N ~ _ ~ 2500 ~ ran -. - -- Q r- C-30 - ~ I C-20 ~ U ____ uz - _ ~ K-2 Base > 5000 - 9 5/8" Csg - 12 1/4" Hole 9-5/8" Csg Pt; 2540' MD, 2400' TVD 0 1500 SHL; 2928' FNL & 245' FEL; Sec24-T11 N-R04E Kick-off Point; 3° DLS, 0° TFO, 600' MD, 600' TVD Start Sail; 26.3° INC, 1475' MD, 1445' TVD 9 5/8" Csg - 12 1/4" Hole 9-518" Csg Pt; 2540' MD, 2400' TVD Begin Dir; 4° DLS, 115° TFO, 5073' MD, 4671' TVD ---- _ - - 7" Csg - 8 3/4" Hole 6235' TVD; 3449' FNL 8 2499' FEL; Sec24-;Target (Toe); 13115' MD, 6205' TVD, 3612' FNL 8 4988' FEL; Sec13-T11 N-R04E Target (T2); 8323' MD, 6250' TVD L ~ ap- Target (T4); 11917 MD, 6250' TVD - Albian 97- --- --i ~ ~o o rn ~ Top Nanuq (Albian 96) ' ^ `O Target (Heel); 7423' MD, 6235' TVD -5000 -2500 0 41/2" Lnr-61/8" Hole Target (T3); 11018' MD, 6230' TVD t' v 1-- - - - 2500 5000 ~~~~~7500 __ _i n~ ~ nno incnn rsr~~ 10000 f11t/ -1.. ~ ~ / Sperry Drilling Services ~ ~~ MAL.I.IBUFlTC~N ~OI IOCO t`t 11 Ip5 Planning Report -Geographic - - - -- - Alaska Sperry Drttttng Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD4-210 Company: ConocoPhiAips Alaska Inca TVD Reference: Planned Doyon 19 @ 55.90ft (Doyon 19 (36.3 + 19.6)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 55.90ft,(Doyon 19 (36.3 + 19.6)). Site: Alpine CD4 North Reference: True Well: Plan: CD4-210 Survey Calculation Method: Minimum Curvature Wellbore: Plah: CD4-210 Design: CD4-210wp06 Project Colville 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: CD4-210 Well Position +N/-S 0.00 ft Northing: 5,957,483.77ft Latitude: 70° 17' 32.521" N +E/-W 0,00 ft Easting: 377,999.47 ft Longitude: 150° 59' 15.850" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.60ft Wellbore Plan: CD4-210 Magnetics Model Name Design Audit Notes: Version: Vertical Section BGGM2005 _- CD4-210wp06 Sample Date 5/25/2006 Phase: Depth From (TVD) (ft) 36.30 Declination Dip Angle Field Strength ', 23.32 80.63 57,500 PLAN Tie On Depth: 36.30 +N/-S +EhW Direction 0.00 0.00 314.00 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/.S +E/_yy Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 ~ 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 0.00 1,475.81 26.27 220.01 1,445.44 -151.14 -126.85 3.00 3.00 0.00 0.00 5,073.18 26.27 220.01 4,671.14 -1,370.90 -1,150.61 0.00 0.00 0.00 0.00 7,423.37 83.00 334.07 6,235.90 -520.47 -2,254.51 4.00 2.41 4.85 114.70 7,589.77 89.66 334.07 6,246.55 -371.20 -2,327.08 4.00 4.00 0.00 0.00 8,305.94 89.66 334.07 6,250.85 272.86 -2,640.20 0.00 0.00 0.00 0.00 8,323.13 90.00 334.07 6,250.90 288.33 -2,647.72 2.00 2.00 0.01 0.22 8,344.55 90.43 334.07 6,250.82 307.59 -2,657.08 2.00 2.00 0.00 0.02 10,997.43 90.43 334.07 6,230.98 2,693.41 -3,816.92 0.00 0.00 0.00 0.00 11,018.90 90.00 334.05 6,230.90 2,712.72 -3,826.31 2.00 -2.00 -0.13 -176.21 11,087.97 88.62 334.04 6,231.73 2,774.82 -3,856.54 2.00 -2.00 0.00 -179.96 11,848.45 88.62 334.04 6,250.07 3,458.40 -4,189.29 0.00 0.00 0.00 0.00 11,917.54 90.00 334.07 6,250.90 3,520.51 -4,219.51 2.00 2.00 0.03 0.96 12,156.61 92.39 334.07 6,245.91 3,735.45 -4,324.02 1.00 1.00 0.00 0.00 13,115.73 92.39 334.07 6,205.90 4,597.25 -4,743.09 0.00 0.00 0.00 0.00 5/10/2006 1:21:47PM Page 2 of 7 COMPASS 2003.11 Build 50 Q ~ ~ ~ ~ i V '~-' , ~ Sperry Drilling Services C©norCtaP"h~~l~ s Ma~.~.aBUA-ror~ p Planning Report -Geographic ql Sperry Drilling Services Database: EDM 2003.11 Single Userpb Local Co-ordinate Reference: Well Plan: CD4-210 Company: ConocoPhillips Alaska Inc.. TVD Reference: Planned Doyon 19 @ 55.90ff(Doyon 19 (36.3 + 19.6)} Project: Cobille River Unit MD Reference: Planned Doyon 19 @ 55:90ft (Doyon 19 (36.3.+ 19.6)} Site: Alpine CD4 North Reference: True Well: Pla n: CD4-210 Survey Calculation Method: Minimum Curvature Wellbore: Pla n: CD4'-210 Design: CD4-210wp06 Planned Survey CD4-210wp06 Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°I100ft) (ft) 36.30 0.00 0.00 36.30 -19.60 0.00 0.00 5,957,483.77 377,999.47 0.00 0.00 SHL; 2928 ' FNL 8~ 245' FEL; Sec24-T11 N-R04E 100.00 0.00 0.00 100.00 44.10 0.00 0.00 5,957,483.77 377,999.47 0.00 0.00 200.00 0.00 0.00 200.00 144.10 0.00 0.00 5,957,483.77 377,999.47 0.00 0.00 600.00 0.00 0.00 600.00 544.10 0.00 0.00 5,957,483.77 377,999.47 0.00 0.00 Kick-off Point; 3° DLS, 0° TFO, 60 0' MD, 600' TVD - 700.00 3.00 220.01 699.95 644.05 -2.00 -1.68 5,957,481.79 377,997.76 3.00 -0.18 800.00 6.00 220.01 799.63 743.73 -8.01 -6.73 5,957,475.87 377,992.62 3.00 -0.73 900.00 9.00 220.01 898.77 842.87 -18.01 -15.12 5,957,466.01 377,984.06 3.00 -1.64 1,000.00 12.00 220.01 997.08 941.18 -31.97 -26.83 5,957,452.24 377,972.13 3.00 -2.91 1,100.00 15.00 220.01 1,094.31 1,038.41 -49.85 -41.84 5,957,434.61 377,956.83 3.00 -4.53 1,200.00 18.00 220.01 1,190.18 1,134.28 -71.60 -60.09 5,957,413.16 377,938.23 3.00 -6.51 1,300.00 21.00 220.01 1,284.43 1,228.53 -97.16 -81.55 5,957,387.95 377,916.36 3.00 -8.83 1,377.17 23.32 220.01 1,355.90 1,300.00 -119.46 -100.26 5,957,365.97 377,897.29 3.00 -10.86 Base Permafrost 1,400.00 24.00 220.01 1,376.81 1,320.91 -126.47 -106.15 5,957,359.05 377,891.29 3.00 -11.50 1,475.81 26.27 220.01 1,445.44 1,389.54 -151.14 -126.85 5,957,334.72 377,870.19 3.00 -13.74 Start Sail; 26.3° INC, 1475' MD, 1445' TVD 1,500.00 26.27 220.01 1,467.13 1,411.23 -159.34 -133.74 5,957,326.63 377,863.18 0.00 -14.49 1,600.00 26.27 220.01 1,556.79 1,500.89 -193.25 -162.19 5,957,293.20 377,834.17 0.00 -17.57 1,700.00 26.27 220.01 1,646.46 1,590.56 -227.15 -190.65 5,957,259.76 377,805.17 0.00 -20.65 1,800.00 26.27 220.01 1,736.13 1,680.23 -261.06 -219.11 5,957,226.32 377,776.17 0.00 -23.73 1,900.00 26.27 220.01 1,825.80 1,769.90 -294.97 -247.57 5,957,192.88 377,747.17 0.00 -26.81 2,000.00 26.27 220.01 1,915.47 1,859.57 -328.87 -276.03 5,957,159.45 377,718.16 0.00 -29.90 2,100.00 26.27 220.01 2,005.14 1,949.24 -362.78 -304.49 5,957,126.01 377,689.16 0.00 -32.98 2,200.00 26.27 220.01 2,094.81 2,038.91 -396.69 -332.95 5,957,092.57 377,660.16 0.00 -36.06 2,300.00 26.27 220.01 2,184.47 2,128.57 -430.60 -361.40 5,957,059.13 377,631.16 0.00 -39.14 2,321.66 26.27 220.01 2,203.90 2,148.00 -437.94 -367.57 5,957,051.89 377,624.87 0.00 -39.81 C-40 2,400.00 26.27 220.01 2,274.14 2,218.24 -464.50 -389.86 5,957,025.69 377,602.15 0.00 -42.23 2,500.00 26.27 220.01 2,363.81 2,307.91 -498.41 -418.32 5,956,992.26 377,573.15 0.00 -45.31 2,540.36 26.27 220.01 2,400.00 2,344.10 -512.09 -429.81 5,956,978.76 377,561.44 0.00 -46.55 9-518" Csg Pt; 2540' MD, 2400' TVD - 9 5/8" Csg - 12 1/4" Hole 2,544.71 26.27 220.01 2,403.90 2,348.00 -513.57 -431.05 5,956,977.31 377,560.18 0.00 -46.69 C-30 2,600.00 26.27 220.01 2,453.48 2,397.58 -532.32 -446.78 5,956,958.82 377,544.15 0.00 -48.39 2,700.00 26.27 220.01 2,543.15 2,487.25 -566.22 -475.24 5,956,925.38 377,515.14 0.00 -51.47 2,800.00 26.27 220.01 2,632.82 2,576.92 -600.13 -503.70 5,956,891.94 377,486.14 0.00 -54.56 2,900.00 26.27 220.01 2,722.48 2,666.58 -634.04 -532.16 5,956,858.50 377,457.14 0.00 -57.64 2,952.88 26.27 220.01 2,769.90 2,714.00 -651.97 -547.21 5,956,840.82 377,441.80 0.00 -59.27 C-20 3,000.00 26.27 220.01 2,812.15 2,756.25 -667.95 -560.61 5,956,825.07 377,428.14 0.00 -60.72 3,100.00 26.27 220.01 2,901.82 2,845.92 -701.85 -589.07 5,956,791.63 377,399.13 0.00 -63.80 3,200.00 26.27 220.01 2,991.49 2,935.59 -735.76 -617.53 5,956,758.19 377,370.13 0.00 -66.89 3,300.00 26.27 220.01 3,081.16 3,025.26 -769.67 -645.99 5,956,724.75 377,341.13 0.00 -69.97 3,400.00 26.27 220.01 3,170.83 3,114.93 -803.57 -674.45 5,956,691.31 377,312.13 0.00 -73.05 5/10/2006 1:21:47PM Page 3 of 7 COMPASS 2003.11 Build 50 OR!GI~!AI, ~ ~ `/ Sperry Drilling Services Ph tl ~ qTo i"A`"~~' "' Conoc a i ~ s p Planning Report -Geographic glas}~ $pmrry Drilling Services Database: EDM 2003.11 Si ngle UsecDb Local Co-ordinate Reference: Well Plan;: CD 4-210. Company: ConocoPhillips Alaska lnc: TVD Reference: Planned Doyon 19 @ 55.90ft (Doyon 19 (36.3"+ 19.6)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 55:90ft (Doyon 19 (36.3 + 19.6)) Site: Alpine CD4 North Reference: True Well: Plan: CD4-210 Survey Calculation Method: Minimum Curvature Wellbore: Plan' CD4-210 Design: CD4-210wp06 Planned Survey CD4-210wp06 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) 3,500.00 26.27 220.01 3,260.49 3,204.59 -837.48 -702.91 5,956,657.88 377,283.12 0.00 -76.13 3,600.00 26.27 220.01 3,350.16 3,294.26 -871.39 -731.37 5,956,624.44 377,254.12 0.00 -79.22 3,700.00 26.27 220.01 3,439.83 3,383.93 -905.29 -759.83 5,956,591.00 377,225.12 0.00 -82.30 3,800.00 26.27 220.01 3,529.50 3,473.60 -939.20 -788.28 5,956,557.56 377,196.11 0.00 -85.38 3,900.00 26.27 220.01 3,619.17 3,563.27 -973.11 -816.74 5,956,524.12 377,167.11 0.00 -88.46 4,000.00 26.27 220.01 3,708.84 3,652.94 -1,007.02 -845.20 5,956,490.69 377,138.11 0.00 -91.55 4,100.00 26.27 220.01 3,798.50 3,742.60 -1,040.92 -873.66 5,956,457.25 377,109.11 0.00 -94.63 4,141.70 26.27 220.01 3,835.90 3,780.00 -1,055.06 -885.53 5,956,443.30 377,097.01 0.00 -95.91 K-3 4,200.00 26.27 220.01 3,888.17 3,832.27 -1,074.83 -902.12 5,956,423.81 377,080.10 0.00 -97.71 4,300.00 26.27 220.01 3,977.84 3,921.94 -1,108.74 -930.58 5,956,390.37 377,051.10 0.00 -100.79 4,382.59 26.27 220.01 4,051.90 3,996.00 -1,136.74 -954.08 5,956,362.76 377,027.15 0.00 -103.34 K3_Basal 4,400.00 26.27 220.01 4,067.51 4,011.61 -1,142.64 -959.04 5,956,356.93 377,022.10 0.00 -103.87 4,421.62 26.27 220.01 4,086.90 4,031.00 -1,149.98 -965.19 5,956,349.70 377,015.83 0.00 -104.54 K-2 4,500.00 26.27 220.01 4,157.18 4,101.28 -1,176.55 -987.49 5,956,323.50 376,993.10 0.00 -106.96 4,542.07 26.27 220.01 4,194.90 4,139.00 -1,190.81 -999.47 5,956,309.43 376,980.89 0.00 -108.25 K-2 Base 4,600.00 26.27 220.01 4,246.85 4,190.95 -1,210.46 -1,015.95 5,956,290.06 376,964.09 0.00 -110.04 4,700.00 26.27 220.01 4,336.52 4,280.62 -1,244.36 -1,044.41 5,956,256.62 376,935.09 0.00 -113.12 4,800.00 26.27 220.01 4,426.18 4,370.28 -1,278.27 -1,072.87 5,956,223.18 376,906.09 0.00 -116.20 4,900.00 26.27 220.01 4,515.85 4,459.95 -1,312.18 -1,101.33 5,956,189.75 376,877.08 0.00 -119.29 5,000.00 26.27 220.01 4,605.52 4,549.62 -1,346.09 -1,129.79 5,956,156.31 376,848.08 0.00 -122.37 5,073.18 26.27 220.01 4,671.14 4,615.24 -1,370.90 -1,150.61 5,956,131.84 376,826.86 0.00 -124.62 Begin Dir; 4° DLS, 115° TFO, 507 3' MD, 4671' TVD 5,100.00 25.84 222.24 4,695.23 4,639.33 -1,379.77 -1,158.36 5,956,123.09 376,818.97 4.00 -125.22 5,200.00 24.56 231.15 4,785.75 4,729.85 -1,408.96 -1,189.21 5,956,094.41 376,787.65 4.00 -123.30 5,300.00 23.85 240.76 4,876.99 4,821.09 -1,431.88 -1,223.05 5,956,072.05 376,753.45 4.00 -114.88 5,400.00 23.75 250.68 4,968.52 4,912.62 -1,448.42 -1,259.71 5,956,056.11 376,716.53 4.00 -100.00 5,500.00 24.29 260.43 5,059.90 5,004.00 -1,458.50 -1,299.01 5,956,046.66 376,677.07 4.00 -78.73 5,600.00 25.41 269.57 5,150.67 5,094.77 -1,462.09 -1,340.76 5,956,043.76 376,635.27 4.00 -51.18 5,700.00 27.05 277.83 5,240.40 5,184.50 -1,459.14 -1,384.77 5,956,047.41 376,591.32 4.00 -17.49 5,800.00 29.12 285.12 5,328.64 5,272.74 -1,449.69 -1,430.81 5,956,057.61 376,545.45 4.00 22.19 5,900.00 31.53 291.45 5,414.98 5,359.08 -1,433.78 -1,478.65 5,956,074.29 376,497.87 4.00 67.67 6,000.00 34.21 296.92 5,498.98 5,443.08 -1,411.48 -1,528.08 5,956,097.39 376,448.81 4.00 118.71 6,100.00 37.10 301.66 5,580.23 5,524.33 -1,382.91 -1,578.84 5,956,126.78 376,398.53 4.00 175.08 6,200.00 40.16 305.80 5,658.35 5,602.45 -1,348.19 -1,630.69 5,956,162.33 376,347.25 4.00 236.49 6,300.00 43.35 309.43 5,732.95 5,677.05 -1,307.51 -1,683.38 5,956,203.86 376,295.24 4.00 302.64 6,400.00 46.64 312.65 5,803.67 5,747.77 -1,261.06 -1,736.64 5,956,251.16 376,242.74 4.00 373.23 6,444.65 48.13 313.98 5,833.90 5,778.00 -1,238.52 -1,760.54 5,956,274.09 376,219.21 4.00 406.08 Albian 97 6,500.00 50.01 315.54 5,870.16 5,814.26 -1,209.07 -1,790.23 5,956,304.01 376,190.01 4.00 447.89 6,600.00 53.44 318.15 5,932.10 5,876.20 -1,151.78 -1,843.87 5,956,362.16 376,137.30 4.00 526.27 6,700.00 56.93 320.54 5,989.19 5,933.29 -1,089.49 -1,897.31 5,956,425.31 376,084.89 4.00 607.99 6,800.00 60.46 322.75 6,041.15 5,985.25 -1,022.48 -1,950.29 5,956,493.16 376,033.01 4.00 692.65 6,900.00 64.02 324.80 6,087.73 6,031.83 -951.10 -2,002.55 5,956,565.37 375,981.92 4.00 779.83 5/10/2006 1:21:47PM Page 4 of 7 COMPASS 2003.11 Build 50 ®~ ~ / Sperry Drillin g Services ~ ' HA LL~~E3ut ~TC~1V C011t}C ©~ tl~~l Planning Report -Geographic __ Alaska Spsrry Drifting $aFeyic$~ Database: EDM 2003.11 Si ngle User Db Local Co-ordinate Reference: Well Plan: CD4-210 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 55:90ft (Doyon 19 (36.3 + 19.6)} Project: Colvipe River Unit MD Reference: Planned Doyon 99 @ 55.90ft (Doyon 19 (36.3 + 19.6)) Site: Alpine ;GD4 North Reference: True Well: Plan: CD4-210 Survey Calculati on Method: Minimum Curvature Wellbore: Plan: CD4-210 Design: CD4-21Owp06 Planned Survey CD4-210wp06 Map Map ~~ MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Yert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 7,000.00 67.61 326.74 6,128.69 6,072.79 -875.68 -2,053.83 5,956,641.61 375,931.87 4.00 869.11 7,100.00 71.22 328.57 6,163.84 6,107.94 -796.59 -2,103.89 5,956,721.49 375,883.11 4.00 960.05 7,199.55 74.84 330.33 6,192.90 6,137.00 -714.60 -2,152.26 5,956,804.25 375,836.07 4.00 1,051.80 Top Nanuq (Albian 96) 7,200.00 74.85 330.33 6,193.02 6,137.12 -714.23 -2,152.48 5,956,804.62 375,835.86 3.74 1,052.22 7,300.00 78.49 332.03 6,216.07 6,160.17 -628.98 -2,199.36 5,956,890.61 375,790.38 4.00 1,145.16 7,400.00 82.14 333.69 6,232.88 6,176.98 -541.27 -2,244.31 5,956,979.03 375,746.86 4.00 1,238.42 7,423.37 83.00 334.07 6,235.90 6,180.00 -520.47 -2,254.51 5,957,000.00 375,737.00 4.01 1,260.21 7" Csg Pt; 7423' MD, 6235' TVD; 3449' FNL 8, 2499' FEL; Sec24-T71 N-R04E -Target (Heel); 7423' MD, 6235' TVD - 7" Csg - 8 3/4" Hole - CD4- 7,500.00 86.06 334.07 6,243.20 6,187.30 -451.87 -2,287.86 5,957,069.12 375,704.77 4.00 1,331.85 7,589.77 89.66 334.07 6,246.55 6,190.65 -371.20 -2,327.08 5,957,150.41 375,666.87 4.00 1,416.10 7,600.00 89.66 334.07 6,246.61 6,190.71 -362.01 -2,331.55 5,957,159.68 375,662.55 0.00 1,425.70 7,700.00 89.66 334.07 6,247.21 6,191.31 -272.07 -2,375.27 5,957,250.30 375,620.30 0.00 1,519.63 7,800.00 89.66 334.07 6,247.81 6,191.91 -182.14 -2,418.99 5,957,340.92 375,578.04 0.00 1,613.55 7,900.00 89.66 334.07 6,248.41 6,192.51 -92.21 -2,462.72 5,957,431.55 375,535.79 0.00 1,707.48 8,000.00 89.66 334.07 6,249.01 6,193.11 -2.27 -2,506.44 5,957,522.17 375,493.53 0.00 1,801.40 8,100.00 89.66 334.07 6,249.61 6,193.71 87.66 -2,550.16 5,957,612.79 375,451.28 0.00 1,895.33 8,200.00 89.66 334.07 6,250.21 6,194.31 177.59 -2,593.88 5,957,703.42 375,409.03 0.00 1,989.25 8,300.00 89.66 334.07 6,250.81 6,194.91 267.53 -2,637.61 5,957,794.04 375,366.77 0.00 2,083.17 8,305.94 89.66 334.07 6,250.85 6,194.95 272.86 -2,640.20 5,957,799.42 375,364.26 0.00 2,088.75 8,323.13 90.00 334.07 6,250.90 6,195.00 288.33 -2,647.72 5,957,815.00 375,357.00 2.00 2,104.90 Target (T2); 8323' MD, 6250' TVD -CD4-210wp0 5 T2 8,344.55 90.43 334.07 6,250.82 6,194.92 307.59 -2,657.08 5,957,834.42 375,347.95 2.00 2,125.02 8,400.00 90.43 334.07 6,250.41 6,194.51 357.46 -2,681.33 5,957,884.67 375,324.52 0.00 2,177.10 8,500.00 90.43 334.07 6,249.66 6,193.76 447.39 -2,725.05 5,957,975.29 375,282.27 0.00 2,271.02 8,600.00 90.43 334.07 6,248.91 6,193.01 537.33 -2,768.77 5,958,065.91 375,240.02 0.00 2,364.94 8,700.00 90.43 334.07 6,248.16 6,192.26 627.26 -2,812.49 5,958,156.54 375,197.77 0.00 2,458.86 8,800.00 90.43 334.07 6,247.41 6,191.51 717.19 -2,856.21 5,958,247.16 375,155.52 0.00 2,552.79 8,900.00 90.43 334.07 6,246.67 6,190.77 807.13 -2,899.93 5,958,337.78 375,113.26 0.00 2,646.71 9,000.00 90.43 334.07 6,245.92 6,190.02 897.06 -2,943.65 5,958,428.41 375,071.01 0.00 2,740.63 9,100.00 90.43 334.07 6,245.17 6,189.27 986.99 -2,987.37 5,958,519.03 375,028.76 0.00 2,834.55 9,200.00 90.43 334.07 6,244.42 6,188.52 1,076.93 -3,031.09 5,958,609.65 374,986.51 0.00 2,928.48 9,300.00 90.43 334.07 6,243.67 6,187.77 1,166.86 -3,074.81 5,958,700.28 374,944.26 0.00 3,022.40 9,400.00 90.43 334.07 6,242,93 6,187.03 1,256.79 -3,118.53 5,958,790.90 374,902.01 0.00 3,116.32 9,500.00 90.43 334.07 6,242.18 6,186.28 1,346.73 -3,162.25 5,958,881.52 374,859.76 0.00 3,210.24 9,600.00 90.43 334.07 6,241.43 6,185.53 1,436.66 -3,205.97 5,958,972.15 374,817.51 0.00 3,304.17 9,700.00 90.43 334.07 6,240.68 6,184.78 1,526.59 -3,249.69 5,959,062.77 374,775.25 0.00 3,398.09 9,800.00 90.43 334.07 6,239.94 6,184.04 1,616.53 -3,293.41 5,959,153.39 374,733.00 0.00 3,492.01 9,900.00 90.43 334.07 6,239.19 6,183.29 1,706.46 -3,337.13 5,959,244.02 374,690.75 0.00 3,585.93 10,000.00 90.43 334.07 6,238.44 6,182.54 1,796.39 -3,380.85 5,959,334.64 374,648.50 0.00 3,679.86 10,100.00 90.43 334.07 6,237.69 6,181.79 1,886.33 -3,424.57 5,959,425.26 374,606.25 0.00 3,773.78 10,200.00 90.43 334.07 6,236.94 6,181.04 1,976.26 -3,468.29 5,959,515.89 374,564.00 0.00 3,867.70 10,300.00 90.43 334.07 6,236.20 6,180.30 2,066.19 -3,512.01 5,959,606.51 374,521.75 0.00 3,961.62 10,400.00 90.43 334.07 6,235.45 6,179.55 2,156.13 -3,555.73 5,959,697.13 374,479.50 0.00 4,055.55 10,500.00 90.43 334.07 6,234.70 6,178.80 2,246.06 -3,599.45 5,959,787.76 374,437.25 0.00 4,149.47 10,600.00 90.43 334.07 6,233.95 6,178.05 2,335.99 -3,643.17 5,959,878.38 374,394.99 0.00 4,243.39 10,700.00 90.43 334.07 6,233.20 6,177.30 2,425.93 -3,686.89 5,959,969.01 374,352.74 0.00 4,337.31 10,800.00 90.43 334.07 6,232.46 6,176.56 2,515.86 -3,730.61 5,960,059.63 374,310.49 0.00 4,431.24 10,900.00 90.43 334.07 6,231.71 6,175.81 2,605.79 -3,774.33 5,960,150.25 374,268.24 0.00 4,525.16 5/10/2006 1:21:47PM Page 5 of 7 COMPASS 2003.11 Build 50 ~~~~~r~ ConocoPhi~lips Alaska Database: EDM 2003:.11 Single User Db Local Co-ordinate Reference: Well Plan: CD4-210 Company: ConocoPhillips Alaska )nc. TVD Reference: Planned Doyon 19 @ 55.90ft (Doyon 19 (36.3 + 19.6)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 5590ft (Doyon 19 (36.3 + 19.6)) Site: Alpine CD4 ' North Reference: True Well: Plan: CD4-210 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD4-210 Design: CD4-210wp06 Planned Survey ~ CD4-210wp06 _-- _ __-- ___ - _ - _ - ~~, Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Eastirtg DLSEV Vert Section (ft) ( °) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 10,997.43 90.43 334.07 6,230.98 6,175.08 2,693.41 -3,816.92 5,960,238.54 374,227.08 0.00 4,616.66 11,000.00 90.38 .334.07 6,230.96 6,175.06 2,695.73 -3,818.05 5,960,240.88 374,225.99 1.97 4,619.08 11,018.90 90.00 334.05 6,230.90 6,175.00 2,712.72 -3,826.31 5,960,258.00 374,218.00 2.00 4,636.83 Target (T3); 11018' MD, 6230' TVD -CD4-210w p05 T3 11,087.97 88.62 334.04 6,231.73 6,175.83 2,774.82 -3,856.54 5,960,320.58 374,188.79 2.00 4,701.72 11,100.00 88.62 334.04 6,232.02 6,176.12 2,785.63 -3,861.80 5,960,331.47 374,183.70 0.00 4,713.01 11,200.00 88.62 334.04 6,234.43 6,178.53 2,875.52 -3,905.56 5,960,422.05 374,141.41 0.00 4,806.93 11,300.00 88.62 334.04 6,236.84 6,180.94 2,965.41 -3,949.31 5,960,512.63 374,099.13 0.00 4,900.84 11,400.00 88.62 334.04 6,239.26 6,183.36 3,055.29 -3,993.07 5,960,603.21 374,056.84 0.00 4,994.76 11,500.00 88.62 334.04 6,241.67 6,185.77 3,145.18 -4,036.82 5,960,693.79 374,014.55 0.00 5,088.67 11,600.00 88.62 334.04 6,244.08 6,188.18 3,235.07 -4,080.58 5,960,784.36 373,972.27 0.00 5,182.59 11,700.00 88.62 334.04 6,246.49 6,190.59 3,324.96 -4,124.33 5,960,874.94 373,929.98 0.00 5,276.50 11,800.00 88.62 334.04 6,248.90 6,193.00 3,414.84 -4,168.09 5,960,965.52 373,887.70 0.00 5,370.42 11,848.45 88.62 334.04 6,250.07 6,194.17 3,458.40 -4,189.29 5,961,009.41 373,867.21 0.00 5,415.92 11,900.00 89.65 334.06 6,250.85 6,194.95 3,504.74 -4,211.84 5,961,056.11 373,845.41 2.00 5,464.34 11,917.54 90.00 334.07 6,250.90 6,195.00 3,520.51 -4,219.51 5,961,072.00 373,838.00 2.01 5,480.81 Target (T4); 11917' MD, 6250' TVD -CD4-210w p05 T4 12,000.00 90.82 334.07 6,250.31 6,194.41 3,594.67 -4,255.57 5,961,146.73 373,803.15 1.00 5,558.27 12,100.00 91.82 334.07 6,247.99 6,192.09 3,684.58 -4,299.29 5,961,237.32 373,760.90 1.00 5,652.17 12,156.61 92.39 334.07 6,245.91 6,190.01 3,735.45 -4,324.02 5,961,288.59 373,736.99 1.00 5,705.30 12,200.00 92.39 334.07 6,244.10 6,188.20 3,774.44 -4,342.98 5,961,327.88 373,718.67 0.00 5,746.03 12,300.00 92.39 334.07 6,239.93 6,184.03 3,864.29 -4,386.68 5,961,418.42 373,676.44 0.00 5,839.87 12,400.00 92.39 334.07 6,235.76 6,179.86 3,954.14 -4,430.37 5,961,508.96 373,634.22 0.00 5,933.72 12,500.00 92.39 334.07 6,231.59 6,175.69 4,044.00 -4,474.06 5,961,599.50 373,591.99 0.00 6,027.57 12,600.00 92.39 334.07 6,227.42 6,171.52 4,133.85 -4,517.76 5,961,690.05 373,549.77 0.00 6,121.41 12,700.00 92.39 334.07 6,223.24 6,167.34 4,223.70 -4,561.45 5,961,780.59 373,507.54 0.00 6,215.26 12,800.00 92.39 334.07 6,219.07 6,163.17 4,313.56 -4,605.14 5,961,871.13 373,465.32 0.00 6,309.11 12,900.00 92.39 334.07 6,214.90 6,159.00 4,403.41 -4,648.83 5,961,961.67 373,423.09 0.00 6,402.96 13,000.00 92.39 334.07 6,210.73 6,154.83 4,493.26 -4,692.53 5,962,052.22 373,380.87 0.00 6,496.80 13,100.00 92.39 334.07 6,206.56 6,150.66 4,583.11 -4,736.22 5,962,142.76 373,338.64 0.00 6,590.65 13,115.73 92.39 334.07 6,205.90 6,150.00 4,597.25 -4,743.09 5,962,157.00 373,332.00 0.00 6,605.41 Target (Toe); 13115' MD, 6205' TVD, 3612' FNL 8 4988' FEL; Sec13-T11 N-R04E - 41/2" Lnr - 61/8" Hole -CD4-210wp05 TS Sperry Drilling Services Planning Report -Geographic MALi.,IBURT0111 Sperry Drilling Services 5/10/2006 1:21:47PM Page 6 of 7 COMPASS 2003.11 Build 50 ORIGINAL Rh ll Sperry Drilling Services '"~``'"~"'~'~°"' Conoco i ~ s p Planning Report -Geographic Al Sperry Drilliing Services Database: EDM 2003.11 :Single User Db Local Co-ordinate Reference: Well Plan: CD4-210 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 55.90ft (Doyon 19 (36.3 + 19.6)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 55.90ft (Doyon 19 (36.3 + 19.6)) Site: Alpine CD4 North Reference: True Well: Plan: CD4-210 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD4-210 Design: CD4-210wp06 Geologic Targets Plan: CD4-210 TVD Target Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 6,230.90 CD4-210wp05 T3 2,712.72 -3,826.31 5,960,258.00 374,218.00 - Point 6,250.90 CD4-210wp05 T4 3,520.51 -4,219.51 5,961,072.00 373,838.00 - Point 6,250.90 CD4-210wp05 T2 288.33 -2,647.72 5,957,815.00 375,357.00 - Point 6,205.90 CD4-210wp05 T5 4,597.25 -4,743.09 5,962,157.00 373,332.00 - Point 6,235.90 CD4-210wp05 T1 -520.47 -2,254.51 5,957,000.00 375,737.00 - Point Prognosed Casing Points I Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (~~) (") 2,540.36 2,400.00 9-5/8 12-1/4 7,423.37 6,235.90 7 8-3/4 13,115.72 6,205.90 4-112 6-118 Prognosed Form ation Intersection Points Measured Vertical Depth (ft) Inclination Azimuth Depth (°) (°) (ft) +N!-E (ft) +E/-W (ft) Name 1,377.17 23.32 220.01 1,355.90 -119.46 -100.26 Base Permafrost 2,321.66 26.27 220.01 2,203.90 -437.94 -367.57 C-40 2,544.71 26.27 220.01 2,403.90 -513.57 -431.05 C-30 2,952.88 26.27 220.01 2,769.90 -651.97 -547.21 C-20 4,141.70 26.27 220.01 3,835.90 -1,055.06 -885.53 K-3 4,382.59 26.27 220.01 4,051.90 -1,136.74 -954.08 K3_Basal 4,421.62 26.27 220.01 4,086.90 -1,149.98 -965.19 K-2 4,542.07 26.27 220.01 4,194.90 -1,190.81 -999.47 K-2_Base 6,444.65 48.13 313.98 5,833.90 -1,238.52 -1,760.54 Albian 97 7,199.55 74.84 330.33 6,192.90 -714.60 -2,152.26 Top Nanuq (Albian 96) 5/10/2006 1:21:47PM Page 7 of 7 COMPASS 2003.11 Build 50 ~~'~~ G_. • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD4 Plan: CD4-210 Plan: CD4-210 CD4-210wp06 Anticollision Report 10 May, 2006 Sperry Drilling Services ORIGIN4L ~~ ConocoPhillips F4ALLIBYRTON ~iNeY OrdRK 7allkw •..m crw r. rp CD4-209wp07 i CD42061vp05 CDa207wp04 60 CD4204wp04 - _ CDI-211 ~1`, ,, CD4205wp04 130 / .. ~ . , coa2oawpod coa2oe coa2oepR1 Nor -1501 210; ; CD4213wp03 1801180 NEGATIVE TP09Ari values hom tl1e Survey Edibr or Travallina Cylinder Report Jnewa ee ploil•d on me rh ewe orehe Travelling cylina•c Travetling Cylinder Azimuth (TFO+AZI) [°) vs Centre to Centre Separation [25 Nin[ Trrveltleq CyNnder Aaimur (TFOfAZq i°) vs Centrr 1• Crnlre SepmfWe i5 ftlbi u-ze9wpo eei sm Im :1r1 T\D +V/Ji +FJ-w' ULeq TFace Verc Tarxel 1 saso alw e.oe 3a.3x e.ae aoo xlr n.xo aae z 6ao.no xnn e.ne 6oo.ee aao e.oe e.no e.oe o.m 3 IJJ5x1 2aD 2EO.U1 Ill5.1J -Ig.IJ -12ax5 3.m EE0.01 .uJJ J 5mate Ian zzo.ol J6]LU -IS]o.% -uw.61 n.ne e.m dza6E 5 ]133.3] Bi.00 3310] 6215 YO -520.1] -2351.51 Jlr 11170 1260.21 <21SSIOap05 T1 6 ]5x9.]] 89.66 33a0] 62J65G J]1.E0 -UI].OB J.M 11.00 IJIh10 ] 810(9) 89.66 330.01 6250.8-< 2]286 -36x1.20 0.00 0.00 20xx]S 8 x{21.13 911.x11 S}J.0] 6241.90 EBxJJ -2617.12 200 0.2I 21 M.% ('Di210wpM T2 9 MSJJ55 90.11 3330) 6250.8E JO].59 -2a5J.08 L011 0.0E SI25UE 10 1099'i.J3 90.13 SJJ.O] 6210.9N 2693.11 -381692 x.OD 0.00 161666 11 1101x911 90.00 331.05 62x1.90 2]12'3 -3826.31 t.00 -1]621 Jh1aR1 (T)0.EIOap05 TS 12 1108].91 Bx6E 3JJ.W 6211.]3 27]1.82 -5856.51 2.00 -179.% JJUI 7E I3 IlHixdS 8x63 530.x1 62;0.0] 315810 d189E9 0.00 0.00 511592 lJ 1191].51 90.00 331.81 6250.90 352x51 1219.51 2.00 0.% 51x0.81 ('U621Ap05 TJ 15 IIISa61 9239 331.0] 6215.91 3]3313 -JS2A112 1.00 0.00 5]IK30 16 13115]3 9239 3310'/ 6205.Y0 159].LS .1111.09 0.00 0.00 6605.11 <T16210wp05 TS 5/10/2006 9:49 AM i2o _ ~~,, ~~~ CD4212 (wp04). Critical Issues: 0/360 • C+DnocoRhillips Alaska Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Reference Site: Alpine CD4 Site Error: O.OOft Reference Well: Plan: CD4-210 Well Error: O.OOft Reference Wellbore Plan. CD4-210. Reference Design: CD4-210wp06 - Sperry Drilling Services Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HALLIBURTClN Sperry Drilling Services Well Plan: CD4-210 Planned Doyon 19 @ 55.90ft (Doyon 19 (36.3 + 19.6}) Planned Doyon 19 @ 55.90ft (Doyon 19 (36.3 + 19.6)) True Minimum Curvature 1.00-sigma EDM 2003.11 Single User Db Offset Datum Reference CD4-210wp06 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refers Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,507.94ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program From (ft) 36.30 1,000.00 Date 5/10/2006 To (ft) Survey (Wellbore) Tool Name Description 1,000.00 CD4-210wp06 (Plan: CD4-210) CB-GYRO-SS Camera based gyro single shot 13,115.73 CD4-210wp06 (Plan: CD4-210) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Site Name Offset Well -Wellbore -Design Alpine CD2 CD2-36 - CD 2-36 - CD 2-36 CD2-36 -CD2-36 PB1 -CD2-36 P61 CD2-37 -CD2-37 -CD2-37 Alpine CD4 CD4-208 -CD4-208 -CD4-208 CD4-208 -CD4-208P61 -CD4-208PB1 CD4-318 -CD4-318 -CD4-318 CD4-318 -CD4-318P61 -CD4-318P61 CD4-319 -CD4-319 -CD4-319 Nanuq 5 /Plan: CD4-212 -Nanuq 5 -Nanuq 5 Nanuq 5 /Plan: CD4-212 -Plan: CD4-212 -CD4-~ Plan: CD4-16 -Plan: CD4-16 -CD4-16wp02 Plan: CD4-17 -Plan: CD4-17 -CD4-17wp01 Plan: CD4-203 -Plan: CD4-203 -CD4-203wp04 Plan: CD4-204 -Plan: CD4-204 -CD4-204wp04 Plan: CD4-205 -Plan: CD4-205 -CD4-205wp04 Plan: CD4-206 -Plan: CD4-206 -CD4-206wp05 Plan: CD4-207 -Plan: CD4-207 -CD4-207wp04 Plan: CD4-209 -Plan: CD4-209 -CD4-209wp07 Plan: CD4-211 -Plan: CD4-211 -CD4-211wp04 Plan: CD4-213 -Plan: CD4-213 -CD4-213wp03 Plan: CD4-214 -Plan: CD4-214 -CD4-214wp03 Plan: CD4-215 -Plan: CD4-215 -CD4-215wp03 Plan: CD4-320 -Plan: CD4-320 -CD4-320wp06 Alpine Satellites Nanuq 5 -Nanuq 5 -Nanuq 5 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (ft) (ft) (ft) 11,908.39 16, 725.00 1,142.84 13,111.65 15,050.00 1,112.90 11,753.12 17,085.00 1,453.37 625.33 625.33 350.74 350.74 300.75 830.74 830.74 375.59 425.59 450.79 350.79 648.70 500.52 649.51 649.47 751.98 350.79 550.79 350.79 499.65 625.00 625.00 350.00 350.00 300.00 825.00 825.00 375.00 425.00 450.00 350.00 650.00 500.00 650.00 650.00 750.00 350.00 550.00 350.00 500.00 No-Go Allowable Distance Deviation (ft) from Plan (ft) 268.89 990.07 286.64 930.81 286.01 1,236.85 39.44 39.44 161.81 161.81 181.69 33.75 33.75 120.44 140.43 140.76 120.81 100.81 78.81 60.82 20.31 21.06 60.16 80.31 100.33 201.79 55.90 55.90 39.65 12.45 26.99 12.45 26.99 7.42 154.39 7.42 154.39 6.08 175.61 15.76 18.17 15.76 18.17 7.90 112.54 8.99 131.45 9.39 131.37 7.22 113.60 13.69 87.11 10.62 68.18 13.71 47.11 13.85 6.46 16.07 5.01 7.36 52.80 11.70 68.61 7.36 92.97 10.61 191.18 1.17 38.49 Warning Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 5/10/2006 9:45:45AM Page 2 of 2 COMPASS 2003.11 Build 50 C G' z s r cnslNC oeraLs `~ Calcda0on Method: Minimum Curvature ConoeoPhillips Frror System 19CWSA "° ,w ,~ Name Sim swnMethod:rta~.cyrnde,rb.,n Project: Colville River Unit ~ , 2/00.00 2sw.39 eva•'ceg-,2,M••Hde 958 a,«su,ra~e: e,,;p,wa,conw Site: AI ineCD4 : e2u.,a r/n.37 7"CSg-83//"Mde ] Wamirg Method: Rules Based P 3 8205 A' 1 80 13115 ]2 /12"l 81 8"Hd ,"' . . ir- 1 e 41x1 /'11GISt~p Geodetc Datum: NAD 1927 (NADCON CONU3) Well: Plan: CD4210 , Magre,¢Model. 6(~GM2005 Wellbore: Plan: CD4210 HALLIBURTON GroundLavol 19.60 Plan: CD4210wp06 ftKB. Plonne<i Doyon 19 X55-BOIL (Goyon 19 (36.3 + 1 .8)) ~ , • Nudhing/ASP Y: 5957483.77 3p~rry Drilling 3~rvle~s Fasting/ASP %: 377999.4] 800 0 6000 Z p.NP~6 G~ ~,0~ G~ ~1 4000 ~$P O~''~ G -- ~ c \ 0 0 N t ~ t 2000- 0 Z t rn CD4319 `~ M ~ ~ G Q ~~ ~ ~ ~ ~ ~ 0 ~ z ' ~ , - 2000 I i ~~1 ~ / _ I - ,~,~$ ~ - - - G~ 5 A Nan C0~318 Z -12000 -10000 -8000 -6000 -4000 ~ -2000 0 2000 4000 6000 , West(-)/East(+) (2000 fUin) C z `~ Project: Colville River Unit ConocoPhillips Site: a,IpineCD4 Well: Plan: CD4210 ~ ~ Alaska Wellbore: Plan: CD4210 Plan: CD4210wp06 HALLIBLiFiTON Groiincl Lovo l'. 19.b0 Sperry Drllting Services RK8 Pla nnod Doyon 19 dig 55.90[[ (Doyon 19 (36.3 ~ 19 i~jl I ~ • Northiny/ASP Y. 5957483.77 Fasting/ASP X. 377999 47 Nanuq 5 CD4-208 CD4-319 Op~6 OOSL t- ~ o °O°9_ CD4-210wp06 ~--- ~~ ~' °ps ~_ o ooo~-_ / ° oos-~_ Nanuq 3 / O % ~S'/ Op.n^Ir CenocoPkNpa Alaska lnc. Gid CoMCllom -0.95 lob Na rN/A N.IE: Cdvlle NVx Un4 Mapmtlc O.cMdbn: 2152 A]E Na NN/A wN: CD1~210ep06 Oip: 10.63 AN Ne: EN/A Ila IN/A DegMq px 100 SyaMm (NO) Ielxen<.: Mean Sea I.vN sxac.l«won Original VS Plane: 314.00 rs.N w.lt Nam cw-mo %: JA999A] n Vlew VS Plane: 314.00 IAe NNyIR. ss.ro 1 Y: 599)40.1)] 11 UnN Sytlem: API Iaa.A /fP5 SecHOn (VS)INxance: Lel Comments: Plan View m ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ M M ~ ~ ~ m ~ m m 'o 0 Z ~ n a h ah n M ro r] M o9 a7 M n n ~ w ~ ~ ~ 5965 5964 5963 5962 ~ ~. 5961 596 5959 ' 4 595 ~ i 5957 Z 595 595 d ~ - 5954 --- - ~ 595 595 5951 595 5949 n 5948 000 000 000 000 000 • 0000 000 8000 000 6000 5000 000 3000 2000 000 0000 000 000 O Section ViQW - y -CD4-210wp06 Plon -+-CD4-208 ~-Nanuk I ~~ -+-Nanuk2 ~Nanug3 -~-NanugS ~/V 'V~ ../// ..~~ ,/~ 1 ~~~ S L_ D 0 U 1 0 E T 4000 • 5000 6000 7~~ 8000 9000 ~ o ~ ~ ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O O O O O ' P P a A a P ~ P P P P P a P P P P O P W I~ ~O ~ V M N - N M V h ~O t~ c0 P O N M Q N ~O Venical Section along "View VS Plane" Combo Preview Page 1 of 1 (CD4-210wp06 Toolbox (5_10_2006).x15) 5/10/2006 12:49 PM Closest in POOL 1rY >~ Closest Approach: Reference Well: CD4-210wp06 Plan Offset Well: CD4-208 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. ..,.>,,<. Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Dist. Depth Incl. Angle TRUE Azi. TVO E(+)NV(-) (314°) Comments Depth Incl. Angle TRUE Azi. TVD E(+)NV(-) (314°) Comments POOL Min Distance POOL Min Distance (1482.87 ft) in POOL (1482.87 ft) in POOL (7423 - 13115.73 MD) (7423 - 13115.73 MD) to CD4-208 (6135 - to CD4-210wp06 Plan 1482.87 8900 90.43 334.07 6190.821 5958338 375113 2646.84 6290 TVDss) 9700 85.41 336.51 6136.956 5958953 376461.2 2126.966 (6135 - 6290 TVDss) Closest Approach: Reference Well: CD4-210wp06 Plan Offset Well: Nanuq 3 Coords - Coords.- 3-D etr- ASP ASP ctr Min. „>,.. Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Dist. Depth Incl. Angle TRUE AZi. TVD E(+)NV(-) (314°) Comments Depth Incl. Angle TRUE Azi. 7VD E(+)/W(-) (314°) Comments POOL Min Distance POOL Min Distance (1738.81 ft) in POOL (1738.81 ft) in POOL (7423 - 13115.73 MD) (7423 - 13115.73 MD) to Nanuq 3 (6135 - to CD4-210wp06 Plan 1738.81 8600 90.43 334.07 6193.073 5958066 375239.8 2365.066 6290 TVDss) 7525 23.59 272.32 6139.112 5957333 373664.2 2962.474 (6135-6290 TVDss) Closest Approach: Reference Well: CD4-210wp06 Plan Offset Well: Nanuk 2 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. F.cr r., ~, .. Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+~S(-) Vrew VS Dist. ':.~ i.,., Depth Incl. Angle TRUE AZi. TVD E(+)/W(-) (314°) Comments Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (314°) Comments POOL Min Distance POOL Min Distance (2959.43 ft) in POOL (2959.43 ft) in POOL (7423 - 13115.73 MD) (7423 - 13115.73 MD) to Nanuk 2 (6135 - to CD4-210wp06 Plan 2959.43 ;'. ~ 7423.37 83 334.07 6180.128 5957000 375736.9 1260.315 6290 TVDss) 7050 1.89 272.92 6139.274 5954429 374272.1 442.1149 (6135-6290 TVDss) Closest Approach: Reference Well: CD4-210wp06 Plan Offset Well: Nanuk 1 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. I'.o .-..,.. Meas. Subsea N(+)/S(-) Viaw VS Meas. Subsea N(+)/S(-) View VS Dist. Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (314°) Comments Depth Incl. Angle TRUE Azi. TVD E(+)NV(-) (314°) Comments POOL Min Distance POOL Min Distance (3409.29 ft) in POOL (3409.29 ft) in POOL (7423 - 13115.73 MD) (7423 - 13115.73 MD) to Nanuk 1 (6135 - to CD4-210wp06 Plan 3409.29 7423.37 83 334.07 8180.128 5957000 375736.9 1260.315 6290 TVDss) 6200 0.5 12.12 6160.876 5958137 378951.1 -203.336 (6135-6290 TVDss) CD4210wp06 PoolSummary.xls 5/10/2006 10:30 AM • • • • __ SHARgqN K. ALLSUP-DRAKE CONO~OPHILLIPS 1148 ATO 1530 700 G ST. ANCHORAGEAK 99501 n DATE ~"' ~ ss-tssi/aai PAY TO THE ~ 1 ~~ / l L/ (~~r[ ~~ ORDER OF / / ( ,, / /' d //~y~ /'mil ~ '~ -~.'_' ( /Gl- ~ °~~ ~L l /S ~ 1/~-~-e/lam ,D` b~L7.7C1~5(l/t/. CJ~I/ ~F....., i `~' ,~,~ JPMorganChase ~ valiaupro5000~aiars JPMorgan-Chase Barik, NA. Columbus, OH ~ '~ MEMO __ i _ .4L~ ~~~'C - ~ ~ ~ -- f ~.044i155L1~.528747i90?927n'1L4$ ~,. _ _ _. ._ .._. --tmuvEASU.- __ • TRANSMITTAL LETTER CHECKLIST WELL NAME C~~ ~ T ' Z ~~ PTD# ~~ ~° '~ 6 ~ ~ / Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL" The permit is for a new wellbore segment of existing well , (If last two digits in permit No. 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. 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 10' 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 well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\j ody\transmittal_checkl i st • • ^^ y ~ ~ ~ ~ m a> o o- , y y , a~ ~ , o ~ ~ L , O C ~ ~ ~ ~ ~ O' ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N, ~ ~ ~ ~ ~ ~ ~ ~ ~ t A , Q ~ ~ ~ N N. ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ lD~ ~ ~ p. ~ ~ ~ ~ ~ ~ ~ ~ CO.T ~ O =~ Z o ~ p ~, ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ fps v. ~ ~' V~ ~ ; o ~ s ~ ° m. , c c p v, '~ o, a ~ ~ , ~, ~, o y, N. , ~ N, n as , ~ d of ~, ~ ~, c. c• • ~ 'N, fl, E. , ~, o o , ~ c. o, c o o' ~ a ' w cn ~ v. Z; - 3' ~ v. m ~~ Z. y o o' m, o. m , m a m ~ O m~ ~ ' ~ ~ ~ >, o, a~ a ,n, , ~, r ; o m '~ E O ~ Sri c 2i U' o o ~_ ~ y 4 o°i, - o. °~ a o y. 3. '; ; ~ O ~ i ~ y ~ ~~ ~ N. ~~ ~ ~ ~ ~ ~ Q f6 ~~ C a W ~ 7 ~ _ Y ~ 7 ~ d p M' ~ ~' + y a ' ~ ~ ~ ~ ~ ~ ~ ~, , , , ~ ~ c ao, ~ ~. ~ ~ ~ . a~ a ~' '' , ~ ' Q. > c ~~ ~? ~ ~ ~ ~ 3. ~, ~ v ~ m ~ . o , v, y , C C N ~ C N 3 N r~ r ~ ~ d~ ~~ - 'V~ •V, C• ~ ~ ~ ~ ~ ~ I I ~ ~ ~ ~~ ~ ~ G ~, ~ d N ~ .0.~ ~ m O, ~ y c ~ N Of t. `n m ~ ~ O, ~ y ~ ~~ ~ ~ ~ 4 a; ~ ~ i a 3. , M ~ j f0 - - C• ~ ~ ~ ( C• ~ •a G Q W p ~ y N. O, Z Q Z ~ ~ O ~ W ~ O • C• ~ ~ . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ p~ OI ~ • ~ f6, ~ ~ p~ . ~ ~ Z C• C ~, ~ ~ ~ C• O. )~ N. ' ~, O. 7. N ~~ N~ O. ~~ Q =~ , y' ~ ~ ~ ~ c; ui ui ~, ~ ~ 'm o. O Z' t ~ o, 0 n ~, a , , ~ C' ~ ~ ~, N• N• N• ~ ~ ~ ~ ~ ~ i p. ~ 'O C. ~ '-' ~ ~, Z. O• ~ ~ (0. • y N~ J ° ~ ~ ~ ~ ~ ~ ; 3 n ~, ~ m o N o ~ 4 ~, ~ o d , , d o, L, ~ ~ ~ . Q, l o~ . ~~ y~ c, ~ a°~i; ~ o, a? ~~, o o. , , ~ c, ai~ ~ -~ ~ 0 (~ Z Z Z 7 O o N~ Q ojf~ ~ ~ "O, a~ ~, ~, ~~ _~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i ~ Q ~ Q~ ~ O. ~~ ~ N. Q ~ t. •3. . ~ ~ ~ y. ~ y. ~ ~ ~ l0. ~ ~ ~ ~ I C• r 'O. N~ ' •~ N, y « . m ~ y o, ~ ~ ~, a ~, •m a~ o a c~ ' Z ' Z ~ ~ ~ y. p j C• ~ ~ ~ ~ ( ~ ~ ~ ~~ ~ N '~~ ~ ~ d ~ L' ~ ~ a ~ ~ ~ + O m O > W 3 ~ O O• O• O• ~ ~ ~ ~ ~ ~ ~ ~ O• . ~ C• ~ ~ . ~ f6• ~ Q. ~ ~ N, N• X• (n U (~ U~ U. N ~ Z. Q y, ~, a, ~ ~ ~ _, _, W. ~, W ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ V ~, a tlD y~ ~, ~ ~-, } y~ y~ y~ y~ ~, ~ ~ ~ }, r; }, }, VA Uh ~, ~, >-, r, VD ~, r, tlN y~ y~ ~, ~, ~ r, r, r, y ~ r y~ ~ 1 ~ a. a' a. ~, z, z' z y~ ~, a. >-, z y~ ~ ~ ~ o, o, }, z z V} y~ ~, ~, ~-, >- y, y~ a. ~, a ~ z ~-, z }, y~ y~ y~ ~, ~, ~, >-, }, r, y~ ~ ~ o, a; r, z z t/D y~ V} ~, ~ ~, a, ~, ~•, }, z a z T y T I O' ~ ~ ~ ~ C ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , E r ~ o a 3 , rr O`, ~~ ~ ~ c. o, • v. a~, ~ ~, p ~ m ~ ~ ~ ~ ~ ~ ~~ ~ ~, y' Q N, y, N• ~ ~ rn W. ~ U ~ ~ a a ~ ~ N~ ~, ~ U~ ~ ~ ~ O~ ~ ~ ~ a X, ~ Z ~ ~ C, ~ 7. ~ ~ ~ ~ ~ ~ ~ ~ >~ , O. C. O, N~ ~ ~' .~ C• ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ O, p_ ~ ~ c6~ f6. O ~ ~ ~ ~ ~ C, ~ ~ ~ ~ LLy ~ ~ -O~ ~ ~ ~ 7 ~ ~ ~ N O, y' ~ f6 ~ Q ~ ~ Q ~ ~ ~ ~ ~ ~ ~ 4 ' ~~ -O, O. Q• y y `~ ~y C ~ W N N 0 ~ d . ~ ~ U. ~ ~ ~ a~ ~ ~ ~ ~ ~ ~ ~ 4T O. ( ~ Y Q' ~ ~ ~ ~ 7. N. ~ ~ C• ~ •~ N, p 'O, ~ ~ y O, 7. COQ ~~ ~ ~, ~ ~~ y, f6 ~ C ~ >~ N• N, ~ ~ ~' W ~ pp >i, •C O. ~ ' 3 d ~ ~ M ~ U y. •N. fl: ~ ~ O. - ' py ~ 30 Q' 'a, N, ~ y. p `ti ~ c ~, , _ ~~ ~ ~ ~~ ~, ~ y, T m ~, ~, 4. ~ 3. m. ~o, ~ ~, ~ ~ ~, `o ~ . ~~ ~ ~, ~, ~, .4 ~ ' ' M~ o, ,n, v~ ~ p. ~ Q~ ~, ~, ~ y, ui ~ ' ~' U Z ~ -a a ~ c. ~ Z o, o •c. v O m. a~~ o, N ~ c rn o, c, o m. C y O o. o. rn ~r d 7 r. c y N y N ~, c. Of a ~ J ~ ~ ~ ~ E~ E, -~ 'D. v _ C, C E' ' ' r _ ~, N O M tn' C 3' C tll, > ' ~ ~ .-,~ C ~ `', °~ ' ~~ ~ c' C. N. ~ ~ pl ~' N L ' y' O. ~ C 3 • ~ ~ 0 o ~, w ~ ~ a o ~ o m ~ o' Q in o ~ o ~ ~ U 'Q, m ~, °; ~, ~, o ~, d ' ° ~ 3 m ui 8 >~ co ~ ~; Y c a~ y J _ ~ O N c •C 1 ; 7 7 O w ; 'O f6 O ~ Y Y, O' O~ O' p ~~ ~' ~~ f6• Q~ N. ~~ y. >. O. pp O. N• ~ ,N ~ Q m. ~~ a ~ ~ ~ c . ~ , ~ t , °. ~ ~ m. ~, y. . . , S °* ~ ~ °, %, ~= m, rn o N o; a 3 d m; o w ~ • ~ , o , _ s v m ~ ° , M , ~ , ~ o a a a' ° a. a, > ~ ~ 3, 3. • ~~ m > m, ~ ~, a v_, ~ ~, 3, 'v. . -:, o ~, ~ o a~ ~ a ~ ~' , a a a ~ ~, o. 3, o. t, ~ °, w U 0 4 -~ o v. c. r=. m, m ' a a ' a m a a~ 2'i, a a, a, o. o o ' ' o ~, o, c ~' o, ' ~' ~, ~' ' o. o~ c ,e, ¢ o, ~, v. o y' E' ' ' ~ a~ f°' E' ' o rn c o ~ ~ v. y. o °' ,~ u~i ' ' ' ~, ' . ~ a~ ~ ~ 4 ~ ~ a N 4 O _ N N ~ ~ ~ U y a c U N ~ d o :? °? - a N ~ m m ~ rn o ~ U _ «. N ~ o c o ~ = L U. N. . L ~~ ~ O. O, ~ N 3 . ~~ A ~ 4 N, N~ d N , ~ . .L..,, r, 'C, y, OI 0- ~ ~ N f6 f0 gyp, f/Y N ~ f6~ O `~~~ ~ ' , C, , T ~ 'O ~ , 3 =. C~~ y. C• y O~ y~ O. L. O. a d ~ :.6 ~~ Q N• C' C. O. 4 - ' N. ~ U T O' y' y' ~ Q ~ N -O 3' C' ~' m ' « G m O' O' N' G Y' ~ ~ N' ~ ~' O L ~ ~ ~~ ~~ O' ~' "- Q " ~ U N• N~ T ~' O C ~, ~ ~ . o, ~ O~ -, 6~ a~ ~, c> a~ a~ ~ . ca, .a C• o, ~ ~ ~ ~, ~ ' y' C, ~ • , ~ y y 'O 'O p' , ~ . , , . 3~ , ~~ C a, , ~ • o, iy ~ . . C f0~ ~ y ~ ~ , ~ O ~ m a a o' ° '~ ~, ~ ~ ° E 3 o a ~, .°, o ~ o ~ ~ , • o ~ ~ o, ~ _ ` o ~ ~ Q ,3 N, . ~ ~ ° o ~ ~ ' ti an ~, ~' ~' , o o, o. _, coi' ' , 3 = v ~, ~ r ~ vi. ~ 0 a. a ~, J U E' ~ a -' -' -' ~ ~ ~ ~ a ' m. a~~ ~, ~ c - 3, °i c ' ~ c. 'C, F-; I- !-; ' y; m `> aoi~ ? o d; a; o. '~ ~ cLi ~ ~ ~, w; ~ c. m Y >, c a~~ a~~ a J c, °~ °~ °~ ~ ~,~;~, ~, v ~n ~-; 4 O ~ a~ a~ a;a; O m U o ~ o, - ~ z ~;da o, ~, v ~ ~, ~ , ~, ~ ~ ~ m, v, ¢ ~ co a, ~° ._ "=~a "-'~p~ O, O, t, m m U ° ~ ~ ~, ~,~~ a~~ m. a~~ a~~ o ~ ~ ~- o. U ~ U w a , , , , , , , , , , ~ ~ ~ , ~ , ~ , , ~ , , , , , N M I to (O f~ 00 ~ ~ ~ ~ ~ r~ ~ ~~ _ N N N N N N N N N _ N M M M M M M M M M M U U ~ o 0 0 o y o d c C C (`0 0 N ~ N lYp N V O 4 L G ~ ~ O . J ° N ~+ ~ ~ ~ C7 E J #k p c ~ o ~ U d Q ~ W Q H ~ Q~ Q • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permilting Process but is part of the history file. To improve the readability of the Well History file and to simplify rending information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jul 19 08:40:00 2006 Reel Header Service name .............LISTPE Date .....................06/07/19 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing. Library Tape Header Service name .............LISTPE Date .....................06/07/19 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 Colville River Nanuq MWD/MAD LOGS WELL NAME: CD4-210 API NUMBER: 501032053300 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 19-JUL-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: W-0004443583 W-0004443583 W-0004443583 LOGGING ENGINEER: E. QUAM E. QUAM E. QUAM OPERATOR WITNESS: D. BURLEY D. LUTRICK D. LUTRICK MWD RUN 5 JOB NUMBER: W-0004443583 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: D. LUTRICK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE ~6 - o~~- 24 11N 4E 2352 245 37.20 19.60 CASING DRILLERS ~ ~YoaS- 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT S~ (IN) 8.750 6.125 SIZE (IN) DEPTH (FT) • 9.625 2540.0 7.000 7470.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) GEOPILOT ROTARY-STEERABLE BHA (GP) ALSO WAS INCLUDED IN MWD RUNS 2,4,5. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-5 REPRESENT WELL CD4-210 WITH API#: 50-103-20533-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11710'MD/6218'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 (SEDP). 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.......06/07/19 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 D H STOP DEPTH GR 2513.0 11652.5 RPD 2525.0 11659.5 RPS 2525.0 11659.5 RPM 2525.0 11659.5 FET 2525.0 11659.5 RPX 2525.0 11659.5 ROP 2550.5 11710.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 2 2513.0 3 5911.0 4 7480.0 5 7500.0 REMARKS: MERGED MAIN PASS. MERGE BASE 5911.0 7480.0 7500.0 11710.5 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down .Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .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 2513 11710.5 7111.75 18396 2513 11710.5 RPD MWD OHMM 0.58 2000 19.5933 18270 2525 11659.5 RPM MWD OHMM 0.76 2000 15.459 18270 2525 11659.5 RPS MWD OHMM 0.24 2000 12.4433 18270 2525 11659.5 RPX MWD OHMM 0.21 1350.01 10.0443 18270 2525 11659.5 FET MWD HOUR 0.21 74.75 1.57004 18270 2525 11659.5 GR MWD API 52.64 182.55 97.8174 18280 2513 11652.5 ROP MWD FT/H 0.3 271.58 104.695 18321 2550.5 11710.5 First Reading For Entire. File..........2513 Last Reading For Entire File...........11710.5 File Trailer Service name............~LIB.001 • Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/19 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.......06/07/19 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 for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2513.0 5873.5 RPD 2525.0 5865.5 RPM 2525.0 5865.5 RPX 2525.0 5865.5 RPS 2525.0 5865.5 FET 2525.0 5865.5 ROP 2550.5 5911.0 LOG HEADER DATA DATE LOGGED: 16-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5911.0 TOP LOG INTERVAL (FT) 2550.0 BOTTOM LOG INTERVAL (FT): 5911.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 19.8 MAXIMUM ANGLE: 30.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 56933 BOREHOLE AND CASING DATA OPEN HOLE BIT SIDE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2540.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.60 MUD VISCOSITY (S) 40.0 MUD PH: • 8.8 • MUD CHLORIDES (PPM): 6200 FLUID LOSS (C3) 14.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.080 66.0 MUD AT MAX CIRCULATING TERMPERATURE: .620 120.0 MUD FILTRATE AT MT: 1.880 66.0 MUD CAKE AT MT: 1.070 66.0 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 MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 l 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2513 5911 4212 6797 2513 5911 RPD MWD020 OHMM 0.58 2000 11.2823 6682 2525 5865.5 RPM MWD020 OHMM 0.76 1350.36 5.10337 6682 2525 5865.5 RPS MWD020 OHMM 0.68 1350.17 5.08172 6682 2525 5865.5 RPX MWD020 OHMM 0.43 1350.01 5.0083 6682 2525 5865.5 FET MWD020 HOUR 0.21 50.41 0.868505 6682 2525 5865.5 GR MWD020 API 54.75 182.55 108.861 6722 2513 5873.5 ROP MWD020 FT/H 2.51 271.58 156.247 6722 2550.5. 5911 First Reading For Entire File..........2513 Last Reading For Entire File...........5911 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/19 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.......06/07/19 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5866.0 7431.5 FET 5866.0 7431.5 RPM 5866.0 7431.5 RPD 5866.0 7431.5 RPS 5866.0 7431.5 GR 5874.0 7439.0 ROP 5911.5 7480.0 LOG HEADER DATA DATE LOGGED: 18-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7480.0 TOP LOG INTERVAL (FT) 5911.0 BOTTOM LOG INTERVAL (FT) 7480.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 30.9 MAXIMUM ANGLE: 83.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 56933 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2540.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.60 MUD VISCOSITY (S) 38.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3) 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.500 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .820 134.0 MUD FILTRATE AT MT: 1.200 70.0 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 1.800 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5866 7480 6673 3229 5866 7480 RPD MWD030 OHMM 4.53 27.62 8.53224 3132 5866 7431.5 RPM MWD030 OHMM 4.54 29.08 8.72745 3132 5866 7431.5 RPS MWD030 OHMM 4.53 28.17 8.36936 3132 5866 7431.5 RPX MWD030 OHMM 4.46 25.04 7.90707 3132 5866 7431.5 FET MWD030 HOUR 0.48 14.99 1.45774 3132 5866 7431.5 GR MWD030 API 56.18 149.15 98.217 3131 5874 7439 ROP MWD030 FT/H 0.53 200.67 76.6506 3138 5911.5 7480 First Reading For Entire File..........5866 Last Reading For Entire File...........7480 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/19 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.......06/07/19 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 7432.0 7449.5 FET 7432.0 7449.5 RPM 7432.0 7449.5 RPX 7432.0 7449.5 RPD 7432.0 7449.5 GR 7439.5 7442.5 ROP 7480.5 7500.0 LOG HEADER DATA DATE LOGGED: 20-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7500.0 TOP LOG INTERVAL (FT) 7480.0 BOTTOM LOG INTERVAL (FT) 7500.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.8 MAXIMUM ANGLE: 83.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87224 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 7470.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.80 MUD VISCOSITY (S): 40.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.400 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .740 138.0 MUD FILTRATE AT MT: 1.100 70.0 MUD CAKE AT MT: 1.800 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7432 7500 7466 137 7432 7500 RPD MWD040 OHMM 2.94 2000 1411.4 36 7432 7449.5 RPM MWD040 OHMM 2.59 2000 1010.92 36 7432 7449.5 RPS MWD040 OHMM 2.51 2000 548.202 36 7432 7449.5 RPX MWD040 OHMM 1.55 3.95 2.345 36 7432 7449.5 FET MWD040 HOUR 51.64 51.71 51.6922 36 7432 7449.5 GR MWD040 API 56.78 66.49 61.3586 7 7439.5 7442.5 ROP MWD040 FT/H 0.3 89.65 73.0747 40 7480.5 7500 First Reading For Entire File..........7432 Last Reading For Entire File...........7500 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/19 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.......06/07/19 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7443.0 11652.5 RPM 7450.0 11659.5 RPX 7450.0 11659.5 RPS 7450.0 11659.5 RPD 7450.0 11659.5 FET 7450.0 11659.5 ROP 7500.5 11710.5 LOG HEADER DATA DATE LOGGED: 26-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11710.0 TOP LOG INTERVAL (FT) 7500.0 BOTTOM LOG INTERVAL (FT) 11710.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.5 MAXIMUM ANGLE: 94..1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87224 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 7470.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.20 MUD VISCOSITY (S) 42.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 29000 FLUID LOSS (C3) 9.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .180 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .090 141.8 MUD FILTRATE AT MT: .150 70.0 MUD CAKE AT MT: .260 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type........~.......0 • Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .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 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 7443 11710.5 9576.75 8536 7443 11710.5 RPD MWDO50 OHMM 6.74 1905.52 24.3526 8420 7450 11659.5 RPM MWD050 OHMM 1.63 2000 21.9249 8420 7450 11659.5 RPS MWD050 OHMM 0.24 1164.11 17.51 8420 7450: 11659.5 RPX MWD050 OHMM 0.21 1113.15 14.8687 8420 7450 11659.5 FET MWD050 HOUR 0.38 74.75 1.95424 8420 7450 11659.5 GR MWD050 API 52.64 145.8 88.8828 8420 7443 11652.5 ROP MWD050 FT/H 0.39 146.5 74.1444 8421 7500.5 11710.5 First Reading For Entire File..........7443 Last Reading For Entire File...........11710.5 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/07/19 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................ST5 LIS Writing Library. Reel Trailer Service name .............LISTPE Date............ .......06/07/19 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Scientific Technical Services Comments ................~5 LIS Writing Library. Scient~c Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 13 15:24:49 2007 Reel Header Service name ....... ......LISTPE Date ............... ......07/04/13 Origin ............. ......STS Reel Name .......... ......UNKNOWN Continuation Number ......01 Previous Reel Name. ......UNKNOWN Comments ........... ......STS LIS Writing Library Tape Header Service name ....... ......LISTPE Date ............... ......07/04/13 Origin ............. ......STS Tape Name .. ......... ......UNKNOWN Continuation Number ......01 Previous Tape Name. ......UNKNOWN Comments ........... ......STS LIS Writing Library Physical EOF ~J Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Colville River Nanuq MWD/MAD LOGS WELL NAME: CD4-210 API NUMBER: 501032053300 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 13-APR-07 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: MW0004443583 MW0004443583 MW0004443583 LOGGING ENGINEER: E. QUAM E. QUAM E. QUAM OPERATOR WITNESS: D. BURLEY D. LUTRICK D. LUTRICK MWD RUN 5 JOB NUMBER: MW0004443583 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: D. LUTRICK SURFACE LOCATION SECTION: 24 TOWNSHIP: 11N RANGE: 4E FNL: FSL: 2352 FEL: 245 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 37.20 GROUND LEVEL: 19.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2540.0 2ND STRING 6.125 7.000 7470.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED ~~~~~ Y ~~ APR 1 7 2007 '~iG ~ a ~Ar W1N. ~}u,N f~li • THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) GEOPILOT ROTARY-STEERABLE BHA (GP) ALSO WAS INCLUDED IN MWD RUNS 2,4,5. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-5 REPRESENT WELL CD4-210 WITH API##: 50-103-20533-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11710'MD/6218'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 (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name ............ .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .07/04/13 Maximum Physical Record. .65535 File Type ............... .LO Previous File Name...... .STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2513.0 RPD 2525.0 RPS 2525,0 RPM 2525,0 FET 2525.0 RPX 2525.0 ROP 2550.5 all bit runs merged. STOP DEPTH 11652.5 11659.5 11659.5 11659.5 11659.5 11659.5 11710.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH C~ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 MWD 5 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2513.0 5911. 0 5911.0 7480. 0 7480.0 7500. 0 7500.0 11710. 5 Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .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 Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2513 11710.5 7111.75 18396 2513 11710.5 RPD MWD OHMM 0.58 2000 19.5933 18270 2525 11659.5 RPM MWD OHMM 0.76 2000 15.459 18270 2525 11659.5 RPS MWD OHMM 0.24 2000 12.4433 18270 2525 11659.5 RPX MWD OHMM 0.21 1350.01 10.0443 18270 2525 11659.5 FET MWD HOUR 0.21 74.75 1.57004 18270 2525 11659.5 GR MWD API 53.32 182.55 98.3397 18280 2513 11652.5 ROP MWD FT/H 0.3 271.58 104.695 18321 2550.5 11710.5 First Reading For Entire File..........2513 Last Reading For Entire File...........11710.5 File Trailer Service name .......... ...STSLIB.001 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/04/13 Maximum Physical Record..65535 File Type ............. ...LO Next File Name........ ...STSLIB.002 Physical EOF File Header Service name ........... ..STSLIB.002 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/04/13 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2513.0 5873.5 RPD 2525.0 5865.5 RPM 2525.0 5865.5 RPX 2525.0 5865.5 RPS 2525.0 5865.5 FET 2525.0 5865.5 ROP 2550.5 5911.0 LOG HEADER DATA DATE LOGGED: 16-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5911.0 TOP LOG INTERVAL (FT) 2550.0 BOTTOM LOG INTERVAL (FT) 5911.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 19.8 MAXIMUM ANGLE: 30.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 56933 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2540.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.60 MUD VISCOSITY (S) 40.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 6200 FLUID LOSS (C3): 14.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.080 66.0 MUD AT MAX CIRCULATING TERMPERATURE: .620 120.0 MUD FILTRATE AT MT: 1.880 66.0 MUD CAKE AT MT: 1.070 66.0 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 MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2513 5911 4212 6797 2513 5911 RPD MWD020 OHMM 0.58 2000 11.2823 6682 2525 5865.5 RPM MWD020 OHMM 0.76 1350.36 5.10337 6682 2525 5865.5 RPS MWD020 OHMM 0.68 1350.17 5.08172 6682 2525 5865.5 RPX MWD020 OHMM 0.43 1350.01 5.0083 6682 2525 5865.5 FET MWD020 HOUR 0.21 50.41 0.868505 6682 2525 5865.5 GR MWD020 API 54.75 182.55 108.861 6722 2513 5873.5 ROP MWD020 FT/H 2.51 271.58 156.247 6722 2550.5 5911 First Reading For Entire File..........2513 Last Reading For Entire File...........5911 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5866.0 7431.5 FET 5866.0 7431.5 RPM 5866.0 7431.5 RPD 5866.0 7431.5 RPS 5866.0 7431.5 GR 5874.0 7439.0 ROP 5911.5 7480.0 LOG HEADER DATA DATE LOGGED: 18-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7480.0 • TOP LOG INTERVAL (FT) 5911.0 BOTTOM LOG INTERVAL (FT) 7480.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 30.9 MAXIMUM ANGLE: 83.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMA G. RESIS. 4 56933 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2540.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S) 38.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3) 4.2 RESISTIVITY (OHMM) AT TEMPE RATURE (DEGF ) MUD AT MEASURED TEMPERATURE (MT) 1.500 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .820 134.0 MUD FILTRATE AT MT: 1.200 70.0 MUD CAKE AT MT: 1.800 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefine d Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefine d Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Ns am Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5866 7480 6673 3229 5866 7480 RPD MWD030 OHMM 4.53 27.62 8.53224 3132 5866 7431.5 RPM MWD030 OHMM 4.54 29.08 8.72745 3132 5866 7431.5 RPS MWD030 OHMM 4.53 28.17 8.36936 3132 5866 7431.5 RPX MWD030 OHMM 4.46 25.04 7.90707 3132 5866 7431.5 FET MWD030 HOUR 0.48 14.99 1.45774 3132 5866 7431.5 GR MWD030 API 56.18 149.15 98.217 3131 5874 7439 ROP MWD030 FT/H 0.53 200.67 76.6506 3138 5911.5 7480 • • First Reading For Entire File..........5866 Last Reading For Entire File...........7480 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 7432.0 7449 .5 FET 7432.0 7449 .5 RPM 7432.0 7449 .5 RPX 7432.0 7449 .5 RPD 7432.0 7449 .5 GR 7439.5 7442 .5 ROP 7480.5 7500 .0 LOG HEADER DATA DATE LOGGED: 20-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7500.0 TOP LOG INTERVAL (FT) 7480.0 BOTTOM LOG INTERVAL (FT) 7500.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.8 MAXIMUM ANGLE: 83.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87224 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 7470.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.80 MUD VISCOSITY (S) 40.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 1000 • • FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.400 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .740 138.0 MUD FILTRATE AT MT: 1.100 70.0 MUD CAKE AT MT: 1.800 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....DOwn Optical log depth units....... ....Feet Data Reference Point .......... ....Undefine d Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefine d 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 Ns am Reading Reading DEPT FT 7432 7500 7466 137 7432 7500 RPD MWD040 OHMM 2.94 2000 1411.4 36 7432 7449.5 RPM MWD040 OHMM 2.59 2000 1010.92 36 7432 7449.5 RPS MWD040 OHMM 2.51 2000 548.202 36 7432 7449.5 RPX MWD040 OHMM 1.55 3.95 2.345 36 7432 7449.5 FET MWD040 HOUR 51.64 51.71 51.6922 36 7432 7449.5 GR MWD040 API 57.87 79.17 64.2029 7 7439.5 7442.5 ROP MWD040 FT/H 0.3 89.65 73.0747 40 7480.5 7500 First Reading For Entire File..........7432 Last Reading For Entire File...........7500 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7443.0 11652.5 RPM 7450.0 11659.5 RPX 7450.0 11659.5 RPS 7450.0 11659.5 RPD 7450.0 11659.5 FET 7450.0 11659.5 ROP 7500.5 11710.5 LOG HEADER DATA DATE LOGGED: 26-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11710.0 TOP LOG INTERVAL (FT) 7500.0 BOTTOM LOG INTERVAL (FT) 11710.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.5 MAXIMUM ANGLE: 94.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87224 EWR4 Electromag Resi s. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 7470.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.20 MUD VISCOSITY (S) 42.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 29000 FLUID LOSS (C3}: 9.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .180 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .090 141.8 MUD FILTRATE AT MT: .150 70.0 MUD CAKE AT MT: .260 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet • • Data Reference Point ...... . .......Undefined Frame Spacing .. ........... . .......60 .1IN Max frames per record ..... . .......Undefined Absent value ... ........... . .......-999 Depth Units .... ........... . ....... Datum Specifica tion Block s ub-type...0 Name Service Order Units Siz e Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7443 11710.5 9576.75 8536 7443 11710.5 RPD MWDO50 OHMM 6.74 1905.52 24.3526 8420 7450 11659.5 RPM MWDO50 OHMM 1.63 2000 21.9249 8420 7450 11659.5 RPS MWDO50 OHMM 0.24 1164.11 17.51 8420 7450 11659.5 RPX MWDO50 OHMM 0.21 1113.15 14.8687 8420 7450 11659.5 FET MWDO50 HOUR 0.38 74.75 1.95424 8420 7450 11659.5 GR MWDO50 API 53.32 147.66 90.0142 8420 7443 11652.5 ROP MWDO50 FT/H 0.39 146.5 74.1444 8421 7500.5 11710.5 First Reading For Entire File..........7443 Last Reading For Entire File...........11710.5 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/04/13 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/04/13 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
